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186-055
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-11-13_23056_KRU_3I-09_VividLeakDetectLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23056 KRU 3I-09 50-029-21561-00 VIVID Leak Detect Log 13-Nov-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 186-055 T39804 12/4/2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.04 12:40:53 -09'00' Originated: Delivered to:9ͲOctͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#13IͲ09 50Ͳ029Ͳ21561Ͳ00 909619414 Kuparuk River Multi Finger CaliperField & Processed 6ͲOctͲ24 0 123JͲ02 50Ͳ029Ͳ21398Ͳ00 ALSL770Ͳ15 Kuparuk River Multi Finger CaliperField & Processed 8ͲSepͲ24 0 133MͲ26 50Ͳ029Ͳ22431Ͳ00 909593342 Kuparuk River Plug Setting Record FieldͲFinal 28ͲSepͲ24 0 145678910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39697T39698T39699186-055185-163193-19310/21/2024Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.10.21 10:53:44 -08'00'186-055185 1633IͲ0950Ͳ029Ͳ21561Ͳ00 909619414KuparukRiverMultiFingerCaliperField&Processed6ͲOctͲ2401T39697 Originated: Delivered to:9ͲOctͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#12AͲ04 50Ͳ103Ͳ20026Ͳ00 909593518 Kuparuk River Plug Setting Record FieldͲFinal 29ͲSepͲ24 0 122AͲ05 50Ͳ103Ͳ20030Ͳ00 909524907 Kuparuk River Plug Setting Record FieldͲFinal30ͲAugͲ24 0 132AͲ11 50Ͳ103Ͳ20057Ͳ00 909594128 Kuparuk River Multi Finger CaliperField & Processed 4ͲOctͲ24 0 142AͲ12 50Ͳ103Ͳ20058Ͳ00 909524545 Kuparuk River Multi Finger CaliperField & Processed 22ͲAugͲ24 0 152AͲ12 50Ͳ103Ͳ20058Ͳ00 909524545 Kuparuk River Packer Setting Record FieldͲFinal 24ͲAugͲ24 0 162GͲ10 50Ͳ029Ͳ21140Ͳ00 n/a Kuparuk River Multi Finger CaliperField & Processed 23ͲAugͲ24 0 172MͲ07 50Ͳ103Ͳ20178Ͳ00 ALSL765Ͳ008 Kuparuk River Multi Finger CaliperField & Processed 15ͲSepͲ24 0 182NͲ329 50Ͳ103Ͳ20257Ͳ00 909593520 Kuparuk River Packer Setting Record FieldͲFinal 20ͲSepͲ24 0 192ZͲ10 50Ͳ029Ͳ21378Ͳ00 909593519 Kuparuk River Multi Finger CaliperField & Processed 25ͲSepͲ24 0 110 3IͲ09 50Ͳ029Ͳ21561Ͳ00 909619414 Kuparuk River Leak Detect Log FieldͲFinal 5ͲOctͲ24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39689T39690T39691T39692T39692T39693T39694T39695T39696184-053184-067186-003186-004184-106192-080198-067185-137186-055T3969710/21/2024Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.10.21 10:49:24 -08'00'3IͲ0950Ͳ029Ͳ21561Ͳ00 909619414KuparukRiverLeakDetectLogFieldͲFinal5ͲOctͲ2401T39697185 137186-055 3I-09 90-Day Bleed HistoryWELL DATE STR-PRES END-PRES DIF-PRES CASING3I-09 2024-05-12 1800 1000 -800 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod ByLast Tag: 8823' RKB (Est.29' of Fill) 8,823.0 3/14/2019 3I-09 zembaejLast Rev Reason Annotation End Date Wellbore Last Mod ByRev Reason: Updated Tag Depth 3/14/2019 3I-09 zembaejCasing StringsCasing DescriptionCONDUCTOR OD (in)16 ID (in)15.06 Top (ftKB)31.0 Set Depth (ftKB)110.0 Set Depth (TVD) …110.0 Wt/Len (l…62.50 GradeH-40 Top ThreadWELDEDCasing DescriptionSURFACE OD (in)9 5/8 ID (in)8.92 Top (ftKB)30.6 Set Depth (ftKB)3,928.1 Set Depth (TVD) …3,239.4 Wt/Len (l…36.00 GradeJ-55 Top ThreadBUTTCasing DescriptionPRODUCTION OD (in)7 ID (in)6.28 Top (ftKB)28.4 Set Depth (ftKB)9,047.2 Set Depth (TVD) …6,408.7 Wt/Len (l…26.00 GradeJ-55 Top ThreadBTCTubing StringsTubing DescriptionTUBING String Ma…2 7/8 ID (in)2.44 Top (ftKB)24.0 Set Depth (ft…8,686.0 Set Depth (TVD) (…6,198.5 Wt (lb/ft)6.50 GradeJ-55 Top ConnectionEUE8rdABMODCompletion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 24.0 24.0 0.03 HANGER FMC TUBING HANGER 2.875 1,800.5 1,750.2 28.36 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 8,597.2 6,145.9 53.66 PBR CAMCO OEJ-10 PBR 2.297 8,614.7 6,156.3 53.69 PACKER CAMCO HRP-1-SP PACKER 2.347 8,653.8 6,179.4 53.74 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,685.4 6,198.1 53.78 SOS CAMCO SHEAR OUT SUB 2.441 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,742.0 8,766.0 6,231.5 6,245.6 A-5, A-3, 3I-09 11/23/1987 4.0 RPERF 2 1/8" EnerJet; 0 deg. ph 8,758.0 8,762.0 6,240.9 6,243.2 A-3, 3I-09 11/23/1987 4.0 RPERF 2 1/8" EnerJet; 0 deg. ph 8,758.0 8,759.0 6,240.9 6,241.5 A-3, 3I-09 11/23/1987 5.0 RPERF 2 1/8" EnerJet; 0 deg. ph 8,762.0 8,763.0 6,243.2 6,243.8 A-3, 3I-09 11/23/1987 5.0 RPERF 2 1/8" EnerJet; 0 deg. ph 8,762.0 8,766.0 6,243.2 6,245.6 A-3, 3I-09 11/23/1987 4.0 RPERF 2 1/8" EnerJet; 0 deg. ph 8,780.0 8,784.0 6,253.8 6,256.1 A-2, 3I-09 11/23/1987 4.0 RPERF 2 1/8" EnerJet; 0 deg. ph 8,784.0 8,785.0 6,256.1 6,256.7 A-2, 3I-09 11/23/1987 5.0 RPERF 2 1/8" EnerJet; 0 deg. ph 8,784.0 8,788.0 6,256.1 6,258.5 A-2, 3I-09 11/23/1987 4.0 RPERF 2 1/8" EnerJet; 0 deg. ph 8,788.0 8,789.0 6,258.5 6,259.0 A-2, 3I-09 11/23/1987 5.0 RPERF 2 1/8" EnerJet; 0 deg. ph 8,788.0 8,800.0 6,258.5 6,265.5 A-2, 3I-09 11/23/1987 4.0 RPERF 2 1/8" EnerJet; 0 deg. ph 8,812.0 8,814.0 6,272.5 6,273.6 A-1, 3I-09 12/13/1996 4.0 RPERF 2 1/8" EnerJet; 90 deg. ph 8,814.0 8,832.0 6,273.6 6,284.1 A-1, 3I-09 12/13/1996 5.0 RPERF 2 1/8" EnerJet; 90 deg. ph 8,832.0 8,852.0 6,284.1 6,295.8 A-1, 3I-09 5/25/1986 4.0 APERF 4" Csg Gun HJ II Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,423.1 2,249.5 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/26/1986 2 4,666.7 3,707.3 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/26/1986 3 6,031.4 4,541.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/26/1986 4 6,723.6 4,971.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/26/1986 5 7,198.7 5,278.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/26/1986 6 7,670.8 5,582.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/26/1986 7 8,109.8 5,854.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/26/1986 8 8,551.5 6,118.8 MMH FMHO 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/18/2018 Notes: General & Safety End Date Annotation 11/15/2010 NOTE: View Schematic w/ Alaska Schematic9.0 CommentSSSV: TRDP3I-09, 3/15/2019 7:11:35 AMVertical schematic (actual) PRODUCTION; 28.4-9,047.2 APERF; 8,832.0-8,852.0 RPERF; 8,814.0-8,832.0 RPERF; 8,812.0-8,814.0 RPERF; 8,788.0-8,800.0 RPERF; 8,788.0-8,789.0 RPERF; 8,784.0-8,788.0 RPERF; 8,784.0-8,785.0 RPERF; 8,780.0-8,784.0 RPERF; 8,762.0-8,766.0 RPERF; 8,762.0-8,763.0 RPERF; 8,758.0-8,762.0 RPERF; 8,758.0-8,759.0 RPERF; 8,742.0-8,766.0 SOS; 8,685.4 NIPPLE; 8,653.8 PACKER; 8,614.7 PBR; 8,597.2 GAS LIFT; 8,551.5 GAS LIFT; 8,109.8 GAS LIFT; 7,670.8 GAS LIFT; 7,198.7 GAS LIFT; 6,723.6 GAS LIFT; 6,031.4 GAS LIFT; 4,666.7 SURFACE; 30.6-3,928.1 GAS LIFT; 2,423.1SAFETY VLV; 1,800.5CONDUCTOR; 31.0-110.0HANGER; 24.0 KUP INJ KB-Grd (ft)35.99 Rig Release Date3/15/1986AnnotationLast WO:End Date 3I-09H2S (ppm) Date...TDAct Btm (ftKB)9,200.0Well AttributesField NameKUPARUK RIVER UNIT Wellbore API/UWI500292156100 Wellbore StatusINJ Max Angle & MDIncl (°)54.70 MD (ftKB)9,000.00WELLNAME WELLBORE3I-09 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, September 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3I-09 KUPARUK RIV UNIT 3I-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/12/2023 3I-09 50-029-21561-00-00 186-055-0 W SPT 6155 1860550 1539 2890 2890 2890 2890 410 500 500 500 4YRTST P Brian Bixby 7/16/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3I-09 Inspection Date: Tubing OA Packer Depth 570 1820 1765 1760IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230718164107 BBL Pumped:1.3 BBL Returned:1.3 Tuesday, September 12, 2023 Page 1 of 1 MEMORANDUM TO: Jim Regg n Cj P.I.Supervisor Key sh(m FROM: Matt Herrera Petroleum Inspector Well Name KUPARUK RIV UNIT 31-09 Insp Num: mitMFH190723100725 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 24, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 31-09 KUPARUK RIV UNIT 31-09 Src: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-21561-00-00 Inspector Name: Man Herrera Permit Number: 186-055-0 Inspection Date: 7/21/2019 Packer Well 3109 ]Tpe j w -ITVD PTD I860550 ]Type Test�l saT Test psi BBL Pumped: 1.4 BBL Returned: Interval j 4vRTST P/P Notes: MIT -IA to 1800 PSI Per Operator Depth Pretest Initial 15 Min 30 Min 45 Min 60Min 6U5 Tubing '830 1330 Uo _1810 - 1539 IA - 400 1805 - 1765 - 1760 1.4 OA 440 - 595 595 '9'- 1' ✓ Wednesday, July 24, 2019 Paec I d I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg %7 DATE: Wednesday,July 08,2015 P.I.Supervisor K Qf 481 6 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 31-09 FROM: John Crisp KUPARUK RIV UNIT 3I-09 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3I-09 API Well Number 50-029-21561-00-00 Inspector Name: John Crisp Permit Number: 186-055-0 Inspection Date: 7/3/2015 Insp Num: mitJCr150707104019 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3109 1Type Inj TVD 6155 Tubing 2825 T 2825 2825 2825 PTD j 1860550 ,Type Testi SPT Test psi 1539 IA 770 2100 2020 2010 -- — Interval 4YRTST p/` P OA 200 340 - 350 350 Notes: 1 6 bbls pumped for test SCANNED r► Wednesday,July 08,2015 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday, July 19, 2011 P.I. Supervisor 1 `e(� Jl r/ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 31 -09 FROM: John Crisp KUPARUK RIV UNIT 31 -09 Petroleum Inspector Src: Inspector Reviewed By: P.I. NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3I -09 API Well Number: 50- 029 - 21561 -00 -00 Inspector Name: John Crisp • Insp Num: mitJCr110717144855 Permit Number: 186 -055 -0 Inspection Date: 7/16/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ' 31 - ' Type Inj. W TVD I 6155 - I IA 998 3265 - 3393 3175 : P.T.D 1860550 TypeTest i SPT Test psi 1538 - OA 600 880 880 880 Interval 4YRTST _ P/Ii' P - Tubing 2750 2750 2750 2750 Notes: 2.7 bbls pumped for test. Tuesday, July 19, 2011 Page 1 of 1 • ConocoPhillips ~~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • r- .,. . ~.~,. ~~; ~j i ~6~# n t-~ ` ~, n -' a~~~'~~~'l.~ ~~•~~~ w `~ Gtr ~~~~~ 1 ~~ ~, Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped Apri17~' , 2009. The corrosion inhibitor/sealant was pumped April 15th and 16~', 2009. 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, l Perry Klein ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 4/17/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 31-01 185-307 58' 10.10 4' 1" 4/7/2009 4.40 4/15/2009 31-03 185-309 69 '8" 10.20 4' 3" 4/7/2009 8.50 4/15/2009 31-04 185-310 26' 4" 4.10 2' 4/7/2009 3.40 4/15/2009 31-05 186-036 76' 12.70 3' 6" 4/7/2009 8.50 4/15/2009 31-08 186-040 8' 6" 1.20 1' 9" 4/7/2009 3.40 4/15/2009 31-09 186-055 40' 5.10 1' 9" 4/7/2009 3.40 4/15/2009 31-11 189-035 1' 9" N/A N/A N/A 2.60 4/16/2009 31-12 186-060 44' 6.80 1' 11" 4/7/2009 2.60 4/16/2009 31-13 189-025 SF N/A N/A N/A 2.50 4/16/2009 31-14 186-062 77' 11.30 2' 11" 4/7/2009 8.50 4/16/2009 31-16 189-022 24' 3.54 1' 7" 4/7/2009 2.30 4/16/2009 31-17 189-024 37' 3.64 1' 7" 4/7/2009 2.00 4/16/2009 . . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU /31 07/31/07 Greenwood/lvesl Bates Chuck Scheve - (Waived) - Fog and rig move fQt()s& \QJ Packer Depth Pretest Initial 15 Min. 30 Min. Well 31-02 I Type Inj. W TVD I 6,228' Tubing 2770 2770 2770 2770 Interval 4 P.T.D.!1853080 I Type test I P Test psil 1557 Casing 925 2020 2010 2010 P/F P Notes: OA 190 210 210 210 wellbl-06 Type Inj. W TVD 6,064' Tubing 2700 2700 2700 2700 I nterval 4 P.T.D.!1890380 Type test! P Test psil 1516 Casing 790 2060 2000 1990 P/FI P Notes: OA 680 840 840 840 wellbl-07 I Type Inj. W TVD I 6,119' Tubing 2900 2900 2900 2900 I nterval 4 P.T.D.!1860390 Type test! P Test psi11529. 75 Casing 100 2050 2010 2000 P/FI P Notes: OA 400 500 500 500 Well 31-09 Type Inj.1 N TVD 6,156' Tubing 2330 2350 2350 2350 I nterval 4 P .T.D. I 1860550 Type test! P Test psi I 1539 CasinQ 830 1880 1870 1870 P/FI P Notes: S/I for pressure management OA 200 230 230 230 We1l131-12 I Type Inj.1 W TVD I 5,031' Tubing 2650 2650 2650 2650 Interval 4 P.T.D.!1860600 I Type test! P Test psil 1500 Casing 775 2030 2020 2020 P/FI P Notes: OA 210 230 230 230 Well 31-13 I Type Inj.1 W TVD I 6,059' TubinQ 2670 2670 2670 2670 Interval I 4 P.T.D.!1890250 I Type test! P Test psi11514.75 CasinQ 1160 2080 2030 2025 P/FI P Notes: OA 780 890 880 880 Well!3I-14 I Type Inj.1 W TVD 6,092' Tubing 2570 2560 2560 2560 Interval I 4 P.T.D.!1860620 I Type test! P Test psi I 1523 Casing 820 2060 2030 2020 P/F P Notes: OA 90 150 150 150 Well 31-16 I Type Inj.1 W TVD I 5,940' TubinQ 2900 2900 2900 2900 Interval 4 P.T.D.!1890220 I Type test I P Test psi! 1500 Casing 700 1920 1860 1920 P/FI P Notes: OA 460 620 620 620 D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer survs~liMI\I~n A=TemperatureAnomalySurvey W'WUUiIIiooI AUG 0 D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = other (describe in notes) 6 2007 "," 2007-0731_MIT _KRU_31-16.xls MEMORANDUM TO: Jim Regg \~>, {' ~[~ 04- P.I. Supenisor 1 '( FROM: Lou Grimaldi Petroleum Inspector \Vell Name: KUPARUK RIV UNIT 31-09 Insp Num: milLG04071312S61S Rellnsp Num: Packer Well I 31-0~ Type Inj. P TVD P.T. I 18605:>0 TypeTest _SPT Test psi I Inten'al -IYRTST P/F P Notes: Good lest. no problems. \\lednesda~. July 14. 2004 State of Alaska Alaska Oil and Gas Consen'ation Commission DATE: Wednöda). Jul) 14. 