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193-020
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:NSK Wells Integrity Eng CPF1 & CPF3 Subject:10-426 form from 1H PAD on 8-23-25 Date:Sunday, August 24, 2025 8:41:47 AM Attachments:image001.png MIT KRU 1H PAD SI TESTS 08-23-25.xlsx Good Morning, Please see the attached 10-426 form from the non witnessed shut in MITIA’s that were conducted on 8-23-25. If you have any questions please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .58+ 37' non witnessed shut in MITIA’s OPERATOR:FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1930200 Type Inj N Tubing 2300 2300 2300 2300 Type T 6334 BBL Pump 1.1 IA 460 1760 1730 1725 Interv 1584 BBL Return 1.0 OA 10 10 10 10 Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1921290 Type Inj N Tubing 200 220 220 220 Type T 6489 BBL Pump 1.7 IA 170 1820 1780 1775 Interv 1622 BBL Return 1.6 OA 130 320 320 320 Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 2180310 Type Inj N Tubing 0 0 0 0 Type T 3737 BBL Pump 1.4 IA 250 1810 1770 1760 Interv 1500 BBL Return 1.4 OA 20 30 30 30 Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type T BBL Pump IA Interv BBL Return OA Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type T BBL Pump IA Interv BBL Return OA Resu TYPE TEST Codes INTERVAL Codes Result Codes 1H-18 1H-20 1H-110 p, Kuparuk / KRU / 1H Pad Arend 08/23/25 9 9 9 9 9 9 999 9 9 -5HJJ 1H-18 1`l 30 ZDV Regg, James B (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> 36 ,/ Sent: Thursday, August 12, 2021 8:39 AM �Cje'1 '0(?'C'z( To: Regg, James B (CED); Wallace, Chris D (CED); Brooks, Phoebe L (CED); DOA AOGCC Prudhoe Bay Subject: Recent KRU SI MITIAs Attachments: MIT KRU 2C-03 SI TEST 08-10-21.xlsx; MIT KRU 1 H PAD SI TESTS 08-09-21.xlsx; MIT KRU 2D PAD SI TESTS 08-09-21.xlsx; MIT KRU 1 H PAD SI TESTS 08-08-21.xlsx Em Recent non -witnessed SI MITIAs performed in Kuparuk. Please let me know if you have any questions. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regg(a)alaska.gov: AOGCC.Inspectorsna.alaska.gov: phoebe. brooks@alaska.gov OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1 H Pad 08/08/21 Green / Hills chris.wallace(a)alaska.gov Well 1H-09 - Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1930290 - Type Inj N Tubing 2310 2310 2310 2310 Type Test P Packer TVD 6468 BBL Pump 3.5 IA 810 3225 3155 3130 Interval 4 Test psi 1617 BBL Return 3.4 OA 310 650 650 650 Result P Notes: Well 1H-18 - Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1930200 Type Inj N - Tubing 2410 - 2410 - 2410 _ 2410 Type Test P Packer TVD 6334 BBL Pump 1.3 IA 140 1900 _ 1860 - 1850 Interval 4 Test psi 1584 BBL Return 1.3 OA 10 10 10- 10- Result P Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBI -Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval 4 - Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Form 10-426 (Revised 01/2017) MIT KRU 1H PAD SI TESTS 08-08-21 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,August 21,2017 TO: Jim Regg P.I.Supervisor 1\)'dC) S Zt(� SUBJECT: Mechanical Integrity Tests ( CONOCOPHILLIPS ALASKA,INC. 1H-18 FROM: Brian Bixby KUPARUK RIV UNIT 1H-18 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry-J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1H-18 API Well Number 50-029-22341-00-00 Inspector Name: Brian Bixby Permit Number: 193-020-0 Inspection Date: 8/17/2017 Insp Num: mitBDB170817165020 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1H-18 Type Inj W 'TVD 6334 - Tubing 2050 2050 2050 2050 - PTD 1930200 " Type Test SPT Test psi 1584 - IA 1040 2800 2760 " 2750 - BBL Pumped: 1.6 " BBL Returned: 1.6 OA 500 700 " 700 - 700 - Interval 4YRTST P/F P Notes: SOWED _:.r,a 2 y Monday,August 21,2017 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. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs-of various kinds [] Other COMMENTS: Scanned by: ~ Dianna Vincent Nathan Lowell D TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: is~ • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,August 27,2013 TO: Jim Regg Cr(-7 I P.I.Supervisor 3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1H-18 FROM: Jeff Jones KUPARUK RIV UNIT I H-I8 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1H-18 API Well Number 50-029-22341-00-00 Inspector Name: Jeff Jones Permit Number: 193-020-0 Inspection Date: 8/11/2013 Insp Num: mitJJ130822144229 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1H-18 " ype nj IT I • W TVD 6334 IA j 850 2800 - 2760 - 2760 PTD1 1930200 - 1Type Test]SPT Test psi 1584 OA F 500 720 - 720 720 p Interval 4YRTST _IP/F 1 „- Tubing] 1650 1650 1650 1650 ' - Notes: 1.3 BBLS diesel pumped. 1 well house inspected,no exceptions noted. SCANNED DC 0 9 ZOO Tuesday,August 27,2013 Page 1 of 1 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 14, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 1H -18 Run Date: 7/8/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1H -18 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 22341 -00 61'1 q PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.wood @halliburton.com IIII Date: )(, Signed: Q 1 93-0 Page 1 of j • • Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Thursday, June 16, 2011 11:07 AM To: Maunder, Thomas E (DOA) Subject: RE: May 2011 Monthly failed MIT Monthly Data. Tom, I am unaccustomed to customary inclusions and appreciate the assistance. I reviewed the report, 1H-18 was added as it is suspected to have T X IA communication following a failed MIT -IA. All other additions / changes were bleed events. Ian Ives C� Problem Well Supervisor \ l' ) ?C) DHD Lead Technician AES Central Shops Phone: (907) 659 -7224 Pager: 909 JUN 6,113 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, June 16, 2011 9:24 AM To: NSK Problem Well Supv Cc: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: May 2011 Monthly failed MIT Monthly Data. Ian, am just starting to look at the monthly report. It has been customary to provide a quick summary of new additions and deletions. Were there no changes for the month? I include the text from last month's report for reference. Thanks in advance for your response. Tom Maunder, PE AOGCC Jim /Tom /Guy, Attached for your records is the ConocoPhillips April 2011 monthly injector report. Wells added to the report: 2W -10: Failed State witnessed MITIA 2X -05: Surface casing leak Wells removed from the report: None Please contact me at your convenience if you have questions or comments. 6/16/2011 • • ConocoPhillips Well 1H-18 Injection Data • Water Injection *Gas Injection I 4000 3500 3000 - .°_) 2500 7) a 2000 0 • • • • 1500 1000 - 500 - 0 0 500 1000 1500 2000 2500 3000 3500 4000 4500 Injection Rate, bwpd or mscfpd Date of Water Gas Injected Tubing IA Pressure OA Pressure Injection Injected Pressure (mscfpd) (psi) (psi) (bwpd) (psi) 31- May -11 2279 0 1858 2350 400 30- May -11 2456 0 1903 2350 400 29- May -11 2562 0 1926 2300 450 28- May -11 2560 0 1923 2300 450 27- May -11 2554 0 1911 2300 500 26- May -11 2563 0 1903 2300 500 25- May -11 2535 0 1887 2200 500 24- May -11 2444 0 1860 2200 400 23- May -11 2389 0 1846 2200 500 22- May -11 2516 0 1877 2300 400 21- May -11 3057 0 1995 2300 450 20- May -11 3232 0 2036 2000 500 19- May -11 3922 0 2184 2450 500 18- May -11 3166 0 2109 2100 400 17- May -11 1936 0 1936 250 50 16- May -11 1927 0 1930 250 50 15- May -11 1941 0 1934 250 50 14- May -11 2002 0 1954 250 50 13- May -11 2203 0 2017 400 50 12- May -11 2179 0 2010 250 50 11- May -11 2265 0 2036 400 50 10- May -11 2323 0 2048 400 50 9- May -11 2329 0 2048 400 50 8- May -11 2300 0 2042 350 20 7- May -11 2331 0 2055 350 20 6- May -11 2232 0 2033 280 20 5- May -11 2343 0 2063 280 20 • • 4- May -11 2300 0 2054 280 20 3- May -11 2222 0 2029 150 20 2- May -11 2152 0 2008 150 20 1- May -11 2348 0 2052 200 20 30- Apr -11 1915 0 1933 200 20 29- Apr -11 1942 0 1945 200 20 28- Apr -11 1953 0 1942 200 20 27- Apr -11 1904 0 1923 200 20 26- Apr -11 2048 0 1970 300 20 25- Apr -11 2105 0 1987 300 100 24- Apr -11 2086 0 1980 300 100 23- Apr -11 2059 0 1966 300 100 22- Apr -11 2069 0 1963 300 100 21- Apr -11 2066 0 1963 300 100 20- Apr -11 1999 0 1936 250 10 19- Apr -11 1958 0 1921 250 10 18- Apr -11 2046 0 1943 250 10 17- Apr -11 2045 0 1942 250 10 16- Apr -11 2097 0 1954 250 10 15- Apr -11 2079 0 1948 300 10 14- Apr -11 2085 0 1956 250 10 13- Apr -11 2212 0 2002 250 10 12- Apr -11 2442 0 2064 250 10 11- Apr -11 2424 0 2060 300 10 10- Apr -11 2358 0 2047 300 10 9- Apr -11 2367 0 2050 300 10 8- Apr -11 2463 0 2083 300 10 7- Apr -11 2544 0 2104 300 10 6- Apr -11 2553 0 2109 300 10 5- Apr -11 2537 0 2104 300 10 4- Apr -11 2433 0 2077 300 10 3- Apr -11 2337 0 2058 300 10 2- Apr -11 2163 0 2014 300 10 1- Apr -11 2420 0 2096 300 10 31- Mar -11 2372 0 2089 200 10 30- Mar -11 2381 0 2094 200 10 29- Mar -11 2265 0 2064 200 10 28- Mar -11 2271 0 2074 200 10 27- Mar -11 2261 0 2074 200 10 26- Mar -11 2349 0 2102 200 10 25- Mar -11 2157 0 2051 200 10 24- Mar -11 2244 0 2078 200 10 23- Mar -11 2099 0 2036 200 10 22- Mar -11 2215 0 2067 200 10 21- Mar -11 2220 0 2063 100 10 20- Mar -11 2220 0 2061 100 10 19- Mar -11 2223 0 2062 200 10 18- Mar -11 2060 0 2013 100 10 17- Mar -11 2062 0 2008 100 10 16- Mar -11 2192 0 2044 200 10 15- Mar -11 2171 0 2037 200 10 14- Mar -11 2180 0 2043 250 10 • • 13- Mar -11 1703 0 1924 300 10 12- Mar -11 1721 0 1910 200 10 11- Mar -11 1971 0 2003 200 10 10- Mar -11 1941 0 1992 200 10 9- Mar -11 2249 0 2091 200 10 8- Mar -11 2273 0 2094 200 10 7- Mar -11 2262 0 2086 200 10 6- Mar -11 2252 0 2084 200 10 5- Mar -11 2261 0 2083 200 10 4- Mar -11 2242 0 2076 40 10 3- Mar -11 2312 0 2085 40 10 2- Mar -11 2330 0 2082 110 10 • • • Tbg Psi • IA Psi • OA Psi I 4000 3500 3000 2500 ■ a • VF a 2000 «�w+ •�..•""•"'�A w M � • • • dw ""•««..w«•. • ' M '""'"«« b ,...... x 1500 1000 500 �� ■ ■ •"'•. i 0 ..... 02/11 03/11 04/11 05/11 06/11 Date J PTD 193 -020 Reason: Suspect Tx IA, failed MITIA Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878 ©conocophillips.com] Sent: Wednesday, June 01, 2011 9:51 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: Injector 1H -18 (PTD 193 -020) Attachments: 1 H- 18.pdf; 1H-18 TIO.pdf Tom ConocoPhillips injection well 1H-18 (PTD 193 -020) failed a diagnostic MITIA after the report of several thermally induced IA bleeds following a choke setting increase. The well will be SI and freeze protected and added to the monthly injector report. Leak detection diagnostics and a repair plan will be completed in the next few weeks followed by the appropriate AOGCC 10-403 or AA requesting approval. The TIO and Schematic are attached. Please let me know if you need any additional data. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. �_ �. I � 1" Office (907) 659 -7043 �' J U t Cell (907) 943 -1687 6/2/2011 CHOKE FTP FTT IAP OAP TJUO Plot -1 H -18 200 • _ 2000 — - 150 1500 _ mo — — 100 1000 50 • 500 . T _. , , F , I I F I , `--- f — rt --- 1 1 1 1 1 1 0 01- tar -11 14- Mar -11 27- Mar -11 09 -Apr -11 22 -Apr -11 05-May-11 18- flay -11 31- lay -11 Date ~ MEMORANDUM To: Jim Regg ~~~, ,~j~2~5~t7~ P.I. Supervisor FROM: John Crisp Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 24, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1H-18 KUPARLTK RIV iJNIT 1H-18 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.L Suprv .~~'' Comm Well Name: KUPARUK RIV CTNIT 1H-18 - Insp Num: miUCr090823160311 Rel Insp Num: API Well Number: 50-029-22341-00-00 Permit Number: 193-020-0 , Inspector Name: John Crisp Inspection Date: 8~21/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~/ejj ~H-18 Type Inj. N ~j'~ 6334 ~ jA 800 2800 2680 2650 ' P.T.D 1930200 ypeTest SPT Test psi 1583.5 . QA 300 540 540 520 Interval 4YRTST P~ P i Tubing 1950 1950 1950 1950 Notes• 2 bbls pumped for test. No problems witnessed. ~ ~"r~ - ~{E '~. Monday, August 24, 2009 Page 1 of 1 ~~ ~~~, ~~ ~i~~~~~~~r~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~f , ;- ~/ Log Description ~' ,'1~1'+;~~ N0. 4861 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Beluga River Unit Date BL Color CD 09/05/08 iJ-127 12096529 INJECTION PROFILE ~ - ~ 08/14/08 1 1 1R-11 12096530 PRODUCTION PROFILE 08/15/08 1 1 iJ-118 12066541 MEM INJECTION PROFILE 08/17/08 1 1 1J-122 12066542 MEM INJECTION PROFILE / 08/18/08 1 1 2D-09 11978477 PRODUCTION PROFILE (p 08/18/08 1 1 2B-14 119966275 PRODUCTION PROFILE r ~(- ~ (Q 08/19/08 1 1 1J-105 12066543 MEM INJECTION PROFILE ap'}- I(D 08/19/08 1 1 2E-12 11996653 SBHP SURVEY C, Cr-• 08/21/08 1 1 1J-156 12080419 INJECTION PROFILE ~ 08/21/08 1 1 1A-26 12080420 SBHP SURVEY ~Q -/ 08/22/08 1 1 1A-23 12080421 SBHP SURVEY ~ ` 08/22/08 1 1 2D-05 12080422 G(- ,((p - INJ PROF/LDL ~ 08/23/08 1 1 iH-11 12080423 PRODUCTION PROFILE 08/24/08 1 1 28-03A 11996656 PRODUCTION PROFILE f 08/24/08 1 1 3C-17 11996658 PERF/SBHP SURVEY ~ p~- Irp / 08/26/08 1 1 2M-11 12080427 PRODUCTION PROFILE / :r r sQ 08/28/08 1 1 1Y-21 11996662 PRODUCTION PROFILE 'r O' ~r4 08/30/08 1 1 2E-13 12080431 SBHP SURVEY G - G 08/31/08 1 1 2E-14 12080432 SBHP SURVEY ~-(•- 08/31/08 1 1 1 B-13 11996664 PRODUCTION PROFILE ~ 09/01/08 1 1 1 H-18 11996666 INJECTION PROFILE - c/ 09/03/08 1 1 F-10 11996660 PLUG SETTING RECORD 08/28!08 1 1 iG-05 11996665 PACKER SETTING RECORD 09/02/08 1 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 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate Q Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 193-020 / 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22341-00 7. KB Elevation (ft): 9. Well Name and'Number. RKB 96', Pad 54' GL 4, 1 H-18 8. Property- Designation: 10. Field/Pool(s): ~ ADL 25639 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8670' feet true vertical 6907' feet Plugs (measured) Effective Depth measured 8214' feet Junk (measured) true vertical 6547' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 4975' 9-5/8" 4975' 4144' PRODUCTION 8556' 7" 8652' 6892' Perforation depth: Measured depth: 8046'-8124', 8191'-8221' ';~~~~ ~~~ ~ 2UD8 ~c,~ L U true vertical depth: 6416'-6477', 6529'-6552' Tubing (size, grade, and measured depth) 3-1/2" , J-55 / L-80, 7971 ' MD. Packers & SSSV (type & measured depth) pkr- BAKER'FB-1' PERM. pkr- 7939' Otis Selective Landing nipple @ 2010' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 8046'-8124 ', 8191'-8221' pumped 700 bbls lake water 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 2487 Subsequent to operation 3382 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ ^~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Guy Schwartz @ 26 -6958 ~cr ~ Printed Name GUy SChw Title Wells Engineer "tf55` Signature Phone: 265-6958 Date ~"7~^~$ Pre red b haron Allsu Or ke 263-4612 Form 10-404 Re sed 04/2006 ~ i Submit Original Only i ` , +.,. Li • ;~^. ~~~~~ Conocf~Rhiltips ~-laska, ~nC. KRU 1 H-18 1H-18 API: 500292234100 Well T e: INJ An le TS: 39 de 8048 COILED SSSV T e: NIPPLE Ori Com letion: 2/15/1993 An le TD: 37 de 8670 TUBING Annular Fluid: Las[ W/O: 4/3/1994 Rev Reason: TAG FILL (1347-2001, Reference Lo Ref L Date: Last U date: 5/2/2006 OD:3.500, Last Ta : 8214' RKB TD: 8670 ftK6 ID:2.859) ( Last Ta Date: 4/23/2006 Max Hole An le: 44 de 4057 suR. Casin Strin' -ALL STRINGS CASING Descri lion Size To Bottom TVD Wt Grade Thread (0-4975, SUR. CASING 9.625 0 3118 2791 47.00 L-80 OD:9.625, Wt 36 W) SUR. CASING 9.625 0 4975 4144 36.00 J-55 . . ~ PROD. CASING 7.000 0 8652 6892 26.00 J-55 CONDUCTOR 16.000 0 121 121 62.50 H-40 Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 1342 1347 1344 9.30 J-55 EUE 8RD-MOD NIPPLE 3.500 2002 2021 1975 9.30 J-55 EUE 8RD-MOD (2010.2011, 3.500 7810 7825 6246 9.30 J-55 EUE 8RD-MOD OD:3.094) 3.500 7825 7903 6306 9.30 L-80 EUE 8RD MOD TUBING ~ 3.500 7903 7971 6358 9.30 J-55 EUE 8RD-MOD (zooz-zoz1, ~ Tubin Strin -COILED TUBING oD:3.soo, ID:2 992) Size To Bottom TVD Wt Grade Thread . 3.500 0 1342 1339 7.15 OT-800 3.500 1347 2001 1958 7.15 OT-800 3.500 2021 7810 6234 7.15 OT-800 SUR. caslNG i ( PerfOrBtIOrIS`SURImB (0-3116, Interval TVD Zone Status Ft SPF Date T Comment OD:9.625, - 8046 - 8124 6416 - 6477 UNIT 78 6 10/29/1993 IPERF 2 1/8" EnerJet III; 90 deg'V' Wt:47.00) i D,C-0,C-3 Phasin COILED ~ 8191 - 8221 6529 - 6552 C-2,C-1,UNI 30 6 10/8/1993 IPERF 2 1/8" EnerJet III; 90 deg TUBING L. g Phasin ~ 45 de Orient (zozl-7s1°' OD:3.500 Gas Lift Mandrels/Valves , ID:2.859) St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Vlv I Run Cmnt 1 7891 6297 Camco MMG-2 DMY 1.5 RK 0.000 0 4/5/1994 Other lu s e ui .etc. -JEWELRY De th TVD T e Descri lion ID Gas Lift d l/D 2010 1966 NIPPLE Otis Selctive Landin no SSSV Pulled MCX Valve on 5/25!95 2.813 in re ummy Valve 1 7938 6333 PBR Baker GBH-22 3.000 (7891-7692, - 7939 6334 PKR Baker'FB-1' PERM. 4.000 OD:5.970) 7961 6351 NIP Camco'D' Ni le NO G O 2.750 7970 6358 WLEG Baker WireLine Re-Ent Guide 2.992 7971 6358 TTL 2.992 PBR General Notes (793a-7939 Date Note , OD:3.500) 10/3/1993 Had to work tools 2.825" OD thru weld @ 1336' WLM (4/11!94) TUBING (7903-7971, - '- Three Pup Joints in Coiled Tubing Section: 3 1/2"TBG; J-55 9.3# EUE 8rd MOD OD:3.500, Pup Joint #1 1342-1347 ID:z.992) i Pup Joint #2 2002-2010 Pup Joint#3 2017-2021 NIP Otis Selective Landin Ni le 2010' has 31 /2" TBG u Join on Each Side (7961-7962, OD:3.500) WLEG (7970.7971, OD:3.500) -......... -- TTL ~ (7971-7972, I OD:3.500) PROD. CASING (0652, OD:7.000, Wt26.00) Perf (8046-8124) Pert (8191-8221) ........... ... ... ._....-- . 1 H-18 Well Work DATE SUMMARY 7/3/08 POOR BOY HIGH PRESSURE BREAKDOWN. PUMPED 700 BBLS OF 45 DEGF LAKE WATER IN 2 STAGES. STAGE 1 -TOTAL 402 BBLS STARTED 9.8 BPM AT 3575 PSI AND ENDED AT 9.9 BPM AT 3400 PSI. WHP FALLS FROM 1875 PSI TO 1700 PSI IN 15 MIN. STAGE 2- TOTAL 300 BBLS PUMPED 10 BPM AT 3300 PSI. WHP DROPS FROM 1900 PSI TO 1175 PSI AFTER 45 MINUTES. PAD OPERERATOR TO PUT BACK ON INJECTION. . )F-/ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 29, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 \Vest 7th Avenue, Suite 100 Anchorage, AK. 99501 SCANNED JAN 1 6 2007 '}fJ "3/0 \~ Dear NIr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were first filled with cement to a level of approximately 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG24 0 1 that was engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on December 16, 2006 and the sealant top was completed on December 27,2006 for 1H-Pad and December 28, 2006 for 1D-Pad. Schlumberger Well Services mixed 15.7 ppg Expando cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The 2401 sealant was pumped in a similar manner. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or M.1. Loveland at 907-659-7043, if you have any questions. Sincerely, ~-/cD~ Jerry Dethlefs ConocoPhillips Problem \Vells Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTD# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Oate Gallons Oate 1 H-01 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21' 4" 2.9 14'6" 12/16/2006 na na 1 H-1 0 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1 H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1 H-18 193-020 14'4" 2.7 12" 12/16/2006 7.4 12/27/2006 1 H-21 193-046 4" na 4" na 2.4 12/27/2006 1 H-401 198-101 45' 4.4 18" 12/16/2006 20.1 12/27/2006 1 0-109 197-235 10'9" 2.1 12" 12/16/2006 10.8 12/28/2006 1 0-11 0 200-039 8'6" 1.4 10" 12/16/2006 9 12/28/2006 10-111 198-166 17' 7" 3.4 25" 12/16/2006 21 12/28/2006 10-120 197-221 13'6" 2.9 18" 12/16/2006 16 12/28/2006 10-121 197-181 13' 2.2 20" 12/16/2006 16.2 12/28/2006 10-132 198-121 10'8" 2.0 14" 12/16/2006 11 12/28/2006 10-133 197-206 6' 1.0 6" 12/16/2006 4.6 12/28/2006 10-136 200-046 10'2" 2.0 10" 12/16/2006 6.4 12/28/2006 10-137 200-047 11 ' 2.00 24" 12/16/2006 13.2 12/28/2006 1 0-138 200-048 11' 7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 10-139 200-049 11'2" 2.2 18" 12/16/2006 9.9 12/28/2006 1 0-140 200-136 29'9" 3.4 12" 12/16/2006 na na Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk \ q 'b - 0 ~O \ H-\~ Schlumbepgep NO. 3792 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SCAj~NEü JUN 1 320Di) Field: Well Job # Log Description Date BL 1Y-29 11213739 PRODUCTION PROFILE W/DEFT (~- f..C\, 04/28/06 1 3M-25A N/A SHUT IN 8HP i ctL. - aG(., 04/23/06 1 2N-303 N/A LDL .:::> c0 - I ¿.,C; 04/21/06 1 1 R-21 11213737 PRODUCTION PROFILE W/DEFT l~I-t\3 04/25/06 1 3F-07 N/A INJECTION PROFILE / ~-)- - (~4f...