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190-164
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 8, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1L-22 KUPARUK RIV UNIT 1L-22 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/08/2024 1L-22 50-029-22114-00-00 190-164-0 W SPT 5908 1901640 3000 2431 2431 2433 2438 140 150 150 150 REQVAR P Guy Cook 6/1/2024 MITIA to maximum anticipated injection pressure per AIO 2C.042. Testing completed with a Little Red Services pump truck and calibrated gauges. Water header pressure at 2750 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 1L-22 Inspection Date: Tubing OA Packer Depth 190 3300 3180 3180IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC240601184231 BBL Pumped:3 BBL Returned:3.2 Monday, July 8, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9James B. Regg Digitally signed by James B. Regg Date: 2024.07.08 12:21:47 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1L-22 KUPARUK RIV UNIT 1L-22 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/20/2022 1L-22 50-029-22114-00-00 190-164-0 W SPT 5908 1901640 3000 2530 2533 2537 2538 130 140 135 135 REQVAR P Adam Earl 6/18/2022 MIT-IA tested as per AIO 2C.042 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 1L-22 Inspection Date: Tubing OA Packer Depth 230 3280 3160 3125IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220622101943 BBL Pumped:3.5 BBL Returned:3.5 Wednesday, July 20, 2022 Page 1 of 1 MEMORANDUM TO: Jim Regg n P.I. Supervisor FROM: Austin McLeod Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 8, 2020 SUBJECT: Mechanical Integrity Tests ConomPhillips Alaska, Inc. 1L22 KUPARUK RN UNIT 1L-22 Svc: Inspector Reviewed By P.I. Sapry Comm Well Name KUPARUK RIV UNIT 1L-22 API Well Number 50-029-22114-00-00 Inspector Name: Austin McLeod Permit Number: 190-154-0 Inspection Date: 6/4/2020 ✓ Insp Num: , mitSAM200605094050 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min We - IType InJ I N ITVD s9as 'Tubing 460 490 490- 490 - 490 " PTD 1901640 Type Test SPT Test psi 3000 IA 370 3310 3280 ' 3220 3210" BBL Pumped: z.9 BBL Returned: 2.8 OA 100 U0 - 110 - 110 ' 110 " Interval I REQVAR P/F P Notes: 2 year to MAID as per AIO 2C.042. 8/1 for curtailment. ✓ Monday, June 8, 2020 Page 1 of 1 Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <nl617@conocophillips.com> Sent: Thursday, January 31, 2019 1:25 PM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: KRU 11--22 (PTD 190-164, AIO 2C.042) IA Diagnostic Review Chris, Kuparuk injector 1L-22 (PTD 190-164, AID 2C.042) has Administrative Approval to continue water only injection due to previously suspected IA to formation communication. However, recently a diagnostic crew discovered and repaired leaking jewelry on the IA at surface. AID 2C.042 states that the IA pressure is not to exceed 500 psi, however, for diagnostic purposes CPAI intends to leave the IA pressure above 500 psi during a 90 -day monitor period to investigate the possibility that the previous IA pressure decline resulted from a small leak at surface rather than downhole. If the monitor confirms that the surface jewelry was the primary source of the pressure falloff, then CPAI may submit the appropriate documentation to cancel the Administrative Approval. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz (covering forlan Byrne or Kelly Lyons) Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 • • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday, October 08, 2016 8:47 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of IA and OA pressure anomaly 1L-22 (PTD 190-164) 8-9-16 update 10-8-16 Attachments: 1L-22 90 day TIO 10-8-16.PNG Chris, The extended monitor period is coming to an end today. During the monitor,the IA has continued to demonstrate a very slow pressure fall off. However any slight increase in OA pressure can be potentially attributed to thermal effects. In order to better understand the dynamics in play on this well, I would like to extend the monitor out again for an additional 60 days. An MITIA will be performed to confirm the production casing's integrity down to the packer(we have only performed an MITOA since reporting the anomaly in August, which only tests the PC down to the surface casing shoe). Following the MITIA, the pressures will be manipulated several times during the course of the monitor to see if there will be any change in response pattern. I believe that whatever is occurring here is of an unclear and slow enough nature to warrant this abnormally long monitor period. If the MITIA does fail, the well will be shut in and freeze protected as soon as possible. Please let me know if you disagree with the plan forward. Attached is an updated TIO plot. Kelly Lyons/Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224S WED FEB 2 7 2017 Mobile Phone (907) 943-0170 From: NSK Problem Well Supv Sent:Thursday, September 08, 2016 2:16 PM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R. Tyler<R.Tyler.Senden@conocophillips.com> Subject: RE: Report of IA and OA pressure anomaly 1L-22 (PTD 190-164) 8-9-16 update 9-8-16 Chris, A passing MITOA was performed on 8/11/16. The 30 day monitor period is coming to an end today. However, CPF1 had an extended shutdown period earlier in the month and there have been too many thermal fluctuations to definitively conclude whether or not there is slow IAxOA communication present. Several days ago we reestablished the dP across the annuli and we plan to extend the monitor out an additional 30 days. An email will be sent at the conclusion of the extended monitor period. Please let me know if you disagree. Attached is the updated 90 day TIO trend plot. Kelly Lyons/ Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907)943-0170 1 w V • i Naa_ aa w w cr ,-.5HwI-- w a D ....-- D (L) o = o _ fn oo .no Lu co C) CD r CC CJ CD <I i a Li p <n G O CO O w O O N -, CC o N- = ctt. L O m y `w C-6 VI C, CD C, CD Lu CO 0, O, CJ CC 0-, *t • N O. tz I- H . CD CD CD CO O O O O C'J N CV CV (;', f"'i CO I:- d) co t7.- OD co 91 (J CJ CJ CJ _J C"J CJ CJ CJ s J J J J n .O' o o 8 B8P 0 0 0 I a, CO r. (l. u, I 1 I 1 1 1 C7 (D (D 1 V I Q n, :17:51 ( [ti, (D 1251 K. 6. [5 uJ cS R <co to �y r6. � co ctO to tO C �„�� - On O 5Q }, r a> Ex E a E D e H d Qc `. ., SCI a ID I CO r 11,46. r O eh "III t C '� (D i f <L 50§ • _ I I I 1 1 1 RS CD RSO O o O O U :< t: t: h ? Z .n o .n o u, »,n[111111y L.+ �CJ CJ • • CD v now Isd • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, August 09, 2016 9:03 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of IA and OA pressure anomaly 1L-22 (PTD 190-164) 8-9-16 Attachments: 1L-22 90 day TIO 8-9-16.PNG; 1L-22 schematic.pdf Chris, KRU WAG injector 1L-22 (PTD 190-164) is being reported for an IA and OA pressure anomaly. Yesterday the drillsite operator charged the IA so as to establish a dP across the IA and OA. Upon review of the TIO trend plot,there does appear to be a very slow rise in OA pressure with a simultaneous decrease in IA pressure. This may only be an abnormal hysteresis affect after the well was recently returned to injection after being offline for several weeks. The theory behind the abnormal hysteresis is that the OA is slowly rising in response to the well being brought online, while the IA has been decreasing and is more sensitive to localized thermal swings in injection temperature because it was recently fluid packed in early June when a passing witnessed MITIA was performed. However,we plan to confirm this theory by performing an MITOA and monitoring the well for 30 days to confirm that no communication is present. A follow-up email will be sent at the conclusion of the monitor period. Please let me rnow fyou disagree with the plan forward. Attached are the 90 day TIO plot and schematic. Kelly Lyons/ Brent Rogers s�W+.A4NEO AUG 1 1 2016 Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 1 4111 a V! Z CC CC N w w Q V = LOSW C c G NI c' 02 , r. c a 0' r. u, d 2 0? W CT:, N W % o u IV rJ ci rJ U, N 4) ID W d F to0 .„.1IJ J 1"'J J J c �o 0 n ,4444 0 Bap ap 0 0 00 0 w m I I - 04 a' 4 aC rDaAVM a_ 411 1 3 7 ite) t0 t0 Q r• C - I 4 -7 a V C •C 10 t0 cC ` 7 C C 7 E 0 to t0 L j N Q) Z C 16 ti aos es ID W - A - to a W N N t0 N r- r- 440 00 .44 in coa ' i ! f t t a iso 2 I I Ig Ilii to w E I I [ al R -O O O O O c,C� t-1z z 8 R - q. Z407 O 0 AD 0 c«u a. t N N CJ CD V3 !Sd • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday,June 09,2016 Jim Regg P.I.Supervisor �j 6 !3 1 to SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1L-22 FROM: Jeff Jones KUPARUK RIV UNIT 1L-22 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry agr- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1L-22 API Well Number 50-029-22114-00-00 Inspector Name: Jeff Jones Permit Number: 190-164-0 Inspection Date: 6/3/2016 Insp Num: mitJJ160608070738 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IL-22 Type Inj w 'TVD I 5908 Tubing 2200 - I 2200 2200 - 2200 PTD 1901640 ' Type TestLSPT Test psi 1500 -� IA 520 1 2920. 2840 - 2830 P Interval 4YRTST 1P/F OA 180 180 190 190 Notes: 1 well inspected,no exceptions noted. SCANNED DEC 2 9 2016 Thursday,June 09,2016 Page 1 of 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. PAGES TO DELETE Complete RESCAN Color items- Pages: E] Grayscale, halftones, pictures, graphs, charts- . Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type OVERSIZED .~' . . Logs 'of various kinds Other COMMENTS: Scanned by: ianna Vincent Nathan Lowell TO RE-SCAN Notes:. Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: isl • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well^ Plug Perforations ^ Stimulate ^ Other0 Repair BH tv.>~`~~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development ^ Exploratory ^ 190-164 ~ 3. Address: Stratigraphic ^ Service^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22114-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 130' 1 L-22 8. Property Designation: 10. Field/Pool(s): ADL0025660 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 10192' ~ feet true vertical 6407' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 5119' 9-5/8" 5249' 3611' PRODUCTION 10062' 7" 10192' 6416' Perforation depth: Measured depth: Intervals from: 9554'-9608' C, 9614'-9707' B, 9822'-9928' A, 9470-9472' squeezed true vertical depth: 6003'-6036' C 6039'-6095' B 6167'-6236' A {~ ~{ 1`j~f(}t /~j (~pj " ~ ~~ L ' Tubing (size, grade, and measured depth) 3-1/2 , J-55, 9466 MD. ~ ~ °` ~ Packers & SSSV (type & measured depth) Baker HB packer 9,396' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAGQ - GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: N/A contact Perry Klein/MJ Lovela Printed Name MJ LOVeI ,,~''f .-~- "Title WI Project Supervisor Signature Phone 659-7043 Date 11/13/2008 G !L • Form 10- 4 Revised 04/,004 ~ ~ ~ ~~ Submit ert~ al 0 ~4'/~f 3 r?i • . 1 L-22 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/01/08 11/05/08 11 /08/08 T/I/O = 1350/800/40.Drilled and tapped two 1/2" holes,TOC = 1".Installed nitrogen purge jewelry.Bled down IA & OA,removed VR plugs from both installed jewelry for nitrogen purge.OAFL = 4'. Cleaned braden head with wire wheel. T/I/O = 0/0/O.Started nitrogen purge on OA and conductor,.Assisted with cooper heat and monitored nitrogen purge.Made 3 weld gasses as per mechanical engineer specs. Weld completed.Reinstalled IA , OA VR plugs and normal wellhead jewelry.Final T/I/O = 0/0/0. MITOA -Passed. Initial T/I/O = 0/0/0. Pressured up IA with 2.5 bbls diesel. T/I/O = 0/0/1800. 15 min T/I/O = 0/0/1700. 30 min T/I/O = 0/0/1650. Repressured IA with 1/4 bbl diesel. T/I/O 0/0/1800. 15 min T/I/O = 0/0/1770. 30 min T/I/O = 0/0/1780. Bled down IA. T/I/O = 0/0/0. • • .t ~- .