2(¡O" SlIBJECT: f\lechanlcJllnlegTlt) TestS CONOCOPHILLlPS ALASf.:...A rNC 31-(19 KUPARUK R1V UNIT 31-09 Src: Inspector NON-CONFIDENTIAL API \Vell Number: 50-029-21561-00-00 Permit Number: 186-055-0 Re\'iewed By: P.I. Supr\' ~:J:sr,- Comm Inspector Name: Lou Grimaldi Inspection Date: 7/13/2004 Depth Pretest Initial 15 1\1 in. 30 Min. 45 Min. 60 Min. 6-196 IA 125(1 17()(1 1690 I 1690 1539.25 OA 520 58(1 580 I 580 Tubing I l'¡~Li 2-120 2-120 -I ~-I~() Page I of I MEMORANDUM TO: Dan Seamount ~)1~'~/'~ CommiSsioner THRU: Blair Wondzell P.I. Supervisor ~..(. FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Sept. 1,2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 31 Pad 31-02, 31-06, 31-07, 31-09, 31-12, 31-13, 31-14, 31-16 KRUIKuparuk River Field NON- CONFIDENTIAL WellI 31-02 P.T.D.I Notes: I P.T.D.I Notes: VVe"I 3~-07 P'T'D'I 1860390 Notes: WellI 31-09 P.T.D.I 1860550 Notes: WellI 31,12 P.T.D.I 1860600 1853O80 Packer Depth Pretest Initial 15 Min. 30 Min. I Type~ni.I .S IT'V'D' I 6228 ITubingi 292O I 29201 2920J 292O I~nter~a~l 4 ITypetestl P. ITestpsil 1557 I Casingl 1o0o118101181o118o01 P/F 3,-06 I Type,nj.IS ~l~.V.O. I 6084 ITubingl ~001 ~001 ~001 ~00 I,nterv.,I 4 1890380 ITypetestl P ITestpsil 1516 I Casingl 980 I 184011800117901 P/F I P I Typelnj.IS I I ~ I Tubingl 2850 I I ! ~,so Ilntervall 4 TypetestI P' ITestpsil 1530 I casingl 118O1172O117OO117OOI P/F I _,P I TyPelnj. I S IT:V'D' I 6156 ITubingl 2850 I 2850 I 2850 I 2850 I lntervall' 4 ' Type testI P I Testpsil 1539 ICasingI 1O50118001179O11785I P/F I P I TY,e~.i.I .s I T.V.D. I 508~ ITuUingl 2~0 I 2~00 I 2~00 I 2,00 I~n~l ~ TyPe testI P I Testpsil 1258 I CasingI 760 1189o118601185o1 P/F I P' I Notes: WellI 31-13 I Typelnj. I S I T.V.D. I 8059 ITubingl 2950I 2950I 29501'2950 I lntervall 4 P.T.D.I 1890250 ITypetestl P I TestpSil 1515 ICasingI 700 I 1830 I 1790 J 1780 I P/F I P Notes: WellI 31-14 ITypelnj.I S I T.V.D. I 6092 I Tubingl 2880 I 2880. 2880 I 2880 ,Intervall 4 P.T.D:I 1860620ITypetestl P ITestpsil 152.3 I Casingl 1320 I 1640 I 4810 I 1610I P/F I P Notes: WellI 31,16 I Typelni. I N IT'V'D' I 5940 ITubingl 1280 I 1280 I 1280 I 1280 I lntervall 4 P,T.D..I 1890220 ITypetestl P I Testpsil 1485 ICasingl 1200 I 1860 I 1740 I 1730I P/F I P Notes: Type INJ. Fluid Codes F = FRESH WATER IN J, G -- GAS INJ. S = SALT WATER INJ. · N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard PreSsure TeSt .R= Internal Radioactive TraCer Survey A= Temperature Anomaly Survey D-- Differential TemperatUre TeSt Interval I= Initial TeSt' 4= Four Year Cycle V= Required by Vadance W= Test dudng Workover O= Other (describe in notes) Test's Details Frida)', Sept. ~ ZOO0: I tra¥clcd to Phillips Alaska ]ac.'s KRU 3I pad to wimcss thc 4 ycar MTT's on wells fi 02, 06, 07, 09, 12, 13, 14, 16. Jerry Dcthlefs was thc PIA rep. In charge of testing. The standard annulus pressure test was performed with all eight wells passing the 30 minute pressure test. Summar3,.: I witnessed eight successful MIT's on PIA's KRU 3I Pad. .I.T.'s Performed: _8 . Number of Failures: Attachments: Well schematics {8) 0 Total Time during tests: 3 hrs CC; MIT report form 5/12/00 L.G. MIT KRU 31 9-1-00 JJ.xls 9/5/00 MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA AL/-~KA OIL AND GAS CONSERVATION COMMISsiON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development __ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 180' FSL, 10' FEL, Sec. 36, T13N, R8E, UM At top of productive interval 891' FNL, 1693' FWL, Sec. 36, T13N, R8E, UM At effective depth 728' FNL, 1539' FWL, Sec. 36, T13N, R8E, UM At total depth 589' FNL, 1407' FWL, Sec. 36, T13N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 92OO 6496 6. Datum elevation (DF or KB) RKB 71 feet , 7. Unit or Property name Kuparuk River Unit 8. Well number 31-09 9. Permit number/approval number 86-55 10. APl number 50-029-21561-00 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet Effective depth: measured 8 9 6 5 true vertical 6360 feet Junk (measured) None feet Casing L e n g t h Structural Conductor 8 0' Surface 3 8 9 7' Intermediate Production 9019' Liner Perforation depth: measured 8742'-8766', true vertical 6230'-6244', Size Tubing Pressure Cemented Measured depth True vertical depth 255 Sx CS II 1 10' 1 10' 1500 Sx CS III & 3928' 3239' 315 Sx Class G 500 Sx Class G & 9047' 6407' 175 Sx PFC 1 6" 9-5/8" i! 8780'-8800', 8812'-8852' 6252'-6264', 6270'-6294' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 8686' Packers and SSSV (type and measured depth) Packer: Camco HRP-I-SP @ 8615'; SSSV: Camco TRDP-1A-SSA @ 1800' 13. Stimulation or cement squeeze summary Reperforated 'Al' sand on 12/13/96. ORIGINAL Intervals treated (measured) 8812'-8832' Treatment description including volumes used and final pressure . Perforated using 2-1/8" EJ guns w/ DP charges, 180° Phasing - 4 spf, fp = 2800 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 0 0 307 950 2884 Subsequent to operation 0 0 478 95O 2861 1,5. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service 17. Signed ~.~,~ ~ ~ Form l~4~)4,,/'R~v/ O~/15~"-~'8 / I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent Date ~'~:.~'~? SUBMIT IN DUPLICATE ARCO Alaska, [ F~os~ Office B,o~ Ar~ch©rage~ Alaska 995~ '}/eie?ho~e ~07 2~6 "i2'iS November 15, 1990 Mr. L. C. Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith' Attached in duplicate is a Report of Sundry Well Operations for the well listed below. WELL ACTION 31-09 Stimulate If you have any questions, please call me at 263-4241. P. S. White Senior Operations Engineer CC: J. R. Brandstetter ATO 1120 L. L. Perini ATO 1130 S. M. Renke ATO 1126 KOE1.4-9 w/o attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 180' FSL, 10' FEL, Sec. 36, T13N, R8E, UM At top of productive interval 891' FNL, 1693' FWL, At effective depth 728' FNL, 1539' FWL, At total depth 589' FNL, 1407' FWL, 5. Type of Well: I 6. Datum elevation (DF or KB) Development __ I Exploratory __ 71' RKB Stratigraphic __ I 7. Unit or Property name Service X I Kuparuk River Unit 1 8. Well number 31-09 Sec. 36, T13N, R8E, UM Sec. 36, T13N, R8E, UM Sec. 36, T13N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 9200' feet 6496' feet feet 9. Permit nqmber/_approval number_ 10. APl number 50-029-21561 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 8956' true vertical 6360' Casing Length Size Structural Conductor 8 0' I 6" Surface 3 8 9 8' 9 - 5 / 8" Intermediate feet feet Junk (measured) None Cemented Measured depth True vertical depth 110' 110' 3928' 3238' 255 Sx CS II 1500 Sx CS III & 315 Sx Class "G" Production 901 9' 7" 500 Sx Class "G" Liner Perforation depth: measured 8742'-8766', 8780'-8800', true vertical 6231 '-6245', 6254'-6265', Tubing (size, grade, and measured depth) 2 7/8", 6.5# J-55 AB mod. tubing with tail set @ 8686' MD Packers and SSSV (type and measured depth) 8814'-8832', 6274'-6284', Camco HRP-1-SP pkr. @ 8615' MD; Camco TRDP-1A-SSA SSSV @ 1800' MD 13. Stimulation or cement squeeze summary hydraulically refractured Kuparuk A sand Intervals treated (measured) 8742'-8852' Treatment description including volumes used and final pressure Pumped 101,000 pounds of 16/20 Carbo-lite with 1469 barrels of gelled water. 14. RePresentative Daily Average Production or In!ection Dat~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 7 5 4 0 0 . Subsequent to operation 3 0 0 4 0 0 1 5. Attachments Copies of Logs and Surveys run __ 1 16. Status of well classification as: Daily Report of Well Operations ..X I Oil Gas Suspended 17. I her~/,~ ~Y certify th{~theI, ,/~'~''''_f°reg°ing is true and correct to the best of my knowledge. Sic~ned I ~,.~~ ' ~ Title Senior Operations Engineer Form 10-404 Rev 06/15/88 Service X 2450 245O SUBMIT IN DUPLICATE ARCO Alaska~''-~ ~ SuDsidiary of Atlantic Ricnfiel(. ,,~. , WELL SERVICE REPORT WELL CONTRACTOR . ~EMARKS FIELD- DISTRICT- STATE OPERATION AT REPORT TIME C..o~pc~'rE tDAYS I DATE goo P_c/ 1130 IZ/y 12- !~oo Io/, o oo~/- I--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots ARCO Alaska, Inc. Bos~ Office B©x ]003(}0 'Feiepho~e 907 276 ORI§INAL July 25, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Woll Action Anticipated Stad Date 31-09 Stimulate August, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J.R. Brandstetter ATO 1120 w/o attachments L. Perini ATO 1130 KOE1.4-9 Alaska Oil & ~_~a~ Cons. Anchorag~ ~,a~aa, hlc. is a Subsid;ary o? Atia,:-~fi:;',~b;:tfi ;i,: ~ ~ ~. STATE OF ALASKA ALASKA OIL AND GAS ~ERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 180' FSL, 10' FEL, Sec. 36, T13N, R8E, UM At top of productive interval 891' FNL, 1693' FWL, Sec. 36, T13N, At effective depth 728' FNL, 1539' FWL, Sec. 36, T13N, At total depth 589' FNL~ 1407' FWL~ Sec. 36r T13N~ 12. Present well condition summary Total Depth: measured 9 true vertical 6 Abandon _ Suspend I Alter casing _ Repair well Change approved program 5. Type of Well: Development _ Exploratory _ Stratigraphic Service X R8E, UM R8E, UM R8E~ UM 200' feet 496' feet Effective depth: measured 8956' feet true vertical 63 6 0' feet 13. Casing Length Size Structural Conductor 8 0' 1 6" Surface 3 8 9 8' 9 - 5 / 8" Intermediate Production 9 01 9' 7" Liner Perforation depth: measured Operation Shutdown _ Re-enter suspended well Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance Plugs (measured) Perforate Other 6. Datum elevation (DF or KB) 71' RKB I 7. Unit or Property name IKuparuk River Unit 8. Well number 31-09 Junk (measured) 9. Permit number feet 10. APl number so.029-21561 11. Field/Pool Kuparuk River Field _ _KuparuK Riv_er~Oi! Pj~ql~ ,~. ,.~ Alaska Oil & Cement~ Measured depth irue ve~lCal oep~n, 255 SX. CS II I 1 0' I 1 0' 1500 Sx CS III & 3928' 3238' 315 Sx Class "G" 500 Sx Class "G" 9 04 7' 6 4 0 7' 8742'-8766', 8780'-8800' 4 SPF 0° phasing; 8814'-8832' 1 SPF 90° phasing; 8832'-8852' 4 SPF true vertical - 6231'-6245', 6254'-6265', 6274'-6284', 6284'-6296' Tubing (size, grade, and measured depth 2 7/8", 6.5# J-55 AB mod. tubing set at 8686' Packers and SSSV (type and measured depth) Camco HRP-1-SP pkr. ~ 8615'~ Camco TRDP-1A-SSA SSSV ~ 1800' Attachments Description summary of proposal _ Detailed operation program Hydraulically refracture the A sand. 90° phasing BOP sketch 14. Estimated date for commencing operation July 1990 Oil I 16. If proposal was verbally approved Name of approver Date approved Si~n,ed ~r ~!~ . Title Sr. Operations Engr. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test_ Subsequent form require 10- ~/~ 15. Status of well classification as: Gas ~ Suspended Service Water Iniector Date '7"' IApproval No. Approved b~/ the order of the Commission Form 10-403 Rev 5/03/8g Commissioner Date Ir- SUBMIT IN TRIPLICATE ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Application for Sundry Approval Kuparuk Well 31-09 July 12, 1990 1. The estimated bottom hole pressure is 2300 psig at-6200' ss. 2. No workover fluids will be required for refracturing the well. Pre 1, 10. Kuparuk Well 31-09 A Sand Refrac Procedure Cost Tracking AFE: # K81310 -Frac Tag fill (end of tubing Iocator should be utilized to check accuracy of wireline measured depth). 2. Set standing valve in 'D' nipple @ 8654' MD-RKB. 3. Pull dummy valve from 1-1/2" GLM @ 8552' MD-RKB. 4. Set circ valve in 1-1/2" GLM @ 8552' MD-RKB. 5. Displace 7" x 2-7/8" annulus with 260 barrels of 9.8 ppg NaCI brine. The freezing of 9.8 ppg brine is -5° F while the freezing point of 10.0 ppg brine is 25° (not acceptable for wellbore freeze protection). Therefore, it is very important that the density of the brine be held to 9.8 _+ 0.1 ppg. 6. Pull circ valve from 1-1/2" GLM @ 8552' MD-RKB. 7. Set dummy valve in 1-1/2" GLM @ 8552' MD-RKB. 8. Pull standing valve from 'D' nipple @ 8654' MD-RKB. 9. Make sure the tubing is fluid filled to surface and pressure test 7" annulus to 2500 psi. Shut well in 48 hours prior to the refracture treatment in order to allow the reservoir pressure to fall-off. Fracture Treatment Quality Control: 1. Check all tanks for cleanliness and check proppant for fines. uncontaminated. Insure water is 2. Insure adequate proppant and water are on location for the frac. 3. Perform pre-frac quality control tests on gelled water using water which has been delivered to the drill site for the frac. Frac Job' 1. MIRU fracturing equipment. Install tree saver and pressure test all surface lines. 2. Pressure up 2-7/8" x 7" annulus to 3000 psi. Do not allow this pressure to exceed 3500 psi during fracture treatment. Maximum allowable wellhead treating pressures are shown below as a function of annulus pressure. annulus pressure (psi) *maximum WHTP (psi) 2500 6100 3000 6600 3500 7100 * Well 31-09 has 2-7/8", 6.5 Cf/ft., J-55 tubing· Maximum WHTP's ~p~.,.e...ar~ based 100% of the MYS of 2-7/8" J-55 tubing ~¢ i:~. ,( L. ! ~,~;, . , . Pump 150 barrel gelled water breakdown stage, shut-down for ISIP, and check for excess friction. Check tank straps against flow meter and correct flush volume as necessary. Pump fracture treatment per attached schedule starting with a 900 barrel gelled water pad. The following gelled water systems are acceptable for the refracture treatment: Halliburton' Hybor Dowell: YF240D B.J. Titan' RXL The expected treating pressure is 5200 psi based on the following' Fracture gradient = 0.850 psi/ft (6231' TVD) Tubing friction = 0.300 psi/ft (8686' MD) Fluid gradient = 0.437 psi/ft (6231' TVD) Estimated perf friction = 0 psi 6. If necessary, cut rate in 1 BPM increments down to 16 BPM during job to reduce WHTP. 7. Bleed down annulus to 500 psi. Rig down fracturing equipment. Post-Frac Flowback 1. Obtain representative fluid samples from the pad, slurry, and flush stages during the fracture treatment. Operations Engineer: Place samples in hot water bath at 150° F to observe break time. Operations Engineering will contact the foreman after the gel has broken completely. Wait at least 24 hours after the refracture treatment before re- initiating injection into the well. 2. Tag fill (end of tubing Iocator should be used to check accuracy of wireline measured depth). 