- 04/23/06 1 18-16 11235353 PRODUCTION PROFILE W/DEFT IC I../-('~"":} 04/04/06 1 38-15 11213741 INJECTION PROFILE ¡ ~<L;,- ~ {' ;:)..:.,- 04/30/06 1 1 G-07 N/A PRODUCTION LOG W/DEFT I "{ ~ - ~l" \ 04/19/06 1 1 A-20 11235356 PRODUCTION LOG W/DEFT 1'10 - III' ~ 04/26/06 1 1H-18 N/A INJECTION PROFILE ¡c(~ - t'¡~b 04/24/06 1 1 R-12 11213738 PRODUCTION LOG W/DEFT I ~':> -O'ì?l 04/27/06 1 1Y-13 11213740 INJECTION PROFILE 1'""62> - C' \.ç- 04/29/06 1 2N-318 11213742 LDL dOO -lOb 05/01/06 1 1 Q-08A 11213743 INJECTION PROFILE I ~'1 - -'C -~ 05/02/06 1 1G-01 11213744 INJECTION PROFILE ¡Ÿd-- l~b 05/03/06 1 3J-17 11258704 PRODUCTION LOG W/DEFT }c,~ - (L(-r 05/04/06 1 1 R-26 11258705 INJECTION PROFILE -¡ (1 - ('] C. '::t 05/05/06 1 2A-04 11249902 INJECTION PROFILE ì <:.(1 -l~<~ 05/06/06 1 1 G-06 11249903 INJECTION PROFILE I 15 ri - ;:}~t"-, 05/07/06 1 1 E-18 11216193 MEMORY PRODUCTION PROFILE 1~2,~.- t~ 05/07/06 1 1G-14 11249904 INJECTION PROFILE 1-4<-:?'--/"-/1 05/08/06 1 05/09/06 e Color CD e Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM TO: Julie Heusser ~ Commissioner _ State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 6, 2001 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~_~r~.o,~ Phillips Alaska Inc. P.I. Supervisor/~J,- "~"- ' ~,...~ ~,g,,.,,., 1.H Pad 3.~\-t\k 1H-12,1H-18, 1H-19, 1H-20, 1H-22 FROM: Jeff Jones KRU Petroleum Inspector Kuparuk River Field NON.- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. wa~I 1H-~2 l'Yype,r;j:l. S. I T-V-D- I r, O8~ I Tuaml 25~o I 2560 I 2~;o I_ 2560 I,,~a~l _4 P.T:D.i 1~ ITypetesti P. IT~I 1521, I'c~ngl' 475 ! 1950 I 1925 I, 1900 ! P/F I P ,l~k~es: Monitored casin~l pressure additional 15 min. & pressqre stabilized at 1900 ~ , , . w~,,I ~.H-~s' .I'TY...Pe.,n.j.I'.. S I ¥.',v:6. I'.s333 .I TuUng. ! 2O6O I. ';;.060 I .2~.' I. 2O6O I,nte,,a,I 4 P.T.D.!1930200 ITypetestI P IT.~! ~ ICa~"gl soo i 24a0 i 2440 i 24,i0 ! P/FI _. Notes: :.'. w~,I ,.-,o I'~..~,n~.l. s ! T-Y-q' ! ~ i*ii~'l '~. ! ~"! '~ I. ~ !'~'1 .~" p-T-D.i 19212~0 i'~t~I ¢,~T~,'I 1~2 ,lC~I ~,, I 1800,~ ,!~,, I, 1~0, I P~, I E,. "w~,I ,,-~o l,,~.,.n~.l" s .i T.v-.D. ! ~"~I Tuu,ngl"27,25IL:2725 i.2725 I' 2~25":l'nterva'l 4 ' "iS:T.D.I 1921290 I,Type, testl P ITestPal !S2~,I c~ngl 750 I 1790,1 1760 ,I 1,7,50/,,P/F I E ". w~'i .~"-~ I*~'~-I''' $'1 ~-v-°' I ',~ I*uu~i ~l ~°! ~s°l ~°"1',~_'1' 4' .P.'r.D.I amr~ i-r~tm.,l, p, IT~ ,~! 1tm ICa~n~l 92o I a7501 173o1 174o1 P~ I_ P Type IN J. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test'$ Details Friday, ~ ~ 2001: I traveled to Phillips Alaska Inc.'s 1H Pad and witnessed the 4-year MIT's on wells IH-12, 1H-18, 1H-19, 1H20 and 1H-22. The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed with all five wells passing the MIT's. Summary: I witnessed successful 4-year MIT's on PAI's wells 1H-12, 1H-18, 1H-19, 1H-20, and 1H-22 in.the Kuparuk River Field / KRU. M.I.T.'s performed: _5 Attachments: Number of Failures: _0 Total Time during tests: 3 h.m. MIT report form 5/12/00 L.G. MIT 1H Pad KRU 7-6-01 JJ.xls 7/16/01 ON OR BEFORE c:i~o~M.p°c PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page' 1 Date- 09/29/95 RUN DATE_RECVD 93-020 5665 93-020 407 93-020 DAILY WELL OP ~35-8669, CDN/CDR ~OMP DATE: 10/07/93 ~/0~/S~ TO ~0/08/S~ 05/26/1993 11/05/1993 11/05/1993 93-020 SURVEY ~.00-8670 11/05/1993 93-020 CBT ~L~H 03/15/1993 93-020 CDN-DC &~L~4976-8670 06/04/1993 93-020 CDR ENHANCEMENT ~988-8632 08/30/1993 93-020 93-020 CDR-DC ~4976-8670 CET ~/CH 93-020 DGR/DGWD 93-020 DGR/DGWD 06/04/1993 03/15/1993 01/28/1994 01/28/1994 04/12/1993 Are dry ditch samples required? yes ~And received? - ye% Au Was the well cored? yes ~~alysis & description re c~-~o Are well tests required? yes n~_~eceived? --~~3 -- Well is in compliance ' Initial ~OM, -~ENTS ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Aiaska 995'i0-0360 Telephone 907 278 !2!5 May 2, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION 1 H- 18 Other (conv) 1L-06 Other (sssv) 1Y-11 Other (sssv) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR050396 (w/o atch) RECEIVED MAY - 5 1994 Otl & Gas Cons. Commission Anchorage AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Stimulate __ 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 4. Location of well at surface 799' FNL, 785' FEL, Sec 33, T12N, RI~3E, UM At top of productive interval 1891' FSL, 2611' FEL, Sec 34, T12N, At effective depth 1696' FSL, 2342' FEL, Sec 34, T12N, At total depth 1659' FSL, 2290' FEL, Sec 34, T12N, 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X R10E, UM * R10E, UM 12. 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-18 9. Permit number/approval number 93-20/94-033 10. APl number 50-029-22341 11. Field/Pool R10E, UM Present well condition summary Total Depth: measured 8670 true vertical 6906 feet feet feet Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 8 5 6 4 true vertical 6 8 2 2 feet feet Junk (measured) None Casing Length Size Structural Conductor 1 2 1 ' 1 6" Surface 4 9 3 5' 9.62 5" Intermediate Production 8615' 7" Liner Perforation depth: measured 8046'-8124', true vertical 6416'-6477', Cemented 225 SX PF 'C' 960 SX PF 'C'& 460 SX Class G 265 SX Class G 8191'-8221' 6529'-6552' Measureddepth True vedical depth 121' 121' 4975' 4144' 8652' 6892' Tubing (size, grade, and measured depth) 3.5", 7.15#, QT-800 @ 7809' & 3.5" 9.3#, J-55/L-80 @ Packers and SSSV (type and measured depth) PKR: Baker 'FB-I' Perm @ 7939'; SSSV: Otis MCX Inj. Valve @ 2010' 13. Stimulation or cement squeeze summary Initiated water injection into well for testing. Intervals treated (measured) N/A Treatment description including volumes used and final pressure RECEIVED 7809'-7971' M&Y - 5 1994 14. Gas Cons. C0mm Began water injection on 4/10/94 following a workover of the well, ftp was 2350 psi. Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf WateroBbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 500 2200 Subsequent to operation 0 0 3000 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run m Daily Report of Well Operations X Oil _ Gas Suspended 17. I hereby,,c'~i~ that the foregoing is true and correct to the best of my knowledge. SiCned~'/]/~~ · ~ Title Senior Engineer 5OO 235O Service H20 Injector Form 10-404 Rev 06/15/88 ssion Date SUBMIT IN DUPLICATE RDgS MORNING WELL REPORT FOR 04-/10/94 DRILLSITE IH PRODUCTION WELL STATUS W Z S E 0 T CHORE L N A OR L E T % ! B PR 2 B TS 6 B PR I0 B PR ii C PR i3 C PR 14 C PR i5 C SI i6 B PR !7 B PR :~'-)1 C PR FTP FTT 176 333 125 41 176 350 136 63 176 331 123 27 176 335 74 2 176 340 123 54 15 2400 43 1 176 328 79 55 0 OM OM 0 176 328 83 3 176 327 38 3 176 347 98 2 / 10" WC H2S CSG CSg % PPM PSI PSI 0 1300 400 10 1500 540 25 1270 650 0 t080 300 5 1450 680 0 1250 0 10 1400 50 0 900 100 5 1300 650 5 950 220 0 50O 100 ~,}AS L!,~ ! 5!ATUS i(}O,q = 1500() 'E:)_' ~AS C:AS IN,J OPT OPT METER VOL RA]-E Ol._ READINg MSCF MSCFD ROOTS 0 1562 ! 593 6. .3 0 0 0 (}. 0 0 963 954 2. 8 0 2061 i 583 6. 3 0 0 0 0.0 0 0 0 0.0 0 26 2100 8. 5 0 0 0 0.0 0 1063 1023 D. 7 0 1293 125'7 6. 9 0 0 0 O. (} S N E C., '300 ,.:1:000 0 00 (} 0 C: 0000 C: i 73(} 63 {2400 6{3 0000 0 (}C~O0 0 (30 C' TOTALS' 6968 8510 INJECTION WELL STATUS W Z S E 0 T CHO~E 7" 10~ L N A OR INd CSG CSG L E T % PSI FTT PSI PSI INJECTION VOLUMES WATER RECMD IN,.; INd METER VOL RATE READING BBLS BWPD gas IN,J VOL MMSCF S ! D AT H M R I D 3 C PW 100 2272 149 400 300 ~ B PW 176 2277 150 1350 100 ' B SI 0 OM OM 520 0 ~ B SI 0 OM OM O~ 0 ~ C PW 100 2276 149 1160 500 ~ C SI 0 OM OM 1000 450 ~-~-~350 150 500 450 19 B PW 100 2280 149 50 200 20 C PW 100 2288 150. 300 450 ?2'2 B PW 176 2283 149 900 100 'TOTALS' SWI · 0 + PWI' 23487 = 0 1 '74.0 0 6159 0 OM 0 0 0 2404 0 0 0 1267 1836- 0 000 000(} 5936e 0 000 0000 0 0 0 000 2400 '70 0 0 000 2400 75 2459* 0 000 0000 0 0 0 000___..~ :]:3 2154~ 0 000 ()100~ 0 3405 3310- 0 000 0 3604 3037* 0.000 0 4908 5517- O. 000 23487 24249 0.000 (} C, 00 C, C, 00 0 (} 000 C.' AN * AFTER THE RECOMMENDED WATER INJECTION RATE INDICATES THAT THE WELL SHOULD BE WIDE OPEN REGARDLESS OF THE LISTED RECOMMENDED RATE. RECEIVED MAY - 5 1994 maska u~; & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown__ Pull tubing X Alter casing Stimulate __ Plugging Perforate Repair well Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 799' FNL, 785' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 1891' FSL, 2611' FEL, Sec. 34 T12N, R10E, UM At effective depth 1696' FSL, 2342' FEL, Sec. 34, T12N, R10E, UM At total depth 1659' FSL, 2290' FEL, Sec. 34, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 8670' 6906' feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 96', PAD 54' GL 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-18 9. Permit number/approval number 93-20 10. APl number 50-029-22341 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 8564' true vertical 6822' feet Junk (measured) feet Casing Length Structural 8 0' Conductor Surface 4935' Intermediate Production 8 61 5' Liner Perforation depth: measured Size Cemented 1 6" 250 Sx PFC 9-5/8" 960 sx PF E &460 sx CLASS G 7" 265 sx CLASS G 8046'-8124', 8191'-8221' MD Measured depth True vertical depth 121' MD 121' TVD 4975' MD 4144' TVD 8652' MD 6892' TVD true vertical 6416'-6477', 6529'-6552' TVD Tubing (size, grade, and measured depth) 3.5" 7.148# QT-800 X 3.5" L-80 X 3.5" 9.3# J-55 @ 7971' MD Packers and SSSV (type and measured depth) BAKER FB-1 PERM PKR @ 7939', OTIS 3.5" SLN @ 2010' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector X Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 1~'-~04' Rev' 05'~7/89 Title Area Drilling Engineer S't~BMFI/ IN DUPLICATE ARCO ALASKA INC. DAILY OPERATION~ PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1H-18 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25639 ALK 464 50-029-22341 93-20 ACCEPT: 02/07/93 07:00 SPUD: 02/07/93 02:30 RELEASE: 04/03/94 10:00 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: DOWELL 02/08/93 (1) PARKER 245 TD: 2600' (2600) 02/09/93 ( 2) PARKER 245 TD: 4995' (2395) 02/10/93 (3) PARKER 245 TD: 4995' ( o) DRILLING 16"@ 121' MW:10.5 VIS: 55 FIN MOVING RIG TO 1H-18. NU DIVERTER SYSTEM. FUNCTION TEST 20" DIVERTER. TEST WAIVED BY JERRY HERRING W/AOGCC. FILL STACK W/MUD-NO LEAKS. FIN NU DIVERTER LINES. PU 12.25" BIT & BHA. ORIENT NAVIDRIL & MWD. C/O 16" F/108'-121'. DRLG 12.25" HOLE F/121'-292' PU 6 7-3/4" DC'S. DRLG 12.25" HOLE F/292'-2600' DRILLING 9-5/8"@ 4974' MW:10.5 VIS: 42 DRLG 12.25" HOLE F/2600'-3930'_ GAS CUT MUD TO 9.8 PPG. SERV RIG. DRLG 12.25" HOLE F/3930'-4995'. CBU FOR SHORT TRIP. HOLE UNLOADING PEA GRAVEL. POOH W/41 STDS TO 1200' HOLE TIGHT & SWABBING. SLM-NO CORR. RIH-NO FILL. CIRC & COND HOLE FOR 9-5/8" CSG @ 4995'. HOLE UNLOADING PEA GRAVEL. POOH TO RUN 9-5/8" CSG. HOLE TIGHT F/2200'-1750' FIN BOP TEST 9-5/8"@ 4974' MW:10.5 VIS: 41 LD MWD, MOTOR, 2 STAB, & 1-MONEL DC-HOLE TOOK 16.5 BBLS OVER CALC. RIG TO RUN 9-5/8" CSG. HOLD SAFETY MEETING W/TOOLPUSHER & ARCO REP. RUN 9-5/8" CSG W/21 CENT. TIGHT HOLE @ 1972'_ MU TOP DRIVE IN 9-5/8" CSG. WASH THROUGH TIGHT HOLE F/1972'-3116', CONT TO RIH TO 4974', MU LANDING MANDREL. CIRC & RECIP PIPE, COND HOLE FOR CMTING. RU HALLIBURTON, TEST LINES TO 3000 PSI, CMT 9-5/8" CSG W/371 BBLS, 12 PPG LEAD & 94 BBLS 15.8 TAIL. USED 3-PLUGS. RECIP PIPE WHILE CMTING. FULL RETURNS, 17 BBLS 12 PPG CMT TO SURF, BUMPED PLUG W/2000 PSI, BLED OFF, FLOATS HEAD. CIP @ 22:30 HRS. RD CSG TOOLS, LD CMT HEAD & LANDING JT. ND DIVERTER LINES, WASH CMT OUT OF DIVERTER VALVES & BAG. PACK DRY CMT AROUND MANDREL HGR. INSTALL JUNK RING. MU 11-3/4 BTC X 11" 3M FMC SPEED HEAD, TORQUE TO 15K FT/LBS. NU BOP. TEST ALL BOP EQUIP. TEST WITNESSED BY AOGCC INSPECTOR DOUG AMOS. WELL: 1H-18 API: 50-029-22341 PERMIT: 93-20 PAGE: 2 02/11/93 ( 4) PARKER 245 TD: 7583' (2588) 02/12/93 (5) PARKER 245 TD: 8263' ( 680) 02/13/93 ( 6) PARKER 245 TD: 8494' ( 231) 02/14/93 ( 7) PARKER 245 TD: 8670' ( 176) DRILL, LOG, & SURVEY 9-5/8"@ 4974' MW: 9.2 VIS: 35 LD TEST JT. SET WEAR BUSHING, BLOW DN ALL LINES. CUT 167' DRLG LINE, SET & CHECK DUO-MATIC. CHANGE OUT GRABS ON TOP DRIVE, CHANGE SAVER SUB. CHANGE BEARING SECTION ON TURBINE. PU BHA, ORIENT, PROGRAM LWD, LOAD R/A SOURCE. RIH TO 4889' CIRC & COND MUD FOR CSG TEST. TST CSG TO 2000 PSI FOR 1/2 HR-GOOD TEST. DRILL PLUGS, FC, & CMT TO 4911'. SERV TOP DRIVE & RIG. DRILL CMT, FS, & 10' NEW FORMATION TO 5005'. CIRC, TEST FORMATION @ 4160' TVD W/8.55 PPG MUD IN HOLE PRESS. 860 PSI EMW=12.5 PPG. DRILL, LOG, & SURVEY. SHORT TRIP 20 STDS 9-5/8"@ 4974' MW:ll.9 VIS: 43 DRILL, LOG & SURVEY. SERV RIG & TOP DRIVE. DRILL, LOG & MWD SURVEY TO 8263' WELL KICKED @ 1535 HRS, 8263' MWD, 6570' TVD, 375 PAI ANN, 300 PSI SIDPP, 10 BBL GAIN, 10.6 PPG MUD. WT MUD ON FLY TO 11.7 PPG, CIRC OUT KICK, OPEN BAG, MONITOR WELL. RAISE MUD WT TO 11.9 PPG FOR EXTRA TRIP MARGIN. CIRC & COND MUD, MONITOR WELL FOR FLOW 1/2 HR. SHORT TRIP 10 STDS, SWABBING SLIGHTLY FROM 7700'-7415' CIRC & COND MUD, 430 BBLS, MONITOR WELL, CIRC, MUD CUT TO 10.9 PPG. CIRC UNTIL RETURNS 11.9 PPG. PMP SURVEY, PMP SLUG. SHORT TRIP 20 STDS, HOLE TOOK CALC FILL. DRILL & LWD LOG 9-5/8"@ 4974' MW:ll.9 VIS: 44 FIN SHORT TRIP TO 6281', SWABBED SLIGHT F/7250' TO 7028' CIRC & COND MUD, MIX FINE MICA @ 10# PER BBL (MT WT CUT TO 11.0 PPG FROM SHORT TRIP). POH, MONITOR WELL @ 9-5/8" SHOE 1/4, REMOVE RA SOURCE, DOWNLOAD INFO FROM FRT, LD BHA. MU NEW BHA. INSTALL SOURCE IN FRT. RIH. FILL PIPE @ 4970' & 8063' REAM & LOG FROM 8143' TO 8263' DRILL & LOG TO 8494' RUNNING 7" CSG 7"@ 8651' MW:ll.9 VIS: 44 DRILL & LOG TO 8670'. CIRC FOR SHORT TRIP, PMP SLUG. MAKE 41 STD SHORT TRIP TO 9-5/8". RIH SLOWLY. CIRC & COND MUD FOR 7" CSG. MONITOR WELL FOR FLOW, "OK", DROP SURVEY. POH, LD 32 JTS DP. RETRIEVE SURVEY @ HWDP. REMOVE R/A SOURCE, DOWNLOAD LWD INFO, LD BHA. PULL WEAR BUSHING, RIG TO RUN CSG. HOLD SAFETY MEETING, RUNNING 7" 26# J-55 BTC CSG. WELL: 1H-18 API: 50-029-22341 PERMIT: 93-20 PAGE: 3 02/15/93 ( 8) PARKER 245 TD: 8670' ( 02/15/93 (10) HLS TD: 8670 0) ARCTIC PACK 7"@ 8651' MW:ll.9 VIS: 42 RUNNING 7" CSG, STARTED LOSING RETURNS @ 5540' RIG TO CIRC, PMP 22 BBLS SLOW & RECIP CSG-NO RETURNS. CONT TO RUN CSG SLOW, LOST 77 BBLS MUD. RIG CMT HEAD, PMP SLOW RATE & TRY TO RECIP. VERY SMALL AMT OF RETURNS, PMP 50 BBLS MUD & LOST 467 BBLS, CIRC PACKING OFF WHILE RECIP, STOP RECIP & PMP 4.5 BBLS PER MIN-NO PACKOFF. RIG HALLIBURTON TO CMT W/SHOE @ 8652' & FC @ 8564' START PUMPING PREFLUSH, STARTED GETTING FULL RETURNS IMMED, STARTED RECIP PIPE W/NO PACKOFF. BM]? PLUG W/3500 PSI, TEST CSG 1/2 HR.-GOOD TEST, BLED OFF, FLOATS HELD, CIP @ 20:55 HRS 02/14/93. MONITOR WELL, FLOWING SLIGHTLY OUT OF 9-5/8" X 7" ANN. SHUT WELL IN, MONITOR PRESS BUILDUP, ORDER OUT ARCTIC PACK & MORE CMT. RIG HALLIBURTON, TEST LINES TO 2500 PSI, PMP 300 BBLS FLUSH WATER, PMP 58 BBLS PREMAFROST C FOLLOWED BY 55 BBLS ARCTIC PACK. CIP @ 02/15/93 ARCTIC PACK 7"@ 8651' 02/16/93 ( 9) PARKER 245 TD: 8670'( 08/22/93 (18) DOWELL TD: 8670 PB: 8564 08/27/93 (11) DOWELL TD: 8670 PB: 8564 0) RIG RELEASED 7"@ 8651' MW:ll.9 VIS: 0 SHUT WELL IN & WOC. INITIAL SHUT IN PRESS=550 PSI. PRESS @ 11:00 HRS 80 PSI. BLEED OFF PRESS SLOWLY, MONITOR ANN FOR FLOW, NO FLOW, DRAIN RISER, BLOW DOWN LINES. ND, PU STACK, SET SLIPS ON 7" WITH 165,000 NET WT, BLOW DN INSIDE 7" TO 90', CUT OFF 7" WITH MANUAL CSG CUTTER, SET STACK & RISER ON STUMP, INSTALL PACKOFF & ll"-3M X 7-1/16-5M WELLHEAD, TEST TO 3000 PSI FOR 1/4 HR-GOOD TEST. RELEASE RIG @ 16:30 HRS 02/15/93. RD SWS. -SECURE WELL 7"@ 8651' MW: 0.0 RU SWS E-LINE UNIT PU GAUGE-RING/JUNK. RIH TO 8300'-CORRELATE WITH SHORT JTS. POOH. PU BAKER FB-1 PERM PKR & TAILPIPE ASSY. RIH & TIE IN. SET PKR W/TAILPIPE @ 7971' TOP OF PKR @ 7939' RD SWS. SECURE WELL. SECURE F/NIGHT 7"@ 8651' MW: 0.0 SPOT EQUIP. HOLD SAFETY MEETING. STAB 3-1/2" THRU INJ HEAD. LAY HARD LINE F/PMP TO REEL & ANN. W.O. WELDER. REPAIR ROLLER ON GOOSENECK. NU ON WELL HEAD. FILL COIL W/ll.9# BRINE. TEST STRIPPER, ANN, & ALL RAMS TO 300/3000 PSI-OK. INSTALL COIL TBG CONNECTOR. SECURE F/NIGHT. WITNESSING OF BOP TEST WAIVED BY DOUG AMOS OF AOGCC. WELL: 1H-18 API: 50-029-22341 PERMIT: 93-20 PAGE: 4 08/28/93 (12) DOWELL TD: 8670 PB: 8564 08/29/93 (13) DOWELL TD: 8670 PB: 8564 08/30/93 (14) DOWELL TD: 8670 PB: 8564 10/03/93 (15) DOWELL TD: 8670 PB: 8564 SECURE F/NIGHT 7"@ 8651' MW: 0.0 SERV EQUIP. RU CSG CREW. MU BHA. RIH W/3-1/2" CT TO 938' SHUT DOWN; RADIO SILENCE WHILE PERFING ON OPPOSITE SIDE OF PAD. RIH W/TOTAL OF 5790' CT. DRILL HOLE IN CT & DRAIN FLUID. PULL BACK THRU INJ HEAD & SPOOL UP CT. RU CRANE & CHANGE SPOOLS. STAB 3-1/2" THRU INJ HEAD. DRESS CT ENDS F/CONNECTOR. SECURE WELL F/NIGHT. DOWELL/GBR/PEAK 7"@ 8651' MW: 0.0 SERV EQUIP. HYDRAULIC PMP ON SPOOL UNIT FAILED. REMOVE PMP & WO REPLACEMENT. UNABLE TO FIND REPLACEMENT. W.O. POWER PACK. CHANGE OUT SAME. FIN BUT UP INJ LID. SECURE F/NIGHT. 