~ _. ~., ,C ~'; MEMORANDUM TO: Jim Regg \~ P.I. Supervisor ~ 1 ~+ I (~ ~~ FROM: Jeff Jones Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 11, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1L-22 KUPARUK RIV UNIT 1 U22 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ ~/L- Comm Well Name' KUPARUK RIV UNIT 1L-22 API Well Number: 50-029-22114-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ08061 0 1 14908 Permit Number: 190-164-0 / Inspection Date: 6/1/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 1L-z2 (Type Inj. `n' TVD I s9o9 - IA sso zslo zsoo i zsoo 1901640 I P.T. ITypeTest SPT Test psi 1500 A ]00 I i 100 - 140 ~i 1ao Interval 4YRTST Prn, P -/ Tubing i 1915 ~ 1915 191 191 ~ Notes' 4.l BBLS diesel pumped; one exception noted. Braden head is leaking; operator will initiate repair. Wednesday, ,tune 11, 2008 Page 1 of 1 08/22/06 Scblumbepgep "'f' ~~~ :: 'If"\ t, c) ,/ II..:J F\\.;l1 {o- cl "" RECE\VEQGJ~NNED AUG 2 3 2006 NO. 3936 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 C~·mmisslon . 0.. & Gas Cons. u :'Ja..Cj(3\1 ' Anchorage U:ï:C- lO¡Ò -/ro4 Field: Kuparuk Well Log Description Date BL CD Color Job # 2E-05 11249943 SBHP SURVEY 08/08/06 1 1J-109 11235392 CBUUSIT 08/07/06 1 30-11 11213793 LDL 08/14/06 1 2T-28 11235394 INJECTION PROFILE 08/16/06 1 1H-17 11213794 PROD PROFILE W/DEFT 08/15106 1 1 L-22 11235395 INJECTION PROFILE 08/17/06 1 1J-166 40013010 MD VISION RESISTIVITY 01/19/06 1 1 1J-166 40013010 TVD VISION RESISTIVITY 01/19/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test !§7[2.- ~{\h{04 Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us; and Jim...:.Regg@admin.state.a OPERATOR: ConocoPhillips Alaska Inc. FIELD J UNIT I PAD: KRU1L DATE: 06/14/04 OPERATOR REP: Brake I Rogers AOGCC REP: Waived Packer Depth Pretest Initial 15 Min. 30 Min. well11L-01 I Type Inj I N I T.V.D. I 5762 I Tubing I 8°1 8°1 8°1 8°llnterval 4 P.T.D. 1841730 Type Test P Test psi 1500 Casing 240 1740 1720 1720 P/F P Notes: well11 L-03A I Type Inj I S I T.V. D. I 4456 I Tubing I 255°1 255°1 255°1 2550 lnterval 4 , P.T.D. 1990370 Type Test P Test psi 1500 Casing 450 1800 1760 1760 P/F P Notes: well11L-05 1 Type Inj I G I T.V.D. I 5826 1 Tubing I 354°1 35401 3540 I 354°1 Interval 1 4 P.T.D. 1841230 Type Test P Test psi 1500 Casing 700 1740 1710 1700 P/F P Notes: well11L-07 I Type Inj I S I T.V. D. 1 5738 I Tubing I 255°1 255°1 255°1 255°1 Interval I 4 P.T.D. 1841450 Type Test P Test psi 1500 Casing 560 1740 1740 1740 P/F P Notes: well 1L-10 I Type Inj I S I TVD. 1 58661 Tubin¡¡ I 179°1 179°1 179°1 1790 lnterval 4 P.T.D. 1900350 Type Test P T est psi 15°°. Casing 1240 2500 2450 2450 P/F P Notes: well 1L-14 I Typelnj I G I T.V.D. 1 5768 I Tubing I 28°°1 28°°] 28°°1 28001'nterval 4 P.T.D. 1910100 Type Test P Test psi 1500 Casing 650 1700 1680 1680 P/F P Notes: well 1L-16 I Type Inj I N I T.V.D. I 5794 1 Tubing I 9°1 901 9°1 9°llnterval 4 P.T.D. 1841810 Type Test P Test psi 1500 Casing 125 1625 1620 1620 P/F P Notes: well 1L-17 I Type Inj I G I T.V.D. I 5868 1 Tubing J 326°1 326°1 33°°1 33oollnterval 4 P.T.D. 1910430 Type Test P Test psi 1500 Casing 725 1725 1720 1720 P/F P Notes: we1l11L-18 I Type Inj I P.T.D. 1910350 Type Test Notes: we1l11L-21DPNI Type Inj 1 P.T.D. 1910060 Type Test Notes: well 1L-22 I Type Inj 1 P.T.D. 1901640 Type Test Notes: well 1L-25 I Type Inj I P.T.D. 1910700 Type Test Notes: MIT Report Form Revised: 05/19/02 s I TV.D. I 58591 Tubing 189°1 189°1 189°1 189°I'nterva' 4 P Test psi 1500 Casing 470 2600 2550 2540 P/F P S I T.V.D. I 5769 I Tubing I 229°1 229°1 2290 j 2290 lnteNall 4 P Test psi 1500 Casing 60 1760 1760 1760 P/F P S I T.V.D. I 5909 1 Tubing 23°°1 23°°1 230°1 23001'nterval 4 P Test psi 1500 Casing 60 1760 1750 1750 P/F P N I TV.D. I 5884 I Tubing 1 125°1 12501 1250[ 12501'nterval 4 P Test psi 1500 Casing 410 1760 1720 1720 P/F P MIT KRU 1L 06-14-04.xls 6/15/2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS i..Operations Performed: Abandon ~] Suspend [--] Operation Shutdown [~] Perforate [~ Variance r-]' Annular Disp. · , . . Alter Casing . El' Repair Well [~ Plug Pe~10rations' E] stimulate.El'. Time Extension ~] Other ['~ Change Appr0ved,P~'ogram El.. Pul. I Tul~ing E] . Pe.~orate Ne~vPool . .El . ,Re-e~!er Suspended Well F-~ - 2.'Operator Name: 4..Currer~t Well· Status: .' :. ' 5. Permit to Ddll Number: ConocoPhill!ps Alaska, Inc. Development .El Exploratory E] 190-164/ 3. Address: Straflgraphic [] Service . ['~ 6. APl Number: · P. O. Box 100360 50-029-22114-00 -- 7. KB Elevation (ft): ~. Well Name and Number: RKB 122' 1 L-22 8. Property De'~ignation: 10. '~ield/Pool(s):' Kuparuk River Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured' 10178' feet true vertical 6407' feet Plugs (measured) Effective Depth measured 10073 feet Junk (measured) true vertical 6334 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SUR. CASING 5127' 9-5/8" 5249' 3611' PROD. CASING 10070' 7" 10192' 6416' Perforation depth: Measured depth: 9470- 9707 t~::~; Ii.:::., ~,!~..,..,,,~,~ true vertical depth: 5953 - 6095 AUG Tubing (size, grade, and measured depth) 3-1/2", J-55, 9466' MD. ¢,.,~¢~.~, ~.~ Ii'~li~ ~:'''' Packers & SSSV (type & measured depth) pkr= BAKER 'HB' pkr= 9396' ~t'~l~:"';!"~":~' : sssv= sssv sssv= 180e' · !'2.. Stimulation o'r cemeht'squee~e sgmmary: .. .:' .. . .. . . .... Intervals treated (m'e~uied) .' N/A " .." .. · . ... · . .. .. · · . · Treatment'descriptions inc!uding volumes'used and final pressure: ": ..... .. · · · .. . .. .. · .... .. · . . · . .. , '' · .!3. ' ' : .... ... ' .. .'" 'R~prbse'ntativb:D~ily AVerage Produ=ction or Injecii0n Dat. a. '. .". ..... ·. .. .. Oil-B'bl =' .G~t's-Mcf' " Water-Bbl . ' ' .' Casin',q'P~',essure T~bing' Pressure · Prior to well operation. ,. : '.... i 'l · ':2~.22.. '..' . "'. ".i00 "2412 ' · · ... Subse.quenl~ tO 9peration .. = . 4819 ....... 100 ':'. 368'9. · ...... 14. Attachments · · . .15.' Well .Class' afte[ proposed Work: .. ' ..... ". .... · · . Copies of Logs and SUrveys run_. .' 'Explomt0ry' I-'i Development' I-1 Service · .... · . · . :. · . Daily Report Of Well Operations _X 16. well Siatus after pi'oposed work: o,r--1 GasFI WAGI- '" G NJI]' w uJ.F1 w SPLE] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.C. Exempt: I Contact Jeff Spencer @ 659-7226 Printed Name,,~ I:~oli;tcrt D. Ch~;istensen Production Engineering Technician Form 10"404 AUG g 0 2003 ORiGiNAL 1 L-22 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/011031Commen'C~ed WAG EOR Injection .. "' I MEMORANDUM TO: Dan Seamount~ Commissioner THRU: BlairWondzell .~.~ P.I. Supervisor . o/~(-~(orO FROM: John CrisP: ,~,~,~ ~_ Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation CommisSion DATE: September 11,2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 1L Pad 16,17,18,21,22 Kuparuk River Unit Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI 1L-16 I Typelnj. I S I T.V.D. 15800 I Tubingl 2650 I2~S0 12~S0 I '2SS0 I,nterva,I 4 I __P'T'6'I 1841810 ITypetestl P I Testpsil 1450' ! CasingI. 490 I 1675 I 1630 I 1625I. P/FI N~tes: ' ' '-' -- ITypelnj. I S I T.V.D.I 5871 ITUbingl 2475'[ 2475 12475 12475 Ilntervall WellI 1L-17 ITypetest[ P I Testpsil 1468 ICasing'I 600 I 15501 15401 15201 P/F' /'P J P.T.D.I 1910430 .... Notes: V~e,I 1L-18 I Type,nj.! S I,.v.o. i= .oI lntervall 4 p'.T.D.I 1910350 ITypetestI .P., I TeSt psiI 1464 I C'asing I 500 I 1580 I 1560 I 155° I" P/F I --P Notes: . ' WellI 1L-21I Tvp.,,i.I s'IT.V.D. I,%,1 I I = -llnterVall4 P.T.D.I 1900540 ITypetestJ P ITestpsil' 1420 I Casihgl 520 I 1590 I 168o11576'1 PIE I Notes: WeliI 1L-22 ITypelnj. I N ITubingl 1300 11325'I 1325 11325 Ilntervall 4 P.T.D.! 1901640 ITypetest'I P ITestpsil 1481' I Casing.} 520 115'9oI 1580I 1575I p/I~ I --P' Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G -- GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test' Interval · I= Initial Test : 4= Four, Year Cycle V= Required by Variance W= Test during Workover O= Other describe in notes) Test's Details No failures witnessed. Testing went well with no problems.encountered. .I.T.'s performed: S__ Attachments: Number of Failures: 0 'Total Time dudng tests: 2. hrs. cc: MIT report form 5/12/00 L.G. MIT KRU 1 Lb 9-11-00jc.xls 9/13/00 To: Wc:li Name Log 'l'ypn Run l)atr. NJver iJnit i i:.- 1A River Unit 1A-.Il River Unit 11.-10 i~ivcr Unit 11..-14 River U,tit 11:22 River Unit 1R 04 River Unit 1Y-10 l{iver Unit 2B-08 River Unit 20-02 Rive, Unit 2C-04 hirer Unit 2C 05 River Unil 2C--06 River Unit 2V-13 trivet Unit 30-12 River Unit 3G-20 Water i"iow I.og ('i'i)'i'--P') Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile if1 ~; on t'rollle Injection Profile Injection Profile Injection Profile Injection Profile Injectio. Profile Suwey Injection Profile Sup'ey Injection Profile Pmduclion Production Log Injection Profile Injection Profile Survey Injcclion Profile 07.IAN 1991 10-1--91 03 NOVEMBER 1991 4 NOVEMBI£R 1991 4 NOVEMBER 1991 11 --06.. 1991 6130191 12--13-.-1991 i 1-19-9i 11- 1%1991 12--2-91 12--27-.1991 26 DEC 1991 10-27--1991 11/25/91 11--16~1991 8-.IIJNE~I g91 314ULY-.1991 11 NOV 1991 101119/91 11 -29-1991 R;~ceived by:. ~~ Dated: Copy sent to sender: Yes ¢'/ No ~ RECEIVED MAR 2_ 6 1992_ Alaska 011 & Gas Cons. Commission Anchorage ~ OIL AND GAS ~SERVATION COMMI,.~oiON '~,/'" REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing . Alter casing Stimulate m Plugging Perforate ~X Repair well Other 2. Name of Operator ARCO Alaska, Ins. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 445' FNL, 217' FWL, Sec. 32, T11N, R10E, UM At top of productive interval 1270' FSL, 867' FWL, Sec. 33, T11N, R10E, UM At effective depth 1044' FSL, 1195' FWL, Sec. 33, T11N, R10E, UM At total depth 1001' FSL, 1257' FWL, Sec. 33, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 1 01 76' feet Plugs (measured) 6404' feet 6. Datum elevation (DF or KB) 122' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1 L-22 9. Permit number/approval number 90-164 10. APl number 50-029-2;~114 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 10073' feet Junk (measured) true vertical 6334' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 122' 1 6" 214 Sx Cold Set II 122' 5245' 9 5/8" 1200 Sxv AS III & 5245' 600 Sx Class G 1 01 60' 7" 375 Sx Class G 1 01 60' measured 9554'-9608',9614'-9625',9822'-9850',9914'-9928' true vertical True vertical depth 122' 3608 6394 6002'-6034',6038'-6045',6166'-6185',6226'-6236' Tubing (size, grade, and measured depth) 3 1/2" 9.3#, J-55, 9466' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSSV, 1808', Packer: 13. Stimulation or cement squeeze summary Perforated "C" Sand @ 6 SPF on 4/1/91 Intervals treated (measured) 9554'-9608',961 4'-9625' Treatment description including volumes used and final pressure N/A Baker HB, 9396' 14. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 126 63 0- 200 Tubing Pressure 0- Subse~ )eration 8 5 0 4 2 0 0 - 0 - 7 0 0 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Water Injector Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 300 Service 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, In~-~ ~. Subsidiary of Atlantic Richfield Compar,~ WELL IPBDT /Z- gz- /0: .,.-~ITRACTOR REMARKS WELL SERVICE REPORT IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME o~iq'7 / o/0 r--i CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather , Temp. 1 Chill Factor I Visibility JWlnd Vel. Report i - '/c 'F -/~, 'Fl ~ miles · knots ISig~3e~ - -- '"T' .... 7J- ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate m Plugging Pull tubing Alter casing Repair well Perforate _ Other X 2. Name of Operator ARCO Alaska,, Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 5. Type of Well: Development ----X-. Exploratory _ Stratigraphic Service 4. Location of well at surface 445' FNL, 217' FWL, Sec. 32, T11N, R10E, UM At top of productive interval 1270' FSL, 867' FWL, Sec. 33, T11N, R10E, UM At effective depth 1044' FSL, 1195' FWL, Sec. 33, T11N, R10E, UM At total depth 1001' FSL, 1257' FWL, Sec. 33, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 1 01 76' feet Plugs (measured) 6404' feet 6. Datum elevation (DF or KB) RKB 1 2 2 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1L-22 9. Permit numl)er/approval number 90-164 / ~/I-233- 10. APl number 50-029-22114 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 1 0073' feet Junk (measured) true vertical 6334' feet Casing '-. Length Size Cemented Structural Conductor 1 22' 1 6" 214 Sx CS II Surface 5246' 9 5/8" 1200 Sx AS III & Intermediate 600 Sx Class G Production 1 01 61 ' 7" 375 Sx Class G Liner Perforation depth: measured 9554'-9608' 9614'-9625' ! 