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193-133
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 1, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2A-21 KUPARUK RIV UNIT 2A-21 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/01/2024 2A-21 50-103-20192-00-00 193-133-0 W SPT 5774 1931330 1500 2390 2390 2390 2390 100 100 100 100 4YRTST P Adam Earl 5/19/2024 4-year MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2A-21 Inspection Date: Tubing OA Packer Depth 460 1800 1725 1715IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240521072855 BBL Pumped:2.8 BBL Returned:2.6 Monday, July 1, 2024 Page 1 of 1 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger COPA Wireline Backlog – Batch 2 DATE: 03/01/2024 Transmitted: North Slope, KKuparukk Via SFTP drop - DEVELOPMENT - AOGCC - SCHLUMBERGER 1 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 198-011/ T38554 179-059/ T38555 179-112/ T38556 183-020/ T38557 186-002/ T38558 201-083/ T38559 193-133/ T38560 203-099/ T38561 184-022/ T38562 183-095/ T38563 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 10:47:17 -09'00' 193-133/ MEMORANDUM State of Alaska w Alaska Oil and Gas Conservation Commission TO: Jim Regg�) p DATE: Monday, May 11, 2020 P.I. Supervisor SUBJECT: Mechanical Integrity Tests 4.9 ConocoPhillips Alaska, Inc. 4YRTST -L / 2A-21 FROM: Guy COOK KUPARUK RIV UNIT 2A-21 Petroleum Inspector Sre: Inspector Reviewed By: P.I.sup.'JG NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2A-21 IInsp Num: mitGDC200507160419 Rel Insp Num: API Well Number 50-103-20192-00-00 Inspector Name: Guy Cook Permit Number: 193-133-0 Inspection Date: 5/6/2020 Packer Depth Well ! 2A-21 -Type Inj w TVD 5774 - PTD 1931330 BBL Pumped: Type Test SPT Test psi 5.1 � BBL Returned: 1500 - 4.9 Intervals -- 4YRTST -L / P_ Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 2335 - 2345 - 2347 - 2348 IA 410 3000 2875 - 2850 ' OA 60 80 - 80 80 Notes: Testing was done with a Little Red Services pump truck and calibrated gauges. ✓ Monday, May 11, 2020 Page 1 of 1 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,May 09,2016 TO: P.I.JimuRper gg cl ,S'24IICa SUBJECT: Mechanical Integrity Tests P.I.Supervisor EC/ tt CONOCOPHILLIPS ALASKA INC 2A-21 FROM: Johnnie Hill KUPARUK RIV UNIT 2A-21 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Jr-r--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2A-21 API Well Number 50-103-20192-00-00 Inspector Name: Johnnie Hill Permit Number: 193-133-0 Inspection Date: 5/7/2016 Insp Num: mitJWH160508214423 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Weill 2A-21 Type Inj G 1TVD 5774 - Tubing 3060 3060 - 3060 - 3060- PTD 1931330 Typ e Test SPT Test psi 1500 - IA 1 650 2010 . 1950 - 1940 Interval 4YRTST . P/F P j OA 60 70 - 70 . 70 - Notes: 2.7 bbls diesel . SCANNED SEP 2`7 2016 Monday,May 09,2016 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday,May 07,2012 TO: Jim Regg c---)x< < , P.I.Supervisor ' \ef7 '/1 (-, //7" SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2A-2I FROM: John Crisp KUPARUK RIV UNIT 2A-21 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2A-21 API Well Number 50-103-20192-00-00 Inspector Name: John Crisp Permit Number: 193-133-0 Inspection Date: 5/1/2012 Insp Num: miLICr120503083144 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min — 7 ell I 2A-21 ' Type Inj G TVD I 5774 IA 1770 2620 2570 - 2550 1 ,---- 'TD 1931330 '1Type Test SPT Test psii 1500 OA 360 420 . 420 420 " Interval 4YRTST P/F 1 P Tubing 355° 3550 3550 3550 Notes: 1.6 bbls pumped for test. SCANNED MAR 1 3 2 014 Monday,May 07,2012 Page 1 of I • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2A-21 Run Date: 4/12/2010 May 19, 20 i 0 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A-21 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20192-00 Injection Profile Log , r, 1 Color Log 50-103-20192-00 ~ ~'~~~~ ~°=°~h' '~~'`' ' `~ ~`` PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barre 1~ ~,c ~ ~ ~ ~_~~~~~1 _ ~ L-~ 1 -i ~ Date: ~~.i ~~ ~ l~-3 Signed: t~ L~ ~~ ~c~ MEMORANDUM TOE Jim Regg '~ P.I. Supervisor ~~~z'~ .~ ~ 1~~~ FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 07, 2008 SliBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASIGI [NC 2A-21 KLPARUK RIV U'VIT 2A-21 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv` i Comm Well Name: KUPARUK RN UNIT 2A-2t Insp Num• mitJCr080504090752 Rel Insp Num: API Well Number: 50-1 03-20 1 92-00-00 Inspector Name: John Crisp Permit Number: 193-133-0 Inspection Date: s~2;2oos Packer Depth Pretest Initial 15 Min. 30 iVlin. 45 Nlin. 60 Min. zAZ] T- Well IType Inj. W '--TVD ~~ X774 ~ IA X40 ~ zo3o I9so ~ I96o ' i --- ~ -- ---- 1931330 3,p SPT p ' 2000 QA ! 3~0 420 420 I 420 1 P.T __ _ T eTest _~ Test si Interval P/F g'~- - r --_ _ -- ,- --~--- 4YRTST P ~ Tllbin 2650 ! 2650 2650 2650 i NOteS: 3 bbl's pumped for test. Wednesday, May 07, 2008 Page I of 1 • • ~ ~F~~. f -.-x Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 15, 2007 ~, Mr. Tom Maunder -= ~-- a ~ ~ ~ -- f:. Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 _ ' Anchorage, AK 99501 ~'~~ ~ ~ ~ ~ ~` 2007 ,~~ (~ Dear Mr. Maunder: 1 " \~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCG, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of .Sundry Operations. The cement was pumped September 24 & December 12 2007 and the corrosion inhibitorlsealant was pumped on December 6 & December 14 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • • Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant ?op-off Report of Sundry Operations (10-404) Kuparuk Field Dada Well Name PTD # tnittai top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbis ft al 2A-01 184-057 SF na SF na 1.5 12!14/2007 2A-02 184-050 SF na SF na 3.5 12/14/2007 2A-03 184-051 44" na 44" na 50 12/14/2007 2A-04 184-053 9'6" 1.2 10" 9/24/2007 3.5 12/14/2007 2A-05 184-067 SF na SF na 5 12/5/2007 2A-06 184-064 25'5" 1.5 20" 12/12/2007 8.5 12/14!2007 2A-08 185-248 SF na SF na 3 12/5/2007 2A-09 186-001 SF na SF na 1.75 12/14/2007 2A-10 186-002 23' 3.1 11" 9/24/2007 7 12/5/2007 2A-11 186-003 SF na SF na 11 12/5/2007 2A-12 186-004 SF na SF na . 6 12/5/2007 2A-13 185-144 SF na SF na .1.75 12/14!2007 2A-14 185-i45 SF na SF na 3.5 12!14/2007 2A-17 193-140 SF na SF na 15 12/5/2007 2A-18 195-059 NA na 8' na 35 12/14/2007 2A-21 193-133 5' 0.7 18° 9/2A12007 3 .12/5/2007 2A-22 195-068. 39" na 39" na 7.5 12/14/2007 2A-23 193-142 SF na SF na 2 12/5/2007 Schlumberger RECEiVED NO. 3615 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth DEC 2 1 Z005 Company: ~ Cit& Gas Cons. c-cmrrÜ~~¡Cf1 Aochürage Field: Well Job # Log Description Date BL 1Y-19 11144040 PIEZO SONA TOOL 11/19/05 1 1 Y -27 11072935 PRODUCTION PROFILE WIDEFT 11/22/05 1 2D-09 11072933 SBHP SURVEY 11/18/05 1 1 R-15 11072932 SBHP SURVEY 11/18/05 1 3F-05 N/A PRODUCTION LOG 11/13/05 1 1 L-25 11056689 SBHP SURVEY 09/14/05 1 3F-12 11057064 INJECTION PROFILE 11/06/05 1 3H-01 11056685 PRODUCTION PROFILE W/DEFT 09/10/05 1 10-16 11141232 PRODUCTION PROFILE WIDEFT 12/01/05 1 1 E-33 N/A GLS & BHP 12/04/05 1 3N-13 11141234 INJECTION PROFILE 12/03/05 1 2N-329 11141236 SLIM CHFR 12/08/05 1 1 C-07 11141231 PRODUCTION PROFILE WIDEFT 11/30/05 1 1 Q-09 11141233 INJECTION PROFILE 12/02/05 1 3B-16 N/A INJECTION PROFILE 12/08/05 1 10-06 N/A PRODUCTION PROFILE W/DEFT 12/1 0/05 1 -"""-~ 2A-21 Itt_~ It I ~7, 11141237 INJECTION PROFILE 12/12/05 1 2A-24 11144049 PROD PROFILE WIDEFT 12/15/05 1 10-101 11144044 MDT 11/24/05 12/20/05 \q"ò~¡33 Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color CD 1 SIGNED: SCANNED ,H\N 3 Ú 2.005 DATE:&~ 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: Jim Regg P.I. Super\'i~or Þ1'1 tlZ'l(Û4 FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RlV UNIT 2:\-21 Insp Num: milCS040621125700 Rellnsp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday. June 23. ~OO..¡ SlIBJECT: t-.techanicallntegrn)' Tests CONOCOPH[l..UPS ALASKA INC 2A-21 KUPARUK RIV UNIT 2A-21 Src: Inspector NON-CONFIDENTIAL API \Vell Number: 50-103-20192-00-00 Permit Number: 193-133-0 Reviewed By: P.I. Supn' J.gÇ- Comm Inspector Name: Chuck Scheve Inspection Date: 6/2012004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2.'\-21 Type Inj. P I TVD 616.. IA 580 2560 2470 24" 0 P.T. 1931330 TypeTest SPT I Test psi ]4" 35 OA 330 570 570 570 Inten'al .¡ YR IST PIF P Tubing 1700 1700 1700 1700 Notes: The pretest pressures were observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wednesday. June 23, 2004 Page J of I MEMORANDUM TO: Dan Seamount Commissioner THRU: Blair Wondzell P.I. Supervisor FROM: Jeff Jones ~J~- Petroleum Inspector state of Alaska Alaska Oil and Gas Conservation Commission DATE: Sept. 1,2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 2A Pad 2A-01A, 2A-02, 2A-03, 2A-04, 2A-06, 2A-08, 2A-20, 2A-21,2A-23 KRUlKuparuk River Field NON- CONFIDENTIAL P.T.D.I Notes: WellI P.T.D.I Notes: ' Well! ' P.T.D.I Notes: WellI 2A-04 P.T.D.I 1840530 Notes: WellI 2~-06 P.T.D.I 1840640 Notes: · WellI 2~-08 P.T.D.I 1852480 Notes: WellI 2A-20 , P.T.D.I 1931510 Notes: Well1 2A-21 P.T.D.J 1931330 Notes: · Well1 P.T.D.! Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N -- NOT INJECTING Packer Depth Pretest Initial 15 Min. 30 Min. 2~-O~A I TY~,nj.I ~ I'*'v'~'I5796 ITubingl 35001 3500 I ~001~oo I lntervall 4' 1840570 ITypetestl ' P ]TestpsiI 1449 I CasingI 52b 1176O1176O1176O1 P/FIE ~^-o~ l~,.i:l s IT.V'D- I 58°° ITubingl 2740 I 27501 27501 2750 I lntervall 4 1840500 ITypetestI P I Testpsil 1450 ICasingI 575 I 1710 I 1700 I 17-10I P/F I E ~-o~ lTd.,nj.I ~ I~'v'~' I 5845 ITUbin~l 3550l 35001 35001 3500 I~nter~a~l 4 1840510 IT~etestI P I Testpsil 1461 I CasingI 1160I 1675I 1610I 1610I P/F I P "'"J:l ~ I'T'v'~'l ~ ITu~""I ~°°1 ~°°1 ~26 I~ I'"~e~"'l" T~etestlP..I TestpsiI 1453 I CasingI ~50 I ~690 I ~6s0 I 1680 I P/FIE I~.~n~. I ~ I~'v'D' I ~ ITubing I ~o I ~°°1 ~oo I ~o0 I~nte~a~l 4 IT~etestl ' P ITes{psil 1443 I CasingI 1650I 22001 2200I 2200 I P/F I P I T~e~n~.I S IT'V'D' I 5765 ITUbi"gl 27251 27251 ~1 2~ I~nte~.