7"@ 8651' MW: 0.0 SERV EQUIP. HOLD SAFETY MEETING. RU CSG CREW. MU CT LANDING NIPPLE ASSY & CT CONNECTOR. RIH. W/+ 2090' 3-1/2" -- CT, TAG UP & LAND SEAL ASSY; LOCATE W/2000 PSI-OK. SPACE OUT; SET BACK INJ HEAD; CUT 3-1/2" COIL; MU TBG HGR & LAND HGR; RILDS; TEST TBG TO 2000 PSI-OK. TEST ANN TO 2000 PSI-LOST 700 PSI IN 5 MIN. CIRC OUT TBG; RETEST TBG-CIRC ANN. BOTH SIDES WILL PRESS UP TO 1500-1700 PSI & BLEED DOWN. (FREEZE PROTECT 500' TBG & ANN). ND BOP'S & NU TREE; TEST SEALS TO 5000 PSI-OK. TEST TREE TO 250/5000 PSI-OK. SECURE WELL. TEST TBG AGAIN-SECURE WELL 7"@ 8651' MW: 0.0 TRUCKED BOP'S TO KUPARUK. SET BPV, ND TREE, NU 7-1/6" BOP'S. BOP TEST WAIVED BY AOGCC. PULLED BPV. MU 10' 3.5" TBG PUP INTO HGR. LATCHED TBG PUP INTO TBG ELEVATORS & PULLED TBG HGR & CONNECTOR ABOVE THE WORKING PLATORM VIA 42 TON CRANE. SET BOWL & SLIPS. B/O TBG PUP, HGR, PUP BELOW HGR. REMOVED ORIG CONNECTOR. BOTH O-RINGS WERE CUT & SHOWED EVIDENCE OF FLUID CUT. REDRESS TBG HGR. CUT .5' OF 3.5" CT & GROUND LEVEL ON NEW TOP. INSTALLED NEW CONN THAT CONTAINED 2 CHEVRON SEALS & ONE CMT 0-RING. MU PUP HGR AND LANDING TBG PUP. RU CRANE & ELEVATORS, ETC. PULLED TEST CONN. LANDED HGR IN TBG HEAD. RILDS. MU PMP-IN SUB IN LANDING TBG PUP. RU LITTLE RED. TESTED TBG TO 2000 PSI-HELD. LD LANDING JT. ND PLATFORM, BOP'S, ETC. NU TREE. TESTED SAME. TESTED 3.5" X 7" ANN. HAD SOME DOUBT. TESTED TREE SEALS, ETC. TESTED TBG AGAIN & HELD PRESS 16 HRS. TBG HELD SOLID. BLED PRESS ON TREE TO 0 PSI. SECURED WELL. PERF PENDING OPS ENG DECISION. WELL: 1H-18 API: 50-029-22341 PERMIT: 93-20 PAGE: 5 10/06/93 (16) DOWELL TD: 8670 PB: 8564 10/08/93 (17) DOWELL TD: 8670 PB: 8564 03/19/94 (19) DOWELL TD: 8670 PB: 8564 03/20/94 (20) DOWELL TD: 8670 PB: 8564 RIG DOWN & SECURE 7"@ 8651' MW: 0.0 RU CTU & HOT OIL TRUCK. TEST LINES & COIL & BOP TO 4000 PSI-OK. RIH W/1.75" SWIRL NOZZLE ON 1.5" CT. PUMPING 170' BRINE. RIH TO 5000' CIRC TIL 90' RETURNS. POOH TO 2000' DISPLACE COIL & WELL TO DIESEL. POOH. RIG DOWN & -- SECURE. PREP TO PERF. TURN OVER TO WELLS GROUP 7"@ 8651' MW: 0.0 PU E-LINE UNIT; TEST BOP & LUB TO 3000 PSI-OK. RIH. TIE IN TO CBL/CBT DATED 03/02/93. PERF C-SAND F/8191'-8221' W/2-1/8" EJ III GUN @ 6 SPF, 90 DEG PHASING, 45 DEG ORIENTATION, RDX CHARGES: 181 SHOT TOTAL-ASF. MAKE CONFIRMATION PASS & MAKE JEWELRY LOG. POOH. RD & SECURE. TURN OVER TO WELL GROUP @ 12:00 10/07/93. WAIT ON AUX POWER PACK 7"@ 8651' MW: 0.0 SET WELL HOUSE OVER WELL. UNFLANGE & SET OUT TREE. SET IN 7-1/16, 5K FULL BORE VALVE, FLANGE UP SAME. SET IN 7-1/16, 5K STACK & FLANGE UP SAME. SET PENTHOUSE ON WELL HOUSE. BUILD SCAFFOLDING AROUND STACK. HOOK UP CONTROL LINES & FUNCTION TEST RAMS. RIG HARD LINES F/CHOKE, KILL & HOLE FILL. RIG WINCH LINE F/CTU T/3-1/2 CT ON ROC. HELD PREJOB SAFETY MEEING. RE-SPOT CTU & ROC. RE-RIG WINCH LINE TO 3-1/2 CT. HYDRAULIC SYSTEM OVER HEATED WHILE TRYING TO PULL 3-1/2 CT OFF REEL. ATTEMPTED TO RELOC HYDRAULICS TO WINCH, NO SUCCESS. WAITING ON AUX HYDRAULIC POWER PACK FROM PRUDHOE BAY. HARD LINE F/CTU IN KUPARUK 7"@ 8651' MW: 0.0 WAIT ON POWER PACK & RU SAME. PULL 3-1/2 CT F/ROC TO INJ HEAD. INSTALL ROLLERS. PICK INJ OUT OF CRADLE. MU LUB. MU TO STACK. PMP 40 BBLS BRINE TO WARM UP. PRE-TEST SAFETY MEETING. TEST STACK FLANGES, LUB, CHOKE KILL VALVES, BLIND SHEAR & BLIND RAMS-OK. STAB LANDING JT & MU 3-1/2 CT TO SAME W/EXTERNAL CONNECTOR. BOLDS. PULL TEST AGAINST SLIP RAMS. TRACTION CHAINS SLIPPING @ 42K. W/O CRANE. DE-ICE TRACTION CHAINS. RE-PULL CHAINS STILL SLIPPING @ 40K. CONTROL PRESS ON TOP, BTM & MIDDLE RAMS IN CTU 2500 PSI. CONTROL PRESS @ INJ HEAD TOP & BTM RAMS 500 PSI, MIDDLE RAMS 1500 PSI. CTU TBG. LOWER INJ HEAD. FOUND DULMP VALVES NOT OPERATING PROPERLY. REPLACED PRIORITY HYDRAULIC PUMP. PULL TEST 65K AGAINST DOG COLLAR. ATTEMPT TO MOVE BRINE, TWO INCH HARD LINE FROZE UP. THREE INCH HARD LINE F/WELL TO CHOKE OK. HOT OIL ON THE WAY TO PMP ON 3-1/2 CT. DOWELL GATHERING UP ADDITIONAL HARD LINE F/CTU IN KUPARUK. WELL: 1H-18 API: 50-029-22341 PERMIT: 93-20 PAGE: 6 03/21/94 (21) DOWELL TD: 8670 PB: 8564 03/22/94 (22) DOWELL TD: 8670 PB: 8564 HOT TAP CT 7"@ 8651' MW: 0.0 RIG HOSE TO 3-1/2" CT REEL & FLUSH W/20 BBLS HOT DIESEL. RU NEW 2" HARD LINE. PULL LANDING JT. MU LUB TO STACK. SET SLIP RAMS ON CT. PULL TEST. HAD TO INCREASE RAM CLOSING PRESS TO 2500 PSI IN ORDER TO PULL 65K ON TBG. PULL 3-1/2" CT. MU LANDING JT & 3-1/2" CT EXT CONN. PULL TESTED TO 57K, TRACTION CHAIN SLIPPING. FIN BOP TEST. ALL EQUIP TESTED TO 500/2500 PSI. BOLDS. HOLD SAFETY MEETING. PULL HGR(54K). HAD TO WORK HGR THROUGH BLIND/SHEAR RAM CAVITY. TAGGED HGR ON TOP OF FULL BORE RISE & SLACKED OFF 2' SET SLIP RAMS & CLOSED HYDRIL. BROKE LUB & OPENED TIW VALVE. MU LUB. ATTEMPT TO PULL SMALL STRAIN ON TBG. NO STRING WT. MOVED CT UP HOLE 2' BREAK LUB, CLOSE TIW. BACK OUT LANDING JT. 3-1/2" EXT CT CONN PULLED OFF TBG. DEVELOPED PIN HOLE LEAD IN 1-1/2" HYD LINE WHILE PULLING HGR. LOWER INJ HEAD. SWITCH LEAKY HI PRESS LINE TO LOW PRESS SIDE. PU INJ HD. INSTALL NEW 3-1/2" EXT CT CONN. PULL TEST TO 60K THREE TIMES. OPEN TIW. MU LUB. LINE UP TO CBU. 2" LINE FROZE UP INSTANTLY WHILE PUMPING 100 DEG BRINE. INSTALL FRESH HARD LINE. WAIT ON HOT DIESEL. P/T 2" LINE FROM PUMP TO WELL & ROC TO 2000 PSI W/HOT DIESEL. PMP 10 BBLS HOT DIESEL DOWN CT, CHASE W/228 BBLS 11.5 PPG BRINE. FREEZE PROTECT CT W/3 BBLS DIESEL. MONITOR WELL-NO FLOW. CRIMPED END BLEW OFF 3/4" HYD HOSE ON ROC. WAIT ON NEW HOSE & REPLACE SAME. OPEN HYDRIL. PULL TEST EXT CONN T/60K AGAINST SLIP RAMS. OPEN S/R. PULL UP 2' SET SLIP RAMS, CLOSE HYDRIL. HOT TOP CT & CUT OFF BELOW HGR PUP. PREP TO SECURE WELL 7"@ 8651' MW: 0.0 CUT & DRESS 3-1/2" CT. INSTALL 3-1/2" INTERNAL SPOOLABLE CONNECTOR. PULL TEST TO 58K. MONITOR WELL, STABLE. 3-1/2" CONNECTOR HANGING UP IN INJECTOR HEAD PACK-OFF. SLACK OFF, BREAK LUB. THE RUBBER ON THE CONNECTOR WAS PEELED DOWN, JAMMING IT. SOME MINOR DAMAGE WAS DONE TO THE RUBBER WITH A PIPE WRENCH DURING INSTALLATION. THIS MOST LIKELY CAUSED THE FAILURE. CUT OFF BAD CONNECTOR. INSTALL NEW CONNECTOR TO CT ON INJECTOR HEAD SIDE, PULL SAME THROUGH PACK-OFF, NO PROBLEMS. DE-ICE TRACTION CHAIN. MAKE UP OTHER IND OF CONECTOR. PULL TEST AGAINST S/R TO 60K. BUTTON UP LUB. POOH W/3-1/2" CT. CONNECTOR PULLED SMOOTH FOR+ 1335', THEN STOPPED COMING. INSPECT INJ HAD. FOUND INSER~ BLOCK RETAINER BROKEN. REPAIR TRACTION CHAINS. WELL STATIC, HOLE FILL GOOD. ROLLER BEARING ON TRACTION CHAIN TRASHED. PREP TO SECURE WELL & FREEZE PROTECT. *UNIT HAS TO GO TO PRUDHOE BAY F/REPAIRS WELL: 1H-18 API: 50-029-22341 PERMIT: 93-20 PAGE: 7 03/23/94 (23) DOWELL TD: 8670 PB: 8564 03/24/94 (24) DOWELL TD: 8670 PB: 8564 TAKE CTU TO DOWELL F/REPAIRS 7"@ 8651' MW: 0.0 FREEZE PROTECT WELL. CUT 3-1/2" CT & INSTALL EXTERNAL CONNECTOR. MU 2-TIW VALVES. STAND BACK INJ HD. SWALLOW TIW VALVES W/7-1/16" LUB. MU 7-1/6" TREE CAP. RD CTU. TAKE UNIT TO DOWELL YARD FOR REPAIRS. SHUT DN OPERATIONS OPERATION TEMP SHUTDOWN. 7"@ 8651' MW: 0.0 OPERATIONS SHUT DOWN WHILE UNIT BEING REPAIRED. 03/29/94 (25) DOWELL TD: 8670 PB- 8564 RESUME OPERATIONS 7"@ 8651' MW: 0.0 LOAD RIG TO KUPARUK. SPOT CTU TO WELL ON DIKE. RAISE MAST. PREP TO RIG UPIN AM. 03/30/94 (26) DOWELL TD: 8670 PB: 8564 03/31/94 (27) DOWELL TD: 8670 PB: 8564 04/01/94 (28) DOWELL TD' 8670 PB: 8564 04/02/94 (29) DOWELL TD: 8670 PB: 8564 SECURE RIG F/NIGHT 7"@ 8651' MW: 0.0 SPOT ROC UNIT TO CTU. RU HYDRAULIC LINES & HARDLINE. PULL 3-1/2" FROM ROC TO INJECTOR HEAD & STAB SAME. INSTALL ROLLERS. STRIP 7-1/16" LUB OFF 3-1/2" STUMP & TIW VALVES. CHECKED SICP & TP:0 PSI. RE-SPACE LUB SECTIONS & PREP TO PU IN AM. MU INTERNAL CONNECTOR UNDER INJECTOR HD. WRAP ROC REEL & INJECTOR HEAD FOR INDIRECT HEATER. SECURE F/NIGHT. LAY DOWN INJECTOR 7"@ 8651' MW: 0.0 TIE ONTO TBG W/EXT CONNECTOR. PULL TEST TO 63K. PULL UP TO SSSV @ 2084' FREEZE PROTECT COIL ON REEL. CUT CT & LD SSSV & PUPS. INSTALL EXT CONNECTOR & TIW TO CT IN WELL. LD INJECTOR-CHANGE OUT REELS. SECURE WELL F/NIGHT 7"@ 8651' MW: 0.0 RIG TO PULL 3-1/2" CT F/ROC TO INJECTOR HEAD. STAB 3-1/2" CT INTO INJ. INSTALL ROLLERS. HOLD SAFETY MEETING. INSTALL INTERNAL SPOOLABLE CONNECTOR. MU LUB. PULL TEST W/58K. CHECK CSG, TBG PRESS=0 PSI. RELEASE SLIP RAMS. POOH. LD GLM & PUPS. LD SEAL ASSY. INSPECT SEALS, OK. CUT 55' 5" OFF CT. NO VISIBLE HOLE OR MAJOR CORROSION. INSTALLED DUMMY VALVE IN GLM. PRESS TEST REMAINING CT TO 2000 PSI F/30 MIN. GOOD TEST. SECURE WELL F/NIGHT. WELL SECURED F/NIGHT 7"@ 8651' MW: 0.0 RUN SEAL ASSY, GLM W/DUMMY & 3-1/2" T & C TBG. MU 3-1/2" EXT CT CONNECTOR. PULL TEST TO 60K. EXTERNALLY TEST EXT CT CONNECTOR TO 1000 PSI. RIH W/CT. SET SLIP RAMS. CUT OFF CT. INSTALL TIW & LUB. WELL SECURED F/NIGHT. WELL: 1H-18 API: 50-029-22341 PERMIT: 93-20 PAGE: 8 04/03/94 (30) DOWELL TD: 8670 PB: 8564 WELL SECURED 7"@ 8651' MW: 0.0 CHANGE CT REELS. PULL 3-1/2" CT FROM ROC. T/INJ, STAB SAME. INSTALL ROLLERS. MU EXT CT CONNECTORS & OTIS SELECTIVE LANDING NIPPLE. PULL TEST EXT CONN TO 60K. EXTERNALLY TEST EXTERNAL CONNECTORS TO 1000 PSI. RIH W/ +655' CT. MU 2 EXT CT CONNECTORS & 4' PUP. PULL TEST -- CONN TO 58K. EXTERNALLY TEST EXT CONN TO 1000 PSI. SPRUNG AHEAD. RUN IN REMAINING CT & TAG UP ON PKR. SPACE OUT. CUT OFF CT. MU EXT CT CONNECTOR, HGR & LANDING JT. PULL TEST EXT CONN TO 50K W/82 TON CRANE. LAND HGR W/82 TON CRANE. WELL SECURE. 04/04/94 (31) DOWELL TD' 8670 PB- 8564 DOWELL OFF LOC 7"@ 8651' MW: 0.0 RU TO PRESS TEST 3-1/2" X 7" ANN & 3-1/2" TBG. P/T 3-1/2" X 7" ANN TO 2136 PSI. WITNESSED & APPROVED BY LOU GRIMALDI(AOGCC). P/T 3-1/2" TBG TO 2150 PSI. SET BPV. CLOSE 7-1/16" FULL BORE VALVE ON WELL. WELL SECURE FOR NIGHT. RD DOWELL, MISC TANKS, CHOKE & START PAD CLEAN UP. DOWELL OFF LOC @ 2200 HRS 04/03/94. 04/05/94 (32) DOWELL TD: 8670 PB: 8564 7"@ 8651' MW: 0.0 SET OFF PENTHOUSE. UNFLANGE & SET OUT 7-1/16" BOP STACK. SET IN & FLANGE UP TREE. TEST PACK OFF T/5000 PSI. TEST TREE TO 250 & 5000 PSI. INSTALL BPV. WELL SECURE. SIGNATURE: DATE: MEMORANDt., V! TO: . State v,' Alaska Alaska Oil and Gas Conservation Commission David Joh~ Chairmar¢~/ THRU: Blair Wondzell'~~ ~.~Y"" FILE NO: P. !. Supervisor"~TM DATE: April 4, 1994 FROM: Lou Grimaldi, v'"~-'~ ,.,/-¢-1"/ SUBJECT: Petroleum Inspector JA9JDCBD.DOC Mechanical Integrity Tests Arco well 1H-18 Kuparuk river field PTD # 93-20 Sunday, April 3, 1994: I traveled to the Kuparuk River field to witness initial Mechanical integrity test on Arco's well 1 H-18. This well was just finished with a 3.5 coil tubing completion and the tubing / annulus was standing full of 11.5 brine. The annulus was pressured up to 2150 psi and lost 15 psi over the next thirty minutes. I passed the well for injection. Summary: I witnessed the successful initial mechanical integrity test on Arco's well 1 H-18 in the Kuparuk River Field. Attachment: JA9JDCBD.XLS cc: Wes Wilder / Hurley Schurfius (Wells Group Supervisor) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: Arco FIELD I UNIT I PAD: Kuparuk River Field/CPF 1-H pad DATE: 4/3/94 PRETEST START 15 MIN 30 MIN *P *1 TYPE PACKER REQ TBG TIME TIME TIME WELL *S ANNULUS TVD CASING TBG TEST CSG TBG TBG TBG START P F NAME *M *N FLUID MD SIZEIWTIGRADE SIZE PRESS PRESS CSG CSG CSG TIME PRESS PRESS PRESS , , ,, , , ,, , 0 0 0 0 1H- 18 P N 11.5 Brine 7, 939 7 . 26# J55 3.5 0 0 2,150 2,140 2,135 1425 P COMMENTS: PTD#g3-20, New coil tubing completion .COMMENTS: COMMENTS: COMMENTS: COMMENTS: *TUBING INJECTION FLUID: P = PRODUCED WATER INJ. S = SALT WATER INJ M = MISCIBLE INJ. I = INJECTION N = NOT INJECTING ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 0.00 0.00 11.5 0.60 0.00 0.00 WELL TEST: Initial 4 - Year Workover Other X Distribution: odg - Well File c - Operator c - Database c -Trip Rpt File c - Inspector AOGCC REP SIGNATURE OPERATOR REP SIGNATURE JA9JDCBD.XLS Louis R Grimaldi Bobby Momson Fi-O5i (Rev. 3/-33) ARCO Alaska, Inc. Post Office Box 100369 Anci~orage, Alaska 995i0=03G0 Telephone 907 276 i215 February 5, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate are multiple Applications for Sundry Approval on the following Kuparuk wells. Well Action 01~,-~:~ 1H-18 Variance ~'5~ 2C-.,0/7' Other (inj valve) ~'o--~q~~~:21 Other If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments RECEIVED F£~ - ,9 19~4 & Gas Cons. Commission Anchorage AR3B-6003-93 242 2603 bxc: V. L. Ferguson P. A. Billingsley ATO-1228 (w/o attachments) ATO-1 431 (w/o attachments) FTR020195 (w/o attachments) Subject: Application for Sundry Approvals, 1H-18, 2C-07(injvlv), 3G-21 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Alter casing __ Repair well Change approved program __ Operation Shutdown __ Re-enter suspended well __ _ Plugging_ Time extension _ Stimulate__ Pull tubing __ Variance ~x Perforate __ Other 2. Name of Operator ARCO Alaska,, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 799' FNL, 785' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 1891' FSL, 2611' FEL, Sec. 34, T12N, R10E, UM At effective depth 1696' FSL, 2342' FEL, Sec. 34, T12N, R10E, UM At total depth 1659' FSL~ 2290' FEL~ Sec. 34~ T12Nr R10E~ UM 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-18 9. Permit number 9;~-20 10. APl number 5o-02~)-22341 11. Field/Pool Kuparuk River Field/Oil Pool feet 12. Present well condition summary Total Depth: measured 8 670 true vertical 6906 Effective depth: measured 8564 true vertical 6822 Casing Length Size Structural Conductor 1 21 ' 1 6" Surface 4935' 9 - 5 / 8" Intermediate Production 861 5' 7" Liner Perforation depth: measured 8046'-8124', true vertical 6416'-6477', Tubing (size, grade, and measured depth) feet feet Plugs (measured) None feet feet Junk (measured) None Cemented Measured depth 250 Sx PF 'C' 960 Sx Perm. E & 460 Sx Class G 265 Sx Class G 121' 4975' 8652' 8191'-8221' 6529'-6552' True vertical depth 121' 4144' 6892' RECEIVED FEB -9 1994 3.5" , 7.1 If/ft. , QT-800 @ 7885', 3.5" , 9.3 If/ft. , J-55 @ 7885'-7971' Packers and SSSV (type and measured depth) Pkr: Baker 'FB-I' @ 7939', SSSV: Will run inj valve prior to iniection, SLN @ 2084' 13. Attachments nitiate injection into well for testing. 14. Estimated date for commencing operation February 1994 16. If proposal was verbally approved Description summary of proposal X Date approved Detailed operation program_ Alaska 0~1 & Gas Cons. Commis,, Anchorage 15. Status of well classification as: Oil Gas BOP sketch Service Suspended __ Water Injector Name of approver t n, is true and correct to the best of my knowledge. Title Sr. Engineer FOR COMMISSION USE ONLY 17. Ihe,~~(~t¢ Signed Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test _ Location clearance Mechanical Integrity Test ~ Subsequent form require 10- ¢-I O~ Original Signed nn,,id W _inhne.+nn IApproval No. I. Approved Oopy Returned Commissioner Dine ) ~ cr"~ '~ ~ SUBMIT IN TRIPLICATE ion Approved by order of the Commission Form 10-403 Rev 06/15/88 Attachment 1 Request for Variance Kuparuk Well 1H-18 As per Area Injection Order No. 2, Rule 7, ARCO Alaska is hereby notifying the Commission of pressure communication between the tubing and casing in plan_,_.~A~ Water Injection Well 1H-18. Well 1H-18 has not yet been placed on injection service. As set forth in the Rule 7, ARCO Alaska is requesting Commission approval to initiate water injection into this well. As found in Area Injection Order No. 2, the aquifers described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit are exempted for Class II injection activities by 40 CFR 147.102(b) (3) and 20 AAC 25.440(c). As such, injection will not endanger any Underground Source of Drinking Water (USDW). Well 1 H-18 was completed on 8/31/93 without perforations. The tubing would not hold pressure and a spinner and temperature survey was performed. Results of the survey indicated a leak at the connector below the tubing hanger, and possibly at the packer. A pressure test with plug at 2000' indicated the leak was at the tubing connector. The tubing hanger and connector were subsequently pulled and redressed. Wellhead pressure was tested and held for 16 hours following the redressing, and well 1H-18 was then perforated. ARCO proposes to demonstrate/~medhanical integrity by setting a plug below the packer and simultaneously pressure testing the tubing and casing. Future plans for 1H-18 are to work it over and repair the suspected source of the tubing by 7" communication leak. Injection has not been initiated into this well and the well currently remains shut in. Gas Cons. commissio" Anchorage ARCO Alaska. Inc. .-~o3=. ©ffio:~ ~_~.~ Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 12, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION '~ ~- ~'-~ 1H-12 Stimulate .?;-~ -.¢'3. 1 H-1 5 Perforate __.iH- 1 6 Perforate cl~-I-~1 H-16 Stimulate i H'-18 Perforate (C3,4) 95-" ~o H-1 8 Perforate (C1) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASr¢, OIL AND GAS CONSERVATION COMMIS~,oN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate Plugging Repair well Perforate X Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic Service X 4. Location of well at surface 799' FNL, 785' FEL, Sec 33, T12N, R10E, UM At top of productive interval 1891' FSL, 2611' FEL, Sec 34, T12N, R10E, UM At effective depth 1696' FSL, 2342' FEL, Sec 34, T12N, R10E, UM At total depth 1659' FSL, 2290' FEL, Sec 34, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 8670 6906 feet feet 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit fee~ 8. Well number 1H-18 9. Permit number/approval number 93-20 10. APl number 5o-028-22341 ~1. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 85 64 true vertical 6822 feet feet Junk (measured) None Casing Length Structural Conductor 1 21 ' Surface 4 93 5' Intermediate Production 8 61 5' Liner Perforation depth: measured 8191'-8221' true vertical 6529'-6552' Size 16" 9.625" 7" Cemented 225 SX PF 'C' 960 SX PF 'C' & 460 SX Class G 265 SX Class G Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7971' & 3.5" 7.15#, QT-800 @ 7885' Packers and SSSV (type and measured depth) PKR: Baker 'FB-I' Perm @ 7939'; SSSV: Otis 3.5" SLN @ 2084' Measured depth 121' 4975' 8652' True vertical depth 121' 4144' 6892' -"~i1188/017 13. Stimulation or cement squeeze summary Perforated 'C1' Sand on 10/8/93. Intervals treated (measured) 8191'-8221' Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 11 O0 2200 Subsequent to operation 0 0 0 1080 2200 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended __ Service H20 Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si,ned '~~ ~~), ~'~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 'ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL 1H-I~ CONTRACTOR REMARKS IPBDT WELL SERVICE REPORT FIELD-DISTRICT-STATE JDAYS IDATE OPERATION AT REPORT TIME cc: ??7PZ7 ~ C,,rt~ ~' /{o 5'oo /022_.3 0¢30 Iloo /3/3 /32~- /7/0 i74. ~ P£~F ~ $~ ! ~ ,' ~_ sN, ?~ '?EXT {CCH. ~(ly£ F/]clb P ~/o/.S~/~b gyp ~[Fo~[ - l~oo pd/ , gPr~'~- l~oo psI. ~}y ~/ ra~ TS/ ¢0'., { ..... SP;,, P~'op~&~ ~y. SET Do~y iglg P IP'HXB. PoiK TIE ly 6~H5 To F/~z ~ P!Og'-PoPI '~0; ~ 'To ccc. sET bl/TH GOHJ FI~ED/ ~Y~3, LOG upi foil. ~SP, / cc].. 5£ T ~£77H ~ po .4-].5 718 60//5 F/4£~ / £/~4/ ¢¢¢-, RECEIVED , JAN ! 4 199,'I- Oil & Gas Cons, Commission AnchoragF~ E~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather TemP.Report 0 OF Chill Fact°r I VisibilitY°F miles Iwind Vel'/,.?' knots I Signed? ~ ARCO Alaska, Inc. ~J~l~y of Ati~tlo I=l~f~fl~ld Oompa~ ~-I~ . REMAR~ . ~ WELL SERVICE REPORT R£C£1vED i [-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK We.ther ~ T. mP.Reporl .... 'F I C'hlll FIcI lViiiblllty' ~F miles 1wlrN:l v'l' knots INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 11/18/1993 PAGE: 1 93-020 CBT CH 93-020 CDN-DC 93-020 CDR ENHANCEMENT 93-020 CDR-DC OH,4976-8670 7988-8632 OH,4976-8670 93-020 CET CH 93-020 GCT 93-020 407 93-020 DAILY WELL OP 93-020 SURVEY 93-020 5665 COMP DATE: 10/07/93 2/08/93 TO 10/08/93 0.00-8670 4835-8669, CDN/CDR SUMMARY Are well tests required? Yes ~ Was well cored? Yes ~ If yes, was the core analysis & description received? Are dry ditch samples WELL IS IN COMPLIANCE. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~o51ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well O~L I---I GAS I--q SUSPENDED E3 ABANDONED [] SERWCE ~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 93-20 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 .,-'-u: ................ ~ ~r 50-029-22341 4 Location of well at surface ! ~'"~u'~L~:;;.?; '-'. ~"'"'~'~: 9Unit or Lease Namer ¢¢ 799' FNL, 785' FEL, SEC 33, T 12N, R 10E, OM ! ~"~" ;r: !Z_~ _.?.~_'~_~_'~.._~.~ At Top Producing Interval ; .... '~ '-- 1891'FSL, 2611'FEL, SEC34, T 12N, R10E, UMi ~¢-~__~ ..... ...... _,~ 10 WellNumberlH_18 At Total Depth .............. ~.- r~.~j 11 Field and Pool 1659' FSL, 2290' FEL, SEC 34, T 12N, R 10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER RKB 96', PAD 54' GLI ADL 25639 ALK 464 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 07-Feb-93 13-Feb-93 .~;~/.2ece3 (Comp) 10/07/93(Perfed)I NA feet MSL 1 8670'17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional~Survey~ 20 Depth where SSSV set 21 Thickness of permafrost MD, 6906' TVD 8564' MD, 6822' TVD YES ~ NO ~ SLN @ 2084' feet MD 1500' APPROX 22 Type Electric or Other Logs Run CDR, CDN, CET, CBT, GCT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF 121' 24" 250 SX PFC CMT 9.625" 47#/36# L-80/J-55 SURF 4975' 12.25" 960 SX PERM E CMT, 460 SX CLASS G 7" 26# J-55 SURF 8652' 8.5" 265 SX CLASS G CMT 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7.148# CT 7971' 7939' 2-1/8" EJ III @ 6 SPF F/8191'-8221' MD 6529'-6552' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OiL RATIO TEST PERIOD I~ FlowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/ARECEiV,, ~4()V '~ 5 199~ ,~laska Oil & Gas Cons, ^nch0ra.~0 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 recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP OF KUPARUK C 8030' 6404' BASE OF KUPARUK C 8233' 6562' TOP OF KUPARUK A 8409' 6699' BASE OF KUPARUK A 8550' 6811 ' 31. LIST OF ATI'ACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed Title pz-/~? ~_.