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Home My WebLink About189-038CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Cc:Brooks, Phoebe L (OGC) Subject:FW: KRU 3I-06 (PTD 189-038) Update and plan forward Date:Tuesday, August 30, 2022 2:09:44 PM Attachments:AnnComm Surveillance TIO for 3I-06.pdf MIT KRU 3I-06 06-05-22.xlsx From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Thursday, August 25, 2022 9:52 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: KRU 3I-06 (PTD 189-038) Update and plan forward Chris, KRU 3I-06 (PTD 189-038) has reached the end of the 90 day monitor period on Produced Water Injection. The monitor period went well with no signs of TxIA communication while on Produced Water Injection. This corroborates the theory that the TxIA communication was only active while on Seawater Injection. Additionally the well passed a SW MITIA during the monitor period. CPAI plans to return this well to normal operation under AIO 2C and manage the well internally to limit the well to Produced Water Injection only. A 90 day TIO trend and 10-426 are attached. Please let me know if you disagree or have any questions with the plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 From: Well Integrity Specialist CPF1 & CPF3 Sent: Monday, October 18, 2021 12:20 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3I-06 (PTD 189-038) Report of intent to BOI Chris, KRU 3I-06 (PTD 189-038) has been shut in since 6/11/2019 due to slow TxIA communication while on Seawater Injection. To determine if this is a temperature sensitive issue CPAI intends to bring the well online, on Produced Water Injection for a 90 day monitor period. Once the well has stabilized a State Witnessed MITIA will be performed (the last MITIA passed on 7/9/2019, attached). The well will then be monitored for TxIA communication for the remainder of the monitor period and if it is proven to have integrity on Produced Water Injection the proper paper work will be submitted for continued injection. A wellbore schematic is attached. Please let me know if you disagree or have any questions with the plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 3I-06 90-Day Bleed HistoryWELL DATE STR-PRES END-PRES DIF-PRES CASING3I-06 2022-05-30 1100.0 750 -350.0 IA3I-06 2022-05-30 800.0 250 -550.0 OA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod ByLast Tag: SLM 6,950.0 12/19/2015 3I-06 pprovenLast Rev Reason Annotation End Date Wellbore Last Mod ByRev Reason: PULL CA-2 PLUG 11/9/2016 3I-06 pprovenCasing StringsCasing DescriptionCONDUCTOR OD (in)16 ID (in)15.06 Top (ftKB)36.0 Set Depth (ftKB)116.0 Set Depth (TVD) …116.0 Wt/Len (l…62.50 GradeH-40 Top ThreadWELDEDCasing DescriptionSURFACE OD (in)9 5/8 ID (in)8.92 Top (ftKB)35.0 Set Depth (ftKB)3,459.7 Set Depth (TVD) …3,401.9 Wt/Len (l…36.00 GradeJ-55 Top ThreadBTCCasing DescriptionPRODUCTION OD (in)7 ID (in)6.28 Top (ftKB)33.0 Set Depth (ftKB)7,065.8 Set Depth (TVD) …6,543.6 Wt/Len (l…26.00 GradeJ-55 Top ThreadBTCTubing StringsTubing DescriptionTUBING String Ma…2 7/8 ID (in)2.44 Top (ftKB)31.0 Set Depth (ft…6,593.9 Set Depth (TVD) (…6,128.1 Wt (lb/ft)6.50 GradeJ-55 Top ConnectionEUE8rdABMODCompletion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.0 31.0 0.02 HANGER CAMERON TUBING HANGER 2.875 1,823.3 1,823.3 0.36 SAFETY VLV OTIS SERIES 10 TRDP SAFETY VALVE 2.313 6,507.7 6,051.8 27.36 PBR AVA PBR w/ HYDRAULIC RELEASE 2.312 6,522.3 6,064.8 27.45 PACKER AVA RHS RETRIEVABLE PACKER 2.347 6,559.2 6,097.4 27.67 NIPPLE CAMCO D NIPPLE 2.250 6,593.2 6,127.6 27.88 SOS AVA SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 6,976.0 6,464.7 28.40 FISH 1 1/2" DMY Found GLM #7 (6461') Empty; DV installed on 1/26/97 Fell to Rathole 1/30/1997 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,665.0 6,673.0 6,191.0 6,198.1 C-4, UNIT B, 3I- 06 11/7/1989 6.0 IPERF Zero deg. phasing, 2 1/8" SIlver Jet 6,721.0 6,736.0 6,240.4 6,253.7 A-3, 3I-06 11/7/1989 6.0 IPERF Zero deg. phasing, 2 1/8" SIlver Jet 6,743.0 6,772.0 6,259.8 6,285.4 A-2, 3I-06 5/16/1989 4.0 IPERF 90 deg. phasing, 4 1/2" Ultrapak 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 2,600.5 2,599.9 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 5/15/1989 2 4,221.9 4,064.6 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 5/15/1989 3 5,039.5 4,770.6 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 5/15/1989 4 5,401.4 5,083.6 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 5/15/1989 5 5,764.2 5,396.7 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 5/15/1989 6 6,128.9 5,716.1 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 5/15/1989 7 6,461.1 6,010.3 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/20/2015 Notes: General & Safety End Date Annotation 1/10/2011 NOTE: View Schematic w/ Alaska Schematic9.0 10/8/2011 NOTE: WELDED 3' LONG SLEEVE IN EXISTING SURFACE CASING CommentSSSV: TRDP3I-06, 6/12/2019 6:00:09 AMVertical schematic (actual) PRODUCTION; 33.0-7,065.7 FISH; 6,976.0 IPERF; 6,743.0-6,772.0 IPERF; 6,721.0-6,736.0 IPERF; 6,665.0-6,673.0 SOS; 6,593.2 NIPPLE; 6,559.2 PACKER; 6,522.3 PBR; 6,507.7 GAS LIFT; 6,461.1 GAS LIFT; 6,128.9 GAS LIFT; 5,764.2 GAS LIFT; 5,401.4 GAS LIFT; 5,039.5 GAS LIFT; 4,221.9 SURFACE; 35.0-3,459.7 GAS LIFT; 2,600.5 SAFETY VLV; 1,823.3CONDUCTOR; 36.0-116.0HANGER; 31.0 KUP INJ KB-Grd (ft)42.01 Rig Release Date4/19/1989AnnotationLast WO:End Date 3I-06H2S (ppm) Date...TDAct Btm (ftKB)7,100.0Well AttributesField NameKUPARUK RIVER UNIT Wellbore API/UWI500292193500 Wellbore StatusINJ Max Angle & MDIncl (°)30.87 MD (ftKB)4,200.00WELLNAME WELLBORE3I-06 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1890380 Type Inj W Tubing 2200 2210 2210 2210 Type Test P Packer TVD 6065 BBL Pump 1.8 IA 640 3000 2920 2900 Interval 4 Test psi 1516 BBL Return 1.8 OA 420 660 670 670 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 3I Pad Austin McLeod Arend / Richwine 06/06/22 Notes: Notes: 3I-06 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)MIT KRU 3I-06 06-05-22 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3I-06 KUPARUK RIV UNIT 3I-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 3I-06 50-029-21935-00-00 189-038-0 W SPT 6064 1890380 1516 2200 2210 2210 2210 420 660 670 670 4YRTST P Austin McLeod 6/6/2022 MITIA 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-06 Inspection Date: Tubing OA Packer Depth 640 3000 2920 2900IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220606190858 BBL Pumped:1.8 BBL Returned:1.8 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 16:11:22 -08'00' 