9822'-9850', 9914'-9928' true vertical 6166'-6236', 6002'-6045' Tubing (size, grade, and measured depth) 3 1/2" J-55 set at 9465' Packers and SSSV (type and measured depth) Baker HB @ 9396', Camco TRDP-1A-SSA @ 1808' 13. Stimulation or cement squeeze summary Intervals treated (measured) Measured depth True ve~ical depth 122' 122' 5246' 3608' 10161' 6394' 6 SPF 0 degree phasing 4 SPF 180 degree phasing RECEIVED S E P 1 2 t991 .& Gas Cons. Commission :Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 866 4477 0- 500 270 Subsequent to operation -0- 0- 1700 0 2300 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector X Oil m Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. --orm 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMIS,~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska. Inc. Exploratory _ RKB 122 feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 445' FNL, 217' FWL, Sec. 32, T11N, R10E, UM, 1L-22 At top of productive interval 9. Permit number 1270' FSL, 867' FWL, Sec. 33, T11N, R10E, UM 90-164 At effective depth 10. APl number 1044' FSL, 1195' FWL, Sec.33, T11 N, R10E, UM so-2211 4 At total depth 11. Field/Pool Kuparuk River Field 1001' FSLr 1257' FWL~ Sec. 33~ T11Nr R10E~ UM Kuparuk River Oil Pool 12. Present welI condition summary Total Depth: measured 1 01 76' feet Plugs (measured) true vertical 6404' feet NOlle Effective depth: measured 10,073'feet Junk (measured) true vertical 6 3 3 4' feet NOne Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 22' 1 6" 214 Sx CSII 1 22' 1 22' Surface 5246' 9 5/8" 1200 Sx AS III & 5246' 3608' Intermediate 600 Sx Class G · Production 1 0,1 61' 7" 375 Sx Class G 1 0,1 61' 6 3 9 4' Liner Perforation depth: measured 9822-9850 4 SPF 9914-9928 4 SPF 9554-9608 6 SPF 9614-9625 6 SPF 9016-9024 /]~Ska'- -- 0it ,~,~ ,,:?,, ,-, true vertical 6166'-6236', 6002'-6045', TVD ..~..,~,.,~.~,o Tubing (size, grade, and measured depth) 3 1/2" J-55 set at 9465' Packers and SSSV (type and measured depth) Baker HB @ 9396' Camco TRDP-1A-SSA @ 1808' 13. Attachments. Description summary of proposal _ Detailed operation program _ BOP sketch_ Convert well from oil producer to water injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: Au(]ust. 1991 Oil ~ Gas ~ Suspended _ 16. If proposal was verbally.,,,, --./appr°ved ~:~'_~_¢~1 Name of approver ,L,)- ~J'""~r/1, A,6 ~ Date approved Service Water Iniector . - 17. I hereb f"~ertify that_the foregoing is true and correct to the best of my knowledge. Sic]ned ~ J~ '~' ~ Title Senior Operations Engineer Date ~"'l"~/f FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApprow~No. Plug Integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form-require 10-,~__<:~/~/~ ~ ~. [ Approved by order of the Commission Commissioner Date Form 10-403 Rev 09/12/90 Approvect Copy SUB TRIPLICATE P~eturrled ~ ,, ~ ~,id W. ,l~hnston , Spud Date: 1 2 - 1 6 - 9 0 Completion Date: 1 - 2 6 - 9 1 Maximum Hole Angle: 5 9 Original Rig RKB: 37.1 5' All depth are RKB MD to top EL 1 5,6 ARC(, .LASKA INC. - KUPARUK FI ) APl# 50-029-22000-00 C Sand: NOT PERFED A Sand: ~ deg. @ 3711' MD of equipment. Well Type: OIL Tree Type: FMC GEN IV Tree Cap Type: Tree Cap Size: Tree Cap O-ring ASN: Last Workover Date: 1 - 2 6 - 9 1 Jewelry 1 SSSV: CAMCO TRDP-1A-SSSV 2.812" ID @ 1808' 2 PBR: BAKER 3.5" ID @ 9382' 3 PKR: BAKER HB 3.5 ID @ 9396' 4 NC)GO: CAMCO'D' NIPPLE 2.750" ID @ 9432' 5 SHEAR OUT: BAKER @ 9465' 8 TUBING TAIL: @ 9466' Minimum ID:2.750" NOGO Casing and Tubing Size Weight Grade Top Bottom 9.625" 36# J-55 0 5244' 7" 26# J-55 0 10159' 3.5" 9.3# J-55 0 9433' Description CASING CASING TUBING Gas Lift Information De_oth Stn# Valve Ty_~e Sz. 2128' I D/V 1 ' BK2 9338' 2 D/V 1.5" F~ Port Sz. AID# Perforation Data Interval SPF Date Phase ET. 9554-9808 6 4-01-91 0 54 9614-9625 6 4-01-91 0 1 1 9822-9850 4 1-24-91 180 28 9914-9928 4 1-24-91 180 14 C C A A Date Run Comments Comments: LAST TAG: 9871' ON 4-21-90 PBTD: 10076' LAST REVISION: 7-19-91 STATE OF ALASKA ~ ~ ! ~ AL~r,,A OIL AND GAS CONSERVATION COM,v~;.SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL r-~ GAS ~] SUSPENDED E~ ABANDONED ~] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-164 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22114 4 Location of well at surface 9 Unit or Lease Name 445' FNL, 217' FWL, SEC 32, T11N, R10E, UM~:' ~"'~;~"~'~'~1-~ ,:~., .' ' ~' ;~~-'~-~'~ 'L~.-,~,~ ~.'~'~-.~ '~ '~ KUPARUK RIVER At Top Producing Inte~al ~ ~-.~.~ ~. ~ , ~"~'-::~-~ ~. 10 Well Number 1270'FSL, 867'FWL, SEC~,T11N, R10E, UM ~ ........ :~ { ~~ 1L-22 A~Total Depth ~ ~]~,~h~ '~, ~ :;'~ 11 Field and Pool 5 ~levation in feet (indicate KB, DF, etc.) 6 Lea~ D~ignaaon and ~Hal ~. KUPARUK RIVER OIL POOL RKB 122', PAD 86' GL ADL 25~0 ALK 470 1 ~16/90. 1 ~27/90. 1126/91.~ NA feet MSLI 1 17 Total Dep~ (MD+~D) 18 Plug ~ck ~pth (MD+~D) 19 Direc~o~l Su~ey 20 Dep~ where SSSV set ~ 21 Thickness of permafrost 10176' MD, 6404' ~D 10073' MD, 6~4' TVD YES ~ NO ~ 1~08' feet U D~ 15~0' APPROX 22 Ty~ El~tdc er Other Logs Run DI~SFL, LDT, CNL, CET, CBL, GYRO 23 CASING, LINER AND CEME~ING RECORD S~ING DEPTH MD CASING SIZE ~. PER ~. GRADE TOP ~ HOLE SI~ CEMENTING RECORD AMOU~ PULLED 16" 62.5~ H-40 SURF 122' 24" 214 SX COLD SET II 9-5/8" 36~ J-55 SURF 5246' 12-1/4" 12~ SX ASIII, 600 SX C~SS G 7" 26~ J-55 SURF 10161' 8-1/2" 375 SX CLASS 24 Perorations open to Production (M~D of Top and BoEom and 25 ~BING RECORD inte~al, size and number) SIZE DEPTH S~ ~MD) PACKER SET {MD) ~1/2" 9465' 9396' 9822'-9~0' W/4-1/2" CSG GUN ~ 4SPF MD 61~'-6185' ~D 26 ACID, F~CTURE, CEME~ SQUEEZE, ETC 991~'-9928' W/4-1/2" CSG GUN ~ 4SPF MD 6226'-6~6' ~D DEP~ I~ERVAL {MD) AMOU~ & KIND OF MATERIAL USED SEE ATTACHED ADDENDUM 27 PROD~TION ~ST Date First Production ~Me~od of Opera, on (Flowing, gas li~ etc.) I Date of Test HoursTest~ PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD ~ FIowTubing Casing Pre,ute CALCU~TED OIL-BBL GA~MCF WATER-BBL OILG~VITY-API (co,r) Press. 24-HOUR RATE ~ 28 CORE DATA Bdef description of li~ology, porosi~, fractures, apparent di~ and pres~ce of oil, gas or water. Submit core chips. . . , ', : .., .~ ~ . .~ .. ~ ..,-...~/;'~. ' . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 9555' 6003' NA KUPARUK C BOTTOM 9598' 6028' KUPARUK A TOP 9795' 6149' KUPARUK A BOTTOM 9930' 6237' 31. LIST OF ATTACHMENTS GYRO, FRAC, & WELL HISTORY ,32. I hereby certify that the foregoing is true and correct to the best of my knowledge ,, INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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 pedinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 3/11/91 1 L-22 Frac KRU "A" sand perfs from 9914'-9928', 9822'-9859' @ 4spf in 10 stages as follows: Stage 1. Pmp Stage 2 Pmp Stage 3 Prnp Stage 4 Pmp Stage 5 Pmp Stage 6 Pmp Stage 7 Pmp Stage 8 Pmp Stage 9 Pmp Stage 10 Pmp Pmp Pmp Average Pressure: Fluid to recover: Sand in zone: Sand in casing: 150 bbls Surf XLGW @ 25 bpm 7000-6800 psi 84 bbls Non XLGW @ 25 bpm 6800-5150 psi 800 bbls Sud XLGW @ 25 bpm 5500-5800psi 150bbls Surf XLGW w/2ppg Carbolite @ 25 bpm 5800psi 125bbls Surf XLGW w/4ppg Carbolite@ 25 bpm 5700 100 bbls Sud XLGW w/6ppg Carbolite @ 25 bpm 5800psi 75 bbls Surf XLGW w/Sppg Carbolite @ 25 bpm6250 psi 50 bbls Surf XLGW w/10ppg @ 25 bpm 6600 psi 25 bbls Surf XLGW w/12ppg @ 25 bpm 6650 psi 12 bbls Sud XLGW @ 25 bpm 6400 psi 12 bbls Non XLGW @ 25 bpm 6300 psi 20 bbls Slick Dsl @ 25 bpm 6100 psi 6,037 psi 1,660 90,828 Carbolite 0 Drilling S~~pe ' tendent ~ Date ARCO ALASKA INC. DAILY OPERATIONS BOROUGH: NORTH SLOPE FIELD: KUPARUK RIVER FIELD UNIT: KUPARUK RIVER LEASE: ADL 25660 ALK 470 API: 50-029-22114 WELL: KRU 1L-22 PERMIT/APPROVAL: 90-164 AFE: AK4877 WI: 55.252072 SPUD/ACCEPT WO: 12/16/90 COMPLETE/RELEASE: 12/28/90 OPERATION: DRILL RIG: POOL 7 12/16/90 (1) TD: 122' ( 122) SUPV:CTD/SAK 12/17/90 (2) TD: 354' ( 232) SUPV:CTD/SAK 12/18/90 (3) TD: 1931' (1577) SUPV:CTD/SAK 12/19/90 (4) TD: 4075' (2144) SUPV:CTD/SAK 12/20/90 (5) TD: 5625' (1550) SUPV: JT 12/21/90 (6) TD: 5265'( SUPV:JT o) NU DIVERTER MIX MUD 16"@ 115' MW: 0.0 VIS: 0 MOVE TO 1L-22 & SET IN PLACE, NU DIVERTER & MIX MUD, RIG ACCEPT 16-DEC-90 0100 DAILY:S10,593 CUM:$10,593 ETD:S10,593 EFC:$1,670,300 RIG REPAIR, CHANGE OUT HYDRILL 16"@ 115' MW: 8.8 VIS: 91 FINISH NU DIVERTER, MU BHA, ORIENT MWD, TEST DIVERTER, DRILL F/96'-125', RIG REPAIR, WORK ON TOP DRIVE, CIRC TO BOTTOM, DRILL 125'-354', LOST RETURNS WHILE DRILLING, POH COULD NOT GET 12-1/4" THRU HYDRILL, HYDRILL HAD CLOSED WHILE DRLG CAUSING LOSS OF RETURNS, 100 BBL MUD TO FORMATION, DIVERTER VALVES DID NOT OPEN WHEN HYDRILL CLOSED, APPEARS HYDRILL MALFUNCTION INTERNALLY OR CONTROL LINES NOT PROPERLY INSTALLED DAILY:S59,582 CUM:$70,175 ETD:S70,175 EFC:$1,670,300 DRILLING 16"@ 115' MW:10.0 VIS: 66 ND HYDRILL, CONTROL LINES IMPROPERLY INSTALLED, WAIT ON NEW HYDRILL, NU HYDRILL, CONFIRM OPERATION OF CONTROL PANEL, FUNCTION TEST DIVERTER, TIH TO 354' KICK OFF & DRILL W/ 12-1/4" BH DYNA DRILL F/345'-1931' DAILY:S65,108 CUM:$135,283 ETD:S135,283 EFC:$1,670,300 POOH FOR BIT 16"@ 115' MW:10.0 VIS: 46 DIRECTIONAL DRILL W/DYNA DRILL F/1931'-4075', ROP 148 FT/HR, PUMP SLUG, TOH F/BIT #2, TIGHT HOLE PULLING THRU KICK OFF DEPTH DAILY:S57,865 CUM:$193,148 ETD:S193,148 EFC:$1,670,300 TOH 9-5/8"@ 5246' MW:10.1 VIS: 53 TRIP FOR NEW BIT. DRLD F/4075-5265' (7.5 HR ADT). CIRC AND COND HOLE. SHORT TRIP TO HWDP. ~ULLING TIGHT, FREED UP AFTER 1900' DAILY: $60,475 CUM: $253,623 ETD: $253,623 EFC:$1,670,300 DISP SURF CMT JOB 9-5/8"@ 5246' MW:10.0 VIS: 40 FINISH SHORT TRIP. CIRC AND COND. POH. RU AND RUN 108 JTS 9-5/8" 36 PPF J-55 BTC CSG. LOST RETURNS @ 4579'. WATER BACK MUD. RAN REMAINDER OF CSG, TOTAL OF 126 JTS. CIRC AND COND. PRESS TEST CMT EQUIP. MIX AND PUMP 1200 SX PERMAFROST E AND 600 SX CLASS G + 2% CC @ 5-6 BPM AND 600 PSI. LOST RETURNS 198 BBL INTO 395 BBL DISPLACEMENT. DISP W/FW. DAILY:S49,309 CUM:$302,932 ETD:S302,932 EFC:$1,670,300 WELL: KRU 1L-22 OPERATION: DRILL RIG: POOL 7 PAGE: 2 12/22/90 (7) TD: 5164'( SUPV:JT o) TESTING BOPE 9-5/8"@ 5246' MW: 0.0 VIS: 0 DISPLACE CEMENT AT 5-6 BPM WITH WATER, BUMP PLUG TO 1600 PSI WITH 397.5 BBL. FLOATS OK, ND DIVERTER, PERFORM TOP JOB, NU SPEED HEAD, NU BOPE, TEST WITNESS BY AOGCC. DAILY:S249,777 CUM:$552,709 ETD:S552,709 EFC:$1670,300 12/23/90 (8) TD: 5438' ( 274) SUPV:JT DRILLING AT 5438' 9-5/8"@ 5246' MW: 8.5 VIS: 60 TEST BOPE WITNESSED BY MR. GRINWALDE WITH AOGCC. MU BHA WITH MUD MOTOR AND RLL LOGGING TOOL. RIH AND TAG CEMENT, DRILL FLOAT COLLAR AND TEST CASING TO 2000 PSI. DRILL OUT 10' OF NEW FORMATION TO 5275' PERFORM FORMATION INT- GRITY TEST TO 12.5 PPG EMW, NO LEAK OFF. DRILL FROM 5275' TO 5438' · DAILY $58,498 CUM:$611,207 ETD:S611,207 EFC:$1,670,300 12/24/90 (9) TD: 8014' (2576) SUPV: JT 9-5/8"@ 5246' MW: 9.2 VIS: 46 DRILL FROM 5438' TO 8014' ADT= 17 HRS, ROP = 152 FT/HR. DAILY:S46,151 CUM:$657,358 ETD:S657,358 EFC:$1,670,300 12/25/90 (10) TD: 9180' (1166) SUPV:JT TRIP TO CO BHA 9-5/8"@ 5246' MW:10.1 VIS: 48 DRILL FROM 8014' TO 9180'. CBU, POH TO 5160', PERFORM FORMATION INTEGRITY TEST TO 10.9 PPG EMW. POOH TO CHANGE BHA TO ROTARY. DAILY:S46,151 CUM:$703,509 ETD:S703,509 EFC:$1,670,300 12/26/90 (11) TD: 9889' ( 709) SUPV:JT DRILLING AT 9889' 9-5/8"@ 5246' MW:10.3 VIS: 44 LOADED LOGGING TOOL, TIH TO 8900' REAM FROM 8900' TO 9180' , DRILL FROM 9180' TO 9889' · DAILY:S84,587 CUM:$788,096 ETD:S788,096 EFC:$1,670,300 12/27/90 (12) TD:10176' ( 287) SUPV:CTD TIH FOR WIPER TRIP 9-5/8"@ 5246' MW:10.4 VIS: 40 DRILL FROM 9889' TO 10176' TD. POOH, LD LOGGING TOOL AND DOWN LOAD LOGS. ROAD TO DEADHORSE IS CLOSED, CAN NOT GET HALLIBURTON AND CASING CREWS TO LOCATION. RIH WITH ROCK BIT WHILE WAITNIG ON ROAD TO BE CLEARED. DAILY:S75,533 CUM:$863,629 ETD:S863,629 EFC:$1,670,300 12/28/90 (13) TD: 10176' ( SUPV: CTD o) CIRC 7" CASING 9-5/8"@ 5246' MW:10.5 VIS: 44 CONT TIH WHILE WAITING FOR SPINE ROAD TO OPEN. REAM FROM 10100' TO 10176' TD. CIRC AND CONDITION MUD, SPOT DIESEL PILL AND POOH. RU CASING CREWS, RUN 239 JTS 7' 26# J-55 BTC CASING. SET AT 10160'. RU HALLIBURTON, CIRC 7' CASING WITH 20% RETURNS. DAILY:S118,159 CUM:$981,788 ETD:S981,788 EFC:$1,670,30 12/29/90 (14) TD:10176' ( SUPV:CTD FINAL REPORT / RIG REL 9-5/8"@ 5246' MW:10.6 VIS: 0 0) CIRC 7" CSG W/10% APPROX RETURNS. TEST LINES TO 4000 PSI. PUMP 10 BBL ARCO PREFLUSH. PUMP 35 BBL HALLIBURTON DUAL SPACER. MIX AND PUMP 375 SX CL G + .2% CFR 3 + .5% GEL + .6% LAP-1 + .18% HALAD 344 + .11% LWL @ 15.8 PPG. DISP ~'W/10.6 PPG BRINE. BUMPED PLUG. FLOATS HELD. RAN OUT OF .