3. Set standing valve in 'D' nipple @ 8654' MD-RKB. 4. Pull dummy valve from 1-1/2" GLM @ 8552' MD-RKB. 5. Set circ valve in 1-1/2" GLM @ 8552' MD-RKB. 6. Pump down tubing with 310 barrels of diesel to displace tubing and 7" x 2-7/8" annulus. The brine will be recovered from the annulus into a flowback tank. 7. Pull circ valve from 1-1/2" GLM @ 8552' MD-RKB. 8. Set dummy valve in 1-1/2" GLM @ 8552' MD-RKB. 9. Pull standing valve from 'D' nipple @ 8654' MD-RKB. Kuparuk Well 31-09 Refracture Treatment STAGE CLEAN VOLUME PROPPANT DIRTY VOLUME CUMULATIVE STAGE HITS (BBL) (POUNDS) (BBL) DIRTY VOL (BBL) PERFS ¢ (BBL) BREAKDOWN (GW) 150 0 150 150 52 PAD (GW) 900 0 900 1050 202 SLURRY (GW) 2 PPG 64.3 5404 70 1120 1102 4 PPG 68.0 11425 80 1200 1172 6 PPG 71.2 17936 90 1290 1252 7 PPG 76.4 22467 100 1390 1342 8 PPG 73.9 24840 100 1490 1442 10 PPG 41.6 17490 60 1550 1542 12 PPG 13.1 6593 20 1570 1602 FLUSH (GW/SD) 50 0 50 1620 - TOTAL 1509 106155 1620 TOTAL GW 1469 TOTAL SD 4O VOLUME TO PERFS (BBLS) = 52.4 GW-- GELLED WATER SD -- SLICK DIESEL PROPPANT = 16/20 MESH (CARBO-LITE OR LWP) PUMP RATE = 20 BPM (drop rate to 16 BPM if necessary) ESTIMATED TREATING PRESSURE = 5200 psi BREAKDOWN = GW + 40 LB/1000 GAL SILICA FLOUR + BREAKER PAD = GW + 40 LB/1000 GAL SILICA FLOUR + BREAKER SLURRY = GW + BREAKER (NO SILICA FLOUR) FLUSH = 10 BBLS GW + BREAKER (NO SILICA FLOUR) FOLLOWED BY 40 BBLSC~SD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT 'OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [; Stimulate [] Plugging L~ Perforate [-] Pull tubing Alter Casing 23 Other X, 2. Name of Operator ARCO Alaska, Inc. 3. ~,d~res~ v.u. pox 100360, Anchorage, Alaska 99510 4.L~ior~[,well d(~rf~t, Sec. 36, T13N, R8E, UM Attop, of productive interval 891 FNL, 1693' FWL, Sec. 36, T13N, R8E, UM At_effective dep. t h 728' FNL, 1539' F~L, Sec. 36, T13N A~fl ¢~_t,h 1407' FWL, Sec. 36, T13N , R8E, UM , R8E, UM 11. Present well condition summary 9200' Total depth: measured 6496' feet Plugs (measured) 5. Datum elevation (DF or KB) RKB 71 ' Feet 6. Unit or Property name Kuparuk River Unit 7. We113r~u_r~e r ! 8.~proval number,,.. ~ 86-55 9. ~PI number 50-- 029-21561-00 true vertical feet '8965' measured 6360' feet true vertical feet Effective depth: Casing Length Structural 80' Conductor Surface 3898' Intermediate 9019' Production Liner Perforation depth: measured true vertical Size 16" 9-5/8" 7" 10. POOIKuparuk River Oil Pool REC[iV F D Junk (measured) Cemented Measured depth True Vertical depth 255 Sx CS II 110' 110' 3928' 3238' 9047' 6407' 1500 Sx CS III & 315 Sx Class "G" 500 Sx Class "G" Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 8758' 8762' 8784' 8788' 8814' -8832' 8832' -8852' MD 6239' 6242' 6255' 6257' 6272' -6283' 6283' -6294' TVD , , , , ~ 2 7/8", J-55 tbg w/tail @ 8686' HRP-I-SP pkr @ 8615' & TRDP-1A-SSA SSSV @ 1800' 12. Stimulation or cement squeeze su.m. m_a_ry . Well converted from oil producer to water injector. Intervals treated(measured) First injection occurred 11-23-87. Preparation for injection included a CTU fill cleanout and adding additional perfs. Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation · Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 90 80 0 450 120 0 0 320 1100 2300 13. 14. Attachments Daily Report of Well Operations J~ Copies of Logs and Surveys Run Lq 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~/4.?...£~/. Form 10-404 Rev. 12-~ "-- Date Submit iff Duplicate ~ . ARCO Alaska, Inc_~.~O . ~ubsidlary of Atlantic Richfield Compa~jL CONTR, A~;TOR REMARKS FIELD- DISTRICT- STATE OPERATION AT REPOI~IT TIME WELL SERVICE REPORT iDA? J'-J CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK J Signe~['~ .~ 'ARCO Alaska, Inc(-~ Subsidiary of Atlantic Richfield Company'~ IPBDT v,NTRACTOR REMARKS WELL SERVICE REPORT FIELD- DISTRICT- STATE OPERATION AT REPORT TIME 0?/5' M.z,~. ~ · . · 'ARCO Alaska, In;c~ Subsidiary of Atlantic RichfieldCompan · WELL C~ITRACTOR REMARKS I PBD~30~ IFIELD ' DISTRICT' STATE WELL SERVICE REPORT IDAYS l DATE OPE TION AT RE ORTTIME ~~KUP*RUK OPER*TIONS ENGINEERING CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc~.~- SuDsidiary of Atlantic Richfield Comoany WELL SERVICE REPORT WELL CONTRACTOR REMARKS FIELD.DISTRICT-STATE iDAZ IOPERATI'ON AT REPOR;r TIME DATE iPARUK OPERATIONS ENGINEER' 0 740 - / I'-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~"~'1"'~' Ic'''-~v'''~'''', Iw''v'' RelX~ - 'F - ?..5- °F ] w~ ~.'~ miles ARCO Alaska, Inc Subsidiary of Atlantic Richfield Company WELL CONTRACTOR REMARKS WELL SERVICE REPORT PBDT I FIELD- DISTRICT- STATE DAYS DATE IOPERATION AT REPORT TIME ,,?/- [--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Teml), Chill Factor Visibility Wind Vel. Report °F °F miles Isigr~a'. ARCO Alaska, Inc.~'~ Subsidiary of Atlantic Ricl~field Company WELL CONTR~IOR REMARKS WELL SERVICE REPORT FIELD- DISTRICT- STATE OPERATION AT REPORT TIME IDAYS 1 DATE [-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. / Wind Vel. .o.. o~1c~.,-~,o~~ oF J Visibility mil~ ARCO Alaska, In Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL CONTRACTOR REMARKS I PBDT l FIELD- DISTRICT- STATE IOPERATION AT REPORT.TIME · F'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Wind Vel. ~ .... STATE OF ALASKA ALA,_.,A OIL AND GAS CONSERVATION CON,,,,ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well L] Alter casing I. I Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order rZ] Pedorate [] Other IX 2. Name of Operator ARCO Alaska, [nc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 180' FSL, 10' FEL, Sec. 36, T13N, R8E, UH At top of productive interval 891' FNL, 1693' FWL, Sec. 36, T13N, R8E, UN At effective depth 728' FNL, 1539' FWL, Sec. 36, T13N, R8E, UM At total depth 589' FNL, 1407' FWL, Sec. 36, T13N, R8E, UM 5. Datum ~evation (DF or KB) RKB 71' 6. Unit or Property name Kuparuk River Unit 7. Well number 31-09 8. Permit number #86-55 9. APl number 50-- 029-21561 10. Pool feet Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9200' 6496' feet feet 8965, 6360' feet feet Plugs (measured) Junk(measured) None None Casing Length Structural Conductor 80' Surface 3898' Intermediate Production 9019' Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size 16" 9-5/8" 7" Cemented Measured depth 255 Sx CS II 1500 Sx CS III & 315 Sx Class "G" 500 Sx Class "G" 110' 3928' 9047' 8758' MD, 8784' MD, 8814-8832' MD 8762' MD, 8788' MD, 8832-8852' MD 6239' TVD, 6255' TVD, 6272-6283' TVD 6242' TVD, 6257' TVD, 6283-6294' TVD Packers and SSSV (type and measured depth) 2-7/8"J HRP-I-SP True Vertical depth 110' 3238' 6407' RECEIVED SEP 2 :~ 1987 -55 tbg w/tail @ 8686' Alaska0il&GasC0ns. C0ml Anchorage pkr @ 8615' & TRDP-1A-SSA SSSV @ 1800' 12.Attachments Description summary of proposal Z] Detailed operations program [] BOP sketch Convert well from oil producer to water injector. 13. Estimated date for commencing operation October 1987 14. If proposal was verbally approved Name of approver Subsequent Work Reported on .. Form No./0~ Date approved 15. I hereby certify that the foE,egoing is true and correct to the best of my knowledge Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by Form 10-403 Rev 12-1-85 by order of Commissioner the commission Date ,issl0tl Submit in triplicate~,.-- ARCO Alaska, In Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 11, 1987 Transmittal # 6020 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2Z-4 Dual-Zone PBU 'A'-Sand 7-14-87 2Z-4 Dual-Zone PBU 'C' Sand 7-14-87 2Z-12 Dual-Zone PBU 'C' Sand 7-2-87 2Z-12 Dual-Zone PBU 'A' Sand 7-2-87 2U-15 Pressure Buildup 5-28-87 2W-6 Dual-Zone PBU 'C' Sand 7-15-87 2W-6 Dual-Zone PBU 'A'Sand 7-15-87 3M-9 Static Well Pressure Report 7-26-87 3M-3 Static Well Pressure Report 7-17-87 3M-8 Static Well Pressure Report 7-28-87 2Z-6 Static Well Pressure Report 7-21-87 2Z-8 Static Well Pressure Report 7-25-87 2U-6 Static Well Pressure Report 7-19-87 3I-9 BHP Report 7-16-87 2W-7 Static Well Pressure Report 7-21-87 2X-lO Static Well Pressure Report 7-17-87 2X-14 Static Well Pressure Report 7-17-87 2X-12 Static Well Pressure Report 7-17-87 2W-3 Pressure Buildup Test 7-4-87 2Z-2 Static Well Pressure Report 7-17-87 2Z-6 Static Well Pressure Report 7-13-87 2Z-2 Static Well Pressure Report 7-9-87 2Z-8 Static Well Pressure Report 7-13-87 3M-1 Static Well Pressure Report 7-13-87 3M-2 Static Well Pressure Report 7-13-87 1Y-lO Static Well Pressure Report 4-23-87 1Y-4 Static Well Pressure Report 4-21-87 1Y-4 Static Well Pressure Report 3-3-87 EV AUG 1 ]987 Alaska Oil & Bas Cons. Commission Anchorage Receipt Acknowledged: Date DISTRIBUTION: BP Chevron Mobil SAPC Unocal State of Alaska D &H ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ALASKA C~IL AND GAS CONSERVATION CO,~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ]~]~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Nar~e of Operator 7. Permit Number ARCO Alaska, Inc, 86-55 3. Address 8. APl Number P, O. Box 100360, Anchorage, AK 99510 50- 029-21561 4. Location of well at surface 9. Unit or Lease Name 180' FSL, 10' FEL, Sec.36, T13N, R8E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 891' FNL, 1693' FWL, Sec.36, T13N, R8E, UM 3~.-9 At Total Depth 11. Field and Pool 589' FNL, 1407' FWL, Sec.36, T13N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri ver 0i l Pool RKB 71'I ADL 25523 ALK 2559 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 03/05/86 03/11/86 12/22/86'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey i 20. Depth where SSSV set I 21. Thickness of Permafrost 9200'MD, 6496'TVD 8965'MD, 6360'TVD YES [~ NO [] 1800 feet MD 1650' (approx.) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, Cal, CET/GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE !TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 255 sx CS II 9-5/8" 36.0# J-55 Surf 3928' 12-1/4" 1500 sx CS Ill & 315 sx Class G 7" 26.0# J-55 Surf 9047' 8-1/2" 500 sx Class G & 175 sx PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 8686' 8615' 8758'MD 6239'TVD 1 spf, 90° phasing 8762'MD 6242'TVD I spf, 90° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8784'MD 6255'TVD 1 spf, 90° phasing DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8788'MD 6257'TVD 1 spf, 90° phasing See attached Adderdum, dated 03/24/87, 8814'-8832'MD 6272'-6283'TVD 1 spf, 90° phasin~ for Fracture da1 a. 8832'-8852'MD 6283'-6294'TVD 4 spf, 90° phasinG 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED 'OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE 28. CORE DATA Br[~ndeescription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NOTE: Drilled RR 03/15/86. Well perforated & tubing run 05/25/86. w~a .~.n.n~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate~ 29. ~ 30. GEOLOGIC MARKERS FORMATION. TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8690' 6199' N/A Base Kuparuk C 8700' 6205' Top Kuparuk A 8738' 6228' Base Kuparuk A 8860' 6299' . 31. LIST OF ATTACHMENTS Addendum (dated 03/24/87). 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~"~, //~/)'?,,/)/'-~ .~ !/J-~t~-~ Title Associate Eng~nee~ Date Z~--/,Z~---~-c~7 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 5105186 7/07/86 8/02/86 12/22/86 3I-9 Rn CET/GR/CCL to 8955' WLTD - 7100' WLM. Rn GCT f/surf - 8900'. Rn 6.125" gage ring/JB f/surf - 8965'. Pmp ~250 gal diesel dn 9-5/8" x 7" ann; well not Arctic Pak'd. Arctic Pak w/30 bbls PF "C", followed by 56 bbls Arctic Pak. Frac'd Kuparuk "A" sand perfs 8758', 8762', 8784', 8788', 8814'-8832' & 8832'-8852' in 12 stages per 12/7/86 procedure using Musol, diesel, gelled diesel, 20/40 mesh sand & 100 mesh sand. Press'd ann to 2620 psi w/diesel. Tst ins to 7900 psi; OK Pmp'd by Production: Stage 1: 35 bbls diesel w/5% Musol, 3900 psi, 1BPM Stage 2: 51 bbls diesel @ 1BPM, 4000 psi Pmp'd by Drilling: Stage 3: 100 bbls gelled diesel @ 20 BPM, 5175 psi avg Stage 4: 20 bbls gelled diesel pad @ 5220 psi, 20 BPM Stage 5: 46 bbls gelled diesel w/ 1 ppg 100 mesh sand @ 20 BPM, 5200 psi Stage 6: 308 bbls gelled diesel, 20 BPM, 5540 psi Stage 7: 24 bbls gelled diesel w/2 ppg 20/40 mesh sand @ 20 BPM, 5570 psi Stage 8: 39 bbls gelled diesel w/4 ppg 20/40 mesh sand, 20 BPM, 5760 psi Stage 9: 51 bbls gelled diesel, 5 ppg 20/40 mesh sand, 20 BPM, 6050 psi Stage 10:66 bbls gelled diesel 6 ppg 20/40 mesh sand @ 20 BPM, 6285 psi Stage 11:27 bbls gelled diesel w/8 ppg 20/40 mesh sand @ 6800 psi, 20 BPM Stage 12:51 bbls gelled diesel flush, 7145 psi initial & 6220 psi final press @ 20 BPM (underflush by 2 bbls) Pmp'd 37,683# 20/40 mesh in formation leaving 672# 20/40 mesh sand in csg. Load to recover 783 bbls of diesel/gelled diesel. Job complete @ 1346 hrs, 12/22/86. ADDENDUM WELL: 1/17/87 3I-9 RU CTU, tst BOP & hardln to 4000 psi. RIH to 8575', pmp gel diesel @ 1BPM & N~ @ 300 scf/min. RIH to PBTD @ ±8965'; no appreciableZamt of sand, well not making fluid. Inc Nh tO 600 scf/min & inc discharge temp f/100° to 150°. WshZup & dn across perfs; well started flowing @ ±30 BPH. Displ well w/clear diesel, POOH, RD CTU. Release well to Production. Dr~l ing Sup~.