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Tuesday, October 19, 2021 9:17 AM To:AOGCC Records (CED sponsored) Subject:FW: KRU 3I-06 (PTD 189-038) Report of intent to BOI Attachments:3I-06.pdf; MIT KRU 3I-06 and 13 SI TESTS 07-09-19.xlsx From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, October 18, 2021 12:20 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3I‐06 (PTD 189‐038) Report of intent to BOI Chris, KRU 3I‐06 (PTD 189‐038) has been shut in since 6/11/2019 due to slow TxIA communication while on Seawater Injection. To determine if this is a temperature sensitive issue CPAI intends to bring the well online, on Produced Water Injection for a 90 day monitor period. Once the well has stabilized a State Witnessed MITIA will be performed (the last MITIA passed on 7/9/2019, attached). The well will then be monitored for TxIA communication for the remainder of the monitor period and if it is proven to have integrity on Produced Water Injection the proper paper work will be submitted for continued injection. A wellbore schematic is attached. Please let me know if you disagree or have any questions with the plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 6,950.0 12/19/2015 3I-06 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: PULL CA-2 PLUG 11/9/2016 3I-06 pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 116.0 Set Depth (TVD) … 116.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 3,459.7 Set Depth (TVD) … 3,401.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 7,065.8 Set Depth (TVD) … 6,543.6 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 31.0 Set Depth (ft… 6,593.9 Set Depth (TVD) (… 6,128.1 Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.0 31.0 0.02 HANGER CAMERON TUBING HANGER 2.875 1,823.3 1,823.3 0.36 SAFETY VLV OTIS SERIES 10 TRDP SAFETY VALVE 2.313 6,507.7 6,051.8 27.36 PBR AVA PBR w/ HYDRAULIC RELEASE 2.312 6,522.3 6,064.8 27.45 PACKER AVA RHS RETRIEVABLE PACKER 2.347 6,559.2 6,097.4 27.67 NIPPLE CAMCO D NIPPLE 2.250 6,593.2 6,127.6 27.88 SOS AVA SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 6,976.0 6,464.7 28.40 FISH 1 1/2" DMY Found GLM #7 (6461') Empty; DV installed on 1/26/97 Fell to Rathole 1/30/1997 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,665.0 6,673.0 6,191.0 6,198.1 C-4, UNIT B, 3I- 06 11/7/1989 6.0 IPERF Zero deg. phasing, 2 1/8" SIlver Jet 6,721.0 6,736.0 6,240.4 6,253.7 A-3, 3I-06 11/7/1989 6.0 IPERF Zero deg. phasing, 2 1/8" SIlver Jet 6,743.0 6,772.0 6,259.8 6,285.4 A-2, 3I-06 5/16/1989 4.0 IPERF 90 deg. phasing, 4 1/2" Ultrapak 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 2,600.5 2,599.9 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 5/15/1989 2 4,221.9 4,064.6 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 5/15/1989 3 5,039.5 4,770.6 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 5/15/1989 4 5,401.4 5,083.6 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 5/15/1989 5 5,764.2 5,396.7 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 5/15/1989 6 6,128.9 5,716.1 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 5/15/1989 7 6,461.1 6,010.3 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/20/2015 Notes: General & Safety End Date Annotation 1/10/2011 NOTE: View Schematic w/ Alaska Schematic9.0 10/8/2011 NOTE: WELDED 3' LONG SLEEVE IN EXISTING SURFACE CASING Comment SSSV: TRDP 3I-06, 6/12/2019 6:00:09 AM Vertical schematic (actual) PRODUCTION; 33.0-7,065.7 FISH; 6,976.0 IPERF; 6,743.0-6,772.0 IPERF; 6,721.0-6,736.0 IPERF; 6,665.0-6,673.0 SOS; 6,593.2 NIPPLE; 6,559.2 PACKER; 6,522.3 PBR; 6,507.7 GAS LIFT; 6,461.1 GAS LIFT; 6,128.9 GAS LIFT; 5,764.2 GAS LIFT; 5,401.4 GAS LIFT; 5,039.5 GAS LIFT; 4,221.9 SURFACE; 35.0-3,459.7 GAS LIFT; 2,600.5 SAFETY VLV; 1,823.3 CONDUCTOR; 36.0-116.0 HANGER; 31.0 KUP INJ KB-Grd (ft) 42.01 Rig Release Date 4/19/1989 Annotation Last WO: End Date 3I-06 H2S (ppm) Date... TD Act Btm (ftKB) 7,100.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292193500 Wellbore Status INJ Max Angle & MD Incl (°) 30.87 MD (ftKB) 4,200.00 WELLNAME WELLBORE3I-06 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1890380 Type Inj N Tubing 2540 2540 2540 2540 Type Test P Packer TVD 6065 BBL Pump 1.3 IA 150 1810 1770 1755 Interval 4 Test psi 1516 BBL Return 1.2 OA 0 10 10 10 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1890250 Type Inj N Tubing 2350 2375 2375 2375 Type Test P Packer TVD 6060 BBL Pump 1.7 IA 350 1800 1730 1715 Interval 4 Test psi 1515 BBL Return 1.6 OA 0 10 10 10 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 3I Pad Weimer / Green 07/09/19 Notes: Notes: 3I-06 3I-13 Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)MIT KRU 3I-06 and 13 SI TESTS 07-09-19 WELL LOG TRANSMITTAL 9905751837 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log with ACX: 3I-06 Run Date: 6/11/2019 3 109 5 August 5, 2019 RECEIVED AUG 13 2019 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3I-06 Digital Data in LAS format, Digital Log file, and Interpretation Report 1 CD Rom 50-029-21935-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: o* Signed: Wallace, Chris D (CED) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Tuesday, May 28, 2019 10:03 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 31-06 (PTD 189-038 Report of Suspect TxIA communication update Attachments: 31-06 90 day TIO trend 5.28.19.1PG Chris, KRU injection well 31-06 (PTD 189-038) was reported for showing suspect signs of TxIA communication. The well is on a 90 day monitor due to the slow if not intermittent nature of the suspect communication. The plan as previously reported is to perform an ultrasonic acoustic log while the well is online, but CPAI has been unable to do so due to the tool being out of Alaska and most recently a telemetry tool string section that is needed is currently being used on a rig job in Alpine. The equipment is scheduled to be available in the next few days post conclusion of the rig job. CPAI intends to extend the monitor period 14 days to leave the well online for the acoustic log. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions. Regards, Jan Byrne covering for Rachel Kautz/Sara Carlisle CPF1 & 2 Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM Conoc&Wips Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday, March 17, 2019 11:56 AM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: RE: KRU 31-06 (PTD#189-038) Report of Suspect TxIA Communication Chris, KRU 31-06 passed the diagnostic MITIA and wellhead packoff tests performed at the start of the water injection monitor period, however, the well continues to show suspect IA pressure increase. Since slow tubing to IA leaks are notoriously difficult to diagnose, CPAI would like to edit the previously communicated plan forward. CPA[ would like to leave the well on water injection service for a time (not to exceed the remainder of the monitor period) to confirm if the suspected leak has a sufficient leak rate and is consistently active to justify running an acoustic leak detect log while the well is injecting. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: Carlisle, Sara E Sent: Thursday, February 28, 2019 7:49 PM , Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: LlkA.Wells Supt <n1030@conocophillips.com> Subject: I-06 (PTD#189-038) Report of Suspect TxIA Communication Hi Chris, KRU injector 31-06 (PTD#189-038) is exhibits signs of TxIA communication due to increasing IA pressure while on seawater injection. This well was previously monitored in 2016 for a slow IA pressure rise; However, TxIA was not observed during that monitor period. The well is currently,pnline and will be placed on a 90 -day monitor period due to the slow nature of the build-up. During this time, we will test the T & IC PO's and perform a MIT -IA and DDT -IA to confirm the integrity of the well. If the suspected communication is confirmed, we intend to shut in the well and will schedule further diagnostics as needed. Please let me know if you have any questions or disagree with this plan. Attached is a 90 -day TIO plot and wellbore schematic for 31-06. Sincerely, SCWalCa# 41& (He44#0 Well Integrity Supervisor, Alpine & CPF3 Wells Data Analytics KOCF-218, ConocoPhillips Alaska Wallace, Chris D (DOA) From: Carlisle, Sara E <Sara.E.Carlisle@conocophillips.com> Sent: Thursday, February 28, 2019 7:49 PM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: KRU 31-06 (PTD#189-038) Report of Suspect TxlA Communication Attachments: 31-06 AnnCom� m 90-dayTIO.pdf; 31-06 Schematic.pdf Hi Chris, KRU injector 31-06 (PTD#189-038) is exhibiting signs of TxlA communication due to increasing IA pressure while on seawater injection. This well was previously monitored in 2016 for a slow IA pressure rise; However, TxIA was not observed during that monitor period. The well is currently online and will be placed on a 90 -day monitor period due to the slow nature of the build-up. During this time, we will test the T & IC PO's and perform a MIT -IA and DDT -IA to confirm the integrity of the well. If the suspected communication is confirmed, we intend to shut in the well and will schedule further diagnostics as needed. Please let me know if you have any questions or disagree with this plan. Attached is a 90 -day TIO plot and wellbore schematic for 31-06. Sincerely, Well Integrity Supervisor, Alpine & CPF3 Wells Data Analytics KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 Cell: 907-331-7514 sara.e.carlisleCa.conocophillips. com • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, December 28, 2016 8:04 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: 3I-06 (PTD 189-038) Update 12-28-16 Attachments: 3I-06 90 day TIO trend 12-28-16.JPG Chris, Kuparuk injector 31-06 (PTD 189-038) is coming to the end of the 60 day monitor period requested in the previous correspondence. The well did not exhibit signs of TxIA communication during the monitor period and CPAI intends to return the well to 'normal'status at this time. If at any time in the future the well exhibits signs of annular communication the proper notifications will be made at that time. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/ Dusty Freeborn Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 Cell Phone (907) 943-0450 WELLS TEAMSCANNED MAY 2 3201Z ConocoPhillips 1 W W ? � U) U 0 If W cc cc < O UI o -too Lu -- -t CV to CY T -t N a LL a O N 0 0 0 0 N WLLJ CD O CO a --r ,-- o in c a) z a) W E t/) O CD O O w 9 T CN o CC -t -: co a T CY r- w 9 CD CO (D T T T O O O O taJ N 0.1 N N F 6-4 i":%1- "-- 1- - -T Q J I CO 9 CO 9 O O O G j CO CO CO Cr, dBap a LJ t J CJ LJ LJ 0 t- tli LU K C t (J LJ h' I I I I I I c r , 0J d) aJ W V C ctsw co Y o 7,- ,L, 10 N f rn V f1 Z L. E • 0 U L N 3 o C E C Q to r CO CO 8 l JL r r C8 O N " O N O 1 t CO M CV N o. CD 1111 P. �, { I L, LJ IQ 0 [] C] l J CJ t J J tN u. ,T,Q CO S 0 (7 L; rJ [1 �, m 0 Cl CJ ut 0 LII LUIS 3A ▪ T 73 Cisd nCLU • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,November 15,2016 TO: Jim Regg - Q P.I.Supervisor I\�li ii1 i3/I( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 31-06 FROM: Brian Bixby KUPARUK RIV UNIT 31-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv�' NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3I-06 API Well Number 50-029-21935-00-00 Inspector Name: Brian Bixby Permit Number: 189-038-0 Inspection Date: 11/13/2016 Insp Num: mitBDB161113152912 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 31-06 Type Inj wiTVD 6064 Tubing 2860 2860 2860 2860 PTD 1890380 Type TesJ-ti SPT psi si 1516 IA 1420 2200 - 2175 - 2175 - ------- - Interval E4YRTST P/F P ✓ OA 70-__ L 80 - 80 80_ Notes: .4 BBLS Diesel to fill IA.Bled back.5 BBLS ✓ SCANNED APR 2 3 Tuesday,November 15,2016 Page 1 of 1 i • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, October 09, 2016 12:42 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: RE: 3I-06 (PTD# 189-038) Proposed injection period Attachments: 3I-06 365 Day TIO plot.JPG Chris- My apologies about the blank email, I seemed to have an issue when I attempted to attach the current message to the previous email. This email is to serve as an update to the status of well 31-06 (PTD# 186-038) due to the last communication of the plan being over two years ago. In Sept of 2014 CPAI proposed a 60 day monitor period due to suspected slow TxIA communication. The well has remained shut in since then due to surface line repair needs. In March of 2016 a substantial differential pressure between the tubing and IA was established and it maintained the differential pressure while the well was off line. The well line upgrade has recently been completed and CPAI intends to carry out the plan to monitor the well 60 days while the well online. If TxIA communication is identified, diagnostics will be conducted to attempt to identify the source of TxIA. If TxIA integrity is proven, the well will be returned to normal injection status. Please let myself or Jan know if you have any questions or disagree with the plan. Attached is a 365 day TIO for reference. Dusty Freeborn /Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907)943-0450 fliWELLS TEAM co ocophi ip 1 ..., • • 5 _ cr zz. ..., ..., _- O cc ai u-I u -- ,„ ..., --r or ,c, CL ' u... t' "5 17:3 1.1.1 31-1 i IIIL -0 8 4, = u., CY CL )-- cri CO .