~l 4 I T~etestI P I Te~PsiI 1446 ICasingl 950 I ~625 I 1625 I ~625 I P/F I P I~"~"~'1 S IT'v'D'i 5786 ITubingl 2850 I 2850 I 2850 J 2850 I lnte~all 4 I T~etestI P I~Te~psil 1447 I CasingI 1175 I 1700 I 1725 I 1710 I P/F J P T~elnj.I S !T'V'D' 1 5774 I Tubing I 2700 I 2700 1.2700 I 2700 I lnte~all 4 : T~etestI P I Testpsil 1444 I CasingI 600 I 1720 I 1725 I 1725 I P/F I E 2A-2~ I T~,~,,~.I S IT'v'°' I 5765 ITubingl 1125 I 1150 I 1150 I 1150 I~.t~a~l 4 1931420 IT~etestl P I Testpsil ~44~ I CasingI 6OO I 1650 I 16~0 I 1600I P/F I P 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 Vadance W= Test dudng Workover O= Other (describe in notes) Test's Details Wednesda% Au~. 30- 2000: I traveled to Phillips Alaska Inc.'s KRU 2A pad to witness thc 4 year MITs on wells # 0lA, 0A, 03, 04, 06, 08, 20, 21, 23. Jen'y Dethlcfs was the PlA rep. In charge of testing. The standard annulus pressure test was performed with all nine wells passing the 30 minute pressure test. Summary: I witnessed nine successful MITs on PIA's KRU 2A Pad. M.I,T.'s performed; _~ Number of FailureS: Attachments: Well schematics {9) 0_. Total Time during teSts: 8 hrs CC: MIT report form 5/12/00 L.G. MIT KRU 2A 8-30-00 JJ.xls 9/5/00 og ggFo AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA_PLUS RUN DATE_RECVD 93-133 595¢ , ~ .... ~,~' 0' 50-11839, OH-CDR/CDN 1 01/18/1994 93-133 407 ~OMP DATE:10/21/93 12/03/1993 93-133 DAILY WELL OP ~/~9/02/93-10/21/93 12/03/1993 93-133 SURVEY ~[RECTIONAL 11/09/1993 / 93-133 SURVEY P~/SS DIRECTIONAL 12/03/1993 93-133 CBT ~/9900-11690 01/01/1993 Q3-I°3~ ~ CDN-LWD/DC ~L-~4650-11800 1 01/18/1994 93-133 CDR-E/LWD/DC ~L~ll100-11800 1 01/18/1994 93-133 CDR-LWD/DC ~A~700-11800 1 01/18/1994 93-133 CET ~/~9900-11718 01/01/1993 Page: ! Date' 09/29/95 Are dry ditch samples required? yes ~~_~And receiv~~ Was the well cored?' yes ~~Analysis & description-~ .~-~f~ Are well tests required? yes ~eceived~ Well is in compliance ~ I~itial COMMENTS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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 st~ace 1286' FSL, 53' F~]_, SEC.14, T11N, R8E, UM At top of productive interval 1430' FSL, 1394' FWL, SEC.15, T11N, R8E, UM At effective depth 1479' FSL, 1195' FWL, SEC.15, T11N, R8E, UM At total depth 1499' FSL, 1128' FWL, SEC.15, T11N, R8E, UM 6. Datum elevation (DF or KB) RKB 122' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-21 9. Permit number 93-133 10. APl number 5o-013-201 92 11. Field/Pool Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 1 1 839 feet true vertical 6 1 64 feet Plugs (measured) Effective depth: measured 1 1731 feet Junk (measured) true vertical 6 0 8 1 feet Casing Length Size Cemented Structural Conductor 80' 1 6" 200 SX PFC Surface 4752' 9 5/8" 792 SX PREM E & Intermediate 385 SX CLASS G Production 1 1 7 7 8' 7" 215 SX CLASS G Liner Perforation depth: measured 11417' 11441', 11472' - 11600' true vertical 13. 5847' - 5865', 5887' - 5981' Tubing (size, grade, and measured depth) 3-1/2" 9.3 #/ft J-55 @ 11344' Packers and' SSSV (type and measured depth) PKR: CAMCO HRP4-SP @ 11315', SSSV: OTIS LDG NIPPLE @ 1800' Stimulation or cement squeeze summary PERFORATE A SAND @ 6 SPF 90 ° PHASING Intervals treated (measured) 11472' - 11600' Treatment description including volumes used and final pressure OP, IGII\IA1._ Measured depth True vertical depth 121' 121' 4793' 2 9 5 4' 11819' 6148' Oil & Gas Cons, Commission Anchor~ "- 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 6455 700 2479 6947¢''/' 500 241S 15. Attachments Copies of .Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: ~L/~ ~ I Jk,J Oil _ Gas Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Wells Superintendent Date ,/z..,/2 1~,//',~..~-' SUBMIT'IN DUPLICATE ARCO Alaska, Inc. WELL DATE DAY TIME DESCRIPTION OF WORK ,.~_ f-.,~[ & B~S G~J~' l~'13~'-Wt[~O~ KUPARUK RIVER UNIT WELL SERVICE REPORT CONTRACTOR / KEY PERSON IAFC/CC ACCUMULATED COST OPERATION AT REPORT TIME FIELD EST: ~/COMPLETE [] INCOMPLETE $ [ '-[ [, ~ ~. ---"'" .,~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK -- .Wee. r.i ~e~,. I Chill Factor Visibility I Wind Vel. I Sig~e~d~. °F I °F miles 'knots AR3B-7031 298-3486 ARCO Alaska, Inc. Date: January 14, 1994 Transmittal #: 8980 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO- 1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items· Please acknowledge receipt and return one signed copy of this transmittal ~ ~i~. ~ ' ~ 4<~'~'~""' ' 1Y-27 (5~"¢~-L Ll~S__T_ap_e~and Listing' .~-.;%~.'"'"~"'"i0-28-93 93426 C_ased H.o_.le-T~r-P~ passes and average ;'i ~...'-_',-~ c'~&55 1Y-18 ~3.-~;:¢.~._ LIS Tape and Listing: 10-28-93 93423 1Y-23 5o~:5~ LIS Tape and Listing: 10-28-93 93425 C~t-CNTG Main and repeat passes, b;¢oK-~-'5~-% P,\ 1Y-31 ~o~5~ LIS Tape and Listing: ~CNTG 2A-21 5ct 5~ LIS Tape and Listing: ~.k-CDR/CDN, 2 Bit Runs 2A-17 ¢_.~~ LIS Tape and Listing: o~r-CDR/CDN, 2 Bit Runs 2A-23 5~5'~ LIS Tape and Listing: O~--CDR/CDN, 2 Bit Runs 2A-24 5~ 5~ LIS Tape and Listing: o~-CDR/CDN, 1 Bit Runs 10-04-93 93429 12-07-93 93452 with QRO Processing ,4 ~.p-i t cs'~% P,. \ 12-07-93 93474 with QRO Processing qoxo-q~Sq, ~ \ 12-07-93 93470 with QRO Processing H~-¢c>-~ ~-'¢.ct P-,~ 12-19-93 93480 with QRO Processing '~t?_.- c~ (o?q P..~ 93497 2A-20 5¢15~ LIS Tape and Listing: 12-20-93 ~[t-CDR/CDN, 2 Bit Rj~ns with QRO Proces/iing Receipt Acknowledged: _/¢~ ;/~9_./~W,¢0 '~;¢~.~ DI~qTRIBUTION: Bob Ocanas Date· State of Alaska ARCO Alaska, Inc. Date: January 14, 1994 Transmittal Cf: 8981 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 .o_~ole items. Please acknowledge °receipt and return one signed copy of this transmittal. / 2A-21 ~i~" \~'/k2A'21 / k2.A-21 2A -17 ~,¥,lt~o 2A-17 ~.A-17 /2A-23 c~?%tu~ ~, 2A-23 ' \2A-23 /2A'24 ~¢.:. ¢~/q ~, 2A-24 2A-24 ,?.-.":<~\ ¢2A-20;~ 2A-20 ~, 2A-20 Dual Compensated Neutron (CNTG) '/CDN LWD/Depth CorrEcted ,/CDRLWD/Depth Corrected ',./CDR Enhancement LWD/Depth Corrected ,/CDN LWD/Depth Corrected -./CDRLWD/Depth Corrected vCDR Enhancement LWD/Depth Corrected vCDN LWD/Depth Corrected ,,,-CDR LWD/Depth Corrected 'cE;DR Enhancement LWD/Depth Corrected ,/CDN LWD/Depth Corrected ac, ~ LWD/Depth Corrected ~CDR Enhancement LWD/Depth Corrected CE;DR LWD/Depth Corrected ,-~,~,- DN LWD/Depth Corrected ,/:CDR Very-Enhanced Resistivity LWD/Depth Corrected .. DISTRIBUTION' 09-08-93 ¢,.',, 6450-7689 09-17-21-93 09-17-21-93 09-17-21-93 R~4650-11800 '~ t%~4700-11800 ~t 11100-11800 09-26-28-93 09-26-28-93 O9-26-28-93 P-\4090-9900 .~N5 4100-9920 -~ 9200-9910 5' 10-04-08-93 10-04-08-93 1 O-04-08-93 10-12-15-93 10-12-15-93 10-12-15-93 4300-11650 4300-11660 11000-11660 __~~ 5' 3400-9800 ¢-:,- ~-w--~ a-¥5 3400-9800 ¢." ~"~¢ 3400-9630 ¢',~'n"¢~ 10-19-23-93 10-19-23-93 10-19-23-93' Date: 4100-11530 41 00-11 530 10400-11510 ":;- ".-~ :~ STATE OF ALASKA ALA~,.A OIL AND GAS CONSERVATION COMMisSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~] GAS ~ SUSPENDED [~ ABANDONED [] SERVICE r~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 93-133 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0369~. _ 50-013-20192 ~ ~'~,'~'r~r~;~: ~",~ 9 Unit or Lease Name 4 Location of well at sL~ac~/.., i ~-~ ~'!0i~ ~ "~;~'~ :~ 1286' FSL, 53' ~V.L, SEC 14, T 11 N, R 8E, UM.,/~:,~,,'/",,',' ~ ~ '~'~''~. ~' ~ KUPARUK RIVER _ At Top Producing Interval i ~" ~-'~/-,/~¢~ ~.,! ~ ~ 10 Well Number 1430' FSL, 1394' FWL, SEC 15, T 11N, R 8E:, ur~~'~ ~ ~_ ~., 2A-21 At Total Depth t_,~ -'~ ..~i~ '-~-~i?~ ~~ 11 Field and Pool _5~r~ 1499' FSL, 1128' FWL, SEC 11'~, T 11 N, R 8E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. RKB 133', PAD 92' GL ADL 25571 ALK 2669 12 Date12-Sep-93Spudded 13 Date 21T'D'-sep-93Reached '. 14 Datel.Q/.2.e~3(C o mp)C°mp', Susp. or/o~,/Aband./)~ ,.~ 15 WaterNADepth, if offshorefeet MSL 16 No. of 1 Completions 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 11839'MD, 6164'TVD l1731'MD, O081'TVD YES [~ NO [~I 1800'SLN feetMD I 1600' APPROX 22 Type Electric or Other Logs Run CDR, CDN, CET, CBT, GCT 23 CASING, LINER AND CEMENTING RECORD SE'II'lNG DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECQRD 16" 62.5# H-40 SURF 121' 24" 200 SX PFC CMT 9.625" 36# J-55 SURF 4793' 12.25" 792 SX PERM E, 385 SX CLASS G 7" 26# L-80 SURF 11819' 8.5" 215 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) 3.5" 9.3# J-55 11344' 11315' 4.5" CSG GUN @ 4 SPF 11417'-11441' MD 5847'-5865' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ FIowTubing 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. NA R£¢£1V£D DEC - 3 199, Atas~ (Jii & Gas Cons. Commission Anchorage 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 TRUEVERT. DEPTH GOR, and time of each phase. TOP OF KUPARUK C 11422' 5851' NA BASE OF KUPARUK C 11 422' 5851' TOP OF KUPARUK A 11 422' 5851' BASE OF KUPARUK A 11 601' 5983' 31. LIST OF ATTACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY(GCT) 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed v~~~'~. Title ~,-~(~ ~/, DATE INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of OPeration: FloWing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut,in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2A-21 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50- ACCEPT: 09/12/93 04:30 SPUD: 09/12/93 08:00 RELEASE: 10/20/93 08:00 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 09/02/93 (1) PARKER 245 TD: 0' ( 09/03/93 (2) PARKER 245 TD: 0'( 09/04/93 (3) PARKER 245 TD: 0'( o) 09/05/93 (4) PARKER 245 TD: 0'( o) 09/06/93 (5) PARKER 245 TD: 0'( o) 09/07/93 (6) PARKER 245 TD: 0'( o) 09/08/93 (7) PARKER 245 TD: 0'( o) RIG PUT ON STANDBY MW: 0.0 VIS: 0 o) BACKED DRILL MODULE OUT OF HOLE & UP ON MATTING BOARDS. REPAIR & COMPACT ROAD IN FRONT OF RIG. TIGHTEN BOLTS ON CAR BODY & LAMPSONS. MOVE MATTING BOARDS F/2E PAD TO RIG & CPF-2. MOVE BALL MILL TO 2C. RIG ON EXTENDED STAND-BY @ 1200 HRS 09/01/93. RIG ON STAND-BY MW: 0.0 VIS: 0 o) FIN LD MATTING BOARDS. MOVED