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Home My WebLink About200-019MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, December 19, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2H-17 KUPARUK RIV UNIT 2H-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/19/2024 2H-17 50-103-20329-00-00 200-019-0 W SPT 5989 2000190 1500 1475 1475 1475 1475 290 310 310 310 4YRTST P Austin McLeod 10/31/2024 MITIA 30 MinPretest Initial 15 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 2H-17 Inspection Date: Tubing OA Packer Depth 870 2220 2160 2160IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM241031180545 BBL Pumped:0.5 BBL Returned:0.5 Thursday, December 19, 2024 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supervisor To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:Well Integrity Specialist CPF2 Subject:10-426 forms for 2H PAD ONLINE and SHUT IN MITIA"s 5-7-24 Date:Wednesday, May 8, 2024 10:10:38 AM Attachments:image001.png MIT KRU 2H-2,14A and 17 SI TESTS 05-07-24.xlsx MIT KRU 2H PAD 05-07-24.xlsx Good morning, Please see the attached 10-426 forms from the AOGCC witnessed MITIA’s that were performed on 5-7-24. If you have any questions please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .58+ 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1840730 Type Inj N Tubing 1810 1810 1810 1810 Type Test P Packer TVD 5904 BBL Pump 2.6 IA 330 3310 3250 3240 Interval V Test psi 3000 BBL Return 2.5 OA 20 20 20 20 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2150940 Type Inj N Tubing 1825 1825 1825 1825 Type Test P Packer TVD 5914 BBL Pump 2.7 IA 550 3300 3240 3220 Interval V Test psi 3000 BBL Return 2.6 OA 10 10 10 10 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2000190 Type Inj N Tubing 2300 2300 2300 2300 Type Test P Packer TVD 5978 BBL Pump 1.0 IA 650 3000 2960 2940 Interval 4 Test psi 1500 BBL Return 1.0 OA 140 150 150 150 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA to MAIP per AIO 2C.071 Notes: 2H-02 2H-14A Notes:MITIA to MAIP per AIO 2C.081 2H-17 Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 2H Pad Casey / Hills 05/07/24 Form 10-426 (Revised 01/2017)2024-0507_MIT_KRU_2H-pad_3wells 9 9 9 9 9 9 9 9 9 -5HJJ 2H-17 2000190 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. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2H-11 50-103-20052-00 185261_2H-11_SCMT Post-BiSN_22Aug2023 185261_2H-11_SCMT Pre-BiSN_27Jul2023 2H-12 50-103-20053-00 185262_2H-12_PPROF_01Jun2023 2H-17 50-103-20329-00 200019_2H-17_IPROF_01Jul2023 2K-07 50-103-20107-00 189071_2K-07_RBP_17Apr2023 2M-20 50-103-20169-00 192048_2M-20_LDL_30Mar2022 2M-29 50-103-20183-00 192097_2M-29_Patch_30Dec2022 2N-310 50-103-20549-00 207090_2N-310_CIBP_16Jul2023 2N-316 50-103-20342-00 200090_2N-316_EVO RPB_23Mar2023 200090_2N-316_LDL Caliper_02Sept2022 2N-329 50-103-20257-00 198067_2N-329_PLUG-LDL_03Mar2023 198067_2N-329_RST_31Dec2022 2T-14 50-103-20061-00 186044_2T-14_Patch_11Jun2022 2U-12 50-029-21304-00 185041_2U-12_LDL_06Aug2023 7of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38372 T38373 T38374 T38375 T38376 T38377 T38378 T38379 T383780 T38381 T38382 2/29/2024 2H-17 50-103-20329-00 200019_2H-17_IPROF_01Jul2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:56:50 -09'00' MEMORANDUM TO: Jim Regg P.I. Supervisor 5!1j'2ti� p FROM: Brian Bixby Petroleum Inspector Well Name KUPARUK RIV UNIT 2H-17 Insp Num: mitBDB200506061159 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 7, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2H-17 KUPARUK RIV UNIT 2H-17 Src: Inspector Reviewed B P.1. Suprv'j� IZ' Comm API Well Number 50-103-20329-00-00 Inspector Name: Brian Bixby Permit Number: 200-019-0 Inspection Date: 5/3/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 2000190 " !Type Test SPT Test 5989 Tubing lsso lsso- lsso lsso psi' 1� I ' - T Well 21-1-17 PTD, InI w PTD p 1500 IA 450 2710 - 2650. 2640 BBL Pumped: 0.9 BBL Ret— — t urned: 1 - OA so - so so - so- p Interval 4YRTST p/F P ✓ Notes: Thursday, May 7, 2020 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: � DATE: Wednesday,May 11,2016 Jim Regg � I/ P.I.Supervisor �� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2H-17 FROM: Lou Grimaldi KUPARUK RIV UNIT 2H-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2H-17 API Well Number 50-103-20329-00-00 Inspector Name: Lou Grimaldi Permit Number: 200-019-0 Inspection Date: 5/10/2016 Insp Num: mitLG160510154621 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well] 2H-17 Type Inj W fTVD 5989 Tubing 1900 -I 1900 - 1900 - 1900 PTD 2000190 Type Testi SPT Test psi 1500 - IA 280 2600 - 2530 - 2520 - Interval i4'TST P/F P ) OA 80 - 80 80 80 - Notes: Pumped 2.0 bbl's diesel, 1.1 bbl's returned.All required paperwork available on location.Good test. - SCANNED SEP. 2 7 2016 Wednesday,May 11,2016 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg �7 DATE:Tuesday,May 08,2012 P.1.Supervisor v ylO ((7(j 1- SUBJECT:Mechanical Integrity Tests 1 CONOCOPHILLIPS ALASKA INC 2H-17 FROM: John Crisp KUPARUK RIV UNIT 2H-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry . NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2H-17 API Well Number 50-103-20329-00-00 Inspector Name: John Crisp Permit Number: 200-019-0 Inspection Date: 5/6/2012 Insp Num: mitJCr120507113617 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well F 2H-17 Type Inj W'TVD 5989 ' IA I 830 2820 - 2780 2780 - PTD 2000190 - Type Test SPT Test psi 1500 ' OA 140 180 180 180 - Interval 4YRTST P/F P ` Tubing 2050 2050 2050 2050 ---- Notes: .8 bbls pumped for test. SCANNED MAR 13 2014 Tuesday,May 08,2012 Page 1 of 1 s • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 28, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2H -17 Run Date: 9/24/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 211-17 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50 -103- 20329 -00 Injection Profile Log NOV 1 WO 1 Color Log 50- 103 - 20329 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wr�d4 halliburton.com Date: Signed: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 21, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2H -17 Run Date: 10/6/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2H -17 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 103 - 20329 -00 Injection Profile Log 1 Color Log 50- 103 - 20329 -00 gLA)ftP NOV 5 2010 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood n 6900 Arctic Blvd. _ 1 Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton vTodahalllbutton`m Date: Signed: - 'a'- >> . ConocoP hi~fips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 17, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • R~CE~VE~ AEG 2 5 208 Alaska Oil & Gas Cans.. Cornr;~i~,sion Anchor~~a aoo-olq 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 AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped August 2-17, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Kle ~ ~ Z ~~1~ ~ ConocoPhillips Well Integrity Projects Supervisor ~iUG ~ 200$ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Date • Report of Sundry Operations (10-404) Kuparuk Field ell Name TD # -- Initial top of cement Vol. of cement um ed Final top of cement Cement top off date an Corrosion inhibitor iiwva Corrosion inhibitor/ sealant date ft bbls ft al 2H-05 185-168 SF N/A SF N/A 5.10 8/2/2007 2H-17 200-019 6" N/A 6" N/A 1.27 8/2/2007 2K-27 201-169 10" N/A 10" N/A 8.92 8/2/2007 2M-03 191-141 16" N/A 16" N/A 2.13 8/2/2007 1 B-14 194-030 SF N/A SF N/A 1.70 8/13/2008 1 B-18 194-061 9" N/A 9" N/A 8.07 8/13/2008 1 B-19 194-064 SF N/A SF N/A 5.10 8/13/2008 16-20 203-115 21" N/A 21" N/A 5.95 8/13/2008 1 B-101 203-133 3" N/A 3" N/A 1.00 8/17/2008 1 B-102 203-122 4" N/A 4" N/A 1.00 8/17/2008 1 Y-05 183-087 6" N/A 6" N/A 1.27 8/13/2008 1 Y-07 183-068 6" N/A 6" N/A 1.27 8/13/2008 1Y-17 193-068 SF N/A SF N/A 1.27 8/13/2008 1Y-22 193-070 SF N/A SF N/A 2.12 8/13/2008 1Y-26a 188-116 SF N/A SF N/A 3.83 8/13/2008 1Y-30 188-090 SF N/A SF N/A 3.83 8/13/2008 1E-112 204-091 14" N/A 14" N/A 5.95 8/17!2008 1 E-119 204-031 14" N/A 14" N/A 4.67 8/17/2008 1 E-121 204-246 6" N/A 6" N/A 1.00 8/17/2008 1 E-123 204-074 5" N/A 5" N/A 1.00 8/17/2008 MEMORANDUM TO: Jim Regg ~ ~~~~~~~~ P.I. Supervisor FRO:vI: Bob Noble Petroleum Inspector L` State of Alaska Alaska OiI and Gas Conservation Commission DATE: Monday, May 19, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2H-17 KLPARUK RIV UNIT ZH-( 7 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~'~- Comm Well Name: KUPARUK RIV" UNIT 2H-17 API Well Number: 50-103-20329-00-00 Inspector Name: Bob Noble Insp Num: mitRCNO805t209>234 Permit Number: 200-019-0 ~ Inspection Date: Sit 12008 Rel Insp Num: Packer Depth Pretest Initial 15 Mtn. 30 Min. 45 Min. 60 Min. ', Well '~H I~ ~~Type Inj. ~ ~~~ TVD s9s9 IA ~ uzs zoao T zooo ! aooo - -- - --- - P.T. ', zooot9o 'TYPeTest sPT', Test psi- zoao ~i pA ~,' loo ; Iso Iso iso Interval aYxrsr p~F P ~ Tubing :, zszs zszs zs~~ zszs Notes: ~~~~~ MAY ~ ~ 2008 Monday, May l9, 2008 Page I of I SchluDlbepger UTC- gOD -()lg D c- 04/20/07 NO. 4239 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 0''; 2007 Company: S~MA,{ ~1AY 0 4 2007 ll; (l'¡1ilmis$inF,! Field: Kuparuk Well Date CD BL Color Job# Log Description 2F-17 11632699 INJECTION PROFILE 04/30/07 1 1 G-17 11632696 PRODUCTION PROFILE 04/27/07 1 1J-170L 1 11661143 MEM INJECTION PROFILE 04/25/07 1 3H-04 11665424 PRODUCTION PROFILE 04/25/07 1 2N-309 11632693 INJECTION PROFILE 04/24/07 1 3A-01 11632691 PRODUCTION PROFILE 04/22/07 1 2H-17 11665423 INJECTION PROFILE 04/24/07 1 1J-180 11632690 PRODUCTION PROFILE 04/20/07 1 2X-11 11632700 PRODUCTION PROFILE 05/01/07 1 2X-13 11632701 PRODUCTION PROFILE 05/02/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. (0 . . F: \LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ) ') ~~fÆ~! :} fÆ~fÆ~~«~ AIlASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. -rrn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 26,2004 ~-Of~ Mr. Mike.Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") received a well safety valve system (SVS) test report from ConocoPhillips at Kuparuk River Unit 2H pad ("KRU 2H") dated November 1 0, 2004. Attached is a copy of the SVS Test Repol1. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 11.1 percent was identified during the above-noted inspection. Commission policy, 'as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 100/0 failure threshold. Effective November 10, 2004 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2H must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to witness the SVS test. Sincerely, ó~B~~G James B. Regg -ll Petroleum Inspection Supervisor Attachment 8CJ\NNED JAN 1 1 ¿DDS ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report ) Operator: ConocoPhillips Operator Rep: Noble - AES AOGCC Rep: Waived Submitted By: Brad Gathman FieldlUnitlPad: KRU 2H Separator psi: LPS Date: 11/10/2004 96 HPS ~lf!\~~,~~l~CPJ!(;j_. Well Permit Separ Number Number PSI 2H-01 1840770 2H-02 1840730 2H-03 1840700 2H-04 1840550 2H-05 1851680 96 2H-06 1851690 96 2H-07 1851700 96 2H-08 1851710 96 2H~09 1852590 96 2H-10 1852600 96 2H-11 1852610 I 96 2H-12 1852620 96 2H-13 1840960 2H-14 1840950 2H-15 1840860 2H-16 1840870 2H-17 2000190 70 50 P P 70 65 P P 70 70 P P 70 50 P P 70 55 P P 70 50 P 4 70 55 P P 70 60 P 4 70 50 P P s~~~lfþ; :$$ŠJf: ll~~ÎÎ!l;~t~~¡¿$l~1iê*~ ';1l~1l!l/!ýli;~~~~ Test Test Test Date Tested and or Oil, WAG, GINJ, Code Code Code Passed Retest or SI GAS, CYCLE, SI WAG WAG WAG WAG OIL OIL OIL OIL OIL 11/11/2004 OIL OIL 11/11/2004 OIL WAG OIL WAG WAG WAG Set LIP PSI Trip 96 Wells: 9 Components: 18 Failures: 2 Failure Rate: 11.110;0 90 Day Remarks: 2H-I0 & 12 serviced and passed re-test Pad to be re-tested in 90 days RJF 09/19/02 Page 1 of 1 SVS KRU 2H 11-10-04.xls MEMORANDUM State of Alaska Alaslt.a Oil and Gas Conserntion Commission TO: Jim Regg P.I. Supervisor <¿tf( 1( J~/{4- I DATE: Wednesday. June 30, 2004 SlIBJECT: t\lechanicallmegrlt)' Tests CONOCOPH1LLlPS ALAS"'-.-\. rNC FROM: John Crisp Petroleum Inspector ~H-17 KUPARUK RIV UNIT ~H-17 Src: Inspector Reviewed By: P.I. Supn' 'T.ü=- Comm NON-CONFIDENTIAL Well Name: KUPARU~ RlV UNIT 2H-17 Insp Num: miùCr040628175358 Rellnsp Num: API Well Number: 50-103-20329-00-00 Permit Number: 200-019-0 Inspector Name: John Cnsp Inspection Date: 6/27/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 1\1 in. Well 2H-17 T)'pe Inj. s TVD 6320 IA 375 2990 2960 2900 2890 P.T. 2000190 TypeTest SPT Test psi 1497.~5 OA 300 600 600 600 600 Interval 4YRTST PIF P Tubing 2100 2100 2100 2100 2100 Notes: 45 minUle test lost 100 psi. wI last 15 min. showing good 5tabilizarion. Wednesday. June 30. 2004 Page I of I Permit to Drill No. 2000190 MD 7180 TVD DATA SUBMITTAL COMPLIANCE REPORT 3/21/2002 Well Name/No. KUPARUK RIV UNIT 2H-17 Operator PHILLIPS ALASKA INC. 6320 Completion Date 3/13/2000 '-/ Completion Status WAGIN AP1 No. 50-103-20329-00-00 Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No -- Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name Interval Log Log Run OH / Scale Media No Start Stop CH (data taken from Logs Portion of Master Well Data Maint) Dataset Received Number Comments ~SRVY RPT · ~//Res/GR TVD ,..~T emplPresslSpinl j' Res/GRMD , 0 7180 5 FINAL 110 7180 5 FINAL 6740 7070 5 FINAL 6825 6951 5 FINAL 110 7180 O 10/17/2000 09815 62-7126 OH 3/21/2000 SPERRY . CH 1/9/2001 BL, Sepia CH 5/19/2000 BL(C) CH 1/10/2001 BL, Sepia CH 1/9/2001 BL, Sepia Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis Received? Daily History Received? Y~N Formation Tops Receuived? ~ N Comments: Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 26 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__X Kuparuk Unit 4. Location of well at surface 8. Well number 110' FSL, 624' FEL, Sec.26, T11 N, R8E, UM (asp's 497775, 5948973) 2H-17i At top of productive interval 9. Permit number / approval number 2109' FSL, 2458' FWL, Sec.26, T11 N, R8E, UM (asp's 495576, 5950973) 200-019 At effective depth 10. APl number 50-103-20329 At total depth 11. Field / Pool 2199' FSL, 2357' FWL, Sec.26, T11 N, RSE, UM (asp's 495475, 5951063) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7180 feet Plugs (measured) Tagged PBTD (9/5/00) @ 6962' MD. true vertical 6320 feet Effective depth: measured 6962 feet Junk (measured) true vertical 6121 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 110' 16" 9 cu yds High Early 110' 110' SURFACE 3189' 7-5/8" 608 Sx AS III, 285 Sx G 3189' 2920' PRODUCTION 6818' 5-1/2" 164 Sx Class G 6818' 5989' LINER 362' 4-1/2 ............ 7180' 6320' Perforation depth: measured 6852 - 6870'; 6905 - 6911'; 6920 - 6940'; 6953 - 6975' true vertical 6021 - 6037'; 6069 - 6074'; 6083 - 6101'; 6113 - 6133' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80, Tubing @ 6818' MD. Packers & SSSV (type & measured depth) No Packer. Camco DS @ 481' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - - 1200 2750 Subsequent to operation - 8000 - 2700 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations __X Oil __ Gas __ Suspended ~ Service (Water Inj) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 9i~lned Dat_repared by John Peirce Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 2H-17i DESCRIPTION OF WORK COMPLETED HIGH PRESSURE BREAKDOWN & PERFORATING 8/8/00: MIRU & PT equipment. Pumped a Fullbore Non-Reactive High Pressure Breakdown to treat the open perforation intervals located at: 6905 - 6911' MD 6920 - 6940' MD 6953 - 6975' MD Pumped a 3 stage High Pressure Breakdown Treatment w/Slick Seawater stages, followed by Gelled Diesel stages w/Rock Salt Diverter, followed by Scour slurry stages w/1 ppa proppant. Pumped all stages at 35 - 45 bpm. Rigged down. 9/5/00: MIRU & PT equipment. perforations as follows: Added perforations: 6852 - 6870' MD Used Enerjet carriers & shot the perfs at 2 spf. RIH w/perforating guns & tagged PBTD at 6962' MD. POOH w/guns. Rigged down. PU & shot 18' of Returned the well to produced water injection & obtained a valid injection rate. Schlmberger NO. 819 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color Sepia Print 1 D-106 INJECTION PROFILE W/PSP 001212 I 1 1 D-109 INJECTION PROFILE W/PSP 001212 I 1 1 D-111 INJECTION PROFILE W/PSP 001208 I 1 2H-17 INJECTION PROFILE W/PSP 001214 I 1 3N-13 INJECTION PROFILE W/PSP 001215 I I 12/21/00 DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. WELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November 16, 2000 RE: MWD Formation Evaluation Logs 2H-17, AK-MM-90250 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2H-17: 2" x 5" MD Resistivity & Gamma Ray Logs' 50-103-20329-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20329-00 1 Blueline 1 Folded Sepia 1 Blueline ~' 1 Folded Sepia C3 F~ I I--I--I N [3 =; E F:~ ~/I r' E=; To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: 1WWD FOrmation Evaluation Logs 2H- 17, AK-MM-90250 October 17, 2000 1 LDWG formatted Disc with verification listing. API#: 50-103-20329-00 PLF-a. SEACKNO~.RECEIPT BY SIGNINGAN~RETURNING ACOPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling. Service Attn: Jim Galvin 5631 Silverado. Way, Suite G. Anchorage, Alaska 995i8 RECEIVED Date: /klaska Oil & Gas Cons. commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas r'~ suspended r-1 Abandoned D Service ~] ~ r MI WAG Injector 2. Name of Operator ....~'~'"r~'~ 7. Permit Number ARCO Alaska, Inc. ,, ¥~ 200-019 ~. Address ~2 ~ ~. A~I ~umbor ~. O. Box ~00~0, Anchorage, AK ~510-0B~0 ~ ¢~i~?