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188-076
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-05 KUPARUK RIV UNIT 3O-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 3O-05 50-029-21839-00-00 188-076-0 W SPT 6514 1880760 3000 2800 2800 2800 2800 120 140 140 140 REQVAR P Adam Earl 6/24/2025 MIT-IA tested as per AIO 2C.073 to max. ant.inj.psi 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-05 Inspection Date: Tubing OA Packer Depth 390 3520 3470 3450IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625080605 BBL Pumped:3.4 BBL Returned:3.3 Tuesday, July 22, 2025 Page 1 of 1 9 9 9 9 9 99 9 999 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.07.23 14:12:20 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3O-05 KUPARUK RIV UNIT 3O-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 3O-05 50-029-21839-00-00 188-076-0 W SPT 6514 1880760 3000 2900 2900 2900 2900 200 230 230 230 REQVAR P Austin McLeod 6/16/2023 Two year to MAIP. AIO 2C.073. 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-05 Inspection Date: Tubing OA Packer Depth 960 3510 3450 3440IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230617184737 BBL Pumped:2.5 BBL Returned:2.5 Thursday, July 27, 2023 Page 1 of 1 9 9 9 9 9 9 99 9 9 9 9 9 9 Two year to MAIP. James B. Regg Digitally signed by James B. Regg Date: 2023.07.31 11:18:14 -08'00' MEMORANDUM State of Alaska Insp Num: mitAGE210607102617 Alaska Oil and Cas Conservation Commission Rel Insp Num: DATE: Tuesday, June 8, 2021 TO: Jim Regg r P.I. Supervisor�r 61 lt'�)Zl SUBJECT: Mechanical Integrity Tests Well ConocoPhillips Alaska, Inc. Type lnj 30-05 FROM: Adam Earl KUPARUK RIV UNIT 30-05 Petroleum Inspector 2860. 2860 - 2860- Src: Inspector Reviewed By: PTD P.I. Supry J.' Type Test NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-05 API Well Number 50-029-21839-00-00 Inspector Name: Adam Earl Permit Number: 188-076-0 Inspection Date: 6/3/2021 Insp Num: mitAGE210607102617 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3405 Type lnj W ,TVD 6514 Tubing 2860. 2860 - 2860- 2860 - PTD 18eo76o Type Test sPr' est psi anon - TA oco 3300 - 3250 - 3250 - BBL Pumped: 2.2 - BBL Returned: 2.2 OA zoo - zzo - zzo zzo - Interval REQVAR _ P/F P Notes: Tested as per AIO 2C.073 to max ant. Inj. Psi. v Tuesday, June 8, 2021 1'agc I of I Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Friday, April 3, 2020 2:20 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: KRU 30-05 (PTD 188-076, NO 2C.073) Suspect IA Behavior Attachments: 30-05 TIO 4-3-20.pdf Chris, 30-05's 60 day monitor to investigate the slow IA pressure increase concluded yesterday. All of the IA pressure changes seen during the monitor period appear to be thermally induced. Attached is the 90 day TIO plot. Please let me know if you have any questions or disagree with the path forward. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Sunday, February 2, 2020 5:35 PM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU 30-05 (PTD 188-076, AIO 2C.073) Suspect IA Behavior Good Evening Chris, KRU water injector 30-05 (PTD 188-076, NO 2C.073) is exhibiting suspect slow IA pressure increase. The well has Administrative Approval for water -only injection due to known TxIA during gas injection. Very slight thermal fluctuations appear to be influencing the IA trend, but given this well's history with TxIA on gas injection we intend to place the well on a 60 -day monitor to better understand the nature of the IA pressure increase. If at any point during the monitor the well clearly indicates deviation from thermal fluctuations we intend to SI and secure the well. Otherwise, we will send an update at the end of the monitor period. Attached is a 90 -day TIO plot. Please let me know if you have any questions or disagree with the plan forward. Sincerely, Sa4,aLCarUA& (SE"k wv) / Steel' aoN & Padv Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Sunday, February 2, 2020 5:35 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 30 OS (PTD 188 076, AIC) 2C.073) Suspect IA Behavior Attachments: 30-05 TIO 8.17.19.pdf Good Evening Chris, KRU water injector 30-05 (PTD 188-076, AI0 20.073) is exhibiting suspect slow IA pressure increase. The well has Administrative Approval for water -only injection due to known TxIA during gas injection. Very slight thermal fluctuations appear to be influencing the IA trend, but given this well's history with TxIA on gas injection we intend to place the well on a 60 -day monitor to better understand the nature of the IA pressure increase. If at any point during the monitor the well clearly indicates deviation from thermal fluctuations we intend to SI and secure the well. Otherwise, we will send an update at the end of the monitor period. Attached is a 90 -day TIO plot. Please let me know if you have any questions or disagree with the plan forward. Sincerely, Sam, CarU41&C}wAi*)/Stepha*)d Pack Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549Pcop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Saturday, August 17, 2019 3:07 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: 30-05 PTD#(188-076) IA Pressurization on Gas Injection Attachments: 30-05 TIO 8.17.19.pdf; 30-05.pdf Hi Chris, KRU gas injector 30-05 (PTD 188-076) was previously suspect for TxIA during gas injection. The well exhibited integrity during a 30 -day water injection monitor period. Upon completing well work to replace the dummy gas -lift valves with new extended packing valves and circulating new fluids into the inner annulus the well underwent a successful monitor on gas injection starting June 21st, 2019. We believe the original source of TxIA while on gas injection was remediated by replacing the dummy valves; However, after recent injection rate increases, the IA pressurization has returned. The well was shut in on August 6th, 2019 due to plant maintenance and will remain SI. CPAI intends for the well to be brought on water injection only after plant maintenance is complete and will conduct a 30 -day monitor period to confirm integrity and pursue administrative approval for continued water injection service with TxIA on gas injection. Attached is a 90 -day TIO plot and schematic. Please let us know if you have any questions or disagree with this plan. Sincerely, SCWa,ClwUJ1& (f(e4 ,(w) / l2ache.LKautk Well Integrity & Compliance Specialist, WNS & C1PF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2542@cop.com Cell: 907-331-7514 1 sara.e.carlisleCa cop com Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Sunday, July 21, 2019 7:51 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: KRU 30-05 (PTD 188-076) IA Diagnostic Update Attachments: 30-05.pdf, 30-05 TIO 7.21.19.pdf Hi Chris, KRU injector 30-05 (PTD 188-076) is an injector that was previously identified with TxIA during gas injection. The well exhibited integrity during a 30 -day water injection monitor period. Upon completing well work to replace the dummy gas -lift valves with new extended packing valves and circulating new fluids into the inner annulus, the well returned to gas injection for an additional 30 -day monitor period starting June, 21" 2019. The 30 -day monitor period on gas injection has completed and the inner annulus exhibited integrity through the duration of the monitor. We believe the original source of TxIA while on gas injection was remediated by replacing the dummy valves. We intend for the well to remain online in normal WAG injection service. Attached is a 90 -day TIO plot and schematic. Please let us know if you have any questions or disagree with this plan. Sincerely, Sa,ra,CarUg& (Ye4k6Vv) /1zachel/Yatittk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549Pcop.com Cell: 907-331-7514 1 sara.e.carlisle0cop.com From: K Well Integrity Supv CPF3 and WNS Sent: Mon June 3, 2019 1:04 PM To: chris.wallace aska.eov Cc: CPA Wells Supt <n30s Subject: KRU 30-05 (PTD Chris, nocophillips.com> 7) IA Diagnostic Update KRU injector 30-05 (PTD 188-076) is an injector that reviously identified with TxIA during gas injection. The well passed a MITIA and packoff testing in January, but remained -but in for several months after the previous report. Water injection finally commenced on May 5, 2019. The well is now ne he end of its 30 -day water injection monitor period. The well has exhibited integrity during the monitor, however, - .1 would like to amend the post -water injection monitor plan forward. Instead of submitting an application for water -only Administrative Approval immediately, CPAI would like to changeout dummy valves in the tubing string, circulate new fluids into the annulus, and WAG the well to s for a 30 -day monitor on gas injection. The purpose of the work is to see if the source of the gas -only TxIA communication was a leaking Wallace, Chris D (CED) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Monday, June 3, 2019 1:04 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 30-05 (PTD 188-076) IA Diagnostic Update Attachments: 30-05.pdf, KRU 30-05 TIO plot 90 -day 6-3-19JPG Chris, KRU injector 30-05 (PTD 188-076) is an injector that was previously identified with TxIA during gas injection. The well passed a MITIA and packoff testing in January, but remained shut in for several months after the previous report. Water injection finally commenced on May 5, 2019. The well is now near the end of its 30 -day water injection monitor period. The well has exhibited integrity during the monitor, however, CPAI would like to amend the post -water injection monitor plan forward. Instead of submitting an application for water -only Administrative Approval immediately, CPAI would like to changeout dummy valves in the tubing string, circulate new fluids into the annulus, and WAG the well to gas for a 30 -day monitor on gas injection. The purpose of the work is to see if the source of the gas -only TxIA communication was a leaking dummy valve. The intent is for the wellwork and WAG to happen as soon as logistics allow. Until the work can be performed, CPAI plans to allow the well to continue in water injection service. Attached is a 90 -day TIO plot and schematic. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: NSK Well Integrity Supv CPF3 and WNS Sent:AVednesday, January 23, 2019 10:53 AM To: Wallace, !)OA) <chris.wallace@alaska.gov> Cc: CPA Wells Supt <n1030 cophillips.com> Subject: KRU 30-05 (PTD 188-076) Reppart-partIA pressurization Chris, Operations reported that KRU injector 30-05 (PTD 188-076) exhibited susjoecClA pressurization while in gas injection service. The well has been shut-in. DHD will investigate the IA with diagnostics including a MITIA and Operations will plan to WAG the well to water to be monitored for 30 -days on water injection. If the diagnostics and monitor period confirm integrity for continued water injection, CPAI intends to submit an application for Administrative Approval to continue water only injection. Attached is a 90 -day TIO plot. Please let us know if you have any questioner-lisagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Wednesday, January 23, 2019 10:53 AM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: KRU 30-05 (PTD 188-076) Report of IA pressurization Attachments: KRU 30-05 TIO Plot 90 -day 1-23-2019.docx Chris, Operations reported that KRU injector 30-05 (PTD 188-076) exhibited suspect IA pressurization while in gas injection service. The well has been shut-in. DHD will investigate the IA with diagnostics including a MITIA and Operations will plan to WAG the well to water to be monitored for 30 -days on water injection. If the diagnostics and monitor period confirm integrity for continued water injection, CPAI intends to submit an application for Administrative Approval to continue water only injection. Attached is a 90 -day TIO plot. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday, November 28, 2017 6:57 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: 30-05 (PTD 188-076) Ending Gas Monitor Period Attachments: KRU 30-05 TIO plot 90-day 11-28-17.docx Chris, KRU injector 30-05 (PTD 188-076) is nearing the end of its 30-day gas injection monitor period. The well passed a MITIA to 3000 psi early in the monitor and the IA pressure appeared fairly stable during the monitor, even after an intentional IA bleed on 11-18-17 to check for re-pressurization. The gas injection rate into this well is somewhat unstable which could affect the monitor results, however,the injection pressure remained fairly constant during the monitor. Since the formation is only taking gas injection intermittently,CPAI plans to WAG the well to water a couple of days before the end of the 30-days on gas. At this time,the well will be returned to normal WAG status. If further signs of communication are identified,the well will be reported at that time. Attached is a 90-day TIO plot. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 • • • z z z z z a l7 a s a s a z W W W W W Di z z z z z `QS z z z z z aO O O CL N tb N 0 ONO YL :Li N 0 4 Y W 9 N O O O S N .r1 m m N g N N $ --I N N N Inh n ri W �I n en-1 N ~ ri • aN WY VY 1/1 ID 9 9 9 o 9 W o O O o O m rn m m m i9ap "15 OD 0 0 0 0 0 N Lt•AON-2Z 11 LT-A°N-Z Z Li-Ito N-SI 4 • 40 LT-A0N-ST Lt+foN•8 LT-A0N-8 LLADN-1 C 4 J v LS-AON-T r m c = Lt-P0-52 I R ' LT-1057 3 Lt-Po-8L = LT-1a0-8T C 3 4 o 11-110-11 to v p o. 'c LT-1)0-TT p. -- 3 4 E I ° Cipov _ E LI-1)01, at V a � = :ddaass-ol: LL-daS-LZC OQ ILT-das-o r� n 0 LT-daS-ES LLdaS.ft 0 0 } N N O 1 LT-da5-9 LT-daS-4 N L1-2nv-o f i 1-Pny Cif zi ` 3V V 8M83N 8N r1 8ri 8N8$88 ` E " d 88g 8 EN 1-1 N H N HO ISd Odle'Qi)SV11 Ql N .- 0 7.--..- 1/) O W • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReDATE: Thursday,June 15,2017 gg P.I.Supervisor f 5 4-44� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-05 FROM: Chuck Scheve KUPARUK RIV UNIT 30-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-05 API Well Number 50-029-21839-00-00 Inspector Name: Chuck Scheve Permit Number: 188-076-0 Inspection Date: 6/4/2017 Insp Num: mitCS170605171815 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ' 30 05 Type Inj G TVD 1 6514 - Tubing 3600 3600 - 3600 - 3600 1880760 " IT a Test SPT Test si l 1628 IA 1170 2000 - 1950 - 1940 • PTD YP P � BBL Pumped: 1.2 - BBL Returned: 1.3 - OA 0 0 0 0 Interval 4YRTST P/F P VNotes: SCANS AUG 3 (42°17' Thursday,June 15,2017 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization {done) RESCAN [] Color items: Grayscale items: [] Poor Quality Originals: [] Other: ~w'Tw-o-Sided DIGITAL DATA Diskettes, No. Other, No/-l-ype TOTAL PAGES: J 00 NOTES; ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [3 Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Is/ Project Proofing [] Staff Proof By. Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI PAGES' of sca[.~i-9) SCANNED BY~ BEVERLY B~SHERYL MARIA LOWELL ReScanned (do°e) RESCANi',IED BY] ~BREN VINCENT SHERYL MARIA LOWELL I$! General Notes or Comments about this file: Quality Checked (donel RevlNOTScanned.wpd • MEMORANDUM To: Jim Regg ~~~ ~ ~ ~ Z ~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July O1, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-OS KUPARLJK RIV UNIT 30-OS Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~L Comm Well Name: KUPARiJK RN iTNI'I' 30-OS Insp Num: mitCS090626185824 Rel Insp Num: API Well Number: 50-029-21839-00-00 Permit Number: 188-076-0 ~ Inspector Name: Chuck Scheve Inspection Date: 6/26/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ 30-OS Type Inj. W T~ 6514 jA 1450 2480 °~ 2440 2440 •~ p.T.D' 1880760 TypeTest SPT TeSt pSl 1628.5 / QA 780 860 860 860 Interval 4YRTST P~ P ~ Tubing 3250 3250 3250 3250 NOtes' Pretest pressures observed and found stable . , - ,, ~ ~ a : + ~ r ~ ~ r ,/ ~~ l,`> «< ) , _ . .r._v ~. -.,. ~ Wednesday, July O1, 2009 Page 1 of 1 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Re~;;rJ , -1J 1('25 DATE: Monday, June 26, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-05 KUPARUK RIV UNIT 30-05 t'l~" tn IP \~ FROM: John Spaulding Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :-1'612- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 30-05 API Well Number 50-029-21839-00-00 Inspector Name: John Spaulding Insp Num: mitlS060620064535 Permit Number: 188-076-0 Inspectio n Date: 6/17/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 30-05 !Type Inj. I G iTVD 6514 I IA ! 2500 I 3120 i 3070 I 3070 I I I i I I i P.T. I 1880760 ¡TypeTest i SPT i Test psi 1628.5 lOA 80 80 I 80 80 i I I i I I I 4YRTST ~/ Tubing I 3650 3650 3650 I 3625 i Interval P/F P I I ¡ Notes Recently this well had a draw down test performed - the results were inconclusive. Hopefully the drawdown and the pbu tests will exhibit integrity. ;z. 'i t,~ ¿'.. Monday, June 26, 2006 Page 1 of 1 MEMORANDUM ) ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg .rJ\,\,ft¡t(, k(:z-t\û(P P.I. Supervisor l DATE: Wednesday, June 21, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA rNC 30-05 KUPARUK RIV UNIT 30-05 Src: Inspector a.-o1{p \ q)l) Reviewed By: P.I. Suprv .~¡2-- Comm FROM: John Crisp Petroleum Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 30-05 Insp Num: mitJCr060613 130702 Rei Insp Num API Well Number 50-029-21839-00-00 Permit Number: 188-076-0 Inspector Name: John Crisp Inspection Date: 6110/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. . :~~I:!.;~~::£~::::~~ i; P:i] -1::~5__~ª- ::.+ ::::n~f~ - .I_-.~~:-f _ _- _~2~O - Notes Note: Well Passes MIT (drawdowrrtest) but failed mechanical integerity based on high initial IA pressue J Regg, 6/20/06. IA was found with 3100 psi. Pressure was bled from 3100 psi to 1925 psi. Pressure increased from 1925 psi. to 2050 psi in 1 hour. Pressure increased from 2050 psi. to 2060 psi from 1 hour to 2 hours of monitoring well. SCANNED JUN 2, U'{ zom) Wednesday, June 21, 2006 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor Chair DATE: June 28, 2002 THRU: Tom Maunder ,~/'~,,-~. ~ P.I. Supervisor FROM: John H. Spaulding Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests PAl 3O multiple KRU Kuparuk River Field Packer Depth Pretest Initial 15 Min. 30 Min. WellI 30-05 Type lnj.I G I T.V:D. J 6514 ]Tubing J 3750 I 3750 I 3750 J 3750 I lntervall 4 P.T.D.I 1880760 Type testI P I mestpsiI 1629 ICasingI 1425 I 2050 I 2040 I 20.0 I PIE I P Notes: w~,I ~o-o~ I~,~,n~.l 'o I ~.v.~. I~,,~ I~.~,n,l~ I~.~ I~. I~ I,.,e~,l ~ P.T.D.I 1880600 ITypetestl P ITestpsiI 1604 I Casingl 2600I 3000I 2980 I 29801 PIE I P' Notes: .. We,,J ~o-o~ I~,~,n~.l s I ~.v.~. I~o~ I~,n,l~oo I~oo I~oo I~0o I,nt~rv~,i ~ P.T.D.I 1880770 ITYpetestl P ITestpsil 1626 I CasingI 950 I 2250 I 22401 2240 I P/F I P, Notes: IWellI 30-10 '" P.T.D. I 1880590 "Notes: WellI 30-12 P.T.D.I 1880410 Notes: IType,~.l ~ I~'v'D' I 636d' ITubing I~°° I~°° I~°° I~°° I'nterva'l 4' Type testI P I Testpsil 1590 ICasingI 2550I 3000I 2980I 2970I P/FI P Type lnj.I G I T.V.D. I 640" I Tubing I 3650 I 3650 I 3650 I 3650 I lntervall'4 Type testI P I TestpsiI 1601 I Casingl 760 I 20501 20501 2000 I P/F I -P Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Page 1 of 2 Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed' 5 Attachments: none Number of Failures: 0 Total Time during tests: 4 hfs cc: none MIT report form 5/12/00 L.G. mit(l) kru 3o 6-28-02js.xls 7/16/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_ RKB 59 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk Unit 4. Location of well at surface 8. Well number 811' FNL, 1892' FWL, Sec. 22, T13N, R9E, UM (asp's 525527, 6022009) 30-05i At top of productive interval 9. Permit number / approval number 1368' FNL, 1956' FEL, Sec.15, T13N, R9E, UM (asp's 525566, 6026732) 188-076 At effective depth 10. APl number 50-029-21839 At total depth 11. Field / Pool 1067' FNL, 1920' FWL, Sec. 15, T13N, R9E, UM (asp's 525529, 6027033) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8840 feet Plugs (measured) Tagged Fill (2/11/00) @ 8557' MD. true vertical 6958 feet Effective depth: measured 8557 feet Junk (measured) true vertical 6742 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 110' 16" 193 Sx AS II 110' 110' SURF CASING 4886' 9-5/8" 1200 Sx AS III & 370 G 4945' 4110' PROD CASING 8772' 7" 200 Sx Class G 8831' 6951' Perforation depth: measured 8445-8459'; 8466-8488'; 8504- 8524' R E C E IV E D true vertical 6658- 6669'; 6674- 6690'; 6702- 6717' APR 0 9 2001 Tubing (size, grade, and measured depth) 2.875", 6.5#, J-55, Tubing @ 8323' MD. '"',.JasI(a 0il & Gas Cons. C0mmissior Anchoraqr~ Packers & SSSV (type & measured depth) AVA 'RHS' Packer @ 8252' MD. Otis 'FMX' (Locked Out on 11/23/96), confirmed Locked Out on 12/23/96 @ 1792' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - 1953 - 3786 Subsequent to operation 2240 - 3727 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service ~.