--. CV C=I —I ...I cO ...I CD LLJ , .2, 0-1 O 6 7 7 ..- ... i 6 co 6 4") ..r. In Er, C/I (CI < < LO CO a- n- 4) = .._ ..- 4) - ', Cl) . 7-. ' it' 03 C ,- o ___ 147.1 to tr. py - — E r . r . u 1... E on --... o . c.,) co co ,— „ ns .., ..... L. ..._ Lu = CI C co C •7 - 6 < . . , 4n 1, I J .n . . n) r-1 . .• , • Le) ..-• 0 co .- "e• kr-) in - 1_8 ' 1 i l• 1 . .0_ el ---- 8 uz, .,.• ”' -.2- •••-.'„, 1 5 fa• C ,,„„ [1 C.3 C.3 IV ,I ur, z CZ CO C.3 C-3 I 3 C 0 %I ui ./ CI Cl 1- '''' t in 7.,43S Os301 1 sd vn cm Lu ( i • ConocoPhillips RECEIVED Alaska OCT 0 9 2012 P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 A GGC October 5, 2012 Qr O Commissioner Dan Seamount O� Alaska Oil & Gas Commission d 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 ' . ` sea*,. OL. "9`Y'1i �y Commissioner Dan Seamount: 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 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 in the summer /fall of 2012. The corrosion inhibitor /sealant was pumped in the month of September 2012.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 Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, 1'4/ _ Martin Walters 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 10/05/2012 1D,WSW,1F,2F,2L,2T,2Z,3G,31 & 3M PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 10-113 50029229170000 1981780 2" n/a 8" n/a 5.1 9/27/2012 1D-117 50029228440000 1972370 7' 0.80 25" 7/22/2012 8.7 9/27/2012 WSW -11 50029208820000 1822120 SF n/a 8" n/a 2.9 9/30/2012 1F-11 50029209930000 1831150 19'8" 3.40 12" 7/22/2012 3.4 9/27/2012 2F -19 50029227280000 1962010 75" 1.30 18" 9/19/2012 19 9/27/2012 2L -305 50103202790000 1982400 SF n/a 7" n/a 4.4 9/28/2012 2T -28 50103202250000 1950920 9" n/a 27" n/a 13.6 9/27/2012 2Z -10 50029213780000 1851370 5'9" 0.80 23" 9/19/2012 7.7 9/30/2012 3G -03 50103202450000 1961220 2" n/a 12" n/a 7.5 9/28/2012 c,... 31 -06 50029219350000 1890380 7' 0.80 11" 7/22/2012 6 9/28/2012 3M -13 50029217200000 1870400 7'7" 0.50 12" 7/22/2012 4.7 9/28/2012 Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, January 02, 2012 12:21 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: Monthly Failed MIT report for December 2011 Attachments: CPAI Failed MITIA Monthly Data 12-11.zip Tom, Jim, Guy k S Attached is the monthly failed MIT report for December 2011. 31-06 was deleted. It had a shallow surface casing leak and a patch was set in October. The 10-404 was submitted 10-11-11. 2B-10 was added due to a surface casing leak. Thanks Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc :itiiiMEOFEf3 art: Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr 909 1/3/2012 STATE OF ALASKA • ALASKA AND GAS CONSERVATION COMMISSI. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell Rug Perforations Stimulate Other SC repair p � 9 r � 0*! Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r . 189 - 038 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 50- 029 - 21935 -00 QQ 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025521 31 -06 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7100 feet Plugs (measured) None true vertical 6574 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 6522 true vertical 0 feet (true vertucal) 6065 Casing Length Size MD TVD Burst Collapse CONDUCTOR (Q 81 16 116 116 0 0 SURFACE (QC) 3425 12 3460 3402 0 0 PRODUCTION 7033 7 7066 6544 0 0 SLEEVE 36" patch fabbed from 10" .500 wall X65 pipe 0 0 0 0 0 0 0 0 ` ' 0 Perforation depth: Measured depth: 665 -6673, 6721 -6736, 6743 -6772 RECEIVED ED True Vertical Depth: 6190 -6198, 6240 -6254, 6260 -6285 OCT 13 ?O1' Tubing (size, grade, MD, and TVD) 2.875, J -55, 6594 MD, 6128 TVD !Alaska Oil & Gas Cons. Commission Arti,n "die Packers & SSSV (type, MD, and TVD) PACKER - AVA 'RHS' RETRIEVABLE PACKER @ 6522 MD and 6065 TVD Otis Series 10 TR - OTIS SERIES '10' TR @ 1823 MD and 1823 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): ;''. *,: . ` (^ !� ° 2 I/ 2. 0 f . rea. ssi t_I , Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service f 6' Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r - WINJ Ei WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -245 Contact MJ Loveland / Martin Walters Printed Name Martin Walters Title Well Integrity Project Supervisor Signature 659 -7043 Date 10/10/11 Mg RBDMS OCT 17 2011 /a • " -!/ Form 10 -404 Revised 10/2010 ,/ / , ' Submit Original Only • • • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 10, 2011 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 31 -06, PTD 189 -038, Sundry 311 -245 surface casing repair. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, / (1 Martin Walters ConocoPhillips Well Integrity Projects Supervisor 4 • 1 s r ilk.s emu_. ,, 11(N ‘‘ - It tit , A. ! It , r J k ,: ) �k /, • j O 4 # ... - ' 1‘411 . j 1 9 • \f) ' i r , yi..., : . 3 .., • Ni ©ConocoPhillips Alaska, Inc fi dr i This photo is copyright by J t.1 ConocoPhillips Alaska, Inc. and cannot be released or '`� published without express u +' "'" written consent of ConocoPhillips Alaska i 'oi,„, ..-- C . i ,:° '' . Z - - __ © ConocoPhillips Alaska, Inc This photo is copyright by ConocoPhillips Alaska, Inc. and cannot be released or published without express • written consent of ConocoPhillips ten con .7;f s „ • • • ( SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. _ 0 ' P.O. Box 100360 V j Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3I -06 Sundry Number: 311 -245 Dear Ms. Loveland: 41„,,VoUtiED AUG 1 6 Z0 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 9 Daniel T. Seamount, Jr. Chair DATED this /® day of August, 2011. Encl. STATE OF ALASKA e/9 '1v-/ i. r. ± s k i ALASKA, AND GAS CONSERVATION COMMISS W" -J o i l ` APPLICATION FOR SUNDRY APPROVALS %� 0 � 20 AAC 25.280 :".,;;,.., , ),JiiiifSSi0C1 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Ch ange Approved Program r Suspend r Rug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other: SC repair P . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 189 -038 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21935 -00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No J 31 -06 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0025521 Kuparuk River Field / Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7100 • 6574 , Casing Length Size MD TVD Burst Collapse CONDUCTOR (QC) 81 16 116' 116' SURFACE (QC) 3425 12 3460' 3402' PRODUCTION 7033 7 7066' 6544' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 665 -6673, 6721 -6736, 6743 -6772 6190 -6198, 6240 -6254, 6260 -6285 2.875 J -55 6594 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - AVA 'RHS' RETRIEVABLE PACKER MD= 6522 TVD= 6065 Otis Series 10 TR - OTIS SERIES '10' TR MD= 1823 TVD= 1823 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program T BOP Sketch r Exploratory r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/20/2011 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r • GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the st of my knowledge. Contact: MJ Loveland /Perry Klein Printed Name MJ Lovelan // _ .— Title: Well Integrity Project Supervisor Signature .e / 4" Commission Date /3//r 66dddd Commission Use Only Sundry Number: 31\ -aq_ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test T r Mechanical Integrity Test T Location Clearance r Other: ftL( , . .1.n t 6—s th J< cci-e-J Subsequent Form Required: , b . �U APPROVED BY . gi / 1 )) Appoved by: 41„ COMMISSIONER THE COMMISSION Date / Form 10 -403 Revised 1/2010 `� 1 � AUG 11201 b mit in Duo � RIGI N, D MS � ..-17,S:( • . ConocoPhillips � g �.► Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 q r^ yysO\ \ t, - : ')°44 Kg August 3, 2011 '.r "" Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 31-06, PTD 189 -038 surface casing inspection and possible repair. Please call Martin Walters or me at 659 -7043 if you have any questions. Sincerely, / MJ Lov and ConocoPhillips Well Integrity Projects Supervisor Enclosures ConocoPhillips Alaska, Inc. Kuparuk Well 3I -06 (PTD 189 -038) SUNDRY NOTICE 10 -403 APPROVAL REQUEST August 3, 2011 This application for Sundry approval for Kuparuk well 31-06 is for the proactive inspection and possible repair of the surface casing near surface. Currently part of the surface casing on this well is exposed to the atmosphere and it appears there is corrosion taking place. 3I -06 has shown visual signs of a leak and was reported in November 2010. During follow up diagnostics no leak was discovered nor was any repeated visual indications. However there are indications of significant surface casing corrosion issues therefore ConocoPhillips requests approval to proactively inspect the surface casing and repair it if damage is present. With approval, inspection and possible repair of the production casing will require the following general steps: 1. Safe -out the well as needed with a tubing tail plug. 2. Remove the floor grate, well house, flow lines, and other equipment from around the wellhead. 3. Remove gravel around well head and build —9' working cellar. ' 4. Install nitrogen purge equipment for the conductor (and OA if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove all of then exposed of conductor if needed. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine if patch or repair is needed to return the casing to operational integrity. 7. If a patch is required, QA/QC will verify the repair for a final integrity check. " 8. Install anti - corrosion coating as specified by CPAI Corrosion Engineer. 9. Replace the conductor and fill the void with cement and top off with sealant. 10. Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well production. 12. File 10 -404 with the AOGCC post repair. Well Integrity Project Supervisor 8/3/2011 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Regg �' J 1, DATE: Tuesday, July 19, 2011 TO: Jim Re P.I. Supervisor) ~ I I SUBJECT: Mechanical Integrity Tests ll CONOCOPHILLIPS ALASKA INC 3I -06 FROM: John Crisp KUPARUK RIV UNIT 3I -06 Petroleum Inspector Src: Inspector Reviewed By• i Supry .1L NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3I -06 API Well Number: 50- 029 - 21935 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr110717144123 Permit Number: 189 -038 -0 Inspection Date: 7/16/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. r Well 3I -06 Type Inj. W + 6064 IA I 220 3193 H I 3075 3049 P.T.D 1890380 'TypeTest SPT L Test psi 1516 ' OA 560 760 760 760 Interval - per P Tubing 2750 I 2750 2750 27 ! ` Notes: 3.2 bbls pumped for test. f ° . 's!N 0 ,, Tuesday, July 19, 2011 Page 1 of 1 • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Sunday, November 14, 2010 5:03 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF3 DS Lead Techs; CPF3 Prod Engrs; Hunter, Lindsey L Subject: 31 -06 (PTD# 189 -038) Report Of Surface Casing Leak Attachments: 31 -06 Wellbore Schematic.pdf; 31 -06 TIO Plot.pdf Jim /Tom /Guy, Kuparuk injector 31 -06 (PTD# 189 -038) was discovered to have a surface casing leak in the course of performing work to apply corrosion inhibiting sealant. The immediate action taken was to bleed the OA until the leak ceased. ConocoPhillips plans to perform diagnostics to determine the location and extent of the leak and will request approval as necessary. The well will also be added to the Monthly Injector Report. Attached are a wellbore schematic and 90 day TIO plot. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 1/3/2012 I Well Name 31 -06 Notes: Report Surface Casing Leak to AOGCC Start Date 8/1/2010 Days 122 End Date 12/1/2010 Annular Communication Surveillance 3000 WHP 80 IAP OAP WHT / ♦ deillA r_--w 70 2500 60 2000 0 50 I 0) • 1500 4 a 30 CL 1000 I '�, I I 20 500 10 111 0 0 0 Aug -10 Sep -10 Oct -10 Nov -10 • il "�DGI T ' • I ' �PWI o , ........swi BL PD IN =Mb' c • ��BL 600 -- 1 . - ' =I 200 .____ 1 1-, =I 200 - I 0 Aug -10 Sep -10 Oct -10 Nov -10 Date . . 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 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk 1 KRU 131 07/31/07 Greenwoodllvesl Bates Chuck Scheve - (Waived) - Fog and rig move (j./ D:JCfJ {.{)- \ Packer Depth Pretest Initial 15 Min. 30 Min. Well 131-02 I Type Ini. I W TVD I 6,228' Tubing 2770 2770 2770 2770 Interval I 4 P.T.D.11853080 I Tvpe test I P Test psil 1557 Casing 925 2020 2010 2010 P/F P Notes: OA 190 210 210 210 Well 131-06 I Tvpe In¡.1 W TVD I 6,064' Tubing 2700 2700 2700 2700 I nterval 4 p.T.D.11890380 I Type test! P Test psil 1516 Casing 790 2060 2000 1990 P/F P Notes: OA 680 840 840 840 Well 131-07 I Type In¡.1 W TVD I 6,119' Tubing 2900 2900 2900 2900 I ntervall 4 P.T.D. I 1860390 I Tvpetest! P Test psi11529.75 Casing 100 2050 2010 2000 P/FI P Notes: OA 400 500 500 500 Well 131-09 I Tvpe In¡.1 N TVD I 6,156' Tubing 2330 2350 2350 2350 Interval 4 P.T.D.!1860550 I Tvpetest! P Test psil 1539 Casing 830 1880 1870 1870 P/FI P Notes: S/I for pressure management OA 200 230 230 230 Wellbl-12 Tvpe Ini.1 W TVD I 5,031' Tubing 2650 2650 2650 2650 Interval I 4 P.T.D. I 1860600 I Tvpetest! P Test psi I 1500 Casing 775 2030 2020 2020 P/F P Notes: OA 210 230 230 230 Wellbl-13 I Tvpe Ini.1 W TVD I 6,059' Tubing 2670 2670 2670 2670 I ntervall 4 P .T.D.!1890250 I Tvpe test I P Test psi I 1514.75 Casing 1160 2080 2030 2025 P/F P Notes: OA 780 890 880 880 Wellbl-14 I Tvpe Ini.1 W TVD I 6,092' Tubing 2570 2560 2560 2560 Interval 4 P.T. D .!1860620 I Type test I P Test psi I 1523 Casing 820 2060 2030 2020 P/FI P Notes: OA 90 150 150 150 We1l131-16 I Tvpe Ini.1 W TVD I 5,940' Tubing 2900 2900 2900 2900 I nterval 4 P.T.D.11890220 I Tvpe test! P Test psil 1500 Casing 700 1920 1860 1920 P/F 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 Survey A=TemperatureAnomalySurvey ~<"f\"'\MED AUG 0 6 2007 D = Differential Temperature Test ""UlUVY¡ I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= other (describe in notes) 2007-0731_MIT _KRU_31-16.xls MEMORANDUM TO: Ket¡ 1 r zoo{ C<4 Jim Regg P.I. Supervisor FROM: Lou Grimaldi Pelroleum Inspeclor \Vell Name: KUPARUK RIV UNIT 31-06 Insp Num: mitLGO..