~,/,j~ DATE - ? . INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATION& PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1H-18 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25639 ALK 464 50-029-22341 93-20 ACCEPT: 02/07/93 07:00 SPUD: 02/07/93 02:30 RELEASE: 10/07/93 12:00 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: DOWELL 02/08/93 (1) PARKER 245 TD: 2600'(2600) 02/09/93 (2) PARKER 245 TD: 4995' (2395) 02/10/93 (3) PARKER 245 TD: 4995'( o) DRILLING 16"@ 121' MW:10.5 VIS: 55 FIN MOVING RIG TO 1H-18. Nil DIVERTER SYSTEM. FUNCTION TEST 20" DIVERTER. TEST WAIVED BY JERRY HERRING W/AOGCC. FILL STACK W/MUD-NO LEAKS. FIN NU DIVERTER LINES. PU 12.25" BIT & BHA. ORIENT NAVIDRIL & MWD. C/O 16" F/108'-121'. DRLG 12.25" HOLE F/121'-292'. PU 6 7-3/4" DC'S. DRLG 12.25" HOLE F/292'-2600'. DRILLING 9-5/8"@ 4974' MW:10.5 VIS: 42 DRLG 12.25" HOLE F/2600'-3930'. GAS CUT MUD TO 9.8 PPG. SERV RIG. DRLG 12.25" HOLE F/3930'-4995'. CBU FOR SHORT TRIP. HOLE UNLOADING PEA GRAVEL. POOH W/41 STDS TO 1200'. HOLE TIGHT & SWABBING. SLM-NO CORR. RIH-NO FILL. CIRC & COND HOLE FOR 9-5/8" CSG @ 4995'. HOLE UNLOADING PEA GRAVEL. POOH TO RUN 9-5/8" CSG. HOLE TIGHT F/2200'-1750' FIN BOP TEST 9-5/8"@ 4974' MW:10.5 VIS: 41 LD MWD, MOTOR, 2 STAB, & 1-MONEL DC-HOLE TOOK 16.5 BBLS OVER CALC. RIG TO RUN 9-5/8" CSG. HOLD SAFETY MEETING W/TOOLPUSHER & ARCO REP. RUN 9-5/8" CSG W/21 CENT. TIGHT HOLE @ 1972'. MU TOP DRIVE IN 9-5/8" CSG. WASH THROUGH TIGHT HOLE F/1972'-3116', CONT TO RIH TO 4974', MU LANDING MANDREL. CIRC & RECIP PIPE, COND HOLE FOR CMTING. RU HALLIBURTON, TEST LINES TO 3000 PSI, CMT 9-5/8" CSG W/371 BBLS, 12 PPG LEAD & 94 BBLS 15.8 TAIL. USED 3-PLUGS. RECIP PIPE WHILE CMTING. FULL RETURNS, 17 BBLS 12 PPG CMT TO SURF, BUMPED PLUG W/2000 PSI, BLED OFF, FLOATS HEAD. CIP @ 22:30 HRS. RD CSG TOOLS, LD CMT HEAD & LANDING JT. ND DIVERTER LINES, WASH CMT OUT OF DIVERTER VALVES & BAG. PACK DRY CMT AROUND MANDREL HGR. INSTALL JUNK RING. MU 11-3/4 BTC X 11" 3M FMC SPEED HEAD, TORQUE TO 15K FT/LBS. NU BOP. TEST ALL BOP EQUIP. TEST WITNESSED BY AOGCC INSPECTOR DOUG AMOS. .A!aska Oil & Gas Cons, i..;ornmissio~' Anchorage WELL: 1H-18 API: 50-029-22341 PERMIT: 93-20 PAGE: 2 02/11/93 (4) PARKER 245 TD: 7583' (2588) 02/12/93 (5) PARKER 245 TD: 8263'( 680) 02/13/93 (6) PARKER 245 TD: 8494' ( 231) 02/14/93 ( 7) PARKER 245 TD: 8670' ( 176) DRILL, LOG, & SURVEY 9-5/8"@ 4974' MW: 9.2 VIS: 35 LD TEST JT. SET WEAR BUSHING, BLOW DN ALL LINES. CUT 167' DRLG LINE, SET & CHECK DUO-MATIC. CHANGE OUT GRABS ON TOP DRIVE, CHANGE SAVER SUB. CHANGE BEARING SECTION ON TURBINE. PU BHA, ORIENT, PROGRAM LWD, LOAD R/A SOURCE. RIH TO 4889'. CIRC & COND MUD FOR CSG TEST. TST CSG TO 2000 PSI FOR 1/2 HR-GOOD TEST. DRILL PLUGS, FC, & CMT TO 4911'. SERV TOP DRIVE & RIG. DRILL CMT, FS, & 10' NEW FORMATION TO 5005'. CIRC, TEST FORMATION @ 4160' TVD W/8.55 PPG MUD IN HOLE PRESS. 860 PSI EMW=12.5 PPG. DRILL, LOG, & SURVEY. SHORT TRIP 20 STDS 9-5/8"@ 4974' MW:ll.9 VIS: 43 DRILL, LOG & SURVEY. SERV RIG & TOP DRIVE. DRILL, LOG & MWD SURVEY TO 8263'. WELL KICKED @ 1535 HRS, 8263' MWD, 6570' TVD, 375 PAI ANN, 300 PSI SIDPP, 10 BBL GAIN, 10.6 PPG MUD. WT MUD ON FLY TO 11.7 PPG, CIRC OUT KICK, OPEN BAG, MONITOR WELL. RAISE MUD WT TO 11.9 PPG FOR EXTRA TRIP MARGIN. CIRC & COND MUD, MONITOR WELL FOR FLOW 1/2 HR. SHORT TRIP 10 STDS, SWABBING SLIGHTLY FROM 7700'-7415'. CIRC & COND MUD, 430 BBLS, MONITOR WELL, CIRC, MUD CUT TO 10.9 PPG. CIRC UNTIL RETURNS 11.9 PPG. PMP SURVEY, PMP SLUG. SHORT TRIP 20 STDS, HOLE TOOK CALC FILL. DRILL & LWD LOG 9-5/8"@ 4974' MW:ll.9 VIS: 44 FIN SHORT TRIP TO 6281', SWABBED SLIGHT F/7250' TO 7028'. CIRC & COND MUD, MIX FINE MICA @ 10# PER BBL (MT WT CUT TO 11.0 PPG FROM SHORT TRIP). POH, MONITOR WELL @ 9-5/8" SHOE 1/4, REMOVE RA SOURCE, DOWNLOAD INFO FROM FRT, LD BHA. MU NEW BHA. INSTALL SOURCE IN FRT. RIH. FILL PIPE @ 4970' & 8063'. REAM & LOG FROM 8143' TO 8263'. DRILL & LOG TO 8494'. RUNNING 7" CSG 7"@ 8651' MW:ll.9 VIS: 44 DRILL & LOG TO 8670'. CIRC FOR SHORT TRIP, PMP SLUG. MAKE 41 STD SHORT TRIP TO 9-5/8". RIH SLOWLY. CIRC & COND MUD FOR 7" CSG. MONITOR WELL FOR FLOW, "OK", DROP SURVEY. POH, LD 32 JTS DP. RETRIEVE SURVEY @ HWDP. REMOVE R/A SOURCE, DOWNLOAD LWD INFO, LD BHA. PULL WEAR BUSHING, RIG TO RUN CSG. HOLD SAFETY MEETING, RUNNING 7" 26# J-55 BTC CSG. Aiask~t Oil & Gas Cons. Anchorage WELL: 1H-18 API: 50-029-22341 PERMIT: 93-20 PAGE: 3 02/15/93 (8) PARKER 245 TD: 8670' ( 02/15/93 (10) HLS TD: 8670 o) ARCTIC PACK 7"@ 8651' MW:ll.9 VIS: 42 RUNNING 7" CSG, STARTED LOSING RETURNS @ 5540'. RIG TO CIRC, PMP 22 BBLS SLOW & RECIP CSG-NO RETURNS. CONT TO RUN CSG SLOW, LOST 77_BBLS MUD. RIG CMT HEAD, PMP SLOW RATE & TRY TO RECIP. VERY SMALL AMT OF RETURNS, PMP 50 BBLS MUD & LOST 467 BBLS, CIRC PACKING OFF WHILE RECIP, STOP RECIP & PMP 4.5 BBLS PER MIN-NO PACKOFF. RIG HALLIBURTON TO CMT W/SHOE @ 8652' & FC @ 8564' START PUMPING PREFLUSH, STARTED GETTING FULL RETURN~ IMMED, STARTED RECIP PIPE W/NO PACKOFF. BMP PLUG W/3500 PSI, TEST CSG 1/2 HR.-GOOD TEST, BLED OFF, FLOATS HELD, CIP @ 20:55 HRS 02/14/93. MONITOR WELL, FLOWING SLIGHTLY OUT OF 9-5/8" X 7" ANN. SHUT WELL IN, MONITOR PRESS BUILDUP, ORDER OUT ARCTIC PACK & MORE CMT. RIG HALLIBURTON, TEST LINES TO 2500 PSI, PMP 300 BBLS FLUSH WATER, PMP 58 BBLS PREMAFROST C FOLLOWED BY 55 BBLS ARCTIC PACK. CIP @ 02/15/93 7"@ 8651' 02/16/93 (9) PARKER 245 TD: 8670' ( 08/22/93 (18) DOWELL TD: 8670 PB: 8564 08/27/93 (11) DOWELL TD: 8670 PB: 8564 o) RIG RELEASED 7"@ 8651' MW:ll.9 VIS: 0 SHUT WELL IN & WOC. INITIAL SHUT IN PRESS=550 PSI. PRESS @ 11:00 HRS 80 PSI. BLEED OFF PRESS SLOWLY, MONITOR ANN FOR FLOW, NO FLOW, DRAIN RISER, BLOW DOWN LINES. ND, PU STACK, SET SLIPS ON 7" WITH 165,000 NET WT, BLOW DN INSIDE 7" TO 90', CUT OFF 7" WITH MANUAL CSG CUTTER, SET STACK & RISER ON STUMP, INSTALL PACKOFF & ll"-3M X 7-1/16-5M WELLHEAD, TEST TO 3000 PSI FOR 1/4 HR-GOOD TEST. RELEASE RIG @ 16:30 HRS 02/15/93. RD SWS. SECURE WELL 7"@ 8651' MW: 0.0 RU SWS E-LINE UNIT PU GAUGE-RING/JUNK. RIH TO 8300'-CORRELATE WITH SHORT JTS. POOH. PU BAKER FB-1 PERM PKR & TAILPIPE ASSY. RIH & TIE IN. SET PKR W/TAILPIPE @ 7971' TOP OF PKR @ 7939'. RD SWS. SECURE WELL. SECURE F/NIGHT 7"@ 8651' MW: 0.0 SPOT EQUIP. HOLD SAFETY MEETING. STAB 3-1/2" THRU INJ HEAD. LAY HARD LINE F/PMP TO REEL & ANN. W.O. WELDER. REPAIR ROLLER ON GOOSENECK. NU ON WELL HEAD. FILL COIL W/ll.9# BRINE. TEST STRIPPER, ANN, & ALL RAMS TO 300/3000 PSI-OK. INSTALL COIL TBG CONNECTOR. SECURE F/NIGHT. WITNESSING OF BOP TEST WAIVED BY DOUG AMOS OF AOGCC. Alaska Oil & uao Ooas. Oomi~fissi°''~ Anchorage WELL: 1H-18 API: 50-029-22341 PERMIT: 93-20 PAGE: 4 08/28/93 (12) DOWELL TD: 8670 PB: 8564 08/29/93 (13) DOWELL TD: 8670 PB: 8564 08/30/93 (14) DOWELL TD: 8670 PB: 8564 10/03/93 (15) DOWELL TD: 8670 PB: 8564 SECURE F/NIGHT 7"@ 8651' MW: 0.0 SERV EQUIP. RU CSG CREW. MU BHA. RIH W/3-1/2" CT TO 938' SHUT DOWN; RADIO SILENCE WHILE PERFING ON OPPOSITE SIDE OF PAD. RIH W/TOTAL OF 5790' CT. DRILL HOLE IN CT & DRAIN FLUID. PULL BACK THRU INJ HEAD & SPOOL UP CT. RU CRANE & CHANGE SPOOLS. STAB 3-1/2" THRU INJ HEAD. DRESS CT ENDS F/CONNECTOR. SECURE WELL F/NIGHT. DOWELL/GBR/PEAK 7"@ 8651' MW: 0.0 SERV EQUIP. HYDRAULIC PMP ON SPOOL UNIT FAILED. REMOVE PMP & WO REPLACEMENT. UNABLE TO FIND REPLACEMENT. W.O. POWER PACK. CHANGE OUT SAME. FIN BUT UP INJ LID. SECURE F/NIGHT. 7"@ 8651' MW: 0.0 SERV EQUIP. HOLD SAFETY MEETING. RU CSG CREW. MU CT LANDING NIPPLE ASSY & CT CONNECTOR. RIH. W/+ 2090' 3-1/2" CT, TAG UP & LAND SEAL ASSY; LOCATE W/2000 PSI-OK. SPACE OUT; SET BACK INJ HEAD; CUT 3-1/2" COIL; MU TBG HGR & LAND HGR; RILDS; TEST TBG TO 2000 PSI-OK. TEST ANN TO 2000 PSI-LOST 700 PSI IN 5 MIN. CIRC OUT TBG; RETEST TBG-CIRC ANN. BOTH SIDES WILL PRESS UP TO 1500-1700 PSI & BLEED DOWN. (FREEZE PROTECT 500' TBG & ANN). ND BOP'S & NU TREE; TEST SEALS TO 5000 PSI-OK. TEST TREE TO 250/5000 PSI-OK. SECURE WELL. TEST TBG AGAIN-SECURE WELL 7"@ 8651' MW: 0.0 TRUCKED BOP'S TO KUPARUK. SET BPV, ND TREE, NU 7-1/6" BOP'S. BOP TEST WAIVED BY AOGCC. PULLED BPV. MU 10' 3.5" TBG PUP INTO HGR. LATCHED TBG PUP INTO TBG ELEVATORS & PULLED TBG HGR & CONNECTOR ABOVE THE WORKING PLATORM VIA 42 TON CRANE. SET BOWL & SLIPS. B/O TBG PUP, HGR, PUP BELOW HGR. REMOVED ORIG CONNECTOR. BOTH 0-RINGS WERE CUT & SHOWED EVIDENCE OF FLUID CUT. REDRESS TBG HGR. CUT .5' OF 3.5" CT & GROUND LEVEL ON NEW TOP. INSTALLED NEW CONN THAT CONTAINED 2 CHEVRON SEALS & ONE CMT 0-RING. MU PUP HGR AND LANDING TBG PUP. RU CRANE & ELEVATORS, ETC. PULLED TEST CONN. LANDED HGR IN TBG HEAD. RILDS. MU PMP-IN SUB IN LANDING TBG PUP. RU LITTLE RED. TESTED TBG TO 2000 PSI-HELD. LD LANDING JT. ND PLATFORM, BOP'S, ETC. NU TREE. TESTED SAME. TESTED 3.5" X 7" ANN. HAD SOME DOUBT. TESTED TREE SEALS, ETC. TESTED TBG AGAIN & HELD PRESS 16 HRS. TBG HELD SOLID. BLED PRESS ON TREE TO 0 PSI. SECURED WELL. PERF PENDING OPS ENG DECISION. WELL: 1H-18 API: 50-029-22341 PERMIT: 93-20 PAGE: 5 10/06/93 (16) DOWELL TD: 8670 PB: 8564 RIG DOWN & SECURE 7"@ 8651' MW: 0.0 RU CTU & HOT OIL TRUCK. TEST LINES & COIL & BOP TO 4000 PSI-OK. RIH W/1.75" SWIRL NOZZLE ON 1.5" CT. PUMPING 170' BRINE. RIH TO 5000'_ CIRC TIL 90' RETURNS. POOH TO 2000'. DISPLACE COIL & WELL TO DIESEL. POOH. RIG DOWN & SECURE. PREP TO PERF. 10/08/93 (17) DOWELL TD: 8670 PB: 8564 TURN OVER TO WELLS GROUP 7"@ 8651' MW: 0.0 PU E-LINE UNIT; TEST BOP & LUB TO 3000 PSI-OK. RIH. TIE IN TO CBL/CBT DATED 03/02/93. PERF C-SAND F/8191'-8221' W/2-1/8" EJ III GUN @ 6 SPF, 90 DEG PHASING, 45 DEG ORIENTATION, RDX CHARGES: 181 SHOT TOTAL-ASF. MAKE CONFIRMATION PASS & MAKE JEWELRY LOG. POOH. RD & SECURE. TURN OVER TO WELL GROUP @ 12:00 10/07/93. SIGNATURE: DATE: Aiask~,.. ()il & Gas Cons. Comm%ssio':~ Anchorage SUB - S URFA CE DIRECTIONAL ORIGINAL SURVEY ~'~'i UIDANCE F~'I ONTINUOUS I'~ OOL Company Well Name Field/Location ARCO ALASKA, INC. 1H-18 (799' FNL, 786' FEL, SEC 33, T12N, RIOE, UN) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 93110 Lo~lcjed By' FORMICA Date · '-" ~"~mputed By: SINES .. ~ SCHLUMBEROER ~ GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 1H- 18 KLPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE' 02-MAR-1993 ENGINEER' JEFF FORMICA METHODS OF COMPUTATION TOOL LOCATION MINIMUM CURVATURE INTERPOLATION LINEAR VERTICAL SECTION. HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 53 DEG 9 MIN EAST COMPUTATION DATE' 1-APR-93 PAGE I ARCO ALASKA, INC. 1H - 18 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 02-MAR-1993 KELLY BUSHING ELEVATION' 96.00 FT ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN 1OO 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 FEET DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 599 99 699 99 799 98 899 98 -96.00 0 0 N 0 0 E 4.00 0 3 N 52 42 W 104.00 0 9 N 22 31 E 204.00 0 8 N 9 4 W 304.00 0 19 N 5 7 E 404.00 0 24 N 2 14 E 503.99 0 37 N 7 40 E 603.99 0 37 N 7 3 E 703.98 0 35 N 11 11 E 803.98 0 41 N 41 6 E 0.00 0.00 0.02 0.42 -0.05 0.00 -0.19 0.00 -0.38 0.21 -0.74 0.36 -1.22 0.00 -1.77 0.00 -2.25 0.00 -2.58 1.24 000 N 0 05 N 0 16 N 0 38 N 0 76 N 1 36 N 2.31 N 3.41 N 4.44 N 5.43 N 0 O0 E 0 06 E 0 06 E 004 E 009 E 0 10 E 021 E 034 E 051 E 0 85 E 0 O0 N 0 0 E 08 N 50 2 E 17 N 2O 46 E 38 N 6 43 E 76 N 6 43 E 37 N 4 10 E 32 N 5 7 E 42 N 5 45 E 47 N 6 33 E 50 N 8 51 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 999 go O0 1099 O0 1198 O0 1297 O0 1395 O0 1493 O0 1589 O0 1685 O0 1778 O0 1869 903 90 53 1003 81 1102 57 1201 75 1299 03 1397 68 1493 40 1589 96 1682 65 1773 3 39 S 72 24 E 53 5 53 S 71 36 E 81 7 59 S 71 12 E 57 9 57 S 65 26 E 75 12 15 S 58 30 E 03 14 18 S 54 32 E 68 15 30 S 53 4 E 40 18 25 S 51 58 E 96 22 52 S 49 29 E 65 27 4 S 48 34 E 0.14 8 30 19 56 34 69 53 41 76 52 102 15 131 08 166 26 208 21 3.23 1 90 2 68 1 76 3 39 0 95 I 73 4 25 4 22 3 75 28 43 61 83 111 5.20 N 2 42 N 12 I 28 S 23 7 03 S 38 15 95 S 54 83 S 74 99 S 94 61S 117 82 S 144 54 S 176 4 07 E 18 E 12 49 E 23 08 E 38 79 E 57 02 E 79 69 E 104 63 E 132 95 E 167 60 E 208 6 60 N 38 2 E 42 N 78 46 E 52 S 86 53 E 72 S 79 33 E 07 S 73 46 E 43 S 68 43 E 41 S 65 5 E 79 S 62 21E 44 S 59 58 E 87 S 57 43 E 2000 O0 1957 10 1861.10 31 0 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 2040 90 1944.90 35 2 O0 2120 91 2024.91 38 35 O0 2197 34 2101.34 41 38 O0 2270 74 2174.74 43 24 O0 2343 35 2247.35 43 25 O0 2415 94 2319.94 43 31 O0 2488.45 2392.45 43 36 O0 2560.79 2464.79 43 42 O0 2633.07 2537.07 43 45 S 48 5O E S 49 34 E S 48 39 E S 48 38 E S 48 58 E S 48 40 E S 48 25 E S 48 19 E S 48 23 E S 48 18 E 256 52 310 90 370 71 434 96 502 68 571 25 639 80 708 42 777 22 846 09 3 85 3 56 3 10 2 88 0 36 0 35 0 18 0 21 0 17 0 32 143 60 S 212 95 E 256 84 S 56 0 E 179 218 261 305 351 396 442 488 534 13 S 254 40 S 299 08 S 347 76 S 399 O1S 450 60 S 502 36 S 553 24 S 605 18 S 656 27 E 311 59 E 370 89 E 434 03 E 502 80 E 571 31E 64O 76 E 708 36 E 777 99 E 846 04 S 54 50 E 75 S 53 55 E 97 S 53 7 E 71 S 52 32 E 34 S 52 6 E O0 S 51 42 E 76 S 51 23 E 71 S 51 7 E 75 S 50 53 E 3000.00 2705.42 2609.42 43 37 3100.00 2777.75 2681.75 43 39 3200.00 2850.28 2754.28 43 22 3300.00 2923.00 2827.00 43 21 3400.00 2995 68 2899.68 43 28 3500.00 3068 04 2972.04 43 50 3600.00 3140 19 3044.19 43 45 3700,00 3212 43 3116.43 43 45 3800,00 3284 53 3188.53 43 52 3900.00 3356 56 3260.56 43 57 S 48 10 E 914 86 S 47 43 E 983 64 S 47 48 E 1052 17 S 47 41 E 1120 S 47 39 E 1188 88 S 48 12 E 1257 60 S 48 23 E 1326 60 S 48 32 E 1395.51 S 50 16 E 1464.65 S 49 58 E 1533.92 0.30 0 65 0 29 0 O3 0 30 0 62 0 28 0 6O 0 54 0.32 580.14 S 708 49 E 915 71 S 50 41 E 626.40 S 759 672.69 S 810 718.86 S 861 765 13 S 912 811 46 S 963 857 46 S 1015 903 42 S 1066 948 46 S 1119 992 90 S 1172 77 E 984 72 E 1053 52 E 1122 29 E 1190 43 E 1259 19 E 1328 86 E 1397 51E 1467 76 E 1536 69 S 50 30 E 46 S 50 19 E 04 S 50 9 E 66 S 50 1E 63 S 49 54 E 85 S 49 49 E 98 S 49 45 E 27 S 49 44 E 63 S 49 45 E COMPUTATION DATE' 1-APR-93 PAGE 2 ARCO ALASKA, INC. 1H - 18 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 02-MAR-1993 KELLY BUSHING ELEVATION' 96.00 ET ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN iO0 ,FEET OF MEASURED DEPTH ll~UE SL~-SEA CDL~SE 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 4000 O0 3428 64 3332 64 43 52 4100 4200 4300 4400 4500 4600 4700 480O 4900 O0 3500 O0 3572 O0 3645 O0 3718 O0 3791 O0 3864 O0 3938 O0 4012 O0 4087 65 3404 92 3476 56 3549 26 3622 16 3695 62 3768 37 3842 60 3916 38 3991 65 43 54 92 43 31 56 43 25 26 43 20 16 42 57 62 42 37 37 42 18 60 41 49 38 41 20 S 50 1E 1603 13 S 51 7 E 1672 S 51 12 E 1741 S 51 9 E 1810 S 51 4 E 1878 S 51 11E 1947 S 52 10 E 2015 S 54 4 E 2082 S 54 7 E 2149 $ 54 25 E 2215 44 52 21 83 23 O5 58 58 95 0 27 0 36 0 42 0 27 0 19 0 47 I 87 0 36 0 45 0 52 1037 51 S 1225 81 E 1605 94 S 49 45 E 1081 1124 1167 1211 1254 1296 1336 1376 1414 60 S 1279 92 S 1333 98 S 1386 11 S1440 15 S 1493 38 S 1546 68 S 1600 O1S 1655 78 S 1708 40 E 1675 26 E 1744 82 E 1813 25 E 1881 47 E 1950 57 E 2018 76 E 2085 02 E 2152 90 E 2218 33 S 49 47 E 42 S 49 51E 13 S 49 54 E 78 S 49 56 E 22 S 49 59 E O4 S 50 2 E 46 S 50 8 E 32 S 50 16 E 55 S 50 23 E 5000 O0 4162 71 4066 71 40 59 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4238 O0 4313 O0 4388 O0 4463 O0 4537 O0 4612 O0 4686 O0 4760 O0 4834 05 4142 28 4217 48 4292 52 4367 81 4441 19 4516 68 4590 68 4664 05 41 13 28 41 12 48 41 13 52 41 49 81 42 2 19 41 53 68 41 50 68 42 43 24 4738.24 42 35 S 54 57 E 2281 71 S 55 16 E 2347 S 55 22 E 2413 S 55 36 E 2479 S 55 36 E 2545 S 55 31E 2612 S 55 44 E 2678 S 55 51E 2745 S 56 29 E 2812 S 56 36 E 2880 42 26 12 15 03 81 46 62 25 0 63 0 19 0 17 0 37 1 06 0 27 0 15 0 46 0 38 0 22 1452 91S 1762 50 E 2284 15 S 50 30 E 1490 1528 1565 1602 1640 1678 1715 1753 1790 51S 1816 O0 S 1870 41S 1924 65 $ 1979 54 S 2034 29 S 2089 82 S 2145 27 S 2200 60 S 2257 44 E 2349 61E 2415 89 E 2481 49 E 2546 67 E 2613 84 E 2680 O0 E 2746 86 E 2813 39 E 2881 69 S 50 38 E 36 S 50 45 E 07 S 50 53 E 93 S 51 0 E 67 S 51 7 E 31 S 51 14 E 83 S 51 21E 85 S 51 27 E 33 S 51 35 E 6000.00 4907 97 4811.97 42 25 6100.00 4981 6200.00 5054 6300.00 5127 6400 O0 5199 6500 O0 5272 6600 O0 5345 6700 O0 5419 6800 O0 5493 6900 O0 5567 85 4885.85 42 33 70 4958.70 43 35 23 5031 23 43 27 93 5103 93 43 20 77 5176 77 43 12 93 5249 93 42 43 73 5323 73 42 18 79 5397 79 42 0 96 5471 96 42 37 S 56 30 E 2947 69 S 56 29 E 3014 S 56 35 E 3O83 S 56 43 E 3152 S 56 45 E 3220 S 56 43 E 3288 S 56 43 E 3357 S 56 51E 3424 S 56 56 E 3491 S 56 9 E 3558 96 34 O7 6O 97 O2 36 42 35 0 14 1 17 0 14 0 23 0 32 0 26 0 51 0 O5 0 81 1 14 1827 84 S 2313 76 E 2948 64 S 51 42 E 1865 1902 1940 1978 2015 2053 2090 2127 2163 06 $ 2369 86 S 2427 70 S 2484 37 S 2541 96 $ 2599 39 S 2656 36 S 2712 06 S 2768 91S 2825 94 E 3015 07 E 3O84 58 E 3152 99 E 3221 27 E 3289 25 E 3357 70 E 3424 99 E 3491 03 E 3558 80 S 51 48 E 07 S 51 54 E 69 S 52 0 E 13 S 52 6 E 42 S 52 12 E 39 S 52 18 E 67 S 52 23 E 66 $ 52 28 E 55 S 52 33 E 7000 O0 5641 41 5545.41 42 43 7100.00 5714 7200.00 5787 7300.00 5860 7400.00 5933 750000 6005 7600 O0 6077 7700 O0 6151 7800 O0 6226 74 5618 74 42 59 89 5691 89 42 55 69 5764 69 43 40 15 5837 15 43 37 48 5909 48 43 4] 95 5981 95 43 15 82 6055 82 41 50 85 6130 85 40 21 7900 O0 6303 62 6207 62 39 37 S 56 0 E 3626 13 S 56 19 E 3694 03 S 56 15 E 3762 11 S 55 54 E 3830 58 S 56 17 E 3899 41 S 56 32 E 3968 35 S 56 31 E 4037 14 S 55 34 E 4104 46 S 55 49 E 4170 50 S 54 36 E 4234 52 0 25 0 31 0 67 0 38 0 31 0 16 1 97 0 45 2 65 I 87 2201 89 S 2881 26 E 3626 29 S 52 37 E 2239 2277 2315 2354 2392 243O 2468 2505 75 S 2937 58 S 2994 86 S 3051 35 S 3108 56 S 3166 50 S 3223 38 S 3279 62 S 3333 74 E 3694 47 E 3762 34 E 3830 51E 3899 02 E 3968 55 E 4037 29 E 4104 91 E 4170 2541 81 S 3386 80 E 4234 16 S 52 41E 21 S 52 45 E 65 S 52 48 E 46 S 52 52 E 38 S 52 55 E 15 S 52 59 E 47 S 53 2 E 51 S 53 4 E 52 S 53 7 E ARCO ALASKA, INC. 1H - 18 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 1-aPr-93 PAGE 3 DATE OF SURVEY: 02-MAR-1993 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULar COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/100 FEET FEET FEET DEG MIN 8000 O0 6380 70 6284.70 39 30 S 54 11 E 4298 21 8100 O0 6458 11 6362.11 38 53 S 54 33 E 4361 51 8200 O0 6535 97 6439 97 38 54 S 55 6 E 4424 23 8300 O0 6613 93 6517 93 38 38 S 55 7 E 4486 81 8400 O0 6692 38 6596 38 37 58 S 54 1 E 4548 81 8500 O0 6771 47 6675 47 37 25 S 53 6 E 4609 99 8600 O0 6850.86 6754 86 37 25 S 53 6 E 4670 79 8670 O0 6906.43 6810 43 37 25 S 53 6 E 4713 36 0.29 2579 07 S 3438 46 E 4298 21 S 53 8 E 0.78 2616 03 S 3489 86 E 4361 51 S 53 9 E 0.54 2652 13 S 3541 19 E 4424 23 S 53 10 E 0.68 2687 91 S 3592 58 E 4486 81 S 53 12 E 0.76 2723 83 S 3643 13 E 4548 81 S 53 13 E 0.00 2760 15 S 3692 37 E 4609 99 S 53 13 E 0.00 2796 66 S 3740 99 E 4670 80 S 53 13 E 0.00 2822 22 S 3775 03 E 4713 36 S 53 13 E COMPUTATION DATE: 1-APR-93 PAGE 4 ARCO A~SKA, INC. 1H - 18 KL~ARL~ RIVER NORTH SLOPE, A~KA DATE OF SURVEY: 02-MAR-1993 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: JEFF FORMICA IN1-ERPOLATED VALUES FOR EVEN 1OO0 FEET OF MEASURED DEPTH TRUE SUB-SEA CODRSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG M~N DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERII~ NORllJ/SOLFFH EAST/WEST DIST. AZIMLFFH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5O00 6000 7000 8000 8670 O0 999 O0 1957 O0 2705 O0 3428 O0 4162 O0 4907 O0 5641 O0 6380 O0 6906 0 O0 90 903 10 1861 42 2609 64 3332 71 4066 97 4811 41 5545 70 6284 43 6810 -96 O0 0 0 90 3 39 10 31 0 42 43 37 64 43 52 71 40 59 97 42 25 41 42 43 70 39 30 43 37 25 N 0 0 E S 72 24 E 0 S 48 50 E 256 S 48 10 E 914 S 50 1E 1603 S 54 57 E 2281 S 56 30 E 2947 S 56 0 E 3626 S 54 11E 4298 S 53 6 E 4713 0 O0 14 52 86 13 71 69 13 21 36 0 O0 3 23 3 85 0 3O 0 27 0 63 0 14 0 25 0 29 0 O0 0 O0 N 5 143 580 1037 1452 1827 2201 2579 2822 0 O0 E 20 N 4 60 S 212 14 S 7O8 51S 1225 91S 1762 84 S 2313 89 S 2881 07 S 3438 22 S 3775 0 O0 N 0 0 E 07 E 6 95 E 256 49 E 915 81E 1605 50 E 2284 76 E 2948 26 E 3626 46 E 4298 03 E 4713 60 N 38 2 E 84 S 56 0 E 71 S 50 41E 94 S 49 45 E 15 S 50 30 E 64 S 51 42 E 29 S 52 37 E 21 S 53 8 E 36 S 53 13 E COMPUTATION DATE' 1-APR-g3 PAGE 5 ARCO ALASKA, INC. 1H - 18 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 02-MAR-1993 KELLY BUSHING ELEVATION' 96.00 FT ENGINEER' JEFF 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 SEVERIT~ NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 96 O0 196 O0 296 O0 396 O0 496 O0 596 01 696 01 796 02 896 02 0 O0 96 O0 196 O0 296 O0 396 O0 496 O0 596 O0 696 O0 796 O0 896 O0 -96.00 0 0 N 0 0 E 0.00 0 3 N 36 49.W 100.00 0 9 N 25 23 E 200.00 0 8 N 11 15 W 300.00 0 19 N 6 15 E 400.00 0 23 N I 35 E 500.00 0 37 N 7 51E 600.00 0 38 N 7 4 E 700.00 0 36 N 11 5 E 800,00 0 40 N 37 28 E 0 O0 0 O2 -0 O5 -0 18 -0 37 -0 72 -1 20 -1 75 -2 24 -2 59 0 O0 0 36 0 O0 0 O0 0 23 0 25 0 O0 0 O0 0 O0 ! 