(WAG)~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by John Peirce 265-6471 _~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 30-05i CEMENT OUTER ANNULUS DESCRIPTION OF WORK COMPLETED 2/11/00: RIH & tagged fill at 8557' MD. 6/7/00: MIRU. RIH w/high pressure hose 60' down the 9-5/8 x 16" annulus, then pumped 10.8 bbls of 12 ppg Litecrete cement into the annulus. POOH w/hose. RD. Returned well to miscible gas injection & obtained a valid injection rate. 18r o?&o MEMORANDUM TO: Julie Heusser, Commissioner THRU: FROM: Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission .. ~I~%{ DATE: Chuck Scheve; SUBJECT: Petroleum Inspector January 26, 2001 Safety Valve Tests Kuparuk River Unit 30 Pad F. ridav, January 26, 2,001: ! traveled to the Kuparuk River Field and witnessed the 90-day retest of the safety valve systems on 30 Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Low pressure pilot on WAG injector 30-05 tripped below the required set point. This pilot was retested and passed at the the time of this test. Eamie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhouses entered at this location were clean and all related equipment appeared to be in good condition. Summary: I witnessed the 90-day SVS testing at 30 Pad in the Kuparuk River Field. KRU 30 Pad, t2 wells, 24 components, 1 failure 4.1% failure rate 12 welihouse inspections Attachment: SVS KRU 30 Pad 1-26-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 30 Pad 1-26-01CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: .,,P.,.h!llips Operator Rep: Eamie Barndt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Uffi~ad: Kupamk / KRU / 30 Separator psi: LPS 67 Date: 1/26/01 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number ..,Number. , PSI,. PSI Trip , Code Code Code Passed GAS or CYCLE 30-01 1880730 67 70 80 P .... i~ ........... OIL 30-02 .... 188~740 ' 67" "70 60 P e ........ OiL 30-03 1880750 ' 67 ' ' 70 ' 60 P P ......... OIL 30-'04 1880620 ' 67 70 65 P 'P ..... OIL. 30-06 1880600 30-08 ' 18806401 67 70 '~0.. ' P .... P . . L 0IL 30-09 "~181~0~i0'' 67'' 70' '40:' P P ........ OIL 30-11 '18804201 67 70 " 60' P .... P ..... OIL 30-13 1880406 '67 70 -60~ P ' P 0IL 30,1'4 ' 1880396 ..................... 30-i5 ' '1880310 ' 67! "70 . 70~ P P ...... OIL 30-1~ " 1880260 6;/ ''' 70 55 "P "P' ' 0I'L 30-20 '' 1970450 ' 67~' '~0 ~0' P P ........ 6IL 30-05 '1880760 "~750! .... 2000' 11'00 ' 3" P ...... 1)26/01 " -WAG' · Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.17% l"190 Day Remarks: Pilot on WAG injector 30-05 tripped below required set pressure. Pilot was retested and passed this date. RJF 1/16/01 Page 1 ofl SVS KRU 30 Pad 1-26-01 CS.xls MICROFILMED 10/12/00 DO NOT PLACE ANY NE W MATER/AL UNDER THIS PAGE ARCO Alaska, In' Post Office oox ,00360 Anchorage Alaska 99510-0360 Telephone 907 265 6513 Frank M. Brown Senior Vice President February 10, 1997 Mr. David W. Johnston, Chairman ~ Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 COMM COMM iRES ENG SR ENG NRO GEOL ; GEO-;_ ASS.~r Subject: AOGCC Notification of Well Control Kuparuk River Unit Well 30-5 Dear Chairman Johnston: .~.ol~ ~ Thank you for your letter of January 9, 1997 regarding well intervention activities on Kuparuk Unit Well 30-5. While we are certainly proud of ARCO's environmental performance on the North Slope, we recognize that effective communication with the AOGCC is critical to continued performance improvement. After receiving your letter, another review of the events regarding this well was completed. Again, our findings conclude that the well was at no time uncontrolled or without adequate well control devices. In this case, coiled tubing BOPs and a Bowen-type wireline lubricator were employed. Your staff was notified when it was believed that freezing the tree and lifting off the well control equipment would be necessary. Ultimately, the tools were freed without having to take this action. The actions taken and notification procedures followed were benchmarked with other North Slope operations and are in keeping with industry best-practices. We are certainly open to further discussion of expanded notification protocols; however, we believe that current practices adequately address the important well control situations. Expansion of notification practices could easily result in a barrage of administrative information that could well dilute the effectiveness of current notifications. Please contact Don Puckett, Kuparuk Production Manager, at 263-4250 or Jeff Kewin, Kuparuk Wells Superintendent, at 659-7226 if your staff is interested in continuing this discussion. Sincerely, Frank M. Brown RECEIVED FEB 12 1997 Alaska 0il & Gas C0n~. C01]il'ni~i0r~ Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company c: J. B. Kewin D. L. Puckett d. K. Thompson NSK 69 ATO 1226 ATO 2100 FEB 1 Alaska Oil & Gas Cons, A~¢h~ag,e TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 9, 1997 Mr. Ken Thompson President ARCO Alaska, Inc. PO Box 100360 Anchorage, Alaska 99510-0360 Subject' AOGCC Notification of Well Control Situations Kuparuk River Unit Well 30-5 ~ g- 0"7 to Dear Mr. Thompson: A recent well control problem at the Kuparuk River Unit 30-5 gas injection well has come to our attention and we would like your assistance to avoid a reoccurrence. From well records, we have gleaned the following information. On November 23, 1996, wireline tools hung up in the well; the operator cut the wireline and left the tools in the hole. Later that day, a second string of tools hung up and were similarly left in the hole. By November 24, there were three tool strings in the hole. On November 26, the operator moved in a coil tubing unit. While bleeding well head pressure to a tank, the wireline tools apparently moved up hole and lodged in the tree, making it impossible to close the master or swab valves. Apparently, the operator maintained well control by using the lubricator and either the wireline BOPs or coil tubing BOPs (well records are unclear as to which BOPs, we assume the coil tubing's). The well's initial tubing pressure was 4000 psi. Over the next few days, the coil tubing became stuck and it too was cut. The operator then attempted to thaw suspected hydrates by pumping methanol down the tubing and SSSV control line and hot diesel down the annulus. By December 2, the operator began efforts to cut the tools lodged in the tree by using a flat-bottom drill and 2.0" hole saw, while still injecting methanol and heating with diesel. On December 7, they attempted to drill out the wireline tools by going thru the wing valve. On December 12, the operator finally succeeded in cutting the lodged tools, but they would not drop. Efforts then began to freeze the tree so the stack could be removed. At this date, the operator contacted Commission staff to inform them about the well problem. On December 16, the operator was able to push the plug down hole and remove the tools. Ken Thompson 2 January 9, 1997 Losing a string ofwireline tools is common and the Commission does not need to be notified. However, when tools are lodged in the tree, making it impossible to close the master or swab valves, the Commission should be informed because of the potential for a more serious well control problem. In this case, the Commission was notified about 16 days after the tools became lodged in the tree. The Commission maintains an active field inspection staff on the North Slope. We are there to help ensure safe oil field practices, and we can be an important buffer if events turn out for the worse. However, we can only be effective if we are kept fully informed of potential problems when operations go beyond the norm. It may prove helpful for your staff to review situations warranting Commission notification. Thank you for your attention and assistance in improving communications between ARCO and Commission staff. Chairman cc: Blair Wondzell ku para b'notify.doc TONY KNOWLE$, GOVERNOR AI~SKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 8, 1997 Mr. Ken Thompson President ARCO Alaska, Inc. PO Box 100360 Anchorage, Alaska 99510-0360 Subject: AOGCC Notification of Well Control Situations Dear Mr. Thompson: A recent well control problem at the Kuparuk River Unit 30-5 gas injection well has come to our attention and we would like your assistance to avoid a reoccurrence. From well records, we have gleaned the following information. On November 23, 1996, wireline tools hung up in the well; the operator cut the wireline and left the tools in the hole. Later that day, a second string of tools hung up and were similarly left in the hole. By November 24, there were three tool strings in the hole. On November 26, the operator moved in a coil tubing unit. While bleeding well head pressure to a tank, the wireline tools apparently moved up hole and lodged in the tree, making it impossible to close the master or swab valves. Apparently, the operator maintained well control by using the lubricator and either the wireline BOPs or coil tubing BOPs (well records are unclear as to which BOPs, we assume the coil tubing's). The well's initial tubing pressure was 4000 psi. Over the next few days, the coil tubing became stuck and it too was cut. The operator then attempted to thaw suspected hydrates by pumping methanol down the tubing and SSSV control line and hot diesel down the annulus. By December 2, the operator began efforts to cut the tools lodged in the tree by using a flat-bottom drill and 2.0" hole saw, while still injecting methanol and heating with diesel. On December 7, they attempted to drill out the wireline tools by going thru the wing valve. On December 12, the operator finally succeeded in cutting the lodged tools, but they would not drop. Efforts then began to freeze the tree so the stack could be removed. At this date, the operator contacted Commission staff to inform them about the well problem. On December 16, the operator was able to push the plug down hole and the remove the tools. Ken Thompson 2 December 19, 1996 Losing a string of wireline tools is common and the Commission does not need to be notified. However, when tools are lodged in the tree, making it impossible to close the master or swab valves, the Commission should be informed because of the potential for a more serious weIl control problem. In this case, the Commission was notified about 16 days after the tools became lodged in the tree. The Commission maintains an active field inspection staff on the North Slope. We are there to help ensure safe oil field practices, and we can be an important buffer if events turn out for the worse. However, we can only be effective if we are kept fully informed of potential problems when operations go beyond the norm. It may prove helpful for your staff to review situations warranting Commission notification. Thank you for your attention and assistance in improving communications between ARCO and Commission staff. o Chairman cc: Blair Wondzell kuparuk notify.doc MEMORANDUM State of Alaska Oil and Gas Conservation Commission TO: David Johnston, DATE: Chairman December 13, 1996 THRU: Blair Wondzell, F1LE NO: P. I. Supervisor gc9hlmdd.doc Confidential: Yes _, No_X, Attachment Only . FROM: Doug Amos,-b. ~-- S~JB,rECT: Petroleum Inspector Murphy's Law Gas Injection Well 30-5 Kuparuk River Field ,Friday, December 13, 1996' i received a call from Arco Kuparuk representative Eric Zuspan, Eric wanted to inform me of the problems they were having on Gas Infection Well 30-5. The attached copy of the Kuparuk River Unit Well Service Report details the events as they happened. Saturday, December 14, 1996' I traveled out to well 30-5 to get an update on .-.--' ~,,'~ ~,,.. · ~.; · their progress. Hot diesel was being continually circulated down the annulus in ~ ,¢,. ,,( ., .~.., an attempt to thaw the ice plug down hole. Arrangements were being made to prepare the wellhead for freezing tomorrow morning. Sunday, December 15, 1996: I received a call from Arco representative Tommy Johns and informed that the well head freezing operations had been canceled. During the night the circulation effort had paid off and the ice plug was pushed down hole, this will allow the well to be killed and the tools retrieved. Monday, December 16, 1996: I traveled back to the 30-5 location to check on the status of the killing operations. The well had been killed and all tools and BOP's removed from the well head, the tubing pressure was 0, the IA read 100 and OA read 175 psi. I talked with the DS operator and he told me that they were going to replace all the well head vaive~because they weren't sure where're or not the valve bodies had been damaged during the milling operations. .SUMMARY: I gathered information and conducted inspections on fishing job at Arco's 30-5 gas injection well. Attachment: Arco's KRU Well Service Report (18 Pages) ARCO Alaska, Inc, , UPARUK RIVER UNIT WELL SERVICE REPORT K1{30-05(W4-6)) WELL JOB SCOPE JOB NUMBER 30-05 TUBING LEAK: DIAGNOSE, PATCH 1122961 655.5 DATE 11 I23/96 DAY 1 Ft ELD ESTIMATE DAILY WORK TUBING LEAK: DIAGNOSE, PATCH 0 Y~S ~ NO ] Q Y~ ~ NO I HES-L~HMAN ~FC~ lCCf ........... i D~ILY C~ST I ACOUM COST KAWWRK 1 230DS36OL I $6,781 ! $6,781 I~tial T~ Press J Final ~ Pre~ J ~nitiat I~ner Ann J Final InnerA~n J ' 4000 PSIJ 2400 PSIJ 2700 PSIJ 3000 PSt 1 UNIT NUMBER 70175 SUPERVISOR SMITH Signed Initial Outer Ann [ Final Outer Ann 0 PSi[ 0 PSI DAILY SUMMARY TOOL STRINGS IN HOLE; IN I:~ROGRESS. TIME LOG ENTRY 07:00 MI-HELD SAFETY MEETING-RU HES & LRS. 1.875"TS-RS,QC,5',KJ,5',KJ,LSS,QC. PT EQUIP TO 4000~. 08:00 BEGIN DISPLACING TBG TO KNOCK PRESSURE DOWN-HiGH PRESSURE GAS INJ. 08:30 RIH Wf3' STEM & 2,30"SWAGE WHILE FINISHING DISPLACEMENT. TAGGED "D" NIPPLE ¢~' ~247'WLM (8288'RKB). POOH. HUNG UP @ SSSV. RU TO TREE. PRESSURED SSSV TO 6000#: 2500//ON TBG. CUT WIRE r,.2,, ROPE SOCKET, 08:30 TS IN HOLE= 25', LAY DOWN LUB & RESTRING WIRE. TS: RS,QC,5' X 2.125"STEM,KJ,SSS,QC. STAND BY FOR LOCK OUT & EXERCISE TOOLS. 10:50 8LED CONTROL LINE TO 0 DOESN'T APPEAR TO HAVE MUCH GAS IN LINE. 11:20 12:.15 13:05 RIH W/2,5"RB & OTIS 2.5"EXERCISE TOOL FOR 2.875"FMX. TOOL DID NOT LOCATE iN PROFILE. ~UNG UP BELOW FLA. PPER TRIED STROKING HYD WHII_E GOING TO Y-PAD FOR DAP TOO[_. SI BOP'S DROPPED 2.875"DAP TOOL WORKED WIRE AFTER 10 MIN. WIRE CLIPPED AGAIN. 3:45 LAY DOWN LUB & REDO STUFFING BOX. TS=RS,5' X 2.125,KJ,LSS,QC. 4:30 16:25 17:50 8:30 9:40 21:00 RIH W/2"SSJ & 2.875"OTTS LOT. SET tN PROFILE @ 175.9' WLM (179ZRKB). PRESSURED TBG TO 3000#, 3500~, 4000¢ & 4500#. CONTROL LINE SHOWS NO CHANGE. BLED OFF PRESSURE & TRIED SAME W/NO LUCK. POOH W/ LOT. RIH W/2,35"CENT W/TANDEM BLB TO BRUSH PROFILE. t63 ,m, BTM BRUSH TO NO GO/. BRUSH DIDNq' WANT TO GO. REWORKED, COULDN'T GET PAST 41' WLM. POOH. RING AROUND BTM OF CENT. SUSPECT SCALE. REMOVE CENT. BLED CONTROL LINE TO 0#. FLAPPER IS CLOSED. RIH W/TANDEM BLB. BRUSHED PROFILE @ 1759¥¢.J~, TBG PRESSURE WAS SLOWLY RISING. POOH. Rill W/2"SSJ & ~.,875" OTIS LOT. SbT IN PROFILE .:~ 1759'WLM. PRESSURED TBG TO 4500#. NO CHANGE IN CONTROL LINE PRESSURE. POOH, REPIN SSJ LIGHT TO LEAVE LOT IN HOLE. RIH W/Z"SSJ & 2.875" OTIS LOT. SET IN PROFILE ~ 1759'WLM. PRESSURED TBG TO 4500#. NO CHANGE IN CONTROL LINE PRESSURE UNABLE TO SHEAR OFF TOOL. POOH W/TOOL. F~MO. SERVICE: COMPANY - SERVICE ............. DAILY COST 'AC'~UM'TOTAL ,, ,,,, ._ ,t ,$378.00 $378.00 _.H._ALLIBURTON $3,104.00 - $3,104.00 _LITTLE ~ED ............. $3,300,00 " $3' ,300.00. TOTAL FIELD ESTIMATE $6,782.00 $6,782.00 ,,,,, ARCO' Alaska, Inc. ,.UPARUK RIVER UNIT .~ WELL SERVICE REPORT ~' K1(30-05(W4.,6)) WELL JOB SCOPE JOB NUMBE,~ 30-05 FISHING: FISHING & MILLING CPS 1204961353.2 DATE DAILY WORK UNIT NUMBER 11/24/96 FISHING: FISHING & MILLING OPE 701 75 DAY .... ~i~i~'RATION COMPLETE '|":§UCCESSFUL KEY PERSON SUPERVISOR 1 0 Yes ~ NoI 0 Yes ~ No HE S-LEHMAN SMITH FIELD AFC# ~ DAILY CCST AcCuM COS]' Signed ESTIMATE KAWWRK 230DS36OL $2~736 _ $2,736 Initial Tb.q Press Final Tbcl press Initial Inner Ann Final Inner Ann ! In',tJal Outer Ann I Final Outer Ann ...... 2400 PSI! 2400 PSt[ 30,5,0, PSI , 2500 PSI] 0PSI[ 0PSI DAILY SUMMARY UNABLE TO LOCK OUT SSSV DUE TO SCALE. JOB SUSPENDED. J TIME LOG ENTRY ... 07:00 MI-HELD SAFETY MEETtNG-RU HES & LRS. TS=RS,5' X 2 125",KJ.5' X 2.125",LSS CC. PT EQUIP TO 3000#. 07:45 PUMP. 30 BBLS HOT DIESEL. 08:00 RIH W/2"SSJ & OTIS LOT. SET IN PROFILE ~ 1759'WLM, =RESSURED TBG TO 45{:X~#. MONITORED FOR 3 HRS. KEPT BUMPING TBG PRESSURE UP. VALVE NOT LOCK!NG OUT. POOH. REDRESS TOOL. CHANGE TS TO 1.875"-RS~5',KJ,5',KJ,LSS,QC. 11:35 RIH W/LOT, BLED CONTROL LINE TO 4100# TBG @ 2400~. SET TOOL IN PROFILE. PRESSURED TBG TO 3000#. NO LUCK POOH. WILL SET UP FOR HYDROBLAST. 12:45 RDMO. 00:00 00:00 00:00 TOOLS IN HOLE. TS#1 (BTM). 1,875"-RS,QC,5',KJ,5',KJ,LSS,QC,XO,3' X 1,5"STEM & 2.30"SWAGE, ALL FIN'S ARE 1.75" (2.5" PT). 1.5' S.TEM & 2.30" SWAGE ARE i &,'8' F?N. i2_, PT). TOTAL LENGTH OF TS= 298' (, 2_.5't. TS#2 (MIDDLE). RS,QC,5' X 2.125",SSS,QC,XO,2.5"RB,2.875:'OTIS EXERCISE TOOL. ALL F,"N'S ARE 1.75" (2.5"PT). 2.5"RE HAS 1 3/8"F/N (2" PT). TOTAL LENGTH OF TS= 220' (- 19'}. #3 {TOP). 2.875' DAP T'OOL; 60" LONG; I"F/N {! .3(.,8" PT). SERVICE COMPANY - SERVICE ...... DAILY-~O'ST ACCUM TOTAL $147.001 $147.00 APG $0.00 ~ $0,00 BAKER Oil.' ~OOLS ......... $0.00 $0.00 "DOWELL ....... $0.00 - ' $0,00 FUFWIANITE .......... $0,00._ $0.00 , ,, HALLIBURTON $1,269.00 $1,269.O0_ ,.. ,,,,, LITTLE RED $1,320.00 $1,320.00 SHIPPING CHARGE _ $0.00 $0.00 TOTAL FIELD ESTIMATE $2,756.00 $2.736.00 ARCO Alaska, Inc. r~UPARUK RIVER UNIT '~. WELL SERVICE REPORT ~1~' K1(30-05(W4-6)) '"WELL ,JOB SCOPE '" JOB NUMBER 30-05 FISHING: FISHING & MILLING CPS 1204951353.2 DATE DAI~'WoRK ........... UNIT NUMBER 11/26196 FISHING: FISH{NC & MILUNG CPS DAY 'OP R^T ONCOMPL E I SUCCES UL KEY P .SON SUP RWSOR 1 O Yes ~ N¢.,.I O Yes ~ No WOLD JOHNS, Ft~D A~ C~ DALLY C~T ACCUM ~T S~ned ESTIMATE KA~RK 230DS36OL $18,500 S21,236 ..... Initial TbR Press Final Tbg PreSs In~i~] Innsr Ann Final InnCr Ann ~ Initial Outer Ann ~' 'Final' Outer A~' 0PSI 0PSI[ 0PS!] 0PSI[ ,.. 0PSII 0PSi DAILY SUMMARY COfL TUBING STUCK ON WELL, BECAUSE SLICKLINE TOOLS ARE ACROSS TREE VALVES. CAN"F SHUT SWAB OR MASTER TO GET OFF THE WELL. SHUT DOWN FOR NIGHT AND DISCUSS PLANS. TIME LOG ENTRY 12:00 MIRU COIL TUBING, BAKER CONgCTOR$ AND HES HYDROBLAST TOOL. ~ 3:00 PRESSURE TEST AND HELD SAFE ~'~t' ME~TtNG 13:10 OPEN UP TO WELL AT 27Cq'J P~l, TRIED TQ RI.ELD WP.= TO TANK, TO GET COIL TO RIH, BLED TO 1500 PSI. COIL WONq' GO. PUH WTCOtL, TRIED TO CLOSE SWAS VALVE WON'T CLOSE. SUSPECTED HYDRATES. CANT' PUMP INTO WELL. 14:00 TRIED TO PUMP ABOVE SWAB, WITH HOT DIESEL & METHANOL PUMPED THRU WING , UP SWAB TO TANK. W/HOT DIESEL_ PUMPED OK, SJS¢'ECT WIRELiN~: TOOL5 ACROSS TREE VALVES , ATTEMPTED TO CLOSE MASTER V~LVE WON'T CLOSE. 15:45 BLEED WHP TO 500 PSI , ATTEMPTED TO PUSH TOOLS WITH COL, TOOLS WON'T MOVE. WELL PRESSURES UP TO 4400 PSI AND WONT TAKE DIESEL SUSPECT HYDRATE PLUG BELOW TOOLS AND OR SSSV FLAPPER IS CLOSED. SERVICE COMPANY - SERVICE DALLY COST ACCUM TOTAL ' ' $0.{30" $147.00 APO ...... $3,000.00. _ $3,.000.00 BAKER OiL TOOLS ............. i $3 ~ 0. .00 . 00 $3,000.00 DOWELL ............ $10~000.00 $10~000,00 FURMANITE $0.00 $0.00 _~HA..LUBURTON $2,500.00 -' $3~,769,00 LITTLE RED $0.00 $1,320.00 SHIPPING CHARGE $0.Q0 $0.0tl TOTAL FIELD ESTIMATE $18,500.00 $21,236.00 ...... ,,=,, ARCO Alaska, Inc, ,.UPARUK RIVER UNIT WELL SERVICE REPORT K1(30-05(W4-6)) WELL 30-05 JOB SCOPE FISHING: FISHING & MILLING CPS JOB NUMBER 1204961353.2 DATE UNIT NUMBER 11/27/96 DAY 2 DALLY WORK FISHING: FISHING & MILUNG Initial Thc Press ~ Final TbQ Press initial :nner Ann 0 PS11 '0 PSI 0 PSI KEY PERSON WOLD ACCUM COST $34,586 Final inner Ann o PSI FIELD ESTIMATE SUPERVISOR JOHNS Signed Init!al Outer Ann J Final Outer Ann o PSiI o PSi DALLY SUMMARY PROBLEM WITH WIRELINE TOOLS $ ~'~UCK ACROSS TREE. WELL IS CONTRCLED AT THIS POINT WITH LUBI:IICTORS AND WiRELINE BOP, NOT SEEING ivfUCH WELLHEAD PRESSURE BUT IT IS BUIU:}ING UP VERY SLOWLY. SUSPECT SSSV IS NOT CLOSED AND ICE OR HYDRATES HOLDING 4300 GAS PRESSURE UNDER iT. WELL IS CONTROLED , BUT PLAN OF ACTION IS UNSURE TONIGHT. PLAN TO X-RAY THE TREE VALVES TONhGHT TO SEE HOW WIRELINE TOOLS ARE STUCK IN TREE. TIME [ LOG ENTRY 07:30 t CTU IS STILL CONNECT6D TO TREE. 08:00 HELD SAFETY MEb-I',NG, D,CUSSED PLANS LFFT 3190 PS,, OVERN,GH'F. ,~ ~'~.A~ 3290 PS, TH',S M?~R,N,NG. BLED HYDRAULIC CONTROL UNE TO ZEFO AND 08;30 i BROUGi-'T WELL HEAD PRES~UmE; © 7.ERO. TFIit',;,% N.