DRILLING & UTILITY MODULES ACROSS SOFT SPOT IN SPINE ROAD. TESTED ROAD FOR SOFT SPOTS W/LOW-BOY TRAILER LOADED W/160,O00# FROM RIG TO 2A PAD. PREPARE TO LD TOP DRIVE & DERRICK. RIG ON EXTENDED STAND-BY @ 1200 HRS 09/01/93 TO KEEP ROAD OPEN FOR SCHEDULED SHUT DOWN @ CPF-2. RIG ON STAND-BY MW: 0.0 VIS: 0 RIG ON EXTENDED STANDBY. PREPARE TOP DRIVE & DERRICK TO BE LAYED DOWN. START PU MATTING BOARDS BEHIND RIG. RIG ON STAND-BY MW: 0.0 VIS: 0 RIG ON EXTENDED STANDBY. PREPARE TOP DRIVE & DERRICK TO BE LAYED DOWN. RIG ON STAND-BY MW: 0.0 VIS: 0 RIG ON EXTENDED STANDBY. PREPARE TOP DRIVE & DERRICK TO BE LAYED DOWN. LAY MATTING BOARDS & PLYWOOD TO CPF-2. PLAN TO START MOVING RIG TO CPF-2 @ 0800 HRS THIS MORNING. MOVING RIG TO 2A PAD MW: 0.0 VIS: 0 RIG ON STANDBY FOR CPF-2 SHUTDOWN. LAY MATTING BOARDS & PLYWOOD TO CPF-2. MOVED RIG & UTILITY MODULE TO CPF-2. PU MATTING BOARDS & PLYWOOD. BLADE ROAD FOR CRANES. SKID RIG TO WELL CENTER. LD FRONT WIND WALLS, TOP DRIVE & COMPENSATOR. LD DERRICK. PREPARE TO SET DERRICK OFF RIG. MOVED UTILITY MODULE F/CPF-2 TO 2B PAD. MOVING RIG TO 2A PAD MW: 0.0 VIS: 0 FIN R/D & LOAD OUT DERRICK. SKID RIG TO CENTER OF MODULE. REMOVE DIVERTER & BOPE. MOVE RIG AROUND CPF-2. PU MATTING BOARDS & PLYWOOD @ CPF-2 & STAGING IT TO 2B PAD. MOVE RIG F/CPF-2 TO 2B PAD. Gas Cons. Corem%ss%on WELL: 2A-21 API: 50- PERMIT: PAGE: 2 09/09/93 (8) PARKER 245 TD: 0' ( 09/10/93 (9) PARKER 245 TD: 0'( o) o) 09/11/93 (10) PARKER 245 TD: 121' ( 121) 09/12/93 (11) PARKER 245 TD: 121'( o) 09/13/93 (12) PARKER 245 TD: 1100' ( 979) MOVING RIG TO 2A PAD MW: 0.0 VIS: 0 09/14/93 (13) PARKER 245 TD: 4300'(3200) LAYING MATTING BOARDS & PLYWOOD FROM 2B PAD TO 4 WAY STOP. MOVE UTILITY MODULE & RIG FROM 2B PAD TO 4 WAY STOP. LAYING MATTING BOARDS & PLYWOOD FROM 4 WAY STOP TO 2A PAD. 09/15/93 (14) PARKER 245 TD: 4810' ( 510) MOVING RIG TO 2A PAD MW: 0.0 VIS: 0 LAYING MATTING BOARDS & PLYWOOD F/4 WAY STOP TO 2A PAD. MOVE UTILITY MODULE & RIG FROM 4 WAY STOP TO 2A PAD. PU MATTING BOARDS & PLYWOOD FROM 4 WAY STOP TO 2A PAD SO ROAD CAN BE BLADED TO BRING IN THE CRANES TO RU THE DERRICK. MW: 0.0 VIS: 0 SPOT UTILITY MODULE ON 2A-21. SPOT DRILLING MODULE & LOAD 13-5/8" BOPE & 20" DIVERTER. PIN DERRICK & RAISE SAME. SKID RIG BACK TO CENTER & INSTALL TOP DRIVE. FIN PU MATTING BOARDS & PLYWOOD. NU DIVERTER 16"@ 121' MW: 0.0 VIS: 0 FIN RU TOP DRIVE & RIG FLOOR. LAY MATTING BOARDS & MOVE RIG AROUND CORNER. SPOT RIG OVER WELL @ 0430 HRS 09/12/93. NU 20" DIVERTER. TIH 16"@ 121' MW: 8.9 VIS: 72 FIN NU 20" DIVERTER & MIX SPUD MUD. RU FLOOR & MU STABBING BOARD. SLIP & CUT 400' DRILL LINE. FIN RU RIG FLOOR. PU HWDP, DC'S & STAND BACK IN DERRICK. FUNCTION TEST DIVERTER-CHECK FOR LEAKS-OK. JOHN SPAULDING W/AOGCC WAIVED WTINESSING TEST. PU BHA, ORIENT & TEST MWD. REPAIR CABLE ON TOP DRIVE. SPUD, DRILL, & SURV 12.25" HOLE F/121'-1100'. MWD TOOL FAILED. CBU. PMP PILL & POOH. LD MWD TOOL. LOAD NEW MWD TOOL. MU NEW MWD TOOL, ORIENT & TIH. DRILLING 16"@ 121' MW:10.0 VIS: 48 FIN TIH. DRILL & SURV F/1100'-2950'. CBU. SHORT TRIP-20 STDS. TIGHT SPOT F/1530'-1500'. DRILL & SURV F/2950'-4300'. PREPARE TO CMT 9-5/8" CSG 9-5/8"@ 4792' MW:10.0 VIS: 44 DRILL 12.25" HOLE F/4300'-4810'. CBU. SLUG DP. MADE 39 STD SHORT TRIP TO 1200'. TIGHT. REAMED HOLE. RIH. REAMED F/1700'-1900'. CBU. MUD GAS CUT TO 9.3 PPG. POH. LD BHA. MOTOR LOCKED UP. RU CASERS. HOLD SAFETY MEETING. RAN 47 JTS 9-5/8" J-55 & 67 JTS 9-5/8" 47# L-80 CSG. BROKE CIRC @ 3225'. MU HGR, LANDING JT, & CMT HEAD. CIRC & COND MUD & HOLE W/CSG ON BTM @ 4792'. PMP 6.5 BPM @ 400 PSI. RECEIVED DEC - 199, Alaska Oil & Gas Cons. Commission Anchorage WELL: 2A-21 API: 50- PERMIT: PAGE: 3 09/16/93 (15) PARKER 245 TD: 4810'( 09/17/93 (16) PARKER 245 TD: 4810' ( o) o) 09/18/93 (17) PARKER 245 TD: 5710' ( 900) 09/19/93 (18) PARKER 245 TD:l1058' (5348) CLEAN PIT 9-5/8"@ 4792' MW: 9.3 VIS: 31 CIRC & COND MUD. RECIP CSG. TEST LINES TO 3000 PSI. DOWELL CMT 9-5/8" CSG W/792 SX PERM E CMT & 385 SX CLASS G CMT. HIT MAX CSG PRES 2000 PSI W/24 BBLS LEAD AROUND SHOE. RELEASED PRESS & DROPPED TOP PLUG. PRESS UP TO 3000 PSI. UNABLE TO MOVE CMT-RECIP PIPE-PIPE MOVING FREE-9-5/8" CSG PLUGGED ON INSIDE. BLEED PRESS OFF & REPRESS TO 3000 PSI. COULD NOT MOVE CMT @ MAX PRESS. RELEASED PRESS. CLEAN CMT OUT OF SURF LINES. LD LANDING JT & CSG TOOLS. RIH W/3 STDS HWDP & WASH OUT GREEN CMT TO 270'. ND DIVERTER & INSTALL SEAL RING IN STARTING HEAD. NU DIVERTER. PU 8.5" BIT, BS, 6-6-1/4" DC'S. CLEAN CMT OUT OF 9-5/8" CSG F/266'-4644'. DISPLACE 9-5/8" CSG W/10.0 PPG MUD. CLEAN PITS. WOC 9-5/8"@ 4792' MW:10.0 VIS: 43 C/O CMT OUT OF 9-5/8" CSG F/4644' TO FC @ 4711'. CBU. COND MUD & RAISE MUD WT TO 10 PPG. DRILL SHOE @ 4792'. POH. LD 3-DC'S. ND DIVERTER. PULLED SEAL RING OUT OF STARTING HEAD, C/O CMT OUT OF 9-5/8" BUTTRESS THREADS. NU DIVERTER. FUNCTION TEST SAME. TEST LINES TO 3000 PSI. DOWELL CMT'D 9-5/8" CSG @ 4792'. DROPPED BTM PLUG, PMP 50 BBLS WATER, 410 SX AS III CMT, 935 SX CLASS G CMT. DROPPED TOP PLUG & DISPLACED W/344 BBLS WATER CUT MUD. FULL RETURNS. CIRC 16 BBLS 11.1 SLURRY TO SURF. PLUG DN & JC @ 0430 HRS. SHUT IN @ CMT HEAD W/l150 PSI ON 9-5/8" CSG. ND DIVERTER LINES & WASH CMT OUT OF BAG & VALVES. WOC. DRILLING 9-5/8"@ 4792' MW:10.0 VIS: 31 WOC. BLED PRESS OFF CSG. ND DIVERTER. INSTALL SEAL RING IN STARTING HEAD. SCREW ON 11"-3000 PSI BRADEN HEAD-17000 FT/LBS. NU 13-5/8"-5000 PSI BOP'S. RU TEST EQUIP. TEST BOPE TO 300/3000 PSI. TEST WITNESS BY LOU GRIMALDI W/AOGCC. PU BHA-ORIENT & PROGRAM TOOLS, LOAD RA SOURCE. TEST MWD. RIH-FILL PIPE @ 4000'. TAG CMT @ 4610'-CIRC F/CSG TEST. TEST 9-5/8" CSG @ 4610' TO 2000 PSI FOR 30 MIN-HELD. C/O GOOD CMT F/4610' TO SHOE @ 4792' DRILL OUT CMT F/4792'-4810'. DRILL 10' NEW HOLE F/4810'-4820'_ CIRC & COND FOR EMW TEST. SI WELL. PRESS UP TO 650 PSI @ 2957' TVD W/8.6 PPG MUD. LEAKED OFF TO 600 PSI IN 10 MIN. EMW=12.5 PPG. DRILL 8.5" HOLE F/4820'-5710'. DRILLING 9-5/8"@ 4792' MW:10.3 VIS: 37 DRILL 8.5" HOLE F/5710'-7210' SERV RIG. DRILL 8.5" HOLE F/7210'-11048'. RAISED MUD W~ TO 10.3 PPG-NO MUD LOSS. RECEIVED DEC 199) Alaska Oit & Gas Cons. Commission Anchorage WELL: 2A-21 API: 50- PERMIT: PAGE: 4 09/20/93 (19) PARKER 245 TD:11255' ( 197) 09/21/93 (20) PARKER 245 TD:11839' ( 584) 09/22/93 (21) PARKER 245 TD:11839' ( o) 09/23/93 (22) PARKER 245 TD:11839' ( o) 10/17/93 (26) DOWELL TD:11839 DRILLING 9-5/8"@ 4792' MW:ll.2 VIS: 46 DRILL 8.5" HOLE F/11058'-11148'. CBU @ 11148'. POH TO ANADRIL TOOLS. HOLE IN GOOD SHAPE. REMOVE RA SOURCE & LD BHA. PU 8.5" ROTARY ASSY & LD LWD TOOLS. INSTALL RA SOURCE. RIH-FILLED PIPE @ 2000' & @ SHOE. SERV RIG. RIH SLOW-WASHED THRU BRIDGE @ 6721' & WASHED 70' TO BTM-NO FILL. CIRC & COND MI/D-FIN MIXING 30 PPB LCM-RAISE MUD WT F/10.3 TO 11.3 PPG. NO MUD LOSS. DRILL 8.5" HOLE F/11148'-11255'. NO MUD LOSS. CUT DRILL LINE 9-5/8"@ 4792' MW:ll.2 VIS: 45 DRILL 8.5" HOLE F/11255'-11839'. CBU @ 11839'. POH TO 9-5/8" SHOE. HOLE TIGHT F/11311'-11621' SLUG DP. RUNNING CSG 9-5/8"@ 4792' MW:ll.2 VIS: 45 SLIP & CUT DRILL LINE. FIN TIH. NO FILL. CIRC & COND MUD. DROP SURV & PMP SLUG. POOH. LD 3 JTS HWDP & RETRIEVE SURV. REMOVE SOURCE & DOWNLOAD LWD. LD TOOLS. LUB RIG & PULL WEAR RING. RU CSG EQUIP & HOLD SAFETY MEETING. RUN 7" 26# BTC MOD L-80 CSG. TOTAL OF 274 JTS & 1 MARKER JT WILL BE RUN. BROKE CIRC @ SHOE & 7138'. RIG RELEASED 7"@11819' MW: 0.0 VIS: 0 FIN RUNNING 7" 26# BTC MOD L-80 CSG. SHOE SET @ 11819'. CIRC & COND MUD. RECIP CSG W/FULL RETURNS. CMT W/46.7 BBLS CLASS G CMT @ 15.6 PPG. RD CMT HEAD & CSG EQUIP. PU STACK & SET SLIPS W/190,000#. MAKE ROUGH CUT. ND BOPE, MAKE FINAL CUT, INSTALL PACK-OFF, NU TREE & TEST PACK-OFF TO 3000 PSI. FLUSH 9-5/8" X 7" ANN W/150 BBLS WATER & FREEZE PROTECT W/70 BBLS DIESEL. LD DP OUT OF DERRICK. RELEASE RIG @ 03:30 HRS. MOVE RIG F/2A-21 TO 2A-17. 7"@11819' DO ARCTIC PACK JOB. 10/19/93 (23) NORDIC 1 TD:11839 PB:l1731 POOH W/GUN 7"@11819' MW: 0.0 MOVE F/1Y-31 TO 2A-21. ACCEPT RIG @ 2000 HRS 10/18/93. ND LOWER TREE. NU BOP. CHANGE PIPE RAMS TO 3-1/2". TEST BLIND RAMS & FLANGES TO 3000 PSI. RU SWS. PERF F/11441'-11437' & 11437'-11417' ASF. POH. RECEIVED OEC - 7) Oil & Gas Cons. Commission Anchorage WELL: 2A-21 API: 50- PERMIT: PAGE: 5 10/20/93 (24) NORDIC 1 TD:11839 PB:l1731 NU TREE 7"@11819' MW: 0.0 POOH W/PERF GUN. LOAD 360 JTS 3-1/2" TBG IN PIPE SHED. RUN 360 JTS 3-1/2" TBG, GLM'S, HRP-4SP PKR & ACCESS. INSTALLED TBG HGR & LANDED SAME. RILDS. DROPPED BALL & ALLOWED TO FALL TO SHEAR OUT SUB. PRESS TBG TO 2500 PSI TO SET CAMCO HRP-4SP PKR @ 11315'. BLED OFF PRESS. BOLDS. PU & SHEARED PBR @ 30K# OVER PU WT. RELANDED TBG HGR & RILDS. TESTED 3-1/2" TBG & ANN TO 2500 PSI. TEST TBG TO 3000 PSI. PRESS UP ON TBG TO 3700 PSI & SHEARED OUT BALL. BACKED OUT LANDING JT. SET BPV. ND BOP. NU TREE. 10/21/93 (25) NORDIC 1 TD:11839 PB:l1731 FINAL REPORT 7"@11819' MW: 0.0 NU TREE. RETRVD BPV. SET TEST PLUG. TEST TREE TO 250/5000 PSI. REVERSE CIRC & DISPLACED THE 3-1/2" X 7" ANN TO 450' W/12 BBLS DIESEL FOR FREEZE PROTECTION. PMP 4 BBLS DIESEL DOWN TBG. SET BPV. RD & MOVE RIG TO 2A-17. RELEASE RIG @ 0800 HRS 10/20/93. SIGNATURE: dri~erintende~ DATE: RECEIVED DEC -3 199 , Alaska Oil & Gas C, or~s. ~mmission Andloral]e SUB.