14 0 O0 N 0 05 N 0 15 N 0 37 N 0 74 N I 34 N 2 27 N 3 36N 4 40N 5.40 N 0.00 E 006 E 0 06 E 005 E 009 E 0 10 E O2O E 034 E 050E 081 E 0.00 N 0 0 E 0.08 N 52 14 E 0.16 N 2O 47 E 0.37 N 7 8 E 0.74 N 6 44 E 1.34 N 4 12 E 2.28 N 5 4 E 3.38 N 5 44 E 4.43 N 6 30 E 5.46 N 8 34 E 996 09 1096 1197 1298 1400 1503 1606 1711 1818 1929 996.00 900.00 3 32 45 1096.00 1000.00 5 49 16 1196.00 1100,00 7 55 41 1296.00 1200.00 9 56 26 1396.00 1300,00 12 15 07 1496.00 1400.00 14 19 56 1596.00 1500.00 IS 37 19 1696.00 1600.00 18 53 54 1796.00 1700.00 23 37 74 1896.00 1800.00 28 8 S 72'57 E -0.09 S 71 31E 7.95 S 71 19 E 19.19 S 65 31E 34.42 S 58 29 E 53.47 S 54 30 E 77.28 S 53 2 E 103.90 S 51 54 E 134.65 S 49 1E 173.55 S 48 29 E 221.95 3 03 2 05 2 67 I 77 3 40 0 86 ,, 2 02 4 06 3 80 3 51 5 27 N 2 1 6 15 29 45 63 88 120 3 84 E 53 N 11 15 S 23 91S 37 98 S 54 27 S 74 O4 S 96 82 S 120 59 S 150 67 S 186 6 52 N 36 4 E 83 E 12 12 E 23 83 E 38 84 E 57 63 E 80 09 E 106 45 E 136 49 E 174 92 E 222 10 N 77 55 E 15 S 87 8 E 46 S 79 39 E 12 S 73 45 E 17 S 68 35 E 12 S 64 53 E 31 S 62 5 E 63 S 59 31E 49 S 57 9 E 2045 85 1996 O0 1900 O0 32 51 2168 2298 2434 2572 2710 2848 2986 3125 3262 36 2096 22 2196 78 2296 51 2396 42 2496 70 2596 99 2696 21 2796 87 2896 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 37 33 O0 41 35 O0 43 28 O0 43 30 O0 43 37 O0 43 42 O0 43 36 O0 43 34 O0 43 21 S 49 20 E S 48 55 E S 48 38 E S 48 55 E S 48 25 E S 48 20 E S 48 21 E S 48 12 E S 47 43 E 1000 S 47 44 E 1095 280 71 351 27 433 79 526 53 620 94 715 58 810 75 905 92 95 14 4 58 3 44 2 86 0 15 0 19 0 17 0 O0 0 25 0 O5 0 10 159 48 S 231 27 E 280 92 S 55 25 E 205 260 321 384 447 510 574 638 701 54 S 284 93 E 351 31 S 347 O1 E 433 47 S 417 06 E 526 04 S 488 15 E 621 14 S 559 13 E 715 59 S 630 50 E 811 16 S 701.80 E 906 09 S 772.63 E 1002 70 S 842.67 E 1096 33 S 54 12 E 79 S 53 8 E 57 S 52 23 E 11 S 51 48 E 94 S 51 21E 32 S 51 0 E 74 S 5O 43 E 06 S 50 27 E 58 S 50 13 E 3400.45 2996.00 2900,00 43 28 3538.77 3096.00 3000.00 43 52 3677.26 3196.00 3100.00 43 45 3815.91 3296.00 3200.00 43 51 3954.73 3396.00 3300.00 43 51 4093.55 3496.00 3400.00 43 55 4231.80 3596.00 3500,00 43 24 4369,41 3696.00 3600.00 43 19 4506,61 3796,00 3700.00 42 55 4642.62 3896.00 3800.00 42 31 S 47 39 E 1189 19 S 48 25 E 1284 S 48 23 E 1379 S 50 18 E 1475 S 49 56 E 1571 S 51 6 E 1667 S 51 14 E 1763 S 51 5 E 1857 S 51 12 E 1951 S 53 26 E 2043 36 84 67 81 97 38 85 72 89 0 3O 0 27 0 35 0 36 0 11 0 38 0 25 0 24 0 49 1 71 765 33 S 912.51 E 1190 97 S 50 1 E 829 892 955 1017 1078 1138 1197 1256 1313 33 S 983.49 E 1286 98 S 1055.10 E 1382 51 S 1127 98 E 1478 34 S 1201 81 E 1574 79 S 1275 92 E 1670 62 S 1350 30 E 1766 92 S 1423 92 E 1860 96 S 1496 98 E 1954 84 S 1569 53 E 2046 48 S 49 52 E 26 S 49 45 E 29 S 49 44 E 58 S 49 45 E 85 S 49 47 E 29 S 49 52 E 79 S 49 56 E 71 S 49 59 E 85 S 50 4 E COMPL~ATION DATE' 1-APR-93 PAGE 6 ARCO ALASKA, INC. IH - 18 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 02-MAR-1993 KELLY BUSHING ELEVATION' 96.00 FT ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH IRUE 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 FEET DEG MIN 4777 70 3996 O0 3900 O0 41 56 4911 5044 5177 5310 5443 5578 5712 5848 5983 48 4096 15 4196 04 4296 O0 4396 68 4496 25 4596 51 4696 04 4796 79 4896 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 450O O0 4600 O0 4700 O0 4800 O0 41 17 O0 41 6 O0 41 11 O0 41 12 O0 42 4 O0 41 55 O0 41 53 O0 42 39 O0 42 27 S 54 4 E 2134 70 S 54 26 E 2223 S 55 7 E 2310 S 55 21E 2398 S 55 39 E 2485 S 55 31E 2574 S 55 42 E 2664 S 55 55 E 2753 S 56 35 E 2845 S 56 31E 2936 53 68 14 70 33 3O 80 13 77 0 57 0 43 0 19 0 16 0 39 0 24 0 31 0 74 0 39 0 22 1367 28 S 1642 96 E 2137 47 S 50 14 E 1419 1469 1519 1569 1619 1670 1720 1771 1821 20 S 1715 52 S 1786 40 S 1858 13 S 1930 17 S 2003 10 S 2077 51S 2151 23 S 2228 80 S 2304 06 E 2226 26 E 2313 17 E 2400 32 E 2487 57 E 2576 84 E 2665 91E 2755 O3 E 2846 64 E 2937 11 S 50 24 E 05 S 50 33 E 29 S 50 44 E 63 S 50 54 E 05 S 51 3 E 83 S 51 13 E 15 S 51 21E 29 S 51 31E 74 S 51 40 E 6119 23 4996 O0 4900 O0 42 50 6256 6394 6531 6667 6802 6938 7074 7211 7348 97 5096 60 5196 83 5296 91 5396 97 5496 15 5596 40 5696 07 5796 75 5896 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 55O0 O0 5600 O0 5700 O0 5800 O0 43 31 O0 43 2O O0 43 5 O0 42 20 O0 41 59 O0 42 46 O0 42 55 O0 42 55 O0 43 30 S 56 30 E 3027 96 S 56 42 E 3122 S 56 45 E 3216 S 56 43 E 3310 S 56 49 E 3402 S 56 56 E 3493 S 55 54 E 3584 S 56 15 E 3676 S 56 13 E 3769 S 56 2 E 3864 52 90 70 80 40 20 61 64 15 2 39 0 04 0 32 0 44 0 20 0 74 0 O0 0 26 0 64 0 53 1872 26 S 2380 79 E 3028 78 S 51 49 E 1924 1976 2O27 2078 2128 2178 2230 2281 2334 44 S 2459 34 S 2538 91S 2617 53 S 2694 15 S 2770 37 S 2846 O7 S 2923 77 S 3000 69 S 3079 84 E 3123 19 S 51 58 E 89 E 3217 44 S 52 6 E 46 E 3311 12 S 52 14 E 62 E 3403 13 S 52 21 E 66 E 3493 64 S 52 28 E 48 E 3584 38 S 52 34 E 23 E 3676 75 S 52 40 E 74 E 3769 73 S 52 45 E 18 E 3864 21 S 52 50 E 7486 89 5996 O0 5900 O0 43 41 7624 67 6096 7759 18 6196 7890 11 6296 8019 82 6396 8148 65 6496 8277 03 6596 8404 59 6696 8530 90 6796 8656 86 6896 O0 6000 O0 6100 O0 6200 O0 6300 O0 6400 O0 6500 O0 6600 O0 6700 O0 6800 O0 42 45 O0 41 25 O0 39 39 O0 39 27 O0 38 50 O0 38 43 O0 37 57 O0 37 25 O0 37 25 S 56 30 E 3959 31 $ 56 2 E 4053 S 55 45 E ,4143 S 54 55 E 4228 S 54 12 E 4310 S 54 55 E 4392 S 55 14 E 4472 S 53 58 E 4551 S 53 6 E 4628 S 53 6 E 4705 93 79 22 81 O1 47 63 78 37 0 18 2 82 2 23 2 13 0 03 0 35 0 57 0 72 0 O0 0 O0 2387 57 S 3158.47 E 3959 35 S 52 55 E 2439 2490 2538 2586 2633 2679 2725 2771 2817 85 S 3237.53 E 4053 94 S 53 0 E 58 S 3311.81 E 4143 80 $ 53 3 E 18 S 3381.64 E 4228 22 S 53 7 E 44 S 3448.68 E 4310 81 S 53 8 E 65 S 3514.78 E 4392 O1 S 53 9 E 71 S 3580.81 E 4472 47 S 53 11 E 49 $ 3645.41 E 4551 63 S 53 13 E 43 S 3707.40 E 4628 78 S 53 13 E 42 S 3768.64 E 4705 37 S 53 13 E 8670 O0 6906.43 6810.43 37 25 S 53 6 E 4713.36 0 O0 2822.22 $ 3775.03 E 4713.36 S 53 13 E ARCO ALASKA, INC. iH - 18 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a GCT LAST READING BASE KUPARUK A PBTD 7" CASING COMPUTATION DATE: 1-APR-93 PAGE 7 DATE OF SURVEY: 02'MAR-1993 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR CHOSEN HQRIZONS SURFACE LOCATION = 799' FNL & 785' FEL, SEC33 T12N RIOE MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA 4975 O0 8030 O0 8233 O0 8409 O0 8499 O0 8550 O0 8564 O0 8652 O0 8670 O0 4143.84 6403.86 6561.67 6699.48 6770.68 6811.16 6822.28 6892.14 6906.43 4047 84 6307 86 6465 67 6603 48 6674 68 6715 16 6726 28 6796 14 6810 43 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 1443 46 S 2590 23 S 2663 98 S 2727 09 S 2759 78 S 2778 40 S 2783 52 S 2815 65 S 2822 22 S 1749 10 E 3453 93 E 3558 17 E 3647 60 E 3691 90 E 3716 68 E 3723 49 E 3766 28 E 3775 03 E ARCO ALASKA, INC. 1H - 18 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 1-APR-93 PAGE 8 DATE OF SURVEY: 02-MAR-1993 KELLY BUSHING ELEVATION: 96.00 ET ENGINEER: JEFF FORMICA ************ S1-RATIQRAPHIC S/~ARY ************ MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD SURFACE LOCATION = 799' FNL A 785' FEL, SEC33 T12N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 8030.00 8233.00 8409.00 8550.00 8564.00 8670.00 6403 86 6561 67 6699 48 6811 16 6822 28 6906 43 6307 86 6465 67 6603 48 6715 16 6726 28 6810 43 2590 23 S 2663 98 S 2727 09 S 2778 40 S 2783 52 S 2822 22 S 3453 93 E 3558 17 E 3647 60 E 3716 68 E 3723 49 E 3775 03 E FINAL WELL LOCATION AT -rD: 1-RUE SUB-SEA MEASURD VERTICAL VERTICAJ_ DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 8670.00 6906.43 6810.43 4713.36 S 53 13 E DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. FIELD KUPARUK RIVER WELL 1 H - 18 COUNTRY USA RUN ONE DATE LOGGED 02 - MAR - 93 DEPTH UNIT FEET REFERENCE 93110 Ail Int®~pr~atione are opinlone ba.~e~ on Inferences from electrical or other mea~uremenl~ and we cannot, end do not guarantee the accuracy or correct,ieee of any In~e~pretatione. and we shall not. except In tl'~ ceee of g~s~ or wlEull ~l~en~ on our pa~. be liable or rlspons~ for ~y Io11. col~. d~ages o~ lXptnlll Incu~td or su~al~d by WELL: 1H-18 (799' FNL, 785' FEL, SEC 33, T12N, RIOE, UN) HORIZONTAL PROJECTION 3000 2000 1000 -1000 -2000 -3000 931 iO SCALE = 1 / i. ..... 1000 ~N/f"r soum -5000 -2000 - 1000 0 1000 5000 WEST 6000 ~AS'r bELL: 11-1-18 (799' FNL, 785' FEL, SEC 33, T12N, RIOE, UN) VERTICAL PROJECTION 7 O0 -1000 -5OO 0 0 500 1000 1500 2000 2500 3000 . ..t ;:ii i::I).- ! i'*:' f'~: :,i: .... . I J : : ' ' ~' : : :'' : * : !':> i3000' ~ : : :' : : ' ............. I .... i-hi-:- * ~:: i.:! :- ; ..... ;!:..:~:i:..i.~: .... . , ~ .... l::::i!"! ~:~,:;!~ iii: ~!~:i:!:: ::" ::~! !!~ ii:: ~!! .× oe',o ....../ ,'-~!'7---- -~ .... ~ T i 7- . : ; :' i : ~ ! '' i' i ..... ........... [ ....... i' ii:. " . . .... '.L.,; ......... : ...... ~; .................... ;', ...... ~ ........... . · : : - --:i :: i ..;! :i ..... : ; : !: . . ;::. ;: : :: :- ....... ~ ;.: .... ~ ....... : ...... ; i. ,.~.-.,...i--;..:-i ..... ~ ~ ~ i..: ......... : -4 ..... ~ ,., .i..;4..~ i., ; ..... : ..~ ...... : . : . . : ..... ~ ~ :.i i i i..i.i.i., i i..:..i. .;.i.i.i ..... i.~.! i ;.~ i.i ~ ~ ; .... : . ; ~ , i : : ..; ~ : ~ . : i ; ~ · .... ; :: '::~: ' ' ': . r .... J .... -- ;.. :: :; : :.:: ~ : ..: ,,, ,, .. . .~. ....... i ...: i i i :.: .... L ..! ....... ! ..i..: .... i..i.!.: ...... · .......... i . : .... ~ : :.: i .... i ..... i ..... i ...... :.i i .... : ..... . - . . ,-' i~i; ;-;--!; :~oo, ;-~i' ~: .......... - -~!-! i:-: .... ii-! !i:: ~-!ii- i-~: . ' · ..... :: .::~ !i:.; ii~ ~.!i! !!'!: 'ii ............. :' ,i:~ ~i:..~..!..!.!~ "i"i!i 'i'-i'!"!'~ii~ ~i~'i' I ..... i ..... : .... : ..... "::. 'i;i'"'";';'i'!"~":'"~'!~'?:"~"~'"~-~i!~'~'!'i: ' I "'~": ~ ....... . .......... } . 1 ~'' '~!!''?'!"2! .... !-!''!' ~.!!!,~:!*i~- I' !'~ '' '' ..... :.. _i:.:...}...}..~..~..~...i..;.i..:. 2::; .~:-,:I ..... : ..... .......... . . ....................................... ,;.~.i',,...,., ............ , : : ' ! ! i i'' !'i' ! i' i' ! ! i"i ~ ..... ! i ! i !'; ; : i = ! ! : ; ! i > i ~ i i .... I ..... i i ~ ! i ! ' i ' ! ~ ~ - ~ ! ' i ....... i ' ' ! --; ..... ........ : -. i::i :ii: :i*: :~:i :i:: -:'' · ! :,:- :- - . . . : ..... . . : : . . _='~;'~"!!' !i'i~''~!'!L[;~o~{~;''!''' ' ....... ; .... ~";:~.... ~'" PROJECTION ON VERTICAL PI.ANE7.00 *187.00 SCALED IN VER'FICN, OEI~THg ~lZ ~CALE -- I / 500 SUB - S URFA CE DIRECTIONAL SURVEY J'~ UIDANCE [~ ONTINUOUS ~ OOL Company Well Name Field/Location Job Reference No. 93110 Logc~ed By: FORlqICA ARCO ALASKA, INC. 1H-18 (799' FNL, 786' FEL, SEC 33, T12N, RIOE, UN) KUPARUK, NORTH SLOPE, ALASKA 0¥ ~ 5 199;~ & Gas Oons, Corr~missi~:~"~ Anchorage Date 2-NAR-1993 Computed By: STNES · SCHLUMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 1H - 18 KUPARUK RIVER NORTH SLOPE, AI_ASKA SURVEY DATE: 02-MAR-1993 ENGINEER' JEFF FORMICA METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH $3 DEG 9 MIN EAST ARCO ALASKA, INC. 1H - 18 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE' 1-APR-93 TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 599 99 699 gg 799 98 899 98 PAGE 1 DATE OF SURVEY: 02-MAR-1993 KELLY BUSHING ELEVATION: 96,00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN IO0,FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 0 N 0 0 E 0 3 N 52 42 W 0 9 N2231 E 0 8 N 9 4 W 019 N 5 7E 0 24 N 2 14 E 0 37 N 7 40 E O37 N 7 3 E 0 35 N 11 11 E 0 41 N 41 6 E S 72 24 E S 71 36 E S 71 12 E S 65 26 E S 58 30 E S 54 32 E S53 4 E $51 58 E S 49 29 E S 48 34 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 -96 O0 4 O0 104 O0 204 O0 304 O0 404 O0 503 99 603 99 703 98 803 98 999.90 903.90 3 39 O0 1099.53 1003.53 5 53 O0 1198,81 1102.81 7 59 O0 1297 57 1201.57 9 57 O0 1395 75 1299.75 12 15 O0 1493 03 1397.03 14 18 O0 1589 68 1493.68 15 30 O0 1685 40 1589.40 18 25 O0 1778 96 1682.96 22 52 O0 1869 65 1773.65 27 4 2000 O0 1957 10 1861 10 31 0 90 35 2 91 38 35 34 41 38 74 43 24 35 43 25 94 43 31 45 43 36 79 43 42 07 43 45 S 48 5O E S 49 34 E S 48 39 E S 48 38 E S 48 58 E S 48 4O E S 48 25 E S 48 19 E S 48 23 E S 48 18 E 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 2040 O0 2120 O0 2197 O0 227O O0 2343 O0 2415 O0 2488 O0 256O O0 2633 90 1944 91 2024 34 2101 74 2174 35 2247 94 2319 45 2392 79 2464 07 2537 FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 0 O2 -0 05 -0 19 -0 38 -0 74 -1 22 -1 77 -2 25 -2 58 0.14 8.30 19.56 34.69 53.41 76.52 102.15 131.08 166.26 208.21 256.52 310 90 370 71 434 96 502 68 571 25 639 80 708 42 777 22 846 09 0 O0 0 42 0 O0 0 O0 0 21 0 36 0 O0 0 O0 0 O0 I 24 3 23 1 90 2 68 1 76 3 39 0 95 1 73 4 25 4 22 3 75 3.85 3.56 3.10 2.88 0.36 0.35 0.18 0.21 0.17 0.32 0.00 N 0.05 N 0.16 N 0.38 N 0.76 N 1.36 N 2.31 N 3.41 N 4.44 N 5.43 N 000 E 0 06 E 0 06 E 0 04 E 009 E 0 10 E 021 E 0 34 E 0 51 E 0 85 E 0.00 N 0 0 E O. 08 N 50 2 E O. 17 N 2O 46 E 0.38 N 6 43 E 0.76 N 6 43 E 1.37 N 4 10 E 2.32 N 5 7 E 3.42 N 5 45 E 4.47 n 6 33 E 5.50 N 8 51 E 2 1 7 15 28 43 61 83 111 5 20 N 42 N 12 28 S 23 03 S 38 95 S 54 83 S 74 99 S 94 61S 117 82 S 144 54 S 176 4 07 E 18 E 12 49 E 23 O8 E 38 79 E 57 02 E 79 69 E 104 63 E 132 95 E 167 60 E 208 6 60 N 38 2 E 42 N 78 46 E 52 S 86 53 E 72 S 79 33 E 07 S 73 46 E 43 S 68 43 E 41 S 65 5 E 79 S 62 21E 44 S 59 58 E 87 S 57 43 E 143.60 S 212 95 E 256.84 S 56 0 E 179.13 S 254 218.40 S 299 261.08 S 347 305.76 S 399 351.01S 450 396.60 S 502 442.36 S 553 488.24 S 6O5 534.18 S 656 27 E 311.04 S 54 50 E 59 E 370.75 S 53 55 E 89 E 434.97 S 53 7 E 03 E 502.71 S 52 32 E 80 E 571.34 S 52 6 E 31 E 640.00 S 51 42 E 76 E 708.76 S 51 23 E 36 E 777.71 S 51 7 E 99 E 846.75 S 50 53 E 3000.00 2705.42 2609.42 43 37 3100.00 2777.75 2681.75 43 39 3200.00 2850.28 2754.28 43 22 3300.00 2923.00 2827.00 43 21 3400.00 2995.68 2899.68 43 28 3500.00 3068.04 2972.04 43 50 3600.00 3140.19 3044.19 43 45 3700.00 3212.43 3116.43 43 45 3800.00 3284.53 3188.53 43 52 3900.00 3356.56 3260.56 43 57 S 48 10 E 914.86 S 47 43 E 983.64 S 47 48 E 1052.17 S 47 41 E 1120.51 S 47 39 E 1188 88 S 48 12 E 1257 60 S 48 23 E 1326 60 S 48 32 E 1395 51 S 50 16 E 1464 65 S 49 58 E 1533 92 0 3O 0 65 0 29 0 03 0 30 0 62 0 28 0 6O 0 54 0 32 580 14 S 708 49 E 915 71 S 50 41 E 626 672 718 765 811 857 903 948 992 40 S 759 69 S 810 86 S 861 13 S 912 46 S 963 46 S 1015 42 S 1066 46 S 1119 90 $ 1172 77 E 984 72 E 1053 52 E 1122 29 E 1190 43 E 1259 19 E 1328 86 E 1397 51E 1467 76 E 1536 69 S 50 30 E 46 S 50 19 E 04 S 50 9 E 66 S 50 1E 63 S 49 54 E 85 S 49 49 E 98 S 49 45 E 27 S 49 44 E 63 S 49 45 E ARCO ALASKA, INC. IH - I8 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 1-APr-93 PAGE 2 DATE OF SURVEY: 02-MAR-1993 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN IO0 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4000 O0 3428 64 3332 64 43 52 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3500 O0 3572 O0 3645 O0 3718 O0 3791 O0 3864 O0 3938 O0 4012 O0 4087 65 3404 92 3476 56 3549 26 3622 16 3695 62 3768 37 3842 60 3916 38 3991 65 43 54 92 43 31 56 43 25 26 43 2O 16 42 57 62 42 37 37 42 18 60 41 49 38 41 20 5000 O0 4162 71 4066 71 40 59 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4238 O0 4313 O0 4388 O0 4463 O0 4537 O0 4612 O0 4686 O0 4760 O0 4834 OS 4142 28 4217 48 4292 52 4367 81 4441 19 4516 68 4590 68 4664 05 41 13 28 41 12 48 41 13 52 41 49 81 42 2 19 41 53 68 41 50 68 42 43 24 4738.24 42 35 6000 O0 4907 97 4811 97 42 25 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 4981 O0 5054 O0 5127 O0 5199 O0 5272 O0 5345 O0 5419 O0 5493 O0 5567 85 4885 70 4958 23 5031 93 5103 77 5176 93 5249 73 5323 79 5397 96 5471 85 42 33 70 43 35 23 43 27 93 43 20 77 43 12 93 42 43 73 42 18 79 42 0 96 42 37 7000 O0 5641 41 5545 41 42 43 7100 720O 7300 7400 7500 7600 7700 780O 7900 O0 5714 O0 5787 O0 5860 O0 5933 O0 6005 O0 6077 O0 6151 O0 6226 O0 6303 74 5618 89 5691 69 5764 15 5837 48 5909 95 5981 82 6055 85 6130 62 6207 74 42 59 89 42 55 69 43 40 15 43 37 48 43 41 95 43 15 82 41 50 85 40 21 62 39 37 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEG MIN FEET S 50 1E 1603 13 S 51 7 E 1672 44 S 51 12 E 1741 52 S 51 9 E 1810 21 S 51 4 E 1878 83 S 51 11 E 1947 23 S 52 10 E 2015 05 S 54 4 E 2082.58 S 54 7 E 2149.58 S 54 25 E 2215.95 S 54 57 E"2281 71 S 55 16 E 2347 42 5 55 22 E 2413 26 S 55 36 E 2479 12 S 55 36 E 2545 15 S 55 31 E 2612 03 S 55 44 E 2678 81 S 55 51 E 2745 46 S 56 29 E 2812 62 S 56 36 E 2880 25 S 56 30 E 2947 69 S 56 29 E 3014 S 56 35 E 3083 S 56 43 E 3152 S 56 45 E 3220 S 56 43 E 3288 5 56 43 E 3357 S 56 51E 3424 S 56 56 E 3491 S 56 9 E 3558 96 34 O7 60 97 O2 36 42 35 S 56 0 E 3626 13 S 56 19 E 3694 S 56 15 E 3762 S 55 54 E 3830 S 56 17 E 3899 S 56 32 E 3968 S 56 31E 4037 $ 55 34 E 4104 S 55 49 E 4170 S 54 36 E 4234 03 11 58 41 35 14 46 50 52 DEG/IO0 FEET FEET FEET DEG MIN 0 27 0 36 0 42 0 27 0 19 0 47 I 87 0 36 0 45 0 52 0 63 0 19 0 17 0 37 1 06 0 27 0 15 0 46 0 38 0 22 0 14 1 17 0 14 0 23 0 32 0 26 0 51 0 05 0 81 1 14 0 25 0 31 0 67 0 38 0 31 0 16 I 97 0 45 2 65 1 87 1037 51 S 1225 81 E 1605 94 S 49 45 E 1081 1124 1167 1211 1254 1296 1336 1376 1414 60 S 1279 92 S 1333 98 S 1386 11S 1440 15 S 1493 38 S 1546 68 S 1600 O1S 1655 78 S 1708 40 E 1675 26 E 1744 82 E 1813 25 E 1881 47 E 1950 57 E 2018 76 E 2085 02 E 2152 90 E 2218 33 S 49 47 E 42 S 49 51E 13 S 49 54 E 78 S 49 56 E 22 S 49 59 E O4 S 5O 2 E 46 S 50 8 E 32 5 50 16 E 55 S 50 23 E 1452 91 S 1762 50 E 2284 15 S 50 30 E 1490 1528 1565 1602 1640 1678 1715 1753 1790 51S 1816 O0 S 1870 41S 1924 65 S 1979 54 S 2O34 29 S 2089 82 S 2145 27 S 2200 60 S 2257 44 E 2349 61E 2415 89 E 2481 49 E 2546 67 E 2613 84 E 2680 O0 E 2746 86 E 2813 39 E 2881 69 S 50 38 E 36 S 50 45 E 07 S 50 53 E 93 S 51 0 E 67 S 51 7 E 31 S 51 14 E 83 S 51 21E 85 S 51 27 E 33 S 51 35 E 1827 84 S 2313 76 E 2948 64 S 51 42 E 1865 1902 1940 1978 2015 2053 2090 2127 2163 06 S 2369 86 S 2427 70 S 2484 37 S 2541 96 S 2599 39 S 2656 36 S 2712 06 S 2768 91S 2825 94 E 3015 07 E 3084 58 E 3152 99 E 3221 27 E 3289 25 E 3357 7O E 3424 99 E 3491 03 E 3558 80 S 51 48 E 07 S 51 54 E 69 S 52 0 E 13 S 52 6 E 42 S 52 12 E 39 S 52 18 E 67 S 52 23 E 66 S 52 28 E 55 S 52 33 E 2201 89 S 2881 26 E 36~6 29 S 52 37 E 2239 2277 2315 2354 2392 2430 2468 2505 2541 75 S 2937 58 S 2994 86 S 3051 35 S 3108 56 S 3166 50 S 3223 38 S 3279 62 S 3333 81S 3386 74 E 3694 47 E 3762 34 E 3830 51E 3899 02 E 3968 55 E 4O37 29 E 4104 91E 4170 8O E 4234 16 S 52 41E 21 S 52 45 E 65 S 52 48 E 46 S 52 52 E 38 S 52 55 E 15 S 52 59 E 47 S 53 2 E 51 S 53 4 E 52 S 53 7 E COMPUTATION DATE: 1-APr-93 PAGE 3 ARCO ALASKA, INC. 1H - 18 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 02-MAR-1993 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET Of MEASURED DEPTH TRUE SUB-SD COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASLARED VERTICAL VERTICAL DEVIATION AZIMLFFH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMLFFH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 8000.00 6380 70 6284.70 39 30 S 54 11 E 4298 21 8100.00 6458 11 6362.11 38 53 S 54 33 E 4361 51 8200.00 6535 97 6439.97 38 54 S 55 6 E 4424 23 8300.00 6613 93 6517.93 38 38 S 55 7 E 4486 81 8400.00 6692 38 6596.38 37 58 S 54 1 E 4548 81 8500.00 6771 47 6675.47 37 25 S 53 6 E 4609 99 8600.00 6850 86 6754.86 37 25 S 53 6 E 4670 79 8670.00 6906.43 6810.43 37 25 S 53 6 E 4713 36 0 29 2579 07 $ 3438 46 e 4298 21 S 