~ SSSV iS CLOSED AT THIS POINT. WATCHED FCR THREE HOURS. DECIDED TO V,,,AT,..,H'" "' SOME MORE 14:00 DECIDED TO STOl.D UP CO!L ABOVE CTL~ BOP;S AND CU F.COIL. DAP TOOLS HAD HIT COIL HYDROBLAST TOOLS. COULD NOT PULL COIL TOOLS LOOSE. CUT COIL AT BAKER CONNECTOR 17:130 THINKING IF WE PICKED UP, CTU BOP'S WE MITE COULD PULL, TOOLS OUT OF WELLS. 17:30 GETTING READY TO PICK LIP BOP'S, WHEN -GAS STARTED BLOWING OUT OF HYDRAULIC LINE. AT THIS POINf WE ARE I'HINKiNG $S$V MAY NOT BE CLOSED AND WE HAVE HYRATES HOLDING WELL PRESSURE BACK, STAB LUBRICATOR AND SLIOKLINE BOPS ON TOP OF CTU BOPS. 18:00 WE HAVE WELL CONTROL IF WELL PRESSURES UP. LEAVE MANWATCH ON WELL TONIGHT. 19;00 TALKING WITH ALL EVOLVED ~ ABOUT ANY P .L~. N OF ACTIONS, , , SERVICE COMPANY - SERVICE DALLY COST -~CCUM TOTAL , $0.00 $147.00 ~PC ,s~oo.oo ~3,~oo.oo ... BAKER OIL TOOLS $0,00 $3,000.00 -- , .................. ,,, _ _ . DOWELL $10,0(30.00 $20,000.00 _ FURMANITE ................................ $0,00 , $0.00: _HALLIBURTON .......................... $,,2,,.7,,50,00 $6,51 LITTLE RED $0,00 .... $1,3.20.00 SHIPPING CHARGE $0,O0 $0.00 .. ,, - .... , ,, ........ , ,, ,. ,-... . ....~- . TOTAL FIELD ESTIMATE $13,350,00i $34,586.00 ARCO Alaska, Inc. r, dPARUK RIVER UNIT -~', WELL SERVICE REPORT ~1~' K1(30-05(W4-6)) WELL JOB SCOPE .............. JOI;i NUMBER 30-05 FISHING: FISHING & MILLING OPS 120d961353.2 DATE DAI[.~ W~)RK ....... UNIT NUMBER 11/27/96 SLICKL1N~ SUPPORT OF FISHING OPERATIONS "'DAY :OPEnATION COMPLr'TF-" ! succESsFul" ' KEypERSON ~UPE~VISOR 2 0 Yes ~ .,.N.o .j (~) Yes 0 No RES-NANSEN. ..... FITZPATRICK FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE KAWWI:IK 230DS360L $2~750 $34,566 .... Initial Tbcl Pr°~s Fina! Tbg Press In~tial Inr~'~"~,hn - Final Inner Ann I Initial Outer Ann t" Final O~ter Ann ......... p PSI! 0 PS~ 650 PS~ §50 PS1! ,,0 PSiI 0 PSI [~A!LY SUMMARY SUPPORT ONGOING FISHiNG/TROUBLESHOOTiNG TIME LOG ENTRY 08:30 ON LOCATION, TGSM DISCUSS SAFETY ISSUES REGARDING UNUSUAL FISHING dOB. og :00 STAND-BY 15:CO COIL TUE~It',JG CUTS PIPE - RIG WIRELINE BOPS ~- 5' RISER ABOVE CTU BOPS- SECURED WELL. 17:31 STAND-BY 19:30 RDMO Si~'R~/ICE COMPANY . SERVICE DAILY COST ACCUM TOTAL $0.00 $147.00 APC $6130.00 $3,600.00 BAKER OIL TOOLS $,0.00 $3,000.00 DOWELL $10,000.00 $20,000,00 FURMANITE $0.00 $0.00 HALLIBURTON $2,750.00 $6,519.00 ............. LITTLE RED ....... $0.O0 $1,32Q00 SHIPPING CHARGE $0.00 $0.00 ARCO Alaska, Inc. KUPARUK RIVER UNIT '~, WELL SERVICE REPORT ~' K1 (30-05(W4-6)) WELL' 'JOB SC;OPE ' 'l JOU NOMBER ' 30-05 FISHING: FISHING & MILLING CPS 1204961353.2 DATE DAILY WORK UNIT NUMBER 1 1/29/96 THAW iCE PLUG DAY ' "~DPERATION COMPI'~rE I SUCCESSFUL KEY PERSON "'SUPERVISOR 3 O Yes (~ N.o! O Yes (~) No JOHNS FIELD AFC# ~ ! DAILY COST 'ACCUM C(~T Signed ESTIMATE KAWWRK 230DS36OL[ $33,708 $68,294 Initial Tbcl 5~'~$s "-Final Tb.q Press t~,itJal In'ncr Ann Final Iriner Ann I Initial duter Ann ~ Final Outer Ann 0 PSI .... 0 PSt 0 PSi 0 PSIi 0 PSI~ . 0 PSI DALLY SUMMARY CONTINUE TO MAINTAIN WHP WITH METHANOl , IN ATTEMPT TO THAW !CE PLUG FOR FISHING JOB. TIME 07:00 LOG ENTRY CONTINUE TO APPLY PPESSURE TO WELL HEAD TO FORCE METHANOL DOWN THROUGH HYDRATE PLUG. ALSO P!JMFiNG METHANOL DOWN $$,9V CONTROL UNE, MAINTAINED 4500 PSi ON WELL HEAD, NOT BLEEDING OFF. RUNNING JOia, ON 24 HOUR BASIS. .SERVICE COMPANY - SEI~V,!,CE ..... , ........... DAILY cOST ACCUM TOTAL $0.00 $1zt7,00 ,, . , .. APO $3~000.00 $6,600.00 , BAKER dlL TOOLS ...... $0.00 _DOWELL ........ $1"8,468.00 '$38,468.00 FURMANITE $0.00 $0.00 ,, , HALLIBURTON .... $0.00 $6,519.00 LITTLE R.E,,D ..... $12,240.00 ~13,,560.00 __SHIPPING CHARGE $0.00 $0.00 TOTAL FIELD ESTIMATE $33,708.00 $68,294.00 .. , ARCO Alaska, Inc. KUPARUK RIVER UNIT .~ WELL SERVICE REPORT "~' K 1 (30-05(W4-6)) WELL JOB SCOPE ...... ~J08 NUMBER 30-05 FISHING: FISHING & MILLING OPS 12049613,53.2 DATE DA~L.Y ~ORK UNIT NUI~,~ER 11/30(9.6 THAW ICE PLUG {PREP, FOR FISH..!NG WIRELINE TOOLSt DAY "bPERATION COMPLETE I SUCCESSFUL' - KEY PERSON SUPER'~ISOR 4. C) Yes ~ NC,I O Yes (~) NO JOH,.NS ..... "FIELD AFC# CC~ DALLY COST ACC~JM COST Signed P..S 'I'IMATE KAWW RK 230DS36OL $13,234 $81 r528 ' Initial Tb.q Prcss Final Tb[l Press i~'itial Inner Ann Final hlner Ann '1 Initial Outer Ann I Final Outer Ann ,, 0 PSi ...... 0 PSI 0 PS! ........ 0.,~SiJ 0 PSI I.. 0 PSi OAILY SUMMARY CONTII',IUE TO ,~OLD PRESSURE ON WELL HEAD WITH METHANOL, PUMPED SOME HOT DIESEL DOWN TUBINGXCASING AN_'N,.U.LUS (23 8BLS ) IN AN ATTEMPT TO THAW HYDRATE PLUG BELOW WtRELINE FISH STUC;~ IN TREE TIME LOG ENTRY 07:00 HOLDING 4500 PSi WHP W/METHANOL 1 t :0~ PUMPED, 23 BBLS HOT DIESF-J, IN TUBING X CASING ANNULUS IN AN ATTF, MpT TO THAW HYDRATES BELOW WiRE L!NE TOOLS ( FISH STUCK IN TREE~,. PUMPING AND RI_EEDING '3ACK HOT DIESEL ALL DAY. "-$~RvICE COMPANY - :SERVICE - DAILY CO~T ACCUM TOTAL .~,0.00 $147.00 APC ....... $1,500.00 , $8~ 100.00 BAKER (~i~. TOOLS $0.00 $3,000.00 'hOWELL .... $9,234.00 $47,702.00 r,., ., FURMANITE ,~.00 $0.00 ,, ,., __HALLIBURTON .... ~ ..... $O.00 ........ $0,519100 LITTLE RED $2,500.00 $16,060,00 SHIPPING OHAI~'GE $0.00 $0.00 TOTAL FIELD ESTIMATE $13,234.00 $81,528.00 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~1~ K1(30-05(W4-6}) WELL J JOB $COP5 ' " JOB NUMBER 30-05J FISHING: FISHING & MILLING CPS 1204961353.2 DATE DAILYwOmhK ''m UNIT'NUMRF,:~ 12/02/96 THAW ICE PLUG, CUT STUCK WIRE TOOLS IN TREE D~v ..... b.~.AT,O. CO~' PLATE i ~U~FuL ' ~EY P~SON I '' SU~RV'SOR 5 © ® No! ©YesNo JOHNS ~ .,,.. FIELD AFC~ C~ DAILY COST ACCUMC~T Si~ed ES I"IMATE KAWWRK 230DS36OL $34,008 $115,536 Initial ~ Pross Final T~ Press Initial Inner Ann Final Inner Ann ~ Initial Outer ~nn I Final Outer Ann 4500 PSI~ 4500 PSi 0 PSi _. 0.PSI] , 0 PSI[ .... ~ PSI DAILY SUMMARY ATT'EMPT TO CUTWIRE LINE TOOLS THAT ARE ACROSS WELL HEAD TREE. MADE A CUT WITH A 2.0" HOLE SAW. TOOL DiD NOT FALL. ICE PLUG IS PUSHING UP ON TOOLS. MAINTAINING 4500 PSI ON WELL HFAD TO ATTEMPT TO KEEP ICE OUT OF THE TREE ANID PUSHING UP ON TOOLS. HOT OIL PUMP IS RECYCLING 4 TO 5 DBLS OF HOT DIESEL IN 7" X TUBING TO THAW ICE [~,~ ~_TUEING. MAINTAINING 24 HOURS MAN WATCH CN WELL WHILE WE ARE UNABLE TO CLOSE TREt~ VALVES. TIME 02:00 LOG ENTRY MADE A 2.00' CUT ON THE TOP OF SPANG JAR,~ THAT ARE ACROSS THE TREE VALVES. MADE THE C;JT WITH ATASCO DRILL AND 2.00" HOLE SAW. UNSURE IF TOOLS ARE CUT COMPLETLY THRU. BUT THEY DID NC.T FALL AWAY FROM BLOCKING THE SWAB. SSV AND MASTER VALVE. CONTINUING TO RECYCLHj 4. TO 5 EBLS OF DIESEL IN T' CASING X TUB!NG , TO THAW ICE PLUG. , MAINTAINING 24 HOUR MAN WATCH. SERVICE COMPANY - SERVICE DAILY ¢~)ST ACCUM TOTAL $0.00 $147.00 .APC ......... $3,500.00 $1 BAKER OIL TOOLS $0.00 $3,000.00 DOWELL ...... $18.468.00 $66,170.00 ,.. FURMANITE ............ $0.00 ' $0.00 HALLIBURTON ..... $0,00 $6,5'19.00 LITTLE RED ....... $12,'~40.00 ,$28,300.90 SH IPPI'NG C, HA RG E .... $0.. 0{3 $0.00 '~TOTAL FIELD I~STIMATE $34,008,00 $115,5,36.00 , ., ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~' K1(30-05(W4-6/) WELL JOB SCOPE JOB NUMBER 30-05 FISHING: FISHING & MILLING CPS 1204961353.2 UNIT NtlMRF;~ BATE 12/03t96 DAY 6 FIELD ESTIMATE DAILY WORK INJECT METHANOL KAWWRK ~ ~30BS36OL $17,154 Initiat Tb~ Pres~ ~ Finel Tb~ Press tnltial Inner finn 4500 PSI[ 4500 PSI 3500 PSI KEY PERSON SUPERVISOR BRADLEY Ac_,,CCJM CCST Signed $1 32,690 Final II~ne~ Ann J Initial Outer Ann · 350¢11=SIJ 500 PSI Final Cuter Ann 500 PS! DAILY SUMMARY CONq', TO MAINTAIN TUBfNG PRESSURE AT 4,500~. W/METHANOL fNJECTION AND HEAT ANNULUS W/HOT DIESEL BY PL.~'¢IPII:IG AND BLEEDING. TIME LOG ENTRY 06:00 CON'T. TO KEEP TUBING PRESSURED UP TO 4500# BY INJECTING METHANOL. WELL TAKING VERTiALLY NO FLUID. HEAT 2-7/8" X7" ANNULUS BY PUMPING 180 BEG DIESEL. ANI~,~ULUS PRESSURES dP 'FO 3500# IN 4..5 BEiLS, AFTER DIESEL HAS BEGAN TO COOL, RI FFD BACK 4.5 BBLS, RE-HEAT AND RE-INJECT. HAVE TO BLEED TUBING PRESSURE WHILE PUMPING UP ANNULUS TO KEEP TUBING FROM RISING ABOVE 4500#. SERVICE COMPANY - SERVICE ,,, ' ....... DAILY COST ACCUM .ToTAl.'' $0,00 $147.00 '-AFC .... $1,800.00 $13,200.00 BAKER OiL TOOLS ...... $0 00 $3,000,00 DOWELL $9~234.00 ,$75, 404.00 FURMANITE ........ $0.00 $0.00 7.iqALLIBURTON ' , $0.00 ~- S8,519.00 LI'I-rLE RED $6,120.00 ...... $3_4,420.00 SHIPPING CHARGE ....... $o.00 $0.00 TOTAL FIELD ESTIMATE :$17,154.00 $132,690.D0 ARCO Alaska. Inc.' ..UPARUK RIVER UNIT ~I. WELL SERVICE REPORT ~t~' K1(30-OS(W4-6)) --- , , WELL JOB SCOPE JOB NUMBER 30-05 ..FISHING; FISHING & MILLING CPS ... 1204961.353.2 DATE DAILY WORK ..... UNIT NU'MBER 12i04/96 INJECT METHANOL DAY OPERA'[']0~ ~OMPLE,-5 I SUCCESSFUL - KE"~"PERSON SUPERVISOR 7 .. O Yes .. (~) NoJ . .O Yes (~) N..o. .... BRADLEY FiEL~ ^FC# I CC~ I DAILY COST ACCUMCOST ESTIMATE K,~WWRK 230D$360 L :$19,654 Initial Tb, Press Final Tb.q Press Initial Inn,r Ann Final ,nnei Ann, Initial 0uter Ann , F~nal Outer Ann 4500 PSI 45..00 PSI ! 3500 F~, 3500 PSI! 1 500 PSI 500 ~.S.., DAILY SUMMARY I CON"[ TO MAINTAIN TBG PRE,~,gI,!I~F AT' 4500# W/METHANOL !HJECTION AND HEAT ANNULUS W/HOT DIESEL 5Y PUMPING Ai~D BLEEDING. TIME LOG ENTRY 06:00 DON'T. TO KEEP TBG PFIEDSURED UP TO 4500..'/BY INJECTING MECH. STILL TAKING HQ FLUID. HEAT ANNULUS BY PUMPING AND BLEEDING 4.5 BBLS 180 DEGREE DIESEL. SERvicE COMPANY - SERVICE ~IAILY COST ACCUM TOTAL $0.00 $147.00 APC ' ' $'1,800.00 ' $15,000.00 BAKER OIL TOOLS $0.00 83,000.00 ~OW~LL .... "', ........... ~9,234...00 ~8,~,~.00 FURMANITE SO,CO SO.O0 HALUBURTON .... $2. 500.00 $9,019.00 LITTLE RED $6,120. O0 ,$40, 540. O0 ._SHIPPING CHARGE $0.00 $0.00 TOT'AL FIELD ESTIMATE $19,6.54.00 $152,344.00 . . , ARCO Alaska, Inc. r~UPARUK RIVER UNIT '~. WELL SERVICE REPORT ~" K1(30-05(W4-6)) 'WELL JOB SCOPE ............... JOB NUMB~-R ..... _30-05 FISHING; FISHING & MILLING CPS 1204961353.2 ,, ,,, , DATE DAILY WORK UNIT NUMBER 12/05/96 INdEGT METHANOl. DA"( .... 0PE~ATION COMPLETE ' SL]~:C,E, SS FLIL I~ERSON ~UPEFIV!SOR _. BRADLEY FIELD AFC# CCC DALLY COST AC~UM COST ~:igned ESTIMATE KAWWRK 230 DS36OL $13,82 0 $166:164 4500 PSi 4500 PSI; 3500 PSi 3500 PSIJ 350 PSi[ ....... 350 PSI DAILY,,,,,S, UMMARY lAND BLEEDING, CON'F. TO MAINTAIN TBG PRESSURE AT 4500# W/METHANOL INJECTION ANC HEAT ANNULUS WITH HO'T DIESEL BY PUMPING TIME LOG ENTRY 0§:00 CON'T. TO KEEP TBG PRESSURED UP TO 4E~00f~ 9Y INJECTING blEOH. STILL TAKING NO FLUIU. Hb. A i ANNULUS BY PUMPING AND BLEEDING 4.5 BBLS 180 DEGREE DIESEL. REMOVED FLOWLINE FFiOM WING \/ALVE. SER,V. ICE COUP.~I~tY - SERVICE D~IL¥ COST ACCUM TOTAL $0.00._ $147.00 --APC .... .... $3,000.00 $18,000,00 BAKER OIL TOOLS $0.00 $3,000.00 DOW ,E,L,,L, ..... $0,00 S8.4~,638,00 FURMANITE $2,200.00 ! $2,200,00 MALLIBORT0~ $2.500.00 S11,519.00 ~LI'Ff'L'~ RED $6.120.00 " S4,6.660.00 SHIPPING GHARGE ........ $0.00 $0.00 L,TOTAL FIELD ESTIMATE .... $13,820.00 $166,164.00 ARCO Alaska, Inc. .,dPARUK RIVER UNIT ,t~ WELL SERVICE REPORT '~,~' K1(30-05(W4-6)) WELL JOB SCOPE JOB N~JMB5R 30-05 FISHING; FISHING & MIUJNG CPS 1204961353.2 DATE DALLY WOR~ UNIT NUMBER ...... 12/06/96 INJECT METHANOL DAY OPERATION COMPLETE I SUCOESS'FUL KE"/P='RS(~'~I SUPERVISOR 9 O Yes ~ NoI O Yes t~ No BRADLEY FIELD AFC# CcC I DAILY COST flC~JM COST signed ~$TIMATE KAWWRK 230DS36OL I $21,820 $187~.9.84 Initial Tb~ Pre.~s FinatTb¢l Press i !'nitial Inner Ann t' Fir~'a!'!nner Ann ! Initial Outer Ann I Fin8l Outer Ann 4500 PSI ,..4500.psiI 3500 P..S.l~l 3500 P.SIl 350 PsiI 350PSI DAILY SUMMARY CONT. TO MAINTAIN TBG PRESSURE AT 4500¢, W:METHANOL. HEAT ANNtJL[JS P,Y PUMPING AND BLEEDING HOT DIESEL. TIM E 06:00 LOG ENTRY DON'T. 'TO KP.,E.P 'fBG PRESSURED UP TO 4500# W;ME-i'HANOL. KEEF ANNULUS HOT BY PUMPING AND BLEEDING HOT DIESEL (4.5 BBLS), HES DRILLING MACHINE ARRIVED IH KRU AT 1 !:00 HRS. FUNCTIONED SAME IN SHOP. READY TO DRILL IN AM. SCAFFOL~ I',IG Ri. JILT IN FRONT OF 'WELLHEAD SHELTER. SERVICE"~6MPANY - SERVICE ........... DAILY COST ~bCUM TOTAL $0.00 $147,00 APO $2:50.0.00 $20,500.00 BAKER OIL TOOL~ ....... $0.00 $$,000,00 ,,,, , , DOWELL SD 00 $84,638.00 .. FURM~NI;FE ... "' ' ...... $7~200.00 $91400.00 HALU ,BURTON ..... $2,500.00 $14~019.00 LI~-fLE RED $6,120.00 $52,780.00 SHIPPING CHARGE ' $3,500.00 $3,500.00 I TOTAL FIELD ESTIM~:TE " $'21,820.00 $187,954.00 ARCO Alaska, Inc. KUPARUK RIVER UNIT ~1~ WELL SERVICE REPORT '~' K1(30,-05(W4-6)) WELL JOB SOd'tSE ' J'(~:)B NIjMOER 30-05 .... FISHING: FISHING & MILLiN.G. ePS ..... 1204961353,,2, DATE DAILY WORK ' UNIT NUMBER 12/07196 DRILL TOOL STRING _ DAY OPERATION C(~'ItviPLETE ~ SUCCESSFUL KEY PERSON ....... ~UPERVISOR 10 O Yes ~ NoI O Yes (~) No PiES BRADLEY FIELD AFC# CC~ J DAILY COST ~iOCUM COST '" Signed ESTIMATE KAWWRK 230DS$6OL $1 7,820 $205,804 ....... InitiaJ fb, Press Final Tb.~ Pr,ss ,nitia, inner Arr, F;nal ,nner Anr~ I I~tial Outer Ann ! Final Cuter ^~n . 4500 PSI 41, 0.0 FSI 3500 PSi_._ 3300 PSI[ 350 PSII 300 PSi DAILY SUMMARY ATTEMPT TO DRILL WIREUNE TOOLS THRU COMFANION VALVE W,~H FF, ,~Rt! J. lNG 'vlACHINE AND 2.5" FLAT BO'Fi'OM MILL. UNABLE TO DRILL THRU TOOLS. TIME LOG ENTRY 07:00 MIRU HES TOOLS, EDOM TRUCK, AND CRa, NE, fIELD SAFETY MEETING. RIG UP TOOL TO COMPANION VALVE. PT TO 4800¢¢ W/nOT OIL TRUCK. MEASURE VALVE '~.ND MARK ROD ON DRILLING MACHINE, 12:00 OPEN COMPANION VALVE, RUN TOOL INTO TREE AND TAG TOOL STRING. BEGIN DRILLING AT 1230 HRS. MAKING VERY LITTLE PROGRESS. AT 14:45 HqS, MILL QUIT DRILLING. 15;30 17:30 CCH W/MILL MILL SEVERELY WORN, FLANGE UF 1502 CAP BACK CN COMPANION VALVE. BEGIN BIjIbDfNG DR?~.iNG MACHINE (REPLACE PACKING, REP_ACE ROD, EDT). RIG HOT OiL BACK UP TO 7" ANNL)LUS TO RESUME HEATING, PUMPING AND BLEEDING. RESUME MAINTAINING TBG AT ,4.500#. PI,.A,t~; TO SHOOT ×-RAYS OF TREE TONIGHT. SERVICE COMPANY - SERVICE ............ ' ...... DAILY cOST J ~'C~uM TOTAL ..... $0.00.L $147.00 ..APC .... $~,..5oo.oo BAKER OIL TOOLS $0.00 $3,000.00 D.__~,C,,ELL ....... $0.00._ $84,638.00 FURMANITE $2,200.00 $11,600.00 _HALLJBURTON ...... $5.000.00~_ $1g,019,00 LITTLE RED $6~!.20.00 $58,900.00 SHIPPING CHARGE'" ... , TOT&L FIELD E.S...TIMATE ..... ,$.17,1120.00 '$205,804.00 ARCO Alaska, Inc. KUPARUK RIVER UNIT ,d~ WELL SERVICE REPORT '~i~ K1(30-05(W4-6)) WELL JOB SCOPE JOB NUMBER 30-05 FISHING: FISHING & MILLING OPS 1204961353.2 -- DATE ' [;)A~[Y WORK ..... UNIT NUI~IBER 12/08/96 PREP WELL FOR MILLING THRU WING VALVE [~AY OPEraTION COMPLETE' ~SUCCESSFUL ,~EY p'L-zRsoN SUIEERVI~OR 11 O) Yes (~ No ! O YeS (~ No BRADLEY ~i"IE~.D AFC# CC~¢ I DAILY COST '~'SbUMCOST Sigh'ed ESTIMATE KAWWRK 230DS36OLI $1 4,820 $~20,624 ,nitlalTbc~Press '¢i~slTb(3Pres, ,niti,llnnerAnn iFi,'la, lnner.~n' llnilialOuterAnn IFin,lOuterAnn'- __ . ...... 4500 PSI i 4500 PSI .. 3500...P..Si 3500 PSi 350_pSI 350 PSi DAILY SUMMARY PREP WELLHEAD SHELq:'E R FOP, MILLING THI~.j W~NG V~l .VF, CON'T, TO HOLD 45t%D~f ON TBG ANC HEAT ANNULUS BY PUMPING- lAND BLEEDING. TIME 06;00 LOG ENTRY CON'T. TO HOLD 4500# ON TBG W/MEOH. KEEP ANNU'.US WARM DY PUMPING AND BLEEDING HOT DIESEL (4.5 EELS). C,,UT ~' × 8' WINDOW IN WELLHEAD SHELTE~ N ORDER TO GET DRILLING MACHINE IN TO MILL THRU WING VALVE. 8L:ILD SCAFFOLDING BETWEEN WH SHELTER #5 AND ,46. S;RVICE '~'I~PANY - SERVICE DAILY '~0ST ACCUM TOTAL ,. $0.00 $147.00 _A_pC $3,500.00 $28,500.00 , , _BAKER OIL TOO LS ....... $0.00 $3t 000,0,0, DOWELL $0.00 $84,638.00 FURMANITE '" $2,20a00 $13,e00.00 HALLIBURTON' ............ ..... $3~,000,00 $22,019.00 LITTLE RED $6,120.00 $65,020.00 SHIPPING CHAR .G.E. $0,OO $3r500.00 TOTAL FIELD ESTIMATE $14,820.00 $220,624.00 ,,¢ · ARCO Alaska, Inc. ,,dPARUK RIVER UNIT .,41~. WELL SERVICE REPORT "~' K1(30-OS(W4-6)) WELL JOB ScoPE JOB NUMBE~ .... 30-05 FISHING: FISHING & MILLING CPS 1204961353.2 DATE DAILY WORK "' UNIT NUMBER 12/09/96 DRILL TOOLS THRU WING VALVE DAY OPERATi~ COMPLETE 1 SUCCESSFUL "T I~Y PERSON S'I}PERVISOla 12 O Yes (~) NoI OYes ~ NoI BRADLEY Fii~D AFC# [ C~ DALLY COS~ ' ACCUM COST '~i~ed'- ESTIMATE KAWWRK ....J 230DS38OL $19,320 $Z39,944 ........ 4500 PS~ ... 4500 PSI ....3500 p~l 3500 PSI! 350PS[.. I 350 PSI DALLY SUMMARY ATTEMPT TO MiLL THRU TOOL Sq'RING THRU WING VAt.VF. ST:tIPPED THREADS ON MILL AND LEFT SAME IN TREE. WILL I 1 A.-q'EMPT TO FISH TOMORROW. IN PROGRESS. TIME LOG ENTRY 06:00 CON'T. TO KE;EP TBG AT 4~'~0~ AND ANNULUS ,-.lOT BY PUMPING AHD BLEEDING DURING NIGHT. SUSPENDED HEAT QN ANNIJI [_.IS AT 0800 TO BEGIN RU OF DRILLING MACHINE ON WING VALVE. 08:00 HELD SAF:-FY MEETING, BEGIN RIGGING UP DRILLING MACHINE, LOWER DRILUNG MACHINE ONTO SCAFFOLDING IN 8E%~/EEN WELLHEAD SHELTERS 5 AND 6. BEGIN HOOKING UP HOSES FOR HYDRAULIC TEST ON DRILLING MACHINE. BOOM TRUCK HYDRAULICS WENT DOWN. 10;00 SEND TRUCK TO SHOP FOR RE;AiRS. 14:30 8OOIvl T~UC.K CN LOCATION. RU C~RILL!NG N,A,-il,-,L TO WING VALVE. FUNCTIC)I',I TEST HYDRAULICS. PT TOOL TQ 4700# UP TO WING VALVE. t5:30 OPEN WiNG VALVE, RUN TOOL INTO TREE AND BEGIN MILLING TOOLS W/2.5" FLAT BOTTOM, HOLLOW MILL, TOTAL LENGTH = 10". ~8" SUCKER ROD MALE THREADS ON TOP. MADE 1" IN APPOXIMATELY 1.5 HRS. COULD HEAR TOOLS CHA ,-FTERING IN TREE. CLOSED'$WAU ON 'rOOl~ (5 TURNS TOTAL), DURING NEXT 2_5 HR$, ONLY ABLE TO MAKE 1/4". 20:15 PULL BIT. MINOR WEAR ON FACE. DECIDE TO RE-RUN 21:30 NIPPLE BACK UP TO WING VALVE. PTTO 4500~. RUN BIT INTO TREE AND BEGIN MILLING. MAKING APPROXIMATELY 1/4" HOLE IN 3 HRS. 01 ;00 MILL IS APPROXIMATLY 0,4" FROM 8ACK SIDE OF 9ORE (23" F!::iOM FACE OF FLANGE OF WING VALVE), DECIDE TO TRIP BIT TO INSPECT. 01:30 CCH W/TOOt_ LEFT MILL IN TREE, STRIPPED OFF THREADS, RD FOR NIGHT. RESUME I IEATING BACKSIDE AND KEEPING TUBING PRESSURE AT 45,0.0# W/MEOH FOR REMAINDER OF NIGHT. sERVICE COM@~NY - SERVICE D&ILY COST ACCUM TOTAL , ! , ,, , , ,,, ..... $0.00 $147.00 ARC $~,ooo.oo s3,,.,5oo, oo _BAKER OIL T(~OL'S ...... ~._ $0,00.. $3,000.08 DOWELL $0.001 $84,638.00 FURMANITE ..... $2,200.00.~. $16,0.00.00 _HALLIBURTON ... $,5,000.00 $27,019.00 LITTLE RED $6,120.00 $71,14.0.00 SHIPPING CHARGE ................. $0.00 $3,500.00 ,, ,Hill .... - ............ , , -- TOTAL FIELD ESTIMATE $19,320.00 $239,944.00 ARCO Alaska, Inc. .,UPARUK RIVER UNIT ~1~. WELL SERVICE REPORT '~ K1(30-05(W4-6)) WELL JOB SCOPE ............... JO'~ NUMBER 30-05 FISHING: FISHING & MILLING CPS 1204961353,2 DATE DAILY WORK UNIT NUMBER 12/10/96 FiSH MILL & CONT. DRILL TOOLS THRU WING VALVE -DAY OPERATION COMPLETE I SUCCESSFUL .... KEY PERSON " SUPERVlSO'R' ' 13 O Yes ~,,,,~,9J O Yes ~ No JOHNS ,,, FIELD AF~ C~ DAILY COST ACOUM COST Si~ed ESTIMATE ~WWRK 230DS36OL $12~ 520 j $252,464 ,~itialTb~Press F~I'Tb~Pm'~' ~nitiallnnerAnn l~a~lnner~n' i Initial Outer Ann I Final Outer Ann ...... 4500 PSI 4500PSI; .... 3500PSI 3500 PslJ opsI oPSl, DAILY SUMMARY GETTING TOOLS MADE TO FISH MILL, AND CONTINUE RECYCLE 5 BBLS HOT DIESEL COWN 7" ANNUl I. TIME 07;00 LOG ENTRY GETTING TOOLS MADI::: r'O PItH MILL OUT FROM FLOWCROSS AT WING VALVE , CONTINUE RECYLCE 5 BBLS HOT DIESEL DOWN 7" ANNULI. 24 HOUR BASIS. APO MAN WATCH ON LOCATION. ,, ,, SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL ,, ,, , $0.00 $147.0Q; ,APO ..... , .... $"~ ,'200.00 ,~...5,.700.00: BAKER OIL TOOLS $0.00 $3,000,001 DCWELL $0.00 $84,638.00 ' ' FURMANITE ......... $2.~00.00 $18,200.00 HALLI~U"R'ToN .......... $3,000.00 .... $30,0i9,00 LITTLE RED $6,120.00 $77,260.00 SHIPPING CHARGE $0.00 $3,500.00 TOTAL FIELD E~'IM~'E ' '' $12,520.00 $252,464,0(~ ARCO Alaska, Inc. ,.dPARUK RIVER UNIT WELL SERVICE REPORT ~1~' K1 (30-05(W4-6)) WELL JOB SCOPE J'~B NUMBER 30.05 FISHING: FISHING & Mll.I.1NG CPS ...... 120,4961353.2 .,, DATE DAi'LY WORK 'UNIT NUMBER 12/11/'96 FISHING & MILLING TOOLS AT TREE VALVES -DAY OPERATION COMPLETE I SUCCESSFUL KEY pERSON. SUPERVISOR 14 O Yes ~ NoI O Yes (~) No . JOHNS ...... -Fl ELD AFC¢ "' CC~ ;3ALLY COST ACCUM COST Signed ESTIMATE KAWWRK 230D$36OL $10 ~ 6.,,0, 0 $263,064 ,,, J'nitiat Tbq Prass Final Th¢t Pm&~ initiat Inner Ann " 'Finai Inner Ann I Initisl O[;ter Ann I Final Outer Ann o PSII 0 P.$.I. _ 0 PSI 0 PS11 o PSIJ o P__SI DAILY SUMMARY FISHED 2.5" MILL FROM FLOW CROSS AT WING VALVE 8, STARTED DRILLING O!.JT TOOl. STRING AT WING WITH 2.0" MILL, STILL NEEDTO CUT ABOUT 0.5" TO COMPLETE CUT AT WING VALVE, REOYLE HOT OIL DOWN 7"ANN ULI TO ATTEMPT TO THAW HYDRATE PLUG. TIM__. LOG ENTRY 07;00 RIG UP HES HYDRAULIC DRILL, WIT~' MAGANET AND FISHF...~ OUT 25" MILL FROM ACROSS WING VALVE. 15:00 03:00 RIG UP 2,0" MILL AND START MILLING SPANG JARS, ENTRY FOR MILL AT WING VALVE. CONTINUE RECYCLE 5 BBLS HOT DIESEL DOWN 7' ANNUL! STILL NEED TO CUT ANOTHER t/2 INCH TO COMPLETE CUTTHRU SPANG JARS. MILLWORN DOWN. RIG DOWN , WAITING O1'4 ANOTHER MILL FROM BAKER OIL TOOLS. SERVICE COMPANY SERVICE ..... DAILY COST ACCUM TOTALS' $0.00 $147.00 -APO ' '- $1,200,00 ,, $36?00.00 , , BAKER OIL TOoLS ' , ............ $400,;,,00 $3,400.00 $0,00 $84,,638,00 ~ DOWELL ..... FURMANtTE $0,00 $18,200.00 H _ALUBuRTON ....... ~_ $3.000.00 $33,019,00,,, -LI'I-rLE RED ....... $6,000,00 _ ~3,2e0,00_ .SHI~;PING CHARGE .... $0.00 $3,5oo.00 TOTAL FIELD ESTIMATE $107500.00 $263,064.00 ARCO Alaska, Inc. .,UPARUK RIVER UNIT ,dm WELL SERVICE REPORT '~' K1 (30-05(W4-6)) '" WILL JOO SCOPe ........... 3(~i~' NuMS-E-R 30-05 FISHING; FISHING & MILLING CPS 1204961353.2. DATE DAILY WORK UNIT NUMBER 12/12/96 FISHING WIRELINE TOOLS FROM WELLHEAD TREE DA~/ 'OPERATION COMPLETE I SUCCESSFUL "KEY PERSON SUPERVI~0R 15 _. _.(j~) Yes (~ Noi O Yes (~) No JOHNS ............. FIELD AFC# ..... CC~' DAILY COST ACCUbl CO~T Signecl ESTIMATE KAWWRK 230DS36OL $1 1 ~,,300 $274,.364 Ihi;tial Tbcl Pr6ss Final Tb{::l Press Initial Inner Ann Fin~,i Inner Ann I ,nitia, O,,te, Ann I Final OIJ'{6~'Ann , 4500 PS1 3700 PSI 3500 PSI .... 3000 PSII0PSII 0 PSI DAILY SUMMARY COMPLETED CUTTING TOOL STRING IN TREE, TOOLS DiD NOT FALL AWAY FROM BLOCKING TREE VALVES HAS WAS HOPED, SHUT DOWN HOT OIL HEATING ON 7" ANNUM AND STARTED GETTING EQUIP READY TO FREEZE TREE TO REMOVE STACK ABOVE TREE TIME 07:00 13:00 LOG ENTRY COMPLETED CU'FFING SPANG JARS, BUTTOOLS DID NOT FALL AWAY FROM BLOCKING TREE VALVES, SO STILL UNABLE TO SHUT VALVES. SHUT DOWN 7"/~NNULI HE~TING . STARTF:D GETTING PEOPLE AND EQUIP READY TO FREEZE TREE TO REMOVE BOP STACK ABOVE WELL HEAD, s'~R~IC'E COMPANY - SERVICE DAILY COST ACCUI~ TOT~A~_ $0,00 $147.00 ARC " '. .,30o.00 BA,,KER..O. IL TOOLS ,.. $600.00 . $4,000.O0 _DOWELL $0,00 $8~,6R8.00 . , ---, ....... __ , FURMAN1TE $1,800.00 $20,000.00 _HALLIBURTON .................................. $3,000,00 ..... $36,0.1.9,0(~ UTI'LE RED .... .$~. ,50.0,00 .$,87,760,00 SHIPPING CHARGE $0,00 $3,r~30.00 , , . TOTAL FIELD ESTIMATE $11,300.00 $274,364.00 ~ , ., ,. ARCO ALASKA, INC. DEV. & EXT GEO$CI£NCE T RA# SI~ I TTAL Transmitted herewith are the following: ACKNOWLEDGIqENT: ~ , Retu~'n rece,,t to: ARCO~¥ & ~xl~Lu~~~~ihnston "A, A~N: ~, O, ~x 100360 Anchorage~ Alaska 99510 Processed v ARCO Alaska, Inc. Date: April 24, 1989 Transmittal #: 7462 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. 30-18 Sub-Surface Pressure Survey 2-1 1 -89 #64613 30-08 Bottom Hole Pressure Surveyq 2-26-89 #962636 30-05 Sub-Surface Pressure Survey 2-16-89 #29855 30-14 Sub-Surfece Pressure Survey 1-23-89 #72655 3 O- 18 Kuparuk Well Pressure Report 2 - 1 1 - 8 9 Sand 'A° 3 O- 14 Kuparuk Well Pressure Report I - 2 3 - 8 9 Sand 'A' 3 O- 08 Kuparuk Well Pressure Report 2 - 2 3 - 8 9 Sand 'A' 30-17 Kuparuk Well Pressure Report 3 - 0 4 - 8 9 Sand 'A° Receipt Acknowledged: ,,DISTRIBUTION: D&M State of Alaska SAPC Mobil Chevron Unocal 1. Operations Performed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C, OMbi~ION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate Plugging Perforate ,,, Pull tubing Alter casing ~ Repair well Other feet 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ... Exploratory _ Stratigraphic _ Service ~ 4. Location of well at surface 811' FNL, 1892' FWL, $EC.22, T13N, R9E, UM At top of productive interval 1368' FNL, 1956' FWL, SEC.15, T13N, At effective depth 1129' FNL, 1927' FWL, SEC.15, T13N, At total depth 1067' FNL~ 1920' FWL~ SEC.15r T13N~ 12. Present well condition summary Total Depth: R9E, UM R93, UM R9Er UM measured 8 8 4 0' feet true vertical 6 9 5 8' feet Plugs (measured) Effective depth: measured true vertical 8742' feet Junk (measured) 6883' feet Oasing Length Structural Conductor 80' Surface 4 91 0' Intermediate Production 8 7 9 8' Liner Perforation depth: measured 8504'-8524', true vertical 6702'-6717', Tubing (size, grade, and measured depth) 2-7/8 J-55 6.5# @ 8323' 6. Datum elevation (DF or KB) RKB 59' 7. Unit or Property name Kuparuk River Unit 8. Well number 30-05 9. Permit number/approval number 88-76 / 9-402 10. APl number 50-029-2183900 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Size Cemented Measured deplh True vertical depth 1 6" 193 SX AS II 110' 110' 9-5/8" 1200 SX AS III & 4945' 41 09' 37O SX CLASS G 7" 200 SX CLASS G 8831 ' 6951 ' 8466'-8488', 6674'-6690', 8444'-8458' 6657'-6668' MAR 0 5 t993 13. Packers and SSSV (type and measured depth) Alaska 0il & Gas Cons. AVA RHS PKR @ 8252', OTIS FMX sssv @ 1781' ~nchnrngn Stimulation or cement squeeze summary CONVEFITED FROM PRODUCING WELL TO WATER INJECTION WELL 0 ~ ~ / 2 7__ / ~ ~, Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation ,,, Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 830 535 0 1190 0 0 2341 16. Status of well classification as: Water Injector _X Oil Gas ~ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C-~u~., ~ Title Petroleum Engineer Form 10~404 Rev 09/12/90 Tubing Pressure 140 10 10 Service Da. 3/4/'~'..~ SUBMIT IN DUPLICATE STATE OF ~ ALASKA OIL AND GAS C1,ONSERVATION COMMIS,51ON :{'~ ~? ! C I ~J ~ APPLICATION FOR SUNDRY APPROVAES ' , 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other X 2. Name of Operator ARCO AIc~ska. Inc, 3. Address P. O. Box 100360,.Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 811' FNL, 1892' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1368' FNL, 1956' FWL, Sec. 15, T13N, R9E, UM At effective depth 1129' FNL, 1927' FWL, Sec.15, T13N, R9E, UM At total depth 1067' FNL~ 1920' FWL~ Sec. 15~ T13N~ R9E~ UM 12. Present well condition summary Total Depth: measured 8840' feet true vertical 6958' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 59' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 30-O5 9. Permit number 88-76 10. APl number 50-029-21839 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 8742' feet Junk (measured) 68 8 3' feet Nor~ Casing Length Structural Conductor 8 0' Su dace 491 0' Intermediate Production 8 79 8' Liner Perforation depth: measured 8504'-8524, true vertical 6702'-6717', Tubing (size, grade, and measured depth 2 7/8" J-55, 6.5# @ 8323' Packers and SSSV (type and measured depth) AVA 'RHS' packer @ 8252' Size Cemented Measured depth 1 6" 193 Sx AS II I 1 0' 9 5/8" 1200 Sx AS III & 4945' 370 Sx Class G 7" 200 Sx Class G 8831 ' 8466'-8488', 6674'-6690', 8444'-8458' 6657'-6668' Otis 'FMX' SSSV @ 1792' 13. Attachments Description summary of proposal,,~ Convert well from oil producer to water injector. 14. Estimated date for commencing operation 06-01 -89 16. If proposal was verbally approved Name of approver Date approved True vertical depth 110' 4109' 6951' Detailed operation program _ BOP sketch 15. Status of well classification as: Oil X Gas Suspended Service Water Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. F~ ~MMi~N ~E ONLY Date &--//~( - '~ '~ Conditions of approval: Plug integrity m BOP Test Mechanical Integrity Test ~ Notify Commission so representative may witness Location clearanco Subsequent form require 10-~ Approved by the order of the Commission Form 10-403 Rev 5/03/89 SIGNED :-~O,:~INIE C. SMITH IApproval No. Approved Copy Returned Commissioner Date SUBMIT IN TRIPLICAT~ 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 1. 5000 PS1 ?" W[LLH[.AD CONNECTOR FLANGE 2. 5000 PS1 WIR[LINE: RAMS (VARIABLE: SIZE:) 3. 5000 PSI 4 1/6" LUBRICAIOR 4. 5000 PSI 4 1/6" FLOW TUB[ PACK-Orr ,H]REL]N.E BOP .... EO.UI, PMENT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION * WELL COMPLETiON OR RECOMPLETION REPORT AND LOG ,, , 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 88-76 , 3. Address 8. APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50- 029-21839 4. Location of well at surface 9. Unit or Lease Name 811' FNL, 1892' FWL, 5ec.22, T13N, R9E, UN .Kuparuk River Unit At Top Producing Interval 10. Well Number 1368' FNL, 1956' FWL, Sec.15, T13N, R9E, UM 30-5 At Total Depth 11. Field and Pool 1067' FNL, 1920' FWL, Sec.15, T13N, R9E, UM ~uparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. (uparuk River 0i 1 Pool RKB 59' ADL 25513 ALK 2554 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband.115.Water Depth, if offshore 116. No. of Completions 08/05/88 08/11/88 ~//2~,/~~'/E~<~~ I N/A feet MSLI 1 17. Total Depth (MD+TVD} 18. Plug Back Depth (MD+TVD) 19. D!re~4on~lSurvey I 20. Depth where ssSV set I 21. Thickness of Permafrost 8840'MD/6958'TVD 8742'MD/6883'TVD YES ~ NO [] I 1792' feetMD J 1700'(apprgx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL,GR,CBL,Gyro 23. CASING, LINER AND CEMENTING RECORD ,, SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , , , 16" 62.5# H-40 Surf 110' 24- 193 sx A5 II .. ....9-5/8" 36.0# J-55 Surf 4945' 12-1/4" 1200 ~x AS Ill & 370 sx ... 7" 26.0# J-55 Surf 8831' 8-1/2" 200 sx Class C ,,. , ,. 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 2-7iu" ~t~2:~'. 8252 8504 ' -8524 'MD/6702 ' -6717 'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND0~'MATERIAI-"USED See attached Addendlm, dated 'I'-Z~,-~ for fractur data. ' ...... 27. N/A PRODUCTION TEST ' Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test HourS'Tested PRODUCTION FOR OIL-BBL 'GAs-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing C'asing'Pressure CALCULATED.I~' OIL-BBL GAs-MCF WATER-BBL oIL GRAVITY-APl (corri ' Press. 24-HOUR RATE ~ "28. CORE DATA .... - , , , , Brief description of lith01ogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. tone ~0TE: Drilled RR 8/13/88. Perforated well and ran tubing 9/25/88. Fractured well 12/17/88. , , , Form 10-407 097/WC5 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in d~ ~ 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 8374' 6605' N/A Base Kuparuk C 8406' 6628' Top Kuparuk A 8431 ' 6647' Base Kuparuk A 8572' 6753' 31. LIST OF ATTACHMENTS ddendum (dated 1-24-89) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ '~h.,~/,'~t-'U1 Tit~e~ea Drilling Engr, Date ":~' INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10407 ADDENDUM WELL: 9/09/88 12/17/88 30-5 Rn CBL/gyro logs (no depths available). Frac Kuparuk "A" sand perfs 8505'-8524' in seven stages per procedure dated 11/12/88 as follows: Stage 1: Pmp 155 bbls gelled diesel pre-pad @ 20 BPM, 4260-4182 psi Stage 2: Pmp 550 bbls gelled diesel pad @ 20 BPM, 4074-4135 psi Stage 3: 40 bbls gelled diesel, 2 ppg Carbolite @ 20 BPM, 4075 psi Stage 4: 60 bbls gelled diesel, 4 ppg Carbolite @ 20 BPM, 4090 psi Stage 5: 72 bbls gelled diesel, 6 ppg Carbolite @ 20 BPM, 4430 psi Stage 6: 80 bbls gelled diesel, 8 ppg Carbolite @ 20 BPM, 5100 psi Stage 7: 77 bbls gelled diesel, 10 ppg Carbolite @ 20-18 BPM, 5465-5100 psi Flush w/52 bbls gelled diesel @ 19 BPM, 4800-5100 psi Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 997 bbls 65,000# 772# 4700 psi '~D~iiling -Su~ervis~'~ t Date ~R-!8-~ 90 10: 2B I D: KRU,.'C I/NU/DR ILL I HG TEL N0:907-265-6£18 Bss_ Co~s. Got~m~'s~oG ' viCINITY MAP NOTES. I. ~ ~OOROINATE~ ~E A,S.E~ Z~E 4. 4. RE~ FI~ ~ ~-~--~ ~-~. ~ t3 ~, ~ 9 [, UMtAT MERIDIAN. e. HORIZONTA~ ~ITION MONUMENTS ~ ~U~BURY ........... ' .......... mST. OiST. .... Well Y ASPs X LATITUDE .... LONGITUDE ENL. ~NL Flay. F_Jev_ I $,0Z 2,095. Z? 5Z0,478.27 ~1~ ~8' t?.358'* 1490 47' 30.$97'' 724' IB4~' 17.5' 2 6,022,073. 8~ $P_$ ,490.94 70028. I?. 129" 149° 47 '$0.S~6" 745' 1855' 17.71 ~$. $', 3 6,0Z2,052. I~ 525,~.67 ~o~'. 16913" t 49° 4?~50. I~ 76Y 1867' 17.9 I~I ,, 149°47, Zg. Sm. 169', I e79', le.O~ 2S7', 4 6~022~050.~ 525~515.56 ~28~ ' " 5 6,0Z~8.~ 525~528.58 7~8, . 149~47 29.4~. 81 i, 16g~, 16. I ? 6,021 ~965,~ 5~5,553.~ l~9 14~47 28,6~, 06~ 1917, 18.2. 2~1 9 6,021 ~. 12 5~ ,578.27 i5,63Z 149° 47 27,974 897 1941 18.4 23.2 I0 6~021 ~84~ ~ 525 ~623.6l ~28" 14. ~3" 149°47'26.6~" 975' 1986' 18.7' 2~5' 11 6,021,822. ~ 525,655.71 ~' 14.651" 149° 47'26.295' ~7' 199~', 18.8' 2~.5' ~ 6,02I ,8~.87 525,64a.~ 7~2~',*~4.437" 149~47',~.9~ iOt~' 201 18.8' 13 6,021,779. 16 525,66t .~ ~e~, 14.223" 149°47 25.5~, I041', 2024', 18.g', 15 6,02~ 5Z5 ~6 lZ ~e~ 1~.~5 149°47 24,a~ i084~ 2048, 19.0, ,135, ?G · 16 6~0~1~?14. 15 525~698.17 ~e28' 1~.~3" 149o47'~4.4~ I10~ ~0~, 19,1 I? 6~0~1 ~69~ 5~5 ~7t0,85 ~' 13,56~" t49e4T'Z4.0~ 112~ 2073 19.0' I8 6~02 1,670. 97 525,7~3.~ ~29' 13. 157" 149°47'Z3,733' t 149' 2085' 19.0' 23.3' .......... , m r ~ ~ i ,, ~ -- · rice I.AND SURVE?/'ING tN THE STATE OF ALASKA AND THAT THIS PI. AT RE:PRESENTS A .lOCATION SURVEY MADE BY ME OR UNDER. MY 8UPERVI$1ON, AND THAT ALL DIMEN$1ON~ ARE CORRECT ,m __ D.S. 3-0 WELL coNDUCTOR ~-BUILT LOUNSBURY & Associates ANCHORAGE, _ ............. ALASKA Mr. Randy-Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska October 10, 1988 99510 OI IGIivA L Re: Our Boss Gyroscopic Survey Job No. AK-BO-80096 Well: 3-o-5 Field: Kuparuk Survey Date: September 8, 1988 Operator: T. McGuire Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure NL Sperry. Sun/NL Industries, Inc. P.O. Box 231649, Anchorage, Alaska 99523-1649 Tel. (907) 522-1737 ARCO ALASKA, INC. 3-0 -5 KUPARUK FIELD ALASKA ~:~_r~ WELL~_::~RVE.Y_LN~E'__A~NY ANCHORAGE ALASKA C OM~_Lk!ST_I ON._ DATF=_ ................. SEPTEMBER 9, 1988 · ......................................... ._T.R.._Li~ ........... SUBarEA ................. .~JU_R._R~ ......... _COURSE MEASURED VERTICAL VERTICAL INCLINATION DIRECTION DEPTH DEPTH DEPTH DEG M I N DEGREES DOG-LEG SEVERITY DEG/100 PAGe. 1 DATE OF SURVEY SEPTEMBER 8, 1988 BO$~~~__SURVE¥::'::'.:' ":' :. ._lOB NUMBER AK-BO-80096 KELLY BUSHING ELEV. = 59.00 FT. OPERATOR-MCGU I RE · :.: ' ::::: x:ii!: :;: :';::..:i !.." ::ii'" TOTAL RECTANGULAR NORTH/.=.uL TH COORDINATES EAST/WEST ............................... 0 .............. 0.'00 ................ £'.5~'00 0 0 N O. 0 E 0.00 0.00 100 100.00 41.00 0 25 S 68.60 E 0.43 0.14 S ...................... ~ ~00,.00 !.~.~..~ ................ C~ ....... ~.~ ............... ~._.7~,.~._.~ ................... ~.~.~ 0.,..~__~ ....... 300 299.99 240.99 0 35 S 63.60 E 0.18 0.74 S 400 '~"~' ~ 340.''- c. ~.''- ~ 0 40 S =o 89 E O 14 1 33 .~. 500 499.98 440.98 0 41 S 37.89 E 0.18 2.15 S 600 599.97 540.97 0 33 S 51.10 E 0.20 2.93 S 700 699.97 640.97 0 36 N 49.39 E 0.74 2.89 S VERTICAL SECTIOn'.) 0. O0 0.00 O. 35 E -0.13 1.04 E ............ _- (2..._. .~ .......... 1.85 E -0.7:_--: 2.78 E -1.31 3.62 E -2.13 4.36 E -2,91 5.13 E -2, 86 750 749.96 690.96 800 799.89 740.89 :_~o0 849.72 790.72 900 899 38 '~-' ' -- . . ........... . ?.40. :~ 950 948.80 889.80 1000 ~7. ~ ~38. ~ 1 I40 3 40 5 45 7 27 9 47 10 49 N 15 30 E 4 02 0 .-..r, . . .z~- N 6.19 E 0.25 N 11.60 E 4.20 4.22 N 7.12 E 4.26 N 9..8(_~ __E_ ............ ~......_4_'_2_ ..... 9.88 N 8.17 _.E_ ................ N 9.60 E 4.66 17.27 N 9.43 E 17.32 N 8.39 E 2.12 26.11 N lC).83 E 26.17 1050 ! 04._6_ .~?.6_ ..... 1100 1095.61 1200 1191.95 130O 1286.72 1400 1379.92 1500 1471.80 1600 1561.58 1700 1648.77 1800 1734.16 1900 1816.54 2000 1893.99 2100 1967.95 2200 2040.77 2300 2113.58 2400 2186.23 2500 2258.43 987. ~- . 12 2..... ..6 .................. ~_ 1036.61 14 11 1132.95 16 52 1227,72. ._ ~0 18 1320.92 22 10 1412.80 24 15 1502.58 27 58 30 38 32 3 36 56 N 6.89 E 3.58 47.50 N N 6.80 E 2.67 74.09 N N 8.80. E 3.50 lC)5.66 N N 10.69 E 1.~8 141.35 N N 9. 0 E 2.19 180.18 N N 6.89 E 3,82 ~____.~ ........ 41 30 43 6 43 25 N 5.19 E N 4. 0 E N 3.19 E N 1.50 E N 1.60 E ...... N .... 2..._5_~.....E_ N 3.80 E N 4.69 E 1589.77 1675.16 1757.54 834.99 908.95 981,77 2054.58 2127.23 .:~ !. ?~., 4.~ ..... 13.71E 47.5] 16.90 E 74.18 21.28 E. 105.77 27.44 E 141.50 34.15 E 180.36 2.81 272.44 N 45.32 E 272.69 1.54 324.30 N 49.48 E 324.57 4.91 380.82 N 53.01E 381.1! 4.67 443.98 N 55.55 E 444.2? :::~:~:~:,~.:60~.~: 511.25 N 57.38 E 511.56 "':i~:~?'~;'69 579.74 N 59.83 E 58~_~0~_ .... 43 7 O. 94 43 40 O. 83 ..4.;~ ......... ~2._' ....... N_ ._D~..~.CJ. g ......... (~.:_.~_,~ .... 648.18 N 63.59 E 648.52 716.70 N 68.69 E 717.07 ARCO ALASI<A· INC. 3-0-5 I<UPARUi< FIELD ALASKA S P E R R Y - S L. IJ~[__I~=_I=.,J~.. S_~ U_~R_V_E_y_!J~I.~_~~.y. ANCHORAGE ALASKA DATE OF SURVEY SEPTEMBER 8, 1988 ~_M P LLT t~__T :l:.~ .__I:_ L.A_ ..T.F=_ .............................. C ~ ......... "' ' '.SEPTEMBER 9 1.- .=,,= . · ~c,.~ JOB NUMBER " n '=' ' g AK-B_-o00.6 KELLY BUSHING ELEV. = 59.00 FT. _ PAGE 2 OPERATOR-MCGU I RE VERT I L. AL ._ EL:T I UN UALIi}ULATED :AL .T. RI__JE. SUB?SEA .......... _C !-.-!!J R_ S.=,_E_ ........... ~OI__I~':._:.!_E_ .............. ~! _O !:.?'_.-. . .g_ E ~.~ TOTAL MEASLIRED VERTICAL VERTICAL INCLTNATION DIRECTION SEVERITY RE_.TANc~ULAR' F: -' F:OARDINATES_ _ VERTICAL DEPTH DEPTH DEPTH DEG M I N DEOREES DEG/100 NORTH/F;OUTH EAST/WEST SECT I C ............,.6L:5' "-'~' 'U .-' ._', :3 0'-"'--"- ' ........ 5o"= 227 i':o...:,==' 43 49 N 6.50 E U.:: ..... 7t~-i ............. .~...,4 .:::~" ......... -~.:., 1 ....................... N ~...-':"-:-:'. 08:> ............................ E :'~54 ............ c--=.:..,c, ...... 2700 2403. O1 2344. O1 43 18 N 7. :39 E O. 81 922.91 N 90.42 E 923.40 ........ 2_~t_.'~.~.. 2476.2! ............ 24_1.__~_.._2_1_ .......... _4.~ ..... 35 N 5.69 E 1,..6 '~'~'" ~':' ~ .~o. 1'.-? E 99_!..._1__2_ .......... 2900 '-'=5'" .... 24:."'? :R"' ,-- ..... v. :::z 3C~00 '--'A''~'=' '--"-'2566 ._ -' 41 4 N 5:39 E 0, ._, . . . ~ ~ ..~ ._,.._~.,.'~"' :R'-, 112:3 "-' '-' ~.:, N 110 10 E 11'-"'".' 92 ' . ~1 ............... !3!__.p~:.~. 2700.83 2641 83 40 52 N 5 69 E O. 28 11 :~,.. 5,c: N 116.4__4__~_ ..... ._,1_~_-~ ........ 3200 3300 3400 3500 3600 3700 2776.14 2717.14 41 23 N 2.80 E 1.98 2851.71 2792.71 40 25 N 1.8~ E 1.14 292~.~ ~ ..... 2869,..~ 3005.42 2946.42 39 16 N 3.19 E 0.62 3083.49 3024.49 38 4 N 3.60 E 1.23 3162.57 3103.57 37 24 N 3.89 E 0.69 3800 3242.69 3~00 3322.78 4000 3400.40 3183.69 3263.78 :~.'34._1 ;,~Q. 36 4 N 3.89 E 1.33 37 30 N O. 0 E 2.74 ........ _4.. ~ ....... ~ .......... _N ......... L,.!_0.._.N ........... _..'~.,_.~ 1254.17 N 121.31 E 1254.82 131~.60 N 124.00 E 1320.27 1447.42 N 129.63 E 1448.12 1=''- 79 . · _,oP. N 133.3:3 E 1510 51 ..... _;L~ZO.8~._~ .......... _l~.~...F.__ 1~Z/~61 .... 1630.55 N 141.40 E 16:31.32 1690.39 N 143.40 E 1691.16 ........... iZ~'~_4_i.....N ........ i._4Ji~_Z~...E ............. 1Z~P 4100 3475.52 4200 3550.11 4300 3624.~7 4400 4500 4600 4700 4800 ............ ~(' 5000 -5100 5200 5300 .5400 5500 3416.52 41 56 3491.11 41 36 3565.97 41 26 3700.10 3775.43 3850.04 - _ 3641.10 41 8 3716.43 41 6 :37'_.9~. Q4 42 . '2__'_.2 N 2. 0 W 1.42 1819.38 N 140.98 E 1820.1 N 2.10 W 0 '~ = ~' '~ = '-.q .... , 1oo~,. 95 N 138.60 E 1 o,_ 6.6:-] N 1.80 W 0,25 _ 1952.20 N.. . 136.35 .E__ _ 1:952.93 .. N 2. 0 W 0.34 2018.16 N 134.16 E 2018.88 N 2.39 W 0.27 2083.88 N 131.63 E 2084.58 .._N .... 3 O__.W ......... 1_.,_~3 ............ .2150.3!~__N ...........12.8_._~$~.E .......... ~O_Z._ ' 3924.26 3999.32 49Z5..~7 4151.75 4228.80 4306.24 4384.15 4462.14 4537.98 3865.26 41 46 N 3i 0 W 0.60 3940.32 40 55 N :3. 0 W 0.85 ...... ~9.~.~.._~1: .......... 4_9 24 N 2.50 W 0.61_. 4092.75 39 37 N 2.69 W 0.79 4169.80 39 33 N 3.10 W ~::i:~,;~26 424Z,~4 .......... ~ ..... 56___ .... ~ .... ~ ~O ~.., 0'8.~ 4325.15 38 41 N 4.39 W 0.31 4403.14 38 47 N :3.60 'W 0.51 4478.98 2217.31N 124.99 E 2217.97 2283.29 N 121.53 E 2283.93 2348.~ ~ ....... ~lq~__~.Q._..E__ ........... ~349.0! ___ 2412.62 N 115.4:3 E 2413.23 2476.27 N 112.26 E 2476.86 '.~5.~?._~.IY__ ............. l~8~_.E .... ~,.2P_8_ 2601.93 N 103.64 E 2602.47 2664.36 N ~9.28 E 2664.88 .:,FERRY-.:.LN WELL SLIRVEYING COMPANY ANCHORAGE ALASKA ARCO ALASKA, INC. DATE OF SURVEY SEPTEMBER 8,198o~' i<LIPARUK F I ELD SEPTEMBER .-.?, 1'-"'--' ~:~o ,JOB NUMBER AK-B0-80096 ALASKA KELLY BUSHING ELEV. = 59.00 FT. OPERATOR-MC:GLI I RE TRUE :.-,LIB~SEA ................ C.. ~31__. !.R_ ~: _E ........ C_~,.L!~,~[ .[~ O__G'_' .,_.L_E ~ ......................... TOTAL · 'I;I~ASURED vERT'i i~'~L VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEG M I N DEGREES DEG/100 NORTH/SOUTH EAST/WEST SECT I .............. 5&Ob .... 4611'41 ..... 4552-~'41 42 57 ............. -I~1 ....... 0"; ..... b~-W ......... 0~-~;6 ............ ~7-9-~'37 U 97.31 E 2797.87 5700 4684.71 4625.71 42 45 N 0 60 W 0 45 . . ~o~.,. 39 N 96.96 E 2865.88 5900 4831.77 4772· 77 42 ~9 N 0.89 W 0.03 3000.91 N ¥~,.01 E ~001.40 6000 4905.02 4846.02 43 8 N 1.50 E I 71 :3068. ')8 N ' = . )c,. 37 E 3069.46 PAAE '~: 6500 6600 6700 6800 6900 7000 7100 7200 7300 5263.95 5335.49 5406.95 5478.33 5549.61 5620.77 5691.91 5762.93 5833.65 7400 7500 7600 7700 7800 7900 8000 .8100 8200 8300 .8400 8500 5904, 30 5975. O0 ~0.45.9_.! 6116.78 6187.41 6258.33 6329.98 6402.43 6475.57 6549.45 6623.92 6698.85 · ~,204 95 44 16 N "' . . ~ . ~. 0 E 0.21 3416 46 N 115.24 E 3417 05 5276.49 44 22 N 3. 0 E 0.11 3486.24 N 118.90 E 3486.~, '-- = · _,.:,47 ~._, 44 '-"-' ....................... . ........ · ~.~ ........... N 2 60 E 0.28 3556 11 N 1~2.~:2 E .... 3~~ .... 5419.3:3 44 31 N 2.80 E O. 19 3626.07 N 125.62 E :3626.72 ~ ' m ~ i ~49o 61 44 :33 N 1 69 E 0.77 3696.16 N 128.37 E 3696 82 5561.77 44 41 N O, 1 ~ ~ . ~,~7_ ....... :37~ ~.~_~ ....... ~.~.~..~. _.