~¢~ S0-10~-20~2~-00 4. kocation o~woll at sur[ace ~* ~' .... :5:iy [ ...... ~. ~nit or keaso ~amo 110' FSL, 624' FEE, Sec. 26, Tll N, R8E, US (ASP: 497774.95, 5948973.1) ~¢ ~~ / Kuparuk River Unit ~ ~?I,::~--~, ~ 10. Well Number At Top Producing Interval 2109' FSL, 2458' FWL, Sec. 26, TllN, R8E, UM (ASP: 495576.4, 5950973.5) ~. :--' 2H-17 At Total Depth 11. Field and Pool 2199' FSL, 2357' FWL, Sec. 26, T11 N, R8E, UM (ASP: 495475.3, 5951063) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. Kuparuk River Pool RKB 26 feet~ ADL 25587 ALK 2673 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. ~15. Water Depth, if o~hore 16. No. of Completions March 1, 2000 March 10, 2000 March 13, 2000~ WA feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Suwey ~20. Depth where SSSV set 21. Thickness of Permafrost 7180' MD/6320'TVD 7083' MD/6232'TVD YES ~ No feet MD 1442' 22. Type Electric or Other Logs Run GWPWD/DDS/Res, CCL 23. CASING, LINER AND CEMENTING RECORD S~ING DEPTH MD CASING SIZE WT. PER ~. GRADE TOP BO~OM HOLE SIZE CEME~ING RECORD~ AMOUNT PULLED 16" 62.5¢ R-3 Su~ace 110' 20" 9 cu yds High Ear~ 7.625" 29.7¢ L-80 Sudace 3189' 9.875" 608 sx AS III, 285 sx Class G 5.5" x 15.5¢ L-80 SuCaoe 6818' 6.75" 164 sx Class G 4.5" 12.6¢ L-80 6817' 7180' 6.75" included in above 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD intewal, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 6815' N/A 6953'-6975' MD 6113'-6133' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6920'-6940' MD 6083'-6101' TVD 4spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6905'-6911' MD 6069'-6074' TVD 4spf N/A 27~ PRODUCTION TEST Date First Production Method of Operation (Flowing, gas li~, etc.) Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL ~GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. A~cbo~'a~e Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A 6849' 6870' 6901' 7050' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 6018' 6037' 6065' 6202' Annulus left open - freeze protected with diesel. 32. I hlreby certify that the following is true and correct to the best of my knowledge. Signed,...~ ~1~-~~~'~1'~ ~ r~'~itle DrillinaEnaineeringSupervisor Chip Alvord Questions? Call Tom Brockway 263-4135 Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Shut-in, Other-explain. Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, ?~.~ ~,, .,-.~,~,...... ,~ ~ ~..~ Item 28: If no cores taken, indicate "none". Form 10-407 Date: 04/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2H-17 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:03/01/00 START COMP: _ -- RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20329-00 02/28/00 (D1) TD/TVD: 0/0 SUPV: MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0)N/U DIVERTER CHANGE MUD PAN UNDER ROTARY. Turn key derrick up rig move from 3J pad to 2H pad. N/U diverter. 02/29/00 (D2) TD/TVD: 110/110 SUPV:M.C. HEIM MW: 8.7 VISC: 145 PV/YP: 28/38 ( 110) PICKING UP BHA ~1. APIWL: 13.2 N/U diverter and function test. Pick up 4" DP & stand in derrick to drill surface hole. 03/01/00 (D3) MW: 9.2 VISC: 145 PV/YP: 36/55 APIWL: 6.6 TD/TVD: 1081/1078 (971) DRLG. & SURVEYS SUPV:M.C. HEIM Hold pre-spud meeting. Drilling from 100' to 433'. Survey. Drilling, rotate & slide from 433' to 818' 03/02/00 (D4) MW: 9.8 VISC: 110 PV/YP: 29/43 APIWL: 5.8 TD/TVD: 2184/2055 (1103) DRLG. & SURVEYS @ 2400 SUPV:M.C. HEIM Drilling and surveys from 818' to 1650'. Circ bottoms up for wiper trip, survey. Wiper trip, tight ~ 1465'. RIH to 1605', hit bridge. Clean out to 1650' Drilling and surveys from 1650' to 2184' 03/03/00 (D5) MW: 9.8 VISC: 100 PV/YP: 33/42 APIWL: 4.6 TD/TVD: 3191/2866 (1007) CIRC. BOTTOMS UP AFTER WIPER TRIP. SUPV:M.C. HEIM Drilling and surveys from 2184' to 2514', pump sweep. Circ bottoms up. Wiper trip to 1650', no tight spots. Drilling and surveys from 2514' to 3191' 03/04/00 (D6) MW: 9.8 VISC: 60 PV/YP: 25/20 TD/TVD: 3206/2934 ( 15) RIGGING DOWN 20" ANNULAR PREVENTER SUPV:M.C. HEIM APIWL: 6.0 Finish drilling surface hole to 3206' MD. Circ hole clean for wiper trip. Wiper trip to HWDP, hole in good condition. Circ & condition hole for running 7-5/8" surface casing. Pump sweeps. Drop survey, pump pill and POH to run 7-5/8" surface casing. Rig up to run 7-5/8" casing. Hold safety meeting. Run 7-5/8" casing. Circ and condition mud for cement. Pump cement. Full returns thru out plug, floats held Date: 04/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 03/05/00 (D7) MW: 8.8 VISC: 40 PV/YP: 3/ 9 APIWL: 14.8 TD/TVD: 3206/2934 ( 0) PICKING UP BHA #2. SUPV:M.C. HEIM Rig down diverter lines. N/U BOPE and test to 300/3000#. 03/06/00 (D8) MW: 8.5 VISC: 40 PV/YP: 7/10 TD/TVD: 3416/3112 ( 210) DRILLING @ 3870' SUPV:M.C. HEIM APIWL: 8.0 Finish testing BOPE, 300/3000 psi, OK. Pull test plug. RIH w/BHA #2. Tag soft fill ~ 3060', clean out to float collar and displace out old mud. Test 7-5/8" casing to 3000#, OK. Perform stripping and well kill drills. Drilling plug, float collar, cement, shoe and 18' new hole. Circ bottoms up, clean hole for LOT. Perform leak off test. Drilling and surveys from 3224' to 3416' 03/07/00 (D9) MW: 8.8 VISC: 52 PV/YP: 14/21 APIWL: 4.6 TD/TVD: 4663/4156 (1247) POOH TROUBLE DOWN LOADING MWD. CHANGE OUT MUD MOTOR. C SUPV:DONALD L. WESTER Continue directional drilling 6.75" hole from 3416' to 4663'. Pump sweep rotate and reciprocate pipe. Short trip to 7-5/8" casing shoe. Hole in good condition. RIH to 4567'. Wash to bottom @ 4663'. Unable to make hole. Pump sweeps. Motor appears to have broken a shaft. Pump dry job. POOH. Wet. 03/08/00 (D10) MW: 10.3 VISC: 55 PV/YP: 22/29 APIWL: 3.0 TD/TVD: 5819/5122 (1156) CONTINUE DRILLING 6.75" & WEIGHTING UP MUD F/ 8.8 TO 1 SUPV:DONALD L. WESTER POOH with motor failure. M/U same bit on new motor. RIH. Continue directional drill 6.75" hole from 4663' to 5819' Started weighting up mud @ 5800' from 8.8 ppg. 03/09/00 (Dll) MW: 10.8 VISC: 50 PV/YP: 21/25 APIWL: 2.7 TD/TVD: 6884/6050 (1065) CONTINUE DRILLING AHEAD TO 7170' ~ 0600 HRS ECD 11.8 SUPV:DONALD L. WESTER Continue directional drilling 6.75" hole form 5819' to 6205' Started raising mud weight to 10.3 ppg. CBU rotate, reciprocate, pump dry job. Made wiper trip to 4650'. RIH. Wash 95' to bottom ~ 6205'. Drilling 6.75" hole from 6205' to 6687' Mud weight 10.6 ppg. Perform LOT. Continue drilling 6.75" hole from 6687' to 6884'. Raise mud weight to 10.8 ppg. 03/10/00 (D12) MW: 11.1 VISC: 50 PV/YP: 21/26 APIWL: 2.5 TD/TVD: 7180/6320 ( 296) L/D DP CHANGE RAMS TO 5-1/2" TEST BOPS. R/U TO RUN 5-1 SUPV:DONALD L. WESTER Continue drilling 6.75" hole from 6884' to 7180'. Clean and condition hole, rotate, reciprocate and pump sweeps. Weight up to 11.1 ppg. Pump dry job. Lost 10 bbls while weighting up. Short trip to 5273'. RIH. Spot 25 bbl LCM pill on bottom. POOH. Date: 04/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 03/11/00 (D13) MW: 11.0 VISC: 47 PV/YP: 19/22 APIWL: 3.0 TD/TVD: 7180/6320 ( 0) CONTINUE TO N/U, SET 10" X 5.5" SLIPS W/ l15K HUNG, PA SUPV:DONALD L. WESTER Test BOPE 250/3500 psi. Run 4.5" shoe and float equipment and 4.5" casing and 5.5" casing. Full returns. Pump cement. 03/12/00 (D14) MW: 11.0 VISC: 47 PV/YP: 19/22 APIWL: 3.0 TD/TVD: 7180/6320 ( 0) CONTINUE RUNNING 3-1/2" COMPMLETION WET FLOWING OVER. SUPV:DONALD L. WESTER Install packoff. Test BOPs. Freeze protect annulus. Run 3.5" tubing. 03/13/00 (D15) MW: 15.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7180/6320 ( 0) PULL OFF WELL CLEAN UP LOCATION.CLEAN UP AROUND CELLAR SUPV:DONALD L. WESTER Continue running 3.5" tubing. N/D BOPE. N/U tree and test tree 250/5000 psi. Freeze protect annulus and tubing. 