$URFACE DIRECTIONAL $URVEY F'~UIDANCE m~ONTINUOUS ~__jOOL Date Company ARCO ALASKA, INC. I mm I m I Well Nam® 2A-21 (1286' FSL, 53'FEL,, ,SEC'14' TllN, R8E, UM), Field/Location KUPARUK, NORTH SLOPE, AK · I I i ! ~o~ ..,.,..o..o. R £ ¢ E IV E D o.,,: 93483 DEC -3 1993 10/14/93 Loaaed aw Computed By: AJas~ 0it & Gas Cons. Commission G. JOHNSON Anchorage R. SINES ,: . · SCHLUMBERGER * GCT DIRECTIONAL SURVEY C~STDMER LISTING FOR ARCO ALASKA, INC. 2A - 21 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE' 14-0CT-1993 ENGINEER' G. JOHNSON METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE · INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 88 DEG 46 MIN WEST COMPUTATION DATE' 26-0CT-93 PAGE I ARCO ALASKA, INC. 2A - 21 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 14-0CT-1993 KELLY BUSHING ELEVATION' 133.00 FT ENGINEER' G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0.00 -133 O0 100.00 200.00 299.99 399.92 499.76 599.43 698.41 796.39 892.54 -33 O0 67 O0 166 99 266 92 366 76 466 43 565 41 663 759 0 0 N 0 0 E 0 22 N 54 26 W 0 22 N 58 56 W 1 11 N 71 10 W 2 46 N 83 25 W 3 37 N 86 46 W 5 56 N 89 8 W 9 58 N 89 49 W 39 13 32 N 89 30 W 54 18 3 N 89 37 W 0. O0 0. O0 0.52 1.42 5,03 10.64 ,18,67 32,77 52.67 80.04 0 O0 0 O0 0 O3 I 74 0 34 I 24 4.22 ,2.43 3.98 2.65 0 O0 N 0 O0 N 0 33 N 0 76 N 1 28 N 1 76 N 2 O1 N 2 08 N 2 26 N 241N 000 E 000W 0 51 W 140W 500W 10 61 W 18 63 W 32 74 W 52 64 W 80 01 W 0.00 N 0 0 E 0.00 N 54 27 W 0.61 N 57 13 W 1.59 N 61 31W 5.16 N 75 40 W 10.75 N 80 34 W 18.74 N 83 50 W 32.80 N 86 22 W 52.69 N 87 32 W 80.04 N 88 16 W 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 987 O1 O0 1080 O0 1172 O0 1263 O0 1353 O0 1441 O0 1525 O0 1606 O0 1681 O0 1750 854.01 20 7 20 947.20 22 16 28 1039.28 23 38 41 1130.41 25 5 22 1220.22 27 6 08 1308.08 30 2 84 1392.84 34 1 44 1473.44 38 50 59 1548.59 43 44 84 1617,84 48 25 N 89 0 W 112.80 N 88 7 W 149.07 N 86 50 W 188.05 N 85 36 W 229.17 N 84 35 W 273.06 N 84 27 W 320.64 N 85 4 W 373.51 N 84 58 W 432.52 N 86 13 W 498.33 N 87 46 W 570.39 2 69 1 21 I 35 1 73 2 03 3 61 3 93 5.44 4.73 3.81 2.83 N 112 77 W 112 80 N 88 34 W 3.73 N 149 5.47 N 187 8.19 N 229 11.98 N 272 16.58 N 320 21.47 N 373 26.57 N 432 31.84 N 497 35.56 N 569 02 W 149 98 W 188 05 W 229 86 W 273 35 W 320 14 W 373 05 W 432 76 W 498 75 W 570 07 N 88 34 W 06 N 88 20 W 19 N 87 57 W 12 N 87 29 W 78 N 87 2 W 76 N 86 42 W 87 N 86 29 W 78 N 86 20 W 86 N 86 26 W 2000 O0 1814 58 1681 58 52 18 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1872 O0 1925 O0 1972 O0 2013 O0 2051 O0 2088 O0 2126 O0 2165 O0 2205 93 1739 74 1792 94 1839 90 1880 29 1918 67 1955 58 1993 36 2032 06 2072 93 56 15 74 59 55 94 63 56 90 67 27 29 68 9 67 67 57 58 67 31 36 66 50 06 66 26 N 88 13 W 647.41 N 88 15 W 728.58 N 88 13 W 813.47 N 88 36 W 901.60 N 88 30 W 992.80 N 88 17 W 1085.55 N 88 6 W 1178.29 N 88 9 W 1270.82 N 88 17 W 1362.99 N 88 27 W 1454.77 3 76 3 7O 3 23 4 07 2 59 0 37 0 45 0 55 0 73 0 45 38 21 N 646 74 W 647 86 N 86 37 W 40 68 N 727 88 W 729 43 33 N 812 72 W 813 45 87 N 900 82 W 901 48 og N 992 O0 W 993 50 71 N 1084 71 W 1085 53 70 N 1177 41 W 1178 56.76 N 1269 90 W 1271 59.66 N 1362.02 W 1363 62.30 N 1453.77 W 1455 O1 N 86 48 W 88 N 86 57 W 99 N 87 5 W 16 N 87 13 W 89 N 87 19 W 63 N 87 23 W 16 N 87 26 W 33 N 87 30 W 10 N 87 33 W 3000.00 2244 56 2111.56 67 26 3100,00 2282 3200.00 2321 3300.00 2360 3400.00 2399 3500.00 2439 3600.00 2480 3700.00 2521 3800.00 2562 3900.O0 2601 60 2149 60 67 29 32 2188 32 67 2 42 2227 42 66 52 74 2266 74 66 46 52 2306 52 66 16 40 2347 40 65 36 95 2388.95 65 17 57 2429.57 67 5 34 2468.34 67 1 N 88 50 W 1546 63 N 89 6 W 1639 N 89 7 W 1731 N 89 8 W 1823 N 89 6 W 1915 N 89 2 W 2007 N 89 3 W 2098 N 89 6 W 2189 N 89 50 W 2280 S 89 54 W 2372 11 31 35 29 04 30 26 62 78 1 97 0 59 0 34 0 22 0 20 0 82 0 23 0 83 1 72 0 47 64.58 N 1545 60 W 1546 95 N 87 36 W 66.17 N 1638 07 W 1639 67.61 N 1730 26 W 1731 69.03 N 1822 29 W 1823 70.44 N 1914 22 W 1915 71.97 N 2005 95 W 2007 73.50 N 2097 21W 2098 75.01 N 2188.15 W 2189 75.99 N 2279.52 W 2280 75.99 N 2371.69 W 2372 41 N 87 41W 58 N 87 46 W 59 N 87 50 W 52 N 87 54 W 25 N 87 57 W 49 N 88 0 W 44 N 88 2 W 78 N 88 5 W 91 N 88 10 W ARCO ALASKA, INC. 2a - 21 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 26-0CT-93 PAGE 2 DATE OF SURVEY: 14-0CT-1993 KELLY BUSHING ELEVATION: 133.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 2640 75 2507 75 66 35 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 2680 O0 2721 O0 2760 O0 2798 O0 2837 O0 2876 O0 2916 O0 2957 O0 2998 86 2547 86 66 7 44 2588 44 66 10 45 2627 45 67 45 43 2665 43 67 27 19 2704 19 67 8 40 2743.40 66 42 34 2783.34 66 16 02 2824.02 65 40 27 2865.27 65 44 S 89 49 W 2464 66 S 89 45 W 2556 S 89 46 W 2647 S 89 57 W 2739, S 89 45 W 2832 S 89 43 W 2924 S 89 34 W 3016 S 89 21W 3507 S 88 58 W 3199 S 88 34 W 3290 23 6O 65 12 27 24 87 16 17 0 5O 0 43 · 1 17 0 35 I O7 0 O2 0 42 0 47 I 22 0 23 75 76 N 2463 60 W 2464 77 N 88 14 W 75 74 74 74 74 73 72 71 69 40 N 2555 98 N 2646 78 N 2738 55 n 2831 06 N 2923 51N 3015 61N 3107 32 N 3198 28 N 3289 21W 2556 60 W 2647 67 W 2739 18 W 2832 36 W 2924 35 W 3016 02 W 3107 36 W 3199 44 W 3290 32 N 88 19 W 66 N 88 23 W 69 N 88 26 W 16 N 88 29 W 30 N 88 33 W 25 N 88 36 W 87 N 88 40 W 16 N 88 43 W 17 N 88 48 W 5000 O0 3039 26 2906 26 65 55 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 3079 O0 3118 O0 3155 O0 3193 O0 3230 O0 3267 O0 33O3 O0 3338 O0 3374 75 2946 19 2985 93 3022 52 3060 70 3097 19 3134 22 3170 86 3205 02 3241 75 66 35 19 67 51 93 67 52 52 68 1 70 68 24 19 68 46 22 68 57 86 69 15 02 69 36 S 88 33 W 3381 28 S 88 55 W 3472 62 S 89 41W 3564 89 S 89 28 W 3657 46 S 89 21 W 3750 07 N 89 10 W 3842 87 N 88 0 W 3935 97 N 87 55 W 4029.24 N 87 49 W 4122.67 N 87 42 W 4216.27 0 31 2 3O 0 5O 0 22 0 3O 3 04 0 3O 0 3O 0 12 0 42 66 96 N 3380 62 W 3381 28 N 88 52 W 64 63 63 62 61 64 67 71 75 82 N 3472 87 N 3564 17 N 3656 2O N 3749 89 N 3842 61N 3935 92 N 4O28 44 N 4122 10 N 4215 03 W 3472 34 W 3564 94 W 3657 60 W 3750 43 W 3842 49 W 3936 71W 4029 08 W 4122 63 W 4216 64 N 88 56 W 91 N 88 58 W 49 N 89 1W 12 N 89 3 W 93 N 89 5 W 02 N 89 4 W 29 N 89 2 W 70 N 89 0 W 3O N 88 59 W 6000 O0 3408 64 3275.64 69 51 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 3442 O0 3477 O0 3513 oo 3552 O0 3591 O0 3631 O0 3670 00'3710 O0 3749 96 3309.96 70 1 13 3344.13 69 53 84 3380.84 67 3 92 3419.92 67 3 97 3458.97 66 57 16 3498.16 66 56 49 3537.49 66 44 03 3577.03 66 41 ;3 3616.65 66 37 N 87 31W 4310 06 N 87 22 W 4403 N 87 23 W 4497 N 87 23 W 4590 N 87 21W 4682 N 87 24 W 4774 N 87 24 W 4866 N 87 21W 4958 N 87 21W 5050 N 87 26 W 5142 96 92 90 92 94 92 83 66 45 0 31 0 10 1 11 1 34 0 O6 0 O7 0 11 0 33 0 O6 0 14 79 O1 N 4309 36 W 4310 08 N 88 57 W 83 87 91 96 100 104 108 112 117 21N 4403 54 N 4497 78 N 4589 03 n 4681 30 N 4773 46 N 4865 70 N 4957 98 N 5049 17 N 5141 19 W 4403 07 W 4497 98 W 4590 93 W 4682 89 W 4774 80 W 4866 64 W 4958 40 W 5050 12 W 5142 98 N 88 55 W 93 N 88 53 W 90 N 88 51W 92 N 88 49 W 95 N 88 48 W 92 N 88 46 W 84 N 88 45 W 66 N 88 43 W 45 N 88 42 W 7000 00. 3789 35 3656 35 66 37 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 3829 O0 3868 O0 3908 O0 .3947 O0 3987 O0 4026 O0 4065 O0 4104 O0 4143 O0 3696 68 3735 26 3775 72 3814 09 3854 36 3893 53 3932 59 3971 57 4010 O0 66 40 68 66 37 26 66 44 72 66 46 09 66 50 36 66 56 53 66 58 59 67 4 57 67 4 N 87 26 W 5234 20 N 87 29 W 5325 N 87 24 W 5417 N 87 22 W 5509 N 87 37 W 5601 N 87 38 W 5693 N 87 45 W 5785 N 87 50 W 5877 N 87 51W 5969 N 87 51W 6061 98 75 55 42 32 27 27 31 39 0 16 0 14 0 24 0 19 0 27 0 13 0 25 0 11 0 3O 0 32 121 30 N 5232 80 W 5234 21 N 88 40 W 125 129 133 137 141 145 148 152 155 37 N 5324 47 N 5416 68 N 5507 71N 5599 51N 5691 26 N 5783 78 N 5875 25 N 5967 74 N 6059 52 W 5325 22 W 5417 95 W 5509 75 W 5601 60 W 5693 49 W 5785 43 W 5877 42 W 5969 44 W 6061 99 N 88 39 W 77 N 88 38 W 58 N 88 37 W 45 N 88 35 W 35 N 88 35 W 31 N 88 34 W 32 N 88 33 W 36 N 88 32 W 45 N 88 32 W ARCO ALASKA, INC. 2A - 21 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 26-0CT-93 PAGE 3 DATE OF SURVEY: 14-0CT-1993 KELLY BUSHING ELEVATION: 133.00 ET ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 4182.41 4049.41 67 9 8100 8200 8300 8400 8500 86O0 8700 8800 8900 O0 4222 24 4089.24 66 8 O0 4262 O0 4303 O0 4344 O0 4385 O0 4427 O0 4468 O0 4509 O0 4550 81 4129.81 66 1 50 4170.50 65 51 47 4211.47 65 48 89 4252.89 65 24 26 4294.26 65 47 37 4335.37 65 35 68 4376.68 65 44 58 4417.58 65 57 N 88 4 W 6153 53 N 89 20 W 6245 N 89 16 W 6336 N 89 19 W 6427 N 89 32 W 6519 N 89 55 W 6610 S 89 41W 67Q1 S 89 41W 6792 S 89 21W 6883 S 88 50 w 6974 25 65 99 21 22 23 35 38 57 0.96 0.21 0 09 0 64 0 56 0 50 0 46 0 3O 0 73 0 46 159 05 N 6151 53 W 6153 59 N 88 31 W 161 03 N 6243 162 14 N 6334 163 33 N 6425 164 21N 6517 164 70 N 6608 164.49 N 6699 163.95 N 6790 163.20 N 6881 161.74 N 6972 23 W 6245 63 W 6336 97 W 6428 18 W 6519 20 W 6610 24 W 6701 40 W 6792 46 W 6883 70 W 6974 31 n 88 31W 70 N 88 32 W 04 N 88 33 W 25 N 88 33 W 26 N 88 34 W 26 N 88 36 W 38 N 88 37 W 40 N 88 38 W 58 N 88 40 W 9000 O0 4591.22 4458 22 66 14 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 4631.25 4498 O0 4671.64 4538 O0 4712.92 4579 O0 4754.78 4621 O0 4799.57 4666 O0 4847.04 4714 O0 4895.84 4762 O0 4945.20 4812 O0 4994.75 4861 25 66 37 64 65 44 92 65 34 78 64 38 57 62 27 04 61 0 84 60 38 20 60 12 75 60 28 S 88 27 W 7065 85 S 88 9 W 7157 S 88 25 W 7248 S 87 51W 7339 S 87 20 W 7430 S 89 27 W 7519 S 88 40 W 7607 S 87 28 W 7694 S 86 51W 7781 S 86 27 W 7868 36 72 67 29 60 55 70 44 03 0 57 0 31 0 41 0 94 3 44 1 83 I 18 1 O1 0 71 0.41 159.56 N 7064 05 W 7065 85 N 88 42 W 156 83 N 7155 153 151 147 145 143 140 136 131 97 N 7247 13 N 7338 10 N 7428 15 N 7518 71N 7606 81N 7693 48 N 7780 34 N 7867 65 W 7157 08 W 7248 11W 7339 85 W 7430 22 W 7519 21W 7607 45 W 7694 31W 7781 02 W 7868 36 n 88 45 W 72 N 88 47 W 67 N 88 49 W 30 N 88 52 W 62 N 88 54 W 57 N 88 55 W 74 N 88 57 W 50 N 89 0 W 12 N 89 3 W 10000 O0 5043 42 4910.42 61 41 10100 10200 10300 10400 10500 10600 10700 10800 10900 O0 5089 O0 5136 O0 5182 O0 5228 O0 5276 O0 5327 O0 5382 O0 5440 O0 5500 84 4956 84 62 31 17 5003 65 5049 93 5095 78 5143 88 5194 26 5249 15 5307 26 5367 17 62 20 65 62 15 93 62 33 78 60 11 88 58 13 26 55 46 15 53 19 26 52 26 S 87 10 W 7955 09 S 88 3 W 8043 S 88 3 W 8131 S 89 56 W 822O N 89 29 W 8309 N 88 49 W 8396 N 88 59 W 8482 N 89 22 W 8566 N 88 52 W 8648 N 89 17 W 8728 50 99 43 07 86 82 72 25 16 3 71 0 35 0 27 3 43 0 76 0 74 1 19 1 16 1 29 2 66 126 13 N 7954 21 W 7955 21 N 89 5 W 122 119 117 118 119 121 122 123 125 77 N 8042 72 W 8043 79 N 8131 29 W 8132 55 N 8219 80 W 8220 30 N 8308 45 W 8309 58 N 8396 23 W 8397 31 N 8482 17 W 8483 58 N 8566 06 W 8566 86 N 8647.58 W 8648 13 N 8727.48 W 8728 66 N 89 8 W 18 N 89 9 W 64 N 89 11W 29 N 89 11W 08 N 89 11W 03 N 89 11W 94 N 89 11W 47 N 89 11W 38 N 89 11W 11000 O0 5562.49 5429 49 50 40 11100 11200 11300 11400 11500 11600 117oo 11800 11839 O0 5627.27 5494 O0 5694.14 5561 O0 5763.10 5630 O0 5834 53 5701 O0 5907 55 5774 O0 5981 75 5848 O0 6057 56 5924 O0 6133 92 6000 O0 6163 70 6030 27 48 42 14 47 29 10 45 22 53 43 30 55 42 43 75 41 19 56 40 13 92 40 13 70 40 13 N 89 33 W 8806 43 N 89 53 W 8882 N 89 3 W 8956 N 84 9 W 9029 N 79 17 W 9098 N 77 35 W 9165 N 76 21W 9231 N 73 23 W 9295 N 73 23 W 9357 N 73 23 W 9381 60 92 25 68 81 47 O1 26 54 2 76 2 90 4 23 4 10 3 19 1 04 1 92 0 O0 0 O0 0 O0 125 98 N 8805.75 W 8806 66 N 89 11 W 126 126 130 140 154 169 187 205 212 59 N 8881 92 W 8882 46 N 8956 76 N 9028 82 N 9097 93 N 9164 86 N 9229 07 N 9293 55 N 9355 76 N 9379 27 W 8957 53 W 9029 75 W 9098 60 W 9165 96 W 9231 13 W 9295 O0 W 9357 13 W 9381 83 N 89 11W 16 N 89 11W 47 N 89 10 W 84 N 89 7 W 91 N 89 2 W 52 N 88 57 W 02 N 88 51W 26 N 88 44 W 55 N 88 42 W COMPUTATION DATE: 26-0CT-93 PAGE 4 ARCO ALASKA, INC. 2A - 21 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 14-0CT-1993 KELLY BUSHING ELEVATION: 133.00 FT ENGINEER: G. 