~ ........... ~Z~Z. 06 · --, ) 5632.91 44 36 N 0.o( W 5703.93 44 53 N 0.10 W 5774.65 45 5 N ~., 69 W 5845.30 45 0 N 4.30 W 5916.00 45 0 N 4.39 W .... 59~6__-.? 1-- .... ~.4_ .... 40 ..... N____ 4_____. 19 W 6057.78 45 3 N 4.30 W 6128.41 45 3 N 4.50 W 6199.33 44 36 N 4.60 W 6270.98 43 51 N 4.69 W 6343.43 43 18 N 5.39 W 64~57 ..... 4~ 4~ ............ N .... ~_,69 W 6490.45 42 4 N 6.19 W 6564.92 41 :38 N 6.50 W 6~785 .......... ...... 17 ......~ .... 6~?...w 0.17 3836.68 N 129.10 E 3837.3 0.31 3907.08 N 128.86 E 3907.74 2.55, 3977.70 N ..126.51 E_ 3978.,35 ........ 0.43 4048.30 N 121·57 E 4048.92. 0.08 4118.81N 116.21E 4119.39 0,__~5 4189.12~ .......... ll~,~g ..... ~ .... 0.39 4259.48 N 0·14 4330.05 N 0·46 4400.34 N 0.76 4469.86 N .~i~:~:~ii~,..~?~,~.,,~. 73 4538.52 N ..... 0-65 _ _4606,~__~ 0.70 4673.43 N 0.47 473?.75 N 105.69 E 4260.00 100.26 E 4330.55 94.67 E 44~~ 89.02 E 4470.29 82.95 E 4538.91 ......... 76,36 E ............ ~606, Z~ 69.37 E 4673.74 61.99 E 4740.02 6200 6300 6400 4977.._6 4918.36 44 10 N 3.80 E 1.89 3137.-~' ' 9._~ N 98.57 E 31'-'-'. 5049.11 4990.11 44 7 N 3.60 E 0.15 3207.44 N 103.07 E 3207.96 5120· 79 5061 79 44 18 N '~ 39 E 0 23 3277 04 N 107 32 E 3277 58 · ,~,~. m · Ii 5192_..'=:..6 51:3:3,:36 44 17 N :3.30 E 0.07 8.1~.~,7~ N ANCHORAGE ALASKA ARCO ALASKA, INC. DATE OF SURVEY SEPTEMBER 8' 1988 KUPARUK FIELD SEPTEMBER 9, 1988 ,JOB NUMBER AK-BO-800~¢6 ALASKA KELLY BUSHING ELEV = . ~,~. OO FT. VERTIL. AL ~.EC, TILN CALE. ULATE:D ALONG CLOSURE ....................... ' T~Ug :SUB~SE'A .............. C[OUR,~g ~:~DUR:~g ............ ~.9~.gE.~ .................. T~T~L MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGLILAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEG M I N DEGREES DEG/1 O0 NORTH/SOUTH EAST/WEST SECT I ...... ,~600 6774.42 6715.4'2 ........ 4'0 ._,.-,-r,= N ~-" '"'~o > W 0.75 4,=,7~.}. ~4'~ ' N 46.40 E 4,~7D'-' 8700 68~0. A~ 67~1 6'~ 40 ':, N 6 ~'~' -- ou W O. 49 4t~:34 75 N :::8.6~ E 45*34 8'P -- · i ,_I i ~ I ~800 6[¢27 24 686o. 24 40 '~' · e. .N. 6.,,2_.]o0 W .... ~..P.O 47~8,.(74 N _3!,07 E 4998.7¢ ,:,,:, 40 6 ~.J 7. '-' o6 ~,~ .:~c,. HORIZONTAL DISPLAC'EMENT : 5(.?~.z...?~ .FEF]~.__.~T N__.L_-IRTH 0 DEG. 1.~ MIN. EA.=,T AT._.~_[_! ........... :_~..,':_3_4.0~ ....... THE CALCULATION PROCEDURES ARE BASED ON THE LoE OF THREE DIMENSIONAL RADIU~ OF CURVATURE METHOD. ARCO ALASKA, INC. KUPARUK FIELD ALASKA oFERRY-0--.,UN WELL SURVEYING COMPANY ANCHORAGE ALASKA DATE OF SURVEY SEPTEMBER 8, 1988 SEPTEMBER 9, 1'-'"'---' ' - '----' 'x'" .-.~oo ._lOB NUMBER AK-BO-o(..)~6 KELLY BUSHING ELEV. = 59.00 FT. EAnE 5 OPERATOR-MCGU I RE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRLIE SUB-SEA TOTAL MEASURED VERT I C:AL DEPTH DEPTH VERTICAL RECTANGULAR COORDINATES MD-TVD DEF'T_H ........ N 0 ~._T...~./.__.'-'!.~!U TH EA~!T./WE:.=.;T ~! ! F~.EREN~__-:E VERT I C:AL c O.R_R_E. L_-.'._T. ................ ) 0 0.00 -59. 1000 997.99 938. 2000 1893.99 1834.99 3000 2625.32 2566.32 4000 3400.40 3341.40 5000 4151.75 40~2.75 6000 4905.02 4846.02 7000 5620.77 5561.77 8000 6329.98 6270.?8 8840 6957.86 68~8.86 O0 0.00 0.00 0.00 26.11 N 10. A'-' .~.:~ E '~ O1 2 01 -~, ,.-,o N ~ 55 E "106 O1 104 00 44.= ...... ~ ....... 112 ,. :--:L~ 374 68 .-, c: · -'3 '- N 110.10 E , · .-' 6~, 67 5'--I o ,_-. ~.~,- - !.._7.-_-..-_..: ..4.1...N ....... _1_4_~., ..7. !_., E ...... :-?.~ ..~ ._. 6L] ..... 224. ........... 2412.62 N 115.48 E 848. ~, 248.65 3068. :98 N .95.37 E 1094.98 246.73 3766.3~ N 1~9 ?.5 c ~o-~o .-,--., '-"~'~ 25 4469. :36 N :39.02 E 1670. A2 2'PO. 7:9 ~ ¢- .-, .-, ¢- .-., · _, .)~4..-'- .~ N ~8.02 E 1882.14 212.12 ANCHORAGE ALASKA ARCO ALASKA, INC. KUPARUK FIELD SEPTEMBER 9, 1988 ALASKA RAGE 6 DATE OF SURVEY SEPTEMBER,= '~', 1988 ' dOB NUMBER AK-BO-80096 KELLY BUSHINO ELEV. = 59.00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRLIE SUB-SEA TOTAL MEASURED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES; MD-TVD VERT I CAL K_!~PTH ........ DEPTH_ D_E_P._T_H_ ............ N O.R T_H_/._S..!C!.U T H .E~ST / W.E.!.---.!T 0 0 00 · -o ?..'. O0 0. O0 0. O0 .......... ..__.,95,.-?. oo o.._..9c? ..................... _~2,_q'_a_. $ .......... O, (~7. E 1 ~'9 159. O0 100. O0 0. '"(' -. ._-~J S 0.76 E 25¥? 259.00 200.00 0.56 S 1.48 E '"="~ 2.40 E · _'-,.::, ~ 359.00 '~' ' ' · '-,OU. O0 1.04 S 459 ~.,.'=9. O0 400.00 1.77 S 3.31 E 0.02 559 55;?.00 500.00 2.68 S 4.05 E 0.03 /_-,5'.~ 6,5 ~. 00 600.00 '" ~.16 S 4.80 E 0. 7._, :-..' 7.=,':~ 00 700.00 1 77 ':' 5. ",'-' 6.~ E O.A~ _.. . ._l 859 ,:, ~,-"l (.')C) L~OC · ,=,~,.~. -' ') 5.14 N 7.30 E 0.33 '.-?AA 959.00 9 C)('~. 00 19.01 N '~. 73 E 1 '-~ 1062 1059. O0 1000.00 38.73 N 12.61 E 3.33 O. 00 O, 0(! .......... 0.00 0. O0 0.01 O. 00 ...... (!.: q..i 0,9.! 0. O1 0.01 O, 0(~ ............................ O. 02 1.. 02 . 1165 1159.00 1100.00 64.47 N 15.75 E 6.65 ........ ~_~.7_9 .......... !_2_57._ o!:? ........ !_~_0.9._SoC__L .......... 95. e2 N 19.81_ E. ........ _1_1.5~ 1377 1 '---'~'" - · .',._, ~. 00 1:300. O0 1L.~2.97 N 25.85 E 18.41 1485 1459.00 1400.00 174.48 N 33.25 E 26..96 1597 1559. O0 1500.00 222.43 N ........ ,,4.0.02 E ,, :~8,, 09 ! 71 1 ! 659. O0 ! 600. O0 278.48 N 45.86 E 52.89 1829 1759. O0 1700. O0 340, 31 N 50.56 E 70, 57 3.32 4._.8~ ...... 6.87 8.54 11.13 14.80 17.68 ARCO ALA~:.KA, INC. K JF ARUK F'! ELD ALASKA MEASURED DEPTH ANCHORAGE ALASI<A DATE OF SURVEY SEPTEHBER 8,l'°~"~'..-o~, SEF'TEHBER 'P, 1'- ~'c,,:, ._lOB NUMBER AK-BO-::-:0096 KELLY B J.:.HI NG ELEV. 59.00 FT OPERATOR-MCGLi I RE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA T~i~-AL VERT I CAL VERT I CAL RECTANGULAR COnRD I NATES HD-TVD VERT I CAL DEPTH . DgPT_H_ ............ NOR.T...~..~E;O.L!.,TH ....... EA.!.S!.T/_WES.'! p.I.. FFERg._N.!.--.~_E. ........ c_:_C!.F(.'R_E..Ci.TJ: C!.N ................................................... ) ... 1954' 2087 2225 2362 2500 2639 2776 2911 3044 3177 330~ .... 3439 3568 3~95 3820 3946 1'~=-'~ O0 1F:AO 00 414 21 N 54 · --,:_~ E '-=- ~ ~,.-. ....... ~A_,. 04 24.47 1959.00 1900. O0 50~, 8~! N 57..14 E . 128, 74 31~, 71 ................... 2(')5':'~. _.. 00 20('1(').... O0 fi'.-?A_. _. 97 N 60 ..__,.~,:q E 166. A'-?.. :'::7. ._'~-._, '-.":' 1 '"='- ,...,:/, O0 21AA... 00 A90_. .78 N 66.56 E ._':,A3. .35 2:7. ~._, ~-..._'--"-'5':,,. 00 2200 O0 786, 16 N "7,~ ,--_,,--~ ~ 241.79 '--,A 44 '--""".~'-'" O0 "":'-~ ' ' ~,. O0 O0 ~ _-,_ .-.,z, ,=,~ 164 N , . ,= .... 17 E 280 44 . o,:,. 65 '~ "' ~'-'" 00 '--' ') ' z4¢0.00 974.85 N 96.62 E 317.62 37.1 . ~._,¢ O. 00 1065.16 N 104. ~2 E 63 .:.~,. ) 1 265':? 00 '-' ]' _. . _ z6LO.00 115'2.53 N 11'-" 87 E ' . 3o._,. 66 3:3 0:~ · -,~59 00 2700.00 1239.07 N 120.57 E 418 15 :~s, 48 oA~,:; 00 ~800.,00 ~_.._~_~,.,..~_._N_ 124,.-.~ E ~50,_~,~ '~'? ,~3 ~,:..-~....,-.., :-4'-'~" ,-_, .-,¢- 2959.00 2900.00 1409.43 N 127.58 E 480.98 30.40 305.9. O0 3000. O0 1490.65 N 13'2.12 E 509.89 28. '.-? 1 ~, 1 ..,.. 00 31 @0. O0 '-"-'~'-' 00 :~20r~. 00 ._-~ ..-._~ ;~. - :_:::_~59.00 3:300.00 ............ _.4-_~7._7_ ............ .'_3_~.~9 ..Oo .... 34oo. oo 421 1 3559. O0 3500.00 4345 3659.00 3600.00 !~6~,.1~ N ..... 137,.1~.._..E ..... ~.6_,~1 ............ 26,62 .............. 1642.47 N 142.13 E 561.21 24.70 1718.~5 N 143.26 E 587.13 25.92 !804, ~_~L. ........ lil, 50 _F. .........~~'.~_ ........ 31, ~ 1893.84 N 138.31 E 652.89 34.11 1~82.22 N 135.40 E 686.38 33.4~ ARCO ALASKA, INC. 3-0-5 KUPARUK FIELD ALASKA _,FERRY-'-' I ........ .'--;i IRVE TKIG F:O ' ~ ::' ' SL B __W_E. LL_ ........ Y._ ...... ANE:HORAGE ALA.=,KA DATE OF SURVEY SEPTEMBER SEPTEMBER 'P, 1 '-'--"=' :700 ._lOB NUMBER AK-BO-80096 KELLY BL.:,HINU ELEV 5.~. 00 FT I NT£RPOLAT:ED VALJEo FOR EVEN 100 FEET OF SUB-SEA DEPTH TRuE ..... SUB-SEA T'L]'T-AL MEASURED VERTICAL VERTICAL RECTANU JLAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/~:;OLITH EA::;T / WE'.:;T D I FFERENF:E F:ORREF:T I Ol~ 4478 3759.00 ......... 46.1__~ . 4746 '--"---'='" · _'~ ~_, .:.. 00 :3'F~00.00 4878 4057~. 00 4000.00 · _,ou ~ 415'~. O0 4100.00 51 :S:~ 4259. O0 4200.00 5267 4:35'~. O0 4300.00 53'~5 445~. 00 4400. O0 ~'~"=' 55'~. · :,.-,~o 4 .... ~ O0 4500.00 5664 ~ ~':~. . ~,:,._ ~ 00 4600 00 3700. O0 2067.. ~, N 1._~... E 71'~ 19 -. -:,~ 1 . . .,..~.,,~. 3800. O0 ~°158. ._.=,=.., N 128.06 E 7._,o.='--' 1':' _.~._~...~...4'. 2248.24 N 12:-,' . ._'-~,'"_, E 787.54 34 .41 '-"':"-"'~ /_',3 N 119.00 E "--' . ~.~19 77 .:::Z. .... ..~":"-' ~.~ '--I '~,~1 'l~ · I 241"" ~"' o._,.,. 42 '--: ('} _ ~ 5 2501 · 18 N 110. '=? ! E 880.16 2?,. 75 2581 .... 84 N 105 19 E '~08 77 .':~.'-"- 61 2661 84 N .99' 44 E S.~36 '~6 '-'::' '"' 2748 .... 77 N '.97 31 E 96954 '-"~_-,~_. 57 '-":' . . :.~.=. 36 45 ,-,~,41.62 N 97 2! E 1005 '-'-' . 5801 4759.00 4700.00 5937 6074 6213 6353 6493 6632 6772 6913 2933.~1 N ~6.06._.g ............... !~.~7___ .'~_0~ 485~.00 4800.00 3026.00 N ~4.61E 1078.02 35.~5 4~59.00 4~00.00 3120.13 N 97.39 E 1115.41 37.38 ..... ~ ~99 .... 50~.~.~ ............ ~A 17 .£!l___N ................. ~3 ~.6Z_.E_ .......... 1.104.7~_ ................ ~. 37 .................. 5159.00 5100.00 3314.26 N 10~.53 E 11~4.3~ 39.61 5259.00 5200.00 3411.64 N 114.~9 E 1234.08 39.6~ 535~.00 5300.00 3509.21 N 120.10 E 1273.8~ , 37.81 545~.00 5400.00 3607.0~ N 124.69 E 1313.8~ 40.00 5559.00 5500.00 3705.40 N 128.64 E 1354.18 40.29 ANCHORAGE ALASKA ARCO ALASKA, INC. DATE OF SURVEY SEPTEMBER 8, 1988 · ....... ., . .~.o dOB NUMBER AK-BO-00096 KLIFARUK FIELD SEPTEMBER 9 1'~°'-' ALAoKA KELLY BLoHINb ELEV - 59.00 FT. OF'ERATOR-MIZ:GLI I RE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRLIE SUB-SEA TOTAL MEASURED VERT I C:AL VERT I CAL RECTANGULAR COORD I NATES; MD-TVD VERT I CAL DEPTH DEPTH 7Cx_,o ._,c=A='-'._,.~. 00 5600. O0 3804 21 N 129 26 E 1394 77 40 '~'- 7194 = ='- ~ ' .,7._l ~1 00 ~ 700. O0 :RgO:;:. 17 N · .~,-, e,z~ .-.= 7:3:35 =:q='~ O0 =e, - ~_,o00 O0 400:3 "- . .....~_,._ ~, z. 0.~ N 124.87 E 1476 . q 1 41 · 45 7477 s9~'~; O0 ~900.00 4102. ~6 N 117.44 E 1518.37 41.46 775'P 6159. O0 6100. O0 4301.67 N 102.50 E 1600.77 41.36 7900 6259.00 6200.00 4401.00 N 94.62 E 1641.95 41.17 8040 6359.00 6._~c~o. O0 4497.64 N ~:~, 73 E 1~8~ ~4 8177 64._, y ..... 00 6400.00 4591 18 N 77 o,;,e,,: E 1718.45 37. 22 8312 ==c ~.:, 6o._,.~. 00 6500.00 4682. O0 N 68.44 E 17._ .:,. 87 35.41 8579 6759. O0 6700. O0 4857.44 N 47.98 E 1820.71 ~.'~'" 79 8710 6859. O0 6800. O0 4941.68 N 37.86 E 1851.86 31.14 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FO_~!T_MD (FROM RADIUS OR CURVATURE),POINTS .... ANCHORAGE ALASKA ARCO ALASKA, INC. DATE OF SURVEY SEPTEMBER 8~ 1988 3-0-5 ~: ':' ': ~U.T.~"I:I.rI_LI~_... iD~]:E ': KUPARLIK FIELD SEPTEMBER 9~ lo'-'° .~-,=,,~ JOB NUMBER AK-BO-80096 ALASKA KELLY BUSHING ELEV. = 59.00 FT. OE~~~~E ................................................ :" " :: ::~x::~:'.: :::::::::::::::::::::: I NT~RPO~ATED VALL;Eo'" FOR '.SPEC I AL '~;~URVEY' PO I NTS : T OE SU -SEA MEASURED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES ..DEPTM .... DEPTH DEP~.~ ......... ~O~H/.'.~;OUTH ~AS~/N. EST ............ MARK~B 8374 6604.50 .~, . /. 6~45.50 4722 58 N ~_,~.95 E TOP KIIPARI~K C ..... 840..6 66~:? 4 _1 .. =- '~ '-' '=- '- ' _.. ~_'.._~6 '..'~-___4__1. ................... ~..7..4.~L....7..1_...N... ~,.! .__..:._!4 E ...... ._B..~.$E ~ '-~ . ?,.-..~ ._4._ 1 6647 ('):~'/ 0';/ , 59.66 E TOP I<:LIPARLII< · .. o._,_-,,_,, . 4760 '21 N '::?,'?'-' ATM '"! ..... ,;,-- ,' .,::. c ,' .-,..~, 14 66')4. 8700 k:z.:¢,', ,'.':/ '"'"'"':/" ''--"" "":/'--'" '"'=' "' ":":', 6'::/ E SURVEY DEPTH 8742 /- F.:_'o'-, :34 6823 84 4.')61 '='~' ~-~.,.,z.. . · c,c. N 35.49 E PLUG BACK TD 894(;) 6957.86 6898 86 ~- '--, ,;,0~4.20 N .02 E TOTAL DEPTH - - . 28 ARCO ALASKA, INC. ~-0-5 DER]:_VEI'~ USING DIE DEPTHF~ AND :3PERRY .:,LN F:URVEY DATA ::' BKB BKB SUB-SEA VERT I CAL ( OR I G I N- 1892FWL ) . :. : SEC 22 T13N: ROgE TOP KUPARUK C BASE KLIPARUK C TOP KUPARUK A BASE KUPARUK A PLUG BACK TD TOTAL DEPTH 8374 8406 8431 8572 8742 6c, 4._,.._ L) 4722.58N 63.95 6604.50 = = 6~'~,..4.~ '~' '~::.!/-'__'_.:~,_._~=' " ..... 4743.71N 61.54 6647 ' '- .0 ~ ~ ~'~'~ o~,,~. 09 4760.21N 59.66E 6753.14 6694.14 ~'=~ · ~o~,~. 46N 48 59E 6882, 84 "~'-"~ :~ ~'~' ' 5:~' '"= '" 6c,~, '-'F ~(')':'4 20N --,o 02E 6957 o6 ,-,,- o 1) FROM LINEAR EXTRAPOLATION BELOW DEEPEST STATION- 2) COMPUTER PROGRAM - SPERRY SUN THREE DIMENSIONAL RADIUS OF CURVATURE. .___D~_T~_.C.A_~C:LIL__A_._T .!(!N ._AND _IN.T_E~PO_L. AT I ON B_Y__R_~ILIS...OF CURVATURE DATE OF SURVEY SE~T~B_._E_B_~...i.~8 ................ COMPUTATION DATE SEPTEMBER ~, 1988 JOB NU~BER,.~;AK-BO-80096 : ~ ::~!i!!;' ~:': ' ::'~:':!:' :i:~':'~:~'!i~ KE~LYBUSHINQ ELEY. = ~9_.OOFT, .............................. SPERRY 5CRLE KUPRRUK FIELO ;~ -Q -5 RK-80-80096 TRUE NORTH :- 1 INCH TO 1000.00 / tO00. O RRCO RLRSKR. INC. SEPTEMBER 8. i988 8840 ;000.00 000.00 000.00 000.00 000.00 HORiZONTaL PROJECTION SPERBT -SUN 0.00 KUPRRUK FIELO ~ -13 -5 RK-80-80096 $CRLE :- 1 INCH TO 1500.00 / 1500.0 SEPTEMBER 8, 1500.00 INC. 1988 3000.00 4500.00 695?. 66 VERT IC~)L 9ECTIBN 8840 7500.00 i I 1500. O0 30~0.00 45~0.00 I 8000. O0 VERT i CF:IL PROJECT I ON ~ STATE OF ALASKA , ALASr,,A OIL AND GAS CONSERVATION COMMISL REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown __ Stimulate m Plugging ~ Pedorate ~_... Pull tubing _,_. Alter casing __ Repair well ~ Pull tubing ~ Other COMPLETE 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 811' FNL, 1892' FWL, Sec.22, T13N, R9E, UM At top of productive interval 1368' FNL, 1956' FWL, Sec.15, T13N, RgE, UM At effective depth 1129' FNL, 1927' FWL, Sec.15, T13N, RgE, UM At total dep_th 1067' FNL, 1920' FWL, $ec.15, T13N, R9E, UM 5. Type of Welt: ',~ Development __ Exploratory __ Stratigraphic m Service __ 6. Datum elevation (DF or KB) RKB 59' 7. Unit or Property name Kuparuk River Unit 8. Well number 30-5 9. Permit numbedapproval number 88-76/8-669 10. APl number 50-- 029-21839 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 8840'MD 6958'TVD feet feet Plugs (measured) None Effective depth: measured 8742 'MD true vertical 6883 ' TVD feet feet Junk (measured) None Casing Length Size Structural Conductor 80 ' 16" Surface 4910 ' 9-5/8" Intermediate Production 8798 ' 7" Liner Perforation depth: measured 8504 ' -8524 'MD true vertical 6702 ' -6717 'TVD Tubing (size, grade, and measured depth) 2-7/8", J-55~ tbg w/tail ~ 8323' Packers and SSSV (type and measured depth) AVA 'RHS' pkr ~ 8252' & Otis 'FMX' $$5V @ 1792' Cemented 193 sx AS II 1200 sx AS ill & 370 sx Class G 200 sx Class G Measured depth 1lO'MD 4945 'MD 8831 ' MD True vertical depth 110'TVD 4109 'TVD 6951'TVD 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. N/A Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments J 16. Status of well classification as: CoPies of Logs and Surveys run ~ 6y ro Daily Report of Well Operations ~ * ! Oil ~ Gas m Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 (Dani) SW03/046 · NOTE: COmpletion Well History Service Date/¢//~'f¢/'~ SUBMIT IN DUPLICATE 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 ara started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. ARCO Alaska, Inc. NORTH SLOPE arish or borough KUPARUK RIVER UNIT L----- ADL: 25513 __ COMPLETE I Title ~ ~ J. ADZ: 50-029-2183..~___ District Field AK2971 Auth. or W.O. no. ARCO ell no. Operator ACCEPT 09/24/88 Date ~ ~,O. Spudded or W.O. begun Date and depth as of 8:00 a.~).9/25/88 ( ?B: 8742 SUPV:MDD NORDIC 1 Complete record for each day reported RUNNING 2-7/8" COMPL 7" 88 ' · ~7~3~-~-~ 1815 HRS, 9/24/88. NO BOPE AND TEST SAME. PERF 8504'-8524' W/ 8 SPF, 45 DEGREE PHASING. RUN 2-7/8" COMPL. DAILY: $28,600 CUM: $839,152 ETD :$839,152 EFC:$1, 345, 000 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 18 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 District ARCO Alaska, Inc. Field Stat~ no. I CO u nt Y ° ~I'PdI~I~IH SLOPE KUPARUK RI~]~R UNIT ILease°r~ll~: 25513 30-5 I Title CO~JPLETi~. Auth. or W.O.3~1~2971 API: 50-029-21839 Operator ~D, CO Spudded or W~,~ Date and depth as of 8:00 a.m. 09/26/88 TD: 8840 PB: 8742 SUPV:MDD IA-R.Co.~,0000 Date 09/24/88 Complete rec~[~rl~cl'~l_day reported Iotalnumber of wells (active or inactive) on this ost center prior to plugging and I ban.donment of this well J °ur1815 HRS IPrlor status If a W.O. I RIG RELEASED 7"~ 8831' MW:10.0 NACL FIN RUNNING COMPL. TEST TBG, ANN, AND SSSV. SHEAR BALL. ND BOPE. NU TREE AND TEST SAME. DISPL WELL W/DIESEL. RR 1415 HRS, 9/25/88 DAILY=S135,732 CUM:$974,884 ETD:$974,884 EFC:$1,345,000 NOTE: OTIS 'FMX' SSSV ~ 1792', AVA 'RHS' PKR ~ 8252', & TT @ 8322'. Old TD Released rig Classifications (oil, gas, etc.) JNew TD I PB Depth Date IKind 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.P. C.P."" Water % GOR Gravity Allowable Effective date corrected ... S~gnatur~, / ~'----~~ ~ ~ see Procedures Man , Section 10, Drilling, Pages 86 and 87. 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 [-~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate C Other 2. Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska, Inc. RKB 59' feet 3. Address 6. Uniter Property name P. O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of wellatsurface 811' FNL, 1892' FWL, Sec. 22, Attop of productiveinterval 1320' FNL, 1848' FWL, Sec. 15, Ateffective depth 1138' FNL, 1878' Attotaldepth 1077' FNL, 1886' T13N, R9E, UM T13N, RgE, UM (Approx) FWL, Sec. 15, T13N, RgE, UM (Approx) FWL, Sec. 15, T13N, R9E UM (Approx) 7. Well number 30-5 8. Permit number 88-76 9. APl number 50-- 029-21 839 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Length 80' 4910' Casing Conductor Surface Production 8798' 8840'MD feet 6963'TVD feet 8742'MD 6887'TVD Size 16" 9-5/8" 7I' feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 193 sx AS I I 110'MD 1 200 sx AS I I I 4945 ' MD & 370 sx Class G 200 sx Class G 8831'MD ~ue Verticaldepth 110'TVD 4109'TVD 6956'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) None None RECEIVED AUG 3 1 'Alaska 0il & Gas Cons. Commis$io~ .... '-,L ~¢l~orage 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch WELL HISTORY 13. Estimated date for commencing operation September~ 1988 .. . 14. If proposal was verbally approved Name of approver /Dr . /¢ ~,-/_~___ Date approved 15. I hereby certify that the foregoing is t~"u~ and correct to the best of my knowledge Signed ~,~ ~ ~J,,~¢..,4.~ Title Associate Engineer ~ Commission Use Only (SA3/0032) (Dani ) Date Conditions of approval Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Copy . Returne. cl~ Commissioner lapp?val N°' by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate 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 UNIT Auth. or W.O, no. AK2971 ICounty. parish or borough NORTH SLOPE Lease or Unit ADL: 25513 Title DRILL IStaL 30-5 IWell no. API: 50-029-21839 Operator A~CO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 08/06/88 ( TD: 1175' ( 1 SUPV:DL 08/07/88 ( TD: 4233'( 3 SUPV:DL 08/08/88 ( TD: 4963'( SUPV:DL 08/09/88 ( TD: 5260'( SUPV:DL 08/10/88 ( TD: 7608'( 2 SUPV:DL 08/11/88 ( TD: 8084'( SUPV:DL 08/12/88 ( TD: 8840'( 7 suPv:sLc l ARGO W.I. IDate IH°ur II 56'0000 W.O.status if a 08/05/88 1930 HRS ~Prior Complete record for each day reported DOYON 14 ) 75) ) 58) DRILLING 16"@ 110' MW: 9.4 VIS: 63 MOVE RIG FROM 30-1 TO 30-5. ACCEPT RIG @ 1530 HRS, 8/5/88. NU DIVERTER. PU BHA, TEST DIVERTER, FILL HOLE AND SPUD @ 1930 HRS, 8/5/88. DRILL 115'-701'. ORIENT AND KICK-OFF AND NAVIDRILL 701'-1285'. DAILY:S39,222 CUM:$39,222 ETD:S39,222 EFC:$1,345,000 DRILLING 16"@ 110' MW: 9.3 VIS: 54 CONTINUE KICK-OFF 1285'-2043' TOH, PU NEW BIT. DRILL AND SURVEY 2043'-4233' DAILY:S55,713 CUM:$94,935 ETD:S94,935 EFC:$1,345,000 ) PUMPING LEAD CEMENT 9-5/8"@ 4945' MW: 9.5 VIS: 66 30) DRILL AND SURVEY 4233'-4967'. CIRC BOTTOMS UP AND MAKE 40 STAND SHORT TRIP. TIGHT SPOT @ 2080'. WORK THROUGH TIGHT SPOT AND coNTINUE IN HOLE. SIRS WELL CLEAN AND TOH. LD BHA. RU AND RUN 125 JTS 9-5/8", 36#, J-55, BUTT CASING W/SHOE @ 4945'. SIRS AND COND WELL. RU DOWELL, PUMP 80 BBL WATER AND BEGIN PUMPING LEAD CEMENT. DAILY: $135,375 CUM: $230,310 ETD:S230, 310 EFC:$1,345, 0 DRILLING 9-5/8"@ 4945· MW: 8.4 VIS: 29 FINISH CEMENTING SURFACE CASING W/ 1200 SX AS III AND 370 SX 97) CLASS G. DISPLACE W/RIG PUMP. CEMENT TO SURFACE. LOST RETURNS 238 BBLS INTO 376 BBL DISPLACE. DID NOT BUMP FLOATS HELD OK. ClP @ 0800 HRS, 8/8/88. ND DIVERTER, MU'~'~-~.~D~w~ HEAD, NU ROPE AND TEST TO 3000 PSI. CUT DRILL LINE AND PU BHA. TIH. TAG CEMENT @ 4272' DRILL OUT CEMENT TO 4865' AND TEST CASING TO 2000 PSI. DRILL OUT TO 4930' AND TEST TO 2000 PSI, OK. DRILL TO 4973' AND PERFORM LEAK OFF TEST TO 12.5 PPG EMW, OK. DRILL 4973'-5260'. DAILY:S131,212 CUM: $361,522 ETD: $361,522 EFC:$1,345,000 ~8) DRLG 9-5/8"@ 4945' MW: 9.3 VIS: 33 DRLD 8-1/2" HOLE F/ 5260' TO 7608'. DAILY:S42,172 CUM:$403,694 ETD:S403,694 EFC:$1,345,000 ) 76) DRLG 9-5/8"@ 4945' MW:10.0 VIS: 45 DRLD TO 7672'. POOH TO CHANGE BIT. RIH. DRLD TO 7892'. CHECK AND REPAIR WASHOUT IN MUD MANIFOLD. DRLD TO 8084' DAILY:S51,219 CUM:$454,913 ETD:S403,913 EFC:$1,396,000 The above is correct Signature ~!