03/14/00 (D16) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7180/6320 ( 0) SUPV:M.C. HEIM Prep yard for rig move. Prep tree and cellar for move. Release rig ~ 0200 hrs. 3/14/00 ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ WELL SERVICE REPORT ~ K1(2H-17(W4-6)) WELL JOB SCOPE JOB NUM'BER " 2H-17 PERFORATIONS-E-LINE 0505001627.1 DATE DAILY WORK UNIT NUMBER 05/10/00 PERFORATE WITH 2.5" HSD-POWER JET 2145 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES SWS-SPENCER JOHNS FIELD AFC# CC# Signed ESTIMATE AK0061 230DS28HL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 250 PSI 500 PSI 0 PSII 10 PSI 0 PSI DALLY SUMMARY PERFORATED 3 INTERVALS WITH 4 GUN RUNS. INTERVALS: 6953-6975/6920-6940/6905-6911. GUN SYSTEM: 2 1/2" HSD WITH 2506 POWER JET CHARGES AT 4 SPF[Perf] TIME 08:00 09:00 09:15 09:30 10:15 10:30 11:15 11:45 12:20 12:30 13:15 13:35 14:05 14:10 15:00 15:15 15:45 15:50 16:30 17:00 17:30 LOG ENTRY SWS ARRIVE AT 2H-17-BEGIN RU CALLED SECURITY AND DSO-RADIO SILENCE SAFETY MEETING-ARM GUN PT WELL TO 3000 PSI-RIH LOG TIE-IN PASS LOG SHOOT PASS-STOP CCL @ 6945.3 ' MD, CCL TO TOP SHOT:9.7', INTERVAL6955-6975 MD AT SURFACE-ALL SHOTS FIRED ARM 2ND GUN-RIH LOG TIE IN PASS GUN #2 . LOG INTO POSITION-CCL @ 6940.3' MD, CCL TO TOP SHOT=12.7', INTERVAL= 6953-6955 MD AT SURFACE, ALL SHOTS FIRED ARM GUN #3-RIH LOG TIE IN PASS GUN #3 LOG SHOOT PASS FOR GUN#3-CCL @ 6910.3, CCL TO TOP SHOT = 9.7', INTERVAL 6920-6940 MD AT SURFACE, ALL SHOTS FIRED ARM GUN #4-RIH LOG TIE IN PASS LOG SHOOT PASS. CCL @ 6891.3' MD, CCL TO TOP SHOT= 13.7', INTERVAL: 6905-6911 MD AT SURFACE ALL SHOTS FIRED CALLED SECURITY AND DSO-LIFT RADIO SILENCE RDMO North Slope Alaska Alaska State Plane 4 Kuparuk 2H 2H.17 Surveyed: 10 March, 2000 SURVEY REPORT 16 March, 2000 Your Ref: API-501032032900 Surface Coordinates: 5948973.12 N, 497774.92 E (70° 16' 18.5458" N, Kelly Bushing: 125.08ft above Mean Sea Level 150°01'04.7853"W) ORILLING Survey Ref: svy9133 Sperry-Sun Drilling Services Survey Report for 2H- 17 Your Ref: API-501032032900 Surveyed: 10 March, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -125.08 0.00 110.00 0.000 0.000 -15.08 110.00 191.93 0.440 46.210 66.85 191.93 282.12 0.650 46.870 157.04 282.12 372.22 0.500 47.510 247.13 372.21 461.92 0.310 317.180 336.83 461,91 554.32 0.650 276.350 429.23 554.31 648.36 1.180 278.110 523.25 648.33 739.99 3.360 311.850 614.81 739,89 834.54 6.300 311.280 709.01 834.09 925.80 8.150 309.410 799.54 924.62 1016.73 7.580 306.820 889.62 1014.70 1109.45 9.410 313.580 981.32 1106.40 1203.98 11.230 315.340 1074.32 1199.40 1299.55 13.900 313.840 1167.59 1292.67 1396.12 17.350 312.170 1260.58 1385.66 1490.64 20.700 314.920 1349.92 1475.00 1585.18 23.340 316.090 1437.56 1562.64 1681.77 26.610 315.280 1525.11 1650.19 1776.76 29.190 310.970 1609.06 1734.14 1873.61 33.920 309. 520 1691.56 1816.64 1970.70 34.030 309. 890 1772.08 1897.16 2067.81 33.170 309.600 1852.96 1978.04 2160.36 32.670 309.970 1930.65 2055.73 2258.84 33.430 309.770 2013.20 2138.28 Local Coordinates Northings Eastings (ft) (ft) 0.00 N 0.00 E 0.00 N 0.00 E 0.22 N 0.23 E 0.81 N 0.85 E 1.42 N 1.51 E 1.86 N 1.64 E 2.11 N 0.95 E 2.30 N 0.54 W 4.23 N 3.48 W 9.50 N 9,44 W 16.91 N 18.20 W 24.60 N 27.98 W 33.49 N 38.37 W 45.36 N 50.44 W 59.94 N 65,26 W 77.64 N 84,31 W 98,91 N 106.59 W 124.20 N 131.41 W 153.36 N 159,91 W 183.68 N 192.38 W 216.38 N 231.08 W 251.04 N 272.82 W 285.40 N 314.14 W 317.58 N 352,79 W 352.01 N 394.01 W Global Coordinates Northings Eastings (ft) (ft) 5948973.12 N 497774.92 E 5948973.12 N 497774.92 E 5948973.34 N 497775.15 E 5948973.93 N 497775.77 E 5948974.54 N 497776.43 E 5948974.98 N 497776.56 E 5948975.23 N 497775.87 E 5948975.42 N 497774,38 E 5948977.35 N 497771.44 E 5948982.62 N 497765.48 E 5948990.03 N 497756.72 E 5948997.72 N 497746.94 E 5949006.62 N 497736.56 E 5949018.50 N 497724.49 E 5949033.07 N 497709.67 E 5949050,79 N 497690.64 E 5949072.06 N 497668.36 E 5949097.36 N 497643.54 E 5949126.53 N 497615.05 E 5949156.85 N 497582.59 E 5949189.56 N 497543.90 E 5949224.24 N 497502.17 E 5949258.61N 497460.86 E 5949290.81N 497422.22 E 5949325.25 N 497381.01 E Dogleg Rate (°/lOOff) 0.000 0.537 0.233 0.167 0.658 0.500 0.564 2.693 3.110 2.043 0.738 2.245 1.954 2.814 3.602 3.668 2.831 3.404 3.446 4.946 0.241 0.901 0.582 0.780 Alaska State Plane 4 Kuparuk 2H Vertical Section (ft) Comment 0.00 0.00 -0.02 -0.09 -0,16 0,04 0,72 1.95 5.42 13.38 24.84 37.25 50.92 67.84 88.61 114.61 145.40 180.79 221.49 265.91 316.54 370.74 424,42 474.67 528.33 Continued... 16 March, 2000 - 13:38 - 2 - DrillQuest 1.05.04e North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Depth (ft) Survey Report for 2H- 17 Your Ref: A PI-501032032900 Surveyed: 10 March, 2000 2354.14 33.720 310.140 2092.60 2217.68 2447.04 33.380 310.070 2170.02 2295.10 2547.37 32.670 309.560 2254.14 2379.22 2643.80 33.190 310.750 2335.08 2460.16 2739.98 33.350 313.230 2415.50 2540.58 2836.56 32.140 312.530 2496.73 2621.81 2933.69 32.300 312.840 2578.90 2703.98 3029.32 32.580 312.850 2659.61 2784.69 3126.37 31.960 313.110 2741.67 2866.75 3142.07 31.980 312.960 2754.99 2880.07 3251.84 32.080 '313.370 2848.05 2973.13 3346.66 32.340 313.500 2928.27 3053.35 3443.09 32.310 312.750 3009.76 3134.84 3539.17 32.340 312.530 3090.95 3216.03 3636.10 32.390 313.080 3172.82 3297.90 3732.07 32.870 312.630 3253.65 3378.73 3829.73 33.040 312.170 3335.59 3460.67 3926.08 32.970 311.830 3416.39 3541.47 4021.15 32.890 311.820 3496.19 3621.27 4117.47 33.260 311.950 3576.90 3701.98 4214.17 33.320 312.110 3657.73 3782.81 4309.36 33.430 311.270 3737.23 3862.31 4405.45 33.410 311.430 3817.43 3942.51 4501.56 33.420 310.630 3897.65 4022.73 4597.49 33.960 310.460 3977.47 4102.55 Local Coordinates Northings Eastings (ft) (ft) 385.86 N 434.41W 418.93 N 473.68W 453.94 N 515.68W 487.75 N 555.74W 523.04 N 594.95W 558.59 N 633.23W 593.70 N 671.29W 628.59 N 708.91W 663.91 N 746.81W 669.58 N 752.89W 709.41N 795.35W 744.16 N 832.05W 779.41N 869.69W 814.21 N 907.48W 849.47N 945.55W 884.66 N 983.48W 920.48 N 1022.71W 955.60 N 1061.72W 990.07N 1100.23W 1025.16 N 1139.36W 1060.70 N 1178.79W 1095.52 N 1217.89W 1130.49 N 1257.62W 1165.23 N 1297.55W 1199.82 N 1337.98W Global Coordinates Northings Eastings (ft) (ft) 5949359.10 N 497340.62 E 5949392.19 N 497301.36 E 5949427.22 N 497259.37 E 5949461.03 N 497219.32 E 5949496.34 N 497180.12 E 5949531.90 N 497141.86 E 5949567.02 N 497103.80 E 5949601.92 N 497066.20 E 5949637.25 N 497028.30 E 5949642.93 N 497022.23 E 5949682.77 N 496979.78 E 5949717.53 N 496943.09 E 5949752.78 N 496905.46 E 5949787.60 N 496867.68 E 5949822.87 N 496829.62 E 5949858.07 N 496791.70 E 5949893.91N 496752.48 E 5949929.04 N 496713.49 E 5949963.51 N 496674.98 E 5949998.62 N 496635.86 E 5950034.16 N 496596.45 E 5950069.00 N 496557.35 E 5950103.98 N 496517.63 E 5950138.74 N 496477.72 E 5950173.34 N 496437.29 E Dogleg Rate (°/lOOft) 0.372 0.368 0.760 0.861 1.424 1.313 0.237 0.293 0.655 0.522 0.218 0.284 0.417 0.126 0.308 0.560 0.310 0.205 0.084 0.391 0.110 0.499 0.094 0.459 0.571 Alaska State Plane 4 Kuparuk 2H Vertical Section (ft) Comment 580.99 632.29 686.92 739.30 792.05 844.29 896.08 947.37 999.18 1007.50 1065.71 1116.24 1167.80 1219.17 1271.06 1322.80 1375.93 1428.41 1480.09 1532.65 1585.73 1638.09 1691.00 1743.92 1797.10 Continued... DrillOuest 1.05.04e 16 March, 2000 - 13:38 - 3 - Sperry-Sun Drilling Services Survey Report for 2H-17 Your Ref: API-501032032900 Surveyed: 10 March, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 4693.05 33.960 313.570 4056.74 4181.82 4789.70 34.480 313.180 4136.65 4261.73 4885.93 34.760 313.630 4215.85 4340.93 4981.21 33.480 314.170 4294.72 4419.80 5078.09 33.430 314.310 4375.55 4500.63 5174.64 33.650 314.350 4456.03 4581.11 5270.42 34.180 315.220 4535.51 4660.59 5365.44 33.270 315.470 4614.54 4739.62 5461.71 32.830 315.070 4695.23 4820.31 5558.25 33.500 314.590 4776.05 4901.13 5654.27 32.010 312.130 4856.80 4981.88 5749.83 32.160 311.990 4937.76 5062.84 5847.05 32.530 311.460 5019.90 5144.98 5944.99 33.030 311.530 5102.24 5227.32 6041.48 33.840 312.200 5182.76 5307.84 6136.72 34.630 312.190 5261.50 5386.58 6234.92 31.750 313.100 5343.67 5468.75 6331.01 30.060 312.240 5426.12 5551.20 6426.96 28.420 312.100 5509.84 5634.92 6523.48 26.310 312.320 5595.55 5720.63 6619.16 23.910 310.100 5682.19 5807.27 6715.16 23.460 310.250 5770.10 5895.18 6813.33 23.580 310.730 5860.11 5985.19 7112.49 24.440 311.530 6133.39 6258.47 7180.00 24.440 311.530 6194.85 6319.93 1235.54 N 1377.63 W 1272.87 N 1417.14 W 1310.43 N 1456.86 W 1347.49 N 1495.37 W 1384.75 N 1533.63 W 1422.03 N 1571.79 W 1459.68 N 1609.72 W 1497.20 N 1646.80 W 1534.50 N 1683.75 W 1571.73 N 1721.20 W 1607.41 N 1758.95 W 1641.42 N 1796.64 W 1676.03 N 1835.46 W 1711.17 N 1875.18 W 1746.65 N 1914.77 W 1782.64 N 1954.46 W 1819.04 N 1994.01 W 1852.49 N 2030.29 W 1883.96 N 2065.02 W 1913.76 N 2097.89 W 1940.53 N 2128.40 W 1965.41 N 2157.87 W 1990.85 N 2187.66 W 2070.92 N 2279.34 W 2089.44 N 2300.25 W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5950209.07 N 496397.65 E 1.818 5950246.41N 496358.16 E 0.584 5950283.99 N 496318.45 E 0.394 5950321.05 N 496279.95 E 1.380 5950358.32 N 496241.70 E 0.095 5950395.61N 496203.55 E 0.229 5950433.27 N 496165.63 E 0.750 5950470.81N 496128.56 E 0.969 5950508.12 N 496091.63 E 0.510 5950545.36 N 496054.18 E 0.745 5950581.05 N 496016.44 E 2.080 5950615.07 N 495978.77 E 0.175 5950649.70 N 495939.96 E 0.479 5950684.84 N 495900.25 E 0.512 5950720.33 N 495860.67 E 0.923 5950756.33 N 495820.98 E 0.830 5950792.75 N 495781.45 E 2.976 5950826.21 N 495745.18 E 1.818 5950857.69 N 495710.45 E 1.711 5950887.50 N 495677.60 E 2.189 5950914.28 N 495647.09 E 2.694 5950939.17 N 495617.63 E 0.473 5950964.61 N 495587.85 E 0.230 5951044.72 N 495496.20 E 0.307 5951063.24 N 495475.29 E 0.000 Alaska State Plane 4 Kuparuk 2H Vertical Section (ft) Comment 1850.47 1904.81 1959.47 2012.90 2066.27 2119.59 2172.98 2225.66 2278.O9 2330.85 2382.79 2433.54 2485.56 2538.58 2591.74 2645.32 2699.07 2748.42 2795.28 2839.65 2880.23 2918.77 2957.93 3O79.62 3107.55 Projected Survey Continued... 