¡071313531"¡ Rellnsp Num: Packer \Vell I 31-06 Type Inj. P I TVD I P.T. ! 1890380 TypeTest I SPT [T-;st psi I Interval ~YRTST P/F P Notes: Good test. no problems \Vednesday. July l<t. 2004 State of Alaska Alaska Oil and Gas Conserv31ion Commission DATE: \\'ednesday. July I"¡. 200"¡ SlIBJECT: !\kchamcallntegTll) Tests CONOCOPHILLlPS ALASK.A INC 31-06 KUPARUK RIV U1'JlT 31-06 Srr: Inspector NON-CONFIDENTIAL API \Vell Number: 50-029-21935-00-00 Permit Number: 189-038-0 Re\'iewed B,.: P.I. Suprv 5b.Z- Comm Inspector Name: Lou Grimaldi Inspection Date: 7/13/~004 Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 1\1 in. 6574 IA 175 1700 1630 1610 15~3 5 OA 0 100 100 100 Tubing ~820 28~0 2820 2820 Page I of I MEMORANDUM TO: Dan Seamount 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, 3t-07, 31-09, 31-12, 31-1'3, .31'14, 31-16 KRUIKuparuk River Field NON- CONFIDENTIAL Packer. Depth . -Pretest Initial 15 Min. 30 Min. We,I .31-02 I Type 'Ini. I S I T:V.D, I '6228'[ TubJn~l I' 2920 ! 2920. J 2920"'l 2920 [~nterva~I 4' ,P.T.D.,I 1853080 ITypete'~tl P-' ITest.psil' 1557 'l'casing.! 1'000-I 1810 1.1810 "1' '1800 I' P/F I E Notes: - ' . ..... - . . , . we,I ?:[fype Ini.I s I.T.V.D; I so~.. I' Tub,ne I 2"00 I ' 2.00 I ="°~"1=,oo I Interva, I 4 · P,T.D.[~ [T~petestl 'P I Test :psi l ..1516 . [ CasingI 980 I. 1840 I 1800''1 17901 P/F I E Notes: 'we,I 3~-07 ITyp,~n~.I 'S! T.V.D. I' s~-~. I~u~i.~l· '~.so '1 =sso I" =ss°',l =.so I~n~o~.~l. ~ 'p.T,D.I 1860390 ITYpeteStl, ,.P. [TestpsiI .1.530,[caSingl 1180 I '172~ i' 1700 I' 1700 I 'P/F..I P Notes: I' w~"l 3~-09 Type~nj.I S'I T.V.D. [ 6156 I.Tubingl 2850 I. 285O '1 2880 I' 285O I~nterval[ 4 P'T'D'I 1860550 ITYpeteStl P .ITestpsil. 1539 I. Casingl 1050 I 18001 1~90'.1 1785 [ P/F I P Notes:' i 'we"l 3~,12 ['P'T'D'I 18606OO IType~ni.I S' 'I'T.V.'D.'I S031. [Tubin;I 2eeo I =~0;0.1 2800. ! 2800 I~.to~.~l 4 Type,test[ P 'l-Testps!l 1258 ICasingl 760. I.-1890 '1' 1880 I 18501 P/F I E .'Notes: · w,,,I' ~,-~ I TYp.,ni.I s ! ~'v'o"! sos~ I~ub,,~l =~s0 I =~s0 I 2~0 1'2~50 I,nt,,rva, I 4 P'T'D'I'18§0250 ITypete;tl'. 'P'. [Test'psil ,1515 I'Casingl 70° '! '183° I 1~9° I '178° I P/FI E Notes: 'w.,,I ~-~ I~,..,.i.I s .-I~.v.o. I so~-I Tubingl 2880 I 2880 [ 2880'I 2880 I'lntervall 4' P.T.D.I 1860620 ITypetestl P ITest.Psil .1523 Icasin;l' .1320.I i640 I 1610 I 1610 I P/F I E Notes: we,I 3~-16 I Type'ni.!. N. I T.V.D:I :5940 I Tubing'l 1280 I ~.28o I ~sol ~2s0 I~"terva~l 4 P.T.D.1 1890220 I-TypetestI P I~rest.psil 14:85 I'casingl 12001 ~860 I !740."1 173O1 P/F J E Notes: Type INJ. Fluid Codes :F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey .Aa Temperature Anomaly Survey D= Differential'Temperature Test Intarwl I= Initial Teat' 4= Four Year Cyole V= Requir~:l by Va~nce W= Teat during Worlewer O= .Other (de~=ribe in n~es) Test's Details Friday, Seot. ], .2.000: I traveled' to Phi]Ups Alaska Inc.'s-K.RU 3I pad to wimess thc 4 year M]T's on wcUs # 02, 06, 07, 09, 12, 13, 14, ]6. Jerry Dethl~fs was the. PIA rep. In' charge of testing. The' standard annulus pressure test was performed with all eight wells passing the 30 minute pressure test. Summary.: I witnessed eight successful MI'I~s on PIA's KRU 3I Pad. .l:T.'s performed: 8_ Number of Failures: Attachments: Well schematics 0 Total Time during tests: 3,,hm MIT report form 5/12/00 L.G. MIT KRU 31 9-1-00 JJ.xls 9/5/00 ON OR BEFORE OCTOBER 24 E W eL ~,- STATE OFALASKA n m lC IN A L ALASKA OIL AND GAS CONSERVATION COMMISSION %j mt REPORT OF SUNDRY WELL OPERATIONS __ Stimulate Plugging Perforate .. Operation Shutdown 2. "Name' of' 'OPerator ARCO Alaska. IRC. 3. Address P. O. Box 100360, Anchorage, AK 99510 ~4, LOcatiOn'of well at surfa(~e ' 262' FSL, 85' FWL, Sec. 31, T13N, R9E, UM At top of productive interval 1239' FSL, 1699' FWL, Sec. 31, T13N, R9E, UM At effective depth 1314' FSL, 1833' FWL, Sec. 31, T13N, R9E, UM At total depth 1339' FSL~ 1882' FWL~ Sec. 31 T13N R9E~ UM i21' plresen{'well Condition summary' ~ ~1 Total Depth: measured 71 0 0' feet true vertical 6574' feet Pull ...tubing Alter casing . Repair well ..... 5. Type of Well: ' " ..mm Development Exploratory Stratigraphic Service Pull tubing Other X 6. Datum elevati0n (DF or KB) .... 76' RKB feet 7. Unit or Property name Kuparu, k River Unit 8. Well number g. Permit number/approval number 9-896 ......... : 10, APl number so-029-21935 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 6 984' feet true vertical 6472' feet Junk (measured) None Casing Length Size Structural Conductor 8 0' I 6" Surface 3 52 5' 9 - 5 / 8" Intermediate Production 7033' 7" Liner Perforation depth: measured 6665'-6673', true vertical 6191'-6198', Tubing (size, grade, and measured depth) Cemented 254 Sx CS II 563 Sx AS III & 342 Sx Class "G" 250 Sx Class "G" & 175 Sx AS I 6721'-6736', 6743'-6772' 6240'-6254', 6260'-6285' Measured depth 115' 3460' 7066' True vertical depth 115' 3402' 6544' RECEIVED 2 7/8", 6.5# J-55 AB mod. tubing with tail set @ 6594' MD Packers and SSSV (type and measured depth) Otis 10 TR SSSV ~ 1823' MD~ AVA RHS pkr .~ 6522' MD~ 13. Stimula{ion or cement squeeze summary ....... convert well from oil producer to water injector Intl~.rv;~lS. treated (~neaSur~d) .... Treatment description including volumes used and final pressure i4. Reoresentative Daily 'Average Production or Inlectlon Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Pressure MAY 1 5 1990 · Tubing Prior to well operation 8 71 1 2 0 7 0 1 4 8 0 Subsequent to operation 0 0 45 0 0 I 0 2 0 15~ Attac~h~ne.n{;s...... 116. I statu'~' of well' classification as:' Copies of Logs and Surveys run __ I Daily Report of Well Operations __ ! Oil ....... Gas Suspended i7,'1 hereby c~rtify 'that'the'fore~°ing il true andcorrect .......... to the best of my knowledge.' ' ' SignedI I · I I ' ........ Title SeniorOperations Engineer Form 10-404 Rev 06/15/88 156 2300 Service X i i SUBMIT IN' DUPLICATE ALASKA OLL AND GAS ~ERVATiON COPIHISS,QN #ECHANICAL INTEGRITY TEST Company .~ Field PNEI'EST START TS ~lN $0 HIM ~ *1 TYPE OF ~KR · ~1~ ~ ~Q I6 TIHE TIHE T&HE NELL ~ - AN~ IVD 5 tZEt~/~E SI ZE l~l ~G ~ ~ T~ S1~/ T iHE I ~E~S ~E ~ ~ FLU ID PR~ ,o¢o ~ . ~~ ~ ?.~ i~~ z'~ ~ .- ............... .... i i ...... , , , . , -- ~ J I i i i " ~ - ~ .... ~ W ' ~ i ii ..... i i, i I . . ,. ........................ . _ *I*USII: IILIECTI, tl FLUID: i i i i i i p m ~ I~TF.,R INJ S - S~J,.T ITll IIU N - HISCIBLE IIUECIICI I - IILIECTING rev ~ IIIIISS SI(IMIIE ~ ~ ~.252(d) 4115189 4122/89 7116189 ADDENDUM ,© Arctic Pak vel1 v/175 sx AS I & 60 bbls Arctic Pak. RU Schl, RIH v/6.125" GR/JB to ~L PBTD @ 6982'. Rn CET f/6979'-5290'i fair cmt w/o sqz ,required. Rn gyro f/6945'-surf. Frac Kuparuk "A" sand perfs 6743'-6772' in ten stages per procedure dated 5/26/89 as follovs: Stage 1: Pmp 42 bbls, 145' diesel v/51 Husol @ 3 BPM, r2922 psi Stage 2a: Pmp 69 bbls YFOO III pre-pad @ 19-20 BPM, 6800-7200 psi Stage 2b: Pmp 100 bbls gelled diesel pre-pad @ 20 BPH, 7100-4520 psi Stage 3: 800 bbls gelled diesel @ 20 BPH, 5250-4330 psi Stage 4: 37 bbls gelled diesel v/2 pp$, 20/40 Carbolite @ 20 BPH, 5250-4330 psi Stage 5: 34 bbls gelled diesel v/4 ppg,' 20/40 Carbolite @ 20 BPM, 4265-4330 psi Stage 6: 79 bbls gelled diesel v/6 ppg, 20/40 Carbolite @ 20 BPM, 4330-5425 psi Stage 7: 163 bbls gelled dlesel v/8 ppg, 20/40 Carbolite @ 18 BPM, 5425-5550 psi Stage 8: 28 bbls gelled diesel v/10 ppg, 20/40 Carbolite @ 18 BPM, 5550-5630 psi Stage 9: 13 bbls gelled diesel w/12 ppg, 20/40 Carbolite @ 18 BPM, 5630-5710 psi Stage 10:41 bbls gelled diesel flush @ 18-17 BPM, 5710-6930 psi Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 1406 bbls ~iesel 99,329# 20/40 Carboli~e underflushed 3 bbl 978~ 4900 psi Drillin~u'pervis°rO RECeiVeD Oil & Gas Cons. Commission Anchom~ _~__~ _ KA OIL AND GAS CONSERVATION ISSION WELL COMPLETION. OR RECOMPLETION RE:PORT AND LOG OIL r~ GAS r'~ SUSPENDED r'~ ABANDONED D SERVICE r'~ 2 Name of OPerator 7 Permit Number ARCO Alaska~ Inc .' 89-38 ,,, 3 Address 8 APl Number P.O. Box 100360, Anchoragep AK 99510-0360 . , 50-029-21935 ,. 4 Location of well a~~[. ~ . g Unit or Lea~e Name 262' ESL, 85~F,E'L~SEC 31 T13N, RgE ua i~CO~PLETi0~~' LOCATIONS i KUPARUK RIVER UNIT ' ' ._~.A_T~_ _i.~ VEEiI:tED 10 Well Number At Top Producing In--al 1239' FSL, 1669' FWL, SE~, 31, T13N, RgE UMI~'~ 31-6 At Total Depth ~ ~"E~-~{~ t i ~' 1~ Field and Pool 1339' FSL~ 1882' FWL~ SEC 31~ T13N~ RgE UM . KUPARUK RIVER FIELD ,, , 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease DeSignatiOn and Serial No. KUPARUK RIVER OIL POOL RKB 76'I AD.L: 25521 ":12 Date SpUdded 13 Date T.D.-Reached 14 Date Comp., Susp.' or Aband. 115 Water Depb~, if offshore 116 No. of Completions APRIL 12 1989 APRIL 17 1989 . "~IA~'~P-'t~'~ · I NA feet ESLI 1 "'~ 7 Total Deplh (MD+TVD) ' ' 18 Plug Back Depth (MD+TVD) 19 Directional SurVey 2~ Depth"where SSSV ~et' 21 Thickness of permafrost 7100' MD & 6574' TVD 6984' MD & 6472' TVD YES ~ NO ['"] 1823' feet MD 1650' (approximate) ~2 Type Electric or Other Logs Run ' ' DIL~S.F.L, GR,CAL,SP,F .DC,CNL, CBL,GYRO 23 CASING, LINER AND cEMENTING RECORD ' ' ' SETTING DEPTH MD . CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AM,O,UNT PULLED 16" 62.5# H,40 SURF 115' 24" 254 SX CS II 9 5/8" 36# J-55 SURF . 3460, ., 12';,3/4". i5.63 SX AS,Ill & 342 S,X CLASS G .... 7" 26# J-SS SURF 7066' 8-1/2" 250 sX CLASS G & 175 SX AS I .... , , ,, , , 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"~ J-55 6594' 6522' 6743'-6772' MD, 4-1/2" W/4 SPF 6260' - 6285' TVD ,, ' 26 ACID, FRACTURE, cEMENT SQUEEZE, ETC D~ ~.l=ff~l., ,INTERVAL (MD) ,,, AMOUNT & KIND, OF MATERIAL USED ~ 6743'- 6772' ,, , 99~1329 lbs 20/40 C,ARBOLITE · · · 27 PRODUCTION TEST Date First Production :, IMeth°d of Operation (FIo~ng, gas lift,' etc.) , , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I J' TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF wATER'BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 2~ '" CORE DATA " Brief des~ripti0n of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submitcore chips. RECEIVED , Form 10-407 S ~l~l'~t~l~ d u plic ate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP KUPARUK C 6660' 6186' NA BOTTOM KUPARUK C 6674' 6199' TOP KUPARUK A 6710' 6231' BOTTOM KUPARUK A 6840' 6345' · 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~~--¢_,~ ~ ~--,-.~.~ Title AREA DRILLING ENGINEER Date / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 8UB.$URFACE DIRECTIONAL ~]UIDANCE SURVEY r~ONTINUOUS [-~OOL REEEIVED ~UN 0 7 1989 Alaska Oil & Gas Cons. Commission Anchorage Compa.'~: - ARCO ALASKA~,. I NC. , , - Well Name 31',06 (262' FSL,. 85' FlaIL, SEC 31, T13N, R9E, UM) Field/Location KUPARUK, NORTH ,~;[.OP[~I ~LASKA - Job Reference No. 73317 Logaed 8~. SCHWARTZ Date, 22-APR-89 COmputed By: KOHRING i GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. 31-06 KUPARUK NORTH SLOPEr ALASKA SURVEY DATE: II-APR-89 ENGINEER: SCHMARTZ METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR ' -~ii: VERTICAL SECIION: HORIZ. DLSTo PROJECTED ONTO.'A~TA~GET AZIMUTH OF NORTH 62 D~G 4½ MIN EAST ARCO ALASKA INC. KUPARUK NORTH SLOPE, ALASKA COMPU'TAT[ON DATE: 5-MAY-89 PAGE TRUE SUB-SEA COURSE qEA$URED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH :N DEG H~N FEET DEG/IO0 FEET FEET FEET DEG DATE OF SURVEY: ZZ-APR-89 KELLY BUSHING ELEVATION: 76.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH OoUO 0.00 -76.00 N 0 0 E 100.00 1UU.UO 24.00 N 34 51E ZO0.OU ZOO.O0 124.00 N 28 34 W 500000 300.00 ZZ*.O0 ;'''~ N Z3 43 W 400°00 '400o00 524°00 ~,i0~ N 29 0 N 500o00 500.00 4Z4.00/*?".0 , ~& N 47 53 N 600.00 600.00 524.00 O, N 60 39 N lOO.O0 700.00 624.00 0 ~ N 42 25 ~ 800.00 800.00 724o00 0 13 N 5 33 N 900o00 900°00 824.00 0 19 N 13 50 E 0 34 N 50 58 E 0 55 N 82 47 E O 47 N 89 19 E 0 31 N 81 48 E 0 7 S 62 30 E 0 10 S 26 53 E 0 5 N 89 21E 0 12 S 17 23 E 0 21 S 77 36 E 0 23 N 85 4 E S 88 3~ E S 64 4 E S 67 23 E S 5142 E S 88 19 E N 56 52 E N 61 43 E N 65 5 E N 60 45 E N 60 58 E 0.00 0.00 0.00 N 0.00 E 0.02 O.Z5 O.OZ S 0.03 E 0..04 0.00 0.17 N 0.0~ bi 0.05 0.10 0.53 N 0.22 W 0.06 0.2Z 0.8'? N 0.38 ~ O.OZ 0.00 1.03 N 0.51 W -0.08 0.00 1.12 N 0.66 ~ -0.16 0.01 1.28 N 0.85 W -0.13 0.15 1.59 N 0.96 bi 0.13 0.11 2.06 N 0.91 bi 1000.00 999.99 923.99 llO0oO0 1099.98 1023.98 1200.00 1199.9t' 1123.97 1300.00 1Z99.97 1223.97 1400.00 1399.96 1323.96 1500o00 1499.96 1423.96 1600.00 1599.96 1523.96 1100.00 1699.96 1623.96 11100000 1799.96 11'23.96 1900.00 1899.96 1823.96 ZO00oO0 1999.96 1923.96 0 28 2100.00 Z099o9~ 2023.95 0 24 ZZO0oO0 2199.9~ 2123.95 0 15 2300000 Z299.95 2223.95 0 10 2400000 2399o95 Z323.95 0 23 Z~O0oO0 2499.92 2423.92 3 9 Z6UOoUO 2599.44 2523.