~'~'<..BRINE 371 BBL INTO DISPLACEMENT. FINISHED DISP W/ll BBL FW. "~'"' "'' RD CMT HEAD. BLOW OUT 80' OF FW OUT OF 7" CSG. PU BOP ~ ~ STACK. ~.~SET SLIPS· CUT 7" CSG. SET BACK 7" BOP STACK· - ~ATTEMPT~To INSTALL PRIMARY 7" FMC PACKOFF PACKOFF WOULD !'~~NO~-!GO OVER STUB. TAKE PACKOFF TO ARCO SHOP TO MACHINE IT TO '- F.I~T OVER 7" CSG. INSTALL PACKOFF. NU FMC 11" 3000 X 7-1/16" :-~ :i,~i~"000 TBG SPOOL. ATTEMPT TO TEST PACKOFF WOULD NOT TEST . · - ~.~?~.~..gEMOVE TBG SPOOL, RETORQUE PACKOFF, REINSTALL SPOOL, TEST TO ~/.i~, i.."3000 PSI OK. NU LOWER TREE. FREEZE PROTECT 1L-22 W/60 BBL ~iI~--~' ~ DIESEL. RIG REL MIDNIGHT 28-DEC-90. DAILY:S262,499 CUM:$1,244,287 ETD:S1,244,287 EFC:$1,670,30 S I GNATURE: DATE: TITLE: DRLG SUPERINTENDENT ARCO ALASKA INC. DAILY OPERATIONS BOROUGH: NORTH SLOPE FIELD: KUPARUK RIVER FIELD UNIT: KUPARUK RIVER LEASE: ADL 25660 ALK 470 API: 50-029-22114 WELL: KRU 1L-22 PERMIT/APPROVAL: 90-164 AFE: AK4877 WI: 55.252072 SPUD/ACCEPT WO: 01/19/91 COMPLETE/RELEASE: 01/26/91 OPERATION: COMPLETION RIG: AUDI 4 01/19/91 (15) TD:10176 PB: 0 SUPV:BB 01/20/91 (16) TD:10176 PB:10077 SUPV:BB 01/21/91 (17) TD:10176 PB:10077 SUPV:BB 01/22/91 (18) TD:10176 PB:10077 SUPV:BB 01/23/91 (19) TD:10176 PB:10077 SUPV:BB RIG UP 9-5/8"@ 5246' MW: 0.0 WAIT ON SECURITY FOR ESCORT FROM PBU TO KRU, RIM SPLIT ON INSIDE DUAL, BLEW OUT TUBE, SHUT DOWN TO CHANGE TIRE AND WHEEL, FINISH MOVING RIG TO LOC, RIG UP DAILY:SO CUM:$1,244,287 ETD:S1,244,287 EFC:$1,670,300 PICKING UP 3-1/2" DP 9-5/8"@ 5246' MW:10.6 NaCl/Br FIHISH SPOTTING RIG ON WELL, ND DRY HOLE TREE, NU BOP, TEST BOPE, MAKE UP BIT AND 7" SCRAPER, STRAP DP, RIH W/ DP DAILY:S14,147 CUM:$1,258,434 ETD:S1,258,434 EFC:$1,670,300 RIH W/ EZSV STINGER 9-5/8"@ 5246' MW:10.6 NaCl/Br SEVICE RIG, FINISH RIH TO 9800' CIRC BTMS UP, PUMP PILL, POH AND LAY DOWN BIT AND SCRAPER, ND DRILLING NIPPLE AND NU SHOOTING FLANGE, RU SLS E-LINE, RIH W/ GR/JB TO 9800', POH, RIH W/ 7" EZSV AND SET AT 9707', TEST CSG TO 3500 PSI (OK), RUN IN HOLE WITH PERF GUNS, PERF: 9680'-9682' AND 9470'-9472', POH (ALL SHOTS FIRED), RIH WITH EZSV AND SET AT 9505', POH WITH DRILL PIPE, RD SLS E-LINE, RUN WEAR RING, MU HOMCO EZSV STINGER ON 3-1/2" DP, RIH DAILY:S73,844 CUM:$1,332,278 ETD:S1,332,278 EFC:$1,670,300 DRILLING CEMENT 9-5/8"@ 5246' MW:10.6 NaCl/Br SERVICE RIG, RIH W/ HOWCO EZSV STINGER AND TAG CMT RETAINER AT 9486' RKB, STING INTO RET, ESTABLISH INJ RATE, BATCH MIX CMT, STING OUT OF RETAINER, PUMP 15 BBLS H20 - 20 BBLS CMT -10 BBLS H20 - 20 BBLS BRINE AND STAB INTO RET, SQUEEZE 17 BBLS CMT TO PERFS, PULL OUT OF RETAINER, REVERSE OUT (NO CMT RETURNS), BATCH MIX 20 BBLS CMT, PUMP 15 BBLS H20 - 20 BBLS CMT - 10 BBLS H20 - 20 BBLS BRINE, POH 7 STDS DP, REVERSE OUT (NO CMT RETURNS), CLOSE HYDRIL AND SQUEEZE AWAY 10 BBLS AT 1/4 BBLS/MIN, HELD 3,000 PSI FOR 4 HRS, SLIP AND CUT DRILLING LINE, POH AND LAY DOWN STINGER, PICK UP BHA #3 AND RIH, TAG CMT AT 09:30, DRILL OUT SOFT CMT DAILY:S107,754 CUM:$1,440,032 ETD:S1,440,032 EFC:$1,670,300 POH 9-5/8"@ 5246' MW:10.6 NaCl/Br SERVICE RIG, DRILL SOFT CMT: 9174'-9290' FIRM AT , 9280'-9480', CIRC BTMS UP, TEST SQUEEZE TOP SQUEEZE PERFS (GOOD), DRILL 6' CMT AND TAG EZSV AT 9468', DRILL EZSV, DRILL JUNK AND CMT TO 9688'-9707', TEST SQUEEZE BTM SQUEEZE PERFS, GOOD TEST, DRILL EZSV AT 9688', RIH AND TAG BTM AT 100703' DAILY:S27,668 CUM:$1,467,700 ETD:S1,467,700 EFC:$1,670,300 WELL: KRU 1L-22 OPERATION: COMPLETION RIG: AUDI 4 PAGE: 2 01/24/91 (20) TD:10176 PB:10077 SUPV:KKL 01/25/91 (21) TD:10176 PB:10073 SUPV:KKL 01/26/91 (22) TD:10176 PB:10073 SUPV:KKL POH LD DRILL PIPE 9-5/8"@ 5246' MW:10.6 NaC1/Br SERVICE RIG, POH W/ BHA #3, CLEAN JUNK BASKETS, MU BHA #4 AND RIH, TAGGED FILL AT 10071', FILTER BRINE IN PITS, REVERSE CIRC TO FILTER BRINE, BRING BRINE UP TO 10.6 PPG, POH AND LD DRILL PIPE DAILY:S37,675 CUM:$1,505,375 ETD:S1,505,375 EFC:$1,670,300 RD SOS 9-5/8"@ 5246' MW:10.6 NaCl/Br SERVICE RIG, FINISHED POH AND LD DP, PULL WEAR RING, ND FLOW NIPPLE, NU SHOOTING FLANGE, RU SOS, RUN GUN #1 (DID NOT FIRE WET), RUN GUN #2: PERF 9850'-9830' @ 4SPF, RUN GUN #3: PERF 9830'-9822' @ 4 SPF, RUN GUN #4:9914'- 9928' @ 4 SPF, RD SOS E-LINE UNIT SERVICE RIG, FJPOH LD DP & DC, PULL WEAR RING, ND FLOW NIPPLE, NU SHOOTING FLANGE, RU SOS, RIH & PERF FROM 9822'-9850', 9914'-9928' @ 4 SPF, RD SOS DAILY:S29,688 CUM:$1,535,063 ETD:S1,535,063 EFC:$1,670,30 RELEASE RIG 9-5/8"@ 5246' MW:10.6 NaCl/Br SERVICE RIG, RAN 303 JTS OF 3-1/2" 9.3#, J-55 ABMOD TBG TO 9466', SSSV @ 1808' BAKER HB PKR @ 9396', MU FMC HANGER & TEST SSSV TO 5000PSI, LAND TBG, RILDS, DROP SS BALL, PRESS TBG TO 2500 PSI & SET PKR, HELD 10 MIN, PRESS ANN TO 1000 PSI FOR 10 MIN, BOLDS, PU HGR & SHEAR PBR W/40 K# OVERPULL, RELAND TBG & PRESS TO 1000PSI, CLOSE SSSV, BLEED OFF TO 500 PSI HOLD 15 MIN, REPRESS OPEN SSSV, BACK OFF LNDG JT, ND BOPE, NU TREE, TEST TREE, PO, CL, PRESS ANN TO 2500 PSI FOR 15 MIN, SHEARED OUT SHEAR SUB @ 3800 PSI, DISPLACE ANN W/12 BBLS DIESEL, BULLHEAD 4 BBL DIESEL DOWN TBG @ 1500 PSI, SICP=1200PSI, SITP=1200PSI, SET BPV SECURE WELL, RELEASE RIG 1/26/91 @ 04:30 DAILY:S199,138 CUM:$1,734,201 ETD:S1,734,201 EFC:$1,670,300 SIGNATURE: DATE: TITLE: DRLG SUPERINTENDENT SUB. SURFACE DIRECTIONAL SURVEY ~UIDANCE [~]ONTINUOUS r'~OOL Company ARCO ALASKA, INC. Well Name 1L-22 /445' FNL~ 217' FWL~ SEC 32r Fl~ld/Loc~tlon KUPARUK~ NORTH SLOPE~ ALASKA T11N] RIOE) Job Reference No. 74373 Logaed FORMICA Date · 6-JAN-91 Computed By: KRUWELL * SCHLUMBERGER * , * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. 1L-22 KUPARUK NORTH SLOPE, ALASKA SURVEY DATE: 06-JAN-91 ENGINEER: J. FORMICA METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- LINEAR HORIZ. DIST. Averaged deviation and azimuth PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 56 DEG 51MIN EAST ARCO ALASKA INC. 1L-22 KUPARUK NORTH SLOPE, ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 200 O0 300 O0 40O O0 500 O0 600 O0 700 O0 800 O0 900 O0 COMPUTATION DATE: 28-FEB-91 PAGE 1 DATE OF SURVEY: 06-JAN-91 KELLY BUSHING ELEVATION: 122.00 FT ENGINEER: J. FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HoRIz. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 0 0 N 0 0 E 0 15 S 82 21 W 0 21 S 68 2 W 0 24 S 59 17 W 98 1 21 S 22 51 E 72 6 17 S 37 5 E 01 7 7 S 37 50 E 09 8 34 S 43 34 E 70 10 49 S 47 57 E 23 14 58 S 53 14 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 0.00 -122 O0 99.99 -22 01 199.99 77 99 299.99 177 99 399.98 277 499.72 377 599.01 477 698.09 . 576 796.70 674 894.23 772 867.65 19 34 13 961.13 21 43 33 1053.33 23 55 54 1143.54 27 19 83 1230.83 31 1 98 1314.98 34 8 69 1396.69 36 28 34 1475.34 40 2 85 1550.85 41 15 89 1625.89 41 27 S 55 26 E S 53 51 E S 55 55 E S 59 29 E S 6'1 15 E S 6O 14 E S 60 15 E S 60 32 E S 59 31 E S 58 13 E 989 65 O0 1083 O0 1175 O0 1265 O0 1352 O0 1436 O0 1518 O0 1597 O0 1672 O0 1747 2000 O0 1821 O0 1699 O0 45 8 O0 1888 O0 1952 O0 2012 O0 2070 O0 2130 O0 2185 O0 2235 O0 2284 O0 2335 65 1766 73 1830 43 1890 96 1948 40 2008 31 2063 O0 2113 89 2162 74 2213 FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 0 06 -0 25 -0 56 -0 29 5 80 17 03 29 98 46 29 68 14 97 92 133 40 172 07 215 16 263 81 317 67 375 22 436 83 502 28 568 34 2100 2200 2300 2400 2500 2600 2700 2800 2900 S 56 27 E 65 49 19 S 54 6 E 710 73 51 26 S 54 30 E 786 43 54 32 S 56 51 E 866 96 53 31 S 56 3 E 948 40 54 18 S 56 29 E 1028 31 59 6 S 59 5 E 1111 O0 60 34 S 60 1 E 1198 89 59 34 S 59 18 E 1285 74 59 18 S 58 36 E 1371 3000 O0 2387 03 2265 03 58 58 O0 2439 O0 2492 O0 2545 O0 2598 O0 2652 O0 2705 O0 2757 O0 2808 40 57 55 75 57 51 89 57 54 94 57 50 77 57 27 52 58 33 35 58 58 82 58 59 61 58 27 636 53 10 76 95 O3 44 95 6O 16 21 S 57 56 E 1457.03 S 57 7 E 1542.21 S 56 35 E 1626.79 S 56 35 E 1711.50 S 57 10 E 1796.27 S 56 13 E 1880.54 S 58 34 E 1965.47 S 59 11 E 2050.9~ S 61 6 E 2136.55 S 61 57 E 2221.76 3100 32O0 330O 340O 3500 3600 37OO 3800 3900 40 2317 75 237O 89 2423 94 2476 77 253O 52 2583 35 2635 82 2686 O0 2860.61 2738 0 O0 0 49 0 03 0 O0 3 22 2 86 0 65 1 18 3 20 5 2O 4 23 1 72 3 O2 4 22 3 25 2 42 2 80 3 O0 0 77 1 44 4 22 2 12 5 13 0 88 1 41 4 60 5 16 0 62 0 54 1 16 0 9O 1 13 0 58 0 74 1 70 2 11 0 50 1 68 2 54 1 43 0 O0 N 0 17 S 0 36 S 0 67 S 1 54 S 7 02 S 1648 S 26 71 S 38 21 S 52 16 S 0 O0 E 0 04 W 0 54 W 1 11 W 1 35 W 2 34 E 9 58 E 18 36 E 30 33 E 47 32 E 0 O0 N 0 0 E 0 0 1 2 7 19 32 48 7O 17 S 13 55 W 64 S 56 t4 W 29 S 58 54 W 05 S 41 11W 40 S 18 25 E OT S 30 10 E 41 S 34 31 E 79 S 38 27 E 43 S 42 13 E 69.16 S 89.90 S 100 112.28 S 132 135.23 S 168 159.21 S 211 185.38 S 258 214.22 S 308 244.67 S 361 277.39 S 418 311.52 S 475 62 E 134 19 E 173 67 E 216 10 E 264 34 E 317 24 E 375 95 E 436 75 E 502 35 E 568 71 78 E 99 68 S 46 4 E 93 S 48 13 E 44 S 49 39 E 19 S 51 17 E 41 S 52 59 E 98 S 54 20 E 37 S 55 12 E 88 S 55 57 E 29 S 56 29 E 34 S 56 46 E 348.33 S 532 77 E 636.53 S 56 49 E 390.29 S 593 435.43 S 655 480.38 S 721 525 09 S 789 570 15 S 855 614 57 S 926 658 15 S 1001 701 96 S 1076 746 31 S 1150 23 E 710.10 S 56 40 E 32 E 786.79 S 56 24 E 73 E 866.98 S 56 21 E 37 E 948.06 S 56 22 E 97 E 1028.48 S 56 20 E 71 E 1111.97 S 56 27 E 74 E 1198.61 S 56 42 E 52 E 1285.16 S 56 54 E 33 E 1371.21 S 57 2 E 791 56 S 1223.28 E 1457 04 S 57 6 E 837 883 930 976 1022 1068 1112 1155 1196 27 S 1295 16 E 1542 60 S 1365 38 S 1436 42 S 1507 96 S 1577 46 S 1649 86 S 1722 68 S 179T O5 S 1872 92 E 1626 55 E 1711 73 E 1796 98 E 1880 71 E 1965 80 E 205O O8 E 2136 49 E 2221 23 S 57 7 E 80 S 57 6 E 51 S 57 4 E 28 S 57 4 E 55 S 57 3 E 49 S 57 4 E 97 S 57 8 E 60 S 57 15 E 88 S 57 26 E ARCO ALASKA INC. 1L-22 KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATE: 28-FEB-91 PAGE 2 DATE OF SURVEY: 06-JAN-91 KELLY BUSHING ELEVATION: 122.00 FT ENGINEER: J. FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED 'DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 4000 O0 2914 17 2792 17 57 1 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 2968 O0 3021 O0 3077 O0 3133 O0 3190 O0 3248 O0 3303 O0 3358 O0 3413 13 2846 82 2899 03 2955 42 3011 56 3068 21 3126 84 3181 82 3236 31 3291 13 57 45 82 56 57 03 56 8 42 55 21 56 54 48 21 55 16 84 56 44 82 56 51 31 56 46 FEET S 60 23 E 2305 97 01 10 11 40 29 92 97 48 28 5000.00 3468.61 3346 61 56 2 5100.00 3524.76 3402 5200.00 3581.84 3459 5300.00 3639.80 3517 5400.00 3696.97 3574 5500.00 3754.31 3632 5600.00 3812.23 3690 5700.00 3869.93 3747 5800.00 3926.64 3804 5900.00 3983.77 3861 76 55 37 84 54 50 80 54 47 97 55 9 31 54 48 23 54 33 93 55 2 64 55 31 77 54 51 S 60 41 E 2390 S 62 14 E 2474 S 62 4 E 2557 S 61 10 E 2639 S 60 0 E 2721 S 59 1 E 2802 S 58 18 E 2885 S 57 36 E 2969 S 60 1 E 3053 S 60 38 E 3136 42 04 10 56 55 39 82 42 73 75 600000 4041 34 3919 34 55 16 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 4096 O0 4151 O0 4206 O0 4262 O0 4318 O0 4372 O0 4426 O0 4481 73 3974 33 4029 53 4084 67 4140 59 4196 70 4250 89 4304 20 4359 O0 4535.93 4413 73 57 0 33 56 49 53 56 10 67 55 38 59 56 53 70 57 14 89 57 12 20 56 59 93 56 35 S 59 27 E 3219 S 58 21 E 3301 S 58 28 