16 March, 2000 - 13:38 - 4 - DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 2H- 17 Your Ref: A PI-501032032900 Surveyed: 10 March, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 2H All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.383° (26-Feb-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 312.320° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7180.00ft., The Bottom Hole Displacement is 3i07.55ft., in the Direction of 312.251° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 7180.00 6319.93 2089.44 N 2300.25 W Projected Survey Continued... 16 March, 2000 - 13:38 - 5 - DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 2H- 17 Your Ref: AP1-501032032900 Surveyed: 10 March, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 2H Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Depth (ft) 7180.00 Vertical Depth (ft) 6319.93 Survey Tool Description MWD Magnetic 16 March, 2000 - 13:38 - 6 - DrillQuest 1.05.04e Ph,LLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 July 27, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Well Completion Report for 2H-17 (200-019) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Well Completion Report for the drilling operations on 2H-17. If there are any questions, please contact me at 265-6830 or Tom Brockway at 263-4135. Sincerely, ~ R. Thomas ~"l ~-~~ Kuparuk Drilling Team Leader Phillips Drilling RT/TAB/skad 5/12/OO Schlumberg NO. 136 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print CD 2C-03 (J, (cL~ INJECTION PROFILE 000502 I 1 2V-08A q,- LEAK DETECTION LOG 000502 I 1 1C-26 C~.~<-. 20079 RST ~ c¥~'"t 000202 I I 1 1 L-26A 20192 SCUT 000427 1 2H-17 20195 SCMT 000506 1 r3 r'f' r- !~1 r' I~ /'~ I\L~-L I V LIJ ' MAY 2000 SIGNED {~ DATE: Alaska 0ii & Gas cu;~. ~mmissi0n Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 16-Mar-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2H-17 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 7,180.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) RECEIVED ~ 21 2000 Alaska Oil & Gas Cons. Commission Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson~-'~ Chairman DATE: March 6, 2000 THRU: Blair Wondzell, .~~ SUBJECT: P. I. Supervisor -'¢ {,'¢q[oe FROM: John H Spaulding~/~..~ Petroleum Inspectdr BOPE Test ARCO KRU 2H-17 On March 6, 2000 I traveled to ARCO's drill site 2H to witness the BOPE test on Nordic rig 3. The AOGCC BOPE test report form is attached for reference. As noted on the report form 2 failures were observed; a hydraulic leak on the annular preventer seals and also a bad block valve on the back up N2 system rendering this system useless. These items were repaired on 3-6-00 and reported to me at our office. The mud system and gas detectors were not inspected at this time, they were calibrated on 3-3-00 and noted in the log book. SUMMARY: I witnessed the BOPE Test on; Nordic rig 3, 2 failures, 5 hour test time Attachment: bop Nordic 3 3-5-00js STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Nordic Well Svcs. Operator: ARCO Rig No. 3 PTD # Rep.: Rig Rep.: 3, '/89 Location: Sec. Well Name: 2H-17 Casing Size: 7 5/8" Test: Initial Set @ Weekly Other 200-0'/9 DATE: 3/5/00 Rig Ph.# 659-7872 Shane McGeehan M. C. Helm 28 T. 11N R. 8E Meridian Umiat ~TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location yes Standing Order Posted yes - Well Sign yes Drl. Rig ok Hazard Sec. yes ' BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F '/ 250/3,000 P '/ 250/3, 000 P '/ 250/3,000 P '/ 250/3,000 P '/ 250/3, 000 P 1 25O/3, 000 P 2 250/3,000 P N/A 250/3, 000 MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Math Gas Detector H2S Gas Detector Visual Alarm FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Qu an Pressure P/F '/ 250/3, 000 P '/ 250/3,000 P '/ 250/3,000 P I 250/3,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F '/2 250/3,000 P 38 250/3,000 P '/ P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 @ 1900 avg. 2, 750 P 2, '/00 P minutes '/3 sec. minutes 3 sec. X Remote: X Psig. : : ;: : :TEST RESULTS Number of Failures: 2 ,Test Time: 5.0 Hours. Number of valves tested '/9 Repair or Replacement of Failed Equipment will be made within '/ 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: Hydraufic leak on the annular preventer - repaired on 3-6 Broken valve on supply from the backup nitrogen bottles; rendering the N2 backup useless The mud system and gas detectors were calibrated on 3-3 and noted in the Icg book Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspe¢t.(~lL (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO hnnn nc Waived By: Witnessed By: · dic 3 3-05-00 js John H, Spaulding TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COPlPlISSION Chip Alvord, Drilling Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-030 3001 PORCUPINE DRIVE ANCHORAGF, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Kuparuk River Unit 2H-17 ARCO Alaska, Inc. Permit No: 200-019 Sur. Loc. 110'FSL 624'FEL, Sec. 26, T1 IN, RSE, UM Btmhole Loc. 2207'FSL 2353'FWL, Sec. 26. T11N, R8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill thc above rcfcrcnccd xvcll. The permit to drill docs not exempt you from obtaining additional pcrmits rcquircd by law from other governmental agencies, and does not authorize conducting drilling operations until all other requircd permitting determinations are made. Annular disposal of drilling wastcs will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 arc met. Annular disposal of drilling waste will be contingent on obtaining a xvell ccmcnted surface casing confirmed bv a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs lnust bc submittcd to the Commission on form 10-403 prior to the start of disposal opcrations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 2H must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 3 5,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the mechanical integrity (MI) of thc injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before opcration, and of thc BOPE test pcrformed before drilling below the surface casing shoe, must be given so that a rcprcscntativc of thc Commission may ~¥itness the tests. Notice mav be given by contacting the Commission petroleum field inspcctor on the North Slope pager at 659-3607. Chair B'Y ORDER OF THE.~t,OMMISSION DATED this 2~'''-~ day of February, 2000 dlf/Enclosurcs CC: Department of Fish & Gmne. Habitat Section w/o enci. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ...... l';.:l:'~/peofwo;k: "Drill D Redril, D [ l[~'. Type of well." Explo;~;~)ry D Stratigr~pl~ic':T'e~i'J~J ..... Devel°pment°ilD Re-entry D Deepen D Service [] Development Gas D Single Zone [] Multiple Zone D 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 34.6 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25587 ALK 2673 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 110' FSL, 624' FEL, Sec. 26, T11 N, RSE, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2136' FSL, 2431' FWL, Sec. 26, T11N, RSE, UM 2H-17 #U-630610 At total depth 9. Approximate spud date Amount 2207' FSL, 2353' FWL, Sec. 26, T11 N, R8E, UM March 1,2000 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 2353' @ TD feet 2H- 14 30' @ 150' M D feet 2560 7172 ' MD / 6305 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 700' MD Maximum hole angle 33 Maximum surface 1721 psig At total depth (TVD) 2042 psig 18. Casing program Setting Deplh size Specifications Top Bottom Quanti~ of Cement Hole Casing Wei~lht Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" 62.5# R-3 Weld 75' 35' 35' 110' 110' to be set 9.875" 7.625" 29.7# L-80 BTCM 3171' 35' 35' 3206' 595' 378 sx Class G & 275sx AS III 6.75" 5.5" 15.5# L-80 LTC Mod 6755' 35' 35' 6790' 5945' 115 sx Class G 4.75" 4.5" 12.6# L-80 IBT 382' 6790' 5945' 7172' 6305' see above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Intermediate Production ,. . . ? , Perforation depth: measured !'" i~'. ~.'~ °] © ~.:i,,v,,~ r~ true vertical Alaska 0if & Gas C0rls. Commission Anchorafl8 20. Attachments Filing fee J~J Property Plat D BOP Sketch J~i Divertor Sketch J~i Drilling program Drilling fluid program J~l Time vs depth plot DRefraotion analysis D Seabed report D 20 AAO 25.050 requirements D 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Tom Brockway 263-413~ Signed v~,¢,(~_~' ~.,~ Title: DrillingEngineeringSupervisor Date Chip Al Pr~nared hv ,~h~ron AIl.~un-Dr~k~ Commission Use Permit Number I APInumbor J ISee cover letler ~ 4~ {~ 50- /'~) '2~ ,2..O "~ Zg'--~ Approval date -- "'"' ,.-.~ - ~,,.~" "t~ Jfor other requirements Conditions of approval Samples required -~. Yes ,~/~o Mud log required D Yes ,~ No Hydrogen sulfide measures DYes .