# ~,'~' .~/-'LI./.. [ ~%f.A ~DAILY: $ 5 2, o.9 '9o/ iDate For form preparation/~'l~ci distribution, see Procedures Man~aJ, Section 10 Drillino. P.oes 86 anh'87. ) LOGGING 9-5/8"@ 4945' MW:10.0 VIS: 42 56) WIRELINE SURVEY AND CONTINUE DRILLING 8084'-8840' CIRC BOTTOMS UP AND SHORT TRIP TO SHOE. CIRC AND CONDITION WELL DROP SURVEY, SPOT PILL AND TOH. LD BHA AND RU SCHLUMBERGER ~D BEGIN LOGGING_ CUM:$507 ~ ETD:S507,TM EFC:~ ~ nnn · ' ' ~ ] Title ' ' ~ ~ ~ - ' -- ' - ' - - ~-__~ '~ --~3 ~I ASSOCIATE ENGINEER 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 "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish ARCO Alaska, Inc. J NORTH SLOPE Field ILease or Unit KUPARUK RIVER UNIT I 30-5 Date and deptll Complete record for each day while drilling or workover in progress as of 8:00 a.m. DOYON 14 08/13/88 ( I) TD: 8840' ( 0) SUPV: SLC IState AK CIRC CASING FOR CEMENT 7" @ 8831' MW:10.0 VIS: 41 FINISH LOGGING DIL/SFL/SP 8820'-4439', FDC/CNL 8820'-8050', GR 8820'-1000' RD SOS. MU BIT AND TIH, CIRC AND CONDITION WELL, POH LDDP. RU AND RUN 204 JTS 7", 26#, J-55, BTC CASING. BEGIN CIRC AND COND WELL. DAILY:S84,428 CUM:$592,227 ETD:S592,227 EFC:$1,345,000 JWell no. The abo~ s correct Signature ~ ~ For form prel:~ati(~n- and distribution see ProcedurP.,A Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle ASSOCIATE ENGINEER 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. Accounting cost center code District County or Parish State ARCO Alaska, Inc. NORTH SLOPE AK Field KUPARUK RIVER UNIT 30-5 Auth. or W.O, no. Title AK2971 DRILL API: 50-029-21839 Lease or Unit [Well no. ADL: 25513 Operator ARCO Spudded or W.O. begun SPUD A.R.Co. W.I. 56.0000 Date I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W.O. I 1930 HRS 08/05/88 Date and depth as of 8:00 a.m. Old TD Released rig o8/14/88 ( TD: 8840 PB: 8742 SUPV:SLC Classifications (oil, gas, etc.) Complete record for each day reported DOYON 14 RIG RELEASED 7"@ 8831' MW:10.0 NACL CIRC AND CONDITION WELL. RU DOWELL AND CEMENT W/10 BBL CW100, 30 BBL SPACER 3000 AND 200 SX CLASS G. DISPLACED W/ 336 BBL 10.0 BRINE. BUMPED PLUG W/ 3500 PSI, OK. FLOATS HELD OK. CIP 1010 8/13/88. BLOW BRINE FROM CASING, RAISE STACK, CUT CASING, SET SLIPS, SET PACKOFF, NU TREE AND TEST TO 3000 PSI. FREEZE PROTECT W/ 5 BBL DIESEL. RELEASE RIG 1500 8/13/88. DAILY:S218,325 CUM:$810,552 ETD:S810,552 EFC:$1,345,000 INew TD PB Depth Date Kind of r g Type completion (single, dual, etc.) Producing method Official reservoir name(s) otential test data :~tl no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump SPM X length · Choke size T.P. C.P. Water % GOR Gravity !Allowable Effective date corrected The above is correct For form prepa~'~ion and distribution, see Procedures'Manual, Section 10, Drilling, Pages 86 and 87. IDate ITitle ASSOCIATE ENGINEER ARCO Alaska, Inc. Date: August 19, 1988 Transmittal #: 7269 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. 30-05 2" Dual Induction 8-1 2-88 4939-8820 30-05 5" Dual Induction 8 - 1 2 - 8 8 4 9 3 9 - 8 8 2 0 30-05 2" and 5" Porosity FDC 8 - 1 2 - 8 8 4 9 3 9 - 8 7 9 4 30-05 2" and 5" Raw FDC 8 - 1 2 - 8 8 4 9 3 9 - 8 7 9 4 30-05 Cyberlook 8 - 1 2 - 8 8 -8820 Receipt Acknowledged' DISTRIBUTION: NSK Drilling State of Alaska(+sepia) Franzen D&M L. Johnston(vendor package) ARCO Alaska, Inc. Date: August 19, 1988 Transmittal #: 7270 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. ~ 0 - 0 5 OH LIS Tape and Listing 8 - 1 7 - 8 8 # 7 2 8 8 7 Receipt Acknowledged: DISTRIBUTION: Lynn Goettinger State of Alaska "'MEMORANDuM State of Alaska ALASKA OIL AND GAS CONSERVATION CO~ISSION TO: ~ Lonnie C. Smit~ ~ -~ .... DATE: August 10, 1988 Commissioner -~ ' FILE NO: D. ItPQ-t. 007 THRU: Sr. Petroleum Engineer TELEPHONE NO: SUBJECT: Diverter Test AAI KRU 30-5 Permit No. 88-76 Kuparuk Rv Field FROM: Petroleum Inspector Saturday, August 6, 1988. I left AAI KRU 3C-8, subject of another r'eport; tu go to'~i KRU 30-5 to witness a Diverter Test on Doyan Rig 14. The actual Diverter Test performed exceptionally well, but there was a problem with the 10" Diverter line being installed to divert the gas or fluid in two different directions and downwind. As required in the AOGCC regulations, the Diverter line must be biforcated to allow for diversion downwind of drilling rig and other obstruction that could catch fire. There are two 10" Diverter lines extending from the Diverter to the edge of the mud pit (parallel to each other, about 20 feet apart) -- well past the rig, but not past an obstruction between the rig and pit. There is no way to divert gas or fluids away from the rig in the opposite direction of prevail- ing winds. ~lere the Diverter lines leave the spool, the pipe is angled in several directions -- no 90-degree turns with targets as the AOGCC regulations require, i informed Donnie Lutrick of the infractions. In summary I told Donnie Lutrick, company operator, that the infractions should be straightened out unless he or AAI had a letter from AOGCC to exclude them from the required regulations. Attachment Comment from Mike Minder: After reviewing this report with Commissioner Smith, I called Doyan #14 and informed Steve Cameron that their Diverter would have to be brought in compliance with 20 AAC 25.035 before drilling out of the structural casing on their next well. i told him the Commissioner's waiver that permitted them to use 2 - 10" or greater vent lines was still in effect. However, they were required to comply with the rest of the requirements. Bobby Foster was assigned to verify if modifications were appropriate and the Diverter system was in compliance with AOGCC requirements. See his report for details. 060 STATE OF ALASKA ALAS¥~ OIL & GAS CONSERVATION COmmISSION B,O.P.E. Inspection Report Well ~ O- B Location: Sec. { S .T {8~0R~6 M..,klr¢l Drilling Contractor Lbcation, General .---- Well Sign ~__~__ C, enerhl Hbusekeeptng, ~----Rig. ~ ~..~V:tsu al z---Audio Reserve Pit .l'l?d, Sys t ems Trip Tank Pit Cauge Fi-6w Monitor Gas Detectors Test Pressure 1 BOPE Stack Annular Preventer _.. Pipe Rams .... ~__. Blind Rams ~ _ Choke Line'Valves k M.C.R. Valve ~ Kill Line Valves ~ Check Valve Full Charge Pressure_. ~/~)-O.O---pstg__ __ Pressure After Closure__~O_~ psig Pump incr. clos. pres. 200 psig. min~_sec. Full Charge Pressure Attained:__~min~sec. Controls: Master -~ ~emote ~inds switch cover _ _Kelly and Floor Safety Valves Upper Kelly , ~ .Test Pressure Lower Kelly. .L Test Pressure Ball Type_._ j~ _Test Pressure.. Inside BOP~_~___Test Pressure .... Choke Manlfold__.L__Test Pressure No. Valves _[ ~ No. flanges 3 (o ........... Adjustable Choke~ 1 _ _ , ,drau~call, ~ted choke I.__ ,/ Test Time Test Results: Failures, ~ Repair or Replacement of failed equipmdnt to. be made within days and Inspector/ Commission office notified· Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector July 18, 1988 Telecopy: (907)276-7542 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 30-5 ARCO Alaska, Inc. Permit No. 88-76 Sur. Loc. 811'FNL, t892'FWL, Sec. 22, T13N, R9E, Btmhole Loc. I140'FNL, 1846'FWL, Sec. 15, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indema~ify you from the probable 'need to obtain additional permits required by law from other governmental agencies prior to con~mencing 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. Wh~re 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. /' ,;. ......... ? ? ,..,' .... :.,~ /. . : /:__ .... Chair~n of Alaska Oil and Ga~ Conservation Co~ission BY ORDER OF NE COP~ISSION dlf Enclosure cc: Department of FiSh & Game, Habitat Sectio~ w/o encl. Department of Environmental Conservation w/o eacl. · '"'~ STATE OF ALASKA ~" ALASKA L _ AND GAS CONSERVATION CO..,vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen Service [] Developement Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 59', PAD 24'GL feet Kuparuk River Field Kuparuk River Oil Po 3. Address 6. Property De~signation P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25513YALK 2554 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 811'FNL,1892'FWL,Sec.22,T13N,RgE,UM Kuparuk River Unit Statewide At top of productive interval(8 target) 8. Well nu.mber Number 1320 ' FNL, 1 848 ' FWL,Sec . 1 5,T1 3N,R9E,UM 30-5 #8088-26-27 At total depth ~ ~ 9. ApDroximatespud date Amount 11 40' FNL, 1846' FWL,Sec 15,T13N,R9E,UM 08/02/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in prOperty 15. Proposed depth (MD and TVDI property line DS 30-6! DS 30-4 8718'MD 11 40 ' ~ TD feet 25 ' @ surface feet 2560 6867 ' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 700 feet Maximum hole angle 420 Maximum surface 2432 psig At total depth (TVD) 3227 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 1z-1/~." t¢-5/8" 36.U# J-55 BTC 4950 35 35 4985 4109' 1200 sx AS III & iF-bt<~ :570 sx Class G 8-1/2'~ 7" 26.0# J-55 BTC 8684 34 34 8718 6867' 100 sx 50/50 Poz Lea 4F-ER~ 200 sx Class G tail 19. To be completed for Redrilt, Re-entry, and Deepen Operations.~up ,-u~'°'Pa°-'f'kG 500' above 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' P, ECEiYED Surface Intermediate Production .~I..)N ~- 7 ]988 Liner Perforation depth: measured Ai~tsk~ Oil & Gas 00ns. Commission Anchorage true vertical 20. Attachments Filing fee I~ Property plat ~ BOP Sketch [] Diverter Sketch ~ Drilling program F~ Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby~c, ertify that th~ foregoing is true and correct to the best of my knowledge Signed Title Reoional Drillino Fnoin~.r Date '\ Commission Us; Only~.~ (TEM} P~)3/005 Permit Number APl number Approval date See cover letter ¢8 -7¢ 50-- ¢~-9 '- ¢-I 8-~ 0 7 / 18 / 88 for other requirements Conditions of approval Samples required [] Yes J~ No Mud Icg required L-] Yes [~ No Hydrogen sulfide measures [] Yes ,~ No Directional survey required ~ Yes [] No Required workingj;~'~S~ure fg.r BOP,~i~ E]_2M; I~ 3M; [] 5M; [] 10M; [] 15M Other: ~~,/, ,~//~~//,;t ~/~ . by order of Approved by Commissioner the commission Date Fnrm 1~-401R~v. 12-1-85 Submit i' plicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS ,, 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" 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 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and Cement 7" casings, Pressure test to 3500 psig. 11) DownsqueeZe Arctic pack'and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. DEGASSER MUD CLEANER RECEIVED Alaska Oil & Gas Cons. Commission ' Anc,'~m'ago SHALE ~ STIR STIR SHAKERS MUD CLEANER CENTRIFUGE TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 W~ight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate AP1 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators RECEIVED JUN 2 7 1988 .Alaska Oil & Gas Cons. Commission Anchorage Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LNI~/ih -. -"-.-. : ':-?~i~?~i:K'UPARUK RIVER UNIT 20' DIVERTER SCHEHATIC I~£SCRI DTION 4 ARCO ALA~, INC.. I~GLIESI'~ ~M. ~ THIS DIVERTER SY~I'~ AS A VARIANCE FI~0t'I 20AAC2S.0~) i"IA~I NTENANCE & OPERATION ,, . UPON iNITIAL ~NSTALLATION, CLOSE PREVENTER vERIFY TH.~ t VALVE (3~ PR~Y. CLOSE ANNULAI~, PI~VENT~R AND ~L(31~ AIR TH~OUGI DIVERTER LINES EVERY 12 HOUr. CLOSE ANNULAR PREVENTER IN THE EVENT TH,~ T ,~N iNFLUX OF WE:LLBORE FLUIDS OR GAS IS 0ETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNW~NO DIVERSION. RECE VED JUN 2 7-19o8 Alaska Oil & Gas Cons. Commission · 2 I DO NOT SHUT IN WELL UNDEI:I ANY CIRCUMST~CES 7 6 "i DI~ #1 15~_ 5/8' 5000 I:~! RSRRA B(~ STACK !. 16' - 2000 I~l TRICO ~I'N;~'II~ 2. I1' - ~~I 3. I1' - 4. 1~5/8' - KILL 1~/8" - ~~I ~E ~~I~ ~~ T~, 7. 1~5/8~ - ACCL~ATOR CAPACITY TEST I. (~ECK ~ FILL ~T~ RESERVOIR TO ~R LEVEL W/TH HYDRAM. IC FLUID, 2. ~ THAT ACCLIVLLAT~ ~ IS ~ PSI WITH 1500 PSI D(3/61~TREA~ ~ THE REGU.ATOR. 5. OBSERVE TIbE., TFEN Q..OSE ALL UN/TS SIlVU. TAI~O.Z~Y ~ RECI~ ~ TII~ ~ PRE~ REIi~INING AFTER N_L UNITS ARE C~Q~ED I~TN Q-IARGING I~ (3FF. 4. RECORD 13N I~ REPORT, T~I[ ACC~ABLE LOI~ER LII~T 5 4 i ,,1 RECEIVE 13. ~ ~5I~" i B~m STACK TE;ST I. FILL BCP STACK AN:) C3,O<E MaNIFCLD WITH ~]C DIE~. 2. ~ ~T ~L L~ ~ ~~ [N ~L~ ~LY ~T~E~ ~T TEST ~ IN ~L~ ~TH ~I~ JT ~ ~ IN L~ ~~ 3. ~ ~ ~~ ~ ~ KILL L]~ V~ ~~ TO ~ ST~. ~ O~R 4. ~~ ~ TO ~ ~I ~~DF~ I0~ ~ ~~ TO ~~I ~~DF~ I0 ~ED ~~ TO 0 ~. 5. ~N~ ~~ ~~ KI~ ~ LI~ V~ ~ T~ P]~ ~ ~ ~ V~ ~ KI~ ~ ~ LI~. ~ ~ TO ~I ~ ~ ~ ~ IN ~P 4. 7. ~I~ ~]~L V~ LI~ ~ ~S ~ 4. ~ ~T ~~ TF~ ~ ~ T~T ~ A ~L ~I~ ~ITI~ ~ ~. ~Y 8. ~ T~ PI~ R~ ~ ~ ~~ PI~ ~L ~ ~ ~E. II. ~N ~I~ ~ ~ ~~ ~T ~ ~ ~U]~ ~T ~L V~ [N ~]~]~ ~ITI~ 12. ~ST ~~I~ V~ ~Y, ~Y ~ PI~ ~E~ V~. ~ I~l~ ~ TO~ ~ ~I. ~~ TEST I~~TI~ ~ ~~ ~ER ~ST F~ SI~ ~ ~ TO ~ILL~ ~RV[~. ~E~Y T~~ F~TI~LY ~TE ~ ~LY. Alaska Oil & Gas Cons. Commission 510084001 ARCO ALASKA. Ins. Pad ;~0, ~/el I Not § Proposed Kuparuk Field,. North Slope, Alaska 21 · la B! PERPIAFROST TVD-I?lg TI4D-l??5 DEP-2g5 ,l,a EOC TVD- 198T TI"ID-2113 DEP'4gg 3000. 4000 SO00 6000 ?000 T/ UGNU SNDS TVD-2?04 TPID-308~ DEP-1153 T/ t4 SAK SNDS TVD-3489 THD-4146 DEP-1869' K-12 TVD-3909 TPID=4714 DEP-2253 9 5/8' CSG PT TVD-4109 TPID-4985 DEP-2435 AVERAGE. ANGLE 42 DEG 25 K-5 TVD-5889 THD-?395 OEP-4059 T/ ZONE D TVD-6489 TMD=8207 DEP-4607 T/ ZONE C TVD-SSr~ TMD-83~8 DEP-4682 T/ ZONE A TVD-6618 THD-8382 DEP-4725 TARGET CNTR TVD-6669 THD-8451DEP-4??I B/ KUP SNDS TVD-6719 THD-8518 DEP-4817 TD (LOG PT) TVD-6867 THD-8718 DEP-4952 0 1 000 2000 3000 4000 VERTICAL SECTION RECEIVED JUN 2 7 i988 Al~sk~ .Oil & Gas Cons. Commission I 5000 HOR~-~'.'ONTAL PROJECTION .... ~ SCALE I IN. - 1OOO FEET ARCO ALASKA. Z ne. Pad 30. t/ell No, 5 Propoeed Kuperuk Field. North Slope. Alemke .... $OOQ. 4000 3000 _ 2000 - 1 OOO . O m 1000 _ t/EST-EAST 2000 1000 0 1 000 I TARGET CENTER TVD-6669 THD-8451 DEP-4?7't NORTH 4771 WEST 44 2000 I TD LOCAT ION t 40' FNL, !846' FWL S~C. 1:5. T13N. RgE TARGET LOCATION ~ 1320' F#L. 1848' FWI.. ~'~E:O- !5. TI3N. RgE RECEIVED JUN 2 ? ~8 Alaska Oil & Gas Cons. Commission "Anc~orage SURFACE LOCAT [ ON t 811' FNL. 1892' FI/L SEC. 22, TI3N, RgE N O0 DEG 32 MI N W 4771' (TO TARGET) 1 750 ! 800 1 850 1 900 ! 9~0 2000 ' I \\ ..... Ii I ~' 1 300 : I \ I I ! I I \ J 1500 I / ~ 900 I x ~ ~oo ~ X I ~1100 ~ I ~ / I ~ ~ ~ I / I ~ ~00 ~ ~00 I ~oo /~oo ~"500 / I I 4~00 I 800 -500 ~4100 ~ ~2500 ~oo I ~,oo 900 _ I 950 . _ _ - ~0~ ~s ~ons. Commission I I I I I I 1 750 1 800 1 850 1 900 1 950 2000 600. 65Q ......... I 700 .... /'"'2700 2050 I 600 I I ' I 2050 656 75C 80C 85( 90( 95( 10( CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee ~ 6fZ.q[Sa Loc &kg/ 'a (2 thru 8) (3) Admin~ 6/~9/8~ 9. _ (9 thru 13) 10. (10 and 13) 12. 13. (4) Casg ~~.~. 7-J*-S,Y (14 thru 22) (23 thru 28) (6) OTHER (29 thru '31)' (6) Add: Company/~;O Lease & Well NO. YES NO 1. Is the permit fee attached .......................................... f~ 2. Is well to be located in a defined pool ............................. O~ 3. Is well located proper distance from property line .................. ~ 4. Is well located proper distance from other wells .................... ~_ 5. Is. sufficient undedicated acreage available in this pool ............ ~ 6. Is well to be deviated and is wellbore plat included ................ ~ 7. Is operator the only affected party ................................. ~_ 8. Can permit be approved before fifteen-day wait ...................... 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 ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 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 ............................ 23. 24. 25. 26. 27. 28. For 29. 30. 31 Is a diverter system required ....................................... -~w 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 ~O psig .. ~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: A~/~ Are data presented on potential overpressure zones? ................. // Are seismic analysis data presented on shallow gas zones ............ z// If an offshore loc., are survey results of seabed conditions present~ 32. Additional requirements ............................................. REMARKS tqm Geology_: En~ineerin~: WWB~. LCS ,~:~ BEW /<i rev: 02/17/88 6.0tl ' 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. CGMPfiNY NAME : ARCO ALASKA, INC. WELL ~,t&M? : B ~'-5 ~IELO Nt~ME : ~UPARUK STATE : AL~SK~ ~OROUGH : NORTM SLOPE fi.P~ NUmBeR ' 50.-029-2!83g ~EFERENCE NO : 72887 IS TAPE VmRZFZC~TIO"'.: LISTZNS SERVICE :N ~,v E D~.TE g RIG"' N~. REEL NAME CONTINUAtiON PREVISUS REEL C~ '" ...... T,~PE HE :~,D 5~ ....... SERVICE N~ME : ~DIT DATE : ]8109118 ORIGIN : FL!C TAPE NAME : 72887 CONTINU&TZON PREVIOUS T~PE COMMENT : L%S Y~PE,, ~RCO KUP~RUK B 0-5, ~PI ~50-029-21889 X= ~ :k ~-' FIL~ HEADER FIL~ NA~E : ~DIT ,.001 S~- ,. FL ~_RVIC: : IC VERSION : 001A02 DAT~ : :~B708/18 MAX REC SZZ5 : 10:24 FILE TY~E : LO L A S'T n Z L E JOB NUMBER AT /~KCC: 72887 RUN #1, D~TE LOGGED: LOP: J. KOHRING D~TC COt~PUTED :t. 7-AU~-o8 CASING = 9.62~" D'4939"(LOGGE~) - ~T S~E = T'YP5 FLUID = LSND DENSITY = I0.0 L:~/G ~ : 4.50:9 58 DF VISCOSITY = .42,0 S RMF = 5,39 ;:~ 68 DF PH = 8.5 RMC = 2.70 9 68 DF FLUID LOSS = 8.0 C3 ~N AT ~HT = 2,206 ~ ~46 D~ FIELD REMARKS: 1 I/2" STANDOFF USEC ON OIL: 'M,STR!X OENSITY S~NO (2 65); LUz,D DENSITY G/CB; HOLE CO~R ~::CTInN = C~LIm =R; BMr = OPEN' SP SH!F'TS aT 8650' AND 8ZOO T001. TYPES/NU~'~BEPS: DIS :1t3'1 417 FDC ']3 CNC 1449 SGC 2626 ".,- ...... -,-.,." "";"-,-.,-'r ~'I S~,., DATA. Hhq. ....NOT B~FN, . ..... DEPTH, SH I F"r E D~. - OVERLAYS FIELD PRINTS .~.~ "' "'"" '"'-~- -,- ~,- -,- IS TAPE V~-'RZFZC~T'EGN LISTING CHLUN,3ERGER AL~SK& "O~,lPdTZNG CE~$T=R 1B-~UG-19~8 09:B4 SrHLUV:~_~R~.:;¢. ,,, ~ '9GS,- INCLU3E9 WITH THiS :IL: (EDTT.001) <S~= :ILE ~IT, . . . O0Z ~q 1 . 2" S~MPLS~ FOC/CNL ~ 9UAL !NOUCTIgN SPHER'!Ca~LLY FgCUS~ LOG (.OIL) '~ FIRST TO LflST R~DING: '~820' TO 4939' ~,, ~n~a~TlON,, . DENrtTY~ cn~qPSNS~'TEg~ LO~. (.FDC) ~'.. FIRST TO, L~ST R~D!NG:. 3796' TO 8044' ~ ~0 P~NS~.'TEO NEUTRON LOG (.CNL) -,. ~;~M~ RAY IN C~STNG (.CHL) ~ FIRST TO L~ST ~gING': ~939' TO 925' DA~E: TABLE T~PE : tONS TUN! V ~LU .'DEmi CN FN WN N AT 'l STAT COUN SECT TOWN RANG FL SON ~glN APlN ARCO ~LASK.~, INC. KU~m~RUK 3 U. S..A. 4L&SK~ NORTH SLOPE Z2 ~1t ~ FNL F~ 1.99~ ~ FWL 530800 :50-0 Z9-21839 50-029-21839 COMPANY F I E t g N A M E WELL N~TION ST~,T~ GR gRgV'INCE COUNTY S E C'T I '0 N TOWNSHIP R ~NG E ~!ELD LOC.~TION OPERATOR ~S ;CODE SS'RVZCE ORDER NUMSER API S:~!RZ~L NUMBER API S:RIAL NUM~:R TABLE 'T'¥P~ '" CURV DEPT DEPTH CHaNNeL NAME TENS TSNS~ON SFLU S'¢L UNflVE'RAGES ILM IL- HE'OIUF! R~SIS'TIVIYY ILO iL-DEEP RESISTIVITY SP SPONTANEOUS TeNS T~SION DPHI OENSI'TY POROSITY IS TAPE VER~FrCaT!ON LISTZ I~.~ CHLUM3ERGSR ALASK~ CD~'~pUTZNg CENTL,-TR P A,,g E ' C, RHO RHO~, CILI GR TENS NPMI TNR~ R T NR RCFT RCNT CFTC CNTC CALl GR TENS GR DEFI DELT~ ~ :.JL K OE~SZTY C AL!P ER TENSION N=_UTRDN PqRDS!TY CALI~RATED THERMAL NEUTRON R~.TIO R&W THErMaL N~U~R3~ ,. q~TIn RCFT RCNT CFTC CNTC C ,~L !P T ~ N ~ I g N G ~ R ~Y TYPE REPR CODE VALUE: 1 66 0 2 66 4 66 1 8 68 0.5 1,1 66 !.~ 66 O 14 55 =T 1'5 66 16 66 0 66 ~- SET TYPE- C.HAN ,,~'~. NAME SE~V UNIT SERVIC~ AP1 API APl ~P'Z FILE NUMB NUMB SIZE REPR ID O~gER ~ LOG TYPi~ CLASS MOO NUmB S'AMP EL~M :CODE DEPT FT 530~00 TENS DIL L~ 530800 SFLU OIL OHMM 530800 ILM DIL OHMM !530800 ILO git OHM~ 530800 SP DIL MV 530300 GR OIL G.~P! ~30800 PROCESS (HEX) 1 1 1 4 68 1 I 1 .~ 6'3 1 1 ! 4 68 1 1 I 4 63 I I 1 4 6 8 0000000000 O000OO0000 0000000000 0000000000 OOOO0000OO O000OO0000 OOOO0000OO IS TA°E VERZFIC,~T[O'~J LISTING CHLUM55RGER AL$SK~ COMPLjTING CE',JT=R 1,8-'~U[S-19~,8 09: .~4 N~,ME SF~V UNIT SE~V~C~ ~PI I~ SPOE~ ~ LOG RHE'~ :DC ~/C~ CALI FDC ~N GR ~DC G~P~ TENS CNL L% S30800 N~HZ CNL PU 5]0800 TNRA CNL RTN~ CNL ~]0800 ECFT SNL CPS RCNZ CNL C~S CFTC CNL CPS CNTC CNL CPS '$30808 CALI CNL IN 5308n0 G~ CNL G~PI 530800 TENS CHL L~ 530800 Gq CHL G~Pi TYD~ CLASS MOD ~!LE NU~5 NUMB SIZE CODE 1 1 ! ~ 6 8 1 ! 1 4 68 ! 1 1 4 6~ 1 1 I 4 68 1 t 1 4 63 1 1 1 z~ 68 1 I 1 4 68 1 1 1. 4 68 1 ! 1 ~ 68 1 I 1 4 68 1 1 1 4 68 ! 1 1 a 68 1 1 1 ~i 68 1 1 1 ~+ 6~ ! I I ,4 69 I I 1 4 68 1 I 1 4 6~ P~OCESS (HEX) 3000 OOOO 0000 0000 gO00 OOCO 0000 OOOO 0000 0000 OOOO 0000 0000 0000 0000 OOOO 0000 OOOO 3OOOOO 000000 000090 OOOO00 OOOOO0 000000 009000 000000 O000OO 000000 000090 O000OO 000000 000000 009000 OOOOOO 90OOOO 000000 DEPT. B853.009 TENS.OiL ILD.DIL 2.101 SP.DIL DPH'I.FD~C 7.392 D~HO.FDC GR.~DC 105.063 T~NS.CN[ RTNR.CNL 3.339 RCFToCNL CNTC.CNL 20~4.738 C~LI.CNL GR.CHL '-9~9.230 DEPT. ~800.000 TENS.OIL ILO.OIL 2.552 SP.OIL DPHI.FDC ]2.103 DRHO.~D~ GR.