'JOHNSON 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/IO0 FEET FEET FEET DEG MIN COMPUTATION DATE: 26-0CT-93 PAGE $ ARCO ALASKA, Inc. 2a - 21 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 14-0CT-1993 KELLY BUSHING ELEVATION: 133.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SE~ COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN O1 58 1681 56 2111 75 2507 26 2906 64 3275 35 3656 41 4049 22 4458 0 0 854 O1 20 7 58 52 18 56 67 26 75 66 35 26 65 55 64 69 51 35 66 37 41 67 9 22 66 14 ENGINEER: G. JOHNSON 0 O0 -133 O0 O0 987 O0 1814 O0 2244 O0 2640 O0 3039 O0 3408 O0 3789 O0 4182 O0 4591 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 lOO0 2OOO 3000 4000 5000 6000 7000 8000 9000 N 0 0 E 0.00 N 89 0 W 112.80 N 88 13 W 647.41 N 88 50 W 1546.63 S 89 49 W 2464.66 S 88 33 W 3381.28 N 87 31 W 4310.06 N 87 26 W 52~4.20 N 88 4 W 6153.53 S 88 27 W 7065.85 0.00 2 69 3 76 1 97 0 5O 0 31 0 31 0 16 0 96 0 57 0 O0 N 2 38 64 75 66 79 121 159 159 0 O0 E 83 N 112 21N 646 58 N 1545 76 N 2463 96 N 3380 O1N 43O9 30 N 5232 05 N 6151 56 N 7064 0 O0 N 0 0 E 77 W 112 74 W 647 60 W 1546 60 W 2464 62 W 3381 36 W 4310 80 W 5234 53 W 6153 05 W 7065 80 N 88 34 W 86 N 86 37 W 95 N 87 36 W 77 N 88 14 W 28 N 88 52 W 08 N 88 57 W 21 N 88 40 W 59 N 88 31W 85 N 88 42 W 10000.00 5043.42 4910.42 61 41 11000.00 5562.49 5429.49 50 40 11839.00 6163.70 6030.70 40 13 S 87 10 W 7955.09 N 89 33 W 8806.43 N 73 23 W 9381.54 3.71 2.76 O. OO 126.13 N 7954.21 W 7955.21 N 89 5 W 125.98 N 8805.75 W 8806.66 N 89 11 W 212.76 N 9379.13 W 9381.55 N 88 42 W COMPUTATION DATE: 26-0CT-93 PAGE 6 ARCO ALASKA, INC. 2A - 21 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY- 14-0CT-1993 KELLY BUSHING ELEVATION' 133.00 FT ENGINEER' G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 133 O0 233 O0 333 02 433 12 533 31 633 80 735 16 837 80 942 67 0 O0 -133 O0 133 O0 0 233 O0 100 333 O0 200 433 O0 300 533 O0 400 633 O0 500 733 O0 600 833 O0 700 933 O0 800 0 0 N 0 0 E O0 0 21 N 55 56 W O0 0 21 N 56 36 W O0 1 48 N 81 52 W O0 3 7 N 84 17 W O0 4 10 N 87 52 W O0 7 33 N 89 41W O0 10 45 N 89 25 W O0 15 20 N 89 40 W O0 19 I N 89 17 W 0 O0 0 17 0 69 2 24 6 70 12 89 22 63 '39 09 62 08 93 60 0 O0 0 O0 0 17 2 6O I 88 2 35 4 18 .2 39 5 43 2 17 0.00 N 0.12 N 0.44 N 0 95 N I 46 N 187 N 2 05 N 2 12 N 2 33 N 254 N 000 E 0 17 W 0 68W 222W 6 67 W 12 85 W 22 59 W 39 O6 W 62 04 W 93 57 W 000 N 0 0 E 0 0 2 6 12 22 39 62 93 21 N 55 32 W 81 N 57 9 W 41 N 66 53 W 83 N 77 41W 98 N 81 43 W 68 N 84 49 W 12 N 86 54 W 08 N 87 51W 60 N 88 27 W 1157 1266 1377 1490 1608 1734 1873 1049 16 1033 O0 22 1133 49 1233 34 1333 68 1433 65 1533 52 1633 41 1733 2030.56 1833 2214.56 1933 900 O0 21 17 O0 1000 O0 23 3 O0 1100 O0 24 32 O0 1200 O0 26 39 O0 1300 O0 29 43 O0 1400 O0 34 22 O0 1500 O0 40 33 O0 1600.00 47 17 O0 1700.00 53 30 O0 1800,00 60 24 N 88 37 W N 87 19W N 86 1 W N 84 46 W N 84 27 W N 85 7W N 85 7 W N 87 26 W N 88 17 W N 88 13 W 130.18 171 11 215 13 262 85 316 O1 378 35 454 52 550 67 671 79 826 08 2 73 1 18 1 73 I 93 3 30 3 93 4 53 4.93 4.09 3.48 3 19 N 130.14 W 130 18 N 88 36 W 4 7 11 16 21 28 34 38 43 60 N 171.05 W 171 16 N 215.03 W 215 03 N 262.67 W 262 13 N 315.73 W 316 89 N 377.97 W 378 48 N 454.01W 454 73 N 550.05 W 551 96 N 671.11 W 672 72 N 825.34 W 826 11 N 88 28 W 15 N 88 6 W 90 N 87 36 W 15 N 87 5 W 60 N 86 41W 90 N 86 25 W 15 N 86 23 W 24 N 86 41W 49 N 86 58 W 2450.78 2033 O0 1900.00 68 11 2716 77 2133 297O 3229 3483 3726 3980 4228 4489 4741 25 2233 94 2333 77 2433 52 2533 46 2633 91 2733 21 2833 25 2933 O0 2000.00 67 26 O0 2100.00 66 54 O0 2200.00 67 3 O0 2300.00 66 23 O0 2400.00 65 27 O0 2500.00 66 40 O0 2600.00 66 41 O0 2700.00 67 8 O0 2800.00 66 4 N 88 23 W 1039 85 N 88 9 W 1286 N 88 38 W 1519 N 89 7 W 1758 N 89 2 W 1992 N 89 10 W 2213 S 89 5O W 2446 S 89 51W 2674 S 89 42 W 2914 S 89 15 W 3145 31 22 88 18 37 73 O9 34 58 0 89 0 74 I 98 0 22 0 49 1 44 0 42 2 31 0 O9 0 58 49.38 N 1039 03 W 1040 20 N 87 17 W 57.26 N 1285 63.96 N 1518 68.04 N 1757 71.71N 1991 75.38 N 2212 75.81 N 2445 74.88 N 2673 74.11N 2913 72.14 N 3144 38 W 1286 20 W 1519 83 W 1759 09 W 1992 26 W 2213 67 W 2446 10 W 2674 42 W 2914 76 W 3145 66 N 87 27 W 54 N 87 35 W 14 N 87 47 W 39 N 87 56 W 54 N 88 3 W' 84 N 88 13 W 15 N 88 24 W 36 N 88 33 W 59 N 88 41W 4984 66 3033 O0 2900 O0 65 52 5239 23 3133 5506 25 3233 5783 46 3333 6070 87 3433 6349 O0 3533 6604.70 3633 6858.01 3733 7110.09 3833 7362.69 3933 O0 3000 O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 3600 O0 3700 OO 3800 O0 67 48 O0 68 26 O0 69 14 O0 69 59 O0 66 58 O0 66 55 O0 66 39 O0 66 40 O0 66 47 S 88 33 W 3367 30 S 89 36 W 3601 N 88 58 W 3848 N 87 50 W 4107 N 87 25 W 4376 N 87 21W 4635 N 87 24 W 4871 N 87 24 W 5103 N 87 29 W 5335 N 87 32 W 5567 20 69 2O 6O 98 25 91 24 14 0 37 0 25 2 95 0 03 0 32 0 40 0 18 0 19 0 2O 0 42 67 32 N 3366.63 W 3367 30 N 88 51 W 63 61 70 81 93 104 115 125 136 64 N 3600.67 W 3601 96 N 3848.25 W 3848 85 N 4106.63 W 4107 96 N 4375.85 W 4376 85 N 4635.03 W 4635 66 N 4870.13 W 4871 43 N 5102.61 W 5103 78 N 5333.77 W 5335 26 N 5565.49 W 5567 23 N 88 59 W 74 N 89 5 W 24 N 89 1W . 62 N 88 56 W 98 N 88 50 W 25 N 88 46 W 92 N 88 42 W 25 N 88 39 W 16 N 88 36 W COMPUTATION DATE: 26-0CT-93 PAGE 7 ARCO ALASKA, INC. 2A - 21 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 14-0CT-1993 KELLY BUSHING ELEVATION: 133.00 FT ENGINEER: G. JOHNSON 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 7616 93 4033 O0 3900 O0 66 56 7872 8126 8372 8613 8856 9104 9348 957O 9775 87 4133 57 4233 01 4333 98 4433 90 4533 39 4633 36 4733 89 4833 40 4933 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 67 4 O0 66 5 O0 65 49 O0 65 51 O0 65 52 O0 66 35 O0 65 21 O0 61 19 O0 60 18 N 87 48 W 5800 85 N 87 50 W 6O36 N 89 20 W 6269 N 89 31W 6493 S 89 40 W 6713 S 89 4 W 6935 S 88 8 W 7161 S 87 25 W 7~83 S 88 54 W 7582 S 87 0 W 7760 41 55 67 97 26 38 57 O7 14 0.18 O. 23 0.24 0.41 O. 33 O. 62 0.43 1.19 1 · 45 0.81 145.87 N 5799 05 W 5800 89 N 88 34 W 154.79 N 6034 161.31N 6267 164.00 N 6491 164.42 n 6711 162.48 N 6933 156.70 N 7159 149.31N 7382 144.26 N 7580 137.63 N 7758 48 W 6036 53 W 6269 65 W 6493 99 W 6714 37 W 6935 67 W 7161 07 W 7383 72 W 7582 98 W 7760 46 N 88 32 W 61 N 88 32 W 72 N 88 33 W O0 N 88 36 W 27 N 88 39 W 38 N 88 45 W 58 N 88 50 W O9 N 88 55 W 2O N 88 59 W 9978 23 5033 O0 4900 O0 61 9 10193 10408 10609 10787 10953 11108 11256 11397 11534 17 5133 84 5233 71 5333 97 5433 04 5533 69 5633 85 5733 89 5833 54 5933 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 oo 62 19 O0 62 3O O0 58 7 O0 53 32 O0 51 26 O0 48 29 O0 46 16 O0 43 31 O0 42 21 S 86 44 W 7936 03 S 88 4 W 8125 95 N 89 29 W 8316 91 N 89 3 W 8491 07 N 88 50 W 8638 57 N 89 22 W 8769 88 S 89 57 W 8889 13 N 86 18 W 8998.40 N 79 23 W 9097.24 N 77 24 W 9188.71 2.37 0 23 1 O9 1 17 2 10 1 O6 3 15 4 O3 3 26 1 22 127 16 n 7935 13 W 7936 14 N 89 5 W 119 118 121 123 125 126 128 140 159 99 N 8125 37 N 8316 45 N 8490 67 N 8637 63 N 8769 61N 8888 14 N 8997 55 N 9096 98 N 9187 25 W 8126 29 W 8317 41W 8491 91W 8638 21W 8770 46 W 8889 73 W 8998 32 W 9097 39 W 9188 14 N 89 9 W 13 N 89 11W 28 N 89 11W 79 N 89 11W 11 N 89 11W 36 N 89 11W 64 N 89 11W 40 N 89 7 W 79 N 89 0 W 11667.78 6033.00 5900.00 40 27 11798.80 6133.00 6000.00 40 13 11839.00 6163.70 6030.70 40 13 N 74 17 W 9274.62 N 73 23 W 9356.51 N 73 23 W 9381.54 2.71 0.00 0. O0 181.05 N 9272.87 W 9274.63 N 88 53 W 205.33 N 9354.26 W 9356.51 N 88 45 W 212.76 N 9379.13 W 9381.55 N 88 42 W ARCO ALASKA, INC. 2A - 21 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING GCT LAST READING PBTD 7" CASINg TD COMPUTATION DATE: 26-0CT-93 PAGE 8 DATE OF SURVEY: 14-0CT-1993 KELLY BUSHING ELEVATION: 133.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1286' FSL · 53' FEL, SEC14 TllN R8E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4793.00 11'692.00 11731.00 11819.0O 11839.00 2954.14 2821.14 6051.46 5918.46 6081.23 5948.23 6148.43 6015,43 6163.70 6030.70 7~.43 N 3191.98 W 185.39 N 9287.94 W 192.80 N 9312.31 W 209.06 N 9366.76 W 212.76 N 9379.13 W ARCO ALASKA, INC. 2A - 21 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER PBTD TD COMPUTATION DATE: 26-0CT-93 PAGE 9 DATE OF SURVEY: 14-0CT-1993 KELLY BUSHING ELEVATION: 133.00 FT ENGINEER: G. JOHNSON ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 1286' FSL & $3' FEE, SEC14 TllN R8E MEASURED DEPTH TMD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11731.00 6081.23 8948.23 192.80 N 9312.31 W 11839.00 6163.70 6030.70 212.76 N 9379.13 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 11839.00 6163.70 6030.70 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 9381.SS N 88 42 W DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. FIELD KUPARUK RIVER WELL 2A - 21 COUNTRY USA RUN I DATE LOGGED 14 - OCT - 93 DEPTH UNIT FEET REFERENCE 93483 All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not gu&rantee the accuracy or correctness of any Interpret&tions. and we shall not. excerpt In the case of gross or wllfull negligence on our part. be liable or r®sponslble for any loss. costs, darneg®e or expenses Incurred or sustained by anyone resulting from any interpretation made by any of our offtcel~, agents or employees. These interpretations ere also subject to our General Terms and Conditions as set out In our current price .