E 3382 S 59 2O E 3464 S 59 33 E 3546 S 59 31 E 3627 S 58 58 E 3709 S 59 1 E 3791 S 59 4 E 3873 S 59 22 E 3955 45 57 17 40 99 71 63 50 30 84 7000 O0 4591 20 4469.20 56 29 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 4646 O0 4702 O0 4757 O0 4812 O0 4868 O0 4922 O0 4977 O0 5031 O0 5086 50 4524.50 56 16 06 4580.06 56 13 70 4635.70 56 9 92 4690.92 56 38 04 4746.04 56 36 52 4800.52 57 3 12 4855.12 56 48 99 4909.99 56 41 63 4964.63 57 41 S 60 34 E 4038 S 60 27 E 4122 S 60 25 E 4205 S 60 29 E 4287 S 60 38 E 4370 S 60 30 E 4454 S 60 33 E 4538 S 60 26 E 4622 S 60 23 E 4705 S 6O 33 E 4789 01 15 09 97 14 39 10 73 18 78 S 60 45 E 4872 S 60 55 E 4955 S 61 4 E 5037 S 60 43 E 5121 S 60 29 E 5204 S 60 9 E 5288 S 60 17 E 5371 S 60 20 E 5455 S 60 19 E 5538 DEG/ O0 091 0 87 1 78 1 22 0 87 1 56 2 22 1 59 1 73 1 98 1 .17 1 .26 1 .05 2.18 0.48 0.59 0.83 0.88 0.56 0.24 2.58 0.38 0.40 0.90 0 20 2 22 0 59 0 11 0 26 0 53 0 36 0 2O 0 45 0 11 0 55 1 29 0 58 0 12 0 34 3 42 FEET FEET FEET DEG MIN 1236 86 S 1946 41 E 2306 15 S 57 34 E 1278 1318 1357 1396 1437 1478 1521 1566 1610 47 S 2019 85 S 2093 67 S 2167 92 S 2240 19 S 2311 75 S 2381 88 S 2452 55 S 2523 03 S 2595 60 E 2390 67 E 2474 46 E 2557 12 E 2639 62 E 2721 97 E 2803 99 E 2886 57 E 2970 26 E 3054 25 S 57 40 E 43 S 57 48 E 57 S 57 56 E 98 S 58 3 E 97 S 58 8 E 66 S 58 10 E 75 S 58 11 E 27 S 58 10 E 11 S 58 11 E 1650 98 S 2667.82 E 3137 35 S 58 15 E 1692 1734 1777 1819 1861 1902 1944 1987 2029 31 S 2739.51 E 3220 72 S 2809.81 E 3302 72 S 2879.03 E 3383 96 S 2949,36 E 3465 62 S 3019.91 E 3547 92 S 3090.19 E 3629 75 S 3160.34 E 3710 18 S 3230.94 E 3793 42 S 3301,31 E 3875 06 S 58 18 E 17 S 58 19 E 65 S 58 18 E 69 S 58 19 E 61 S 58 21 E 10 S 58 23 E 77 S 58 24 E 13 S 58 24 E 20 S 58 25 E 2071 42 S 3371 46 E 3956,96 S 58 26 E 2112 2154 2195 2236, 2276 2318 2359 2401 2442 95 S 3443 17 S 3516 37 S 3589 20 S 3661 92 S 3733 29 S 3806 65 S 3879 03 S 3952 41 S 4025 62 E 4040.18 S 58 28 E 55 E 4123.90 S 58 31 E 05 E 4207.24 S 58 33 E 03 E 4289.95 S 58 35 E 23 E 4372.80 S 58 37 E 44 E 4456.85 S 58 39 E 61 E 4540.85 S 58 41 E 67 E 4624.78 S 58 43 E 43 E 4708.44 S 58 45 E 2483 49 S 4097 93 E 4791.74 S 58 47 E 2524 2564 2605 2645 2686 2728 2769 2811 2852 32 S 4170 86 S 4243 14 S 4315 75 S 4388 61 S 4461 32 S 4534 95 S 4606 38 S 4679 76 S 4752 56 E 4875.01 S 58 49 E 15 E 4958.11 S 58 51 E 82 E 5041.14 S 58 53 E 64 E 5124.47 S 58 55 E 39 E 5207.86 S 58 57 E 13 E 5291,70 S 58 58 E 83 E 5375.46 S 58 59 E 45 E 5459.04 S 59 0 E 26 E 5542.76 S 59 1 E COMPUTATION DATE: 28-FEB-91 PAGE 3 ARCO ALASKA INC. 1L-22 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 06-JAN-91 KELLY BUSHING ELEVATION: 122.00 FT ENGINEER: J. FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEE7 DEG 8000 O0 5138.64 5016.64 58 48 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 5190 52 5068.52 58 47 O0 5242 O0 5295 O0 5349 O0 5404 O0 5458 O0 5512 O0 5567 O0 5622 59 5120.59 58 26 43 5173.43 57 37 73 5227.73 56 46 22 5282.22 57 14 39 5336.39 57 16 51 5390.51 57 8 18 5445.18 56 40 54 5500.54 56 6 S 59 54 E 5624 05 S 60 4 E 5709 S 6O 24 E 5794 S 60 54 E 5879 S 61 31 E 5963 S 58 45 E 6O46 S 58 9 E 6130 S 58 36 E 6214 S 59 2 E 6298 S 59 38 E 6381 42 65 36 O9 74 78 84 53 72 0 26 0 14 1 01 1 73 1 12 3 69 0 47 0 93 0 82 1 2O 2895.50 S 4826 20 E 5628 16 S 59 2 E 2938.28 S 4900 2980.71 S 4974 3022.37 S 5048 3062.82 S 5121 3103.90 S 5194 3148.33 S 5266 3192.45 S 5337 3235.84 S 5409 3278.26 S 5481 22 E 5713 31 E 5799 28 E 5883 87 E 5967 95 E 6051 31 E 6135 89 E 6219 51 E 6303 17 E 6386 64 S 59 3 E O0 S 59 4 E 86 S 59 5 E 78 S 59 7 E 59 S 59 9 E 63 S 59 8 E 71 S 59 7 E 45 S 59 7 E 72 S 59 7 E 9000 O0 5678 46 5556 46 55 51 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 5734 O0 5791 O0 585O O0 5910 O0 597O O0 6029 O0 6089 O0 6151 O0 6216 74 5612 69 5669 07 5728 07 5788 31 5848 57 5907 59 5967 93 6029 74 6094 74 55 37 69 54 55 O7 53 35 07 52 51 31 53 6 57 53 50 59 52 16 93 50 39 74 48 28 S 57 44 E 6464 58 S 58 6 E 6547 23 S 58 32 E 6629 40 S 57 41 E 6710 56 S 56 20 E 6790 56 S 55 26 E 6870 37 S 54 54 E 6950.88 S 55 15 E 7030.81 S 55 47 E 7108.98 S 56 13 E 7185.12 0 28 1 14 0 43 1 43 1 O3 1 59 1 49 1 61 2 02 2 72 3321 51 S 555] 89 E 6469 61 S 59 7 E 3365 3408 3451 3494 3539 3585 3631 3676 3718 42 S 562] 55 S 569] 33 S 5760 94 S 5827 68 S 5894 89 S 5960 79 S 6025 02 S 6090 51 S 6153 92 E 6552 9O E 6634 89 E 6715 97 E 6795 O6 E 6875 04 E 6955 53 E 7035 O0 E 7113 20 E 7189 25 S 59 6 E 45 S 59 5 E 62 S 59 4 E 57 S 59 3 E 27 S 59 1 E 62 S 58 58 E 41 S 58 55 E 46 S 58 53 E 52 S 58 51 E 10000.00 6284.25 6162.25 46 55 10100.00 6352.56 6230.56 46 55 10176.00 6404.48 6282.48 46 55 S 55 3 E 7259.06 S 55 3 E 7332.05 S 55 3 E 7387.53 0.00 0.00 0.00 3760.20 S 6214.29 E 7263.36 S 58 49 E 3802.05 S 6274.13 E 7336.23 S 58 47 E 3833.86 S 6319.61 E 7391.62 S 58 45 E COMPUTATION DATE: 28-FEB-91 PAGE 4 ARCO ALASKA INC. 1L-22 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 06-JAN-91 KELLY BUSHING ELEVATION: 122.00 FT ENGINEER: J. FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET' OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 0.00 -122 O0 0 0 1000 O0 989.65 867 65 19 34 2000 O0 1821.00 1699 O0 45 8 3000 O0 2387.03 2265 03 58 58 4000 O0 2914.17 2792 17 57 1 5000 O0 3468.61 3346 61 56 2 6000 O0 4041.34 3919 34 55 16 7000 O0 4591.20 4469 20 56 29 8000 O0 5138.64 5016.64 58 48 9000 O0 5678.46 5556.46 55 51 10000.00 6284.25 6162.25 46 55 10176.00 6404.48 6282.48 46 55 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E S 55 26 E 97 S 56 27 E 636 S 57 56 E 1457 S 60 23 E 2305 S 60 38 E 3136 S 59 22 E 3955 S 60 33 E 4789 S 59 54 E 5624 S 57 44 E 6464 0 O0 92 53 03 ,97 42 45 01 05 58 0 O0 4 23 4 22 0 90 091 1 17 2 58 0 36 0 26 0 28 0 O0 N 69 348 791 1236 1650 2071 2483 2895 3321 0 O0 E 16 S 71 33 S 532 56 S 1223 86 S 1946 98 S 2667 42 S 3371 49 S 4097 50 S 4826 51 S 5551 0.00 N 0 0 E 78 E 99.68 S 46 4 E 77 E 636.53 S 56 49 E 28 E 1457.04 S 57 6 E 41 E 2306.15 S 57 34 E 82 E 3137.35 S 58 15 E 46 E 3956.96 S 58 26 E 93 E 4791.74 S 58 47 E 20 E 5628.16 S 59 2 E 89 E 6469.61 S 59 7 E S 55 3 E 7259.06 S 55 3 E 7387.53 0.00 3760.20 S 6214.29 E 7263.36 S 58 49 E 0.00 3833.86 S 6319.61 E 7391.62 S 58 45 E COMPUTATION DATE: 28-FEB-91 PAGE 5 ARCO ALASKA INC. 1L-22 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 06-JAN-91 KELLY BUSHING ELEVATION: 122.00 FT ENGINEER: J. FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET DEG MIN 0 O0 122 O1 222 01 322 02 422 O3 522 42 623 18 724 19 825 80 928 84 0 O0 -122 O0 122 222 322 422 522 622 722 822 922 O0 0 O0 O0 lO0 O0 O0 200 O0 O0 300 O0 400 O0 500 O0 600 O0 7O0 O0 800 0 0 N 0 0 E 0 18 S 68 33 W 0 22 S 62 26 W 0 25 S 55 38 W O0 2 13 S 28 30 E O0 6 40 S 37 17 E O0 7 23 S 39 1 E O0 8 54 S 44 49 E O0 11 40 S 49 13 E O0 16 23 S 54 53 E 0 O0 -0 01 -0 32 -0 63 0 28 8 18 19 81 33 56 51 26 75 89 0 O0 0 02 013 0 O0 4 94 0 63 1 63 2 O0 3 68 5 35 0 O0 N 0 20 S 041 S 0 75 S 2 14 S 9 04 S 18 78 S 29 34 S 41 54 S 56 72 S 0 O0 E 0 14 W 0 66 W 1 24 W 1 06 W 3 87 E ll 40 E 20 92 E 34 10 E 53 60 E 0.00 N 0 0 E 0.24 S 35 41 W 0.78 S 57 48 W 1 .45 S 58 44 W 2.39 S 26 18 W 9.83 S 23 10 E 21.96 S 31 15 E 36.03 S 35 29 E 53.74 S 39 23 E 78.04 S 43 23 E 1034 44 1022 O0 1141 1251 1364 1481 1604 1732 1865 2001 2151 900 O0 20 31 97 1122 O0 1000 38 1222 O0 1100 27 1322 O0 1200 95 1422 O0 1300 11 1522 O0 1400 49 1622.00 1500 46 1722.00 1600 43 1822.00 1700 53 1922.00 1800 S 54 28 E O0 22 38 S 54 24 E 149 O0 25 35 S 57 56 E 193 O0 29 42 S 60 51 E 245 O0 33 43 S 60 38 E 307 O0 36 35 S 60 18 E 377 O0 40 58 S 60 18 E 457 O0 41 25 S 58 45 E 545 O0 45 12 S 56 25 E 637 O0 50 1 S 53 48 E 749 109 75 21 54 80 61 65 95 49 56 33 2 07 2 10 421 4 14 310 2 74 1 06 0 79 4 27 1 50 75.97 S 99.18 S 113 124'.02 S 150 150.47 S 195 180.41 S 249 215.43 S 310 255.12 S 380 299.58 S 455 348.90 S 533 413.44 S 624 81 46 E 111.39 S 47 0 E 43 E 150.68 S 48 50 E 16 E 194.75 S 50 27 E 31 E 246.55 S 52 23 E 58 E 307.96 S 54 8 E 35 E 377.80 S 55 14 E 35 E 457.98 S 56 9 E 87 E 545.49 S 56 41 E 62 E 637,56 S 56 49 E 96 E 749.34 S 56 31 E 2316 51 2022.00 1900 O0 54 35 2485 2673 2873 3067 3255 3443 3631 3825 4014 73 2122.00 2000 55 2222.00 2100 05 2322.00 2200 11 2422.00 2300 03 2522.00 2400 04 2622.00 2500 64 2722.00 2600 56 2822.00 2700 39 2922.00 2800 O0 53 53 O0 60 35 O0 59 24 O0 58 13 O0 57 55 O0 57 21 O0 58 41 O0 58 55 O0 57 0 S 56 49 E S 56 8 E 1016 S 60 8 E 1175 S 58 53 E 1348 S 57 25 E 1514 S 56 26 E 1673 S 56 27 E 1832 S 58 37 E 1992 S 61 44 E 2158 S 60 15 E 2318 880 40 90 6O 03 30 40 61 48 38 02 0 69 3 39 0 56 0 73 1 29 0 13 1 75 0 63 1 71 051 487 74 S 732.99 E 880.43 S 56 22 E 563 646 734 822 909 996 1082 1166 1242 73 S 846.39 E 1016,94 S 56 20 E 66 S 981.78 E 1175.61 S 56 38 E 27 S 1130.51 E 1348 04 S 57 0 E 18 S 1271.69 E 1514 32 S 57 7 E 34 S 1404.79 E 1673 42 S 57 5 E 30 S 1538.15 E 1832 62 S 57 4 E 54 S 1672.76 E 1992 49 S 57 5 E 17 S 1816,30 E 2158 45 S 57 18 E 83 S 1956.90 E 2318 21 S 57 35 E 4200 33 3022.00 2900 O0 56 56 4379 4554 4733 4915 5095 5269 5443 5616 5791 88 3122.00 3000 38 3222.00 3100 04 3322.00 3200 83 3422.00 3300 11 3522.00 3400 29 3622.00 3500 74 3722.00 3600 86 3822.00 3700 81 3922.00 3800 O0 55 27 O0 54 41 O0 56 33 O0 56 40 O0 55 4O O0 54 24 O0 55 3 O0 54 37 O0 55 34 S 62 14 E 2474.38 S 61 22 E 2622.88 S 59 20 E 2765.61 S 57 44 E 2913.56 S 60 19 E 3066.49 S 59 30 E 3215.00 S 58 5 E 3357.54 S 59 27 E 3500.38 S 59 26 E 3641.55 S 59 2 E 3784.99 1 .77 0.98 1 .01 1 .60 1 .56 1.15 1 .83 0.33 0.80 0.63 1318 98 S 2093 92 E 2474 71 S 57 48 E 1388 1459 1536 1616 1690 1764 1838 1909 1983 96 S 2225 61 S 2349 50 S 2476 61 S 2606 25 S 2736 55 S 2857 23 S 2980 91S 3102 70 S 3225 59 E 2623 92 E 2766 40 E 2914 75 E 3067 O3 E 3216 75 E 3358 23 E 3501 03 E 3642 16 E 3786 44 S 58 2 E 33 S 58 9 E 34 S 58 11 E 34 S 58 12 E 03 S 58 18 E 63 S 58 18 E 55 S 58 20 E 84 S 58 23 E 39 S 58 24 E COMPUTATION DATE: 28-FEB-91 PAGE 6 ARCO ALASKA INC. 1L-22 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 06-JAN-91 KELLY BUSHING ELEVATION: 122.00 FT ENGINEER: d. FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 5966 28 4022.00 3900 O0 54 46 6146 6327 6506 6690 6874 7055 7235 7416 7599 34 4122.00 4000 72 4222.00 4100 24 4322.00 4200 97 4422.00 4300 67 4522.00 4400 78 4622.00 ,4500 85 4722.00 4600 51 4822.00 4700 04 4922.00 4800 O0 56 54 O0 55 57 O0 57 1 O0 57 12 O0 56 43 O0 56 27 O0 56 12 O0 56 36 O0 57 3 S 59 3 E 3927 85 S 60 33 E 4077 S 6O 26 E 4228 S 60 37 E 4375 S 60 33 E 4530 S 60 21 E 4684 S 60 41 E 4835 S 61 0 E 4984 S 60 43 E 5134 S 60 9 E 5287 33 35 92 93 72 42 8t 89 29 071 0 18 0 67 1 87 0 11 0 53 0 66 031 0 47 0 56 2057.27 S 3347.74 E 3929 34 S 58 26 E 2132.04 S 3477 44 E 4078 2206.72 S 36O9 2279.49 S 3737 2355.92 S 3873 2431.94 S 4007 2506.31 S 4138 2579.32 S 4269 2652.50 S 4400 2727.91 S 4533 04 E 4230 78 E 4378 O0 E 4533 03 E 4687 45 E 4838 20 E 4987 66 E 5138 43 E 5290 99 S 58 29 E 22 S 58 33 E 02 S 58 37 E 27 S 58 41 E 29 S 58 45 E 22 S 58 48 E 88 S 58 52 E 25 S 58 55 E 89 S 58 58 E 7781.81 5022.00 4900 00 56 42 7967.83 5122.00 5000 8160.61 5222,00 5100 8349.22 5322.00 5200 8532.82 5422 O0 5300 8717.46 5522 O0 5400 8899.04 5622 O0 5500 9077.39 5722 O0 5600 9252.34 5822 O0 5700 9419.76 5922 O0 5800 O0 58 54 O0 58 34 O0 57 6 O0 57 11 O0 56 59 O0 56 6 O0 55 47 O0 54 14 O0 52 52 S 60 19 E 5440 01 S 59 53 E 5596 S 60 13 E 5761 S 61 13 E 5920 S 57 56 E 6074 S 58 40 E 6229 S 59 39 E 6380 S 58 0 E 6528 S 58 14 E 6672 S 56 7 E 6806 56 13 68 33 49 93 56 O5 31 0 44 0 42 1 02 1 15 0 38 0 88 1 19 0 30 1 02 0 80 2803 85 S 4666 24 E 5443.84 S 59 0 E 2881 2964 3042 3118 3200 3277 3355 3430 3503 69 S 4802 07 S 4945 42 S 5084 41 S 5218 08 S 5350 86 S 5480 54 S 5606 91 S 5728 69 S 5841 39 E 5600.63 S 59 2 E 13 E 5765.42 S 59 4 E 53 E 5925.27 S 59 6 E 42 E 6079.18 S 59 8 E 40 E 6234.37 S 59 7 E 48 E 6385.92 S 59 7 E 07 E 6533.58 S 59 6 E 24 E 6677.11 S 59 5 E 06 E 6811.30 S 59 3 E 9587.16 6022.00 5900.00 53 57 9752.43 6122.00 6000.00 51 21 9907.92 6222.00 6100.00 48 15 