~sor ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 22, 1987 Transmittal #5894 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3N-13 3N-14 3I-9 2X-7 2X-7 CET 5-15-86 6342-7768 CET 5-15-86 5882-7328 CET ,5-5-86 7090-8949 CET 1-5-87 5995-7242 CET 1-8-87 5995-7011 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Date: Mobil SAPC Unocal BPAE Chevron ARCO Alaska, Inc. is a Subsidiary of AllanticRichfleldCompany ADDENDUM WELL: 5105/86 7/07/86 8/02/86 12/22/86 31-9 Rn CET/GR/CCL to 8955' WLTD - 7100' WLM. Rn GCT f/surf - 8900'. Rn 6.125" gage ring/JB f/surf - 8965'. Pmp ±250 gal diesel dn 9-5/8" x 7" ann; well not Arctic Pak'd. Arctic Pak w/30 bbls PF "C", followed by 56 bbls Arctic Pak. Frac'd Kuparuk "A" sand perfs 8758', 8762', 8784', 8788', 8814'-8832' & 8832'-8852' in 12 stages per 12/7/86 procedure using Musol, diesel, gelled diesel, 20/40 mesh sand & 100 mesh sand. Press'd ann to 2620 psi w/diesel. Tst ins to 7900 psi; OK Pmp'd by Production: Stage 1: 35 bbls diesel w/5% Musol, 3900 psi, 1BPM Stage 2: 51 bbls diesel @ 1BPM, 4000 psi Pmp'd by Drilling: Stage 3: 100 bbls gelled diesel @ 20 BPM, 5175 psi avg Stage 4: 20 bbls gelled diesel pad @ 5220 psi, 20 BPM Stage 5: 46 bbls gelled diesel w/ 1 ppg 100 mesh sand @ 20 BPM, 5200 psi Stage 6: 308 bbls gelled diesel, 20 BPM, 5540 psi Stage 7: 24 bbls gelled diesel w/2 ppg 20/40 mesh sand @ 20 BPM, 5570 psi Stage 8: 39 bbls gelled diesel w/4 ppg 20/40 mesh sand, 20 BPM, 5760 psi Stage 9: 51 bbls gelled diesel, 5 ppg 20/40 mesh sand, 20 BPM, 6050 psi Stage 10:66 bbls gelled diesel 6 ppg 20/40 mesh sand @ 20 BPM, 6285 psi Stage 11:27 bbls gelled diesel w/8 ppg 20/40 mesh sand @ 6800 psi, 20 BPM Stage 12:51 bbls gelled diesel flush, 7145 psi initial & 6220 psi final press @ 20 BPM (underflush by 2 bbls) Pmp'd 37,683# 20/40 mesh in formation leaving 672# 20/40 mesh sand in csg. Load to recover 783 bbls of diesel/gelled diesel. Job complete @ 1346 hfs, 12/22/86. Drilling 'Supervisor STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION CC,,~4MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILx] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-55 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-21561 4. Location of well at surface 9. Unit or Lease Name 180' FSL, 10' FEL, Sec.36, T13N, R8E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 891' FNL, 1693' FWL, Sec.36, T13N, R8E, UM 31-9 At Total Depth 11. Field and Pool 589' FNL, 1407' FWL, Sec.36, T13N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0il Pool RKB 71' ADL 25523 ALK 2559 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 03/05/86 03/11/86 1 2/22/86* N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ l-VD) 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 9200'MD 6496'TVD 8965'MD 6360'TVD YES~] NO []I 1800' feet MD 1650' (Approx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, Cal, CET/GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 255 sx CS II 9-5/8" 36.0# J-55 Surf 3928' 12-1/4" 1500 sx CS Ill & 315 s Class G 7" 26.0# J-55 Surf 9047' 8-1/2" 500 sx Class G & 175 s PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 8686' 8615' 8758'MD 6239'TVD 1 spf, 90° phasing 8762'MD 6242'TVD 1 spf, 90° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 8784'MD 6255'TVD 1 spf, 90° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8788'MD 6257'TVD 1 spf, 90° phasing See attached Addendum~ dated 1/13/87~ for Fracture data 8814'-8832'MD 6272'-6283'TVD 1 spf, 90° phasing 8832'-8852'MD 6283'-6294'TVD 4 spf, 90° phasing 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ . Flow Tubing Casing Pressure CALCULATED,,k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None *Note: Dril led RR 03/15/86 Wel 1 perforated & tubing run 05/25/86. Alaska 0ii & · Anch0rag~ Form 10-407 Rev. 7-1-80 WC2: 04: PAN I CONTINUED ON REVERSE SIDE Submit in duplic~. . . 29. l' ~: , . 30. . GEOLOGIC MARKERS FORMATION TESTS ' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8690' 6199' N/A Base Kuparuk C 8700' 6205' Top Kuparuk A 87:~8' 6228' Base Kuparuk A 8860' 6299' 31. LIST OF ATTACHMENTS Addendum (dated 1/13/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Signed (~2~{~~ ~~,.,/ Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' ClasSification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 $ UB-$ URFA CE DIRECTIONAL SURVEY ~']UIDANCE I'~'10NTINUOUS I'~OOL Company Well Name Field/Location ARCO ALASKAr INC. 3I-9 {180'FSL & 10'FELr SEC.36rT13NrR8ErUM) KUPARUK. NORTH SLOPE. ALASKA Job Reference No. 71470 Log~3ecl By: PEPPEL Date 5/5/86 Computed By: KRUWELL GCT 3IRECTi]NAL SURVEY 'USTOMER LISTING ~RC3 ALASKA, INC. KU'P~RUK NORTH S~DPE,~LASKA SU~V£¥ DATE: 05-MAY-B6 METHSDS OE C]~PUTATiO~ TODL LOC&TIDN: T~NSENTZAL- 4VER&SED I~TERP2uATIDN: LinEaR VERTICAL SECTION: 40R!Z. DIST. PROJECTED DE~I4TZON &ND O~TO ~ TARGET &ZIM3TH AZIMUTH OF NO R T,-t 38 19 ~IN ~EST ARCO ALASKA, INC. 3I-9 KUPARUK N3RTH SLOPE,ALASKA COMPUT4TI3N INTERmOL&TED VALJES FOR TRUE SJB-SE4 MEASURE2 VERTICAL VERTI=AL DEPTH DEPTH DEPTH 0.00 0.00 -7!.00 lO0.OO 100.00 29.00 200.00 200.00 129.00 300.00 300.00 229.00 400.00 400.00 329.00 500.00 500.00 429.00 500.00 599.99 52~.99 700'.00 699.93 623.93 830.90 799.52 728.52 900.00 898.56 827.55 1000.00 997.31 926.31 1100.00 1095.78 1024.75 1200.00 1193.72 1122.72 1300.00 1290.38 1219.38 1400.00 1385.43 1314.43 1500.00 1478.58 1407.68 1600.00 1570.19 1499.19 1700.09 1660.70 1589.70 1~00.00 1749.76 1573.76 1900.00 1836.53 1765.63 2000.00 1921.42 1350.42 2100.00 2003.35 1932.36 2200.00 2082.45 2011.45 2330.00 2158.71 2087.71 2400.00 2232.58 2161.45 2500.00 2304.26 2233.25 2600.00 2374.57 2303.57 2700.00 2443.59 2372.59 2800.0~ 2511.46 2440.45 2900.00 2577.77 2505.77 3000.00 2642.57 2571.57 3100.03 2706.57 2635.67 3200.00 2770.56 2699.56 3300.00 2534.W9 2763.4~ 3~00.00 2898.77 2827.77 3500.00 2962.97 2891.97 3600.00 3027.11 2956.11 3700.00 3091.32 3020.32 3~00.00 3155.78 308~.7~ 3900.00 3220.55 3149.~5 COJRSE DEVIATION AZIMUTH lEG MIN DES Mt~ 0 0 N 0 0 E 0 T N 10 57 W 0 11 N 9 21 E 0 3 S 24 44 W 0 6 N 60 5 W 0 9 N 48 35 E 1 20 N !7 13 ',~ 259 N 24 11W 6 58 N 28 5 W 8 50 N 20 51W 9 39 N 27 47 W 10 31 N 28 52 W 13 7 N 30 43 W 16 24 N 32 19 W 19 37 N 33 24 W 22 39 N 33 42 W 24 ZT N 33 ~5 W 26 1 N 34 O W 23 21 N 33 39 W 30 50 N 3~* 27 w 50 0 N 41 11 'N 50 13 N 40 45 N 50 22 N 40 45 W 50 4 N ~0 50 ~ 50 0 N 40 52 ~ ~0 3 N 41 3 W 50 7 N 41 8 W ~9 57 N 41 3 ~ 49 46 N 40 59 W 49 37 N ~0 58 ~ DATE: VERTI" SECTI . O. O. O. O. O. 1. 4. 13. 27. w2. 59. 79. 104. 135. 171. 211. 254. 299. 349. 401. 520. 584. 652. 721. 793. ,~65. 933. 1013. 1089. 1166. 1243. 1319. I396. 1473. 15w9. 1526. 1702. 1778. 13-M&Y-85 100 FEET OF AL DOGLEG ON SEVERITY T DEG/IO0. O0 0.00 16 0.21 43 O.1B 54 0.24 63 0.17 77 0.15 58 1.45 35 3.91 46 2.9~+ 05 0.82 MEASURE RECTAN NORTH/ FEE . O. O. O. O. O. 1. 5. 12. 25. 49 0.65 39. 66 1.50 54. 58 3.53 71. 95 3.44 93. 81 2.95 119. 77 2.89 149. 93 1.20 183. 33 1.7~ 218. 65 2.85 256. 02 2.32 297. 92 3.20 340. 11 2.94 387. 26 2.70 ~37. 91 2.27 35 1.70 542. 93 1.61 599. 03 1.34 655. 38 0.88 711. 79 1.55 765. 58 1.45 325. 53 1.15 882. 29 0.13 940. 16 0.~5 998. 98 0.24 1055. 51 0.25 1114. 09 ~.33 1172. 72 0.11 1230. 29 0.24 12~$. 65 0.25 1345. 85 0.68 1403. PAGE i ~TE OF SURVEY: 05-M~Y-86 ELLY BUSHING ELEVATI3N: 71.00 FT ENGINEER: PEPPEL D DEPTH GULAR COORDINATES H3RIZ. DEPARTURE SOUTH EAST/WEST DIST. AZIMUTH T FEET FEET DEG MIN' O0 N 0.00 E 0.00 N 0 0 E 20 N 0.00 W 0.20 N 0 5 W 53 N 0.02 W 0.53 N 2 9 ~ 70 N 0.02 E 0.70 N 1 15 E 59 N 0.14 W 0.71 N 11 29 N 88 N 0.13 W 0.89 N 8 18 W 82 N 0.24 W 1.84 N 7 35 N O0 N 1.50 W 5.22 N 16 45 W 80 N 5.52 W 13.94 N 23 20 W O~l N 11.89 W 27.75 N 25 22 W 05 N 19.11 W 43.48 N 26 4 W 42 N 27.37 W 60.91 X 25 42 W 87 N 37.40 W 81.02 N 27 29 W 62 N 50.79 W 106.51 N 28 28 W 53 N 67.67 W 137.44 N 29 29 W 68 N 87.63 W 173.44 N 30 20 W 18 N 110.02 W 213.68 N 30 59 W 47 N 133.74 W 255.16 N 31 28 W 20 N 159.10 W 301.58 N 31 50 W 32 N 186.68 W 351.07 N 32 7 W 89 N 216.87 W ~04.03 N 32 27 W 79 N 249.75 W 461.26 N 32 46 W O1 N 286.10 W 522.33 N 33 12 W 50 N 325.21 W 586.85 ~i 33 39 W 86 N 365.22 W 654.28 N 33 55 W 09 N 406.28 W 723.86 N 34 8 W 55 N 449.49 W 794.85 N 34 26 ~ 91 N 494.87 W 367.01 N 34 48 N 45 .~ 541.72 W 940.20 N 35 10 W 19 N 590.55 W 1014.73 N 35 35 W 08 N 641.05 W 1090.42 N 36 0 W go N 591.31 W 1167.00 N 36 19 W 50 N 741.51 W 1243.72 N 36 35 W 59 N 791.76 W 1320.41 N 35 50 W 54 N 841.87 W 1395.84 ~ 37 3 W 57 N 892.09 W 1473.34 N 37 15 W 32 N ~42.59 W 1549.89 i 37 27 ~ 10 N 992.98 W 1626.41 N 37 37 W 77 N 1043.17 W 1702.74 N 37 46 W 3'9 N 1093.15 W 1778.90 N 37 54 W C JMPUTATI IN ARCO ALASKA, INC. 3I-9 KJPARJK NORTH SLOPE,ALASKA DATE: 13-M~Y-86 INTERPOLATED VALJES FOR EVEN 100 FEET "DF ~RU£ SJB-SEA MEASURED VERTIC&L VERTISAL DEPTH DEPTH DEPTH CDJRSE V:RTIC~L DOGLEG DEVIATION AZIMUTH SECTION SEVERITY DEG qIN OSG MIN F~ET OEG/IOO 49 28 N 41 31 W 1354.73 0.64 49 54 N 41 49 W 1930.88 0.36 50 16 N 41 59 W Z007.42 0.43 50 44 N 42 4 W 2084.46 0.34 51 5 N 42 10 N 2181.89 0,61 51 33 N 42 19 W 2239,84 0.35 51 49 N 42 35 W 2318.09 0.47 51 52 N 42 47 N 2396.53 0.42 52 8 N 43 11 W 2475.12 0.40 52 24 N 43 42 W 2553.86 0.53 4000.00 3285.%7 3214.47 4100.00 3350.12 3279.12 4200.00 3414.BI 3343.31 4300.00 3477.97 3405.87 4400.00 3540.94 3489.94 4500.00 3803.34 3532.34 4690.09 3665.35 3594.35 4700.00 3727.09 3655.09 4800.00 3788.59 3717.59 4900.00 3849.83 3778.83 3910.59 3839,5'9' 52 3970.93 3899.93 53 1 4030.92 3959.92 53 15 4091.11 4020.11 52 15 4153.00 %082.00 51 48 4214.54 4143.54 52 12 4275.52' 4204.52 52 36 4336.01 4285.01 ~2 56 4396.16 4325.15 32 4457.71 4356.71 51 15 N 44 $ W 2632.91 0.43 N 44 32 N 2712.21 0.44 N 44 53 W 2791.72 ~.58 N 44 I N 2~71,06 2.51 N 42 ~4 W ~949.33 N 4~ 54 ~ 3027.92 0.35 N 43 6 W 3106.90 0.29 N 43 13 W 3186.25 0.27 N 42 45 W 3265.85 1.72 N 40 25 N 3344.51 1.6~ 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 5600.00 5700.00 53D0.00 5900.00 O0.OO 00.00 O0.O0 00.00 00.00 DO.OD 00,00 00.00 00.00 00.00 4520.55 ~449.55 50 57 4583.25 4512.28 51 35 4644.90 4573.90 52 17 4705.~2 4634.92 52 5 4768.50 4697.60 50 37 4831.76 ½7~0.74 51 14 4894.15 4~23.18 51 4956.36 45~5.0~ 51 ~7 5018.46 4947.46 5083.i3 5012.13 N 89 50 W 5422.26 0.73 N 39 51 W 3500,12 0.75 N 39 55 W 3573.84 0.48 N 39 40 W 3858.03 1.48 N 39 i W 3735.~3 0.75 N ~9 3 W 3~13.46 0.53 N 39 2 ~ 3391.58 0.45 N 39 9 W 3~70.13 0.47 N 39 5 W %048.25 1.71 N 38 54 N 4124.52 1.02 60 61 62 63 65 65 67 68 69 00.00 DO.O0 00.00 O0.OO 00.00 00.00 00.00 00.00 00.00 O0.O0 5149.02 5079.02 49 6 5213.~7 5142.97 49 g3 5278.56 5207.55 50 3 5342.93 3271.93 49 34 5408.32 5337.02 ~9 ~1 5472.71 5401.71 50 O 5536.70 5465.70 50 25 5600.18 5529.13 50 55 5662.53 5591.83 51 30 5724.85 5653.~5 51 49 N 3~ 5~ W 4199.73 0.75 N 39 7 W 4275.75 0.79 N 39 31 w 4352.10 1.03 N 40 lO W ~428.59 0.79 N ~0 35 N 4504.45 0.69 N 40 40 W ~550.65 0.20 N ~0 50 W ~557.42 0.30 N 41 0 W ~734.60 0.90 N ~1 ~ ~ 9312.62 0.34 N 41 15 W 4~90.$0 0.84 7O 71 72 73 74 75 76 77 78 79 PAGE 2 D&TE OF SURVEY: 05-M&Y-85 KELLY BUSHING ELEVATION: 71.00 FT ENGINEER: PEPPEL MEASURED DEPTH RESTANGULAR COORDINATES HgRIZ. DEPARTURE NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET FEET FEET DEG MIN 1460.52 N 1143.23 N 1854.75 N 38 3 W 1517.49 N 1193.96 W 1930,89 N 38 11 W 1574.54 N 1245.21 W 2007.42 N 38 20 W 1631.88 N 1296.91 W 2084.46 N 38 28 W 1689.44 N 1348.95 W 2161.92 N 38 36 W 1747.29 N 1401.48 W 2239.90 N 38 43 W 1805.17 N 1454.44 W 2318,19 N 38 51 W 1863.01 N 1507.76 W 2396.59 N 38 59 ~ 1920.69 N 1561.52 W 2~75.36 N 39 6 ~ 1978.07 N 1615.90 W 2554.19 N 39 14 ~ 2035.29 N 1670,98 W 2533.36 ~ 39 23 W 2092.35 N 1725,68 W 2712.82 N 39 31 W 2149.18 N 1783.01 W 2792.51 N 39 40 W 2205.89 N 1839,21 W 2872.05 N 39 49 W 2263,24 N 1892,88 W 2950.46 N 39 54 W 232!.09 N 1946,43 W 3029.20 N 39 58 N 2379.05 N 2000,48 W 3108.34 N 40 3 W 2437.11 N 205~.97 W 3187.85 N 40 8 W 2495.36 N 2109.64 W 3267.63 N 40 12 N 2554.18 N 2162.08 W 3346.40 N 40 14 N' 2613.53 N 2212.00 N 3424.19 N 40 14 ~ 2573,63 N 2261.89 W 3502.07 N 40 13 ~ 2734.05 N 2312.41 W 3380.81 N 40 13 ~ 2794.83 N 2363.22 W 3660.04 N 40 13 W 2~55.16 N 2412.51 W 3737.93 N 40 11 N 2~15.39 N 2461.33 W 3815.45 N 40 10 ~ 2976.05 N 2510.57 W 3893.57 N 40 9 W 3037.04 N 2560.08 W 3972.11 N 40 ? ~ 3097,60 N 2509,45 W 4050.23 N 40 6 ~ 3156.83 N 2657.45 W 4126.49 N 40 5 N 3215.40 N 2704.70 W .201.69 N 40 4 ~ 3274.45 N 2752.60 W 4277.71 N 40 3 ~ 3333.54 N 2800.95 W 4354.05 N 40 2 W 3392.31 N 2849.96 W 4430.58 N 40 2 W 3450,06 N 2899.23 W 4506.49 N 40 2 W 3507.91 N 2948.90 W 4582.74 N 40 3 W 3566.13 N 2999.07 W 465~.58 N 40 3 N 3824.50 N 3049.63 W 4736.83 N 40 4 ~ 3683.38 N 3101.00 W 4~14.92 N 40 5 N 3742.2~ N 3152.57 W 4893.20 N 40 6 ~ COHPUTATiDN ARCO ALASKA, INC. 3I-9 KUP~RUK N]RTN SLOPE,ALASKA DATE: 13-MA¥-85. TRUE MEASUREg VERTICAL DEPTH DEFT4 INTEROOL&TED VALJES FOR EVEN 100 COdRSE DEVI &TI'DH AZIMUT~ '~EG MIN DEG MI~ 8000.00 5786.36 8100.09 5846.95 8200.00 5907.10 8300.00 5965.?3 8400.00 8027,22 8500.00 5086,/7 8500.00 5146.19 87D0.00 5205.31 8800.00 5264.06 8900.00 5322.36 VERTISAL DEPTH 9000.02 5380.!5 9100.00 $437.93 9200.00 $495.71 5T15.36 52 22 N 41 25 W 5775,95 52. ~5 N 41 39 W 5~35.10 53 17 N 41 57 W 5895.73 53 13 N 42 15 W 5~55.02 53 i N ~2 41 W 5015.77 53 24 N ~2 55 W 5075.19 53 ~0 N 43 7 W 513~.31 53 48 N 4B 18 W $193.06 54 15 N 43 23 W 5251.36 54 41 N 43 32 W 5309.15 54 ~2 N ~3 32 W 5366.93 54 %2 N 43 32 N 542¢.71 54 42 N 43 32 W PAGE 3 DATE DF SURVEY: 05-M~¥-85 KELLY BUSHING ELEVATION: 71,00 FT ENGINEER: PEPPEL FS=T Om MEASURE V~RT!CAL DOGLEG RECTAN SECTION SEVERITY NORTH/ F6ET DEG/lOD FEE 1.48 3801. 