~ No Directional survey required J~Yes D No Required working pressure for BOPE D2M; [~ 3M; D 5M; D 10M;D D Other: oRiGINAL- siGNED' BY by order of Approved by m,.,i.,.,..,rt' N- Christenson Commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 February 16, 2000 RECEIVED Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Alaska Oil & Gas Cons. Anchorage Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: KRU 2H-17 110' FSL, 624' FEL, Sec 26, T11N, R8E, UM 2136' FSL, 2431' FWL, Sec. 26, T11N, R8E, UM 2207' FSL, 2353' FWL, Sec. 26, T11N, R8E, UM Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 2H pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 2H pad. The well is designated as a monobore injector and is planned to penetrate the Kuparuk C and A sands using a 7-5/8" surface casing string and a 5-1/2" x 4-1/2" tapered production casing string with a ~ The well will be drilled and completed using Nordic Rig 3. Completion plans call for running 3-1/2" production tubing as a tieback string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 9) 10) 11) A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f). Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are ARCO's designated contacts for reporting responsibilities to the Commission: A) B) Completion Report (20 AAC 25.070) Geologic Data and Logs (20 AAC 25.071) Sharon Allsup-Drake, Drilling Technologist 263-4612 Tony Hillegeist, Geologist 265-6965 Please note that the anticipated spud date for this well is March 1, 2000 If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Chip Alvord at (907) 265-6120. Thomas A. Brockway Operations Drilling Engineer Attaohments: CC: KRU 3F-20 Well File Chip AIvord Brian Noel Todd Mushovic ATO- 1 O3O ATO- 1 O34 ATO-1286 General Procedure: GENERAL DRILL AND COMPLETE PROCEDURE KUPARUK RIVER UNIT- INJECTOR KRU 2H-17 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up Nordic Rig 3. Install diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to 7-5/8" surface casing point (+/3206') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering 4. Run and cement 7-5/8" 29.7# L-80 BTCM casing to surface using lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Note: A port collar will not be run in this casing string. If cement does not circulate to surface a top job will be completed. A Top Job may only be performed after consulting with the AOGCC. 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Record results. 6. Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. 7. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 14.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 8. Drill 6-3/4" hole to well total depth (+/- 7172') according to directional plan, running LWD logging equipment as needed. 9. Run and cement 5-1/2" 15.5# L-80 BTCM x 4-1/2" 12.6# L-80 IBT tapered casing string with polished seal bore as part of XO. Adequate cement will be pumped to place cement top +\- 500' above the Kuparuk sands. Displace cement with mud. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. 10. Pressure test casing to 3,500 psi for 30 minutes per AOGCC regulations. Record results. 11. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. 12. Freeze protect well. Pull landing joint. Install BPV. Nipple down BOP stack and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. 13. Secure well. Release rig. 14. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. Note: As a dedicated injector, cased hole cement bond logs (SLT-J or CBT) will be run to establish isolation after the cleanout is completed, but prior to perforating. 2H-17 TAB, 2/16/00, vl DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS KRU 2H-17 Drillinq Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 7-5/8" surface casing 8.5-10.0 16-26 25-50 150-250* 10-20 10-30 8-15 8-10 4-6% Drill out to TD 10.0-11.0 5-15 5-12 30-40 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Nordic Ri.q 3 Tandem Geolograph/Swaco Shale Shakers Mud Cleaner, Degassers Pit Level Indicator (Visual / Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Flow Line Cleaner *Spud mud should be adjusted to a FV between 100-150 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using an expected surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1903 psi. Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (2917 ft)(0.70- 0.11) = 1721 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of the 3F-20 target location are expected to be -3300 psi (0.55 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 11.0 ppg would be predicted as the maximum mud weight needed to safely drill in this formation using conventional drilling methods, assuming a TVD of 6013'. Well Proximity Risks: The nearest existing well to 2H-17 is 2H-14. As designed, the minimum distance between the two wells would be 30' at 150' MD. 2H-17 TAB, 2/16/00, vl Drilling Area Risks: Risks in the 2H-17 drilling area include lost circulation and possible differential pressure between the "A" and "C" sands in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. If lost circulation cannot be controlled with LCM and a reduction of circulating pressure, 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #3 or a coiled tubing unit will drill out 4-3/4" hole and run a 3-1/2" liner to TD. Careful analysis of pressure data from offset wells shows that a mud weight of 11.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 14.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on 2H pad if one is available or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2H-17 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2H-17 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure Max Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2917') + 1,500 psi = 3320 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTCM 4,790 psi NA 6,890 psi 5,856 psi 5-1/2" 15.5 L-80 3 LTCM 4,990 psi 4,242 psi 7,000 psi 5,950 psi 4-1/2" *12.6 L-80 !2 BTCM 7,500 psi 6,375 psi 8,440 psi 7,174 psi * if needed Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). 2H-17 TAB, 2/16/00, vl Kuparuk 2H-17 Injector P~oposed Completion Schematic Surface osg. 7 5/8" 29.7¢ L-80 BTCM ~ (+/- 3206' MD / 2917' TVD) All Depths Reference Nordic 3 RKB Productiof~ csg. 5~1/2" 15.5# L*80 BTCM run XO/SBE to surface (+/- 6790' MD / 5945' TVD) Production cs9 4-1/2" 12.6# L-80 IBT rui~ TD to XO/SBE (+/- 7172' MD / 6305' TVD) ARCO Alaska, Inc, L 3-1/2" Gen IV tubing hanger witb 3-1/2" L-80 EUE 8RD-Mod pin down H. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to surface G. 3-1/2" Camco 'DS' nipple w/2.812" No-Go Profile. 3-1/2" x 6' L-80 pup installed above. 3-1/2" x 6' L-80 flow co~pling installed below, EUE 8RD-Mod set at +/, 500' MD F 3~1/2" L-80 9.3¢ EUE 8RD-Mod tubing to nipple E, 3-1/2" x 1" Camco 'KBG-2-9' Mandrel w/DV and latch (Max. OD 4.725", iD 2.90"). 15' L-80 crossover handling pups (BTC x Special Clearence EUE 8RD) installed on GLM. D. I it 3-1/2" L-80 9.3# EUE 8RD-Mod tubing C, 3-1/2" Camco 'D'landing nipple with 2.75" ID and No-Go profile (Max OD 4,50") S. 1 j[ 3-1/2" L-80 9.3# EUE 8RD-Mod tubing A, Baker 4~I/2" 'GBH-22' Locator Seal Assembly w/ 15' of seals & Iocator 3-1/2" x 6' handling pup installed on top. EUE 8RD-Mod box up B~ker 5 OD x 4' ID Seal Bore Extension Baker XO, SBE x 4-1/2" BTCM et at ~/- 6790' MD / 5945' TVD Future Thru-Tubing Per~orations 4-1/2" IBT landing collar/FS/FC TAB, 8/3/99, v3 ARCO Alaska, Inc. Sfruofure: Pod 2H Well : 17 Field : Kuparuk River Unif Looafion : Norfh Slope, Alaska I v 350 550 700 1050 1400 1750 2100 2450 2800 5150 5500 5850 4200 4550 4900 5250 5600 5950 6500 6650 550 ESTIMATED RKB ELEVATION: 125' KOP 5.00 6.00 9.00 DLS: 3.00 deg per 100 ft 12.00 15.00 ~ 18.00 ,~ 2'~.oo ~, 30.00 35.00 EOC p West Sak Bose West Sok 7 5/8 Casing Pt Cre~ted by bmichcel For: T Brockway Dote plotted: 15-Feb-200O [ Plot Reference [e 17 Verelon 24, I Co~rdlnoB! ore In feet regerence slot ~17. [ T~e Ve~l ~ihs~~ RKB (Nordic III). 312.32 AZIMUTH ***Plone of Proposol*** AVERAGE ANGLE 33.17 DEG /.':' L' ~; DLS: 2.00 deg per 100 ft Tgt-T/C4 - EOD Begin Angle Drop 52.00 50.00 28.00 26.00 24-.00 Base HRZ 22.00 TTooP ,K. up I~ p ~up A.. Top Kup A'~ l~oD Kup A5 T/KUPA2 - B/ A3 TD - Cs§ Pt TARGET ANGLE 20 DEG 550 700 1050 1400 1750 21 O0 2450 2800 5150 $500 Verfical Secfion (feet) -> Azimufh 312.32 wifh r~f~mn¢, 0.00 N, 0.00 E from slof #17 i 3850 Cn~ted by' brnrchael For: T Brockway Dete plotted: 15-Feb-Z(X~O PI~ Refemn~ 1. 17 Vo~n ~4. Coo~;no~ om ~n ~et m~ce slot ~17. T~O Ve~cOI ~~~ce__ eKB (No~;C I,1).l ARCO Alaska, Inc. Structure: Pod 2H Well : 17 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 · ~000 I I I I I I I I I II I I I I I I I I I I I I I I I I 2800 2600 TD LOCATION: 2207' FSL, 2555' F-WL SEC. 26, T11N, RSE 2400 2200 TD - Csg Pt . T( K~t A2.