~DC 190.688 T~NS.CNL RTNR.CNL 3.448 RCFT.CNL CNTC.CNL 2055.9:06 CALI.CNL GR.CHL -999.250 DEPT. 8700.000 TENS.OIL ILO. O'IL 2.6:52 S ~. OIL DPHI. FDr,,., !Z. 991 DRHO,. . :FD~,r' GR.~ O,. 39 .~5 TENS.CNL RTN~.CNL 3-093 RCFT.CNL CNTC.CNL 2052.5'76 C,~t'I. CNL GR. CHL -999.2'S0 DEPT. 8600.000 TENS.OIL 'rLg. OIL 2 9~1 .~ n ....... :.uIL DPHI.FDC 14.510 DRHO.FDC G~.FDC 95.125 TEN$.CNL 3964.000 -2.674 0.t'18 :3954.000 533.I20 8.492 6504.0:00 -12.750 0.173 6504.000 534.351 8.500 6408.000 0.005 6408.000 589.330 8.578 6260.000 -19.250 0.011, 5250.000 S~LU.OIL GR.DIL RHOS.FDC NPHI .CNL RCNT.CNL G~q .CNL SFLU.DIL GR .OIL RHO~.FDC N~HT CNL , ,,~ . RCNT .CNL GR .CNL SFLU.DIL G!R.DIL RHO~.~OC NPHZ.CNL R,CNT.CNL gP.CNL S~LU.DIL GR.OIL RHO3.FDC N~HI.CNL 3.448 105.063 2.528 :38.322 1973.360 1:05.063 3.2~5 100.688 2.615 42.692 ]1901.792 100.688 2-745 89.875 2.436 35.889 1934.505 89.8?5 3.424 95.125 2.411 43.902 ILM.DIL T~NS.FDC C~LI.FDC TNR~.CNL CFTC.CNL 'TENS.CHL 'IL~. OIL TENS.FDC C~LI. FDC TNR~.CNL C roTC. CNL TENS.CHL ILM.OIL :TENS. FDC CALI .FOC 'TNR,~.. C N L CFTC.CNL TENS. CHL ILM.OIL TENS.FDC CALI.FDC TNRA.CNL 2.778 3964.000 8.492 3.233 645.779 -999.250 2.744 6504.000 8.500 3.472 622.B95 -999.250 2.741 6408.000 8,578 3.106 685. 598 -999.250 3. 059 6260.000 8.445 3. 533 IS TAPE V~R'T_FZC~T[ON LI.STZ,Ni3 CHLUMSERGSR ~,L~SK,q SS~,PUTiMG CENTF_-P, RTNR.CNL, 3. 531 RrFT,~ .r~,'L., ~, CNTC.CNL 19/+9.001 C~LI.CNL GiR. CHL -99 g. Z 50 DEPT. 5500.000 T~NS.3ZL ILD.OIL 12. ~8 SP.DIL DPHZ.=DC ~2,352 DRHO.~DC G2.mDC 44.938 TSNS.CNL RTN2.CNL 2.8!~ RCFT.CNL CNTC.CNL 2651.530 CaLI.CNL GR.CHL DEPT. ~400.OOO TENS.OIL ILO.DIL 3.35,0 So.~IL D.°HI.FDC 10.730 DoHO.FDC GR FDr a3 5~ ~:ENS rNL RTNR.~NL 2.7~ FCFT.CNL CNTC.CNL 2~26.276 C~LI.CNL G~.CHL -S9~.250 DSPT. 3390.000 TSNS.OTL iLO. D~L 3-4't9 So. 9ZL DPHI.~DC 9.1~9 D~HO. FDC GR.FDC 1!4.625 TENS.CNL RTNR.CNL 2.971 RCFT.CNL CNTC.CNL 2151.175 C,qL~.CNL GR.CHL -999. grOT. 3200.000 T~NS.gIL ILO.DIL 1.699 So. OIL DPHZ. FDC 6, ~'36 D~HO, ,:DC GR. FDC 1, !.1.0 .63 T ~N S. CNL RTNR.CNL 4,, 4-~ ~CFt. CNL ,r ML CNT~ CNL 1825.891 C,~L T .~ GR. CHL -9~9.250 DEFT. ~!00.000 'ILO. OIL 1. 468 S?. OIL DPHI.FDC 13.6'.53 D~HO-r-DC GR :Dr 110 ~!3 TENS CNL RTN'~.CNL 4.000 RCFT.CNL CNTC.CNL 17Z5, 5?4 CALI,CNL G'R.CHL -999.250 OE~T, 8000,000 T~NS.OIL ILD.D]L 1.723 SO.OIL DP'HI ~OC -999 2s0 DRHn ~DC G~.FDC -999.2.50 TENS.CNL RTNR.CNL -9~.9.250 ~CFT.CNL CNTC.CNL -999.250 CALi.CNL GR.CHL -999.250 I~-,~UG-t9~8 09:34 50g.8~,2 RCNT.CNL 8 - 4~5 GR. CNL 5850.000 SFLU.PIL -8.000 GR.DIL 0.006 RHO~.FDC 5850.000 N~HI.CNL 53. 512 RCNT.CNL e.2~2 GR.CNL 62~8.000 SFLU. DIL 26.494 GR..OIL 0.000 RHO~. F.r)C 5238.000 NPHI.CNL 773.970 RCNT.CNL ~,B44 GR.CNL 5958. OOO SFLU.OIL I1.4'92 GR.3IL O. 0¢0 RHOB. ~DC ~968.000 NPHI.CNL 6'~1. 856 R ~NT.. CNL 9,3'52 GR. CNL 596B.000 S~LU.OIL 12.367 G~.OIL -0.007 RHOB.~OC 5968.000 NPHi-CNL 4~6.267 RCNT.CNL 8.438 GR.CNL ~772.000 S=LU.OIL -25,266 GR.OIL 0.0~1 RHOB.FCC 5772, .OOO NPHI.rNL~. 4 ~9.8'99 ~CN~T.CNL 8,.6~0 GR.CNL 5908.000 SFLU.DIL -32.375 GR.OIL -999,250 RHOB.FDC ,-999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 GR.CNL 1867 · 704 95 .ITM I~.445 ~4 2.231 29.594 2643.144 44.93~ 3.154 93.553 2.473 31.559 2221.945 93.563 3.243 114.625 2.499 32.656 2072.890 114,625 1,628 111,.063 2.537 52.769 1613.197 111,063 ! .733 110.313 2.4:25 ,~5.909 1615.041 1 :! 0.313 1.787 111.688 -999.250 -999.250 -999,250 -999.250 CFTC.CNL TENS.CHL .IL~.OiL TSNS.~DC CAL[.~DC TNRA.CNL CFTC.CNL TENS.CHL ILM.DIL T~NS.FDC C~LI.FDC TNRA.CNL CFTC.CNL T~NS.CHL ILM.OIL TENS.~DC C~LI.~DC TNRt.CNL CFTC.CNL TENS.CHL IL~q.DIL T'.,T- N S. ~OC CALI. FDC TNR:~t. CNL CFTC .CNL ILM.OIL TENS .FDC CAL!.FDC 'TNRA. CNL CFTC.CNL TENS .CHL ILM.OIL T~NS.FDC C,a, LI. FDC TNRA .CNL CFTC .CNL 'TENS.CHL PAGE: 568.152 -9~9.250 11.593 8.2A2 2.69! 973.751 -999.250 3.455 5288.000 8.844 2.8'72 859.741 -999.230 3.546 5968.000 9.352 2.986 750.230 -999.250 1.777 5968.000 8.438 4.017 486.460 -999.250 1.519 5772.000 8.68O 3.652 478.!38 -999.250 1.738 -999.250 -999.250 -999.250 -999.250 -999.250 IS TAPE V'.,--.RZ:ZC~TIO~ LiSTZNS CHLUN~EqGER ALASK~ CO~P:J? 09:34 D{PT, 7990,000 T-S~S, 9IL ILD, DIL 3. 119 So.OIL DPHI.=Dr -c79 ~';O ~°Hn CD~' G~, FDC -999. RTNR.CNL -9~9.Z~0 RC~T,CMC CNTC. CNL ,, ;.2:0,., r~LZ~ .CML G2.CHL -999.2~0 -999.2'50 -99~.250 -939.250 -979.250 5944. OOO -31 .625 -9~9.2$0 -999.250 -999.250 -999.250 S:LU.DIL N.OH!,CNL RCNT ,CNL Gq,CNL SFLU.OIL GR .DIL RHOB.FOC NPHI.CNL RCNT.CNL GR.CNL DEPT. 7700.000 T,~,~S. SIt 5958. O..qO SFLU.OIL !LO. DIL 1.8:52 SP. DIL -]3. 875 GR. OIL DPHI.FDC -999,250 DqHO.,:DC -999.250 RHO3.~DC GR.FDC -999.2~0 TENS.CNL -999.250 NPHI.CNL RTNR.CNL -9~9.250 RCFT.CNL -9'~9.250 RCNT.CNL CNTC.CNL -999.250 CELI.CNL -999.2'50 GR.CNL GR. CHL -999. 250 DEPT. 7600.000 T~NS.DIL ILD.DIL 2.07~ SP.DiL DPHI.~DC -999.250 DRHg. ::DC GR.FOC -999,250 T~NS.CNL RTNR.CNL -999.2.50 RC~T.CNL CNTC.CNL -939.250 CALI.CNL GR.CHL -999.2~0 5804.000 -30.875 -999.250 -999.250 -999.250 -999,250 SFLU .OIL GR .DIL RHO~,.FDC NPHI.CNt. RCN'T .CNL GR.CNL DEPT, 7500.000 T{:NS, 9IL 5532,000 S:=L~J,DIL ILD. DIL 1.7 83 S ~. OIL - 29.2:50 OR.DtL DPH'I.FOC -9?9.250 DRHg.~C -999.250 RHO'~. ~DC GR.FOC -e99 2:0 T':NS CNL -999 750 NPH~ CNL . . . ,,' i:,. I ~ RTNR,CNL -~99,2¢0 PCFT,CN[ -999,250 RCNT,CNL CNTC,CNL -999.250 CALI,CNt -999,250 5R,CNL GR.CHL -999.250 DEPT. :7400.000 TENS.DIL 5424.000 SFLU.OIL ILO. OIL 2. 8173 S P. OIL -45. 500 Ge. OIL DPHl.?DC -999.250 DRHO.:mDC -999.250 RHOB.FDC GR.~DC -999.250 TENS.CNL -999.250 NPHi.CNL R'TNR.CNL -999.2~50 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 C~[Z.CNE -999.250 GR.CNt GR. CHt -999.2 50 DEPT. 7300.000 TSNS.OIL 5468.000 SFLU.OIL ILO.OIL 3.43~ SP.DIL -39. 125 GR.OIL DPHI.iFDC -999.250 0!~H'0. ~DC -9:99.250 RHD~.:~OC GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL RTN~.CNL -999.250 PC'FT. CNL -999.250 RCNT.CNL CNTC.CNL -999:.250 CA[.~.CNL -999.250 ,G'~ ,. C NL GR.CHL -999.250 2.681 184.375 -999.250 -999.250 -999.25C. -9~9.230 1.997 214.250 -999.250 -999.250 -999.2~0 -999.250 1.685 91.875 -999.250 -999.250 -999.250 -999.250 1.914 85. 563 -999.250 -999.250 -999.250 -999.250 ] .874 74.375 -999.250 -999.250 -999.250 ' 999 · Z 50 2.814 113.375 -999.250 -999.250 -999.250 -999.250 3.791 122.750 -999.250 -999,250 -999.250 -999,250 ILM.OIL TeNS. :9r C&LI.~DC TNRA.CNC CFTC.CNL TENS.CHL IL~. OIL TSNS.FDC TNRA.CNL C~:TC.CNL T..NS. CHL ILM.DIL TENS.,:DC C .&LI. FDC T M R ,%. C N t C~'TC.CNL TENS.CHL ILM.OIL TENS.FDC C&L'I.~DC TNRA.CNL CFTC.CNL T:NS.rHL ILM.DIL TENS .}:DC CALI. FOC T'NR.~.CNL CFTC.CNL TS. NS . CHL ILM.DIL T~NS.FDC CALI.'~=DC TNRA .CNL CFTC.CNL TEN S. SH L It.~-!. DI L TENS .FDC C~aLi. FOC T~R A, CNL C~. TC.r~.NL 'T~NS ,CHL 3.148 -999.250 -999.250 -999.250 -999.250 -999.250 !.828 -9~9.250 -999.250 -999.250 -999.250 -9~9.2~0 1.864 -999.250 -999.250 -999.2~0 -999.250 -999.250 2.052 -999.250 -999.250 -999.250 -999.290 -999.250 1.836 -999.250 -999.250 -999.250 -9'99.250 -99'9.250 2.885 -999.250 -999.250 -999.250 -999.250 -999.250 3.~36 -9'99.250 -999.250 -999.250 -999.250 -999.250 IS T&PE V:ERIFZCt~TZO:',I LI';TZNG 1~-aU5-I988 09: 34, DEPT. 7Z~g,OgO T:t<S.DIL COHT.CO~ -q~q.250 DRHO 'cDr GR.CDC -~9.,. .2=0 T~NS.'rNL~, RTNR.CNL -9~9.250 RCFT.CNL GR.CHL -9~9.25 O DcPT 7'~ .O 0 ~'~0 ~NS IL~ OiL 2.79:~ ~ 9I~ DPHZ.FDC -9']9.2S0 DRHO.FDC GR.FDS -9~9, .~'=0., TENS.CNL RTN~.CNL -999. 250 RCFT.CNL CHTC.CNL -999.250 CALZ.CNL G~.CHL DEPT. 7000.000 TENS.OIL ILO. 9IL Z. 8 ~ 2 S,~. OIL DOHI.=C'C -999,2~0 ORHO.'~OC GR.FDC -9~9.250 TENS.CNL . , :0 PCFT.C~:L RTNR CNL -9'~9.2> CNTC.CNL -999.250 C~LI.CN[ G R. CHL -999.2 S 0 DSFT. 5900,000 TSNS.DIL !LO. OIL 2.622 SP. DPHI :FOC -999 2~0 GR.FOC '-9~9.250 T:~NS.CNL RTNR.CNL -999.2:50 RCFT.CNL CNTC,~CNL -9'~9,2q0..,, . .... C,,¢L~,.. CNL GR.CHL -999,250 DEPT. 5800.000 TENS.OIL ILO. OIL 2-~ 29 S~. OIL D~:~H I. FDC '-999..2 SO DRHO. FDC GR.:DC ~99.250 R~NR.CNL., .-9'9~,2:~0 CNTC.CNL -999.250 C~LZ,CN~ GR.CHL -999 DEPT. 5700. 000 ILS O!t 2 ,5~-~ S~ ~It O P H 'I. F D C '- 999.2 :~',~: 0 D "'2 H g. = O C GR.=DC -999,250 T.F, NS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.2S0 CALZ.CNL GR.CHL -999.2 Di~P'T. 6600,000 T~ZNS.OIL ILO. DIL 2. 809 SP. OIL DPHI.FOC -999.250 GR.~DC -9'99,250 TiENS.CNL RTNR.CNL -999,250 RCFT.CNL CNTC.CNL -999,250 C~LI,CNL q~60.OOO S:LU.OIL 2.593 -33.6Z5 GR.OIL 110.439 -99~.250 RHO~.FDC -999.250 -999.2%0 NPHZ.CNL -999.250 -999.2%0 RCNT.CN[ -999.250 -999,250 GR.CNL -999.250 $308.000 SFLU.OIL 2.894 -30.875 GR.DIL 105.125 -999.250 ~HOB.=OC -999,250 -999,2~0 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 ~R.CNL -999.250 5192.000 SFLU.DIL 3.047 -29.016 G~.DIL 102.500 -999.250 ~HOB.~OC -999.250 -999,250 NOHI.CNL -999,250 -999.250 RCNT.CNL -999.250 -999.250 GR.CNL -999.250 F032.000 SFLU.OIL 2.691 -30.250 Gq. OIL !02.125 -999.250 RHOB.~DC -999,250 -999,250 NPHI.CNL -999,250 -999,250 RCNT,CNt -9'99,2!50 -999.Z~0 GR.CNL -999.250 ~1 72.000 S:LU. OIL 2.973 -'30.1,25 GR. OIL 81. 125 -999.250 RHOS,FDC -999,250 -999,250 NPHI .CNL -999,2:50 -999.250 RCN'T.CNL -999. 250 -9'99.250 G~.CNL -999. 250 49~0.000 SFLU.OIL 2,593 -:36. O00 GR,D IL '89,813 -999,250 RHO~3. FOG -999,250 -999.,250 NPMI,CNt -999,250 -999.250 RCNT.CNL -999.250 -999,250 GR.CNL -999,250 58fi0.000 SFLU.OIL 2.901 -~1.000 GR.OIL 94.313 -999.250 RHOA.~DC -999.2!50 -999.250 NPHI.CNL -999.250 -9~9.250 RCNT.CNL -999.250 -999.2~0 GR.CNL -999,250 fL~ ~iL T~NS.FDC CALZ. :DC TNPA.CNL C FTC. CNL T~NS.CHL ILl..OIL T~NS.,~DC C ,~t !. ~O C TNR~ ..~, NL CFTC .CNL T.ENS. CHL ItM.OIt TENS.~DC C~LI.FDC TNRA.CNL CFTC.CNL T~NS.CHL !tM.~3It T E N S. !F D" CALI. FDC TNRA. CNL CFTC.CNL TENS. CHL !t~.glt T :NS FDC C ~ L !. FO C TNR.~.CNL C:T,q ~NL TENS.CHL ZLM.OIL TENS.~DC CALI.FDC TNRA.CNL CFTC.CNL T~NS.CHL ILM. OIL TENS.~DC CatI, FOC TNR4.CNL CFTC .CNL TENS ,CML 2.606 -999.250 -999.250 -999.250 -999.290 -999.250 2.817 -999.250 -999.250 -999.250 -999.250 -999.250 2.886 -999.250 -999.250 -999.250 -999.250 -999.250 2.642 .-999.250 -999.250 -999.250 -999.250 -999. 250 2.609 -999.250 -9'99.250 -999.2~0 -999.250 -999.250 2.65.4 -999.250 -999.250 -999.250 -999.250 -999.250 2.828 -999,250 -999,250 -999.250 --999.250 -999,250 IS TAPE VERIFICATION LIS?INS CHLUM.3E~GER ~L~SK~ ~C,~4PUTIN,S OR. CHL -999.7_ 50 IR-~UG-19B8 09:34 D~-PT. :6500.000 TYNS.DIL 47!$.000 S,:LU.DIL 3.4~0 IL.q. DIL 2.79~ ILS.OIL 2..BS& S~.~IL -42.250 Go. OIL BB.31~ T~NS.FDC -999.250 D~Hi.=DC -999.250 ~RHS.:~C -9'~9.2$0 RHO?,.FDC -9~9.250 C~L!.~DC -999.250 GR.:DC -999.250 T~NS.C~L -g~9.250 NOHI.CNL -999.250 TNR~.CNL -999.250 RTNR.CNL -999.25G RCFT.CNL -9~9.2~0 RCNT.CNL -999.2~0 C:TC.CNL -999.250 CNTC.CN[ -999.250 C~LI.CNL -999.250 G~.CNL -999.250 TENS.ertL GR.CHL -999. 250 DE~T. 34~0.000 TENS.OIL 4624.000 SFLU.D!L 2.877 ILM.SIL 2.876 ILO.OIL 2.8~9 SO.OIL -~9.500 GR.-OIL 101.563 TENS.FDC -999.250 D~HI FO" . . ',~ -9~9.~50 ORHO.=Br -999.250 RHO~.=OC -999.250 C~L!.=Dr -999-2~0 GR.F~C -999.250 YE~S.CNL -999.250 NPH!.CNL -999.250 TNRa.CNL -9~9.250 RTNR.CNL -999.250 RCFT.CNL -~g9.250 RCNT.CNL -999.250 C~TC.CNL -9~9.250 CNTC.CNL -999-2~0 C~LI.CNL -999.2~0 G2.CNL -999.250 TENS.CHL G~.. CML -999.250 DEP'T. ,$3 .gO.O00 TENS.OIL 46¢8.000 S~LU.'gIL 2.427 IL~,.'DiL 2.223 ILO.OIL 2.161 SP.OIL -36.500 Gq.OIL 105.250 T'~NS.FDC -999.250 DPH'Z.FDC -999.250 DRHO.~DC -999.250 RHDB.FOC -999.250 CAL!.=C'C -9~')9. 250 GRoFDC -9':~g. 2 50 TEMS.CNL -999.250 NgHI.CNL -$99.2~0 TNRA.CNL '-999.250 RTNR.'CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 C~L!.CNL -999.250 G~.CNL -999.250 TENS.CHL -999.250 GR.CHL -999.250 DEPT. 6200.000 TENS.OIL ~608.000 SFLU.OIL 2.~:Z9 ILM.DIL 2.853 !LO.OIL 2.878 SP.OIL -42.250 G~.DiL '99.375 TENS.FOC -999.250 DPHI.FDC -999.250 DRHO.FDC -999.250 RHO~.FDC -999.250 C~[i.FOC -9gg.zsO GR.FOC -999.250 T~NS.CNL -999.250 NPHI.CNL -999.250 TNR~.CNL -999.250 RTNR.CNL -999.2~0 RCFT.,CML -999.250 RCNT.CNL --999.250 .CFTC.CNL -999.250 CNTC.CNL -999.250 CAL!.CNL -999.250 GR.CNL -999.250 T~NS.CH[ -999.250 GR.CHL DEPT. 61gO.OOO Ti~NS.DIL 45~4.000 SFLU.OIL 2.342 ILM.$IL 2.503 ILD.O!h 2.508 SO.OIL -31.61~5 Gq.OIL ~¢.2S0 TYNS.:DC -999.250 DOHI..~DC -999.250 DPHO.FDC -999.250 RHO~.FDC '-999.2~0 C~LI.FDC -999.250 GR.FDC -999.250 TENS.CN[ -999.250 NPHI.CNL -999.Z50 TNR~.CNL -999.250 R'TNR.CNL -999.Z50 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 C,~L, I.. CN[ -999.ZS0 G~.CNL -999.2;50 'TEN'S.CML -999.250 GP.CHL -9'99. 250 DEP'T. 6000.000 TENS.OIL ~512.000 SFLU.OIL 3.019 IL~.OZL 3.062 ILD.OIL 3.108 So. OIL -37.000 Gq.OIL 97.625 TENS.FOC -999.250 DPHI. . ~0r~ ,,. -9'99 . .... ~qO D~Hm~ . FDC. -99e., . 2.,,0= RHO~,.. "~DC - o99.250., CALI.FOC -999.250 GR.FDC -999.250 TENS.CNL --9'99.250 NPHI.CNL -999.250 TNRA.CNL -999.2S0 RTNR.CNL -999.2~0 RCFT.CNL -999.2~0 RCNT.CNL -999.250 C~TC.CN~ -999.250 CNTC.CNL -999.2~0 C~LI.CNL -999.250 G~.CNL -999.250 T~NS.CHL -999.250 G~.CHL -999.250 DEPT. 5900.000 T~NS.DIL 44~4.000 SFLU.OIt 2.301 ILM.$IL 2.871 ILO.OIL 2.875 Se. OIL -30.000 Gq. OIL 79.553 T~NS.~DC -999.250 DPHI.FDC ,-999.250 DRHO.FDC -999.250 RHO~.FDC -999.250 CALl. FOG -999.250 GR.~DC -999.2~50 'T:ENS.CNL -999.250 NPHZ.CNL -999.250 TN~A.CNL -999.2~0 RTNR.CNL -999.250 ~CFT.CNL -999.2~0 RCNT.CNL -999.2:50 C~TC.CNL '-999.250 C E N T C ~ 1 B- ,~ U g- t 9 :B 8 09: 34, CNTC.C. NL -gqg.2~mg Gq.CHL -999.250 DEPT. 5700.000 ILO.OIL 3.1'92 DPHI. FDC -9g9.2c0.., GR.FDC -999.250 RTNR r~'~ -99~ 2~0 CNTC CNL -~39 2:0 GR. CHL -999.2'S0 ruEpT. 5600.000 ILD.OIL 3.074 DPHI.FDC -999.250 GR.~DC -999.2'50 RTNR.CNL -999.250 CNTC.CNL GR.CHL -999.250 D~PT. ~500.000 ILO. OIL 2.5 ~0 DPHI. FDC -999.2 50 GR.FDC -9'99.250 RTNR .CNL -999. 250 CNTC. CNL -9'99.250 G~<.. CHL -q ).,. 250 DEPT. ,ILO .OIL 2. 916 DPHI.FD'~,~ -999. 250 GR.FDC -999.250 RTNR. CNL -999.2=0 CNTC.CNL -999. 250 GR.CHL -999. DEPT. 5390.000 ILD. glL 5. 703 DPHI. FDC -999. 250 GR. FDC -999,250 RTNR. CNL -999.250 CNTC. CNL -999.2:50 GR.CHL :-999.250 DEPT. 5200.000 ILD.DIL 3.108 DPHI.mOC -999.250 GR.=DC -999.250 C ~L I. CNL T-:NS.OIL S o. nP~.9 T~NS.CNL R C F T. S N L CaLT.CNL TENS.OIL Sm.OIL OP, HO.FDC TEN S. CNL RCFT.CNL C ~L !. CNL T~NS.OIL Sm. OIL D~HO.FOC T '5 N S. C N L PCFT.CNL CALI.CNL TENS S P. T E N S. C NL RCFT.CNL C AL I. CNL Sp .OIL T:ENS.CNL RCFT.CNL C~LZ.CNL T Y N S. O I L SP,OIL n R H O. F O" TENS. CNL RCFT. CNL C ~L Z. CNL TENS·OIL SP.OIL ORHg.=DC T~NS.CNL -999.250 -33.250 -999.2S0 -999.250 -999.250 -999.250 ~2~8.000 -32.2~0 -999.250 -999.250 -999.250 -999.250 -34.875 -999.250 -999.250 -999.250 -999.2 50 4140.000 -25.875 -999·250 -999.250 -99~.250 -999.2q0 39 94. 000 -27.500 -999.250 -999·250 -999.2 50 -999.2~0 -18.266 999.2~0 -999·250 -999.2S0 -999.250 3874·000 -27.750 -9~9,.250 -999.2150 Gq rNL · '., S=LU.OIL G~.O!L N~HI.CNL RCNT.CNL GR.CNL SFLU.OIL GR.OIL NPHI.CNL RCNT.CNL GR.CNL SFLU.glL GR.glL RHOB.!~DC NPHI.CNL RCNT.CNL GR.CNL S~LU.DIL GR.OIL RHOB.~DC NPHI.CNL RCNT.CNL G~.CNL SFLU.OIL GR.OIE RHOS,FOC NPHI.CNL RCN'T.CNL GR.CNL S~LU,DIL GR.OIL RHO8.~OC NPH!.CNL RCNT.CNL G~.CNL SFLU.OIL GR.DIL RHOB.~DC NPHI.CNL -9 99.250 2.6B2 105.313 -999.250 -999.250 -999.250 -999.250 81.438 -999.250 -999.250 -999.250 -999.250 3.019 93.000 -9;99.250 -999.250 -999.250 -999.250 2.470 B 9.3 't 3 -999. 250 -999.250 -999.250 -999.250 2.696 87.750 -999.250 -999.2S0 -999.250 -999.250 !~.118 50.531 -999.25,0 -'999.Z50 -999.250 -999.250 2.857 ?I .500 -9'99. 250 -999. 250 TSarS CHL !t~.O!t TeNS.FDC C~L,I. ~OC TNR~.CNL CFTC.CNL TENS. CHL It~. D!L TENS.~DC C~LI. FOC TNR~.CNL CSTC.CNL TENS .CHL tLM.OIL TENS. FDC CALl .=DC TNRA. CNL CFTC.CNL TENS. CHI ILM. DIL TSNS. FDC C&L!.FDC TNR,4. CNL C ~:TC. CNL T~NS.CHL ItM. D! t TENS .FDC C~t!. FDC TNRA.CNL CFTC.CNL T ~f N S.~.. :~' H t ILM.O!L TENS.FDC C4LI.FOC TNR~.CNL CFTr CNL TENS.CHL 'ILM.OIL T~NS. =g~ C~LZ.~DC TNR~.CNL -999.250 2.675 -999.250 -999.250 -999.250 -999.250 -999.250 3.120 -999.250 -999.250 -999.250 -999.250 -999.250 3.014 -999.250 -999.290 -999.250 -999.250 -999.250 2.434 -999.2S0 --999.250 -999.250 -999.250 -999.250 2.816 -999.250 -999.250 -999.250 -999.250 -999.250 6.710 -999.250 -'999.250 -999.250 -999.2:50 -9'99.250 2.973 -999.250 -999.250 -999.250 IS TA°E VERIm'TC~T~rn'i 1 IST'rN<~ CHLUM~E~G~R O, L /': S 'K a, C~.v, PUT!NG CENTER 1B-&UG-t988 09:34 ~GE: 10 RTNR.CNL -999.250 R. CFT.CNL -9q~.250 RCNT.CNL -9'99.250 CFTC.CNL -999.250 CNTC.CNL -999.2~0 C~LI.CNL -g'og.2~O G~.CNL -999.2~.0 T~NS.CHL -999.250 GR.CHL -999.250 D~PT~_ . 5100 , 000 T=NS_ . nIL.~ !740, . OOO S=LU . OIL ,_~. 477 .~_~.~ ~ OIL 2 . 566 iLO.OIL 2,757 SP.D!L -22.5!6 GR.DiL ~9.438 TENS.~DC -999.250 D~HI.~DC -a,n~....2=0~.., D~HD.=DC. -999.250 RHO3.=OC -9~9. .Z=O. CALi.~DC -999.2'~0 GR.FD~;~ -999.2'5n. ,. T:NS~_ .rNL~, -99~, .2~0 Nm~I: .CNL -999.250 TNP~&.. .CNL -999. RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -939.250 C~TC.CNL CNTC.CNL -999.250 CaLI.CNL -999.250 G~.CNL -999.250 TENS.CHL -999.250 G~.CHL -9~9.250 DEPT. 5000.000 TENS.OIL 3694.000 S=LU.DIL 2.960 !L~4. OIL 2.987 ILO.OIL 3,122 SP.DIL -B1.265 GR.OIL 87.563 TENS.FDC -999.250 DPHZ..=OC -999.250 DRHO.~DC -99'9. 250 RHOSocDC -999.250 C~LI.~DC -9~9.250 G~. .~:~r_,., _o,~c~_,=.250 T=NS.CNL -9om~,,..2S0 NmHI, , .CNL -999.250 TNR,~. .CNL -999.250 RTNR.CNL -999.250 RC~T.CNL -999.2~0 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -9~.250 C~,LI.CNL -9.99.250 GR.CNL -999.250 T:_NS.CHL 3460.000 GR.CHL .~3.250 D~PT. .~+900.000 T~NS.DIL -999.250 S=LU.'DIL -999.250 IL~.OIL -999.250 ILO.OIL -999.250 SP.OIL -9'~9.250 GR.DIL -999.250 TENS.=DC -999.250 D'PHI. FOC -977.250 DRHO.:DC -999.250 RHG~.~DC -999.2.50 CALI.:=OC -999.250 GR.FDC .-999.250 TENS.CNL -9'99.250 NPHI.CNL -999.250 TNR,~.CNL -999.250 RTNR.CNL -999.2~0 RC~'T.CNL -999.250 RCNT.CNL -9~9. 250 CFTC.CNL -999.250 CNTC.CNL -999.250 CALI.CNL -999.250 GR.CNL -999.250 TENS.CML 3540.000 GR.CHL 5,F+. 3q~ DEPT. ~800.000 TENS.OIL -999.250 S=LU.DIL -999.250 ILM.O'IL -999.250 ILO.OIL .-999.250 SP.DIL -999.250 GR.DIL -999.250 T~NS.FDC -999.250 DPHZ.FDC -999.250 D~HO.FDC -9i~9.250 RHO:B.FDC -999.250 CALt. FDC -999.250 G~.FDC -999.250 T:~NS.CNL '-999.250 NPHI.CNL --999.250 TNRA.CNL -999.250 RTNR.CNL .-999.2~0 RCFT.CNL -999.250 RCNT.CNL .-999.250 CFTC.CNL --999.250 CNTC.CNL .-9!99.250 C~LI.CNL -999.250 GR.CN[ -999.250 T:ENS.CHL 3~4.000 G~.CHL 80.875 D~PT. 4'700.000 T~NS.OZL -999,250 SFLU.OIL -999.250 ILM.DIL -999.250 ILO.OiL -999.250 SP.DIL -999.250 G~.OIL -999.25~ TENS.FDC '-999.250 DPHI.FDC -999.250 DRHO.FDC -999.250 RMO~.FDC -999.250 CALI.FDC -999.250 GR.FOC -999.250 T~NS.CNL -999.250 NPH~.CNL -999.250 TNRA.CNL -999.250 RTN'p CNL -999.2:0 RCmT.CN~ -9~9.250 RCNT.~r .~ ...... ~ ........ ~NL -999.2!50 CFTC.rNL -999.250 CNTC.CNL -9~99.250 C~LI.CNL -999.250 GR.CNL -99'9.250 TENS.CHL 3364,.000 GR.CHL 57.969 DEPT. 4600.000 T~NS.O!L -9~9.250 SFLU.DIL -999.250 ILM.OIL -999.250 ILS.OIL -,9~9.2 50 SP.OIC -999.250 GiR.DIL -999.250 TENS.F'OC -999.250 DPHZ.FD.C -999.250 D~HO.=DC -9'~9.250 ~HO~.FDC -9'99.250 C~LZ.FDC -999.250 GR.rD~. -9q9.~=0 T:=NS.CNL -9~99.2>0 NPHI.CNL -999.2'50 TNR,,~.CNL -999.250 RTNR.CN[ -9~9.250 RCFT.CNL -9')9.250 RCNT.CN[ -999.250 CFTC.CNL -999.250 CNTC.CNL -9~9.2~0 C~LI..CNL -9~9.250 G~2. CNL -999.250 T!ENS.CHL 3350 G$1. CHL 54.188 IS TAPE VERIFIC'~T!ON I. ISTi.NS CHLU~SERGER AL~.SK& COt~PdTIN,S DEPT. 4500. 090 TS. NS.OIL iLO. SlL -9'.~9.250 SO. OIL DPHZ.FDr -9~q.?sO O~H,~ ~¢ G~,F~: -~.2~0 TS~S.CNL CNTC.CN~ _o~o. ...250 ~.~L~.rNL. G~.CHL ~0.053 DEPT. 4400.000 TENS.OIL ILO.OIL -9,~9.2 ~0 S~.OIL DPHI.FO£ -979.2~0 GR.FDC -999.2~0 TSNS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 C,~LI.CNL GR.CHL ~7.375 DEPT. ~300.000 T~NS.O!L ILD.~IL -999.2~0 SP.DIL D:oHI.FDC -999.250 DqHO.FDC GR.=OC -999.2~0 TENS.CNL RTN~.CNL -999.250 ~CFT.CNL CNTC.CNL .-999.250 CALZ.CN[ GR.CHL 68.000 DEPT. 4200.000 TENS.,gIL ILg. DIL -999. Z .50 S DPH'I.:gC .-999.250 DRHO.FDC GR.~DC '-999.250 T:NS.CNL R'T NR. CNL -999.2 ;50 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL GR.CHL 50.3!3 DEPT. 4100.000 TENS.OIL '!LO.DIL .-999.2 50 SP.OIL DPHI.FDC -999.250 DRHO.~DC G~.FDC -9'99.2~0 T~NS.CNL RTNR. CNL -999.2 50 RCFT. CNL CNTC.CNL -999.250 CALI.CNL GR.CHL 46. ~! 3 D~PT. 40OO.OOO TENS.OIL ILO.OIL -999.250 SP. OIL DPHI.rFDC -999.250 DRHO.~=gC 6R.SDC -999.Z50 T~NS.CNL RTNR.CNL -999.250 RCFT.CNL C N T C. r ,.. . ,~NL -999.250 CAL ~ CNL GR.CHL ~ 54.406 1~- ~US-19~8 09:34 -999.250 SFLU.gIL -999.250 -999.250 GR. 3IL -999. 250 -9~9.2S0 RHO~.FDC -999.250 -9q9.250 NDHi. CNL -999.250 -9'~9.250 RCNT.CNL -999.250 -9 ~9.25 O GR. CML -999. 250 -999.250 SFLU.OIL -999.250 -999.250 GR.gIL .-999.250 -999.250 RHOB.FDC -999.250 -999.250 NPHI.CNL -999.250 -999.250 PCNT.CNL -999.250 -999.2150 GR.CNL -999.250 -999.250 SFLU.OIL -999.2'50 -9 99.2 50 GR. OIL -999.250 -999.250 RHOB.FOC -999.250 -999.2S0 NPHI.CNL -999.250 .-999.2-S0 RCNT.CNL -999.2S0 -999.2 50 G~.CNL -999. 250 -999.250 S:LU.OIL -999.250 -999.250 GR.OIL -999.250 -999.250 RHO~.