0.44 3861. 0.25 3920. !.i1 3980. 0.80 4038. 0.38 4097. 0.25 4156. 0.12 4215. 0.64 4274. ~.W~ 4333. ~959.54 5048.97 $12~.70 5208.81 528~.37 5363.32 5448.47 5528.83 5609.44 5590.36 0.00 4392. 0.00 4~51. 0.00 4510. 5771.64 585Z.91 5934.19 D DEPTH SULAR CDOROI~ATES HgRIZ. DEPARTURE SOUTH EAST/WEST DIST. AZIMUTH T FEET FEET DEG MIN 48 N 3204.65 W 4972.02 N 40 7 W 02 N 3257.41 W 5051,55 N 40 9 ~' 55 N 3310.67 W 5131.40 N 40 10 W 17 N 3364.44 W 5211.64 N 40 12 W 94 N 3418.38 W 5291.35 N 40 14 ~ ?~ N 3472.87 W 5371.46 N 40 16 ~: 56 N 3527.77 W 5451.80 N 40 19 ~ 32 N 3583.01 W 5532.35 N 40 21 W 19 N 3838.54 W 5513.17 N 40 24 W 14 N 3694.45 W 5594.30 N 40 27 ~ 30 N 3750.6'7 W 5775.80 N 40 29 ~ ~7 N 3806.89 W 5857.30 N 40 32 W 53 N 3863.11'W 5938.80 N 40 34 ~ ARCO ALASKA, I~C. 3I-9 KUPARU~ NORTH SLOPE,~L~SK4 TRU: MEASURED VERTIC&L DEPTH DEPTH 0.00 0.00 1000.00 997.31- 2000.00 1921.%2 3000.09 2542.57 4000.00 3285.%7 5000.00 3910.59 6000.09 4520.55 7000.00 5149.02 8000.00 57~.35 9 000.'00 $380 · 15 COMPUTATZ3N INTERPOL&TE3 VALdES FOR SJB-SEA VERTI'AL DEPTH DATE: 13-MAY-85 -71.00 926.31 1850.42 2571.67 3214.47 383'9.59 4449.55 5078.02 5715.36 6309.15 ~VEN lOOO COURSE VERTICAL DEVIATION AZIMUTH SECTION DEG MIN OrS MIN FEET 0 0 N O 0 E 0.00 9 39 N 27 47 W 42.49 33 23 N 34 43 ~ 401.92 50 0 N ~1 11 ~ 1089.53 49 28 N 41 31 ~ 1~54.73 52 44 N 44 6 W Z$32.~1 50 57 N ]9 50 W 3422.26 49 6 N 38 59 W ~199o73 52 22 N 41 26 W %969.54 54 32 N 43 32 W 5771.64 FEET ~ MEASUR DO~LEG RE'TAN SEVERITY NORTH/ DES/lO0 FEE 0.00 O. 0.65 39. 3.20 340. 1.15 882. 0.64 1460. 0.43 2035. 0.73 2513. 0,75 3215. 1.48 3801. 0.00 4392. PAGE 4 DATE OF SURVEY: 05-M~Y-8$ KELLY BUSHING ELEVATION: ?1.00 FT ENGINEER:' PEPPEL ED DEPT SOLAR COORDINATES HDRIZ. DEPARTURE SOUTH EAST/WEST DIST' AZIMUTH T FEET ~EET DEG MIN O0 N 0.00 E 0.00 N 0 0 E 05 N lg.ll W 43.48 N 26 4 ~ 89 N 215.87 W ~04.03 N 32 27 W 08 ~ 64i.05 W 1090.42 N 36 0 ~ 52 N 1143.23 W 1854.75 N 38 3 W 29 N 1670.98 W 2533.36 N 39 23 W 83 N 2212.00 W 3424.19 N 40 14 W 40 N 2704.70 W 4201.69 ~ 40 4 ~' 45 N 3204.65 W 4972.02 N 40 7 N 30 N 3750.67 W 5775.80 N 40 29 N CJMPUTATION ARSO ALASKA, INC. 3I-9 KJPARgK NORTH SLOPE,ALASKA !NT~RPCLATE2 VALUES FOR TRUE SJB-SEA MEASURED V~RTIC&L V=RTICAL DEPTH DEPTq DEPTH 0.00 0.00 -?!.00 71.00 7!.00 0.00 171.00 171.30 100.00 Z?l. OO 271.20 200.00 371.00 371.00 300.00 471.00 471.00 400.00 571.00 571.00 500.00 571,94 671.00 503.00 771.29 771.30 700.00 872.14 871.30 800.00 973.32 971.00 900.00 1074.81 1071.00 1000.00 1176.71 1171.00 1100.00 1279.80 1271.00 1200.00 1384.69 1371.00 1300.00 1491.70 1471.00 1400.00 1600.29 1571.00 1500.00 1711.45 1671.00 1600.00 1824.29 1771.00 1700.00 1940.23 1871.00 1800.00 2050.10 1971.00 1900.00 2185.22 2071.00 2000.00 2316.41 2171.00 2100.00 2453.40 Z271.00 2200.00 2594.87 2371.00 2300.00 2740.11 2471.00 2400,00 2889.72 2571.00 2503.00 3044.24 2671.30 2600.00 3200.70 2771.00 2709.00 3356.83 2371.00 2800.00 3512.51 2971.30 2903.00 3558.39 3071.00 3000.00 3823.55 3171.00 3100.00 3977.77 3271.00 3200.00 4132.45 3371.00 3300.00 4289.13 3471.00 3400.00 4%48.03 3571.00 3500.00 4609.13 3671.00 3600.00 4771.35 3771.00 3700.00 4934.75 3871.00 3803.00 COURSE DEVIATION AZiMUTq DEG MIN DES MIN 0 0 N 0 O E 0 15 N D 51 ~ 0 13 Iq 1 15 W 0 2 N 38 39 E 0 6 N 79 49 W 0 8 N 28 28 E 0 98 N 12 50 W 2 13 N 22 53 W 554 N 28 7 W $ 17 N 27 12 W DATE: EVEN VERTi SECT 13-MAY-86 100 'F~ET OF C~L DOSLEG ION SEVERITY ET DEG/iO0 0.00 0.00 0.09 0.99 0.35 0.31 0.55 0.40 0.59 0.13 0.76 0.27 1.07 1.91 3.61 1.43 10.28 3.90 23.06 0.7~ g 21 N 27 40 W 38.15 10 13 N 28 31 ~ 55.21 12 20 N ZO 23 W 7~.50 15 43 N 32 1 W' 99.31 19 9 N 33 18 W 130.74 22 24 N 33 41 W 168.63 24 28 N 33 45 W 212.30 26 14 N 33 59 ~ 25~.38 29 0 N 33 44 ~ 311.39 31 ~4 N 34 41 ~ 369.89 35 14 N 35 7 W 435.81 38 37 N 35 52 W 510.90 41 45 N 35 43 W 595.77 44 10 N 36 ~ ~ 689.31 ~5 30 N 38 5 ~ 789.35 47 8 N 39 36 W 894.66 48 50 N al 20 W 1005.85 50 12 N 40 51 W 1123.47 50 22 N 40 45 ~ 1243.59 49 59 N 40 51 W 1363.48 50 ~ N ~1 5 W 1432.67 50 1 N ~1 4 W 1602.10 49 43 N 40 53 ~ 1720.62 49 23 N 41 25 W 1837.89 50 1 N 41 53 W 19~5.58 50 ~2. N 42 4 W 2075.06 51 23 N 42 13 W 2199.26 51 51 N 42 ~6 W 232~.24 52 5 N 43 4 W 2452.58 52 32 N 43 50 W 2581.29 1.40 0.95 3.27 3.44 3.08 2.98 1.20 1.83 69 3.05 2.73 2.34 1.32 1.39 1.26 1.49 0.25 0.45 0.14 0.32 0.23 0.23 0.59 0.38 0.3~, 0.6~ 0.52 0.42 0.45 PAGE 5 DATE DF SURCEY: 05-M&Y-86 KELLY BUSHING ELEVATION: 71.00 FT ENGINEER: PEPPEL SUB-SEA DEPTH RECTANGULAR COOR NORTH/SOUTH E&ST FEET FEE DINATES HDRIZ. DEPARTURE /NEST DIST. AZIMUTH T FEET DEG MIN 0.00 N O. 0.I1 N O. 0.43 N O. 0.71 N O. 0.67 N O. 0.82 N O. 1.29 N O. 3.82 N O. 9.94 N 3. 21.45 N 10. O0 E O. O0 N 0 0 E O1 E 0.12 N 3 57 E 03 W 0.43 N 3 44 W 02 E 0.71 N 1 13 E 09 W 0.68 N ? 44 ,; 18 W 0.84 N 12 20 W 09 W 1.30 N 4 10 W 99 W 3.95 N 14 31 W 99 W 10.71 N 21 52 W 05 W 23.'69 N 25 5 ~ 35.14 N 17. 50.45 N 25. 67.45 '~ 34. 88.83 N 47. 115.38 N 64. 147.05 N 85. 183.43 N 110. 222.6? N 136. 266.02 N 165. 314.49 N 198. 06 W 39.06 N 25 53 W ZO W 56.40 N 25 32 W 80 W 75.90 N 2'7 17 W 76 W 100.86 N 28 15 W 87 W 132.36 N 29 20 W 88 W 170.30 N 30 17 ~ 22 W 214.04 N 30 59 ~ 57 W 261.21 N 31 31 W 61 W 313.35 N 31 54 ~ 61 W 371.96 N 32 16 W 368.75 N 236. 429.54 N 280. 497.19 N 331. 572.76 N 386. 552.55 N 447. 734.48 N 513. 819.38 ~ 585. 907.75 N 653. 998.~0 N 741. 1089.54 N 820. 28 W 437.96 N 32 38 W 47 W 513.00 N 33 8 W 73 W 597.70 N 33 42 W 97 W 591.23 N 34 2 W 22 W 791.18 ~ 34 25 W 52 W 896.20 N 34 57 W 43 W 1007.03 N 35 32 W 32 W 1124.27 N 35 9 W 86 W 12~4.25 N 35 36 W 24 W 1353.86 'q 35 58 W 1179.79 N 898. 1269.84 N 977. 1359.35 N 1054. 1447.90 N 1132. 1535.99 N 1210. 1525.53 N 1291. 1717.19 N 1374. 1810,45 N 1459. 190~.18 N 1546. 1997.97 N 1634. 40 W 1482.91 N 37 17 W 07 W 1602.24 N 37 34 W :J6 W 1720.69 N 37 48 W 04 W 1837.92 N 38 I W 55 W 1955.58 N 38 14 W 27 W 2076.06 N 38 27 W I1 W 2199.30 N 38 40 N 29 W 2325.35 N 3:3 52 W 05 W 2452.80 N 39 4 W 97 W 2581.67 N 39 17 ~ COMPUTATI]N OAT6: 13-M~Y-8$ PAGE 6 ARCD ALASKA, INC. DATE OF SURVE'Y: 05-MAY-86 3I-9 KOPARUK NDRTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: PEPPEL 71.00 FT INTERPOLATED VALJES FDR EVEN 100 FEET OF SUB-SEA gEPTH TRU6 SJB-SSA COORSE MEASURED VERTICAL VERTI:AL 3EVIATI3N AZIMUTH DEPTH DEPTH DEPTH 3EG MIN OEG MI~ V6RTiC&L SECTION F~6T DOGLEG RECTANGULAR CGORDIN~TES HORIZ. DEPARTURE SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DES/lO0. FEET FEET FEE~ DEG MIN 5100.11 3971.00 3900.00 53 Z 5256.95 ~071.00 GOO0.O0 52 ~5 5429.15 ~171.00 ~100.00 51 56 5592.55 4271.00 ~202.00 52 35 5758.15 4371.00 ~300.00 53 1 5921.17 ~471.00 ~40~.00 51 10 6080.20 4571.00 ~500.00 51 26 62~2.77 ~671.00 ~600.00 52 25 6~03.76 4771.00 4700.00 50 36 6562.84 4871.00 ~800.00 51 24 N 44 32 W 2712.30 N ~ 34 W 2844.99 N ~2 45 W 2972.19 N 43 5 W 3101.01 N 43 10 W 3232.53 N aD 10 ~ 3350.98 N 39 51 W 34~4.59 N 39 55 ~ 3612.71 N 39 I W 3738.83 N 39 3 W 3~62.53 0.44 2-01 0.47 0.27 0.28 1.01 1.1% 0.17 0.7% 0.17 2092.42 N 1726.74 W 2712.90 N 39 31 W 2187.15 N 1820.86 W 2845.91 N 39 46 W 2280.08 N 1908.43 W 2973.36 N 39 55 N 2374.72 N 1996.43 W 3102.43 N 40 3 W 2~70.95 N 2086.79 W 3234.24 N 40 10 W 2566.79 N 2172.68 W 3362.88 N 40 14 W 2561,71 N 2251.94 W 3486.53 N 40 '13 W 2760.33 N 2334.16 W 3614.70 N 40 13 W 2857.41 ~ 2414.34 W 3740.84 N 40 11 W 2953.~9 N 2492.27 W 3864.52 N 40 9 W 6724.17 4971.00 6881.51 5071.00 7~33.5~ 5171.00 7188.27 5271.00 7343.21 5371.00 7497.35 5471.00 7653.92 5571.00 7813.%3 5671.00 7~75.01 5771.00 8139.78 5871.00 ~900.00 51 ~1 5000.00 49 7 5100.00 49 Z1 $200.00 49 59 5303.00 49 25 5400.00 49 59 5500.00 50 35 5500.00 51 28 3700.00 52 12 5800.00 52 56 N 39 12 W 3999.12 N 38 55 W g110.56 N 39 1 W ~225.19 N 39 29 W 4343.12 N 40 27 ~ 4461.42 N 40 40 W ¢578.61 N 40 55 W %698.97 N ~1 9 W %~23.11 N ~I 23 W &949.~6 N 41 47 W 5080.60 0.65 1.62 0.71 0.9~ 0.54 0.17 0.52 0.23 0.82 0.80 3051.75 N 2572.09 W 3991.10 N 40 7 W 3146.02 N 2648.68 W 4112.53 N 40 5 W 3235.18 N 2720.74 W 4227.15 N 40 3 W 3326.50 ~ 2795.25 W 4345.08 ~ 40 2 W 3417.33 N 2871.23 W 4463.~2 N 40 2 W 3506.37 N ,2947.58 W 4580.11 N ~0 3 W 3597.57 N 3026.29 W 4701.17 N ~0 4 W 3691.29 N 3107.91 W 4825.42 N 40 5 W 3786.70 N 3191.61 W 4952.32 N 40 7 ~ 3884.67 N 3278.50 W 5083.23 N 40 9 W 8307.10 5971.00 5900.00 8~73.55 5071.00 5000.00 85~1.93 6171.00 5100.00 8811.91 6271.00 6200.00 8984.17 5371.00 5300.00 9157.24 6471.00 5400.00 9200.00 6~95.71 542~.71 53 9 53 Z2 53 ~ 54 17 54 %2 N 42 18 W 5214.48 N 42 $1 W 5347.14 N 43 13 W 5482.15 N 43 23 W 561~.08 N 43 32 W 5753,77 N 43 32 W 5899.44 N 43 32 W 5934.19 1.07 0.36 0.28 0.42 0.03 O.OO 0.00 3984.37 N 3368.25 W 5217.32 N 40 12 W &.082.22 N 3458.41 W 5350.24 ~t 40 16 W' 4181.21 N 3550.39 W 5~85.56 N 40 20 W 4281.21 N 3645.19 W 5622.83 ,~ 40 24 W 43~2.94 N 3741.77 W 5762.90 N 40 29 W 4435.33 N 3839.07 W 5~03.95 N 40 33 W 4510.63 N 3863.11 W 5938.80 N 40 34 W ARCO ALASKA, lNG. KUPAR~JK NORTH SLOPE,ALASKA TOP BASE TOP PBTD TD MARKER KUPAR~K C KUPARUK C K~PARUK & KUPARUK 4 COMPUTATIS~ DATE: 13-MAY-85 INTER?OLATED VALJES mOR CHOS£N HORIZONS (=&ULTEO) MEASJRE~ DEPTH 3ELO~ K5 FROM KB ORIGIN: 180 TVO SJB-SE4 8590.00 5199.40 6128.4,0 8700.00 6205.31 5134.31 $738.00 5227.74 5156.74 8~60.00 5!99.02 6228.02 8965.00 5]359.92 5288.92 9200.00 6~95.71 54,2~.71 PAGE 7 DATE OF SdRVEY: 05-MAY-86 KELLY BUSHING ELEVATION: ?1.00 FT ENGINEER: PE~PEL SJRFACE LOCATION FSL, 10 FEL, SEC 36, T13N, RSE, UM RECTANGULAR COORDINATES NORTH/SOUTH EAS?/~EST 4.209.45 N 3577.~+B W 4,215.32 N 3583.01 W 4,237.65 N 3504..05 W 4.309.60 N 3672.05 W 4371.59 N 3730.99 W 4,510.63 N 3863.11 W ARCO AL~A, lNG. 31-9 KUPAR~Y, NgRTH SLD~E ~ AL~,,SKA TOP KUPARUK C BASE KUPARU< C TOP KUP~RUK A BASE KUPARUK A PBTD TD CJMPUT~TION O~TE: (FAULTED) ~EA.SJRED DEPTH B~LON K~ 8690.00 8700.00 8738.00 8860.00 8965.00 9200.20 13-M~Y-85 PAGE 8 D~TE CF SURVEY: 05-M~Y-85 ~ KELLY BUSHINS ELEVATIDN: 71.00 FT ' ~NGINEER: PEPPEL FROM KB 3RIGId: 1BO FSL, TVD SJB-SE& SU 10 FEL RE~T~ NDRT RFACE LDCATIDN EC 36 TI~N ~RjSE gM NGULA~ COOR~I,~T~S rt/SDUT~ EAST/WEST 6199.40 6205.31 6227.74 5299.02 5359.92 5495.71 5128.~0 5134.31 6156.74 5225.02 5288.92 5~24.71 4209.45 N B577.48 W 4215.32 N 3583.01 W 4237.65 N 3604.05 W 4309.60 N 3672.05 W 4371.59 N 3730.99 W 4510.63 N 3853.11 W FINAL WELL LOC&TI]NAT TO: TRJE SJS-SEA MEASURED VERTICAL ~ERTISAL DEPTH DEPTH DEPTH 9200.00 6495.71 5~24.71 qORIZONT4L 9EmA~TURE DiSTaNCE 4Z!MUTH mEET DEG MIN 5938.80 N ~0 34 W SCHLUMBERGER D I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL F I ELD KUpARUK COUNTRY USA RUN DATE LOOOED OS- MAY - B8 REFERENCE 000071470 WELL: 3I-9 (180'FSL & 10'FEL, SEC. 36, T13N,R8E,UM) HORIZONTAL PROJECTION NORTH 613O0 4OOO 3OOO zooo 1 ooo - 1 ooo Sou'rH -zooo MEST REF 000071470 SCALE = ]/]000 IN/FT ~..,t~~4-, r ~-:.?-.. ,,~ ,,,, ,,,,FT.. ..... , ~ ' '~ ...F'*.t4.-i .... ,"*'%"! ....... ,-¢-*H..-r..H*.-½ .... ~-.t..+.*+ ............ ....... i*-.::*+.+ ...... .H~.+..-+--H-+* .+.H....L~, -+.H.*.; ...... 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'?k?-?"-t..-H..H-- ~ ~:.~..~...:...?...~. ...... ~m~?......~...~....~....~...~...~...~...~ ...... ~...~...+...+ ....... m.~...~...~...~....~... : :::?~;;;~;/~;~;~;~ ?~;;?~;~;t~/;~ ::::::::::::::::::::::::::::::::::::::: ,7 :~ :~'"~'"'?? ....... mnnn~'":'-':--';' ...... ~...~...~..--~...~-..~..?+...~ ....... ~.-?-:...%.~...~...~...~ ....... ~...b~..- :::::::::::::::::::::::::::::::::::: ~ PROJECTION ON VERTICAL PLANE 921. - 141. SCALEO IN VERTICAL O£PTHS HORIZ SCALE = 1/1000 IN/FT 7000 9Zl. Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WEL~ NAM~ AND NUMBER Reports and Materials to be received by,.. I'---~l--~° - - Date- , , Required Date Received Remarks ,, , Completion Report,, ye~ / -- ~ 3 - ~~' . , . ~~, WeI1 History , , Hud Log Core Ch~ps 'toro Description , ,, . ~ " Registered Survey Plat ~.~ /~2q-gJ, ~ 0/(. Inclination Survey ~ ..... ,~ OIc ,, Directional Survey ~eS-~/ X ~/~- ~ ~'~ ~ .~, .. Drill Stem Test Reports Production Test Reports re-rs Digitized Data STATE OF ALASKA -- ALASKA ,.,~L AND GAS CONSERVATION COMMI:~ .ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging ~ Perforate:~: Pull tubing Alter Casing [] Other~ Com[o'lete 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 100360 Anchorage~ AK 99510 5. Datum elevation (DF or KB) RKB 71 ' 6. Unit or Property name Kuparuk River Unit Feet 4. Location of well at surface 180'FSL, IO'FEL, Sec.36, T13N, R8E, UM At top of productive interval 891 ' FNL, 1693'FWL, Sec.36, T13N, R8E, UM At effective depth 728'FNL, 1539'FWL, Sec.36, T13N, R8E, UM At total depth 589'FNL, 1407'FWL, Sec.36, T13N, R8E, UM 7. Well number 31-9 8. Approval number 57 9. APl number 50-- 029-21561 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface 9 200 feet 6496 feet Production feet 8965 feet 6360 Length Size 80 ' 1 6" 3898 ' 9-5/8" 9019 ' 7" Plugs (measured) None Junk (measured) None Cemented Measured depth 255 sx CS II 110'MD 1500 sx CS III & 3928'MD 315 sx Class G 500 sx Class G 9047'MD ~ue Verticaldepth 110'TVD 3238'TVD 6407'TVD Perforation depth: measured 8758 'MD 8784 'MD 8762 'MD 8788 'MD true vertical 6239 'TVD 6255 'TVD 6242 'TVD 6257 'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail (~ 8686' Packers and SSSV ltype and measuredpd_e~tAh_) HRP-1SP pkr 8 8615' and TRD SSA SSSV @ 1800' 8814'-8832'MD 8832'-8852'MD 6272'-6283'TVD 6283'-6294'TVD 12. S~r~lation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History & Addendum) Daily Report of Well Operations [] Copies of Logs and Surveys Run ~ Gvz'o 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Associ ate Engineer (DAM) 5W(J/O~.3 Date Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after alrowabie has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish Alaska I North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25523 Auth, or W.O. no. ITitle AFE I Completion Nordic 1 API 50-029-21561 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 5/25/86 IAccounting cost center code State Alaska I Well no, 31-9 Date and depth as of 8:00 a.m. 5/25/86 Complete record for each day reported I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W.O. I 0300 hrs. 7" @ 9047' 8965' PBTD, RR Diesel Accept ri~ @ 0300 hrs, 5/25/86. ND tree, NU & tst BOPE. Perf well @ 8784', 8788', 8758', 8762' & 8814'-8832' @ 1SPF &- 8832'-8852' @ 4 SPF. Rn 2-7/8", J-55, 6.3#, EUE 8RD AB Mod tbg w/SSSV @ 1800', HRP-1-SP pkr @ 8615' & TT @ 8686'. ND BOPE, NU & tst tree. Displ well w/diesel. RR @ 2330 hrs, 5/25/86. Old TD Released rig 2330 hrs. Classifications (oil, gas, etc.) Oil I New 8965 ' PBTD TD PB Depth Date I K nd of rig 5/25/86 I Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval !Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. i C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Slgna'~~~_ lDate 6/04/86 ~itle Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ADDENDUM WELL: 3I-9 5~o5~86 Rn CET/GR/CCL to 8955' WLTD - 7100' WLM. Rn GCT f/surf - 8900'. Rn 6.125" gage ring/JB f/surf - 8965'. "D~ii-ling Supervisor ' .... STATE OF ALASKA ALASK,-, ,all AND GAS CONSERVATION COMMi,., .,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Requests: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing C Comp/. Time extension [] Change approved program [] Plugging [] Stimulate~,,.Pull tubing [] Amend order ~ Perforate ~ Other ~,, 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100~RO Anc. hnr'~.; Al4 qqc, lC~ 4. Location of well at surface 180'FSL, 10'FEL, Sec.36, T13N, R8E, UM At top of productive interval 900'FNL, 1951'FWL, Sec.36, T13N, R8E, UM (approx.) At effective depth 518'FNL, 1813'FWL, Sec.36, T13N, R8E, UM (approx.) At total depth 367'FNL, 1690'FWL, Sec 36, T13N, R8E, UM (approx.) 5. Datum elevation (DF or KB) 71 ' RK B feet 6. Unit or Property name Kuparuk River Unit 7. Well number 8. Permit number 86-55 9. APl number 50-- 029-21 561 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 9200 true vertical 6509 Effective depth: measured true vertical Casing Conductor Surface 8965 6377 Production Length Size 80 ' 1 6" 3898 ' 9-5/8" 901 9 ' 7" feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 255 sx CS II 110'MD 1500 sx CS III & 3928'HD 315 sx Class G 500 sx Class G 9047'MD ~ue Verticaldepth 110'TVD 3237'TVD 6423'TVD Perforation depth: measured No ne true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Description summary of proposal [] Detailed operations program L~ BOP sketch Well Hi story 13. Estimated date for commencing operation June, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~ Title Associate Engineer t¢ Commission Use Only ( DAM ) 5A/022 Date Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance ,' Commi§$iSner' ' by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Inatructlone: Prepare and submit the "lnitlll tiN,oft" on the first Wednesday after a well is spudded or worl~over operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska ICounty, pamsh Or borough North Slope Borough ADL 25523 or Unit ITitle Drill Kuparuk River State Alaska IWell no, 3I-9 Auth. or W.O. no. AFE AK0987 Parker 141 AP1 50-029-21561 Operator ARCO AlaSka, Inc. Spudded 3/5/86 0600 hrs. 3/05/86 3/06/86 3/07/86 3/08/86 thru 3/10/86 Date end depth aa of 8:00 a.m. Complete record for each day reported ARCO W.I. Prior status if e W.O. 56.24% 16" @ 110' 110', (0'), Spud well Wt. 9.8, PV 14, YP 8, PH'I0, WL ll.2,.Sol 11 Accept rig @ 2245 hfs, 3/4/86. NO dtl'erter sys. 16" @ 110' 1665', (1555'), PU DD Wt. 10.2, PV 11, YP 14, PH 10, WL 16.2, So1 13 Spud well @ 0600 his, 3/5/86. Navi-Dzl & surv 1665'. 460', Assumed vertical 690', 3.2°, N25.7W, 689 TVD, 6 VS, 5N, 3W 1036', 9.5°, N28.8W, 1003 TVD, 4.5 VS, 40N, 21W 1605', 25.0°, N34.3W, 1574 TVD, 218 VS, 186N, l16W 16" @ 110' 2989', (1324'), TOH f/wsh out Wt. 9.4, PV 10, YP 10, PH 9.5, WL 20, $ol 11 DD & surv 12¼" hole to 2989'. 1812', 29.0°, N30.SW, 1758 TVD, 311VS, 265N, 166W 2121', 37.1°, N34.6W, 2018 TVD, 478 VS, 406N, 256W 2430', 44.1°, N33.4W, 2252 TVD, 679 VS, 572N, 371W 2934', 49.3°, N40.0W, 2596 TVD, 1047 VS, 867N, 590W 9-5/~' @ 3928' 8032', (5043'), Turbo-drl Wt. 9.7, PV 14, YP 12, PM 10, WL 9.4, Sol 8 Drl & surv 12~" hole to 3950', C&C, TOM. RU & rn 90 its, 9-5/8", 36~, J-55 BTC csg w/FS @ 3928', FC @ 3838'. Cmt w/1500 sx CS III, followed by 315 sx C1 "G". Dtspl using rig pmps, bump plug. CIP @ 206 hfs, 3/8/86. ND diverter, NU &tst BOPE. TIH w/BHA, tst csg to 2500 psi. DO to 3960', tst formation to 12.5 ppg EMW. Turbo-drl & surv 8½" hole to 8032'. 3278', 50.1°, N38.8W, 2818 TVD, 1309 VS, 1070N, 757W 3590', 50.1°, N41.5W, 3019 3910', 49.7°, N39.9W, 3225 4309', 50.8°, N39.5W, 3480 4808', 52.3°, N39.3W, 3790 5336', 51.6°, N40.0W, 4116 5899', 51.1°, N34.7W, 4467 6901', 48.9°, N35.0W, 5106 7926', 52.2°, N36.5W, 5761 T~D, 1548 VS, 1253N, 911W TFD, 1793 VS, 1438N, 1071W TVD, 2099 VS, 1674N, 1267W TVD, 2490 VS, 1976N, 1515W TVD, 2906 VS, 2296N, 1780W TVD, 3345 VS, 2646N, 2047W TVD, 4116 VS, 3282N, 2485W TVD, 4903 VS, 3924N, 2942W The above il correct Signature For form preparation 8nd~'dlstrlbutlon, see Procedure-, Menual, Section 10, Drilling, Pages 86 and 87. Title Drilling Superintendent ARCO Oil and Gas Company '~'v Daily Well History--Interim IllstmJctiolll: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "interim" sheets until final compietion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less fre~3uently than every 30 days, or (2) on Wednesday of the week in which oil string iS set. Submit weekly for workovers and following setting of oil string until completion. District Field County or Parish'jState Alaska North Slope Borough Kuparuk River Lease or Unit ADL 25523 Alaska Iwell no, 3I-9 Date and depth as of 8:00 a.m. 3/11/86 3/12/86 3/13/86 3/14/86 Complete record for each day while drilling or workover in progress 9-5/8" @ 3928' 8908', (876'), Drlg Wt. 9.9+, PV 15, YP 11, PH 9.5, WL 7.6, Sol 10 Turbo-drl & surv 8½" hole to 8908'. 8393', 53.4°, N39.7W, 6043 TVD, 5275 VS, 4220N, 3167W 9-5/8" @ 3928' 9200', (292'), Wrk tight hole Wt. 9.8+, PV 12, YP 7, PH 10.0, WL 7.5, Sol 9 Drl & surv 8½" hole to 9200', 57 std short trip. Hole tight off btm, wrk ea std free, stuck @ 8938'. Wrk & Jar pipe free, C&C. Wsh & rm hole. 8894', 54.8°, N39.3W, 6337 TVD, 5681VS, 4537N, 3420W 9125', 56.6°, N39.5W, 6467 TVD, 5871VS, 4685N, 3541W 9-5/8" @ 3928' 9200', (0'), POH to log Wt. lO.l, PV 11, YP 6, PH 9.5, WL 7.4, Sol 10 Wsh & rm to 9073', spot pill, POH. RIH, wsh & rm f/8844'-9200', 12 std short trip; tight @ 8890'. Wsh & rm f/8890'-9200', 5 std short trip, POH to log. 9-5/8" @ 3928' 9200', (0'), Rn'g 7" csg Wt. 10.1, PV 11, YP 7, PH 9.5, WL 7.8, Sol 10 RU Schl, rn DIL/GR/SP/SFL f/9122'-3929', FDC/CNL f/9122'-8440' & CAL f/9122'-3929', RD Schl. Make cond'g rn f/7" csg. RU & prep to rn csg. The above is correct Signature For form preparation and dis~ibution - see Procedures Manual Secti{ln 10, Drilling, Pages 86 and 87 Drilling Superintendent .ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, re0ort completion and representative test data in blocks provided. The "Final Report" form may be used for re0orting the entire operation rf space is availal31e~ Accounting cost center code District County or Parish I State Alaska North Slope Borough I Alaska Field Lease or Unit ~ Well no, Kuparuk River ADL 25523 3I-9 Auth. or W,O. no. IT t e AFE AK0987 I Drill Parker 141 Operator ARCO Alaska, Inc. Spudded or W,O. begun IA.R.Co. Date Spudded Date and depth as of 8:00 a.m. 3/15/86 Complete record for each day reported API 50-029-21561 W.I. rrotal number of wells (active or inactive) on tillsI Icost center prior to plugging and 56 · 24% labandonment of this well IHour I Prtor status if a W.O. 3/5/86 [ 0600 hrs. I 7" @ 9047' 9200' (TD), 8965' (PBTD) (0'), RR 9.8 ppg NaCl/NaBr Rn 224 its, 7", 26#, J-55 csg w/FS @ 9047', FC @ 8965'. Cmt w/100 sx Cl "G" lead & 400 sx C1 "G" tail. Displ w/9.8 ppg brine, bump plug. CIP @ 1615 hfs, 3/14/86. Tst csg to 3500 psi. ND BOPE, NU adapter flange & master vlv. Tst pack-off; would not hold pressure. ND tbg head, 7" cut too shoz:t. PU spear w/grapple & bumper sub on 1 std HWDP, RIH, set spear 12' below slips. Cut 7" csg, instl lower pack-off. NU tbg head, tst pack-off to 3000 psi. RI{ @ 0230 hfs, 3/15/86. Old TD New TO Date 9200 ' PB Depth 0230 hz:s, 3/15/86 EnO of rg Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Released rig 8965' Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P, Water % GOR Gravity Allowable Effective date corrected The above is correct Fo;' form preparation an~ distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drillin~ Superintendent ARCO AlasJca. Ira. Post Office Box 100360 Anchorage. AlasKa 99510-0360 Telephone 907 276 1215 DA~E 04-01-86 TRANSMITTAL # 5613 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. Please acknowledge receipt and OH LIS Tapes plus Listings: Schl: One of each 3N'9 03-23-86 3N-8 03-14-86 3N-8A 03-19-86 3N-7 03-06-86 31-12 03-22-86 3I-9 03-13-86 3I-8 03-02-86 2T-17 03-08-86 Cms Cum. Receipt Acknowledged: State Of AK-.~. · STATE OF ALASKA .... ~,,.~ ALASKA O,,_ AND GAS CONSERVATION COl,,,¢llSSlON ~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wellY~ Workover operation [] 2. Name of operator 7. Permit No. AR60 Alaska, Inc. 86-55 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21561 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well atsurface 180' FSL, 10' FEL, Sec.36, T13N, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 71' RKB ADL 25523 ALK 2559 10. Well No. 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of March , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0600 hrs, 3/5/86. Drld 12-1/4" hole to 3950'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 9200'TD (3/11/86). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 8965'. Secured well & RR @ 0230 hrs, 3/15/86. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 110'. Cmtd w/255 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 3928'. Cmtd w/1500 sx CS Ill & 315 sx Class G. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 9047'. Cmtd w/500 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/9122' - 3929' FDC/CNL f/9122' - 8440' Cal f/9122' - 3929' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~tt ~TZ/~ ~ TITLE Associate Engineer DATE Z~'Z-~ NOTE--Report his form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAM2/MR01 Submit in duplicate March 4, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 AnChorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: 3I-9. ARCO Alaska, Inc. Permit No. 86-55 Sur. Loc. 180-'FSL, 10'FEL, Sec. 36, T13N, RSE, UM. Btmhole Loc. 625'FNL, 1734'FWL, Sec. 36, T13N, RSE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be .present to witness testing of the equipment before the surface ~casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. (~e~ tru%~y~rs, c7-,;." Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COmmISSION dlf Enclosure cc: Department of Fish & Game, 'Habitat Section w/o encl. Department of Environmental Conservation w/o encl Mr. Doug L. Lowery · ARCO Alaska, Inc Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 24, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3I-9 Dear Mr. Chatterton: Enclosed are: ° An application for Permit to Drill a $100 application fee ° Diagrams showing the proposed horizontal projections of the wellbore ° A proximity plot ° A diagram and description of the system ° A diagram and description of the We estimate spudding this well on March questions, please call me at 263-4970. Sincerely, , : ... ?