- B/ A5 _op up ~ TARGET LOCATION: \Tgp K,up A.4 I L°P ~up ~ 2156' FSL, 24-51' F'WL 2000 · ~OO ~.UO ~ SEC. 26, T11N, RSE / lgf~-T/rC4 - EOB uose HRZ · ¢ /7' ,-- ,.. 800 800 ~7 5/8 Cos~n~ Pt st Sok 600 600 400 ~p~st Sak 400 200 ~C 200 ~ ~r~fms~ ~ aP 0 SURFACE LOCATION: 0 110' FSL, 624' FEL SEC. 26, T11N. RSE 200 , , , , ~ , , , , , , , , ~ , , ~ , , , , ~ ~ , , ~ , 200 2600 2400 ~00 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 <- West (foot) 1800 I 1600 · ,._ 1400 ~ 1200 0 Z 5000 2800 26OO 2400 2200 2OOO 1800 16oo 1400 1200 1000 480 ¢¢0 400 x\ ~2o ,2o] 4O 8O 480 440 ARC~O Alask~a2 I_~.~,_. r,.,:'Z72ZZ,, 560 520 x, 2100 4500 <- West (feet) 4700 1700 9OO 2100 ~oo ~6o ~2o ~8o 240 200 ,~o <- West (feet) 4O 80 600 - 520 400 - 360 80 4O 40 80 40 0 40 8O ARCO Alaska, Inc. Structure: Pod 2H Well: 17 Field: Kuporuk River Unit Location: North Slope, 5700%\ 5500 %. 1800- 5500 5100 1650 1500 0 90O 750 6OO 450 3OO 4900 4700 4500 <- West (feet) 3900 500 4500 4100 3900 5700 3500 900 750 600 450 500 4900 2550 4500 2400 2250 1650 3100 %. 5500 % · 750 2900%\ 2700%% - 600 2500%x 5500 3100 -5OO 2900 <- West (feet) 150 3oo Created by bmichoel FOF." T Dote plotted: 15-Feb-2000 Plot Reference is 17 Version i~4. I Coordinates ore in feet reference slot ~17. Il'rue Vertical Depths ore reference RKB (Nordic III),I ARCO Alaska, Inc. Structure : Pod 2H Well : 17 Field: Kuparuk River Unit Location: North Slope, Alaska Point KOP Base Permafrost EOC Top West Sak Base West Sak 7 5/8 Casing Pt Begin Angle Drop Base HRZ Tgt-T/C4 - EOD Top Kup B Top Kup A Top Kup A4 Top Kup A3 T/ Kup A2 - B/ A3 TD - Csq Pt PROFILE COMMENT DATA MD Inc Dir TVD North 700.00 0.00 312.52 700.00 0.00 1462.06 22.86 312.32 1442.00 101.02 1805.65 55.17 312.32 1744.92 209.53 2312.29 33.17 312.32 2169.00 396.16 2966.96 35.17 312.32 2717.00 657.33 3205.90 33.17 312.32 2917.00 725.35 6202.65 33.17 312.32 5425.43 1829.27 6720.40 22.81 312.32 5882.00 1992.66 6861.10 20.00 312.32 6012.98 2027.24 6874.95 20.00 312.32 6026.00 2030.43 6900.49 20.00 312.32 6050.00 2036.31 6919.65 20.00 312.32 6068.00 2040.72 6949.44 20.00 312.32 6096.00 2047.58 7021.81 20.00 312.32 61 64.00 2064.25 7171.81 20.00 312.32 6304.96 2098.79 East 0.00 -110.93 -250.09 -435.04 -699.87 -796.53 -2OO8.78 -2188.21 -2226.18 -2229.68 -2256.14 -2240.98 -2248.52 -2266.82 -2504.75 V. Sect Deg/lO0 0.00 0.00 150.03 3.00 311.20 3.00 588.39 0.00 946.58 0.00 1077.30 0.00 2716.88 0.00 2959.56 2.00 3010.91 2.00 3015.65 0.00 3024.38 0.00 3030.93 0.00 3041.12 0.00 3065.87 0.00 3117.18 0.00 ARCO Alaska, Inc. Pad 2H 17 slot #17 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 17 VersionS4 Our ref : prop3435 License : Date printed : 15-Feb-2000 Date created : 14-May-1999 Last revised : 15-Feb-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 16 17.458,w150 0 46.601 Slot location is n70 16 18.540,w150 i 4.768 Slot Grid coordinates are N 5948972.486, E 497775.530 Slot local coordinates are 110.00 N 624.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object well path PGMS <O-8873'>,,14,Pad PGMS <O-7550'>,,15,Pad PGMS <O-8530'>,,16,Pad PGMS <0-8052'> ,1,Pad PGMS <0-7865'> PGMS <0-6795'> PGMS <0-6830'> PGMS <0-8110'> PGMS <0-9000'> PGMS <0-8060'> PGMS <0-8800'> PGMS <0-8123'> PGMS <0-7979'>,,lO,Pad PGMS <O-6765'>,,11,Pad PGMS <O-6840'>,,12,Pad PGMS <0-7820'>,,13,Pad ,2,Pad ,3,Pad ,4,Pad ,5,Pad ,6,Pad ,7,Pad ,8,Pad ,9,Pad Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 2H 19-Jun-1992 30.0 0.0 2H 19-Jun-1992 30.0 0.0 2H 19-Jun-1992 79.1 922.2 2H 18-Jun-1992 637.8 600.0 2H 18-~un-1992 697.9 650.0 2H 18-~un-1992 759.5 400.0 2H 18-~un-1992 820.0 0.0 2H 18-~un-1992 866.0 700.0 2H 18-~un-1992 809.6 0.0 2H 18-~un-1992 753.6 0.0 2H 19-Jun-1992 698.0 250.0 2H 19-~un-1992 294.1 0.0 2H 19-2un-1992 281.6 0.0 2H 19-~un-1992 281.6 0.0 2H 19-~un-1992 292.8 722.2 2H 19-~un-1992 63.7 1211.1 O0 700 0 922 2 600 0 650 0 400 0 700 0 700 0 O0 250 0 400 0 O0 400 0 650 0 5060.0 1211.1 Greater Kuparuk Area Leak-Off Test Standard Draft 4 There are several reasons for performing the Leak Off Test at the surface casing shoe, to determine maximum mud weights and maximum allowable shut in pressures are two of these reasons. In the Greater Kuparuk Area it has been decided that the LOT at the shoe would not exceed a 16 ppg EMW. This i 6 ppg EMW allows the wells to be permitted through AOGCC for annular injection and exceeds any known required mud weights to control the reservoir pressure. In some cases the AOGCC may require an additional LOT that goes to break down. Check the well plan or with the AAI drilling engineer assigned to the rig to determine if a second test is required and if so, how much additional hole needs to be drilled prior to performing the test. If a second test is required to satisfy the AOGCC do not exceed the 16 ppg EMW at the shoe prior to consulting the AAI Drilling Engineer assigned to the rig. Contact the project Team Leader if the Engineer can't be reached. Previous tests above 16 ppg EMW at the shoe have damaged the casing cement job. Leak-Off Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. The upper limit of the test will not exceed 16 ppg EMW at the casing shoe without prior consent from the AAI Drilling Engineer assigned to the rig. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 2. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 3. Pull bit into casing shoe and close the annular preventer or pipe rams. 4. Determine the surface pressure required to obtain 16 ppg EMW at the shoe with the weight of mud in use. 5. The AOGCC requires this test to be charted. Make sure chart recorder is working and ready. Send chart to the AAI Engineer assigned to the rig along with the other rig mail. . Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the formation breaks down or the 16 ppg EMW is reached. Do not exceed 16 ppg EMW. If the well breaks down prior to reaching the 16 ppg EMW continue pumping an additional three bhls of mud prior to shutting down the pumps, to satisfy AOGCC requirements. Record the breakdown pressure and record the bleed off pressures at one minute intervals for a minimum of 10 minutes. The AOGCC suggests that a good test will have a stabilized pressure for 10 minutes (this may be incorporated into the new regulations). If pressures have not stabilized after holding the test for 15 minutes total, check for surface leaks. If surface leaks are discovered repair them and do the test over. 7. Bleed back mud from the well and compare with volume pumped on the test. Contact the AAI Drilling Engineer assigned to the rig if the LOT is below the minimum outlined in the well plan, prior to drilling ahead. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 9. Plot the casing and leak-off tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 Greater Kuparuk Area Formation Integrity Test Standard Draft 4 Some wells do not need to go to full leak-off. In those cases, a Formation Integrity Test will be pertbrmed. For instance, if it is known that the Kuparuk formation will be top set, a Formation Integrity Test is all that is necessary. Consult with the AAI Drilling Engineer assigned to the rig if it is unclear whether you need to do a Leak-Off Test or a Formation Integrity Test. Formation Integrity Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. 1. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 2. Pull bit into casing shoe and close the annular preventer or pipe rams. 3. Determine the surface pressure required to obtain the desired EMW at the shoe. 4. This test needs to be charted. Make sure the chart recorder is working and ready. Send the chart to the AAI Drilling Engineer assigned to the rig along with the other rig mail. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the desired surface pressure is reached. Record the initial shut in pressure and record the pressure at one minute intervals for a minimum of 10 minutes. If pressure is bleeding off check for surface leaks. If surface leaks are discovered repair them and do the test over. 6. Bleed mud back from the well and compare with volume pumped on the test. . Contact the AAI Drilling Engineer assigned to the rig if the well breaks down before reaching the desired EMW, prior to drilling ahead. Contact the Drilling Team Leader if the Engineer can't be reached. 8. Plot the casing and formation integrity tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 16" D~ERTER SCHEMATIC-~.~ordic Rig 3 Kuparuk River Unit Operations J 3 Open ! Closed ~r ~ "L _ Closed , _ _ ..~' ~- To Accumulator I From ~- .... Accumulator Open Maintenance & Operation 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 16" Conductor 2. 16-3/4" 2000 psi Slip-on Weld Starting Head (Quick Connect) 3. 