~chedule. _L- 2A-21 .286'FSL, 53'FEL, SEC.14, T:Ir~'-'', R8E, 191) Hf~'~ "Z:ONTAL PROdECTZON 8000 reEF ee4.a;3 6OOO 4O00 2000 -2000 -4000 -6000 sou~-8000 -12000 -10000 -8000 -6000 SCALE = I / 2000 IN/FT .... '"~'i"~'"~ .... F'?"'~"'~ ...... 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N, R8E, UM) i ~TICAL PROJECT[O. 91.00 -4000 -2000 0 0 2000 4000 6000 G000 10000 12000 ......... ~ '~ ...... ~ ...... ~ ...... ~ ...... ~' '~ ~ '! ..... ........ ~ "~"i "~ ...... ~"'~ ...... ~'"~"!'"~" ~'~"~' ~;~ :;~ ~ ' :::: :::: ::: : :: :: : : i ~ ~i~ · ::: ~ ~.~.~ -}.~ ~--}---~-~--}-.-} ~--~ }-.~-~- ~.~ }--~ .... ~---~--[ ~ .-} }-}--}- -~-}-~ ~ ~-~--}---}.~ -}-~-h-F-...}--~---~-}--.i-~-.-h.-}-~-- -}---~-.}-~. ~ ~.-< ~ ~-: : ~ ........... :::: :::: :::: :::: ::;:,:::: :::: :::: ......... .................................... . '~'~'~-~ .... ?~'"~'-i ..... ~'-'}--'h} "i-~--} }'!"'~ ~'~'h'~ "~'}~ "~-~'~"i '~"~'~ .... }~"~"} '~"~}" ~'~'"~'~'~"~'} ~'~ : ..... :::: :::: :~:~ ~ ~:~ :~ [~i~ ~: ~: ~ ~ ~ :: : ' '?~"~-~ -~---?"~-"~ '"?--?"h-~ .... ?'*"~"~'-i--'~'-'~"~ .... ~--~'i"i .... ~-~-?~-'-~-~-';~ ..... ~"?~? '?'~'?"~ ..... ?'~ "h~"?"*''T"~'~'~ *~'~: ; --~-~---~---* .... ~---;--~---~ ..... ~.--~--~---~-- *--~ ~-~ .... ~-.-~---~---~---~.i--~---; ..... ~-~.--~-~ .... *--~ *--~ ..... ¢--~'-~-~---?~-'~'--~ ..... ¢--~--r~ --~-~--~.--~ ..... ¢---*--!.-~-- -~ ~--.~-¢.* - : · : * - ~ :.::: :::.:. . ...... ::::- ::;; .::.: .::::. .,. : : . . . 271.00 PROJECTION ON VERTICAL PLANE 91.00 271.~ ~ALED IN VERTICAL DEPTHS HOFUZ 9CALE = 1 / 2000 IN/FT ARCO Alaska, Inc. Date: N(~vember 5, 1993 Transmittal #: 8916 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2A- 17 Directional Survey 10-15-93 93481 2A-21 Directional Survey' 10-14-93 93483 2A-23 Directional Survey 10-15-93 93482 Acknowledged: · DISTRIBUTION: D&M State of,Alaska (2 copies) ARCO Alaska, Inc. Date: O~'tober 29, 1993 Transmittal #: 8907 RETURN TO: ARCO Alaska, Inc. A'i'TN: 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 q 3--\3'5 ,,/2A-21 Cement Evaluation Log CET X,2A-21 Cement Bond Log CBT,--' ,,/2A-17 Cement Evaluation Log CET,-- q,.3- ~o "-2A-17 Cement Bond Log CBTf z/2A-23 Cement Evaluation Log CET ~-ux~ ~2A-23 Cement Bond Log CBT 10-14-93 10-14-93 10-15-93 10-15-93 10-15-93 10-15-93 9900-11718 9900-11690 8300-9820 8300-9792 0500-11533 0500-11505 Receipt Acknowledge' Drilling NSK Date: MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSER VA TION COMMISSION TO: David ~ Chairman THRU: Blair Wondzell P.I. Supervisor FROM: Lou Grimaldi 1~ ~z~x Petroleum Inspector DA TE: September 17 1993 FILE NO: ABXJIQAB.DOC PHONE NO: 279-1433 SUBJECT: BOP Test Parker # 245 Arco well # 2A-21 Kuparuk River unit PTD # 93-133 Friday, September 17 1993 I witnessed the initial BOP test on Parker rig # 245, drilling Arco's well # 2A-21 in the Kuparuk river unit. The test went well with one failure observed, this being the isolation valve on the downstream side of the #2 manual choke on the choke manifold. The valve was greased but still would not hold pressure, a spare valve was brought up and installed. This valve tested "OK" and the rest of the test went smoothly with no other failures. The area surrounding the rig was neat and clean with good access provided. SUMMARY; I witnessed the initial BOP test on Parker rig # 245 in the Kuparuk River unit. One failure observed, Three hour's. Attachment: ABXJIQAB.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: DATE: SEPT-17-1993 Drlg Contractor: Parker Drilling Rig No. 245 PTD # 93-133 Rig Ph.# 659-7670 Operator: Arco Alaska Rep.: Mike Whiteley Well Name: 2A-21 Rig Rep.: Darrel Gladden Casing Size: 9 5\8 Set @ 4,792 Location: Sec. 14 T. 1 1N R. 8E Meridian UMIAT Test: Initial X Weekly Other Test MISC. INSPECWIONS: FLOOR SAFETY VALVE3: Location Gen.: OK Well Sign OK Upper Kelly / IBOP Housekeeping: OK (Gert) Drl. Rig OK Lower Kelly / IBOP Reserve Pit N-LA Ball Type Inside BOP Test Quan. Pressure P/F 1 300X.3000 P i 300\3000 P I 300~3000 P I 300\3000 P 1 300~3000 P 1 300~3000 P 2 300\3000 P NXA NLA N~ CHOKE MANIFOLD: No. Valves I6 I No. Flanges 38 Manual Chokes 2 Hydraulic Chokes 1 ACCUMULATOR SYSTEM: BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Qu an. Pressure P/F 1 300\3000 P 1 300\3000 P 1 300\3000 P 1 300\3000 P Test Pressure P/F 300\3000 F 300\3000 I System Pressure 3,000 [ P Pressure After Closure 1,600 [ P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure 0 minutes 25 sec. Trip Tank P P System Pressure Attained 2 minutes 28 see. Pit Level Indicators P P Blind Switch Covers: Master: X Remote: X Flow Indicator P P Nitgn. Btl's: SIX BOTTLES Gas Detectors P P 2400 PSI Psig. Number of Failures: 1 ,Test Time: 3.0 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within 1 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: #1 ISOLATION VALVE DOWN STREAM OF MANUAL CHOKE REPAIRED AND RETESTED "OK" "GOOD TEST" Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File e - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R Grimaldi\Darrel Gladden FI-021L (Rev. 7/19) ABXJIQAB.XLS WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 10, 1993 A W McBride, Area Drlg Engr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 2A-21 ARCO Alaska Inc 93-133 1286'FSL, 53'FEL, Sec 14, T11N, R8E, UM 1488'FSL, 1087'FWL, Sec 15, T11N, R8E, 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. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of injection wells must be demonstrated under 20 AAC 25.412 and 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and 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 tests. Notice may be given by contacting the Commission at 279-1433. David ~/...Joh nston Chairman BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl ,*-'~, STATE OF AI_AS~ ..... AL/- A OIL AND GAS CONSERVATION COMMISi 'N' PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry ~ Deepen ~ Service X Development Gas E] Single Zone X Multiple Zone ~ 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 133', Pad 92' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25571,~ ALK 2669 - 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.O25) 1286' FSL, 53' FEL, SEC. 14, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1483' FSL, 1349' FWL, Sec. 15, T11N, R8E, UM 2A-21 #U-630610 At-total depth 9. Approximate spud date Amount 1488' FSL, 1087' FWL, Sec. 15, T11N, R8E, UM 9/1 3/93 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2A-09 11839' MD 3792' ~ TD feet 20.0' ~ 300' MD feet 2560 6176' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum holeangle 66.50o Maximumsurlace 1736 psig At total depth (TVD) 3293 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 47.0# L-80 BTC 2959' 41' 41' 3000' 2244' 410 Sx Arcticset III & HF-ERW 740 Sx Class G 12.25" 9.625" 36.0# J-55 BTC 1727' 3000' 2244' 4727' 2933' HF-ERW 8.5" 7" 26.0# L-80 BTCMOE 11798' 41' 41' 11839' 61 76' 160Sx ClassG 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 ~t/1~sl~d~e~l~ j ~ ~l~le Vertical depth Structural Conductor Surface Intermediate S E P - 3 1995 Production Liner .Alaska 0il & Gas Cons. Commission Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee X Property plat [] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot E] Refraction analysis [-] Seabed report [--~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ... /,~--£. [ ! / -,_- , Title Area Drilling Engineer Date Commission Use Only Number I APl number I Approval date See cover letter for Permi'm' '~ '- ) '~ ~I 5 0- J D.~ -- .3. 0 I ~ ~I ~'"' [~ -- ~ 3 other requirements Conditions of approval Samples required D Yes ~] No Mud log required E~] Yes [~ No Hydrogen sulfide measures [] Yes r~ No Directional survey required ~ Yes E] No Required working pressure forBOPE E] 2M ~;~ 3M [] SM [] 10M [] 15M Other: Original Signed By David W. Johnstor-, by order of Approved by Commissioner the commission Date I o , , , o , . , o 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2A-21 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4727')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 (11,839') 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. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve & NU tree assembly. Move in and rig up Nordic #1. Install and test mOPE. 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. s E P - 998 .~/aska Oil & Gas Cons. Commission Anchorage DRILLING FLUID PROGRAM Well 2A-21 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casinq 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 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% 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: Weight up to TD 11.3 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas.gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1736 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2A-21 is 2A-09. As designed, the minimum distance between the two wells would be 20' @ 300' 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 50-80 sec/qt to drill gravel beds. REE. EIVED s E P - Alaska 0il .