~OC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -9~9.250 GR.CNL -999.250 -9'99.250 SFLU.OIL -999.250 -999.2'50 GR. OIL -9'99.2!50 -9'99.250 RHOB.FOC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCN'T. CNL -999.250 9q9 2r'O g~ CMl_ --999 250 -- i ,,~ .... i I ~ -9'")9.250 S~LU.OIL -999.250 -999. 250 GR.OIL -999.250 -999.250 RHDE.FDC -999.250 -999.2S0 NPHI.CN[ -999.250 -999. 250 RCNT.CNL -999 . 250 -9 99 . 250 GR.CNL -999. 250 'IL~.glL TSNS.mDC CaLi. FOC TNR~.CNL CFTC.CNL TSNS.CHL ILM.OIL T~NS.FDC CALI.FOC TNRA .CML CFTC.CNL TENS .CHL ILM.OIL TEN S.....:D C C ~L I. FD C TNR~I .CNL CFTC .CNL TENS.,CHL !LM.DIL TENS.CDC CALI.FDC TNRA.CNL CFTC.CNL TENS.CHL IL M. gIL T E lq S. F D C C :a, LI. TNR4 .CNL CFTC.CNL TENS. CHL ILM.DIL TENS.FDC C ALI. FOC 'TNR,~.CNL C FTC. CNL TEN S. CHL DEPT. 3900.000 TSNS.OIL -999.2'50 SFLU.OIL -999.250 ILM.OIL ILD.OIL -999.250 SP.OIL -999.250 GR.gIL -999.250 TENS.FDC DPHI FO~ ,-999.:250 D'~Hn ~OC -999.2~0 RHO8 FDC -9~a9.2::0 C~L! FOr G.R. ~DC -999.~50 TENS.CNL -999.250 NPHZ.CNL -999.250 TNRA.CNL RTNR.CNL -9:}9.Z50 RCFT.CNL -999.250 RCN'T.CNL -999.250 C~TC.CNL CNTC.CNL -~99.~30 CALZ.CNL -999.2'50 GR.CNL -999.250 TENS.CHL G~.CHL ~7.9~S9 '11 -999.250 -999.250 -999.250 -999.250 -999.250 3254.000 -999.250 -999.250 -999.250 -999.250 -999.290 3274.000 -999.250 -999.250 -999.250 -999.250 -999.250 325~.000 -999.250 -999.250 -999.250 -999.250 -999.250 3094.000 -999.250 -999.250 --999.250 -999.250 -999.250 3034.000 -999.250 -999.250 · -999.2:50 '-999..250 -999.250 2980.000 -999.250 -999.250 ,-999.250 -999.250 -999.250 2960.000 IS T~.P5 VSRi~ICa, TT. ON LISTING CHLUMBERG~R ~LaSK~ CC',IPUTZ~S CENTER 12 DEPT. BBO0,OOO T:~,~S. OIL -999.,Z50 S~:L!J, OIL -999.250 IL~4. OIL -999,250 iL'S.D!L -999,2~0 So.O~L -9~9.250 G~,gZL -999.250 T-NS.~DC -999.2~0 DPHI,:DC -999,250 D~H~.:DC -9g9,250 RHDS,;OC -999,250 C&LI.FCC -999,250 Gq.~C -999,25C TENS,CML -999.~S0 NO~Z,CNL -9)9.250 TNRa.CNL -999,250 R TN R. CN~_ - S ~i 9,2 SORCF~, . CML -9.qo~ ~ . 250 Rr~T~ ~' , CML - 999 . 250 C eTC, CNL~ -999 . 250 CNTC.CNL -999,250 C&L~,CNL -999.250 GR,CNL -9~9,250 TENS,C~L DSPT. 3700.000 IL D. DIL -999.250 se, D~HI,:D£ -9~9,250 DRHO,'=DC GR.FDC -999.2:,0 TENS,CML RTNR,CNL -999, Z~O RCFT,CNL CNTC.CNL -9q9.ZSO CtL!.CNL GR.CHL 50.000 -999,250 -999,2S0 -999.250 -9~9,2S0 -999,250 -999 ,Z'SO SPLU,OIL GR,OtL RHO~,PDC NoHI,CNL RCNT,CNL GR,CNL -999.250 -999.250 -999.250 -999.250 -999 2=0 -999.250 ;tM,OIL T =_NS, mDC C ~t I, :DC TNR~,CNL CFTC,CML TENS,CHL -999.2~0 -999.2~0 -999.2~0 -999.250 -999.250 2774,000 DEPT, 3600,000 T~NS,OIL -999,250 S:LU,OIL -999,250 ILM,DIL -999,250 ILS,OIL -9~9,250 Se.OIL -999,250 6R,OIL -999.250 T~NS,~OC -999,250 DPHI,'FDC .-999,250 DRHO,~OC -9')9.250 RMO~,FOC -999,250 C~LI,FDC -999,250 GR,FDC .-999,250 TENS.CML -999,250 NPHI,CNL -999,250 TNR~.CNL -999.250 RTNR,CNL -999,250 RCFT,CNL -999,250 RCNT,CNL -999.250 CFTC.CML -999,250 CNTC,CNL -999.2'50 C~LI.CNL -999. 250 Ge.CML -999,250 T~M$.CHL 26?4.000 GR,CHL ~2.56~ D~PT, 3500,000 TENS,D!L -999.250 SFLU,O!L -999.250 'ILM,DIL -999,250 ILO.OIL -999,250 Se,OIL -999,250 GR,DIL -999,250 TEN~S,FDC -999,250 DPHi,FDC -999,2:90 DRHO.FDC -999,250 RHOB,~OC -999,250 .C~LI,FDC -999,250 GR,FDC -999,2~0 TiENS,CNt -999,250 NPHI,CNL '-999,250 TNR~,CNL -999,250 RTNR,CNL -999,250 RCFT,CNL -999,250 RCNT,CNL -999,250 CFTC,CML -999,250 CNTC,CNL -999,250 C~LI,CNL -999,250 GR,CNL -999,250 T~NS,CHL 27130,000 GR,CHL 50,875 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 S~LU,D!L G~,OIL RHOB,FOC NPHI,CNL RCNT'CNL .GR,CNL DEPT, 3300.000 T~NS,O!L -999.250 S~LU.DIt ILO,OIL -999,2150 SP.OIt -999,250 GR,OIL OPH'I.FOC -999,250 DqHO.FDC -999,250 RHOB.FDC GR,FDC -999,2150 T~NS,CML -999,Z50 NPHI,CNL RTNR,CNL -999,250 RCFT,CNL -999,2>50 RCNT.CNt CNTC,CNL -999,250 £ALI,CNL -999,2.50 GR,CNL GR,CHL 52.875 DEPT, 3200.000 T~NS,OIL ILO.OIL -999,2!50 SP.OlL DPHi.FDC -999.250 D~HO.~OC GR,FDC -999.21:~0 TENS,CML RTNR.CNL -999.250 RCFT.CNL CNTC,CNL -999,250 CALI,CNL ,-999.250 -999.250 -9'99.250 -999.250 -999.250 -999.250 -9:99. 250 -999,250 -999. 250 -999.250 -999 - 250 -999.250 -999,250 -999.250 -9'99.250 -999,250 -999.2~0 -999,250 -999.250 -999.250 -9'99.250 -9'99.250 -999.250 -999.250 I t t,~, O I t TENS,FDC C AL I, FDC 'TNR&.,CNL C FTC ,CML T~NS,CHL Itq,'OIt T~NS,FDC CALI,~OC TNR~.CNL C:TC,CNL TENS,CHL 'ILM. OIL TENS.FDC CatI. FDC TNRA.CML C ~TC. 'CNL TENS.CML S FLU. <9I L GR.OIL RHO3.FDC NPH I. CNL RCNT. CNt GR .CNL ,-99'9.250 -999.250 -999,250 -999,250 -999.250 2.564.000 -999,250 -999,250 -999,250 -999,250 -999,250 2494,000 -999.250 -999.250 -999.250 -999.250 -999.250 12410,000 GR CHL &~ 731 OEPT. 3100 . onn.. Tc,NS,. . 9rL.._ -9)a.- . 2qO.~ SFLU .;,~IL -939 . 250. ZLM .31L -999 .250 ~Lg.~II_ -9'~9. .ZSO S~.nlL~ -999.2:0_, GR.DZL -~99. .~50 TENS.FDC -999.250 OPHZ .....~Dr -999 250 DRH2 ~g~, .......... -9~9 250 RHQB ~Or -~q9 250 CAL't ~gC -9~9.250 GR.c3~ -~'~. 250 'TENS.CNL -999.250 NOH.Z.CNL -999.250 TNRI.CNL -999.250 RTN~.~NL -9q9 ~qO RCF~ CN' -999 250 RCNT CNL -999 2S0 CmTC CNL -999 250 G~.CHL ~7.~06 DEPT. 3000.000 T~NS.glL -999.250 S:LU.DIL -999.250 [LM.~ZL -999.250 ILO.OIL -999.250 SP.O~L -9~9.250 G~.gIL -999.250 T~NS.FDC -999.250 D~HI.:DC -999.250 ~HO.:DC -9~9.250 RHOB.~DC -999.250 CALZ.~DC -999.250 GP.=DC -999.250 T~NS.CNL -999.250 NPHI.CNL -999.250 TNR~.CNL -999.250 RTNR.CNL -9:~.2~0 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC r , .~N,~ -9~-.250 C:~LI.CNL -999.250 GR.CNL -9'39.250 TENS.CML GR.CHL 39.9&9 DEPT. 2900.000 TENS.OIL -999.250 SPLU.O!L -999.250 ZLX.DZL -999.250 ILO.OIL -999.250 SP.O!L -999.250 GR.OZL -999.250 TENS.FDC -999.250 DPHZ.FOC -999.250 OqMO.FDC -9~9.2'$0 RHOB.FDC '-999.250 CAL].FDC -999.250 G~.~DC -999.250 T~NS.CNL -999.250 NPHZ.CNL -999.250 Tt'~R.~, . CNL .-999.250 R'TN~.CNL -9'99.250 RC~T.CNL -999.250 RCNT.CNL -999.250 CFTCoCNL -999.250 CNTC.CNL -999.250 C.~LZ.CNL -999.250 GR.CNL -999.250 TENS.CHL 2234.000 GR. CHL 38.~13 DEPT. 2800.000 TENS.OIL -9"~9.250 S~LU.DIL -999.250 ILM.OIL -999.250 ILO.OIL -999.250 SP.DIL -999.250 GR.OIL -999.250 TENS.FDC -999.250 DPH! .FDC -9:99. 250 DRHg. F~C -9'99. 250 RHDB.FDC -999. 250 C~,LI. FDC .-999. 250 GR.FDC -999.250 T'ENS.CNL -999.250 NPHI.CNL -999.250 TNR~.CNL -999.250 RTN~R.CNL -999.250 RCFT.CNL -999.2~0 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 C,~L~. CNL -999.250 GR.CNL -999.250 T~NS.CHL 2194.000 G~.CHL 36.9'~ DEPT. 2700.000 TENS.OIL -9:99.250 SFLU.OIL -999.250 ILM.DIL -999.250 ILO.OIL -999.2S0 SP.DIL -999.250 GR.OIL '-999.2~50 T'ENS. FOC -999.250 DPHI. FDC -999.250 DRHO.~DC -999.250 RHOB.FDC -999.250 CALZ.FDC -999.2f0 GR.FDC -995.250 TENS.CNL -999.250 NPHI.CNL -999.250 TN~A.CNL -999.250 R'TN~.CNL -999.250 R~F~.rNL~ -999.250 RCNT.CNL,, -999. .250 CmTC.CNL -999.250 CNTC.CNL -999.250 C,~LI.CNL .-999.250 GR.CNL -999.2'50 TENS.CHL 2104.000 GR.CHL 36.063 DEPT. 2600.000 TENS.OIL -999.250 S,:LU.D~L -999.250 ZL~.DZL -999.250 iLO.OIL -999.250 SP.OIL -999.250 GR.DIL -999.250 'TENS.FDC -999.250 DPHI.~DC -999.250 DRHO.~OC -99'9.250 RHO~.mOC -999.2:~0 CAL!.~OC -999.250 GR.FDC -999.250 T~N'S.,CNL -999.250 NPHZ.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -9'99.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -9')'9. 250 C~LI.CNL -999.250 G~.CNL -999.2,50 T~NS.CHL 2050.000 GR.CHL ~2.156 D'EPT. 2500.000 TENS.~IL -999.250 SFLU.OIL -999.250 IL',"~. D I L -999.250 ILO.OIL .-999.2S0 SP.OZL -999.250 GR.DIL -999.250 TENS.FDC -999.250 DPHI, . FDC - 9:99 .250 ORHg . ~g~. - 999 .2:}0" ~ R HO:~. FDC -999.250 C ~,L L~. FOc~ - 999.2 50 GR.FDC -999,.250 T:5~S. CNL -999.250 NPHI.CNL -999.2:50 TNR~{.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -9'99.250 CFTC.CNL -999.250 IS TAPE V~RZFIC~TZON LISTING CHLUMBE'~GEP ALASKa CO~,'~PUTING C~NT~R CNTC.CNL -999.250 C~LZ.CNL Gq.CML 40.813 DEPT. 2400.000 T~NS.D]L ILO.OIL -9'~9.2f 0 SP. D~HZ.:D£ '-999.250 DRHO.FDC GR. FD~ -9~9. 250 T:_--NS. rNL~ RTNq.CNL -999.2~-0~ ,,~,...~NL CNTC.CNL -999.250 C&L!.CNL GR. CHL 37. 875 -9 99 . 2 50 GR.CNL -9:39.250 -999.250 S~L~J.DiL -999.2.50 -9 :~9.250 G~.~IL -999.2~0 -9'.~9.250 RHGg.~DC -999.2q, 0 -999.250 NmHI.CNL -999.250 -999.250 RCNT.CNL -999.250 --999. 250 G~.CNL -9 99. 250 T--NS.CHL ILM. gIL T~NS.~OC C ALT- . cDC TNRA.CNL CFTC.CNL T~=NS.CML !965.000 -999.250 -999.250 -999.250 -999.250 --999.250 1915.000 DEPT. 2300.000 T~NS.OIL -999.250 SFLU.OIL -999.250 IL~.DIL -999.250 IL~.DIL -9~.2~0 S~.OIL -9~9.250 GR.OIL -999.250 TENS.~OC -999.250 DPHIoFDC -999.250 D~H~.~C -9~9.250 RH~3.FDC -999.250 C~L'I.FDC -999.250 GR.~OC -999.250 TENS.CNL -999.250 NP~I.CNL -999.2~0 TNRi. CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 C:TC.CNL -999.250 CNTC.CNL -999.250 C&LI.CNL -999.250 GR.CNL -999.250 TENS.CHL 1875.000 GR.CHL ~6.625 D~Pr. 2200.000 T~NS.~!L ILO.OIL -9Q9.250 SP.OIL DPHi.FDC -999.250 OlRHO.FDC GR.;OC -999.2~0 TEMS.CNL RTNR.CNL '-999.250 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL G~.CHL 33.063 -939.250 SFLU.OIL -999.250 ILM.DIL -999.2~0 -999.250 G~.OIL -999.250 IENS.FDC -999.250 -999.250 RHOB.FOC -999.250 C4LI.=~C -999.250 -999.250 NPHI.CNL -999.250 TNR~.CNL -999.250 -999.250 RCNT.CNL -999.250 C~TC.CNL -999.250 -999.250 G~.CNL -999.250 T~NS.CHL 17B5.000 -999.250 SFLU.DIL .-999.250 -999.2 SO GR. OIL -999 . 2'50 -9'99.250 RHO~.FDC -9;99.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 '-999.250 GR.CNL -999.250 IL~.DIL TENS.FDC CALI.FDC TNRA.CNL CF'TC.CNL T~NS.CHL D~PT. I100.000 TENS.OIL ILO.OIL -999.250 SP.OIL DOHI.FDC -999.250 D~HO.FDC GR.mDC -999.250 T:ENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999..2~0 C~L'I.CNL GR.CHL DEPT. 2000.000 TEN'S.DIL -999.250 SFLU.OIL -999.Z50 IL~.DIL ILO.OIL -999.250 SP.OIL -9'99.250 GR.DIL -999.2S0 TEN, S.:gC 5PHI.FDC -999.250 ORHO.~DC -999.250 RHO~.FgC -999.250 C&LI.FDC GR.FDC -999.250 TENS.CNL -999.250 NPH'I.CNL -999.250 TN:~A.CNL RTNR.CNL -999.250 RC~T.CNL -999.250 RCNT.CNC ,-999.250 C~TC.CNL CNTC.CNL -999.2F0 C&L!.CNL -9'99.250 G~.CNL -999.2~0 'TENS.CHL GR.'CHL ~7.969 -999.250 SFLU.DIL -999.250 -999.250 G~.OIL -999.250 -999.250 RHO~oFOC -999.2~0 -999.250 NPHI..CNL -999,.250 -999.250 RCN~T.CNL '-999.250 -999.2S0 G~.CNL -999.250 I L ~'~,. D I L TENS. 'FDC C~LI. FDC TNR4. CNL C~TC .CNL T~NS.CHL ILM.OIL T~NS..'FDC CALI.~OC TNR~.CNL -99'9.250 S:LU.DIL -999.250 -999.250 GR.DIL -999.250 -999.250 RHO~.FDC '-999.250 -999.250 NPHI.CNL -999.250 DEPT. 1900.000 T!ENS.DIL ILO. OIL -999. 250 SP. OIL DPHI.FOC -999.21~0 DRHO.FOC G~.FDC -9~9.250 TENS.CNL RTNR.CNL '-999.2'50 RCFT.CNL CNTC.CNL -999.250 C~LI.CNL G~.CHL 137.9~ DSPT. 1800.000 T~NS.OIL ILO.OIL -999.250 S°.OIL DPHI.~DC -999.250 DRHO.~DC GR.~OC -999.2~0 T~NS.CNL -9'99.250 -999.250 -999.250 -999.250 -999.250 180:5.000 -999.250 -999.250 -999.250 -9 99. ,250 -999.250 1730. 000 -999.250 -999.250 -999.250 -999.250 -999-2:50 !710.000 ,-999.250 -999.250 -999.250 -999.250 IS TAPE VERZFIC~TZON LZSTING CHLUM~ERG.-ZR AL~SK~ CC:'.qPU?ING CENT'~R RTNR.CNL -999.250 RCFT.CNL CNTC rNL -9~9 zqn C~LZ CNL GR.CHL 47.406 13-,~UG-193~ 07:34 -999.250 RCNT.CNL -999.250 -9 99.2 :-0 Gm. CNL -999 . 250 DEPT. !790.000 T~NS.~IL_, -939~ .~50 S~LU.gIt ILO. DIL -999.250 S~. OIL -999. 250 GR .DIL D~HI.~DC --999.250 ~RHg.=gC -999.250 RHO~.~DC GR ~C -og~ 250 T~NS CNL -9q9 '~ ~ . ....... .~50 NPHI CNL RTNR.CNL -~9.2~0 RCFT.CNL -999.250 PCNT.CNL CNTr.CNL -99~ 2c0 C~L'T tnt -999 250 GR rM~ GR.CHL 11.125 DEPT. 16"90.000 TSNS.OIL ILD. DIL -999.250 S P.OIL DPHI.~DC -999.250 gRHO.~DC G~. FO~ ..... ~ -9'a9.2~0 TENS.rNL RTNR.CNL -9'99.250 RCFT.CNL CNTC.CNL -999,250 C~LI.£NL GR.CHL 28.375 -999.230 -999.250 '-999.250 -999.250 -999.250 -999.250 -999.250 S=LU.DIL -999.250 -999. 250 GR.OIL -999 . 250 -9q9.250 RHOi~.FDC -999.250 -999.2'S0 NPHI.CNL -999. 250 -999.2'50 RCNT.CNL -999.250 · -9 ~9.2 50 GR. C Nh -999 . 250 CFTC .CNL TENS.CHL IL~.OIL TENS.~OC C~LZ ~Dr TNR~.CNL CFTC.CNL T~NS.CHL ILM.OIL TENS.FDC CALI.=DC TNR.~ .CNL C:TC.CNL TENS. CHL DEPT. !500.000 TENS.OIL -9?9.250 S:LU.D]L -999.250 !LM.DIL ILO.OIL -999.250 Sm. OIL -999.250 GR.OIL -9'99.250 TENS.FDC DPHi. FDC -999.250 DRHO.=DC .-999.250 RHOB.~DC -999.250 C~LI.FDC GR.FDC -999. Z50 T~NS.CNL -999.250 NmHI.CNL -999.250 TNRS.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 C=TC.CNL CNTC.CNL -999.250 C~LZ.CNL -9;99.250 GR.CNL -999.250 TENS.CHL GR. CHL 35. 500 -9~9.250 S~LU.OIL -999.250 -999.250 GR.DIL -999. 250 -999.250 RHO~.FOC -9':)9.2',,50 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999. 250 GR.CNL -999. 250 -99'9.250 SFLU.OIL -999.250 -999.250 GR.OIL -999.250 -999,250 RHO~.FOC -999.250 -999.250 NPHI.CNL '999.250 -999,.250 RCNT.CNL -999.250 -999.250 GR.CNt -999.250 DEPT. 14'00.000 TENS.git ILO. OIL -999.2 50 SP .OIL DPHI.FDC -999.250 D!~HO.FDC GR.~DC -999.250 TENS.CNL RTNR.CNL -999.2:~0 RCFT.CNL CNTC.CNL -999.250 C~L!.CNL GR.CHL C, EPT. 1300.000 T'ENS.QIL ILO.'DIL -999.250 SP.OIL DPHI..~OC -999. 250 gRHO.=DC GR.~DC -999.250 T:ENS,CNL RTNe CNL -999 25~ ~:~:T rNL CNTC.CNL -99'9.250 C~L].CNL GR.CH[ 35.1Z5 DEPT. 1200.000 TENS.OIL ILO. OIL .-999.2 50 SP.OIL DPHI.!F~C -999.250 GR.FDC -999.2'50 TENS.CNL RTNR.CNL .-999.250 RCFT.CNL CNTC.CNL -999.,250 C~LI,CNL GR. CML 51.2'! 9 '-~999. 250 S~LU.OIL -999.250 -9 99..250 GR.DI L -999 . 250 -999.250 RHO~B,FDC -999.250 -999.250 NPH!.CNL -999.250 -999.250 RCNT.CNL -999.250 -999 . 2:50 GR.CNL -'999.250 IL,M.OIL T~NS .~DC CALl. FOC TNR~.CNL CFTC .CNL TEN S. C HL IL~.OIL TENS.FOC CaLI.~DC TNR~.CNL C~TC.CNL TENS.CH[ ILM.OIL TENS,FOC C4LI. ~DC TNRA. CNL C FT C. :C NL TENS .CHL -999.250 1690.000 -999.250 -9~9.250 -999.250 -999.250 -999.250 16~0.000 -999.250 -999.250 -999.250 -999.250 -999.250 1620.000 -999.250 -999.250 -999.250 -999.250 -999.250 1555.000 -999.250 -999.2=0~. -999.250 -999.250 -999,250 1485.000 -999.250 -999.250 -999.250 -999.250 -999.250 1445.000 -999.250 .-999.250 -999.250 ,-999.250 -999.250 1405.000 IS TAPE V,ERZFiCaT!O'~ LISTING CHLUM~EDGZR AL2SK~ CO~,DUTING CENT?D DEPT. i190.000 TENS.DIL ilLS. OIL -999.250 SP. OIL DPH!.FDC -999.250 DRH~P.FDC GR. FDC -9~9 250 ~NS.rN~ RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 CaLZ.SNL GR.CHL 55.1~8 DEPT. lO00,O00 T~NS.DIL ILD.DiL -999. 250 Sm. OIL g~HI~ =g" -999.250 u~u~"'u" :,hr, GR.~DC -999.250 T~NS.CNL RTNR.CNt -999.250 RCFT.CNt CNTC.CNt -999,250 CaLl. CML GR.CHL ~I .219 D=PT. 9~'4 500 TSNS.nIL iLO. Dl L -999.2 FO S ~.OIt EPHI.~DC, -9~9.250~ ~'~HD.''r~''''~. r~,,,, GR.FDC -9~9.2'50 TENS. :CNL RTNR.CNL -9.?9.250 ~CFT.CNL CNTC.CNL -999.250 C ~ILI.CNL GR.CHL ,'+3.6q8 10,_ r- -999,250 S¢LU.OIL -999,250 -999,250 GR,DIt -999.250 -9~9.250 PHOB.~DC -999,250 -99q.250 NPHI.CNL -999.250 -999.250 RCN~.CNL -g99.250 -9~9.250 GR.CNL -999.250 -999.250 S~LU.O~L -999.250 -9;9,250 GR.DIL -999.2~0 -999.Z50 RHO~.=DC -999.250 -919,250 NmHI.CNL -999.250 -999,250 PCNT,CNt -999.250 -999.250 GR.CNL -9:99.250 -9'~9,250 S~LU.DIL -999.250 -999.250 G~.DIL -999,250 -9~9.250 RHOB.FDC -999.250 -99q.250 NPH!.CNL -999.250 · -999.250 RCNT.CNL -999.250 -999.250 G~.CNL -999.250 IL~.gIL TENS.FDC CALl TNR&.CNL C~TC.CNL TENS.CHL iL~.DIL T:NS.FDC C~LI.FDC 'TNR&.CNL CFTC.CNL TENS.CHL ILM.DIL TENS.~OC CALI.FDC TNR~.CNL C~TC.*NL. TENS.CHL -999.250 -9,~o. 250 -999.250 -999.250 -999.250 !305,000 -999,250 -999.Z50 -999.250 -999.250 -999,250 1270.000 -999.250 -999.250 -999.250 -999.250 -999.250 1195.000 16 END OF O~T~, g* ~Z='$ FTLE.,. 'TR,'It'=R._ *"'*'~*' FILE NAME ~ EDIT SERVICE : FL'!C VERSION : 001~02 DATE : MAX PEC $!Z~ : 1024 FILE TYPE : LO L~ST ~ILE ~'"'~'" FILE ~E~DER ~ FILE NA~E : ~OIT .002 SERVICE : ~LIC VERSION .: 001~02 DATE : 89/0~/18 M~X REC SiZ~ : t024 FIL~E TYPE : LO L~ST FILE : ;~'~'-~-' THIS D'~'T& HaS N3T BEEN DEPTH SHIFTEO - OVERLAYS FIELD PRINTS IS T~,~E VERIFICATION LISTING 1~-~U'S-199,8 09:~4 CHLUPRERG~=_'R ALASKA C3~,~PUTIN~S CENTE~ '17 ScH[UMg_-R~=R~ ~ tOGS T.'qCLUOED WITH THIS FZL~. (SD!T .002)' -,-~ FIRSI T~= LAST. RE~DING'. gT96' TO ,8050' ~. ~O~4P=NSAT~9_ N~UT~ON. . LOS (.rNH).~ -,, m* _ : 3778' ~- ~gST TO LgST Rc~9ING TC 80c0~ TABLE TYP~ : CONS CN FN WN N AT [ STAT C 2 U N SECT TOWN RANG FL OPER S 0 N A!O IN 'TUN! V~LU O E = I .~RCO AL~.SK:~, INC. KUPARUK :3 3-5 U.S.a. ~L~SKA N O'.R TH SLOP~ ZZ 'I 3 N 811' F,qL & 189Z' M:&LL-ARY ~30800 50-029,-~1839 C3MP~NY NAME FIELD NAME W~LL NAME N~TION STAT~ OR PROVINCE COUNTY SECTION TOWNSHIP RANGE FIELD LOC~TION ~ 'T ~ O!~:RA OR S COD~ SE~VZCE ORO~R NUMBER APZ S~5R~,~L NUMB'SR ~I SE~'I,~L NU~BSR 'TABLE TYPE : r,~URV O E P'T TENS DPH! DRHO RH05 CALI GR TENS NPHI TNR A R TNR DEPTH CHANNEL N~ME T ~EN S I ON D~ENSITY POROSITY g E L T ~ R H 0 BUL~. DENSITY C:~L!PER G ~H~,~ R ~Y TENSION N~UTRON POROSITY C~L!BR~TEO THER?~AL ~EUTRON ?A'TIO R~W THE~R~L N?U'TRDN R~TIO IS T~PE VCR]EFIC;~'TION 'LiST!'_MG CHLUM"~E~G:7=R ~L/~,$K~, '~qPUTZNS ~CN'TER ! o-,~%UG-198 ~ 09:B4 18 DE=I RC~:T R,.S.~T RCNT RCNT CFTC C~:TC CNTC C NTC GR G A ~4~..4 $ TYPED RE°R C~'DE V~LUE 2 66 0 ~ 73 54 4 66 1 8 68 0°099 9 6~ ~Y 11 66 16 14 65 ~T 16 66 0 66 ! '~ S~T TYP~- CqBN ,~- NAM5 SE~V UNIT SEqVIC:E API ~IPT ~I ~Pl ~ILE NUM~3 NUMB SIZ~E ~REgR !D ORO~P ~ LOG TYP= rL~SS 'qnO ~IUqg S~MP =L:M COOE p R O C E S S (H~×) D E P T F T 53 O.~.~ ~ O 0 TENS FDH L3 539800 DPHI FDH PU DRHO ~OH G/C3 $308©0 RHOB FO:q G/C3 530800 CALl ~DH IN 530800 GR FDH G.API TENS CNH L+3 530800 N~HI CNH PU 530800 TNRA CNH RTN~ CNH RCFT r~Nd C p~t S~O~u ~0 RCNT CNH CPS 530900 CFTC CNH C~S 530800 CNTC rna,., rP.S~ GR CNH G,~PZ 530800 2 1 1 4 68 2 ! 1 4 68 2 1 1 4 68 2 ! 1 4 68 2 ! 1 4 65 2 I 1 4 6 8 2 1 1 4 ,6 8 2 1 t 4 6 B 2 1 1 4 6B 2 1 1 4 62 2 1 ! ¢ 65 2 ! 1 4 68 2 1 1 ,4 68 2 1 I ~+ 68 O00000OO0,O O00000000O O00OO000OO O0000000OO O000OO00OO O000OO00OO O0000000OO O00000OOOO O000gOOOOO OOOOOO00OO OOOO00OOO0 O0000000OC 0000009090 0000000000 gOOOOOO000 OOOO000000 lq--~U S-19!38 09:34 SE 19 DEPT. ~8SO.OOO TEMS.=DH ~312.000 RHC].FDH 2.368 C~L!.:DH 6.172 N~)HI.CNH ~4.997 TNP~..CNH 3.442 RrNT CN~J t9~8 846 CFTC rtl~ 5~5 839 DEPT. 8890.000 TENS.:DH 6368.000 RHO$.=DH 2.3~5 C~L!.mDH 6.234 NPHI.CNH 43.356 ThlR~.CNH 3.357 RCNT.CN?i 1915.044 CFTC.CNH A15.8~5 DEPT. 8700.000 TENS.FDH 6312.000 RHOB.$DH 2.434 C~LI.FDM 8.445 NmHI.CNH 60.~61 TNP~.CNH 3.340 RCNT.CNH 1926.000 C=TC.CNH 646.399 D~PT. 8600.000 T2NS.F~H 6264.000 RHDB.FDH 2.406 C~LI.:DH NPHI.CNH 41.553 TNR~.CNH 3.405 RCNT.CNH 1895.T17 CmTC.CNH 591.254 DEPT. ~500.000 T~NS.FDH 5732.000 RHOB.FDH 2.297 C,~L i. ~OH 8.266 NPHI.CNH 28.431 TNR~.CNH 2.615 RCNT.CNH 1534.I~9 C~TC.CNH 1014.0T5 DEPT. 8900.000 T,ENS. FDH 6112.000 RHOB.FDH 2.497 C~LI,.F~H 8.758 NPHI.CNH 29. 787 INR~.CNH 2.7~6 RCN T.CNH 2.~ ~ 91 .5~ ~4 C ~TC. CNH 8~,. 2. g~. 8 DEPT. ~300.000 TENS.FDH RHDB.FDH 2.4'~6 C4LI.~DH 9..336 NPHI.CNH 34.406 TNR~.CNH 3.087 RCNT.CNH 1927.120 C~=TC.CNH 750.078 DEPT. ~]200.000 TENS.=DH 5768.000 RHDB.FDH 2.410 CALI.~D~ 8.422 NPHi.CNH ¢7.2~7..~ TNRA.CNH 3. 714 RCNT.CNH 1318.34'7 C=TC.CNH 515.3~8 D~PT. 81,90.000 T~NS.mDH 5652.000 RH08. ~FDH 2.449 C~L!.~PH 8.656 NPHI.CNH 47.2~1 TNR~.CNH 3.735 RCNT.CNH 1637.42~ CFTC.CNH 488.9!7 DEPT. ,~0~9.5.90 T2NS.=DH RHOB.FOH 2.349 C~LI,FOH 9.008 NPHI.CNH ~6.327 'TNR A. CN:H 3.712 RCNT.CNH 1674.929 CFTC.CNH 470.922 gPHI.FDH GR.~DH RTNR.CNH CNTC .CNH OPHI.=DH GR.:OH RTNR.CNH CNTC .CNH DPH! GR .FOH RTNR.CNH CNTC.CNH DPHI .FDH GR .~DH RTNR. CNH CNTC.CNH O~HI.~:OH GR.FOH RTNR.CNH CNTC. CNH DPHI. FOH GR .;DH RTNR .CNH C N T C. C N H DPH I. FDH GR .FOH RTNR .CNH CNTC .CNH OPHI. GR.FDH RTNR .CNH CNTC .CNH O~'H!. FDH GR.FDH RTNR.CNH CNTC .CNH DPHI .FDH GR .FOH RTNP. CNH CNTC .CNH 17. I !0 94.688 3.5:55 2018.851 16.076 94.638 3.345 1997.l~6 13.100 94.375 3.73! Z 0 55.40 ~ 14 8 O = 98.063 3.958 19:53.662 Z1. 376 43.000 2.511 2635.60~ 9.2 93 93.188 2.971 2362.1,64 9 1111. 250 2.829 2147. 037 90.3~13 3.917 !8~3.7'74 12.169 108.250 3.609 1733.716 18.240 1.06.000 3 .OOO 17,~Z.791 TENS.CNH RCFT.CNH GR.CNH DRH3 .FDH TENS. CNH RCFT.CNM GR.CNH DRHg T ENS.CNH RCF'T. CNH GR.CNH DRHi]. FDH T:NS. P. CFT.CNH GR.CNH DRH'O. FDH TENS.CNH RCFT .CNH GR.CNH ORHO.FDH TENS. CNH RCFT .CNH GR .CNH ORHO.FDH 'T E N S. C N H RCFT.CNH GR. CNH D~HO.FDH TENS. CNH R C ~T. CNH GR .CNH DRHO. ~DH TENS .CNH RCFT.CNH GR. CNH DRHO. FDH T ~-NS. CNH RCFT.CNH GR.CNH 0.231 4312.000 538.025 94.6B8 0.232 6368.000 553.029 94.688 0.008 5312.000 554.657 94.375 0.001 5264.000 565.877 98.063 0.021 5732.000 8'94.. 792 ¢3.000 0.059 61t2.00D 814.528 93.188 0.0,~9 5860.000 677.7'75 11 1.2, 50 0.009 5758. OOO 432.469 gO. 313 -0.024 5652.000 459.657 108.250 0.030 5808.000 423.735 106.000 ~'- -'- _ ** -,,-,- END n= O~T:a,, IS TAPE V5RZFZC,AT,ZON L'.Ts~rTNG '18-~,tJG-!988 0~: 3~ P~SE: 20 SERVICE NAME : =giT D.~TE : 83/08/18 ORIGIN : FLOC TAP~ NA~E : 728~7 CONT INU ~T'ZO~,I PREVIOUS 'T~5 COM~qENT ~ LIS TAPE, ~RCO K'JP,~.RUK '3 0-5, ~,PI ~50-029-21'~39 ~~""-"' RE=L 'TRa'IL:~, -~ ....... SERVICE NAME : ~D'IT DATE : :~8,/0 3/18 ORIGIN : ~L!C REEL N~qE : 72B87 CONTINU~T:ZO~ e : PREVIOUS RE~L : COMMENT LIS T&PE~, ARCO KUPIRUK ] ~-5~ &, z _