16-3/4" x 21-1/4" 2000 psi, Double-Studded Adapter Flange 4. 16" Diverter Spool with APl 21-1/4" 2000 psi Flanges 5. 21-1/4" Schaefer 2000 psi Annular Preventer 6. 16" Knife Valve. The valve opens automatically upon closure of annular preventer. 7. 16" Diverter Line TAB, 07/19/99, v2 11" 5( 0 psi BOP Stack-- NC Jic Rig 3 Kuparuk River Unit Operations I Kill Line 4 I Choke Line Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 7-1/16" x 11" 5000 psi Adapter Spool 3. 11" 5000 psi Double Flange Adapter/Spacer Spool 4. 11" 5000 psi Hydril Type V Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ manual locks 5. 11" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 6. 11" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 7. 11" 5000 psi Hydril Annular Preventer TAB, 09/30/98, v.1 Subject: 2H-17 APD Date: Tue, 22 Feb 2000 16:09:20 -1000 From: "Thomas A Brockway" <TBROCKW@mail.aai.arco.com> To: tom_maunder@admin.state.ak, us CC: "Chip Alvord" <CALVORD@mail.aai.aroo.com>, "Brian D Noel" <BNOEL@mail.aai.aroo.com> Tom, As we discussed this morning, the Nordic Rig 3 drilling schedule has been accelerated and as a result the spud date on KRU well 2H-17 has been moved up from the March 1,2000 date indicated on the permit to drill application currently under review by your office. The new proposed spud date for this well is February 27, 2000 and I would appreciate any help that you could give me in expediting the permit reviewto meet this spud date. If you have any questions or concerns, please don't hesitate to give me a call at 263-4135 or page me at 267-9586. Thanks, Tom Brockway Operations Drilling Engineer 263-4135 PAY TO THE ORDER QF: CHF~C~,'. The First National Bank of Chicago-O'710 Chicago, Illinois payable Through RepubliC Bank ShelbyVtlle, Kentucky TRACE NUMBER: 249006594 WELL NAME ,2./-/- / ~ PROGRAM: exp __ dev v/redrll ~ serv ~'"" wellbore seg __ann. disposal para req __ WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION A_~_P R COMPANY /--,//~//'"'~"~ INIT CLASS ~, 1. Permit fee attached ....................... 2. Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force .......... . . . · Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... . 4. 5. 6. 7. 8. 9. 10. 11 DATE 12. 7---- Z.Z: ~ 13. 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... GEOLAREA ~N ENGINEERING 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... ,4, - ~ 31. Data presented on potential overpressure zones ...... /C ¢¢__/ y 32. Seismic analysis of shallow gas zones ............. "?/~_ Y 33. Seabed condition survey (if off-shore) ............. .,4,/,/---( y 34. Contact name/phone for weekly progress reports [exploratory only~';~ I ~P~_b DATE (~N N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; V~ ~q ~z.~ o o (C) will not impair mechanical integrity of the well used for disposal; ~ I (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: O O Z O c:\msoffice\wordian\diana\checklist (rev. 02/17/00) 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 APPENDIXi ,. No special'effort has been made to chronologically organize this category of information. .o Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Oct 13 14:35:24 2000 Reel Header Service name ............. LISTPE Date ..................... 00/10/13 Origin ................... STS Reel Name ................ UNKNOWN ~O~, O~q ~ Continuation Number ...... 01 ~ Previous Reel Name ....... UNKNOWN ~ Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/10/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION.(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-90250 B. HENNINGSE D. HIEM 2H-17 501032032900 Arco Alaska Inc. Sperry Sun 13-OCT-00 MWD RUN 2 AK-MM-90250 B. HENNINGSE D. HEIM 26 lin 8E 110 624 .00 125.08 94.20 RICE VED OCT l'"' 000 Oil & Gas Cons. Corem~issi¢ Anchorage MWD RUN 3 AK-MM-90250 B. HENNINGSE D. WESTER 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 110.0 6.750 7.625 3188.0 6.750 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 3. MWD RUNS 2 & 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). DUE TO A TOOL FAILURE, GAMMA RAY DATA FROM MWD RUN 2 ARE REAL TIME. 4. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D.SCHWARTZ OF PHILLIPS ALASKA DATED 9/28/00. 5. MWD RUNS 1-3 REPRESENT WELL 2H-17 WITH API#: 50-103-20329-00. THIS WELL REACHED A TOTAL DEPTH (TD) 7180'MD, 6320'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 62 0 ROP 111 5 FET 3168 0 RPD 3168 0 RPM 3168 0 RPS 3168 0 RPX 3168 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: STOP DEPTH 7126 0 7181 0 7133 0 7133 0 7133 0 7133 0 7133 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 62.0 3206.0 2 3206.0 4664.0 3 4664.0 7181.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 R?M MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 62 7181 3621.5 14239 ROP MWD FT/H 0 2148.31 119.816 14102 First Reading 62 111.5 Last Reading 7181 7181 GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR 18 95 0 38 0 O6 0 O6 0 02 0 13 548.06 2000 2000 2000 2000 71.15 124.038 14080 4.001 7931 4.02532 7931 9.83745 7931 9.02178 7931 1.64377 7931 62 3168 3168 3168 3168 3168 7126 7133 7133 7133 7133 7133 First Reading For Entire File .......... 62 Last Reading For Entire File ........... 7181 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 62.0 3155.0 ROP 111.5 3204.5 $ LOG HEADER DATA DATE LOGGED: 04-MAR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): memory TD DRILLER (FT): 3206.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .4 MAXIMUM ANGLE: 34.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER 93786 9.875 110.0 Water Based 9.80 110.0 7.8 5OO 5.8 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 125.6 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 62 3204.5 1633.25 6286 ROP MWD010 FT/H 0 483.9 118.824 6149 GR MWD010 API 18.95 202.43 118.88 6187 First Reading 62 111.5 62 Last Reading 3204.5 3204.5 3155 First Reading For Entire File .......... 62 Last Reading For Entire File ........... 3204.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3155.5 4612 5 FET 3168.0 4619 5 RPD 3168.0 4619 5 RPM 3168.0 4619 5 RPX 3168.0 4619 5 RPS 3168.0 4619 5 ROP 3205.0 4666 0 $ LOG HEADER DATA DATE LOGGED: 07-MAR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0.41 DATA TYPE(MEMORY OR REAL-TIME): memory TD DRILLER (FT) : 4664.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 32.1 MAXIMUM ANGLE: 34.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY TOOL NUMBER PB1444GRV4 EWR4 $ ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 PB1444GRV4 6.750 3188.0 Water Based 8.60 40.0 10.0 5OO 4.6 1.700 1.450 1.900 1.800 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 R?S MWD020 OHMM 4 1 68 16 5 R?M MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 75.0 100.1 75.0 75.0 Name Service Unit Min Max Mean Nsam DEPT FT 3155.5 4666 3910.75 3022 ROP MWD020 FT/H 0 443.24 151.636 2923 GR MWD020 API 53.12 548.06 114.05 2866 RPX MWD020 OHMM 1.46 2000 5.47369 2904 First Reading 3155.5 3205 3155.5 3168 Last Reading 4666 4666 4612.5 4619.5 RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR 0.06 2000 0.06 2000 0.02 2000 0.13 71.15 5.5426 2904 21.4474 2904 18. 9987 2904 2.46854 2904 3168 3168 3168 3168 4619.5 4619.5 4619.5 4619.5 First Reading For Entire File .......... 3155.5 Last Reading For Entire File ........... 4666 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR'TOOL CODE START DEPTH GR RPD RPM RPS RPX FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 4613 0 4620 0 4620 0 4620 0 4620 0 4620 0 4666 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : STOP DEPTH 7126.0 7133 0 7133 0 7133 0 7133 0 7133 0 7181 0 10-MAR-00 Insite 0.41 memory 7180.0 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 23.5 34.8 TOOL NUMBER PB1444GRV4 PB1444GRV4 6.750 3188.0 Water Based 10.80 50.0 9.3 50O 2.7 1.850 1.020 2.500 2.000 70.0 136.4 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 t ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 Name Service Unit Min DEPT FT 4613 ROP MWD030 FT/H 8.03 GR MWD030 API 43.02 RPX MWD030 OHMM 0.38 RPS MWD030 OHMM 0.45 RPM MWD030 OHMM 0.54 RPD MWD030 OHMM 0.57 FET MWD030 HOUR 0.26 Max 7181 2148 31 482 62 47 56 38 78 38 32 40 39 18 93 First Last Mean Nsam Reading Reading 5897 5137 4613 7181 102.536 5030 4666.5 7181 136.082 5027 4613 7126 3.15025 5027 4620 7133 3.14882 5027 4620 7133 3.1306 5027 4620 7133 3.2583 5027 4620 7133 1.16732 5027 4620 7133 First Reading For Entire File .......... 4613 Last Reading For Entire File ........... 7181 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/10/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/10/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Services Technical Services Physical EOF Physical EOF End Of LIS File