& Gas 00ns. O0mm~Ss~o~ /~nchorage iCreated by : jones For: M ELMS iDote plotted : 2-Sep-95 iPIot Reference is 21 Version #3. iCoordinotes are in feet reference slot //21. iTrue Vert:icol Depths are reference wellhead. Baker Hughes INTEQ 9450 9000 8550 8100 7650 7200 6750 6300 I I I I I J I I I I I I I I I ! ANCO ALASKA, Inc Structure : Pad 2A Well : 21 Field : Kuporuk River Unit Locofion : North Slope, AloskaI 585O <-- West 5400 4950 4500 4050 3690 51,50 270'0 2250 1800 1350 I t I I I 1 I I I I I I I I I I I I I I Scole 1 : 225.00 90O 450 0 I TD LOCATION: I 1489' FSL, 1086' FWL SEC. 15, T11N, RSE 450 _ 900_ _ 1800_ _ _ 2700_ _ 5150_ _ 4050 _ _ 450O_ _ 4950_ - 5400_ _ 685O_ - 630'0 _ 450 0 450 Scale 1 : 225.00 TARGET LOCATION: 483' FSL, 1349' FWL SEC. 15, 111N, RSE TARGET 1VD=5863 TMD=11431 DEP=9160 NORTH 197 WEST 9158 N 88.77 DEG W 9160' (TO TARGET) JSURFACE LOCATION:I 1286' FSL, 55' FEL SEC. 14, T11N, RSE RKB ELEVATION: 133' KOP TVD=300 TMD=300 DEP=O 6.00 ~ 12.00 "~ I8.00 BUILO 3 OEO / 100' t 24.00 k 50.00 56 O0 4 ~ ' B/ PERMAFROST TVD=1493 TMD=1589 DEP= 18 ~ 42,00 T/ UGNU gl-IDS TV0=1613 TMD=1748 DEP=523 xQ%° °.oo TVD;2OSl TMO=.17 DEP=1148 T/ W SAK SNDS TVD=2233 TMD=2972 DEP=1566 ~B/ W SAK SNDS TVD=2735 TMD=4226 DEP=2716 K-lO TVD=2958 TMO=47.~9_O DEP=3233 ~ 9 5/8" CSG PT TVD=2933-"~;472_... g DEP=3176 K-5 TVD=4333 TM0=8239 DEP=6396~. TARGET ANGLE 40 DEG A 450 J I o Z 0 S E P - 3 !99 A!aska Oij & Gas Cons. Commission Anchorage MAXIMUM ANGLE 66.5 DEG BEGIN ANGLE DROP TVD=5077 TMD=IOI05 DEP=8108'~'"--~ 66.~00 "~ 38.00 DROP 2 D£G / 100' ~ 5%~?00 ~ '46.00 42 O0 TARGET (EOD) TVD=5863 TMD=I1431 DEP=9160 ~ · B/ KUP SNDS TVD=6023 TM0=11659 0EP--9294~ '~,,,~' TD - 7" CSG PT TVD=6176 TMI)=IIB39 DEP=9423 x~ VerJical Section on 271.23 azimuth with reference 0.00 N, 0.00 E from slot #21 900 1 50 18 22 0 2700 3150 36 0 4 50 45 49 0 5400 58 0 6300 6750 72 78 8100 8 50 90 9450 500 450 400 I I. I J.,, I 350 300 I I I. I I , 250 I Wesf 200 ARCO ALASKA, Inc. Structure : Pad 2A Well: 21 Field : Kuparuk River Unit Location : Noflh Slope, Alaska 150 Scale 1 · 50.00 1 O0 50 0 50 I I I ~ '~010700 ~oo 1 2100 2300 7OO 200 ' _ 150 _ lO0 _ 5O _ 0 _ 5O _ 100 _ 150 _ 200 A Z 0 0 0 1000 950 900 85O 800 750 West 700 65O 600 Scale 1 · 50.00 55O 50O 450 2O0 2~00 ¢¢ II 2100 150 100 )A I I 5O Z 0 e~ 100 V ARCO ALASKA, Inc. Structure : Pad 2A Well : 21 Field : Kuparuk River Unit Location : North Slope, Alaska 200 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 2A-21 4,727 ft 2,933 ft 11,839 ft 6,176 ft 2,971 ft 11,430 ft 5,863 ft 3293 psi ** See Page 4 I For Casing Choices 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe {(13.5'0.052)-0.11}*TVDshoe 2,933 ft 1,736 psiI Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =[ 3,293.0 ppg 5,863 ft 150 psi 11.3 PPgl Design lead bottom 500 ft above the Top of West Sak = 2,471 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 774 cf Excess factor = 15% Cement volume required = 890 cf Yield for Permafrost Cmt - 2.17 Cement volume required =[ 410 sxI Surface tail: TMD shoe = 4,727 ft (surface TD - 500' above West Sak) * (Annulus area) = 707 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4110 cf/If Cmt required in casing = 33 cf Total cmt- 739 cf Excess factor = 15% Cement volume required = 850 cf Yield for Class G cmt = 1.15 Cement volume required =[ 740 sxI RECEIVED $ E P - 3 199, Alaska 0il & Gas Cons. OommissiO~ Anchorage Casing Design/Cement Calculations Production tail: 2-Sep-93 TMD = 1'1,839 ft Top of Target, TM D = 11,430 ft Want T©C 500' above top of target = 10,930 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 159 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 176 cf Excess factor = 15% Cement volume required = 202 cf Yield for Class G cmt - 1.23 Cement volume required =l 160 sxJ TENSION - Minimum Design Factors are: T(pb)=1.5 and T(js)=1.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy - Weight of displaced mud Length Casing Wt (Ib/ft) Dead Wt in Air Buoyancy Tension (Pipe Body) Design Factor 1086000 lb 4,727 ft 47.00 Ib/ft 222169.0 lb 37635.2 lb 184533.8 lb Surface (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 =[ 1161000 lb 4,727 ft 47.00 Ib/ft 222169.0 lb 37635.2 lb 184533.8 lb 6.31 Production (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 (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =1 604000 lb 11,839 ft 26.00 Ib/ft 307814.0 lb 52428.0 lb 255386.0 lb 2.41 Production (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) = 667000 lb 11,839 ft 26.00 Ib/ft 307814.0 lb 52428.0 lb 255386.0 lb 2.61 Alaska Oij & Gas Cons. Cornrnission Anchorage Casing Design / Cement Calculations BURST - Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =[ Production Csg: 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 Design 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 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 =[ 2-Sep-93 6870 psi 1736.3 psi 4.01 7240 psi 7127 psi 2858 psi 4269 psi 4750 psi 0.587 Ib/ft 786 psi 6.01 5410 psi 0.587 Ib/ft 3627 psi 1.5J REEE VED s E P - 5 t99 Alaska Oil & Gas (:;oas. Anchorage Casing Design / Cement Calculations 2-Sep-93 Surface Casing Choices OD ID Ib/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 Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi Burst 7240 psi P -- 3 i993 Gas Cons. Commission KUPARUK RIVER 20" DIVERTER SCHEMATIC 6 3 ! 5 I_-I i DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANGE & OPERATION . . UPON INmAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENTTHAT 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' CONDLICTOR 2. SUP-ON WELD STARTING HEAD 3. DIVEFITER ASSEMBLY wrrH ONE 2-1/16'- 2000 PSI BALL VALVE 4. 20' - 2000 PSI DRILMNG SPOOLWITH TWO 10' OUTLETS. 5. 10' HCR BALL VALVES WlTH 10' DIVERTER MNES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTRO~ i ;=n TO ACHIEVE DOWNWIND DIVERSION 6. 20' - 2000 PSI ANNULAR PREVEN'FER S E P - t~ 199;~ Alaska Oil & Gas Co,is. ~;ommissior~ A~choraga < < 7 5 I 2 13 5/8" 5000.=SI BOP STACK AOCUMULATOR cAPAcrTY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE I$ 3000 PSI WITH OBSERVE TIME, THEN Ct.OSE ALL UNITS SIMULTANEOUSLY AND IS 45 SECX)NDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 1. FILL BOP STACK AND MANIFOLD WiTH WATER. 2. CHECK THAT ALL HOI. D-[XTWN 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 3¢X)0 PSI AND HOLD FOR 10 MINUTES. _m m:n TO ZEF~3 PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7. TEST TO 250 PSI AND 30(X) PS! AS IN STEP 4. CONTINUE TESTING ALL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT I$ NOT A FULL CLOSING PosmVE SEAL CHOKE. & OPEN TOP PIPE RAMS AND CLOSE Bo'FrOM PIPE RAMS. TEST SC'FrOM RAMS TO 2-~0 PSI AND ~000 P~. 9. OPEN PIPE RAMS. BAOKC)FF RUNNING ,Jr AND PULI. OUT OF HOLE. CLOSE BLIND RAMS AND TESTTO ~ PSi FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINE~ ARE FUll. OF ARCTIG DIESEL AND ALl. VALVES ARE ,SET IN THE DRIELIN~ POSITION. 12. 'lE,.~r KELLY OOGK$ AND INSIDE BOP TO ~:]00 PSI WITH KOOMEY PUMP. 1~. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM OOMPLETE BOPE TEST ONCE A WEEK AND FUNGTIONAI. J.Y OPERATE BOPE DAILY. 1. 16' - 2000 PSI STARTING HEAD 2. 11" - 3{XX) PSI CASING HEAD 3. 11' - 3{X}0 PSI X 13-5~'6- - 5000 PSI SPACER SPCX~ 5. 13-5f8". ~_~O~__ PSI DRLG SPCX:X. W/ CHOKE AND KILL UNES 6. 13-5/8' - 5lX}O PSI DOUBLE FLa~ WI PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR RE, E VED S E P - ~ ~9~ .Alaska .Oil .&" 6as Co~s, Corr~missio~ Anchorag~ ITEM (1) Fee (2) Loc :::: CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE ' u8] (3) Admin (4) Casg le 5. 6. 7. 8. (5) BOPE [8] t 9. [9 thru 13] ?-/ 10. [10 & 13] 12. %/ ~.~ 13. [14 thru 22] 15. [23 thru 28] 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company (~ ~,,~0 Lease & Well YES Is permit fee attached ............................................... ~,~ Is well to be located in a defined pool .............................. ~ Is well located proper distance from property line ................... '~ · Is well located proper distance from other wells ..................... ~A Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ......................... ' ............. Is administrative approval needed .................................... Is 1 ease nLrnber appropriate .......................................... Does well have a unique name & nLrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. 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 ~~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas.probable ...................................... NO REMARKS (6) Other \~-~ ~ ~%) [29 thru 31] (7) Contact [32] (8) Addl 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 nLrnber of contact to supply weekly progress data ...... Additional requirements ............................................. geo 1 ogy ' en9 i nee r i nq: Rp~. MTM ~- RAD~ ~' c~ TAB~~2/~/9~ rev 6/93 jo/6.011 INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA SHORE o I & Additional remarks' UM X Exp/Dev Inj .~ MERIDIAN' SM WELL TYPE: Redrill Rev 0 ---I ZEZ "'~0 ~'"t 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 effod has been made to chronologically organize this category of information. * ALASKA COmPUTiNG CENTER , * ****************************** ******************************* FIELD NAME : KUPARUK RIVER BOROUGH t NORTH SLOPE STATE API NUMBER : 50-103-20192 REFERENCE MO : 9345~ R EEEIVED ,.lAN 1 8 t994 Anchorage IS Tape Verification I.,isttnq cblumberger Alaska Comput~nq Center 7-DEC-],gg3 ~3:~3 **** REEL HEADER **** SERVICE NAME : EDIT DATF : 93112/ 7 ORIGIN : FL!C REEL NAME : 9345~ CONTINUATION # ~ P~EVIOU$ REEL : COMMENT : ARCO ALASKA, INC.,KUDARUK RIVER UNIT, ~A-21,50-I03-20192-00 ~*** TAPE HEADER SERVICE NAME : EDIT DATE : 93112/ 7 O~IGIH : FLIC TAPE NAME ~ 9345~ CONTI. NUATION # : P~EVIOUS TAPE COMMENT : ARCO ALASKA, INC.,KUPARUK RIVER UNIT, TAP~ HEADER KUP~RUK RIVER MWD/MAD LOGS WELL NAPE: A~I NUMBER: OPERATOR: LOGGING COMPANY: !rAp~ CREATION DATE: ~OB DATA JO~ NUMBER: LOGGING ENGINEER: OPERATOR SURFACE 50CATION 8ECTION~ TOWNSHIP: RANGE: FNL: FSL~ FEL: FWb: ' ELEVATIONCFT FROM MSL O) KELLY BUSHING: DERRICK F~OOR: GROUND LEVEL~ BIT RUN 93452 G, JOMNSO M, WHITELEY # WEb[,, CASING RECORD STRING STRING 2A 2 so;oi2o o ARCO ALASKA, INC,': SCHLUMBERGER 6-DF.C,,93 BIT RUN 93452 ~, JOHNSON M, WHITELEY BIT RUN 3 14 I!N 120:0 133,00 133~00 92'00 ()PEN H · OLE CASING DRILLERS BIT SIZE (i~ SIZE (IN) DEPTH 9,625 4793,0 8.500 7,000 11819,0 PAGE: IS Tape verification Listing 7-DEC-1993 cblumberger Al, asEa Computing Center 3RD STRING PRODUCTION STRING REMARKS: HMLLO ************** RUN t ************* RG$ RP TO BIT: 68 61FT ND$ RP TO BIT: 13{,86 FT DEN TO BlT: 133.17 FT N~UT TO SIT: 140.