~.. /Regional Drilling Engineer JBK/tw PD/L233 Enclosures Kuparuk 3I-9, along with and vertical surface hole diverter BOP equipment 6, 1986. If you have any RECEIVED FEB 2 8 1986 Alaaka 0tl & Gas Cons C0mmis~ton ARCO Alaska, tnc. is a Subsidisry of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COi~,,vllSSlON P :RMIT TO DRILL 20 AAC 25.005 FCEIVED F E B 2 8 1986 la. Type of work. DRILL REDRILL DEEPEN 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SINGLE ZONE ~ MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 9. Unit or lease name Kuparuk River Unit 4. Location of well at surface 180' FSL, 10' FEL, Sec.36, T13N, R8E, UN At top of proposed producing interval 900' FNL, 1951' FWL, Sec.36, T13N, R8E, UM At total depth 625' FNL, 1734' FWL, Sec.36, T13N, R8E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 71', PAD 40' ADL 25523 ALK 2559 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 10. Well number 11. Field and pool Kuparuk River Fi eld Kuparuk River 0il Pool Amount $500,000 15. Distance to nearest drilling or completed :3 I -8 well 75' @ surface feet 18. Approximate spud date 03/06/86 2760 psig@ _80°F Surface j173 _psig@ &226 _ft. TD (TVD) 13. Distance and direction from nearest town 14. Distance to nearest property or lease line :30 mi. NW of Deadhorse miles 625' ~ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8965' MD, 6546' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 47 O[(see20AAC25.035 (c) (2) SIZE Hole Casing 24" 16" 12-1/4" 9-5/8" Weight 62.5# :36.0# CASING AND LINER Grade Coupling H-40 ! Weld -55/HF-EIW BTC -55/HF-E1W BTC Proposed Casing, Liner and Cementing Program SETTING DEPTH Length 4044 ' MD TOP TVD 80' 32' I :32' I 32' 32' I M D BOTTOM TV D 112~11 112' 4076'1 3251 ' QUANTITY OF CEMENT (include stage data) + 200 cf 1435 sx AS III 315 sx Class G 8-1/2" 7" 26.0# 8934' 31 ' I I 31 ' 8965'1 6546' 400 sx C1 ass G I t 22. Describe proposed progr.am: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8965'MD(6546'TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2760 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 31-9 will be 75' away from 31-8 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) · 23. I hereby cer/~j~.t~at the foregoing is true and correct to the best of my knowledge SIGNED / /~__~.~4/J2.~' TITLE Regional Drilling Engineer DATE The space b~e,~TC¢~ss~/us~ ~ - / CONDITIONS OF APPROVAL Samples requ. ired r-{YES ~NO Permit number APPROVED BY Form 10401 Rev. 7-1-80 Mud log required [--J YES Approval date ..--'n 03/0.4/~6 Directional Survey required APl number .h~f~ E s []NO 5O- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE 'lvr~-r-~h /, I ORA ....... , :~ ~.-vv by order of the Commission Submit in triplicate PERMIT TO DRILL 31-9 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. HO'-' ZONT AL ..pROJECT ION scALE 1 II4- = 1000 FEET 5,000 4000 3000 EASTMA14 wHIPSTOCK' INC. 5000 ALASKA WEST-EAST 0 3000 2000 1000 ~...t 4000 ~ TD LocATtON~ , 625' Ftl~-' 173~ FWL SEC- ~' Tt~tt. ~ 1000 2000 - 1000 0 RECEIVED FEB 2 8 1986 Alaska 0il & Gas Cons. Commission Anchorage SURf'ACE LOCAT, tON' o' FSL. ~O FL~___ ~C. 36, T13#, Ru~- 1000 N 38 5455' DEG 1 9 t'lIN W ARCO ALASKA. PAl:) :~. ~ELL Ne, 9 PRePOSED KUPARUF FIELD. NORTH SLOPE, ALASKA EASTH/i~I WHIPSTOCKL INC. I KOP TVD?-500 THD=500 DEP=O 3 9 -ts B~tlLD. 3. ~ PER lOO FT 21 ~ BASE PERMAFROST TVD-164t THD-17'23 DEP-3T8 ~9 45 EOC TVD-1911 TMD-2088 DEP-623 TOP UGNU.SNDS TVD-2221 THD-2548 DEP-963 3000 4000 . 5OOO TOP W SAK SNDS TVD=2811 THD'"3423 DEP=1609 K-t2 TVD-:3051 THD-,3779 DEP-1872 9 5/8" CSG PT TVD""3251 THDI4076 DEP-2092 K-5 TVD=4591 TI'1D=6064 DEP=3561 AVERAGE ANGLE 47 DEG 38 HI N RECEIVED FEB 2 8 1986 Alaska Oil & Gas Cons. Commission Anchorage 6000 7000 T/ ZONE D. TVD=6201 THD=8.453 DEP=5326 T/ ZONE C TVD-6226 THD-8490 DEP-5353 TARGET CNTR TVD-6319 TMD-8628 DEP-5455 T/ ZONE A TVD-6331 THD-8646 DEP-5468 B/ KUP S~DS TVD-6411 THD-8765 DEP-5556 TD (LOG PT) TVD-6546 THD=8965 DEP-5704 VERTICAL SECTION I I I I I i 1000 2000 3000 4000 5000 6000 ,., ! · ' I . " ~uP~u~ ~ ~vE~ UN~ 20" D~v~TER $cHE~T !C 6 5 2 A, ias~a Oil & Gas Co~s. Anchorage REC VrD FEB 2 8 1986 ~,las~ 011 & Gas COns. Anch3rage 7 6 5 4 ,, 13-5/~" D~. AGRAM #1 50C0 PSI RSRRA BOP STA(;:K !. 16" - 2000 PSI TAhI<~ STARTING ~F_AD 2. I1 · - 3000 PSI CASING t,D, AD 3. II · - 3000 PSI X 13--5/8' - 5000 PSI SPACI~R SPCCL 4. 1D-5/8" - 50C0 PSI PIPE 5. 13-5/8' - 5000 PSI DRILLING SPOOL W/C~ KILL LI~ES 6. 13-5/8" - 5000 PSI EO. JBLE R/~ W/PIPE RAM8 CIN TCP, 7. 13-5/8" - 5000 PSI AC~ATOR CAPACITY TEST I. Q-ECX At~ FILL AC~TOR RESI~OIR TO-F~ LEVEL WITH ~~IC ~UID. 2. ~ ~T A~T~ ~ IS ~ ~I WI~ I~ ~I ~T~ ~ ~ ~~T~. -3, ~~ TI~, ~ ~ ~ ~ITS SIXThlY 4. ~~ ~ ~ ~T, ~ A~~ L~ LIMIT IS 45 ~~ ~I~ TI~ ~ I~ ~I ~INI~ 13-5/8" BOP STACK TEST 1. FILL BOP STAQ< AhD CH(3<E MANIFOLD WITH ARCTIC DIESEL. 2. Q"E~ THAT ALL LOCK DC~ SC~ IN I~E]_L~ ARE FLLLY RETRACTED. SE. AT TEST PLUG IN WITH RUtCqING JT AhD RUN IN LC~ SC~. 3.~At~ F~ AhD MAI~JAL KILL Ah~ CHO<E [,Ih~~ VALVES ADJACENT TO BOP STAQ(, ALL OT]-E.R VALVES A, hD ~ SHOM_D BE CPEN. 4. PRE~ UP TO 250 PSI ~ HCLD FOR I0 MIN. IN- __Q:~__ PE~ ~.~Q_q~_P,~.I_,., AhD HCLD FOR I0 MIN. BL~'Fn PRE~ TO 0 PSI, 5. OPEN AhN. JLAR PREVENTER AhD MANUAL KILL AND CHCKE LIhE VALVES. CLOSE TOP PIPE RAMS AhD HCR VALVES C~ KILL AND C:HCKE LIhES. 6. TEST TO 250 PSI AhD 3000 PSI AS IN STEP 4. 7. CCNTIhlJE TESTING ALL VALVES, LI~_S, AhD CHCKES WITH A 250 PSI LOW AhD 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PF~ESSlJ~ TEST ANY NOT A FULL CLOSING POSITIVE SEAL CH(3(E, CN, Y FUNCTICN TEST CHCKES THAT DO NOT FI]L.LY CLOSE, CPEN TOP PIPE RAMS AhD CLOSE Bo'r'rc~ PIPE RAMS. TEST BOTTCI~I PIPE RAMS TO 250 PSI AND 3000 PSI. OPEN BOTTC~ PIPE RA~S, BAQ( OUT Rt,N~ING JT AhD CLOSE BLIhD RAMS AhD TEST TO 250 PSI AhD 3000 PSI. · 'OPEN BLIhD RAMS AhD RETRIEVE .TEST PLUG. MAk'E'.S~ MANIFOLD AhD LI~ES ARE FULL. C~' NCN-FREEZING. FLUID, SET ALL VALVES IN DRILLING POSITICN. 12. -TEST STAhDPIPE VALVES, KELLY, KELLY COQ<S, DRILL' PIPE SAFETY VALVE, AND INSIDE BOP TO 250 PSI AhD 3OOO PSI, 13. RE~ TEST IhF~TIC~ CN BL(3fa3JT P~ TEST F(3;~, SIGN, ~ SEhD TO DRILLING SUPERVISDR. 14, PERF~ ~ETE BCPE TEST AFTER NIPPLING UP AhD WEEKLY THEREAFTER FUNCTI(3qALLY CPERA~ 8OPE DALLY. . 9, .10, il, s~oo~4ool REv. 2 ~AV I ~., I ~.: ARCO Alaska, Inc," Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 17, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3I Pad (Wells 1- 16) Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU13/L06 Enclosure RFCFrVFD 2 4 1 86 5at~ bunS. UUhllnissi0n Anchorage If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany '~ ' ~URVEY SCALE= I =lalL~ NOTES COORDINATES ARE A.S.P ~ ZONE 4. SECTION LINE DISTANCES ARE TRUE. HORIZONTAL PER L.H.D. ~POSITIONSAssoc. BASEDON ON-PAD CONTROL VERTICAL POSITIONS BASED ONTBM 3~ -4 PER LHD & ASSOC. O.G. ELEVATIONS INTERPOLATED FROM S/C DWG. CED- RIXX-- 3050 rev. ~ , LOCATED IN PROTRACTED SEC. 5I,TI5 N, EgE, U. MEE. LOCATED IN PROTR~TED SEC.~,TI3 N, R 8E, U. MER. [- Y= 6,007,235.50 LAT. 70~5'5~.0592'' 9- Y= 6,007,[2[.00 LAT. 70°~5'50.4432" X= 50~,056.44 LONG. [49°56'03.596'' X= 507,~57.9[ LONG. ~49°56'09. ~34'' [79' FWL, 345' FSL 0G. 33.5', PAD 39.9' [80' FSL, [0' FEL OG. 35.0', PAD 39.9' 2- Y= 6 007,269.05 LAT. 70°~5'5[ S978" [0- Y= 6,007,[04.59 LAT. 70°~5'50.~82[ X= 50~,037.66 L0~G. [49~56'04.[4S'' X= 507,849.[[ LONG. [49°56'09.686'' [60' FWL, 328' FSL OG. 33.7', PAD 39.9' [64' FSL, [[- Y= 6,007 3- y= 6,007 LAT. 70°25'5[ X= 50S,0[~.~0 LONG. [49~5~'04.702'' X= 507,B30.23 LONG. [49°56'[0.~40 [4[' FWL, 312' FSL 0G. 33.7', PAD 40.0' ~47 FSL, 48' FEL 0G. 35.0, PAD 40.[ 4- Y= 5,007,236.23 LAT. 70°25'5[.57'52'' [2- Y= 6,007,07[.76 LAT. 70°25'49.9595 X= 507,999.99 LONG. [49~5~'05.255 X= 507,S[[.32 LONG. [49°56'[0.796'' [22' FWL, 295' FSL OG. 33.~', PAD 40.0' [3[' FSL, 66' FEL 0G. 35.0, PAD 40.~ 5- Y= ~,007,219.B[ LAT. 70°25'5[.4139" [3- Y= 6,007,055.3~ LAT. 70~25'49.79S[ X= 507,9~[.[6 LONG. [49°55'05.S0~'' X= 507,792.3~ LONG. [49~5~'[[.353'' [04' FWL, 279' FSL OG. 33.9', pAD 40.0' [[5' FSL, BS' FEL 0G. 35.0', PAD 40.[' 6' Y= 6,007,203.20 LAT. 70°25'5[.2507'' [~- Y= 5,007,03S.$~ LAT. 70~5'49.5359 X= 507,952.[2 LONG. [49~56'06.3~7'' X= 507,773.53 LONG. ~49°5~'~[.903'' S5' FWL, 252' FSL OG. 34.0', PAD 39.9' 9S' FSL, [04' FEL 0G. 35.0, PAD 40.[' 7- Y= 6,007,[S6.78 LAT. 70~25'5[.0S95'' [5- Y= X= 507,943.27 LONG. [49°55'05.920'' X= 507,754.S3 LONG. [49°56'[~.455'' 66' FWL, 246' FSL OG. 34.2', PAD 39.~" S~* FSL, S- Y= 5,007,[70.37 LAT. 70~25'50.92S2'' [6- Y= X= 507,924.40 LONG. [49~5~'07.475'' X= 507,73~.04 LONG. [49°55'[3.007'' 47' FWL, ~30' FSL 0G. 34.5', PAD 39.S' 65' FSL, [4~' FEL 0G. 35.0', PAD 40.2' C ERT1FIC ~TE OF SURVEYOR: ~ ~E~EBY CERTIFY TN~T I ~M ~EGISTE~ED ~ND ~ICEN~ED TO ~R~CTICE L~ND M~DE BY ME O~ UN~R MY SUPERVISION, AND ~Arcf~c Boulevard, Suite 20 7, Anchorage, Alaska 99503 IIs~LE AS SHOWN jl~oe II - . (2 thru (3) Admin (9 thru 12) -(10 and . (4) Cas (13 thru (5) BOPE, /~zT-// ~/Y~ (22 thru' 2~) (6) Add: ~2~ ~/~/$g 5. 6. 7. 8. . 10.- 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23, 24. 25. 26. 27. fee attached- Is well to' be located in defined pool a e®e®®eee®ee-eeeeeeeeeee®eeee®® Is well located proper distance from property line ............. 11 d di f ' Is we locate proper stance, rom other wells .................... Is.sufficient undedicated acreage available in this pool ............. /~. Is well to be deviated. 'and is wellbore plat. included ................ Is operator the only-affected party' · · Can permit be approved before ten-day wait .......................... .. ~K - Does operator have a bond in force ' · Is conservatSon order needed ' Is administrative approval needed ®e®®e®eee®eee®eeeee®eeeee®ee®eeeeee the lease number appropriate ~ ' IS le®e®®eeeeeeeeeeeeeee®eeeeeeeeeeeeee® Is conductor string provided ......................................... Is enough cement used to circulate on conductor and surface . . . Will cement tie in surface and intermediate or production strl;;; :.: Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... ~ · Are necessary diagrams of diverter and BOP equipment attached ....... ~f~ . Does BOPE have sufficient pressure rating - Test to ~rD psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. ~ Additional requirements ............................................. ~J~ Additional Remarks: ~:1 0 i-] H 0 . Geology: JAL Engi~eering: _ · ~ HJH //~'/~ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. LIS T~PE ~ERIFIC~ION LIS~ING H/CliO El HOZ WER[FICATIDN L[STINS PAGE.~. ~E UNIT' TYPE CATE SIZE 000 000' 016 000- 000 00¢ 000- 000 O.OB 000 000 003 000 000 004 000~',:~i~00 00~ 000 'iOOO _012 000 -O00 006 009 000003 · PE- C{TE SiZE 000 000 001 CODE 065 06'5 065 065 065 0:65 06.5. -065 065 CODE 065 LVP OlO. HO2 VERIFICATION LISTIN3 COMPANY WELL FIELD ~OUNTY STATE : ARCO ALRS'KA INC : 3I-9 : KUP~RU'K : NORTH SLOPE BOROUGH = ALASKA JOB NUMBER AT ACC: 71355 RUN' #1, DATE LO2GED:.I3 MAR 86 LOP: L. B. CUDNEY SING PE FLJID DENSITY VISCOSITY PH FLUID LOSS 9.625" : LSND = 9.9 LB/G = ~0.0 S = 9.5 = 7.6 C3 @ 3928' BlT SIZE.= 8.5" TO .3928' RMF ' = RMC - = RM AT BHT = 1, MATRIX SANDSTONE LVP 010.H02 VERIFICATION LISTIN~ PAGE HOLE CORRECTION : CALIPER **"""~--,.~- THIS 'DATA HAS NOT BEEN DEPTH_____________________..________~__._..SHIFTED- gVER~L~YS?~?~E~D C~i~N~TS~ '*****. S MAGNETIC TAPE. * SCHLUMBERGER LOGS INCLUDED WITH TqI * DgAL INDUCTION aPHERI~ALL¥ FDgUSED~L~G~(DIL) ~ DATA AVAILABLE: ~ 9122 ,TO 3~28~ ~ FORMATION DENSITY COMPENSATED LOG'CEDN) ~ COMPENSATED NEUTRON LDG (FDN)o ~ DATA AVAILABLE: 9096' TO 8~&O , G&MMA RAY IN CASING (GR.CNL) ¢ DATA AVAILABLE: 3928' TO 150 DATA FORMAT RECORD--~ - LVP 010.H02 VERIFICATION LISTINS ENTRY BLOCKS TYPE 2 SIZE 1 REPR CODE ENTRY 66 0 ~ I 66 B 4 73 60 9 ~ 65 D i , 66 DATUM sPECIFICATION BLOCKS. MNEM SERVICE SERVICE 'UNIT API API API'.. API FILE, SIZE .! . ' ID ORDERn ~ · LOG TYPE CLASS HOD 'NO. ." :~. DEPT FT 00' 000 00 :0" .'0 4 .lin -SFLU DIL ILD OIL -ILM':: DIL SP GR DIL G R :F ON CAL I. 'FDN RHOB FDN DR H 2. FDN 4RAT FON RNRA FDN ~P~I FDN 4CNL FDN E~ N L F DN GR C NL 1 0 OMMM DqMM DHMM MY GAPI IN G/C3 G/C3 p j,. C PS- CPS. G~PI O0 O0 120 : 46 ?0 -0 00 O0 010 O0 310 01.0 O0 310 01 , 0 O0 280 01:. 0 O0 350 _§2'~' ~ 0-' O0 356 1 0 00'420 O1 0 00 000. 00 0 00 890-~O0 0 O0 330 31 0 O0 330 30 O0 310 O1 220 01 . 0-.0 '4! P A G:E ~'DATA DEPT RH3B NPHI- EPT' p- HOB NPHI 'DEPT $~. RHOB NPHI DEPT SP RHDB I'NPHI DEPT SP RH-OB 9160.0000 '37,4883 -0~,8477 ~0.5859 9100~0000 -31 6826 1.8658 -57.6660 9000.0000 -35.9258 2.2092 49.7559 8900.0000 -34,3633 · 2.3323 39.2090 8800.0000 -45.6~45 2d4182 SFLU GR DRHD NCNL SFLJ GR DR'MD NCNL SFLU GR DRHD NCNL SFL~ GR ORHD NCNL SFLU GR DR~D 10.0254 ILO 1.7227 GR -4.9797 NR~T fi, DODO FCNL 4.2820 72.4023-. GR 0.0186 N~AT 1483. 6875 FCNL 3.3~40, iLO 87,21~8 GR 0.0576 NRAT 1778.6875 FCNL 3.~319 ILO 84-.9648 GR 0.2126 .NRA'T 1925.6875 FCNL 10.7988 ILD ?8.4648 GR 0.0752 NRA~ 352.890 87.214.8 4.'0789 423,3906 84,9.5 -3.63 534.:812'5 '~'GR 13.283'2 IlM 78.'4~48 CALI 2,7502 :RNRA -999 10,~707 9,3223 2,:S803 LVP 010.H02 VERIFICATIDN-LISTI. ~ NPSI NCNL DEPT SP RHOB NPHI DEPT RHDB NPHI: DEPT: SP RHOB 'NPHI DEPT SP RHDB NPHI DE PT SP RHDB NP~tI DEPT Sp RH3B N'PHI DEPT ~SP RHDB NPHI EPT P RHDB NPHI DEPT SR .RHOB NPMI DEPT SP RHDB NPHI DEPT SP 29.1504 8,700.0000 SFLU -40.2070 GR 2.4592 DRHD 36.3281 NC~.L 8500~0000 SFLU -36.9258 GR 2.3069 DRMD '45,7520 NCNL 8500.0000 SF'L~ -36.1i33 GR 2.547I DRH~ 41.