10055.26 6322.00 6200.00 46 55 10176.00 6404.48 6282.48 46 55 S 54 54 E 6940.51 S 55 36 E 7072.01 S 56 13 E 7191.03 S 55 3 E 7299.40 S 55 3 E 7387.53 0.95 1 .79 2.65 0.00 0.00 3579.92 S 5951.55 E 6945.27 S 58 58 E 3655.18 S 6059.46 E 7076.54 S 58 54 E 3721.80 S 6158.11 E 7195.43 S 58 51 E 3783.33 S 6247.36 E 7303.63 S 58 48 E 3833.86 S 6319.61 E 7391.62 S 58 45 E COMPUTATION DATE: 28-FEB-91 PAGE 7 ARCO ALASKA INC. 1L-22 KUPARUK NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST GCT READING PBTD 7" CASING TD DATE OF SURVEY: 06-JAN-91 KELLY BUSHING ELEVATION: 122.00 FT ENGINEER: J. FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 445' FNL & 21T' FWL, SEC32 T11N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 5245 O0 9555 O0 9598 O0 9795 O0 9930 O0 9992 04 10073 O0 10160 O0 10176 O0 3607.87 6003.07 6028.38 6148.76 6236.77 6278.81 6334.12 6393.55 6404.48 3485 87 5B81 07 5906 38 6026 76 6114 77 6t56 81 6212 12 6271 55 6282.48 1754 10 S 3564 96 S 3584 96 S 3673 85 S 3730 94 S 3756 70 S 3790 75 S 3827 16 S 3833 86 S 2840.99 E 5930.29 E 5958.72 E 6086.81 E 6171.75 E 6209.40 E 6257.97 E 6310.04 E 6319.61 E ARCO ALASKA INC. 1L-22 KUPARUK NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST GCT READING PBTD 7" CASING TD COMPUTATION DATE: 28-FEB-91 PAGE 8 DATE OF SURVEY: 06-JAN-91 KELLY BUSHING ELEVATION: 122.00 FT ENGINEER: d. FORMICA · STRATIGRAPHIC SUMMARY ************ SURFACE LOCATION = 445' FNL & 217' FWL, SEC32 TllN RIOE MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA 5245 O0 9555 O0 9598 O0 9795 O0 9930 O0 9992 04 10073 O0 10160 O0 10176 O0 3607.87 6003 07 6028 38 6148 76 6236 77 6278 81 6334 12 6393 55 64O4 48 3485 87 5881 07 5906 38 6026 76 6114 77 6156 81 6212 12 6271 55 6282 48 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 1754.10 S 3564.96 S 3584.96 S 3673 85 S 3730 94 S 3756 70 S 3790 75 S 3827 16 S 3833 86 S 2840 99 E 5930 29 E 5958 72 E 6086 81 E 6171 75 E 6209 40 E 6257 97 E 6310 04 E 6319 61 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 10176.00 6404.48 6282,48 7391.62 S 58 45 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC. WELL 1L-22 F I ELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED 06 - JAN - 9i REFERENCE 7497S ~.: 1L-22 ~ ~'~!~' 45' FNL, 217' FWL, SEC 32, T11N, RIOE) i ~RIZONTAL PROJECTION NORTH 8000 EEF '74393 SERLE : !/2000 !N/FT 600O 4000 2OOO -2000 -4000 -6000 SOUTH -8000 -4O00 NEST -2000 0 2000 4000 6000 8000 !0000 12000 E~I~T 1L-22 ' i~i'' FNL, 217' FWL, SEC 32, T11N, RIOE) < RTICAL PROJECTION -4000 -f>O00 0 0 '~000 4000 E~O00 8000 10000 12000 123. PROJECTION ON VERTICPA. PLANE 123. - 303. SC;Al. ED IN VERTICAL DEPTHS HORIZ SCALE : 1/2000 IN/FT PEFIMIT # ~,~ - ¢OMPLE :-qON DATE AOGCC GEOLOGICAL MATERIALS iNVENTORY' LiST / I~' 1 ?/ co. ~,ONTA~T checl( off or list data as it is received.~list received date for 407. if not reauired list as NH · ~u drilline histo,-v' surve~ well tests core descri cored intervals core analysis ditch intervals dieitai data In,'-' -rune i n, ,ti i IkITcnt~i lC' Lv~ , , ~-~_ ] ~,~ ,,~,~,~o SCALE NO. [to thc nearest foot~ , [inchll 0O'~ I 11] I ,. I~ I I '- ~q I I I ' ' i ' 171 18] ARCO Alaska, Inc. Date: March 15 1991 Transmittal #: 8036 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1L-22 Receipt LIS Tape and Listing I 2 - 2 7 - 9 0 5 0 5 6 - 1 0 1 7 7 Acknowledged' ~ ....... Date' - ......... DISTRIBUTION' Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: March 15, 1991 Transmittal #: 8032 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. I L - 2 2 Compensated Density Neutron 1 2 - 2 7 - 9 0 5 0 5 6 - 1 01 7 7 1 L - 2 2 Compensated Dual Resistivity 1 2 - 2 7 - 9 0 5 05 6 - 1 01 7 7 1A-23 Dual Gamma Ray-Electromagnetic 2- 1 7-91 6667-7495 Wave Resistivity-Formation Exposure Time Directional Data Dual Gamma Ray-Compensated 2 - 1 7 - 91 Neutron Porosity-Simultaneous Formation Density Directional Data 1A-23 6667-7495 Receipt Acknowledged: .~t~~..~~ Date' - ......... DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) ARCO Alaska, Inc. Date: February 4, 1991 Transmittal #: 8000 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. signed copy of this transmittal. 3G-0~ 3G-2 3G-04K'~. 3G-15~( 3 G- 22.X?j 3G-241~ 3G-0 3G-22"/,~ 1L-22~,, Receipt Please acknowledge receipt and return one Pulse Echo Cement Evaluation Log I 0 - 3 - 9 0 Pulse Echo Cement Evaluation Log I 1 - 1 5 - 9 0 Pulse Echo Cement Evaluation log 1 1 - 1 6 - 9 0 Pulse Echo Cement Evaluation Log I 1 - 1 4 - 9 0 Pulse Echo Cement Evaluation Log I 1 - 1 8 - 9 0 Pulse Echo Cement Evaluation Log I 1 - 2 3 - 9 0 Acoustic Cement Bond Log I 1 - 1 6 - 9 0 Acoustic Cement Bond Log 1 1 - 1 8 - 9 0 Squeeze Record 1 - 2 0 - 9 1 Acknowledge' - .... Date' 5229-9682 6698-9704 4900-7939 4500-7815 6600-9595 8466-11;513 4892-7962 6600-9616 9200-9800 Drilling State of Alaska F£p~ 5 1,9~1 Alaska Oil & Gas Cons. Commission Anchorage TO: THRU: FROM: MEMORANL UM State of Alaska BJ~AS~A OIL A/iD ~ '~'-q ~=~, CONSERVATION CO,~,~.4ISSION - f?/'~ DATE: Lonnie C. ~m~nf~ December 26, 1990 Co~,is sioner / FILE NO: JT.LG. 1226.9 TELEPHONE NO: SUBJECT: RIG/BOPE Inspection B_ti Kuparuk well #!L-22 Kuparuk Rv Field Permit No. 90-164 Louis R. Grimal Petroleum inspector Fridav~/~!/90: i performed a RIG/BOPE inspection on Pool ,~,~{~7 rig drz~,_ng we~ ~,~/L/2~ rot ,AA,_ Kuparuk. The rig is in rough shape coome~ca!iy but all equipment is in operating condition. The rig had been stacked ~ ~_or z years and prese{tly housekeeping operations are under way. The activators for the accumulator are located on the second level of the BOP bay exposed directly to the BOP stack. informed the tooipusher that a firewali was needed in that area and work was cor~nenced on that project before I left location. The electrical system did not appear to have a operational air purge working and the kill line was targeted in the wrong direction. All else looked fairly well. ~a~u_day lz/=z/90: I witnessed a BOP test on Pool, ~z7 r~g drilling we.~, ~~ .~or AAI Kuparuk. The test went well and all equipment passed with the exception of the upper kelly cock valve which would not close and the HCR valve had a very slight leak. The gas detector on the rig floor showed a 20% level constantly but set the alarm off when we used the test bottle on the sensors which leads me to believe it is a minor calibration deficiency. ~ GoerzLcn, in s~ary: Gary ~' ' Pool toolpusher, has extra roustabouts scheduled to arrive this week to be used primarily for maintenance and clean up of the rig. The too!pusher is making a conscientious effort to bring the rig back up to top condition as quickly as possible. Pool #7 rig appears to be ready to drill 1I,-20. Attachment. 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COI'~IISSION BOPE Inspection Report OPERATION, Orlg ~ Wkvr Operator /C~ /~- / ~ L~::~/O~ L~ K u~ Rig# We11 sign Rig Location: SecJ~ T//~J. R /~H Orlg contrctr Location (general) Housekeeping (general) Reserve pit Audio. a HUD SYSTEHS: Trip tank Pit gauge Flowmonftor l/ ' I Gas detectors BOPE STACK:. Test Pressure Annular preventer /.~C:~::~ upp~-~,.,/ ~,?~,,..~n- Pipe rams Blind rams ~ ~'~ Choke 1tnb valves HCR valve ~/~ Klll ltne valves o¥ ~//)- - Check valve TEST, Inltlal./~ Weekly Other Representative '~"-F~,~li~ ..~.,~. ~, -/~/ ACCUHULATOR SYSTEH: Fu~ ~h~o p..u~o .~ ~ 0 p.~ Pump tncr clos press 200 pstg / mtn:~ C~se Full charge press attained .~ mtn ~ se Conerols= Haster ~~ .~~ Remo~. ~~ Bltnd swt~ch cover ~ KELLY AND FLOOR SAFETY VALVES: Upper Kelly . ~- Test pressure Lower Kelly ,,'~2~' Test pressure Ball type ~?~// Test: pressure Inside .BOP . ~)'~ Test pressure Choke manifold .~7/~1" Test pressure / Hydraultcally operated choke Number valves Number flanges ,, Adjustable chokes TEST RESULTS Failures, C~. Test ttme/--///& hrs 'Repair or replacement of failed equipment to be made within ,,7 days. Neet fy the Inspector. and follow with wrttten/FAXed verification to Commission office. C.OOq (rev 05/10/90) December 5, 1990 Telecopy.. (907)276-7542 A. Wal~e McBride Area Drilling Engineer ARCO Alaska, Inc. , 0~ P O. Box I0_~60 Anchorage, Alaska 99510-0360 Re: Kuparuk Ri'vet Unit 1L-22 ARCO Alaska, Inc. Permit No. 90-164 Sur. Loc. 446'FNL, 217'~, Sec 32 ' ~ Sec. 33, T1]M, R]0E, Bt~ho!e Loc. 734'FSL, I~I~'FEL, ~.nc.osed is the approved application for permit to drill the above roferenced well. The permit to drill does not exempt you from obtaining additional p~rmits required by law from other governmentsl agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. -%~he Commission will advise you of those BOPE tests that it wishes to witness. Sincere!y, i .-'? ! _, Com±ssiofier Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~-~4ISS~ ~, d,_z Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conse~zation w/o encl. STATE OF ALASKA OIL AND GAS CONSERVATION COMMI~S~Jr, i PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill . X Redrill -- I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone_ 2_. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 130, Pad 86' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25660 ALK 470 4. Location of well at surface 7. Unit or properly Name 11. Type Bond (see 20 AAC 25.025) 446' FNL, 217' FWL, Sec. 32, T11N, R10E, UM Kuparuk River Unit At top of productive interval (TARGET) 8. Well number Number 1,010' FSL, 790' FWL, Sec. 33 , T11N, R10E, UM 1L-22 #U630610 At total depth 9. Approximate spud date Amount 734' FSL, 1,213' FEL, Sec 33, T11N, R10E, UM 12-12-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15, Proposed depth (MD and TVD) properly line 1 L- 1 2 10,227 MD 734' @ TD feet 60' at SURFACE feet 2560 6,352 VD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 400 feet Maximum hole anc~le 57° Maximum surface 1 900psig At total depth (TVD) 6300 ' 2960 psig .18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling! Lenc~th IVD TVD IVD TVD (include stage data1 24 16.0" 62.5# H-40 Weld 80' 35' 35' 115' 115' _+200 CF 12.25 9.625" 36.0# J-55 BTC 5,249' 35' 35' 5,249' 3,620' 1200 Sx Permafrost & HF-ERW 700 Sx Class G $.5 7" 26.0# J-55 BTC 10192' 35' 35' 10,227' 6,352' 200 Sx Class G HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vedical depth Surface Intermediate Production "10V 0 1990 Liner Perforation depth: measured Alaska 0il & Gas Cons. true vertical Anchorage 20. Attachments Filing fee ~ Property plat __ BOP Sketch ~ Diverter Sketch ~ Drilling program X__ Drilling fluid program ~ Time vs depth plot __ Refraction analysis _ Seabed repeal _20 AAC 25.050 requirements 21. I hereby cedify that the foregoing is true and correct to the best of my knowledge (//~-,~/~~t,~ Title Area Drilling Engineer Date Signed Commission Use Only / / Permi/4~ -'/6 ~' 50- C, 2. ~'~ ~ 2 /'/'/__-/z' ] ~, ./0 5 / ("} other requirements Conditions of approval Samples required .__Y e s .,~ N o Mud log required__ Ye s '~,4; N o Hydrogen sulfide measures__ Yes ~ N o Directional survey required )<'Yes __ No Required working pressure 2M; for BOPE/_~ __/' .M; __ 5 M · __ 1 0 M' __ 1 5 M -._ ~ ~J~; by order of _ Approved by ,~. ~/~:' --~...~ ~ '//.~ ........ ~-'--/~/',. Commissioner the commission Dale / 2_- Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO ALASKA, Ped 1L, Well No, 22 Revleed Propomal Kuperuk Field, No~h Slope, ^laeka 0 _ RKB ELEVATIOH' 130' 1000 _ 2000 _ 3000_ 4000_ 5000_ 6000_ 7000, 0 KOP TVD-400 TMD-400 DEP-O 3 9 BUILD 3 DEO 15 PER lOO FT 21 27 33 B/PERMAFROST TVD-1520 TMD-1597 DEP-36:3 39 45 st EOC TVD-1997 TMD-2291 DEP-862 T/ UGNU SNDS TVD=2420 TMD=3062 DEP-1507 T/ W SAK SNDS TVD-2930 TMD=3992 DEP=2284 K-10 TVD-:3905 TMD-5768 B/ W SAK SNDS TVD=3420 TMD-4885 DEP-3030 9 5/8' CSG PT TVD-3620 TMDm5249 DEP-3335 AVERAGE ANGLE 56 DEG 43 HI N K-5 TVD=5200 TMD-8128 DEP-5742 TARGET - T~ ZONE C TVD-6020 TMD=962:3 DEP-6991 T~ ZONE A TVDm6142 TMD-9845 DEP-7177 B/ KUP SNDS TVD=6242 T~D=10027 DEP'7:3:30 TD / LOG PT TVD-6352 TMD=10227 DEP-7497 I I I I I 1 000 2000 :3000 4000 5000 VERTICAL SECT[ON I I I 6000 7000 8000 NOV J 0 1,9 0 Alaska Oli& Gas Cons, Commission Anchorag~ HORIZONTAL PROJECTION SCALE ! IN. - !000 FEET Kup,ruk Field. North Slope. Ala, 1 000 1 000 . _ 1000 _ 2000 _ 3000 _ 4000 5000 _ SURFACE WEST-EAST 0 1 000 2000 :3000 I I I I SURFACE LOCAT ! ON, ' 446' FNL, 217' FWL SEC. 32, TIIN, RIOE 4000 5000 6000 TO00 I I I I S 56 DEG 51 MINE 6991' (TO TARGET) TARGET TVD-6020 THO-9623 DEP-6991 SOUTH 3824 EAST 5853 TARGET LOCATION~ I010' FSL, 790' Fkq. SEC. 33, TIIN, RIOE TD LOCATION~ 734' FSL, 1213' FWL SEC. 33, TllN. RIOE 1 50 200 250 :300 :350 400 450 500 550 I I I I I I I I I 250 3;'00 350 400 45O 50O 550 150 ~' ~00 '%o 200 250 300 350 I 400 I 450 5OO _ 250 300 i i 400 450 _ 50u _ 55O I 550 DRILLING FLUID PROGRAM (1L-22) Spud to 9-5/8" surface casing . Density 8.6-10.0 PV 15-35 YP 15-35 Viscosity 50-100' Initial Gel 5-15 10 Minute Gel 15-40 APl Fluid Loss 10-12 pH 9-10 % Solids 10% + Drill out to weight up 8.6-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Tandem Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuge,Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.6 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,175 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3,000 psi. The nearest well to 1L-22 is 1L-12. As designed, the minimum distance between the two wells would be 60' at surface. The wells would diverge from that point. 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 of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. RECEIVEp 0V ~ 0 ]~qg~ & (]as Cons. Commission Anchorage GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1L PAD · , · · · , · . , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Move in and rig up Pool Rig 7. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing· Install and test B©PE. Test casing to 2,000 psi. Drill out cement and 10' of new hole· Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or LWD as needed. Run and cement 7" casing. Pressure test to 3,500 psi. ND BOPE and install temporary production tree. Secure well and release drilling rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic Rig 1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel. Shut in and secure well. Clean location and release rig. Fracture stimulate well. Re-perforate and add additional perfs. Aiaska Oil & Gas Cor~s. Coramission Anchorage ,.J ..RUK RIVER UNI', 20" DIVERTER SCHEMATIC I I DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE ~ OPERATION 3 . , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) RECEIVED 1. 16"CONDUCTOR A!a~jf8 0jj & L3aS COl'IS. C01~lissJ0[I 2. SLIP-ON WELD STARTING H~D 3. FMC DIVERTER ASSEMBLY WITH ~O 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH ~O 10" CUTLAS. 5. 10" HCR BALL VALVES WI~ 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTO~TICALLY UPON CLOSURE OF ANNU~R PREVE~ER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNU~R PREVENTER SRE 2/6190 13 5/8" 5000 !-..,I bOP STACK 7 'h I 6 5 I I ACCUMULATOR CAPACITY TI~ST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3, CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4, TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-rOM PIPE RAMS. TEST BO'I-rOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TESTONCE A WEEKAND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" -5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIVED NOV 0 Oil & Gas Oons. 6ommission ,Anchorage SRE 8/22/89 DOYON 14 ( (8) (3) Admin ~Pr. . ///~/9/) 9. (10 and 13) 12. 13 (14 thru 22) (23 thru 28) Company /~C_.(D Lease & Well No. ~z9~ P--~5"~('~O~' /~(.~ YES NO R~MAkKS Is the permit fee attached .......................................... 7/-- -- 2. Is well td be located in a defined pool ............................. 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 ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. .~ Is a conservation order needed ...................................... ' ' ,, Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~_ Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate/~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~Oo~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (29 thru 31) (6) Add: Geology: DWJ EngiBeering~ LCS ~:~. BEW ~ rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented__ Additional requirements ...................... ": . ................... INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: 0 ~0 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. T° 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. AbA6KA CO~PUT~NG.C~NTBR *, BOROUGH STATE APINUMBER REFERENCE NO AR¢O:AbASK , ZN~:'i;~: KUPARUK' NORTH SbOPE AbASKA. 50~029~221~4 74269' RECEI.VED MAR 1 8 1991 Alaska 011 & Gas Cons. Commission Anchorage chlumberger las~a Com utin~ Center $-FE~'1991 13~25 SERVICE NAME ; EDIT DATE : 91/02/ 5 ORIGIN il FLIC REEL NA~E il ?4269 C_ONTINUATION ~ ~ P~E~IOUS REEL ~ COMMENT ~ ARCO ALASKA INC,, KUPARUK RIVER, 1~-22, 50-029-22114 **** TAPE HEADER ~**~ SERVICE NAME : EDIT DATE il 91/02/ 5 ORIGIN : r~IC TAPE NA~E : 74269 C~NTINUATION # : 1 PREVIOUS TAPE : COH~ENT il ARCO ALASKA IN¢., KUPARUK. RIVER, 1L-22, 50-029m~2~14 , **** FILE HEADER **** F;~LE NAME : EDIT ,001 SERVICE : FhI~ V:!ERSION : ~001 06 DATE : 91/02/ 5 H~X REC.~IZE ~ 1024 FI~ TYPE : ~0 ~;'PAGE Il ,, SCHLUMBERGER ~EL~ SERVICES *************************************************************************************** **************************************************************************************** COMPANY NA~E: ARCO A~ASKA, INC.i BOROUGH: NORTH LOCATION; SECTION~ 32 i~?~ TOWNSHIP~ 11N RANGE: IOE Z EVATiON: o P~R~ANENT DATU~ IS Tape Yeri~ication bisting Chlumberger Alaska Computing Center 5-FEB-t991 13:25 bOG: MEASURED FRO~ RKB 1~0 ELEVATIONS KB~ 1]0 DATE bOGGEDt 27-DEC-90 RUN NUMBERt TWO TO DRIbbER~ 10177 TD LOGGERt 10177 ABOVE PERMANENT DATUN DFI 130 GLI 88 BIT SIZE I 8 1/2" DENSITYI 10,5 MUD RESISTIVITYI 5 28 ~ 75 FILTRATE RESISTIVlTY~ 5:84 e 75 ~AXIMUM TEMP RECORDEDI t65 LOGGING DISTRICT[ 4615 LOGGING ENGINEER PERRY/HUSBAND FIELD REMARKSI RUNI! GR READING 46.78 FT BEHZNDoTHE BIT.: RESISTIVITY READING 36,4 FT BEHIND BIT, DENSITY READING 1 2~6' BEHIND B!T.~ NEUTRON REAOING :108'8 FT BEHIND BiT. DRILbEO INTERVAL'5269' RUN21. GR. READING 36.~15 FT BEHIND: THE B~T-. RESISTIVITY READING 24,73 FT .BEHIND. BIT,. DENSITY READING 58.~9 BEHINO: BIT,~ NEUTRON READING 64.42rT BEHIND BIT, DRIL~ED'IN?ERVAL. 918$" al/2" STABILIZER BLADE, RUN ON CDN TO EXCLUDEMUD BETNEEN.;~HE~ DENSITY DE?ECTORSAND FOR~A?ION,~ S~NDSTONE:NATRIXe~2.65:,G/CC,: CORRECTION8 fOR TOOL, HOLE $IZE'(BZT SIZE)~AND ~UD CO~PUTING CENTER RE~ARKSl RUN! GA~A RAY ~ERGED TO RUN~ DENSiTY/NEUTRON MERGED TO_RUN2'~120~ RUNi RESISTIVITY-MERGEDTO .RUN2 a9150 RUNI ROPE CRATE OF PENETRA?ION) MERGED TO DATE JOB STARTED~ OI,,FEB-9! JOB REFERENCE NC]I 74269 ~DP/ANA', LUDbAt~ PAGEI. Verif~ication Listing IS Ta~=rger~e. las~a Computing Center chlUm ,, 5-FEB-1991 13=25 DATA SANPLED EVERY DATA INCLUDED - ~OOL EXTENSION TYPE USED ,LWD -,5000 FEET TOOL NAME LOGGING WHILE DRILLING MEASUREMENTS. PAGE~ 3 TABLE TYPE : CONS TONI VALU DEFI TYPE CN WN FL SECT TOWN COUN STAT NAT! LATZ LONG WITN SON PDAT EPD APD EKB EOF EGL TDL DFT DFD DFV DFL MST RMFS RMC8 FT FT FT FT FT FT CP DEGF DEGF OHMM ARCO ALASKA, INC, KUPARUK 1L-22 50-~29-22114 446 FNL & 217' FWL OE 40RTH SLOPE ALASKA O~ 10 .101 10,5 5 280001 Company Name Fleld Name Nell Name, APl Se. ria.~.Number Field Location sectto~ Township Ranq~ County : State'or erovLnce Natron Batttude Eon~ttude:' ~i~ne.l'~Name · vic, Order Number Permanent':.da~um Elev'atlon,,o~ Perm. Da Bog Measured From ABOVE ~ER~A~EN.T DATUM Elevat.$on o~ Kelly Bu Elevatton~e~ Derrick, E[evatton...o~'~Ground.L Total Depths- OrLl[er Total Depth,- ~Ogger Drtlllng'Fl, u[d Type , Drtlltn. g Fluid be~stt Dr[lLtn~ Fluid P~ Ortlltng:Flutd Vtscos Drilli~g,.,,Fl~[d BoSs' Reststl~ttY o~ Mud Sa Mud~.Sample:.Temperatur Res[sttvt'ty Mud_Ftltra. te. SampLe..~ Reslsttvtty DE ~Ud Ca ZONE ZONE ZONE ZONE ZONE IS Ta~e Veri~icatio~ ~isti~ chlu,~ber~erAl~s~ Co~pu~in~ Center 5-FBB-199! 13~25 PAGE~ 4 TUN! VA~U DEF! TYPE HCST DEGF Mud~Cake 8ample Tempe ZONE STE. DEGF -999,25 Surface Temperature BNT DEGF 165, Bottom HOle Temoeratu TABLE TYPE = ZONE TUN! BDEP TDEP DFT DFPH DFV Drb RMC$ HCST ..... 0.~ O, ' O. 0I ,~ : TABLE TYPE = CURV DEPT ATR ATRU ATRD .PSRU PBRD DER SDSF DROR Ob8 ROSl R08~ DCAL DPH! DPOR DRHO TNPH DEF! Oe th Charm. el Name,, RO~'BHC ATTENUATION RESISTIVITY RGS BHC PHASE SIFT RESISTIVITY RG8 UP ATTENUATION RESISTIVITY RGS DOWN ATTENURTION..RE$ISTIVITY RG8 UP PH.ASE SHIFT RESISTIVITY y RG8 DOWN PHASE SHIFT RESISTiVIT DZEbECTRIC RESISTIVITY ND& SUB STD DEr OF SHORT(DWS3) COUNTS_FAST ND$'ROTATIONAb DEbTA RHO'SHORT SPACING Delta,. RHO bS RHO:.Dens~ty CUNCORRECTED RHOB) - bDT 881R.O DenSitY - bDT 882 RHO Densi ~ - bDT Bulk Density photoelectric Factor Dlfterential-Callpet Density ~oroslty Density Porosity ~utPut from an Application Delta RHO Thermal Neutron Porosity GammaRa¥ ?aPe v.ri~ic.tion Listing Chlumber~er Alaska ComPuting Center 5-FEB=tOg! DATA FORMAT SPECIFICATION RECORD ** SET TYPE TYPE REPR CODE ., VALUE ! 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 9 11 66 11 1- 68 65 FT 0 66 0 13125 **-SET TYPE ...-CHAN ~* NAME SERV UNIT "SERVICE APl APl APl APl riLE NUMB NUMB SIZE' REPR PROCESS ID ORDER # LOG TYPE CLASS NOD NUMB SAMP EbEM CODE (NEX)~ .. DEPT F? O0 000 O0 0 I ! I 4 68 0000000000 ATR LWD OHMM O0 000 O0 0 I I 1 4 6B 0000000000 P,R LWO OHMM O0 000 O0 0 I I I 4' 6B 0000000000 ATRU bWD OHMM 00 000 00 0 1 i I 4 6~ - 00000000 PSRU LWD OHMM O0 000 O0 0 I 4 00'0000000 PSRD LWD OHMM O0 000 O0 0 ! ! 4 00000000'0 bWD OHMM O0 000 O0 0 I 1 4 0000000000 0000000000 DER DRO'.SDSF LWD i 1 ~I 4468 000000 LWo CPS O0 000 O0 0 68 G/C3 oo 0oo O0 0 I , 68 000000000000 DRHO LWD G/C3 O0 000 O0 0 I oo ooo ooo! 'ii oooooooooo ROS! L~D G~ 00 000 00 0 1 4, 6 0000000000 ROS2 LWD G.~ 3 00 000 00 0 1 .i 4 0000000000 G/C3 00 000 00 0 1 1 4 0000000000 RHOB LWD .~r ~.~ ooooo ooo ~ ~ ~ ~ ~ oooooooooo ~cA~ ~.~ ~. ooooo ooo ~ ~ ~ ~ ~ oooooooooo ...~ ~.~ .u ooooo ooo ~ ~ ~ ~ ~ oooooooooo .~.~.~ ~. oo ooooo o ~ , , , ~ oooooooooo GR LWD GAPI 00 00000 0 I 1 4 68 0000000000 PAGEt Tape Verification Listing cblumberger AlasKa Computing Center DEPT. ATRD.LWD SDSF.LWD RO$t.bWD DCAL ~WD TNpH~bWD DEPT. ATRD,bWD SDSF,bWD DCA~,~WD TNPH,~WD DEPT' S~$F~LWD ROSl.LWD TNPH.~ND DE~T' g?RD.~WD 6DSF,bND RO$1,~ND DCAL,~WD TNPH,~ND A?RD,~WD DEPT,~ DEPT, SPSF,bWD ROSl,LWD DCAL,bWD TNPR,~WD D~P?,~ A?RD,bWD SDSF,LWD RO$1,bWD 19 , 999, -999, -999, '999, 10100 0 10000 44 99O 2t 9800 4 219 0 9?OO 0 9600. 9500, 254, 2. 000 5O 0 000 i~33 .307 ,387 ,~35 ,000 ,2?9 .0¢1 0,~000 5,'92 15 000 .O00 ~0[ ~30 '767 O0 ioo 399 40? 000 ~44 434 255 ATR.bWD P$RU.bWD DROR.bWD RO$2.bWD GR ND ATR,bWD P$RU,bND DROR,bWD RO$2.bND DPH~,bND GR.bND PSRU~ND DROR,bWD RO$2'~ND DPHZ,~WD GR-bND A?R'bND P$RU,bND DROR,bND RO$~,bND DPHX,bND GR,bND A?R~.bND PSRU,bWD DROR,bND ROS2,LND DPH[,LWD GR,LWD A?R P~RU DROR R052 ~WD DPHi GR bWD DROR,b~D DPH~bWD GRobWD A~R,bWD P5RU,bWD RO$2 WD -999,250 PSR,bWD '999,250 A?RU,hWD -999,250 PSRD,bND -999'250 DER,bND -999.250 DRHO.bWD -999,~50 RObS.bND '999.250 RHOB,bND :999.- 50 PEF:~ND '999,250 DPOR,bND 999,250 DRHO ND '999,250 2.654 P$R.LND 2.