~1 ET DRILLED INTERVAL: 4792 11149 FT **,***********RUN 2'***~********** RGS RP TO BIT 29.62 FT, NDS RP TO BIT 52,07 DENS TO BIT 53,38 FT. NEUT TO BIT 60,32 FT. BIT TO GR 36,87 FT. DRILLED INTERVAL 11149 ' 11839,25 FT. ~AXIMUM HOLE ANGLE 69.97 HOLM ANGLE AT TD ~0,00 DE~, ~ ~8~9'00, BARRITE ADDED TO MUD SYSTEM DATA FROM DOWNHObE MEMORY TAB TA.K~N AT RES &,DEN SEAS.: POINT SLIDING INDICATOR SHOWN IN DEPTH TRACK $ ~!S FORMAT DATA **** FILM HEADER **** FILE NAME : EDIT ,001 SERVICE : FLIC 'VERSION : 001C01 D~TM : g3/i~/ 7 M~X R~C SIZE : 1024 FILM TYPE ~ LO LAST FILE : PAGE: EDITED ~ERGED MWD Depth sblft, ed and cl~,~ed Curves; all bit. runs meroed, DEPTH INCREMENT~ 0'5000 ' # FILM SUMM~RY LDWG.TOOL CODE START DEPTH CDR 4730,0 CDM 4650,0 s BASELINE CURVE FOR SHIFTS: GR STOP DEPTH ~1839,0 !.!830,0 IS Tape yerificatlon Listing Cblumberger Alaska Computing Center 7-DEC-t 993 13:13 PAGE{ CURVE SHIFT DATA (~.:~ASURED DEPT~) # .... -- .... EQUIVALENT UNSHIFTED DEPTH---------- RASELINE D[<PTH 1 1579,0 11500.0 I 142~ 0 11403!5 11397 0 1112g.0 111.08.5 110 ..,0 ] 1046'0 ~ 1038'°o25 10959'0 1093~ 0 10895 0 ~0814 0 ~0809 0 10801 5 10653 0 .1059O 0 1055! 5 !, 0225 5 10128 5 I, 0098 0 1.00!9 0 995 ~ 0 ! O0 0 MERCED DATA SOURCE LDWG TOOL CODE CD~ CDN CDR CDN $ ~8885.0 I1576,0 11497,0 11410 0 11401~0 11393,0 !1125.0 11110,0 11086.0 !1070.5 11045,5 1.1037 5 11023!5 }1005 0 0958'0 ~0930,0 ~0894.5 10814.0 10806.0 10800.5 10652'0 10588'0 10551,0 1022~,5 10!~ ,5 !00 ~.0 10019'5 9960.5 102,5 BiT ~UN NO,. ME~GE TOP 1 4730,0 I 4650,0 I 1 ,0 '° ~ERGE BASE t1~49.0 11149 0 J.!8~9 0 118 9 0 THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT MWD G~ TO W!R:ELINE CET/GR OF 14-0CT-1993, ALL OTHER CURVES WERE CARRIED WITH THE GR SHIFT, THE. VERY ENHANCED ORO PROCESSED RESISTIVITY DATA WITH A 2' AVERAGE IS CONTAINED IN THIS FILE, $ LIS FORMAT DATA IS Tape Verlficatton bistJ, nq chlumberger AlasKa Computln~, Center 7-DEC-1993 13:{3 PAGE: DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 3 73 68 4 66 5 66 6 73 7 65 8 68 0 5 l~ 66 !5 13 66 0 ~4 65 FT ~5 66 68 16 66 0 66 0 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmm ** SET TYPE - CMAN ** N~NM SERV UNIT SE~V!CE API API APl API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CSASS ~OD NUmB SA~P EbEM COD~ .(HEX) 000 O0 0 1 ~ I 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 i 1 ~ 4 68 0000000000 000 O0 0 1 1 ! 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 1 1 ! 4 68 0000000000 000 O0 0 I 1 ! 4 68 0000000000 000 O0 0 1 I I 4 68 0000000000 000 O0 0 I 1 ! 4 68 0000000000 000 O0 0 ~ 1 1 4 68 0000000000 000 O0 0 I 1 ! 4 68 0000000000 000 O0 0 1 1 ~ 4 68 0000000000 000 O0 0 1 I 1 4 68 0000000000 000 O0 0 I I ! 4 68 0000000000 000 O0 0 I 1 1. 4 68 0000000000 000 O0 0 I 1, I 4 68 0000000000 ** DATA ** TaPe Verification I.,lst~na ~hlumberger Alaska Computing Center ?-DEC-1903 13:!3 DEPT 11835.000 RHOf~.MWD -999.250 DRHO.MWD C~N'.M'WD -999,250 NP~I,NWD .-999.250 RA.MWD DER.~WD -999,250 VRP.~WD .999'250 V~A.~WD G~.MWD -999.250 NCNT.MWD ~1838,500 FCNT.MWD G~C~.CET -999.250 DEPT. 4569,500 RMOB.MWD C~LN.~WD -999.250 NPMI.MWD DEP MWD -999,250 VRP,MWD G~:MWD -999,250 NCNT,MWD GRC~.CET -999,250 ** E~D OF DATA -999.250 DRMO,MWD -999,250 RA,MWD -999.250 VRA.MWD 4567.500 FCNT,~WD -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 PEF.MWD RP.MWD ROP.MWD FET.MWD PEF. ~WO RP. EWD ROP. FET. MWD PAGE: -999,250 -999,250 23,053 -999*250 '999,250 '999'.250 '99. 250 **** FILE TRAILER **** FILE NAME : EDIT ,001 SERVICE : FLIC VERSION ~ 00~C01 DATE ~ 93/12/ 7 M~X REC SIZE : ~024 FILE TYPE ~ LO LAST FILE : **** FILE HEADER FIL~ NA~E : EDIT ,002 SERVICE : FLIC YER$I. ON : O01CO1 DATE : 93112/ 7 MAX REC SIZE : ~024 FILE TYPE : LAST FILE FILM NUMBER 2 RAW MAD Curves and lo~ header data for each bit run in separate BIT RUN NUMBER: ! DEPTH I~CRE~ENT: 0.5000 # F!bM SUMMARY X~DWG TOOL CODE CDN CD~ $ hOG HEADER DATA DATE LOGGED: START DE. TM STOP DEPTH 4650.0 11 t49,0 4730,0 11149,0 ~1-$EP-93 f i ! e s. IS Tame Verification blst~.ng cblumberger Alaska Computlno Center PAGEI SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (~EMORY or REAL-TIME): TD DRILLER TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED ~OLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOI~.' TYPE CDN NEUTRON/POROSITY CDR RESISTIVITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPT~ BORE~OLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY MUD FAST 2,4 V4.0C MEMORY 11839 3 4650~0 11839.0 70.0 TOoL NUMBER NDS022 ~GS022 4792.0 BRINE 11,30 MUD CHLORIDES (PPM): ~3000 FLUIDiLOSS (C~)~ ~PERATI.! 150.0 MAXIMJM RECORDE.. TE RE (DEGF): RESISTIVITY (OH~M) ~T TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (~T): 1,580 MUD AT MAX CIRCULATING TEMPERATURE MUD FILTRATE AT (MT): 1,.360 ~UD CAKE AT ~EUTRON TOOL MATRIX~ ~ATRIX DENSITY: HOLE COrRECTiON (IN): TO05 STANDOFF (IN): EWR FREQUENCY (HZ): FIELD REMARKS RGS RP TO BIT: 68,61FT NDS RP TO BIT: !,3!,86 FT DEN TO BIT:. ~33x17 FT N~UT TO BIT' l~u !~ FT DRILLED INT~RV~ 4792 - 1~!49 FT Tn 0.00 8 9.00. SANDSTONE 2.65 58,0 Tape Verification !,ist~,nn chlUmberger AlasKa Computing Center 7-DEC-1993 13~!3 TD ~ 01:00 ON 2l-8EP-93 BARPlTE ADDED TO PUD SYSTEM DATA FROM DOWNHObE mEMORY TAB TAKEN AT RES & DEW MEA8, POINT SLIDING INDICATOR SHOWN IN DEPTH TRACK $ bis FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET.TYPE - 64EE ** TYPE REPR CODE VAbUE t 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0 5 1~ 66 16 1~ 68 13 66 0 14 65 FT 1.6 66 1 0 66 1 ** SET TYPE - CHAN N~F SERV UNIT SERVICE API API APl API FILE NUMB NUMB SIZE REPR PROCES~ ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EhE'M~ CODE (HEX) DEPT FT 619109 O0 000 O0 0 2 1 I 4 68 0000000000 RHOB LWl G/C3 619109 O0 000 O0 0 DPH! LN~ PU 619109 O0 000 O0 0 2 1 D~HO LW] G/C3 619109 O0 000 O0 0 2 PEF LW1 BN/E 619109 O0 000 O0 0 2 DCAL L~I IN 619109 O0 000 O0 0 TNPH Lwl PU 619109 00 000 O0 0 2 1 ATR LWl OHMM 619109 O0 000 O0 0 2 1 PSR Lwl OH~M 619109 O0 000 O0 0 ~ 1 DER Lw! OH~M 619109 O0 000 O0 0 2 ROPE LWl F/HR 619109 O0 000 O0 0 G~ LWl GAPI 619109 O0 000 O0 0 2 1 HEN~ L'wl CPS 619109 00 000 O0 0 HEF~ LW~ CPS 619109 O0 000 O0 0 68 68 68 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 Tape Verffication Listing chlumberger Alaska Computing Center 7-DEC-~9g3 13:13 NAME 5RRV UNIT SERVICE API API AP1 API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMp ELEM CODE (HEX) TAB LW1 HR 619109 O0 000 O0 0 ~ ! 1 4 68 0000000000 ,T~BD LWl HR 619109 00, 000 O0 0 2 1 1 4 68 0000000000 DEPT PE~,LW1. PSR,L~I H~NA.LWI 1!148'000 RHOB*hWl -999.2~0 DPHX.LWI -999'250 DCA5.LW1 m999. 0 TNPH'LW1 -999,250 DER..LW1 Z999.~50 ROPE,LWt 11148*500 HEFA,~LWX 999.250 TAB,LW1 4567.000 RHOB,LW1 ~999.250 DPHI,bWX -999*250 DCAb,LW1 .999~50 TNPH,LW1 D~PT, PEF.LW! PS~,LWI HENA,LWl END OF DATA ~999.250 DRHO,LW! 99g.250 ATR.LW1 ,.303.840 -g9g.~50 TABD.LWi :g99.~50 DR.O.LW1 ggg, 50 ATR.LW1 -999.'250 GR.,LW! -999.~50 TABD,LWi -999.i250 -999~250 ~999 250 -999250 ~999 -999 250 ,:99 2$o · 999 250 **** FILE TRAILER **** FILE NAME ~ EDIT .002 $~RVlCE : gloIC 'VERSION g 001C01 DATE : 93/12/ 7 M~X AEC STZE : !024 FILE TYPE ~ LO LRST FILE : **** FILE HEADER **** FILE NAME ~ EDIT ,003 SERVICE : FLIC VERSION ~ O01CO! DATE : 93/1~/ 7 MRX REC SIZE ~ !.024 FILF TYPE : LO LAST FILE : FILE HEADER F!L~ NUMBER 3 R~W MAD Curves and log header data for' each bit run {n separate BIT RUN NUMBER: 2 "w : 5000 DEPTH INCREME..T O, files. IS Tav. e Verificat~on List]n~ chlUmberger Alaska Computing CeDter 7-DEC-1993 ~:13 PA~E~' FILE SUMMARY L. DWG TOOL CODE , D #o L.. G HEgDER DATA DATE LOGGED: SOFTWA~E~ START DEPTH 11149.0 !1149.0 STOP DEPTH 1183g,0 11839,0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TI~E): TD DRILLER (FT); TOP LO~ INTERVAL (FT): ~OTTOM hOG INTERVAL BIT ROTATING SPEED ~O[,E iNCLINATION (PEG) MINIMUM ANGLE~ M~XIMUM ANGLE: TOOL STRING (TOP TO BOTT:OM) VENDO~ TOOL CODE TOOL TYPE CON'''''''''''''''' ;~;;~;~ OROS!TY CDR RESI&TIVITY $ ~OREHOLE AND CASING DATA OPEN ~.,.,ObE'~ . DRIDLER$ CASING DEPTH ~OREHOLE CONDITIONS MIlD TYPE: MUD DENSI?Y MUD VISCOSITY (S)~ MUD PH~ MUD CHlORiDeS FLUID LOSS MAXIMUM RECORDED TEMPERATUR~ (DEGF): RESISTIVITY (OHMS] AT TEMPERATURE (DEGF): ~UD AT MEASUR.ED TEMPERATURE ~UD AT MAX CIRCULATING TEMPERATURE MUD FILTRATE AT (MT): MUD CAKE AT NEUTRON TOOh MATRIX: .MATRIX DENSITY: HOLE CORRECTION (IN): TO05 STANDOFF fiN): E~R FREQUENCY REMARKS: FIELD REMARKS 21-SEP-93 FAST 2,4 V4,0C ~EMORY 118393 4650i0 ~,1839 0 70.0 TOOL NUMBER NDSO~2 RGS022 4792.0 BRINE !,1,30 23000 !50.0 1,580 1,360 SANDSTON~ 2.65 62.0 Tame Verification Listin~ :hlumberqerAlaska Computina Center 7-DEC-~. 993 1~:1~ RGS RP TO BIT 2g.62 FT. NOS RP TO BIT 52.07 FT. DENS TO BIT 53.38 FT. NEUT TO BIT 60.32 FT. BIT TO GR 36.87 FT DRILLED INTERVAL 1{149 HOLE A, NGLE AT TD 40 O& DEC. 8 !18~ 00, TD 9 01:00 ON' 2~-SEP-93 BAR~ITE ADDED TO ~UD SYSTEM DATA FRO~ DOWNHOL,.~ ~EMOR¥ T~B TAKEN AT ~ES & DEN ~EA$. POINT SLIDING INDICATOR SMOWN IN DEPTH TR~C~ $ ibis FORMAT DATA 10 ** DATA .... FORMAT SPECIFICATION RECO. D~' ** SET T¥~PE - 64EB ** TYPE REP~.CODE VhLUE 1 66 0 2 66 0 ] 73 64 4 66 5 66 6 73 7 65 8 68 0 5 9 65 1! 66 1~ 68 13 66 14 65 15 66 68 ~6 66 0 66 ** SET TYPE -CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ED ORDE~ # LOG TYPE CLASS ~OD NUmB SAMP ELE~ CODE (HEX) DEPT FT 619109 O0 000 00 0 3 I 1 4 68 0000000000 RHOB LW~ G/C3 619109 O0 000 O0 0 3 1 1 4 68 0000000000 DPHI LW~ PU 619109 O0 000 O0 0 3 I 1 4 68 0000000000 I$ Tame verification t, istinq chlumberger AlasKa Computing Center 7-DEC-1993 13:~3 PAGE= t2 DAT~ : g311~1 7 TAP~ NA~E : 93452 C~NTINUATIO~ # P~EVIOUS TAPE CO~E~T **** REEL TRAILER **** DATF : 93/1~/ 7 O~IGIN : FLIC REEL NAME : 93452 CONTINUATION # = PREVIOUS REEL : COMMENT : ARCO ALASKA, INC,,KUPARUK RIVER UNIT, 2A-2i,50-103-20192-00