-3086 NCNL_ 8600.'0000 ~FLJ -41.1133 GE '999.2500 DR~g -999'.2500 NCNL · 83~00.0000 SFLU -49.6445 GR -999.2500 DR'MD -999..2500 NCNL. 8200.0000 SFLU -49.8633 GR -999.2500 DR~D -999.2500 NCNL 00.0000, ~FLU 8~53.8945 GR -999,2500 DRH~ -999.2500 NCNL 8000.0000 SFLU -58o'6133 GR -999.2500 DRHD -999.2500 NCNL 7900,000~ SFLU -58.t75 GR -999.2500 D.R~3 -999-2500 'NCNL 7800.0000 SF'LJ ~:65.7227 GR -999,2500 DRH3 -999.2500 NC'NL 7700.0000 SFL~ -57.6758 GR 2087.5000 FC~.L 98.9568 GR 0.0244 NRAT tSg4,$ST5 FCNL 2.9866 ILB 107~71.:&8 GR ~ 0.0205 NRAT'- 1721.6'875 FCNL 2.6260 ILD 82.9668 GR' . 0.-Q967. NR~T 2085.5000 FC~L 2.7151 ILD 111.2148 '999.2'500 NR~T -999.2500 FCNL 3.2249 ILD" 2~1.~606 GR -999.2'500 NRAT -999.2500 *FCN-L 10.9160 ILD,- 232,0625 GR ' -9)9.2500 NRAT -999.2500 FCNL 5.6265 * IlO 161.187:5 GR -999.2500 NRAT -999.2500 FC~L 4.5945 ILD. ' 1-03.7773 GR '999.2500~ NRAT -999.2500 FCNL 4.3054 ILD _~22,0'898 GR ' 99'2500 NRAT -999.2500 FC~L 102.8398 GR -9)9,2500 NRAT -999.2500 FCNL 3o66~8 ILD 97.0898 GR 808.3125 GR 6.0593 ]LM 98,9648 CALI .3.2~83 RNR~,L 592-81Z5 ~GR ~6 .¸9 -999-, -999. -999,2500'. -999, GR 3"5276 ILM 97.0B98 CALl -'9~9.2500 -999. -99¸ - ,3;5784~ 12.4707 5 ~VP 010.HO2 VERIFIC-ATION LISTING PAGE 6 RHDB -999.2500 DRd2 NPHI -999.2500 NCNL DEPT 7600.0000 SFLJ SP -61.2383 GR RHDB -999.25Q0 DRH3 NPHI -999.2500 NCNL I-DEPT 7500.0000 SFLU SP -55.Z070 GR RH3B -999.2500 DR~D 999.2500 I NPHI - NCNL DEPT 7400.0000 SFLJ SP -57.2383 GR RHOB -999.2500 DRHD NP~I -999.2500 NCNL DEPT 7300.0000 SFL~ SP -66.7227 GR ~'RHDB -999.2500 DRHO NPflI -999.2500 NCNL 'DEPT~ 72-00.0000 SFLU >SP -65.0352 GR RH3B -999.2500 DRH9 NPHI -999.2500 NCNL DEPT 7100o0000 SFLD SP .62.2383 :; GR RHDB -999.2500 DRY'3 'NPHI -999.2500 NCNL DE'PT 7000.0000' SFLU SP -64.5352 GR RHDB -999.2500 DR~3 · NPHI -9.99.2500 NCNL DEPT 6900.0000 SFLU SP -53.7383 GR RHOB -999.2500 DR~ NPHI -999.2500 .NCqL DEPT: 6800.0000 SFL~ SP -65.7852 GR RHDB -999.2500 DRHD NPHI -999.2500 NC~L DEPT 6700.0000 SFL~ SP -71.0352 GR RHDB -999.2500 DRH'O NPHI -999.2500 NCNL DEPT 6600,0000 SFLJ -999.2500 NR&T -999.2500 FCNL 4~2117 ILD 107.6523 GR -999.2500 NRAT -999.2500 FC~L 4.4812 ILD 93.8398 GR -999.2500 NRAT -999.2500 FCNL 4.9656 ILD- 101.0898 GR -999.Z500 NR~T -999.2500 FCNL 4.1531 ILD I0:4.0898 GE -999,2500 -NRAT -9~9.Z500 FCNL 4.1570 ILO 106.5898 GR -999'.2500 NRAT -999.2500 FC~L ~.8~06 ILD 90.2148 GR -999.2500 NEAT -999.2500 FCNL 3.8596 ILD 108.6523 GR -9~9.2500 NRAT -999.2500 FCNL 1.1665 ILD 125.5273 GR -999,2500 NR~T -999.2500 FC~L 3.1252 'ILD 99.6523 GR -999.2500 NR.AT -999.2500 FC~L 4~.1570 ILD 105.2148 GR -999.2500 NRAT -9~9.2500 FCNL 3.0608 ltd -999.2500 RNRA -999.2500 GR ~.Z465 ILM 107.6523 -999.2500 RNRA -999.2500 GR 5,5515' 93.8398 CALt ~99.2500 RNRA -999.2500 GR ~9656'- ILM 101.0898 CALI -999'2500 RNRA -999.2500 GR 104'0898'" CALI -999.2500 -999.25oo 106o5898 CALI ~999.2500 '999.2500 -999.2S00, -99'9*2500 3,883I 108.6523 -999.2500 -999.2500 1o5333 125~5Z73 '999.2 ~9~9.2 .999.2500 -999.2500 .4.23IZ 11.9395 -999.2500. -999~2500 5,5750 - -999:.ZS00- 9~9.~oo ¢.7078 11'~3613 ~999'250§ -999. z50 11.9¢73 '999.2500 -999.~$00 ! 3.0~0 -999.2500 -999.2500 3;5784 ':ILM: 99.6523 CRL! -999*2500 RNRA -999.2500 OR 4°2273 ILM 105.2t~8 CALI -999.2500* RNR~ -999.2500 GR 3.0301 ILM 4. Zl.95 12.7363 -999.2500 -999.2500 3.1545- LVP OlO.H02 VERIFICATION LISTIN3 PAGE . 7 SP RHOB NPHI DEP? SP RHDB NPHI DEPT SP. RHDB NPHI -DEPT SP RHDB NPHI DEPT SP RHDB NPHI DEPT SP RH~B NPHI DEPT SP RHDB NPHI OEPT SP RHDB NPHI DEPT SP RH3B NPHI DEPT SP RH2B NPHI DEPT SP RHOB NPHI -66.3477 GR -999°2500 DRH3 -999.2500 NCNL 6500.0000 SFLJ -68.9102 GR -999.2500 DRHD -999.2500 NCNL 6400.0000 SFLU -61.8945- GR -999.2500 DRHD -999,2500 NCNL 63-00°0000 SFLJ -65.0977 GR -999.2500 DRY3 -999.2500 NCNL 6200.0000 SFL~ -64,8.~77 GR -999.2500 DRH2 -999.2500 NCNL 6100.0000 SFLJ -83.2852 GR -999.2500 DRY3 -999.2500 NCNL 6000.0000 SFLU -83.0977 SR -999.2500 DRHD -999.2500 NCN~ 5900..0000 SFLd -70.5977 SR -999.2500 DRY3 -999.250Q NCNL 5800.0000 SFLU -73.4727 . GR -999.2500 DRH3 -999.2500 NCNL 5700.0000 SFLJ -71.0977 GR -999.2500 DRH3 -999.2500 NCNL 5600.0000 SFLU -73.0977 GR -999.2500 DRHD -999.2500 NCN~ 110.8398 GR -999.2500 NR~T -9~9.2500 FCNL 2.828~ ILD 1~2.2773 GR '-999.2500 NR~T -999,2500 FCNL 2.9709 ILD 102.,~023 GR .999.2500 NRAT -999~2500 FCNL 2.9963 ILD 95~7I~8 GR -999.2500 -999..2500 2.6389 110. '777 3 ~999.2500 -999. 2500 4.2820 131.9375 -999.2,500 -999.2500 4.3992 126.,0898 -999..2500~ -999.2500 2.2932 109.95~8 -999.2500 -999.2500 3.0686 97.6523 -9~9.2500 -999'25'00 2.7424 33. 6523 -999.2500 -9:)9.2500 3.32.25 84,7773 -999*2500 -999.2500 NRA T FCNL ILO GR NR AT FC~L ILD GR NR AT FCNL ILD GR NRAT ~. FCNL ILD GR NRA'T FCNL ILD GR NRAT FC~qL IL ~ GR NRA-T FCNL ILD GR. NR~T FCNL 110.8398 CALl -999.2500 RNRA -999.2500 GR 3.0706 ILM 112,2773 CALl -999.2500 RNRA .999°2500 GR ' 3.2795- ILN; 102.4-023~ CA-LZ -999.2500. RNRA -999.2500 GR 2.65~5- ILM, 95.7t48 CALI -999.250-0 RNRA' -999.2500 GR'. 2 3.0706 11,7988 -999'2500 -999,250'0 -999'~2500 10.5410 -999.2500 RA O0 i 10 -999 -99.9~ ILM: CALI 12, GR . -999 126., -999; -999. 250 3.05'88, 87.6523 '-999o2500 -999,2500 2,9084 93.6523 -999.2'500 -999. 2500 cILM ALI RNRA GR CALl RNR A -99 0 · 2509 · 250 --{ -3.5120 ILM B4.7773 CALI -999.2500 RNR-A -99~.2500 GR "3.3088'. 10,13'~8 · -999.2500 -999.2'5'00 LVP 010oH02 VERIFICATION DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP RHDB NPHI DEPT SP H'DB .PHI DEPT SP' RHDB NPgI DEPT SP RHOB NPHI DEPT SP RHDB NPHI DEPT SP RHDB NPHI DEPT SP RHOB NPHI DEP? SP RHOB NPHI DEPT SP RH~B NP~I 550D.0000 SFLJ -73.8477 GR -999.2500 DRHg -999,2500 NCNL 5~00.0000 SFLd -77.9102 GR -999.2500 DRHg -999.2500 NCNL 5300.0000 SFL~ -79.3677 GR -999.2500 DRH3 -999.2500 NCNL- 5200.0000 SFLU -78.1502 GR -999.2500 DRHg -999.2500 NC~L 5100.0000 SFLg -79.6502 GR -999.2500 DRH] -999.25.00 NCNL $000.0000 SFLd -84.4102 GR -999.2500 DRHD -999.2500 NCNL 4900.0000 SFLU -86.9102 GR -999.2500 DRY3 -999.2500 NCNL 4.800.0000 SFLU -87.1502 GR -999.2500 DR~D -999.2500 NCNL ~700.0000 SFLd -87.0977 GR -999. 500 DRHO -999.~500 NCNL~ §:oooo 660'2 GR -999.2500 DRND -999.2500 NCNL 4500.0000 SFLU -89.~102 GR -999.2'500 DRH3 -999.250'0 NCNL LISTIN3 3.5686 ILD 113.g023 GR -999.2500 NRAT -939.2500 FCNL 3.~006 37.2148 GR -999.2500 NR~T -999.2500 FCNL 3.0139 ILD 91.6523 :GE -999.2500 NRAT -999.2500 FC4L 3.2776 ILD 98*2773 GR -999.2500 NRAT -999.2500 FCNt 3.56~7 ILD 97.96~8 GR -999.2500 NRAT -999.2500 FC~L - 3,9182 ILD 104.7773 GR -999.2500 NRAT -939.2500 FCNL 3.8889 ILD 105.9023 GR -999.2500 NRAT -999.2500 FC4L 4,0671 ILD 35,2773 G~ -999.2500 NR:~T -999.2500 FCNL 4.4539 ILD 101.9023 GR -999.2500 NRAT -999-.2500 FCNL 4.~03I ILD 105.7773 GR -999.2500 NRAT -999.2500 FCflL 3.8772 ILD 100.0273 GR -999.2500 NRAT -999.2500 FC~L 4.215.6 ILM 113.4023 CALI -999.2500 RNRA -999.2500 GR 3.5'706 IL'4' 97.2'148 'CALI -999.2500 'RNRA ~999.2500 GR~ ~3o3303 ILM 91.6523 CALI -999.2500 RNRA -999.2500 3.5~91 ILM 98.2773 -999,,2500 RNRA -999.2500 GR 3:,8889 ILMi 97.96%8 -999.2500' RNRA -999.2500 ~G'R )0 4.3562- 105.9'023' CALI -999.2500 'RNRA -999.2500 GE 3.9963 ILM 95.2773 -999.2500 -999. 2500 GR I CALI -99 RNRA -999..Z!;00 GR 4.6335 ILM 105.7773 CALI: -999.2500 RNR~ -999.2500 GR · ..,4,4929 100.0273 ·CALI -999.2500 R.NRA -999.2.500 . GR PAGE B 4.1335 10.2520 -999.2500 ~999.2500- 3,4573 10'~6035 -999.2500 -999',2:500 3.2i51 1.2.2910 -999.2500 -999.2500 3.9Z99 10~707- .99.9.2500 '999.2500' -999~ 10.5020 -999.2500 -999~2500 10.8535 -999.2500 -999.2500 'LVP 010.H02 VERIFICATIDN LISTINS PAGE 9 DEPT SP RHDB NPHI DEPT SP RHDB NPflI OEPT SP RHOB NPHI DEPT SP RHOB ~PHI DEP? SP RHOB NPHI DEPT SP RHDB NPHI DEPT SP RHDB NPHI DEPT SP RHOB NPHI DEPT SP 'RHDB NPHI DEP? SP RHDB NPHt DEPT SP RHOB 4¢00.0000 SFLU -97.4102 GR -999.2500 -999°2500 NCNL 4300.0000 SFL~ '90.6502 GR -999.2500 DRH3 -999.2500 NC~' 4200.0000 SFLJ '94.4102 GE -999.2500 DR~3 -999.2500 NCNL 4100.0000 SFLJ -95.5977 GR -999.2500 DRH3 -999.2500 NCNL 4000.0000 SFLJ -96.9102 GR -999.2500 .DRHD -999.2500 NCNL 3900.0000 SFLU -999.2500 GR -999.2500 DRH3 -999.1500 NC~L 3800.0000 SFLJ -999.2500 GR -999.2500 DRH3 -999.2500 NCNL 3700.0000 SFLU -999.2500 GR -999.2500 DRHD- -999.2500 NCNL 3600.0000 -SFLd -999.2500 GR -999.2500 DRHD -999,2500 NCNL 3500.0000 SFLU -999.2500 GR -999.2500 DR~3 -999.2500 NCNL 3400'.0000 SFLJ -999.2500 GR -999.2500 DRH'3 4.9656 ILD 124.2148. GR -999.2500 NRAT -999.2500 FCNL 3.5159 ILD 86.2148 GE -999.ZSOONRAT -999.2500- FCN'L 2.9065 ILO 85.589B GE -9~9.2500 NEAT -999.2500 FC~L 3.~865 ILO 96.8398 GR -999.2500 NRAT -999.Z500 FCNL 3.4338 ILO B3.5898 GR -999°2500 NR~T -999.2500 FCNL -999.2500 ILD -9~9.2500 GR -999.2500 NRAT -999.2500 _FCNL -9~9.25'00 ILO -999,2500 GR -999o2500 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 GR -999~2500 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 GR -9~9o2500 NRAT -999.2500 . F~NL -999.2500 ILO -9~9.2500 GR -999.2500 NRAT -9~9.2500 FCiC -9~g.2500 ILO -999.2500 GR -999.2500 NRAT' 4.9226 ILM 124 . 2148 CALI -999o2500 RNRA -999.2500 -GR 3.8108: I ~ 86o21~8' C~[I -999.Z500 RNRA -g99.2500 GR .3.1&2B ILM~ 85..5898~- CALI, -999.2500 ~ RNEA -999.z5oo :i,~Ge 96.8398-.' CALI -999'2500 ~RNRA -999.Z500 ~GR -999' -999o2501 -999, -999, -99 )0 C -999.'Z 500 '999,,,2500' .GR -999.Z500 RNRA -999.2500 GR -999.Z500 -_999'2500 CALI -999.2500 ' RNRA -999.2500 GE -999w2500 -999, Z500. CALI -999;2500 RNEA -999.2500 GR -999°2500 ILM -999.2500 CALI -999.2500 RNR~ 4.8171 12.1&Z6 -999.2500 -999~2500 3.59~9 . 11.36-13 '999.250,0 -9~9.2500 -999,2500 ~ 80.9i :999.2500 999.2500 -999,2500 -999.ZS00 -999. z500. - 99 9.:, 2 SO0 : ~g. 168o ~999 o 2500 '999' 2500" -999'2500 .58,7930 -999.2500' -999.2500 -999.2500 ~7.~805- - 999.25,00 999.2500 999.25.00 51.0.117 -9'99.2500 -999.2500 -999.2500 LVP 010.H02 VERIFICATION NP~I DEPT SP RHOB NPHI DEPT SP RH3B DEPT SP RHOB NPHI OEPT SP RHOB NPMI DEPT SP RHOB NPHI EPT P RHOB NP~I DEPT SP ~ RHOB NPMI DEPT SP .RH3B NPHI DEPT SP RHOB NPHI DEPT HgB NPHI DE'PT SP -999.2500 3300.0000 -999.2500 -999.2500 -999.2500 3200.0000 -999.2500. -999.2500 -999.2500 3i00,00'00 '999.2500 -999.2500 -999.2500 3000.0000 -999.2500 7999.2.500 -999.2500 2900.0000 -999.2500 -999.2500 -999.2500 2800.0000 -999.2500 -999.2500 -999.2500 2700.0000 -999. 2500 -999.2500 -999.2500 2600.0000 ~999.2500 -999.2500 -999.2'500 2500.0000 -999.2500 -999.2500 -999.2500 2~00o0000 -999.2500 -999.2500 -999.2500 2300.0000 '999.2500 NCNL SFLU GR OR~D NCNL SFL~ GR DRHD NCNL SFLU GR DRH3 NCNL SFLU GR ORHO NCNL -SFLU GR OR~D NCNL SFL~ GR ORH3 NCNL SFLU GR DRHD NCNL SFLU GR DRHO NCNL SFLg GR DR~O NCNL SFLJ DRH~ NCNL S',F L U GR LISTING ~999.2500 FCNL -999.2500 ILO -999,2500 GR- -939,2500 NRAT' -999.2500 FCNL -999.2500 ILD -999.25:0'0 GR -9,~9.2500 NRAT'~ -999.2500. FCNL -999,2500 /ILD -999.2500 ~T -999.2500 -999,2500 FCNL -999.2500 ILO -999.2500 G.R -939,2500 NRAT -999,2500 FC~-L -999.Z500 IL'D 999~.2500 GR -999.2500 ,:NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999,2500 FCNL. -999.2500 ILO -999.2500 GR -999.2500 -NRAT -999.2500 FCNL ~999:Z500'/ ILO 9992500GR -999.,2500 NRAT -999.2500. FC,NL: -.999,2500 'ILO '9~9.2500 GR _ -999.2500 NRAT -999.2500 FCNL -9~9.250.0 ILO -999.2~00 GR -9-99;2500 NRAT -999.2500 FCNL -999'.2~00 ILD -999.2500 GR -999.2500 GR -999.2500 ILM -999.2500 CALI -999.25.00 ~ RN~A -999.2500 GR -999.2500 ILM -999.2500 CALl.: ''~99~2500 RNRA -999.2500 GR M lI -99~ -999° 2 -999.2500 .I -999.2'500 -999.2~00~ -999'.2500, -999.2500 ILM- ~ 999.2500-. -99'9.2500- RNR~,; -999.2500 GR -999.2500 -999.2500 -99g,2500 ' RNRA -999.2500 GR -999.2500 -999~2500 C.ALI -999.2500 RN,R~ -999.2500 GR -999.2500' -999.2500 CALI GR PAGE 10 -999o2 -999.Z -9~. -9 .{ --999.2 39 ';07 -999.2500 -999.2500 LVP 010.H02 VERIFICATID~ LISTINS PAGE RHOB -999,2500 DRH3 NPHI -999,2500 NCNL DEPT 2200°0000 SFLU SP -999.2500 GR RHDB -999.2.500 DRHD NPHI -999.2500 NCNL DEPT SP RHO.B DEPT SP EHOB NPHI OE PT SP EHDB NPHI - DEPT SP. NPHI DEPT SP RHDB NPHI, DEPT sP RHDB NP~I DEPT SP RHDB NPHI DEPT:. SP RHOB NPHI 2100.0000 SFLJ -999.2500 GR -999.2500 DRHD -999.2500 NCNL 2000,0000 SFLU -999.2500 GR -999,2500 DRHD -999.2500 NCNL 1~00.0000 SFLU -999.2500 GR -999.2500 DRHD -999.2500 NCNL 1800~O000 SFLJ -999.2500 GR -999.25.00 DRH~ -999.2500 NC~L 1700.0000 SFL~ '999-2500 GR -999,2500 DRHD -999.2500 NC~L i600o0000 SFLU -999,2500 GR -999.2500 DRH3 -999,2500 NCNL 1500.0000 SFLJ -999°2500 GR -999.2500 DRHD -999.2500 -NCN~ 1695.5000 SFLU -999.2500, GR -999.2500 DRHD '999.'2500 NCML. ~ FILE TRAILER ~ FILE NAME ~ :EDIT SERVICE NAME VERSION # : DATE : '999.2500 NR&T '999.2500 FCNL -999.2500 RNR~ -999.2500 GR -999,2500 ILO -999.2500 GR -999.2500 NR~T -999.2500- FCNL -999.2500 ILO -999.2500 GR -9~9.-2500 NEAT -999°2500 FC~L. -999..2500 ILD -999o2~00 GR -999,2500 NR~T -999,2500 FCNL -999,2500' I'LD -999'2500 GR '999.2500 ~ NEAT -999.2500' FCNL -999.2500 ItO -999.2500 GE -999~2500- NEAT -999.2500 FCNL -999.2500 ILM -999.2500 CALI -999.2500 'RNRA -99'9,2500 'GE ,9~9.2500 -999.2500 CA~! -999,2500 RNR;A -999.2500 --4 '999.250 ,999. Z 500' -999.2500' - 999; 250,0 < -999o2500~ -999 -99~, -999.2'500 ILD 9 -999.2500 GR -9-99.2500 NEAT -999.2500 , FCNL -' ~999.2500 ILD ~999w 999-2500 GR -999. -999.2500' 'NEAT''-'999. -9~9.2500 FCNL -999.; -999,2500 ILD .'-999.2500 GR -999.2500 NE~T -999.2500 FC~L ~ -999.2500 ILD' '999.2500 ' GR ~ -999.2500 ~ NEAT -999.2500 'FCNL )0 LVP OlOoHO2 VERIFICATION LISTIN; AXIMUM,-LENGTH : 102¢ ILE TYPE : ' ~EX?~ FILE NAME : :EDIT ~CO~MENT~'. ,EDIT ION ~NAME : COMMENTS ~LIBRARY TApE