~4 PSRD.bWD O, 7 DRHO,bND 2,436 RHOB,bND 1~,943 DPOR,/ND 7 .788 1,2-34 0 9 87 520 5,049 5,053 o · 322 '359 1:648 0,123 2,3~2 15,6 6 63,412 800 906 220 1.692 2'268 0,!75 2,329 P$R.laND PSRD,bND DRHO.bND RHOB, bND DPOR.bND P$RD. D DRHO,bND RHOB'bWD DPOR,bND PSR. laWD PSRD,bND DRHO.bWD: RHOB, bWD DPOR,bWD . P.SR.GND PSRD'bND DRHO,GWD RHOB,bWD DPOR, GWD PSRD, GWD DRHO, GWD R H 0 B' b W D DPOR,bWD PGR, GWD P$RD'bWD DRHO,bND RHOB.bWD !576 374 008 ,229' ,393 ~5,,~99 ,796 ,559 ~'008 .394 15,510 642 R 86 ~0~009 2,~92 15~656 I0,969 1 '032 0,000 2.469 t0'962 ,006 329 ATRU~ bWD DER, bWO ROb$~ bWD PEr, bWO DRHO laND DER, laND ROb~'DND PEFebWD DRftO.bWD A~RU,bWD DER.bWD RObS,bWO PEF*bWD DRHO'bWD A?RU'bWD DER,bWD DRHOabWD DER,~ND DRHO.bWD A?RU~.bND PEFebND DRHO'b~D ATRU'bWD DER, bWD PEF.bWD -999,250 -999,250 -999,250 -999,250 -999,250 2,5~6 2'601 ,401 ~448 3i0 0 4, 5 4 i I~641 857 · 2,247 · 3,7 6.0 IS ?aoe Verl~tcatton btstin~ Chlumber~erAlaska Computing ~enter DCAL.LWD TNPH.bWD DEP?. SDSF.LWD RO$i.bWD DCAL.bWD DEPT. ATRD,bWD $~$F.bWD Ro$i.bWD DCAL.bND ?NPH.bND DEP?. AIRD.bWD SDSF.bWD RO$1'.bWD DCAb'bWD ?NPH.bWD DEP? A?RD bWD s~s~ bWD RO$1bWD DCAb bWD D£PT. 8DS~'bWD RQS!,LWD DCAL,bWD TNPH.bWD: D~PT ~ ATRD bWD ROSIbWD DCAL bWD DEPT...' ROSI,bWD DCAL,LWD TNPH,bWD 0.356 DPHI,LWD 45.242 GR.LWD 9400,000 ATR.LWD .253 PSRU,bWD 29 ,750 DROR bWD 0.264 RO$2:bWD .42! DPHI.bWD 40.649 GR.bWD 9300,000 ATR,bWD 29~,434 PSRU,LWD · 875 DROR;bWD 2,428 ROSR*bWD 0, 16 DPH/ebWD 41, 25 GR,bWD 9200,000 A?R,bWD 2,40? PSRU,bWD 230*43B DROR,bWD ,467 ROS 'i72 DPH{'bWD,bWD , oo,ooo . 3,492 PSRU,bWD 999,250 DROR,bWD, '999,250 RO$2'bWD -999~250 GR. 9000'000 A?R'~wU ,$00 DROR,,bWD ~ DPHI,bWD 18 ,75 DROR'bWD 366 RO$2,bWD 1~8 DPHI.LWD 8800,000 A?R,LWD 495 PSRU.LWD ROS2.LWD 5-FEB-1991 13125 !9 443 106;247 2,086 0.815 ,2!2 2,373 16.805 103.363 3.159 3'544 24 188 ,733 3,276 4.065 - 99,256 * 99.1~0 "999, 0 176,101 74,992 .247 o~ 3,,. 415 4,2 78 0,1.11 2,349 ,657 DPOR,bWD PSR,bWD PSRD,bWD DRHOebWO RHOB,~WD DPOR,~ND PSR,LWD PSRD.bND DRHO,bWD RHOB.bND OPOR.bWD PSRD'bND DRHO~bWD RHOB~bWD DPOR~bWD PSR'bWD P&RD~bWD DRHOi;bWD RHOB~,bWD DPOR~LWD PSR~bWD PSRD,bWD DRHO~bWD RHOB~bWD DPOR.bWD PSR,bND PSRD~bWD DRHO~bWD RHOB,bWD DPOR.~bWD PSRD'LWD DRHO'bND RHOB,bWD DPDR,bWD 19.443 2.630 2,462 0,000 2.373 i6.805 3.527 .3'5i0 -,()_, 2~',265 2,292 -0,019 li'440 ,933 -999,250 3,!385 3, i $ ? 0,026 :2..320 19.974 ,6556 · 6, .i 35 , ,369 15,.81.5 DRHO,LWD ATRU,bWD DER.bWD ROLS,LWD PEF,bWD DRHO.bWD ATRU,bWD DER,bWD RObS,lIND PEF*LWD DRHO,IIND A?RU*bWD DER,bWD ROL&,bWD DRHO'IIWD DER*, bWD RO~$,IIWD PEr~bWO DRHO,b~D A?RU'IIWD DER.LWD ROL,5,bWD P~r*bWO DRHO,bWD ATRU. ~WD DER, ROBS, bWD DRHO;SWD '0,004 1,936 ,365 '264 , 2'Io 2:~:844 0.01,I: Tape Verification Listing chlumberger AlasKa Computing Center DEPT.bND ATRD, SDSF.bND ROS1.LND DCAL.bWD ?NpH.bWD DEPT.~ ATRD,bWD SDSF.bND TNPH.bWD DE~T.~ SDSF.'~WD DCRb*bND TNPH,bWD sPsF DEPT, ATRD,~WD DCAb,,bWD A?RD,bND SDSF~bWD DCAL,b~D TNpH,bWD DEP?.. ATRD.~WD SDSF,bWD R~Sl,bWD DCA5~bWD TNPH.5WD DEPT,~: ATRD,~D RO$1,bWD DCAL,,LWD 8700.000 2.608 214,375 0,1'52 42.331 8600,000 850~,000 ~79,$08 2,3~0 0.015 40.~44 0 44' 5'O 8300"000 33.442 8200,000 179,500 8000,000 2.453 ~80.203 2,319 0.045 37,698 ATR.bND PSRU.bWD DROR.bWD RO82.bND DPHI,bND GR.b~D ATR.bWD P$RU,bWD DRORbWD RO$2 bWD DPH! bWD GR bWD A?R..bND P$RU,bND DRORabND RO$2,bND DPH.~,bND GR,bWD A~R~bWD PSRU,bWD DROR,bND RO82,bND GR~WD A~R~bWD .P$RU.,bWD DROR~bND RO82:,b~D DPHZ.,DND GR',bWD A?R,b~D PSR. U'bND DROR,bND ROS2ebND DPH~.bND GRibWD A~R.bWD PSRU,bWD DROR,~WD RO$2.bND DPH~*bWD GR..~ND ATR'LWD PSRU..bND DROR'bND ROS2..bND DPHi.bND GR.bND 5-FEB-iggl 13125 507 P$R.bND 0,080 DRHO~ND 2.]06 RHOB,~ND 20,$S2 DPOR,~D 121.393 3,045 2. 785 . P$RD, bND :425 -0, 2 DRHO.bND ~0,00! 14. 4 DPOR,bWD 115.339 PSR. laND PSRD,bWD DRHO...bND RHOB~ bND .DPOR'bND P$RD DRHO laND RHOB bND DPOR bWD P$R, :bWD eSR.D, laND DRHO, bND RHOB,bND DPOR, laND PSRD,bND DRHO, bWD RHOB.'.bND DPOR, bWD PSRD,b~D DRHO~bWD R H 0 B * b N D DPOR. bND PSR ~, bWD PSRD.~ bWD DRHO,, bWD RHOB bWD DPOR .bND 3'~36 4, O0 0,~. 13 II'°°° ,'6~6 1.5,704 '3,$24 3,'g~2 0'096 2,~84 ~2.:18e ~55,540 .S92 0.0~! 2~ .268 ~69 .0 44'45~ · . .!11 -,0.01~ 2,2e 22.:2~ 7 93'7 -0. 7 :.2-536 .2,482 0.' 010 2,268 .,23~169 592 61~ A?RU'bND DER.bND ROb$.bWD PEF,bND DRHO.bND ATRU,bWD DER.bND ROb$.bWD PEF-bND DRHO,bND A~RU.bND DER,bND DRHOelaND A~RU.bND .DER,bND RObS,laND DRHO,bND DER~bWD ROb$,bWD PEr,bWD DRHOabND DER,bWD PEr~bND DRHO.bWD DER,bWD RObS,bWO PEF.jbWD A?RUjbWD DER,~WD PEF*~WD DRHO,bWD 2'413 '800 -0, 1,6 4,05? 2,~88 .4,040 · ,,Or6 3;059 ..OoOla Tape Verification Listing chlumberger AlasKa Computing Center PAGE~ DEPT.~. ATRD.LWD ~DSF.LWD ROS],~WD TNPH.LHD DEPT, ATRD LWD S Sr: WD ROSl,LWD DCRb,LND TNpH.LND DEPT, ATRD,bWD SDSF,bWD R@~bWD DCA~.bWD TNP~'WD D~PT ~ ATRD ~WD SDSF LWD RO$1 ~WD DCAb bWD TNPH LWD ATRD..bwD SDSr;LWD RO$'tobWD DCAL,LWD TNpH,bWD ATRD,bWD ROS1,LWD TNPH,LWD A?RD,LWD SDSF,LWD ROS~.tWD DCAL~hWD TNPH'LWD DEPT.~ ATRD.bWD 8DSF,~WD ROSI.LWD DCAL.L~D 7900,000 ATR.LWD 2'725 PSRU,LWD 174,.180 DROR.LWD 2.294 ROS2,bWD 0.034 DPHI,LND 33,051 GR,bWD 7800.000 ATR,EWD 337 RO$2.LWD 0,000 DPHI,L~D 38,414 GR,bWD 7700,000 ATR,bWD 2,685 PSRU.bWD 176,668 DROR'bWD '2,268 RO$2.bWD 0,062 DPHI'bWD 34,414 GR'~WD ? oo'ooo 781 PSRU,bWD 0 DROR,EWD 9 GR'bWD 7500'000 ATR,bWD 2~836 PSRU*bWD 188'906 DROR'LWD ,27 6 RO&2'bWD ~118 DPHI,bWD 35'187 GR,bWD 4oo,ooo DROR,bWD 17~:i14 PSRU,LWD 2, ROS2,LWD . DPHi,LWD~ o0"ooo 2.,)59 PSRU~bWD' 191,063 DROR', WD ,24 ROS2.,~WD · 0,04~ DPHI.,bWD 35,772 GR,LWD ? oo'ooo 23~,~56 PSRU~bWD ,344 DROR*LWD 2~369 ROS2"bWD 0i355 DPHI'bWD 2,675 2,826 0,018 2,282 2~.316 8 .416 2,609 2,8~0 0,0 0 21,~7 106.726 2 606 00~ 2.7!5 2,987 0'112 2,34 .243 ,0~0 84,588 2,839 2'989 0;008 2~827 7~ '907 ,784 .769 12, PSR,LWD PSRD,LWD DRHO,bWD RHOB,bWD DPOR,:LWD PSR bWD PSRD bWD DRHO bWD RHOB {.,WD DPOR LWD PSR'bWD PSRD,'bWD DRHO.~bWD RHOB+bWD DPOR',bWD .PSR~IL, WD PSRD,[.,WD DRHOibWD RHOB,bWD DPOR*bWD PSRD* bWD DRHOa{,WD RHOB,{.,WD DPOR,bWD PSR,bWD PSRD,bWD DRHO,bWD RHOB,bWD DPOR,bWD , PSR,bWD PSRD'.bWD DRHO~bWD RHOB,bWD DPOR'bWD PSR,bWD PSRD,bND DRHO*bND RHOB,bND DPOR,bWD 2.729 2.638 -0.008 2 731 2 618 -0 015 2 291 21 785 2.684 .2,&08 0.01_3 2,247 24.423 0,0I~ '2'26 23,08.8 ",0,0 ~i 2-2 24,881 .2-63~5 0.00 2.96_6 · . ,012 ~ 491 ATRU:~WD DER ND ROL$.LWD PEF.bWD DRHO.bND ATRU'bND DER,LWD RObS,~WO PEF,LWO DRHO,bWD A?RU,bWD DER,bWD ROLS,bWD PEF,LWD DRHO.b~D ATRU~bWD DER,bND ROb&~bND Pgr*bWD DRHO,bND A?RU'bWD DER,.bWD ROb$*bWD PEr*bWO DRHO.bND ATRU,LWD ROL$,LWD PEr,bwO DRHO,b~D ATRU'bWD. DER'LWD ROLS'LWD P'EF,~LWD BRHO,bWD A?RU,bWD DER,LWD ROL$,LWD DRHO,bND cl~lumberqer Alas~ca Computinq Center 5-FEB=IgC1 13~25 PAGEI I0 TNPH"LND DEPT. ATRD.LND SDSF.LWD RO$1.~WD DCAL.bND TNPH.EWD DEPT,~ RTRD,bWD SDSFebND DCRL,bND TNPH.bND DEPT. SDaF,bWD ROalebWD DCAb.bWD TNPH.bWD DEPT~ ATRD bWO R051 DCAL bWD TNPH bWD DEPT,~ ATRD'bWD SDS'F.~LWD ROS~,b~D D~Ab.bUD D£PT, RTRD,bND RO&I*L~D DCAL.b~D TNPH,b~D D~PT, ATRD,LUD ~SDSFebWD RO$!,bWO DCAL.bWD TNpH.bWD DEPT.: ATRD.bWD SDSF,LWD 35.657 GR.bWD 72.076 PSRU.LWD 2.719 PSRD.bWD 557 DER.bWD i,656 18 7 DROR.bWD 0,021 DRHOebWD - 009 ROL$.bWD ,228 42 DPHI.bWD 2 .344 DPOR.LWD 2 344 DRHO.bWD -0 39.605 GR.bWD 87.152 7000,000 828 2O$ 044 6900'000 2,374 37,2t2 6800.000 2,326 197,004 2'237 0;082 4!',064 18~ 4 4~ 66001,000 189,+898 2;237 0,056 39,321 6500'000 2,444 175,313 2'262 0+04~ 38;~05 64001~000 18 242 223 ATR,LWD PSRU.bWD DROR.bWD ROS2.bWD DPHI,LWD GR*LWD A~R bWD PSRU LWD DROR bWD R052 bWO DPH! bWD GE LWD PSRU,LWD DROR.bND ROS2,bWD DPHI~LND ATR,bWD PSRU,bWD DROR'bWD RO$2~LWD~ DPHi.bWD GR.bWD PSRU~bWD DROR~bWD RO${:.ibWD DPUR,b~D ATR,.LWD PSRU,~W DROR,LW~ ROS2.LW DPHI,b~ ATR,LND PSRU.'~ND DROR,~WD RO$2,LND 2,907 2.959 0.064 25,0 86,'/ ~63 ,3:~4 ~,474 0,0~0 89.526 3 3 24,947 79'.315 2 2½5 88 ~.4~ ? 2,5_95' o,o2½ 26'2 2 84,214 2,, 425 ,500 20.004 2,242 ~PSR,bWD 2'928 ATRU,LWD PSRD,bWD 2'896 DER,bWD DRHO,bWD 0,000 ROLS,bWD RHOB.bWD 2.237 PEF'bWD DPORebWD .25,-004 DRHOebWD PSR,bWD .2.~118 ATRU'bWD PSeO.bWO .2'0'/5 D.Ho,[,,wD RHOB.bWD . ,2,, ! DPOR,bWD .26,352 DRHO.bWD · PSR,bWD DER.bWD PSRD.bWD '~ ATRU.bWD DRHO,bWD "0:::920 ROb$,bWD DPOR,bWD PSR:. bWD PSRD,b~D DRHO,bWD RHOB,bWD DPORebND PSR,LWD PSRD,bWD DRHO,b~D RI. lOB DPOR.bWD PSR,bWD PSRD,b~D DRHO, LWD · 22 437 ~'97 -0 ~.i2 2,568 '. ~oi 2 6..2 3 2..482 2'464 :0' 005 2.242 ATRU LWD RDER bWD ObS LWD per bwo DRHO bWD ATRU,[,WD DER.bWD RObS~bWD PEr ~ LWD DRHD.bWD DER,b~D ROL~.LWD PE ,LWD o;o -0,013 ,2,$08 460 IS Tape Ver~flcation L! chlumbergerAlasKa Comp DCAb.bND TNPH.LWD DEPT A?RD SDSF bWD RO$1 DCAL TNPN ATRD.bWD SDSF.bWD RDSl.bWD DCAb.bND TNPH.bWD DEPT. A?RD.bND SDSF,LWD ROSl,bWD DCAL,bWD TNPH,bWD DEPT S~SF,LWD ROSI.bWD DCAb,bWD TNpH.bWD PEP?' ATRD.'~WD SDSF,bWD D¢~b,bWD TNPH,bWD DEPT. ATRD.b~D SDSF*bWD ROS~.LWD DCAL,bWD :TNPH,LWD D~PT.: A?RD,LWD SDSF.~WD ROSI.~WD TNPH.bWD 0 07 6300.000 2.697 2, 0.116 41'205 6200 000 3 S29 22703 36 431 61.00,000 180 2,240 0, ~ 00 40,465 6000'000 5900,000 ' 3* 185'008 2,'08~ 0~068 42'824 5800'0i0 4: i~ 7 · 39 898 5700,000 3.407 251;484 20 sting uttng Center DPHI.LWD GR.LWD ATR,bWD PSRU.LWD DROR,bWD ROS2.bWD DPH! GR:bWD bWD ATR.bWD PSRU,LWD DROR,bWD ROS2.b~D DPHI,bND GReLWD ATR~bND PSRU,bWD DROR~bWD ROS2'bND DPHZ~bND GR:.bND 'PSRU'b~D DROR'b~D RO82'b~D DPH~,bND GR,bWD ATR,bWD PSRU.b~D OROR*b~D ROS2,bWD DPH~bWD GR:'bWD ATR bWD PSRU bWD DROR bWD ROS bWD DPH bWD GR bWO ATR,bWD PSRU.bWD DROR,bWD ROS2*bWD DPHi'bWD GR.LWD 5-FEB-1991 13125 24.756 80.111 2.739 2.799 0,058 2,227 25.648 79.866 · 3~314 3,067 0.i88 2,408 14.6§ 61,451 3,109 0 6 .387 ~,202 .1 2,1 0 68.6 4,476 4.294 09I 0 9 2 042 110~,066 DPOR.LWD PSR,bWD PSRD, bWD DRHO.b~D RHOB,bWD DPOR.bWD PSR.bWD PSRDebWD DRHO. {.,ND RHOB' {aND DPOR.bND PSR,{,,ND PSRD.L, WD DRHO.bND RHOB. bWD DPOR.bWD PSRD DRHO RHOB bWD DPOR P~RD' ~WD DRHO, EWD RHOB,bWD DPOR' bWD 24"756 3.262 4O8 14'663 'i024 043 ol; ,,2 23 25 35~ -3,.t67 0,014 2,460 :29-.684 -0,008 25,210 2'27~ 23,04 DRHO.bWD A?RU'bWD DERebWD RObS.I.,WD PEr' bWO DRHO.bWD ATRU.bWD DER.bWD RObS.bWD PEF;bWD DRHOebND DER bWD RObS pglr bWD DRHO bND ATRU'.bND DER"L, ND RObS'L, WD eEr*bWP DRH. O~tbWD ATRU,bWD DER,bWD RObS,bWO PEr .bwo DRHO. L, WD DER,bWD RObS'L, ND P E F .' b W P DRHOebND DER,bWD RObS,bWD PEF'bWD DRH0'bWD 0,005 ,7 2 .3,037 4'4ss 4'888 ,. -,0 2 4,3~6 c~lu~ber.~er ~lasl<~ ¢o~putln~ Center ATRD LWD SDSF LWD ~OS! LWD DCAL LWD AT~D,~WD SDSF.LWD ROS~,GWD DCAL'~WD TNPH,~WD DEPT, ATRD,hWD SDSF ROS1 ~WD DCAL ~WD TNPH bWD DEPT,~ ATRD,~WD $~SF~LND D~,~WD TNPH,~D ATRD,~WD SDSF~WD ROS. I,~WD DCAL.'bND TNPH,bWD D~P? ~ ATRD bWD ROSl UWD DCA'~ TNPH GWD D~PT,~ ATRD,bWD R~S~.,bWD DCAL,bWD TNpH,LWD 5600,000 ATR.GWD 3 953 PSRU,LWD i DROR.bWD 0,~17 DPHI,bWD 42. 06 5500.000 2.723 PSRU.LWD t85,703 DROR.bWD 2,222 RO$2.bND 0.048 DPHI*bND 42,514 GR.bWD , oo: oo 3 88 PSRU'bWD 179;500 DROR~bWD 31 GR.bWD 5300,000 ATR,bWD 3'503 PSRU,bWD 176,398 DROR'bWD 2,'248 RO$2~bWD 41,304 GR.bND 5200'000 163 DROR;bND 3,096 RO$2,E~D 55 17 GR,bUD ~100.,000 ATR.GWD 999,250 225,859 DROR,~WD ' RO$2~WD 53 DPHI,bWD 56~653 GR.b~D -999,250 PSRU;hWD -999,250 DROR~b~D '999'250 DPHi~L~D -999,250 GR'~D END OF DATA 5-r£B-1991 13:25 3.898 3 637 0 ~12 2 97 2 ?? 9~ 867 PSR'bWD 3.761 PSRD,bND 3,891 DRHO,bWD '0,01~ RHOB,bWD -2.29 DPOR,bWD .2~.377 ATRU.bWD DER.bWD RObS.bWD PEF.bWD DRHO.LWD 33~,844 ,805 .251 ,t56 ' ,013 2,613 PSRD:bND .~769 0,023 DRHO,bWD 022 2,165 RHOB,bWD ' e5 83.022 PSRD,bWD 58 03 pSRD*bND 3.620 0 : 73 RHOB,~WD li:100; DRHO,bWD :-0'02S PSRD,b~D .4~79 041 DRHO'bWD ~0."307 ,84 bW 4 139 RHOB, O DPOR,bWD :28,239 43.677 ATRU~ DER ROb& DRHO 2'802' 2.1!5 bWD .- ; bWD ,,, 022- ~999,250 GWD ': ATRU,b -999.250 ~:587 DRHO.bWD : .,0i-2:4 -999,2 0 PSRD bWD -'999,2~0 DPOR 5WD -999,:250 DRHO.LND :-999 W250 "999,25 · Yerl~lcatton Llsclnq Tmbeap Alaska Computtnq Center Chlu rqer S-FEB-199! 13:25 **** FILE TRAILER *'8' FIL~ NAME : EDIT ,001 SERVICE : FLIC VERSION : O01A06 DATE ~ 91t02/ 5 MAX AEC SIZE ~ 1024 FIL~ TYPE : LO LAST FILE ~ **** TAPE TRAILER **$* SERVICE NAME : EDIT DATE I 91/02/ 5 ORXGIN : FLiC TAPE NAME . : 74269 C NTINUATXONO ~ : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK RIVER, 1L-22, 50-029~22114 **** REEL TRAILER **** SERVICE NAME : EDIT, DATE :' 91/02/ 5 ORIGIN : FLIC REEL NAME:i ~ : 74269 C~NTINUATXON # l PREVIOUS REEL ~ COMMENT : ARCO ALASKA INC., KUPARUK RIVER, iLm~2, 50-029~.~2~14 JJJJJJJJJ JJJJJJJJJ JJJJJJjJJ 4 4 ]33 7 4 4 3 3 7 4 4 3 744444 3 7 4 3 7 4 333 7777 7 7 7 77 SSSSSSSS SSSSSSSS SS SS SS SS SSSSSS SSSSSS SS SS SS SS SSSSSSSS SSSSSSSS AAAAAA MM MM bb !!XlXZ AAAAAA MM M~ bb XXXXXX AA AA MMMM MMMM bb IX AA AA MMM~ MMHM bL IX AA AA MM MM MM~ X X~. 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