53 8 E 0 78 2616 03 S 3489 86 E 4361 51 S 53 9 E 0 54 2652 13 S 3541 19 E 4424 23 S 53 10 E 0 68 2687 91 S 3592 58 E 4486 81 S 53 12 E 0 76 2723 83 S 3643 13 E 4548 81 S 53 13 E 0 O0 2760 15 S 3692 37 E 4609 99 S 53 13 E 0 O0 2796 66 S 3740 99 E 4670 80 S 53 13 E 0 O0 2822 22 S 3775 03 E 4713 36 S 53 13 E ARCO ALASKA, INC. 1H - lB KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 1-APR-g3 PAGE 4 DATE OF SURVEY: 02-MAR-1993 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICA/_ VERTICAL DEVIATION AZIgUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIgLrTH DEPTH DEPTH DEPTH DEG gIN DEG gIN FEET DEG/IO0 FEET FEET FEET DEG 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 8670 0 O0 -96.00 0 0 N 0 0 E O0 999 O0 1957 O0 2705 O0 3428 O0 4162 O0 4907 O0 5641 O0 6380 O0 6906 0 O0 90 903.90 3 39 S 72 24 E 0 10 1861.10 31 0 S 48 50 E 256 42 2609.42 43 37 S 48 10 E 914 64 3332.64 43 52 S 50 1 E 1603 71 4066.71 40 59 S 54 57 E 2281 97 4811.97 42 25 S 56 30 E 2947 41 5545.41 42 43 S 56 0 E 3626 70 6284.70 39 30 S 54 11 E 4298 43 6810.43 37 25 S 53 6 E 4713 14 52 86 13 71 69 13 21 36 0 O0 3 3 0 0 0 0 0 0 0 0 O0 N 23 5 85 143 30 580 27 1037 63 1452 14 1827 25 2201 29 2579 O0 2822 0 O0 E 20 N 4 60 S 212 14 S 708 51S 1225 91S 1762 84 S 2313 89 S 2881 07 S 3438 22 S 3775 0 O0 N 0 0 E 07 E 6 95 E 256 49 E 915 81E 1605 50 E 2284 76 E 2948 26 E 3626 46 E 4298 03 E 4713 60 N 38 2 E 84 S 56 0 E 71 S 50 41E 94 S 49 45 E 15 S 5O 30 E 64 S 51 42 E 29 S 52 37 E 21 S 53 8 E 36 S 53 13 E COMPUTATION DATE: 1-APr-93 PAGE ARCO ALASKA, INC. 1H - i8 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 02-MAR-1993 KELLY BUSHING ELEVATION' 96.00 FT ENGINEER' JEFF 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. DEPARTIJRE SECTION SEVERITY NORTH/SOLFFH EAST/WEST DIST. AZIMLFFH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 96 O0 196 O0 296 O0 396 O0 496 O0 596 O1 696 O1 796 O2 896 O2 0.00 96.00 196.00 296.00 396.00 496.00 596.00 696.00 796.00 896.00 -96 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800.00 0 0 N 0 0 E 0 3 N 36 49 W 0 9 N 25 23 E 0 8 N 11 15 W 0 19 N 6 15 E 0 23 N 1 35 E 0 37 N 7 51 E 038 N 7 4 E 036 N 11 5 E 0 40 N 37 28 E 0 O0 0 02 -0 05 -0 18 -0 37 -0 72 -1 20 -1 75 -2 24 -2 59 0 O0 0 36 0 O0 0 O0 0 23 0 25 0 O0 0 O0 0 O0 1 14 0 O0 N 0 05 N 0 15 N 0 37 N 0 74 N 1 34 N 2 27 N 3 36 N 4 40 N 5 40 N 0 O0 E 0 06 E 0 06 E 0 05 E 0 09 E 0 10 E 0 20 E 0 34 E 0 50 E 0 81 E 000 N 0 0 E 08 N 52 14 E 16 N 20 47 E 37 N 7 8 E 74 N 6 44 E 34 N 4 12 E 28 N 5 4 E 38 N 5 44 E 43 N 6 3O E 46 N 8 34 E 996 09 1096 1197 1298 1400 1503 1606 1711 1818 1929 45 1096 16 1196 41 1296 26 1396 07 1496 56 1596 19 1696 54 1796 996 O0 900.00 O0 1000 O0 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 3 32 S 72 57 E 5 49 S 71 31E O0 7 55 S 71 19 E O0 9 56 S 65 31E O0 12 15 S 58 29 E O0 14 19 S 54 30 E O0 15 37 S 53 2 E O0 18 53 S 51 54 E O0 23 37 S 49 1E S 48 29 E 74 1896.00 1800.00 28 8 -0 09 7 95 19 19 34 42 53 47 77 28 103 90 134 65 173 55 221 95 3 03 2 05 2 67 1 77 3 40 0 86 2 02 4 06 3 80 3 51 5 27N 2 1 6 15 29 45 63 88 120 3.84 E 53 n 11.83 E 12 15 S 23.12 E 23 91S 37.83 E 38 98 S 54.84 E 57 27 S 74.63 E 80 04 S 96.09 E 106 82 S 120.45 E 136 59 S 150.49 E 174 67 S 186.92 E 222 6 52 N 36 4 E 10 N 77 55 E 15 S 87 8 E 46 S 79 39 E 12 S 73 45 E 17 S 68 35 E 12 S 64 53 E 31 S 62 5 E 63 S 59 31E 49 S 57 9 E 2045 85 1996 O0 1900.00 32 51 2168 2298 2434 2572 2710 2848 2986 3125 3262 36 2096 22 2196 78 2296 51 2396 42 2496 70 2596 99 2696 21 2796 87 2896 O0 2000.00 37 33 O0 2100,00 41 35 O0 2200.00 43 28 O0 2300.00 43 30 O0 2400.00 43 37 O0 2500.00 43 42 O0 2600.00 43 36 O0 2700.00 43 34 O0 2800.00 43 21 S 49 20 E S 48 55 E S 48 38 E S 48 55 E S 48 25 E S 48 20 E S 48 21E S 48 12 E S 47 43 E 1000 S 47 44 E 1095 280 71 351 27 433 79 526 53 620 94 715 58 810 75 905 92 95 14 4 58 3 44 2 86 0 15 0 19 0 17 0 O0 0 25 0 05 0 10 159 48 S 231.27 E 280 92 S 55 25 E 205 260 321 384 447 510 574 638 701.70 S 842 54 S 284 93 E 351 31S 347 47 S 417 04 S 488 14 S 559 59 S 630 16 S 701 09 S 772 O1E 433 06 E 526 15 E 621 13 E 715 50 E 811 80 E 906 63 E 1002 67 E 1096 33 S 54 12 E 79 S 53 8 E 57 S 52 23 E 11 S 51 48 E 94 S 51 21E 32 S 51 0 E 74 S 50 43 E 06 S 50 27 E 58 S 50 13 E 3400 45 2996.00 2900.00 43 28 3538 3677 3815 3954 4093 4231 4369 4506 4642 77 3096.00 3000.00 43 52 26 3196.00 3100.00 43 45 91 3296.00 3200.00 43 51 73 3396.00 3300 O0 43 51 55 3496.00 3400 O0 43 55 80 3596.00 3500 O0 43 24 41 3696.00 3600 O0 43 19 61 3796.00 3700 O0 42 55 62 3896.00 3800 O0 42 31 S 47 39 E 1189.19 S 48 25 E 1284.36 S 48 23 E 1379.84 S 50 18 E 1475 67 S 49 56 E 1571 81 SSl 6 E 1667 97 S 51 14 E 1763 38 S 51 5 E 1857 85 S 51 12 E 1951 72 S 53 26 E 2043 89 0 3O 0 27 0 35 0 36 0 11 0 38 0 25 0 24 0 49 1 71 765.33 S 912.51E 1190.97 S 50 1E 829 33 S 983.49 E 1286.48 S 49 52 E 892 955 1017 1078 1138 1197 1256 1313 98 S 1055.10 E 1382.26 S 49 45 E 51 S 1127 98 E 1478 29 S 49 44 E 34 S 1201 81 E 1574 58 S 49 45 E 79 S 1275 92 E 1670 85 S 49 47 E 62 S 1350 30 E 1766 29 S 49 52 E 92 S 1423 92 E 1860 79 S 49 56 E 96 S 1496 98 E 1954 71 S 49 59 E 84 S 1569 53 E 2046 85 S 50 4 E COMPUTATION DATE' 1-APr-g3 PAGE 6 ARCO ALASKA, INC. IH - 18 KUPARUK RIVER NORTH SLOPE, ALASKA DATE Of SURVEY' 02-MAR-1993 KELLY BUSHING ELEVATION' 96.00 FT ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN IO0,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/IO0 FEET FEET FEET DEG MIN 4777 70 3996 O0 3900 O0 41 56 4911 5044 5177 5310 5443 5578 5712 5848 5983 48 4096 15 4196 04 4296 O0 4396 68 4496 25 4596 51 4696 04 4796 79 4896 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 41 17 O0 41 6 O0 41 11 O0 41 12 O0 42 4 O0 41 55 O0 41 53 O0 42 39 O0 4800.'00 42 27 S 54 4 E 2134 70 S 54 26 E 2223 S 55 7 E 2310 S 55 21E 2398 S 55 39 E 2485 S 55 31E 2574 S 55 42 E 2664 S 55 55 E 2753 S 56 35 E 2845 S 56 31E 2936 53 68 14 70 33 3O 8O 13 77 0.57 0.43 0.19 0 16 0 39 0 24 0 31 0 74 0 39 0 22 1367 28 S 1642 96 E 2137 47 S 50 14 E 1419 i469 i5i9 1569 i6i9 i670 i720 1771 i82i 20 S 1715 52 S 1786 40 S 1858 13 S 1930 17 S 2003 10 s 2077 51 s 2151 23 S 2228 80 S 2304 06 E 2226 11 S 50 24 E 26 E 2313 05 S 50 33 E 17 E 2400 29 S 50 44 E 32 E 2487 63 S 50 54 E 57 E 2576 05 S 51 3 E 84 E 2665 83 S 51 13 E 91 E 2755.15 S 51 21 E 03 E 2846.29 S 51 31 E 64 E 2937.74 S 51 40 E 6119 23 4996 O0 4900 O0 42 50 6256 6394 6531 6667 6802 6938 7074 7211 7348 97 5096 60 5196 83 5296 91 5396 97 5496 15 5596 40 5696 07 5796 75 5896 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 43 31 O0 43 20 O0 43 5 O0 42 20 O0 41 59 O0 42 46 O0 42 55 O0 42 55 O0 43 30 S 56 30 E 3027 96 S 56 42 E 3122 52 S 56 45 E 3216 90 S 56 43 E 3310 70 S 56 49 E 3402 80 S 56 56 E 3493 40 S 55 54 E 3584.20 s 56 15 E 3676.61 S 56 13 E 3769.64 S 56 2 E 3864.15 2 39 0 O4 0 32 0 44 0 2O 0 74 0 O0 0 26 0 64 0 53 1872 26 S 2380 79 E 3028.78 S 51 49 E 1924 1976 2027 2078 2128 2178 2230 2281 2334 44 S 2459 34 S 2538 9i S 26i7 53 S 2694 15 S 277O 37 S 2846 07 S 2923 77 S 3000 69 S 3079 84 E 3123 19 S 51 58 E 89 E 3217 46 E 3311 62 E 3403 66 E 3493 48 E 3584 23 E 3676 74 E 3769 18 E 3864 44 S 52 6 E 12 S 52 14 E 13 S 52 21E 64 S 52 28 E 38 S 52 34 E 75 S 52 40 E 73 S 52 45 E 21 S 52 50 E 7486 89 5996 O0 5900.00 43 41 7624 7759 7890 8019 8148 8277 8404 8530 8656 67 6096 18 6196 11 6296 82 6396 65 6496 03 6596 59 6696 90 6796 86 6896 O0 6000.00 42 45 O0 6100.00 41 25 O0 6200.00 39 39 O0 6300 O0 39 27 O0 6400 O0 38 50 O0 6500 O0 38 43 O0 6600 O0 37 57 O0 6700 O0 37 25 O0 6800 O0 37 25 S 56 30 E 3959 31 S 56 2 E 4053 S 55 45 E 4143 S 54 55 E 4228 S 54 12 E 4310 S 54 55 E 4392 S 55 14 E 4472 S 53 58 E 4551 S 53 6 E 4628 S 53 6 E 4705 93 79 22 81 O1 47 63 78 37 0 18 2 82 2 23 2 13 0 03 0 35 0 57 0 72 0 O0 0 O0 2387 57 S 3158 47 E 3959 35 S 52 55 E 2439 249O 2538 2586 2633 2679 2725 2771 2817 85 S 3237 58 S 3311 18 s 3381 44 s 3448 65 s 3514 71 s 3580 49 s 3645 43 s 3707 42 s 3768 53 E 4053 81E 4i43 64 E 4228 68 E 4310 78 E 4392 81E 4472 41E 455i 40 E 4628 64 E 4705 94 S 53 0 E 80 S 53 3 E 22 S 53 7 E 81 $ 53 8 E O1 S 53 9 E 47 S 53 ii E 63 S 53 13 E 78 S 53 13 E 37 S 53 13 E 8670.00 6906.43 6810.43 37 25 S 53 6 E 4713.36 0.00 2822.22 S 3775.03 E 4713.36 S 53 13 E COMPUTATION DATE: 1-APR-g3 PAGE 7 ARCO ALASKA, INC. 1H - 18 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a GCT LAST READING BASE KUPARUK A PBTD 7" CASINO DATE OF SURVEY: 02-MAR-1993 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 799' FNL & 785' FEL, SEC33 Ti2N RiOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4975 O0 8030 O0 8233 O0 8409 O0 8499 O0 8550 O0 8564 O0 8652 O0 8670 O0 4143 84 6403 86 6561 67 6699 48 6770 68 6811 16 6822 28 6892 14 6906 43 4047 84 6307 86 6465 67 6603 48 6674 68 6715 16 6726 28 6796 14 6810 43 1443.46 S 2590.23 S 2663.98 S 2727 O9 S 2759 78 S 2778 4O S 2783 52 S 2815 65 S 2822 22 S 1749 10 E 3453 93 E 3558 17 E 3647 60 E 3691 90 E 3716 68 E 3723 49 E 3766 28 E 377S 03 E COMPUTATION DATE: 1-APR-93 PAGE 8 ARCO ALASKA, INC. 1H - 18 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK a PBTD DATE OF SURVEY: 02-MAR-1993 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: JEFF FORBICA ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 799' FNL ~ 785' FEL, SEC33 T12N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 8030 O0 8233 O0 8409 O0 8550 O0 8564 O0 8670 O0 6403.86 6561.67 6699.48 6811.16 6822.28 6906.43 6307 86 6465 67 6603 48 6715 16 6726 28 6810 43 2590 23 S 2663 98 S 2727 09 S 2778 40 S 2783 52 S 2822 22 S 3453 93 E 3558 17 E 3647 60 E 3716 68 E 3723 49 E 3775 03 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 8670.00 6906.43 6810.43 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 4713.36 S 53 13 E DIRECTIONAL SURVEY COMPANY FIELD ARCO ALASKA, INC. KUPARUK RIVER WELL 1 H - 18 COUNTRY USA RUN ONE DATE LOGGED 02 - MAR - 93 DEPTH UNIT FEET REFERENCE 93110 All intemre~&tlons are opinions based on inferences from electrical or other measurements and wa cannot, and do not guarantee the accuracy or correctness of any Interpretations. and we shall not, except In the case of gross or wllfull negligence on our part, be liable or responsible for any loss. costs, damages or expenses incurred or su~&lned by anyone resulting from any Interpretation made by any of our offlcem, agents or employees, These interpretations are also subject to our General Terms and Conditions as set out In our current price Schedule, WELL: 1H-18 (799' FNL, 785' FEL, SEC 33, T12N, RIOE, UN) HORIZONTAL PROJECTION NORTH 3000 REF 03110 SCALE = I / 1000 IN/FT 2000 1000 - 1000 -2000 -3000 -4000 SOUTH -5000 -2000 WEST -1000 0 1000 2000 3000 4000 5000 6000 FAST WELL' 1H-18 (799' FNL, 785' FEL, SEC 33, T12N, RIOE, VERTICAL PROJECTION -1000 -500 0 0 500 1000 1500 2000 2500 3000 ~,,~ ~=.:*,~ ~,~ .~.~ .:*~-:: ,:,-: ~i-.i-~-..~.~-:..~.h.~: ~.i~ ii, :: . ;!! ..... ::'i: '":~' ":!'~ ;'i .... i~"!':';~?'!" i::'!~i';;':' !::: :i'i! ........ .!i. ' ! ~ 2_ : i.ii~,~iii -iiii'~iill ~ili':xi6OO(!~!VE:RTiO~L'SEI;TION :::: :::: :::~ ..... ~ ;i. 60_O0..~.?!.i.~.i...!i...I !...i.l.i ...... i..i..i...! hi! .i...!.i.! i..!~,!..:; i..!: . . ..... . : .... i'i : i 'i i ~lg': : : i !'i'ii i !'i i' f'~ !'~''i ~ ~' i'; ~ i -i ! !.~ ........ , ~ , ; : i i :.: ..... i.i..i ~ : i.l.~l ..i i..: ~ .! i i ! i-i i...! i..i.! ~ : : i ........ i : [ i . : . ..i [ : ~ : i. : i t. .. i . : f [ ......... : : [ i : : : : ' · - i : :. . :i:: : .... ::i! !i:{i:! ! !'i ! i.!-T.! !.i,.! ! ..... !..i : ! .... i i.i : ..T.!.i ? · i . . ...... i :"i"1'i ...... i'i'i i~ i'i-i'i i-i"i i' 'i'i"i"i ?il i i'i"i ..... ii'"i'i i'ili" 'i'i'i'i ~ ! . ' .... iL;i ;i:~...i~;i,.iii~ .;~.~...~i ;.j..ii.:~.: ,iii i;~;:]~ .... ;,: I i i i i' ~ ' : : ' ~ [ ...... !'i'tl ;12~) .... ['; "~ : t ['i'i .... i" ; i : ' ; ................. ; !' ' . , i!'i i!'i"i i'i~ ..... ii'i'! 'f'ii"i !'ii"i !.-f.i-.!--.i~-.i-.-i--~.i..!i. ~ : ~.! .iii.~ ~ ..... ~ , i · :: :::: :..:.:-: :.:;..::.,:: :::: :::: :::: :::: .:.: .: . ..: I ............................ · :.: :::: :::: .::. :::: :::~ :::: ..:: ,::: . ............... :.:: .::: t87.00 PROJECTION ON VERTICAL PLANE 7.00 187.00 SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1 / 500 IN/FT ARCO Alaska, Inc. Date: August 27, 1993 Transmittal Cf: 8845 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following~ items. receipt and return one signed copy of this-transmittal. Please acknowledge 1 H- 15 -" CDR Enhancement 2-27-93 LWD/Depth Corrected 1 H-17 --~CDR Very Enhanced 2-26-93 LWD/Depth Corrected -~DR Very Enhanced LWD/Depth Corrected ~- CDR Enhancement LWD/Depth Corrected -~ CDR Enhancement LWD/Depth Corrected .-- CDR Enhancement LWD/Depth Corrected ----CDR Enhancement LWD/Depth Corrected ,.-, CDR Enhancement LWD/Depth Corrected --, CDR Enhancement LWD/Depth Corrected Receipt Acknowledged: DISTRIBUTION: D&M Drilling 5-02-93 1-21-93 1-12-93 3-26-93 4-05-93 4-12-93 4-14-93 Date: 9678-10337 7848-8422 7052-7320 9568-9802 8398-8993 7988-8632 4392-7512 5960-9772 5296-10002 Catherine Worley(Geology) ARCO Alaska, Inc. Date: May 28, 1993 Transmittal #: 8752 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the foilowin items. acknowledge receipt and return one. signed cbpy-e-Ptt1~-"l?ansmittal. Please H-09 H-09 _..,.,~_ 1H-11 ~1H-11 /' H-18 ~1I H-18 CDN-LWD/Depth Corrected CDR-LWD/Depth Corrected CDN-LWD/Depth Corrected CD R-LWD/Depth .Corrected CDN-LWD/Depth Corrected CDR-LWD/Depth Corrected Receipt Acknowledged- DISTRIBUTION: D&M Drilling ' 2/22-25/93 2/22-25/93 3/9-12/93 3/9-12/93 2/10-14/93 2/10-14/93 11044-11758 11044-11'758 5983-9774 5983-9774 4976-8670 4976-8670 NSK ~State of'Alaska(+Sepia) Kathy Worley(Geology) ARCO Alaska, Inc. Date' May 21, 1993 Transmittal #: 8~48 RETURN TO: ARCO Alaska, inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO- 1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one signed copy of this transmittal. 1H-18~5~(~'LIS Tape and Listing 02-10-93 0~~_. CDR/CDN in 2 Bit Runs, QRO Processed 1H-1 ~ LIS Tape and Listing 03-05-93 _--~~ CDR/CDN & Enhanced Resistivity 1H-~ LIS Tape and Listing 03-26-93 ot~ LIS Tape and Listing 3-20-93 · -~"~" u~?.., CDR/CDN & Enhanced Resistivity 1 H- 1 _~. CDR/CDN & QRO Enhanced Resistivity 1H-09t~\ LIS Tape and Listing 02-25-93 CDR/CDN in 1 Bit Run, QRO Processed Receipt Acknowledged' Please acknowledge receipt 93O67 93112 931'15 93128 93088 Date: DISTRIBUTION: Bob Ocanas State of Alaska STATE OF ALASKA ALA,~r~ OIL AND GAS CONSERVATION COMMIS,.,,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon B Suspend__ Operation Shutdown B Re-enter suspended well __ Alter casing ~ Repair well _ Plugging_ Time extension _ Stimulate__ Change apProved program ~ Pull tubing __ Variance 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. In(;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory _ RKB 96 feet Stratigraphic _ 7. Unit or Property name Service X Kuparuk River Unit 8. Well number 9. Permit number 93-20 10. APl number $0-029-22341 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 4. Location of well at surface 799' FNL, 785' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 1891' FSL, 2611' FEL, Sec. 34, T12N, R10E, UM At effective depth 1696' FSL, 2342' FEL, Sec. 34, T12N, R10E, UM At total depth 1659' FSL, 2290' FEL, Sec. 34, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 8670 6906 feet Plugs (measured) None feet Effective depth: measured 8 5 6 4 true vertical 6822 feet Junk (measured) None feet Casing Length Size Structural Conductor 1 21 ' 1 6" Surface 4935' 9 - 5 / 8" Intermediate Production 861 5' 7" Liner Perforation depth: measured true Vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Cemented 225 Sx PF 'C' 960 Sx PF 'C'& 460 Sx Class G 265 Sx Class G Measured depth True vertical depth 121' 121' 4975' 4144' 8652' 6892' RECEIVED M AY 2 0 199 Alaska 0il & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal X Detailed operation program _ Install sub-surface, spring controlled safety valve in water injection well. 14. Estimated date for commencing operation 15. Status of well classification as: June 1993 oil Gas 16. If proposal was verbally approved Name of approver Service BOP sketch Suspended Date approved Water Injector 17. I hereby certify tha_t the foregoing js true and correct to the best of my knowledge. Signed C- U.~ Title FOR COMMISSION USE ONLY Date Conditions of approval: Plug integrity BOP Test Mechanical Integrity Test_ O,t',l~in~ Si~ned By Approved by order of the Commission Notify Commission so representative may witness Location clearance Subsequent form require 10- ~g~' Commissioner JApproval No. Date ~¥/7.L ~/'~-~ Form 10-403 Rev 06/15/88 *,pp~"oved Copy Returned SUBMIT IN TRIPLICATE Attachment 1 Request for Variance Kuparuk Well 1H-18 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval to install a downhole, spring-controlled, injection valve in Injection Well 1H-18. This injection valve will act as a one-way check valve allowing downward injection of water while preventing upward flow of the injected fluid. The injection valve is capable of preventing uncontrolled upward flow by automatically closing if such an event should occur. This well's completion design, scheduled to be installed in June, will not include a hydraulic control line from the surface to the subsudace valve, however a landing nipple will be installed at approximately 1800' to accept the spring-controlled injection valve. Installation of the valve would be performed following the original completion and prior to initial water injection. Attached is a schematic of the proposed injection valve. RECEIVED MAY 2 0 t995 Alaska 0il & 6as Cons. Commissior~ Anchorage ~OP SUB ORIFICE ---'--- SPRING DE Otis MC Injection Valve SEAT INSERT FLAPPER VALVE AND SPRING ASSEMBLY MAY Alaska Oil & Gas Cons. Commissiot~ Anchorage ' STATE OF ALASKA ..... ALAS~,,A OIL AND GAS CONSERVATION COMMIS,.,,.JN APPLICATION FOR SUNDRY APPROVALS'F, 1. Type of Request: Abandon __ SuSpend m Operation Shutdown __ Re-enter suspended well m Alter casing __ Repair well _ Plugging_ Time extension _ Stimulate__ Change approved program ~( Pull tubing __ Variance Perforate __ Other __ 2. Name of Operator ~ 5. Type of Well: 6. Datum elevation (DF or KB) I Development ~, ARCO Alaska. Inc. I Exploratory _ RKB 96 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 799' FNL, 785' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 1891' FSL, 2611' FEL, Sec. 34, T12N, R10E, UM At effective depth 1696' FSL, 2342' FEL, Sec. 34, T12N, R10E, UM At total depth 1659' FSL, 2290' FEL, Sec. 34, T12N~ R10E, UM 12. Present well condition summary Total Depth: measured 8 6 7 0 feet true vertical 6906 feet 8. Well number 1H-18 9. Permit number 93-~0 10. APl number S0-029-22341 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 8 5 6 4 feet true vertical 6822 feet Junk (measured) None Casing Length Size Structural Conductor 1 21' 1 6" Surface 4 9 3 5' 9 - 5 / 8" Intermediate Production 8 61 5' 7" Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Cemented 225 Sx PF 'C' 960 Sx PF 'C'& 460 Sx Class G 265 Sx Class G Measured depth 121' 4975' True vertical depth 121' 4144' 8652' 6892' REEEIVED MAY 20 199;~ Alaska 0il & Gas Cons. C0mmissi0~ Anchorage 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch Change classification of well from oil producer to water injector prior to initial completion. 14. Estimated date for commencing operation J 15. Status of well classification as: June 1993 I Oil __ Gas Suspended 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sioned C- (lj. ~ Title FOR COMMISSION USE ONLY Water Injector Date .--~J//~/~ Conditions of approval: Notify Commission so representative may witness Plug integrity BOP~Test _ Location clearance __ Mechanical ~tegr. ity ,Test ~ Subsequent form require 10-~V'~ urlgina~ 8~ed By David W. Johnston Approved by order of the Commission Commissioner Form 10-403 Rev 06/15/88 ,,ppr'oved Copy 'Returned IApproval No. / Date ~?';z ~';'//~' '~ SUBMIT IN TRIPLICATE Attachment 1 ~,hange of Well Classification Kuparuk Well 1H-18 ARCO Alaska requests approval to change the classification of Well 1 H-18 from an oil producer to a water injector prior to its initial completion. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval, correlating with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. REEE[VED MAY Alaska 0il & 6as Cons. ~nchorage ARCO Alaska, Inc. Date: April 08, 1993 Transmittal #: 8706 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Records 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. 1H-1 8 S[~b-Surface Directional 03-02-93 931 10 Survey 1 H - 0 9 Sub-Surface Directional 0 3 - 0 8 - 9 3 931 1 4 Survey Receipt Acknowledged: DISTRIBUTION: D&M .. Date: State of Alaska (2 copies) RECEIVED APR 1 2 1993 Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date' March 12, 1993 Transmittal #' 8682 RETURN TO: ARCO Alaska, Inc. ATTN: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. Cement Bond Log Cement Evaluation Log Cement Bond Log Cement Evaluation Log Cement Bond Log Cement Evaluation Log Receipt Please acknowledge receipt and 03-02-93 03-02-93 01 -31 -93 01 -31 -93 01 -31 -93 01 -31 -93 Drilling Acknowledge' ---',-~--~--~-~ Date' State of Alaska(+sepia) 6800-8518 6800-8541 6480-8313 6480-8332 5090-7373 5090-7382 NSK RECEIVED MAR 1 5 1993 Alaska Oil & Gas Cons. Commission Anchorage MEMORANDUM STATE OF ALA ALASKA OIL AND GAS CONSER VA TION COMMISSION TO: David John~~ Chairmafi.,.Y DATE: Feb.10, 1993 FILE NO: DA-21093.DOC THRU: Blair Wondzell P.I. Supervisor FRO~II: Doug Amos ~ Petroleum Inspector PHONE NO.: 279-1433 SUBJECT: BOPE Test Parker 245 AAI KRU DS1H-16 PDT No. 93-20 Kuparuk Ry. Field Wednesday Feb. 10, 1993: I traveled this date to AAI's KRU DS1H-16 well to witness the BOPE Test on Parker Rig No. 245. As the attached AOGCC BOPE Test Report form indicates, there were no failures. I found all rig equipment in good condition and the drilling crew was very knowledgeable about the equipment and test procedure. IN SUMMARY, I witnessed the successful BOPE Test on 9 components, 24 valves, with a test time of 2.5 hours, at AAI's KRU DS1H-16 well on Parker Rig No. 245. Attachment cc; David Johnston Blair VVondzell STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover:~ DA-I'E: 2/10/93 Drlg Contractor: PARKER DRILLING Rig No. 245 P'r'D # 93-20 Rig Ph.# 659-7670 Operator: ARCO ALASKA INC. Rep. BUFORD BERRY Well Name: KRU 1 H-16 Rig Rep. DEARI.. GLADDEN Casing Size: 9 5/6" Set @ 4975' Location: Sec 33 T. 12N R. 10E Merd. UMIAT Test: Initia YES Weekl'/ Other MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign YES Drl. Rig OK BOP STACK: Ann. Preventer Pipe Rams Blind Rams Chk/Ln Valves HCR Valves Kili Line Valves Check Valve Qua. Test Pressure P/F 300/3000 P 2 300/3000 P I 3O0/3O00 P 2 300/3000 P I 300/3000 P 2 300/3000 P 0 0 N/A MUD SYSTEM: Light Alarm Tdp Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Gas Detectors OK OK FLOOR SAFETY VALVES: Upper Kelly Lower Kelly Ball Type Inside BOP Quem. Pressure P/F I 3OO/3OOO P 1 300/3000 P 1 300/3000 P 1 300~000 P 16 300/3O00 P 38 300/3000 P 2 300/3000 P I 300/3000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes ACCUMULATOR SYSTEM: System Pressure 2,900 I P Pressure After Closure 1,650I P 200 psi Attained After Closu~ 0 minutes 28 sec. System Pressure Attained 2 minutes 37 sec. Blind Switch Covers: Master: YES Remote: YES Nitgn. Btl's: 1 @2300, 3@2400, 2@2500 Psig. Number of Failur~. NONE Test Time 2 1/2 Hours Numberofve. lvestested 24 Repair or Replacement of Failed IEquipment will be made withi N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office ¢: Fax No. 276-7542 Inspector North Slope P~tger No. 659-3607 your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor ~ 279-1433 REMARKS: I did not witness the c~tlibretion of the gas detection system however I did verifythat the system had been c~tlibrated ~md the results entered on the IADC Icrc. D~stribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector ISTATE WITNESS REQUIRED? YES __ X~ NO_ 24 HOUR NOTICE GIVEN YES X NO. Waived By: N/A Witnessed By: Sicned; Dou¢ Amos DA-21 L'I93.XLS Rev. 1/93 ALASKA OIL AND GAS CONSERVATION CO~IMISSION February 4, 1993 "~-. WALTER J, HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride, Area Drlg Engr ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re .' Kuparuk River Unit 1H-18 ARCO Alaska, Inc. Permit No: 93-20 Sur. Loc. 799'FNL, 785'FEL, Sec. 33, T12N, R10E, UM Btmhole Loc. 1587'FSL, 2204'FEL, Sec. 34, T12N, RIOE, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607.~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc.' Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .~ prif~ted on recycled pnpef h y C,i,1. ~"' STATE OF AI..AS'KA ALAS. ,)IL AND GAS CONSERVATION COMMISS~ PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work Drill X Redrill ri 1 b Type of Well Exploratory r~ Stratigraphic Test D Development Oil X Re-Entry O Deepen O Service ri Development Gas O Sir~leZone X Multil~eZone r'l 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. F'~td and Pool ARCO Alaska~ Inc. RKB 96'~ Pad 54' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360~ Anchorage~ AK 99510-0360 ADL 25639r ALK 464 4. Location of well at surface 7. Unit or property Name 11. Type Bond (~ee 20 AAC 25.025) 799' FNL,785' FEL, Sec. 33, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1,894' FSL, 2,613' FEL, Sec. 34, T12N, R10E, UM 1H-18 #UG630610 At total depth 9. Approximate spud date Amount 1,587' FSL, 2,204' FEL, Sec. 34, T12N, R10E, UM 2/2/93 $200,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1H-07 8,790' MD 1,587' ~ TD feet 31.2' ~ 60' MD feet 2560 6r971' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25,035(e)(2)) Kickoff depth 1,000' feet Maximum hole angle 43 18. Casing program Settin~l Del~h size Specifications Top Bottom Quantit~ of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD {include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +P00 CF 12.25" 9.625" 47.0# L-80 BTC 3,000' 41' 41' 3,041 2,746 600 Sx Permafrost E & HF-ERW 12.25" 9.625" 36.0# J-55 BTC 1,105' 3,041 2,746 4,961 4,146' 460SxClassG HF-ERW 8.5" 7" 26.0# J-55 BTCMOE 5,000' 41' 41' 5,041' 4,204' HF-ERW 8.5" 7" 26.0# J-55 BTC 3,749' 5,041' 4,204' 8,790' 6,971' 370SxClassG 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 ~ i True Vertical depth Structural Conductor Surface Intermediate Prod,,ction Liner Aiask~t Oil & Gas f_;ons. Com~f~'s Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee X Property plat ri BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot ri Refraction analysis D Seabed report ri 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Sit:ined ~/~~ Title Area Drillinl~ Encjineer Date Commission Use Only Permit Number APl number Approval dat%/~..~__7/, ~ F~ other requirements Conditions of approval Samples required ri Yes ~ No Mud Io9 required ri Yes ,~ No Hydrogen sulfide measures D Yes .,~ No Directional survey recluired .~ Yes E1 No Required working pressure forBOPE D 2u ~ 3M E] 5M D 1OM ri 15M Other: _Original Signed By David W, Johnston GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 1H-18 o , . 10. 11 12 13 14 15 16 17 18, Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,916')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (8,790') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. DRILLING FLUID PROGRAM Well 1H-16 Spud to 9-5/8" surface casin~ Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-9.6 15-25 15-35 45-75' 5-15 15-4O 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.6 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,460 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1 H-18 is 1H-07. As designed, the minimum distance between the two wells would be 31.2' @ 60' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or 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 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 55-75 sec/qt to drill gravel beds. Adjust FV to 45-55 sec/qt below gravel beds. Casing Design / Cement Calculations 27-Jan-93 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg A MD: Production Csg A TVD: Production Csg B MD: Production Csg B TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice: Production Csg A Choice: Production Csg B Choice: Production Casing Fmc. Pressure 1 H-01 4,961 ft 4,146 ft 5,041 ft 4,204 ft 8,970 ft 6,971 ft 4,110 ft 7,322 ft 6,362 ft 10.6 ppg 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 4,146 ft {(13.5'0.052)-0.11}*TVDshoe =[ 2,454 psiJ Estimated BH pressure at top of target zone Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = =1 10.6 ppg 6,362 ft 3,507 psi 3407 Surface lead: Top West Sak, TMD = 4,110 ft Design lead bottom 500 ft above the Top of West Sak = 3,610 ft Annular area = 0.3132 cf/If Lead length * Annulus area -- 1,131 cf Excess factor = 15% Cement volume required = 1,300 cf Yield for Permafrost Cmt -- 2.17 Cement volume required =[ 600 sxJ Surface tail: TMD shoe = 4,961 ft (surface TD - 500' above West Sak) * (Annulus area) = 423 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 458 cf Excess factor = 15% Cement volume required = 527 cf Yield for Class G cmt = 1.15 Cement volume required =1 460 sxI Casing Design / Cement Calculations 27-Jan-93 Production tail: TMD Top of Target, TMD Want TOC 500' above top of target Annulus area (9" Hole) (TD-TOC)*Annulus area Length of cmt wanted in csg Internal csg volume Cmt required in casing Total cmt Excess factor Cement volume required Yield for Class G cmt Cement volume required 8,970 ft 7,322 ft 6,822 ft 0.1745 375cf 80 ft 0.2148 17cf 392 cf 15% 451 cf 1.23 370 sxI TENSION - Minimum Desion Factors are: T(ob}=l.5 and T(is}=l.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air --Buoyancy = Tension (Pipe Body) -- Design Factor =[ 564000 lb 4,961 ft 36.00 Ib/ft 178596.0 lb 28010.9 lb 150585.1 lb a.?! Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 639000 lb 4,961 ft 36.0O Ib/ft 178596.0 lb 28010.9 lb 150585.1 lb 4.21 Production A (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 415000 1 b 8,97O ft 26.00 Ib/ft 23322O.0 lb 37284.9 lb 195935.1 lb 2.11 Production A (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy -- Tension (Joint Strength) = Design Factor =1 490000 lb 8,970 ft 26.00 Ib/ft 233220.0 lb 37284.9 lb 195935.1 lb Casing Design / Cement Calculations Production B (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For.' Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ Production B (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ BURST - Minimum Desi(]n Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =1 Production Csg A: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =1 Production Csg B: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =[ COLLAPSE- Minimum Desiqn Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Production Csg A 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg B l. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ 27-Jan-93 415000 lb 3,929 ft 26.00 Ib/ft 102154.0 lb 16331.4 lb 85822.6 lb 4900OO lb 3,929 ft 26.OO Ib/ft 102154.0 lb 16331.4 lb 85822.6 lb 5.7J 3520 psi 2454.4 psi 1.4J 4980 psi 5817 psi 1946 psi 3872 psi 1.31 4980 psi 7342 psi 3226 psi 4116 psi 1.2J 2020 psi 0.551 Ib/ft 1349 psi 1 .Si 4320 psi 0.551 Ib/ft 2317 psi 1.91 432O psi 0.551 Ib/ft 3842 psi 1.11 Casing Design / Cement Calculations 27-Jan-93 Surface Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength Collapse Burst 1 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 5750 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength Collapse Burst I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 7240 psi 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb 4320 psi 4980 psi ARCO ALASKA, II'lC. ._ . Created by : jones For: D STOLI'Z C.o[e p*otted 26-Jan-93 P!ot Reference is 18 Version #5 Coordinates are ~n feet reference slot #18. true Vertical Depths are reference wellhead.: Scale 1 Structure : Pad 1H Field : Kuparuk River Unit SURFACE LOCATION: 799' FNL, 785' FEL SEC. 3.3, T12N, R10E o 400 12oO 7200 Well : 18 Location : North Slope, Alaska S 53.15 DEG E 4314' (TO TARGET) 3000 600900 2700 5000 3500 3600 I I I I i I I I I I I I t I i , o.oo E a s t - - > 300 ~200 ~500 ~800 2100 2400 I I I I I I I I I I I I 3900 4200 I I , 300 RK8 £LLrVATION: 96' KOP TVD=-1000 TMD,,IO00 DEP,-O 6.00 12.00 @/ PERMAFROST TV0=1457 TMD=1461 DEP=55 18.00 24.00 eU,L0 $ 0£C / ,oo' 30.00 TARG----~ LOCATION: 36.00 1894' FSL, 2613' FEL 42.00EOC TVD=2307 TM0=2439 DEP=517 SEC. 34, TI2N, R10E TARGET TMD- 7994 TVD=636'2 T/ UGNU $N05 TVD=2941 TMD--5309 DEP---1112 DEP-4514 SOUTH 2587 EAST ,3452 T/ W SAK SNDS 1V0-3525 TMO,=4110 OEP=1660 B/ W SAK SNDS TVD=3946 TMD=4687 OEP=2055 9 5/8" CSG PT 'rv0=4146 TMD=4961 0EP=2245 A/B MODIFIED CSG TVa-a,204 TMD-504.1 DEP==2297 K-10 TV0=4556 TlvlO=5523 DEP--2627 MAXIMUM ANGLE 43.18 DEG K-5 ~/D=5256 TMD=6483 DEP=3284 TARGET ANGLE 40 DEG BEGIN ANGLE DROP TVD=6204 TMD=7783 DEP=4173 TARGET - END ANGLE DROP TVD=636Z TMD=?994 i i i i i '1 i i i i i I i t [ i I i i i i i 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 Scale1 200.00 DROP ~.5 DCG / ~0o' T/ ZONE C TV0=6413 TMD=8061 DEP=4357 T/ ZONE A W0=6712 TMD=8451 OEP=4607 -- 8/ KUP SND$ TVD-6818 TMD=8590 DEP-4696 1'I) / LOGGING PT TV'0=BgTI T~D=8?~O DEP=48Z5 i i i i i 4400 40~0 5200 Vertical Section on 125.85 azimuth with reference 0.00 N. 0.00 E from slot jt18 O .2400 .2700 3OOO TD LOCATION: 1587' FSL, 2204' I'EL SEC. 34, T12N, RIOE Scale 1 '50.00 asr lO0 5O I I I I 0 50 I I I 270O 3100 1700 10001 1100 1300 1 O0 150 200 250 500 350 4-00 4-50 3300 I I I 1500 3500 3700 3900 4100 4300 ARCO ALASKA, Inc. 150 ...... 100 Structure : Pad 1H Well : 18 Field.: Kuparuk River Unit Location : North Slope, Alaska 50 5O 1 300 0 7OO 4700 700 5100 5300 5500 1900 100 100 150 _ 20O _ 250 7 , 6 5 4 I3 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. ?_ 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 UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 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. TEST ALL 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 MNE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING AL VALVES, ENES, AND CHOKES WITH A 250 PSI LOW AND 3(X)0 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY 8. CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BO3-FOM PIPE RAMS. TEST BO3-FOM 9. RAMS TO 250 PSI AND 3000 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10 CLOSE BUND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 12. UNES ARE FULL OF ARCTIC DIESELAND ALL VALVES ARE SET IN THE 13. DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILMNG SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND 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 UNES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR Alaska Oil 8, ~as Cons. Anchorage SRE 8/22/89 KUPARUK RIVER UNI 20" DIVERTER SCHEMATIC I HCR I 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 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., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20"- 2000 PSI ANNULAR PREVENTER EDF 3/10/92 1H-18CI41'.×LS State: Well: Field: State Permit 1H-18 Kuparuk River 93--20 Engineer. Work Sheet: Date: 2/2./'33 Ca¢,'~g Type Casing Size Casing Length H cie Diameter Cement- Sacks Cement- Yield Cement- Cubic fl Cement- Cubic It Cement- Sacks Cement- Yield Cement-Cubic It Cement- Cubic It Cement- Sacks Cement- Yield -Inches - Feet -Inches 111 111 111 111 112 112 112 112 113 113 Cement- Cubic it 113 Cement- Cubic It 113 Cement- Cubic It / Vol Cement - Fill Factor Conductor 16.000 80.000 24.000 0.000 0.000 0.000 200.0OO 0.000 0.000 0.000 0.000 200.000 1.43Z 9.6;25 4,105.000 12.250 G00.000 2.170 1,302.000 1,302.000 4G0.000 1.150 529.000 529.000 0.000 0.000 0.000 0.000 1,831.000 1.424" Linel 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 I~DIV/O! Casing Type Casing Size -Inches Casing Depth - Feet Hole Diameter-Inches: Cement- Sacks111 Cement- Yield111 Cement- Cubic ft 111 Cement-Cubic fl II1 Cement- Sacks112 Cement- Yield112 Cement- Cubic It 112 Cement- Cubic tt 112 Cement- Sacks113 Cement- Yield113 Cement- Cubic Irt 113 Cement- Cubic Irt 113 Cement- Cubic Irt /Vol Cement-Intelval ft Top of Cement- Feet' Intermediate 111 0.000 0.000 0.000 0.OO 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 IIDIV/0! ItDIV/0! Intermediate 112 0.000 0.000 0.00O 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.OO 11DIV/O! I~DIV/O! Roduclion 7.000 8,790.000 8.500 370.00 1.23 455.10 455.10 0.0O 0.00 0.00 0.00 0.00 0.00 0.00 0.00 455.10 3,588.93 5,201.1 Measured Dep't~ State: Alaska Borough: Well: 1H-18 Field: Kuparuk River st. Perm # 93-20 1H-186SG.XLS IOate 2~P_J93 Engr: M. Minder Casing Interval Interval Size Bottom Top Length lA 9,625 2746 41 :3000 2A 9.625 4146 2746 1105 3A 7 6971 41 8749 4A 0 0 0 0 5A 0 0 0 0 GA 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Description Description Description Tension Lbs Grade Thread Lbs 47 L-80 BTC 0 36 J-55 BTC 39780 26 J-55 TC MOD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Collapse Wieght Gradient Gradient ppg psi/ft psi/ft 1 b 9.6 0,499 0,399 2B 9,6 0,499 0399 3B 10.6 0,551 0,451 4B 0.0 0.000 -0.100 5B 0,0 0,000 -0.100 6B 0.0 0.000 -0.100 7B 0.0 0,000 -0.100 8B 0.0 0.000 -0.100 9B 0.0 0.000 -0.100 1 OB 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 2460 6870 2.8 2460 3520 1,4 2460 4980 2.0 0 0 #DIVI0! 0 0 #DIVI0! 0 0 #DIVI0! 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIV/O! 0 0 #DIVIO! Tension Strength K/Lbs K/Lbs 1C 180.78 1086 2C 39.78 3C 227.474 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 TDF 6.01 564 14.18 415 1 o #DIV/0! 0 #DIVI0! 0 #DIVI0! 0 #DIVi0! 0 #DIV/0! 0 #DIV/O! 0 #DIVIO! Collapse Collapse Pr-Bot-Psi Resist. CDF 1096 4750 4.333 1655 2020 1.220 3145 4320 1.373 0 o #DIV/0! 0 0 #DIVIO! 0 0 #OlViO! 0 0 #DIV/O! 0 0 #DIV,,ff)! 0 0 #DIVI0! 0 0 #DIV/O! ITEM (1) Fee (2) Loc .... CHECK LIST FOR NEW WELL PERMITS APPROVE DATE '[ ~] tl~ru [10 & 13] [14 thru 22] [23 thru 28] (6) Other [~29~hru 3~1] .~ (8) Addl geo 1 ogy' eng i nee r i nq: LG rev 12/92 jo/6.011 Company 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from. property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is well bore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ Lease S Well YES NO 9. Does operator have a bond in ¢orce ................................... 10. Is a conservation order needed ....................................... ~_ 11. Is administrative approval needed .................................... 12. Is lease nt~nber appropriate .......................................... ~L ~ 13. Does well have a unique name & number ................................ 14. Is conductor string provided ......................................... ~ ......... 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. 16. Is enough cement used to circulate on conductor & surface ............ 17. Will cement tie in surface g intermediate or production strings ...... 18. Will cement cover all known productive horizons ..................... !.9. Will all casing give adequate safety in collapse, tension, and burst. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wel l bore separation proposed ............................. /~ Is a diverter system required ........................................ ~ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... ~. Does BOPE have sufficient pressure rating -- test to ~OOcgpsig ..... /~_~,, Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~nber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ; Zga /- ? ///go e,,O Additional MERIDIAN' remarks' UM ~< SM WELL TYPE' Exp/e~___~. X' Inj Red r i 11 Rev C) n-Z m Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER ****************************** ******************************* FIELD ~AME : KUPARUM RIVER BOROUGH : NORTH SbGPE STATE : ALASKA REFERENCE NO : 93067 * ALASKA COMPUTING CEMTgR * , ~ ****************************** *------- SCHLUmBErGER -------* ******************************* COMPA~Y NAME : ARCO ALASKA, INC,~ ~EL5 NA~E : !N-18 FIELD NAME : KUPAROK RIVER 80~Ot)GM : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029'22341 REmERENCE NO : 93067 ;chlumberger !aska ComDut,! n ..:~ enter 30-MAR-!993 14:15 SERVICE NAME : EDIT DAT~ : 93/03/30 ORIGIN : FLIC CONTINUATION # PREVIOUS REEL COMMENT : ARCO ALASKA INC., KUPA~UK RIVf]R UNIT, IH-18, 50'029-~234~-00 **** TAPE HEADER **** SERVICE NAME : EDIT ORIGIN : FbIC ~AP~ NAME : 93067 CONtINUaTION # : ! PREVIOUS TAPE : COMUENT : ARCO ALASKA !NC., KUPARUK RIVER UNIT, I,H-l~, 50-029-2234~-00 TAPE HEADER KUPARUK RIVER UNIT ~WD/~AD LOGS WELL NA~E: !H-18 API NUMBER~ 500292~34100 OPERATOR: ANCO AGASKA, LOGGING'cOMPA~Y: SCHLUMBERGER W~:~ SErVICeS TAP~ CREATION D~TE: 30.~AR.93 JOB D~TA jOB NUMBER~ LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION~ TOWNSHIP~ FNL: ELEVATIOM(FT F~O. ~SL O) KELLY BI!SHING: DERRICK GROUND I,EVEL W~LL CASING RECORD BIT RUN I BIT RUN 93 7 93067 ST. gMOUR S~~ A !ST STRING 2ND STRING :BIT RUN 3 ~mm~~ 33 799 785 96.00 96.00 54.00 OPE~4 H()LE CASING D~!I,!,ERS BlT SIZE (IN) SIZE (IN) DEPTH (FT) ''''8.500 ........... gTCO;_ ....... 497~T''''0 PAGE: ~IS Ta~e varification l:.istina ;chtumberger AlaSKa ComPutinq CeDter 30-~,!AR- ]. 993 14:~.5 3RD STRING PRODUCTION STRING # BIT T() ~l.!lJT 1~':7 ' DRILLBD INTE YhL~976 TO 826 ********** RUM 2 BIT TO RES 15,43', BiT Ti) GR 25.46', BIT TO D~M 4].,98' ~T TO MEUT 48096', DRIttED~ INTERvAI~ ~63' TO 86~0', g~;TRI× DENSITY 216~ (Ga/~C), FLUID DENSITY 1,0 (GM/CC} ROTAT!OMAL B[ILK DENSITY P~Oc'E$$ING USED, BARITE ADDED TO MUD SYS...E~, DATA F~OM DOWNMOLE MEMORY, DOWNHOLE SOFTWAR.~M VERSION $ PAGE~ **** FILE HEADER **** FILE NA~E ~ EDIT ,O0! SERVICE : FLIC VERSION : 00!A07 DAT~ MAX REC S!ZE : 10~4 FIL~ TYPE : LO L~ST FILE FILE HEADER FILF NUMBER: 1 EDITED MERGED MWD DePth sb~,~ted and cllpDed ct~rves~ all bit runs mer~ed,~ DEPTH INCREMENT 0.5000 FIbK SUMMARY KRU TOOL CODE START DEPTH STOP DEPTH CD ~g70,0 ~616,0 CDR 4970.0 8643,0 $ CURVE SHIFT DATA. (MEASURED DEPTH) ---- .... --FQUIVALENT UNSHIFTED DEPTH ....... --- gASEL:!NE DEPTH a4 .o 8355.0 8343.0 83~8,0 8305.5 ~300.0 8287.5 8246 0 8~33.5 8213:0 8~03.0 ils ~aDe Verification Listing ~chlumberger AlasK. a ComPutiln~ Center 30-~.A~-1993 14:15 PAGER 8178,0 8055'O 8016,5 7990.0 7948 0 79~6 5 790i.,0 7872 0 7815.0 7752:5 7716 5 7699 5 766! 0 0 75165 7467 5 7431. 5 7384 5 7329 0 7288 5 727! 5 7~55 5 723! 5 7100 5 6974 0 6957 5 694~, 5 6~g9,5 6864.0 6818 0 6803!0 ~,oo o KRU TOr]L COD~ REMARKS: 8!68,0 8!48'0 8046 0 7980,5 7938,5 7908,0 789i.5 7862,5 780:5,~0 7743,5 7706'0 7690,5 7652.5 7607.0 7575,0 7507.5 7458.5 74~,0 7375,5 7320.5 7~79,5 7~62,5 7247,0 7201,0 7091,5 6965,5 694~ 0 6891'5 6856,5 6809,0 6793.5 90,5 BIT RUN NO, MERGE TOP ! 4q76,0 2 8263,0 NERGE BASE 63.0 70.0 THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT MWD GR TO NIR~LIN~ GR OF ¢)2-NAR-93, ALL OTHER CURVES WERE CARRIED WITH THE GR SHIFT. THE SAMPLING TICKS CONTAINED IN THIS EDITED FILE ARE AT ,5 SA~P[.IMG RATE, THE SAMPLING TICKS IN FILE ~2 WILL HE CtOSES IO ACTUAL ACQUISITION RATE. $ LIS FORMAT DATA Schlumberger las~a comPut nq Center 30-~AR-! 993 14:!5 ** SET TYPE - 64EB ** TYPE REPR CODE YAbUE 1 66 0 2 66 0 4 66 ~ 5 66 6 73 7 65 8 68 0,5 9 65 FT 1! 66 12 i2 68 !3 66 0 14 65 FT 15 66 6~ 16 66 ! 0 66 0 ** SET TYPE- CMAN ** NAME SERV UNIT SERVICE API API ADI API FILE NUMB NUMB SIZE REPR PRDCESS ID ORDER # bOG TYPE CLASS MOD NUmB SA~P ELE~ CODE (HEX) DEPT FT 618989 O0 000 O0 0 I ! I 4 68 RMO~ ~WD G/C3 6189~9 O0 000 O0 0 1 1 ! 4 68 O~NO MWD G/C3 618989 O0 000 O0 0 i I 1 4 68 PEF ~WD 8N/E 61~989 O0 000 O0 0 I 1 I 4 68 CALN ~WD IN 61~989 O0 000 O0 0 1 ! 1 4 68 NPH! ~WD PU-S 6!~989 O0 000 O0 0 I ! I 4 68 RA ~WD OHMM 618989 O0 000 O0 0 ! ! I 4 68 RP MWD OHM~ 618989 O0 000 O0 0 i 1 I 4 68 ROP MWD F/HR 618989 O0 000 O0 0 1 1 1 4 68 G~ MWD GAPI 61~989 O0 000 O0 0 I ! ! 4 68 NSI ~WD 61~9~9 OO 000 O0 0 I I 1 ~ 68 RS1 MWD 618989 O0 000 O0 0 1 I I 4 68 HEN ~!WO CPS 618989 O0 000 O0 0 1 1 1 4 68 MEF ~WO CPS 61898~ O0 000 O0 0 1 1 I 4 68 T~B ~WD 618989 O0 OOO O0 0 1 I 1 4 68 TABD ~WD 618989 O0 000 O0 0 ! 1 1 4 68 GTCg MWD $ 618989 O0 000 O0 0 I ! ] 4 68 NTCK ~WD S 618989 O0 000 O0 0 i 1 1 4 68 DTCK gWD S 618989 O0 000 O0 0 1 1 i 4 68 RTCK ~WD $ 6!~989 O0 000 O0 0 I ! 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 mmmmmm#mmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmm#mmmmmm#mmmmmmmmmmm~ ;$h!umberger .. la,$ka CompUt no Center D~PT 86:57:500 C~:L,.N' ' .~WD -999,250 N'PH~,MwD ROP'MWD 1.7.699 GR,MWD HEN,~WD -999.250 GTCK.MWD -999,250 NTCK.AWD DEPT 850o,O00 ~HO} MWD op' HEN,MWD 323.068 GTCK,MWD 1,000 NTCK.~WD DEPT. 8000.000 CaLN . ~ ,~ND 8,93! ..OP'MWD 157 063 GR.MWD HEN.~WD 273:254 ~EF'MWD GTCK.~WD ~.000 NTCK.SWD DEPTo 7500°000 CaI, N,MWD 8.518 NPHI.MWD ROP,~WD 263.686 GR.NWD HEN,MWD 296,750 GTCK.MWD 1.000 NTCK.~WD DEPT, 7000,000 RHOB.D~WD CAbN,MWD 8,728 NPHI.NWD ~OP.MWD 349.609 GR.MWD UEN.MWD 265.250 HEF.~WD GTC~.~WD -999.250 NTCK,MWD DEPT. 6500.000 CAbN.~WD 8.72] NPHI.~WD ~OD.MWD 347.768 GR.MWD ~EN,~WD 265,250 HEF.~WD GTC~.~WD -999,250 NTCK.~WD DEPT 6000,000 RHOB ~OP,MWD 341.042 GR,~WD HEN.~'WD 280.000 HEF.MWD GTCE.~WD -999.250 NTCK.MWD DEPT. 5500.000 RHOB.~WD CALN.MWD ~.525 NPHI.~WD ~OP.~WD 435.3]2 ~R.MWD WEN.MWD 270.250 HEF.MWD GTC~.MWD -999,250 NTCK.MWD DFPT. 5000.000 RHOB.NWD CA[..N.MWD 8.500 NPNI.MWD POP.MWD 425.394 GR.MWD MfN.~WD 259.000 HEF.MWO GTC~'.~WD -999.250 NTCK.MWD 30-~AR-1993 14:15 -999.250 ~999.250 RA,MWD 999.250 NSI*~WD -9991250 TAB.~WD -999,250 DTC:K.MWD ,45] D~HO,M'WD 3 ,600 RA.,:MWD SO 03.4 NSI':MWD 8i178 TAB,MW~ -999 ~50 DTCK,MWD ,540 DRHO,MWD 3.934 !05,982 NSI'.MWD 5.763 TAB,MWD -999,250 DTCK,MWD 32. I DRHO,:MWD TAB,MWD -999.~50 DTCK'~WD 2°4@5 DRH0o~WD 39.~37 ~A,MWD !22.0!0 NSI,MWD 5.628 TAB,~WD -999.250 DTCK.MWD .00 R ~73,535 NSI,aWD 5.563 TAB,MWD !.000 DTCK.MWD ~ 295 DRHO.MWD 3:600 'RA,MWD 72.~94 ~$I.~WD 6.245 TAB.MWD -999.250 DTCK.MWD ~ 306 4:300 RA.Mwb 5.673 TAB.gWD - 99. 5o oTC . O 41.600 67,679 5.]23 TAB.MW~ -999.~50 DTCK.~WD ~999,250 999'250 !,000 =999,250 -999.:~50 ,.o' ol o 3*283 0.000 '99~ '696 .250 0.000 I',441 o:ooo ! !22 1.000 0.000 O0 0,242 '999,~50 O2 0.000 0 358 -999:250 -0 010 21179 0 000 0 328 -999.250 -0.020 2.640 1.000 0.172 -999.250 -0.001 3.521 0o000 0.264 -999.250 -0.033 2.992 000 -999,~50 PEF'MWD RP,MWD R$I,)WD TABD.MWD RTCK:.MWD PEF,MWD aWU R$I'MWD TA BD* P WD RTCK. ~ WD .RP,MWD TABD.PWD RTCK,MWD PEF.~WD RP,~WD RSI'~WD TAB. D:,NWD RTCK,~WD PEF.~ND RP.MWD TABD.~WD RTCK.~WD PEF,~WD RP,N~D RSI.MWD TABD.~WD RTCK.MWD PEF.MWD RP.~WD RSI,MW'D TABD.~WD RTCK.MWD PEF.MWD RP.MWD TABD.MWD PTCK,~D PEF.MWD RP.~WD R$I.~WD TABD.~wD RTCK.WWD '999,250 '999:;250 . .ooo ~999:,,2S0 999'250 16 0,000 1.989 '999,250 4 ~34 24 ~ 000' 2 766 -999 250 4 700 2 697 0 000 0 719 -999 250 3,999 B,093 0,000 0,664 1.000 ] 420 0.000 0,672 -999,250 2 6~9 0,000 0.6!I -999.250 2.903 3.254 0,000 0,576 1.000 2,702 2.816 0.000 0.440 -999.250 TaPe verif!cat!on [~istlna SchlumbergerAlaska Co.mputj.,D..~ Center 30-~R-1993 14:15 PAGE: DEPT, 4970,000 ROD..MWD ! 94,2~. ~ HEN,~WD 249,500 GTCK.~WD -999.250 ~.8~ DRHO.~NWD :45. ~(}0 RA. MWD 4.855 TAB,MWD -999~ 250 DTCK,MWD 0'243 PEF.MWD ~,95! ' Rp. MWD 0'0o0 R$I.MWD 0:'588 T:ABD.MWD -999.250 RTCK.~WD !00,000 2,$17 O. 000 0' ~ '7 ? -999,250 ** END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .001 ERVICE : FLIC ERSION : 00t.A07 DATF : 93/03/30 ~aX RFC SIZE : 10~4 FILE TYPE : bO LAST FILE **** FILE HEADER **** FILE NAME : EDIT ,002 SERVICE : FLIC VFRSION : O0]A07 DAT~ : 93/03/30 MAX RFC SIZE ~ 1024 FILE TYPE : bO LaST FILE FILM NUMBER 2 RAw MWD Curves and log header data for each bit run In separate files, HTr RUN NUMBER: DMPTH INCREMENT: 0.! # FI5~ SUMMARY VENDOR TOOb CODE START DEPTH DR .~36.0 CON 4~36,0 $ bOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHDLE SOFTWARE VERSIOM~ DATA TYPE (MEMORY OR REAL-TIME): ?D DRILLER (FT): STOP OEPTH 8670,0 8670,0 lO-FEB-93 FAST 2,3D V4,0C MEMORY 8670.0 Verification Llstlno ~ChlUmherqer Alaska Computfna CeDter 30-~:AR-1 g93 !4:!5 PAGE: TOP LO~ INTERVAL BOTTOM LOG INTERVAL BIT ROTATING SPEED HOLE INCLINATION MINIMUM ANGLES M~XIMU~ ANGLE: CON ....... ''''' .... NEUTRON/PO''''''''" RO~ITY ~OR R~I~TIVITY BOREHOGE AND CASI~(~ DATA OPEN HOLE BIT SIZE DRILLERS CASING DEPTH (FT): BOREHOLE C[]NDTTIONS ~UD TYPE: ~IJD D....,NSITY CLg~G): ~UD VISCOSITY (~): MHD PH: ~UD CHb~RIDES (PP~)c FLUID bOSS (~3): RESISTIVITY [OHM~DAT,. TE~PERATUPE DEGF) ~'UD AT ~ASUR.~,.. TE~PERATURE MUD AT MAX CIRCULAT,I.'G TEMPERATURE: ~UD FII, TRATE AT ~UD CAKE AT NEUTRON TOOL ~ATRtX: ~ATRIX DFNSlTY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 4976., 0 86't0,0 8,500 4975.0 10.50 2.580 1,810 69,0 61.0 SANDSTONE 2.65 8.500 LIS FOR.AT DATA RE~ARKS: THIS FILE CONTAINS THE SAMPLING TICKS FRO~ THE ~ERGED MWD FILE. THIS DATA IS AS CLOSE TO THE ACTUAL RATE OF AOUISIT!ON ~S POSSIBLE. LIS FORMAT DATA 5IS Tape VerlffcatloD Listin~ SChlumberger Alaska Comput,flng Center 30-MAR-ig93 14:15 FORMAT SPEC!FIC~TI(!~ RECORD SET TYPE -64EB *~ TYPE REPR CODE ! 66 0 2 66 0 3 73 20 4 66 255 5 66 7 65 ~ 6~ 0,1 9 65 FT 1! 66 5I 12 68 !3 66 0 14 65 FT 15 66 68 16 66 1 0 66 ** SET TYPE - CMAN ** NA~M SERV UNIT SERVICE API API AP1 AP1 FtbE NUM0 NUmB SIZE REPR PROC£$$ ID ORDER # bOG TYPE CLASS ~OD NUMB SAMP ELEM CODE (HEX) · ~ ~?~.~ ooooo oo o ~ ~ ~ 4 ~ oooooooooo ~c~ oo~~ ~.~ ooooo oo o ~ ~ ~ 4 ~ oooooooooo ~c~ oos~ ~~ ooooo oo o ~ 1 ~ 4 ~ oooooooooo ~,~c~ ooss ~~9 ooooo oo o ~ ~ 1 4 ~ oooooooooo ~c~ '22~ s ~!~ ooooo oo 2 ~ ! ' ~ ~" 22000°0022 ** DATA ** DEPT. 4826,500 GTCK,O05 -99q 250 NTCK 005 1 000 DTCK,005 RTCK,005 -999,250 ' ' ' DEPT, 4999,900 GTCK,005 '999,250 NTCK,005 -999 250 DTCg,005 PTCK,005 -999,250 ' DEPT. 5000.~0! GTCK,O05 -999,250 MTCK,005 -999 250 DTCK,O05 RTCK,005 -999,250 ' ' ' D~PT 54gg,900 GTCK,005 -999,250 NTCK 005 -999 250 DTCK 005 RTCK~005 -999,250 " ' DEPT. 5500,101 GTCK,005 -999,250 NTCK 005 -999 250 DTCK,005 RTCW,005 '999.250 '"- ' -999,250 -999,250 -999,250 1.000 -999,250 IS Tape Verification Listing ;ehlumberger Alaska Computin~ Center espT. s999.9oo GTC~.OOS ~cKoO05 -999. 256 DEPT 6000,101 GTCK,005 ~TC~:°OS -999'250 DEPT 6499 900 GTCK.O05 aTc.[Oo5 - 999'~S0. DEPT, 6500,101 GTCK,005 RTC~.O05 -999.250 DEPT. 6999.900 GTCK.O05 RTCE.O05 -999.250 DEPT 7000 10! GTC~oO05 RTCK[OO5. '999[25D' ( DEPT. 7499,900 GTCK.O05 RTCK'O05 -999.250 DEPT 15o0.10! GTCK 005 RTCK[005 999,250 ' D~PT. 7999.900 GTCK.OO5 RTC~iO05 -9~9.250 c .oos RTCK]O05 -999. 0 RTC,..O05 1,000 D~PT, 850(t,!00 GTCK 005 RTCK.OO5 -990.250 ' DEPT. ~642.500 G?CK.O05 RTCK.O05 !.000 ** END OF DATA ** **** FILM FILE NA~E SERVICE VERSION ~AX REC SIZE FILE TYPE LAST FILE TRAIl. ER **** ! ED!T : FLIC : O0~A07 : o3/0]/]0 : 1024 : LO : 30-~AR-1993 14:!$ '999.~50 NTCK.O05 -999.250 NTCK.O05 -999.250 NTCK.O05 ~999.~50 MTCK,O05 -999.~50 MTCK,O05 -999.~50 -999.~50 NTCK,O05 -~99.250 NTCK.O05 ~.000 NTCK.O05 1,000 NTC~,005 1,000 NTCK.OO5 1.000 NTCK.O05 -999.250 NTCK.O05 -999.~50 -999.~50 -999.~50 -999.~50 -999.~50 -999o~50 '999.~50 -999.250 '999'250 1'000 1.000 -999.250 DTCK,O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 ~.~c~ oos DTCK,O05 DTCK.O05 DTCK.005 DTCK.O05 DTCK.005 DTCK.005 DTCK.005 PAGE: -999,250 -999.250 'gg9o~50 'ggg.~50 'ggg,~$O 'gg9,250 '999,250 '999.250 '999.250 !.000 !.000 -999,250 Tape Yeti, fi. cation Llstln~ ~ch!umbergerA]..as~a Computing Center 30-MAR-1993 14::15 10 **** FiLE HEADER FILE NAME : EDIT SERVICE : WL!C VFRSIOM : 00lA07 DATE : 93/03/30 M~X REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE NUMBER 3 Curves and !o~ hea~er d~ta ~or each b~t run in sea,rate file~. BlT RUN DEPTH INCREMENT: 0.5000 ~I[,E SUMMARY VENDOR TOOL CODE START DEPTH CDR 4836,0 CDN 4836,0 $ bOG }{EADE~ DATA DATE LOGGED: SOFTWARE~ SURFACE SOFTWARE VERSION:, DOWNHOL~ SOFTWARE VERSION: DATA TYPE {MEMORY OR REAI,-TI~E): TI) DRILLE~ TOP LOG INTERVAL BOTTOM bOG INTERVAL BIT ROTATING SPEED MC)LE INCLINATION (DEG) MINIMUM ANGLE: ~AXIMUM ANGLE: TOO[, STRING (TOP Tf! BOTTOM) VENDOR TOOL CODE TOOL TYPE DN NEU? PORmSIIY CDR R~SISTIVITY SBOREHOLE AND CASING DATA UPEN ~OLE BIT SIZE (IN): DRILLERS CASING DEPTH (WT): BORMHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY STOP DEPTM 826 826~'0 lO 10'FEB'g3 FAST 2,3D V4,,0C ~O~Y 8263 0 4976i0 TOO[, NUMBER ~GS059 8,500 4975.0 !0.50 ~Chlumberger Alaska Co putinq Center 30-MAR-i99] 14::!5 MUD P~l: FL, U~D bOSS (C3): P,.~SISTIVITY (OH~.IM AT T~!PERATURE DEGF) MUD AT MEASURED T~]~PERATURE (MT){ NI~)D AT ~AX CIRC[JI.,ATING TE~'PERATURE: MUD FILTRATE AT MT: ~U~ CAKE AT ~T: NEUTRON TOOL MATRIX: M~.TRIX DENSITY: HOLM CORRECTION (IN): TOOL STAUDOFF (IN): EWR FREOUENCY 2,580 i,SlO 69.0 6!. 0 SANDSTONE 2.65 8,500 ********** ********** BIT TO RES 65.27' BIT TO 8IT TO .~8,[JT 138.7~' DRILLE~ INTERVAb 4976' TO 826 ~ATRIX DENSITY 2.65 (G~/CC).,FLUID ROTAT.ION~L BULK DENSITY PROCESSIUG USE. D.' B~SITE ADDED ~9 ~UD~SYSTEM. DATA FRO~ DOWNHOLE M~MORY, DOWNHObE ~FTw~ VERS~O~ V4.0C' FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EM ** TYPE REPR COl)E; V~L.E mmm~.mmmmmmImmmM~mmmmmmmmmmmmm 66 0 2 66 0 3 73 6O 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 1! 66 17 17 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ImmmmmmmmmmNlmmmmmmmmmmmmmmmmI ~chlum erger ask Compt]tln~ Center 30-MAR-1993 14 ~!5 P A ~ E :J ** SET ?'YPE - CHAN ** .... ' ........... ~'~.'~~.~. ....... ' .... ."'~.''''':'~''~ .... '''''''''''?_'l"''~.~- ...... ...... M~ME SERV UN__ ,., ~.,,, _ .,, ,. ~:,., API APl .a~ ,i,~ ~,I AP IL NUmB DIIMB 8.lZ REPRE PRO ~ ESS !D ORDER ~ LOll TYPE CLASS ~{']D allaB SA~P ELEM CODE (HEX) ~p,· F;~,~;; oo ooo ;"'"'o o ; ~ ~ 4 "'""sa .... oooo~oooo' ..... p~ ~i ~.~ oo 000 oo 0 ~ ~ ~ 4 s~ 0000000000 ~.~ ~, ~,. 6~9 oo 000 oo 0 ~ t , 4 ~ 0000000000 TNP" LW' PU 618989 O0 000 O0 0 ] ! ~ 4 68 0000000000 ATR LWl OH~ 618989 O0 000 O0 0 3 I i 4 68 OOO0000000 ~ ~,~ ~ ~~ ooooo oo o ~ ~ ,. 4 ~ oooooooooo ~ ~ cps ~9~ ooooo oo o 3 , , ~ ~ oooooooooo TAB LWl 618989 00 000 O0 0 3 ! 1 4 68 0000000000 ~ ,,~,, ~!.98s oo ooo oo o ~ I ~ 4 ~$ oooooooo~2 DATA ** DEPT. 8263,000 RHOO.LWI ~g99,250 DRHO.Lw! '999,2:50 .PEF,LWI DCAI.,,LW:I. -999'250 DPHI bWl 999:250 TNPH:,bWI 999,250 "R , A.r LW1 PSR,LWl -999,250 R PE,LWI 91 839 GR,L~I ~999,250 HENA L~i HEFA,LWI -999,250 TAB.LW1 -999,250 TABD,LW1 -999.250 DEPT, 8000,000 RDOB,LW! 2 418 DRHO.Lwl -0 001 PEF.LWI DCAL,LWl 0,384 PSR I ' · · ..... ,200 ATR,LWI ..~.,Wl 1 647 HEFA.LW! 6.0]0 TAB.I..,W! ...:09 TABD,LWi .672 DEPm. 7500,(?00 RItOB.bWl 2~424 DRHO,b~! 0.009 PEr. L~I D¢AL.b~I 0,_ O0 DPHI.L~! 1~[700 TNPH,G~I 31.100 A?R.L~! PSR,LWl 2,814 POPE.LWI 1.7 852 GR,LW1 !04.407 HENA.LWl HEF.fi.LW1 7,330 TAB.LW1 0,239 TABD.LW1 0.708 DEPT 7000.000 RHOB.LWl 2.~07 DRHO.LWl -0 ~11 PEF.LWl DCAL]E, Wl ' 0,050 DPHI,LWl 14. 00 TNPH,Lw! 42] 00 ATR.LWI PSP.bWl 3.075 ROPE,LW1 369.63a GR,LW1 140:537 HENA,LWl HEFA,L~'I 5.463 'TAB.LW1 0.348 TABD.LW1 0 662 DEPT, 6500,000 RHOB.L~I 2,373 DRHO.DWI -0.020 PEF.Lwl DCAL,LWl 0,123 DPHI.LWl 16,800 TNPH.LW! 41.600 ATR.LWl PSR,LWI 2,495 RODE,LWl 335,400 GR.LWI 155.864 HENA.I.,W1 HFFA.LWl 5,523 TAB,LWi 0.321 TABD.LWl 0,643 ' DEDT A000.O00 RH~,LW1 DCAL:5WI 0 051 DP ..bWl i .342 DRHooLWl -0 014 PEF,LWI · .700 ~S~,LWl 2,462 ROPE.L~i 439,~55 GR.LWl @8.69~ B~NA,LWl HEFI.LWl 6,048 TAB.LWl -999,250 :999,250 999'250 3'g!! 1 622 27aiooo 5.524 2.811 294.500 4,268 3.184 265.750 3.330 2.306 266,750 2.832 2.561 283.750 12¸ [.sis TaLe Verification Listing Schlumberger Alaska ComPutIn~ Center 30-~R-1993 !4:.!5 13 DEPT. DCAL.LW! PSR,LWI HEF~.LW! 5500,000 ~HOB.LW! 2:933 ROPf,LWl 6.538 TAB,LW! 0..455 DPH -999,250 DPHI.LWI -999.250 ROPE.LWi 4.030 TAB.LWl EPT PSR.LW1 DEP? DCAL:LW! HEF.A.LW1 END OF DATA ** 424,012 GR, 0,261 TABO.SWl !g'3~ ORHO.I,W! .30 TNPH,LW1 48! ,870 ' 0.723 TAB:D,LWl -0.0i0 PEF.LW! 31.600 ATR.LW! 9!.037 HENA.LWl 0,571 0.011 PEF,LW -999.250 PEF.L~! -999.250 ATR,LWl -999'250 HENA.LW! -999'250 2,835 3,095 266.000 2 }! 253,000 99 .250 =99,250 **** FILE TRA!LE~ **** FIhE NA~E : EDIT ,003 SERVICE : FLIC VERSION : 00lA07 DATE : 93/03/30 ~AX REC SIZE : 1024 FILE TYPE : LO L~ST FIL~ : **** FILE UEADER **** FILE NA~E : EDIT .004 SERVICE : FLIC V~RSION : O01A07 DATE : 93/03/30 M~X REC SIZE : 1:024 FILE T~PE : LO LAST FILE : FILE HEADER PILE NUMBER 4 RAW MWD Curves and lo~ header data for each bit run in separate BIT PUN NUMBER: 2 DEPTH INCREMENT: 0.5000 FILM SUMMARY VENDOR TOOl.., CODE START DEPTH STOP DEPTH C[,)~ 8090.0 8670,0 CDN 809o,0 8670,0 'IS Tape veriflcatloD Listing 3chlumherger Alaska Computing Center 30-M~R-!gg3 14:~5 PA !4 $ bOG HEADER DATA DATE LOGGED: SURFACE SOFTWARE VERSION: 1)OWNHObM SOFTWARE VERSION: DATA TYPE (~EMORY OR REAL-TIME): TD DRILLER (FT); TOP bOG iNTErVAL BOTTOM LOG INTERVAL BIT ROTATING SPEED (RPM): NOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDN NEUTRON/POROSITY CDR RESISTIVITY $ BORE~OLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH B{]~EM0bE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY ~UD ~UD CHLO~!DES FLUID LOSS RESISTIVITY (OHM~ AT TEMPERATURE DEGF) ~UD AT MEASURED TEMPERATURE (MT): MUD AT HAX CIRCULATING TEMPERATURE: ~!!D FILTRATE AT MTg ~UD CAKE AT ~T: NEUTRON TOOL MATRIX: ~ATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): K~R FRE(~UENCY (HZ): REMARKS !O'FEB'9~ FAST V4,0C MEMORY 8670.0 ~090.0 8670,0 TOOL NUMBER NDS049 RG8059 . soo 4;?5.0 10,50 2,580 1,8!0 SANDSTONE 2.65 ~,500 69.0 6!.0 ********** RUN BIT TO ~$ 15 ~', BIT TO GR 25.4''~ ~IT TO DEN 41 98; ~T TO ~EUT 4~ 96', DRIbLE~ XNT~RYA 26~' TO 8670$ ATRIX DENSITY 2.65 (GM2CC), FLUID DENSITY 1,0 (GM/~C OTATIONAL BULK DENSITY PROCESSING [ISE~. BARITE ADDED TO MUD ,SYSTEM DATA FROM DOWNHO[,E ~EMORY. DOwNHOLE SOFT~ARE VERSION V4,0C. · his TaPe Verl. ficatiom .Listlm~ ScblUmber,ger Alaska Computimi~ Center $ # LIS FORMAT DATA 30-MAR-1993 1~:15 PAGE: ** DATA FORMAT SPECIF!C.~TION RECORD ,** ** SET TYPE - 64EB ** TYPE kEPR CODE VA~U~ ! 66 0 2 66 0 3 73 60 4 66 ! 5 66 7 65 9 65 !1 66 !7 !~ 68 13 66 0 1~ 66 68 16 66 0 66 ** SET TYPE - CH~N ** NAMF SERV UNIT SERVICE APl API API API FILE NUMB NUMB SIZE REPR PROCESS ID OPDER # bOG TYPE CLASS MOD NUMB SAMP ELEM COD~ (MEX) DEPT FT 61~9~9 O0 000 O0 0 4 ! ! 4 68 RHOD Lw~ G/C3 618989 O0 000 O0 0 4 1 1 4 68 D~ LW2 G/C3 6!~989 O0 000 O0 0 4 ! ! 4 68 PEF LW2 618989 O0 000 O0 0 4 1 1 4 68 DCA[, LW~ IN 618989 O0 000 O0 0 4 ! 1 4 68 DPH! 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I 4 68 0000000000 ~IS Tape verl'flcation Listinq ~cblumberqerAlaska Computln~ Center 30-~AR-J 993 I4:!5 A ~ P .GEl NAMF $~PV UNIT SE~'V,[CE API A API API FIb~ NUM NUmB ZE REPR ID ORDER ~ LOG TYP~ CLASS MO[) NUMB SAMP EL~4 CODE (HEX} I~.,E~ 002 O~M~ 618989 O0 000 O0 0 5 ] 1 4 68 0000000000 IDV~ 002 OH~M 6i89~9 O0 000 OO 0 5 I I 4 6R 0000000000 I~V~ 002 OM~ 618989 O0 000 O0 0 5 1 1 4 6'8 0fi00000000 ** DATA ** O~PT 8639,500 IDPH.O0~ ~:426 !MP~oOO2 2o3~9 IDEP.O0~ I~E~:O02 2,365 ~DVR'O0 467 I~VR.O02 2,353 ' D~P~. 8500 000 IDPM.002 3 285 I~PH.002 3 13 IDER.00~ : DEPT. 795!.000 Ii)PM 002 1.447 I.=~PM,002 ! ~3~3 ID'ER.002 IMEP,002 1,4!6 IDVR:002 ~,419 IMVR.002 3: 07 ** END OF DATA ** 2.476 3.173 1.430 **** FIbM TRAIbER **** FIGM NAME : ~DIT .005 SERVICE : FLIC VERSION : 001A07 DATE MAX AEC SIZE : 1024 FILF TYPE : LO LAST FILE : **** TAPE TRAILEP **** SERVICE NAME : EDIT DATE : 93/0]/]0 ORIGIN : r[,IC T~PE NAME : 93067 CONTINUATION # PREVIOUS TAPE : CO~ENT : ~CO ALASKA INC., KUPARUK RIVE~ UNIT, IH-I~, 50-029-22341-00 TaPe Yertf~catlon Listin~ ~cblumberger Alaska Comput~nq Center 30'MAR-1993 14:15 19 D~T~ : 93/0]/30 ORIGIN : FLIC REEL NA~E ~ 93067 C..NTINU~TIq~ ~ COM...ENT : ARcr) ALASKA INC,, ~'kIP~RUK RIVE~ UNIT, IH-!8,