~4 7 26 2700o00 Z~98.25 Z6ZZ.Z5 10 22 ZSO0oO0 2796.18 2720.18 13 14 2900000 '2892o48 2816.48 17 28 5000.UU Z~UT.17 2911017 ZO 9 3100.00 3080.24 3004.24 22 32 3Z00000 3171.6~ 3095.68 25 14 3300.00 3261022 3185.22 27 23 3400.00 3349.41 3273041 28 42 3500000 3436.80 3360.80 29 23 3600000 3523.83 3447.83 29 32 3700000 3610.82 3534082 29 37 3800000 369T.81 3621.81 29 26 390000~ 3784.92 3708092 29 21 0.69 0,78 2.63 N 0.57 W 2.01 0.53 3.11 N 0.66 E 3.45 0.56 3220 N 2.23 E 4.50 0.35 3.26 N 3.38 E 5.07 0.48 3.39 N 3.96 E 5.05 0.17 3.18 N 4,04 E 5.20 0.16 3.07 N 4.Z7 E 5.21 0.00 2.91 N 4.36 E 5.39 0.22 2.62 N 4.71 E 5.98 0.03 2.63 N 5.37 E 6.66 0.16 2.57 N 6.17 E 7.28 0.81 2.55 N 6.88 E 7.66 0.30 2.13.N 7.52 E 7.88 0.10 2.'06 N 7.80 E 8.18 0.49 1.85 N 8.25 E 10.29 5.87 2.71 N 10.15 E 19.78 2.20 7.61 N 18.33 E 35005 3.37 14.21 N 32.11 E 55022 4.79 23.71 N 49.90 E 82.09 3.00 36066 N 73.45 E N 59 39 e 114.17 3.68 N 57 30 E 150.60 2.57 N 58 43 E 190.93 2.88 N 58 53 E 235.33 1.74 N 59 51 E 282o39 0.98 N 59 58 E 330.93 0048 N 59 48 E 380.12 0.36 N 59 33 E 429.38 N 59 30 E 478.63 N 59 11 E 527.65 0.00: N 0 0 E 0.04 S 60 15 E 0.17 N 12 5 bi 0.58 N 22 41 N 0.94 N 23 32 'bi 1.15 N 26 27 W 1.31 N 30 34 1.54 N 33 21 bi 1.86 N 31 14 ~1 Z.Z5 N 23 49. bi Z.69 N 12 17 N 3.18 N 11 58 E 3.90 N 34 52 E 4.70 N 46 4 E 5.21 N 49 '26 E 5.15 N 51 47 E 5.26 N 54 15 E 5.24 N 56 15 E 5.39 N 60 56 E 5.98 N 63 53 E 6.68 N 67 ZZ E 7.34 N 69 40 E 7.82 N 74 10 E 8.07 N T5 12 E 8.46 N 77 22 E 10.52 N 74 43 E 19.85 N 61 26 35.11 N 66 7 55.25 N 64 35 E 82°09 N 63 28 E 52.45 N 101.41 E 114.17 N 6Z 39 E 71.69 N 132.48 E 150.63 N 61 34 E 93.08 N 166.82 E 191.04 N 60 50 E 116.10 N 204.91 E 235.52 N 60 27 E 140.19 N 245.43 E 282o65 N 60 15 E 164.49 N 287.53 E 331.25 N 60 13 E 189.19 N 330.13 E 380.49 N 60 11 E 0.42' ' 214.12 N 372.70 E 429.82 N 60 7 E 0.03 239.14 N 415.21 E 479.15 N 60 3 E ,:0e44 264.13 N 457.47 E 528.25 N 59 59 E . ,:-~, . .,,,, ARCO ALASKA 1NC. 3Z-06 &UPARUK NORTH SLOPE, ALASKA TRUE SUB-SEA ~. COURSE EASURbD VERTICAL VERTICAL DEPTH DEPTH DEPTH CONPUTATION DATE: 5-MAY-89 DATE OF SURVEY: ZZ-APR-89 KELLY BUSHING ELEVATXON: 76.00 FT ENGxNeER: SCHNARTL INTERPOLATED VALUES FOR EVLN 100 FEET OF MEASURED DEPTH V~RTZCAL DOGLEG RECTANGULAR COORDZNATES.HOR~Z. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/dEST DIST. AZIMUTH FEET DEG/ZO0 FEET FEET FEET OEG RZN AZIMUTH DEG MIN 58 41 E N. 59 10 E N 58 50 E N 58 8 E · OOOoOU 3872.'13 3796.13 4100o00 3959032 3883,32 4Z00o00 4045.62 3969.62 4500000 4131.46 4055.48 4400.00 4Z17.45 4141.45 4bO0.O0 4303.54 4227.54 : 0':.'30 N 57 23 E 4600.00 4309.74 4313.T4 30~:'2~ N 56 44 E 4700.00 44T6.U4 4400.04 ,30,.:~.,:~' N 56 15 E 4800000 4562,53 4486.53 30 '1'" N 57 25 E 576.48 0.74 625.32 1.53 675.73 0.19 726.90 0.35 777,83 0.35 828.52 O.42 878.96 0.33 929.17 0.27 979.08 1.86 289.37 N 499.40 E 577018 N59 54 E 314.89 N 541.19 E 626.13 :,59 48 E 340.86 N 584.52 E 676.65 N 59 45 E 367.23 N 628.49 E 727.91 N 59 42 E 393.91N 672.04 E 778.97 N 59 37 E 421.04' N 715.08 E 829.83 N 59 30 E~ 448.59 N 757.62 E 880.47 N 59 ZZ E 4900000 46½9.19 4573019 29 SO 500oouO 4736.00 4660.00 29 39 5100000 4822.94 4746.94 29 31 5ZO0oOO 4909.74 4833.74 30 11 5300000 49~5.93 4919.93 30 32 ~400.00 506Z.15 5006.15 30 31 bSO0oO0 5168.28 5092.28 30 31 5600000 5254.37 5178.37 30 3'7 5100000 5340.72 5264,72 29 54 5800000 5427.71 5351.71 29 17 5900000 5515.05 5439005 29 0 6000.00 b602.60 5526.60 28 46 6100.00 5690.41 5614.41 28 21 6ZOOoOU 5778.62 5702.62 Z7 59 6300000 5867.06 5791.06 27 34 6400000 5955.88 5879.B8 27 11 6500.00 6044086 5968.86 ZT 18 6600000 613~.47 6057047 27 55 6700.00 6221o78 6145.78 27 58 6UU0oOO ~30908B 6Z33.88 Z8 34 6900000 6397.76 6321.76 28 26 ~000.00 6485.74 6409074 28 23 7100.00 6573072 6497.72 28 23 N 60 23 E 1028.87 N 60 18 E 1078.47 N 60 10 E 1127.85 N 61 28 E 1177046 N 61 25 E 1228.17 N 60 55 E 1278.81 N 60 12 E 1329057 N 59 11 E 1380.39 N 57 52 E 1430.67 N 57 I E 1479.78 N 56 6 E 1528020. N 55 ZZ ~ 1576o17 N 55 34 E 1623.60 N 57 25 E 1670.44 N 56 32 E 1716.88 N 56 I E 1762.54 N 56 ZO E 1807.86 N 59 30 E 1854.04 N 60 43 E 1900092 N 60 40 E 1948.19 N 61 29 E 1995.90 N 62 13 E Z043041 N 62 13 E 2090.96 0.27 0.32 0.47 1.00 0.90 0'.57 0.37 0.68 1.15 0.52 0.41 0.62 1.18 0.26 0.72 0.49 1.14 1.44 0.36 0.77 1.05 0.00 0.00 529.71 N 884.47 E 1030.96 N 59 4 E 554.22 N 927.64 E 1080.59 N 59 8 E 578.78 N 970.53 E 1130.00 N 59 11 E' 602.97 N 1013.88 E 1179063 N 59 15 E 627.12 N 1058.47 E 1230.30 N 59 21 E 651.55 N 1102.85 E 1280094 N 59 25 E 676.52 N 1147.09 E 1.331.73 N 59 28 E 702.15 N 1191.05 E 1382.61 N 59 28 E 728,50 N 1234.04 E 1433-03 N 59 26 E 755.06 N 1275o60 E 1482.32 N 59 ZZ E 781.89 N 1316.24 E 1530.96 N 59 17 E 809.09 N 1356.19 E,1579.Z0 N 59 10 E 836.35 N 1395.50 E 1626.93 N 59 3 E 862.23 N 1434.85 E 1673099 N 58 59 E 887.65 N 1474o00 E 1720.64 N 58 56 E 913.15 N 1512.22 E 1766.54 N 58 52 E 938.68 N 1550.05 E 1812.12 N 58 48 E 963.27 N 1589o33 E 1858.45 N 58 46 E 986.49 N 1630.10 E 1905.35 N 58 49 E 1009067 N 1671.33 E 1952.63 N 58 51 E 1032.86 N 1713.05 E 2000.34 N 58 54 E 1055.12 N 1755.03 E Z047.79 N 58 59 E 1077.28 N 1797.10 E Z095.26 N 59 3 E IRCO ALASKA iNC. ~I-06 ,UPARUK IURTH SLUP~p ALASKA COMPUTATION DATE: 5-MAY-89 PAGE 3 DATE OF SURVEY: ZZ-APR-89 KELLY BUSHING ELEVATION: 76°00 PT ' INTERPOLATED VALUES FOR EVEN 1000 PEET OF MEASURED OEPTH ENGINEER: SCHWARTZ TRUE SUB-SEA COURSE iASUReD VERTICAL VERTICAL DEVIATION AZI~qUTH DEPTH OeP TH DEPTH D~,/~?~ DEG MtN O.OO O.OO -76.00 ~~. .OOOoO0 999.99 923.99 ~~~?. :000.00 1999.96 1923.96 ~000000 3872.13 3796.13 iO00.O0 ~736.00 ~660.00 ~O00.O0 ~602.60 5526.60 28 ~6 ~ N 55 22 E. 1576.17. ~OOO.OO 6485.74 6409.74 28 23 N 62 13 E 2043.41 rlO0.O0 6573.72 6&97.72 28 23 "N 62 13 5 2090.96 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN N 0 0 E 0.00 N 50 58 E 0,69 S 88 3~ E 6.66 N 59 39 E 114.17 N 58 41 E 576o~8 N 60 18 E 1078.47 0.00 0.78 0.16 3.68 0.74 0.32 0 o6Z 0.00 0.00 0.00 N 0.00 5 0.00 N 0 0 E 2.63 N 0.5'? N Z.69 N 12 17 N 2.57 N 6.17 E 6.68 N 67 22 E 52.45 N 101.41 E 114.17 N 62 39 E 289.37 N 499.40 E 577o18 N 59 54 E 554.22 N 927°64 E 1080.59 N 59 8 E 809.09 N 1356.19 E 1579.Z0 N 59 10 E 1055.12 N 1755.03 E 2047°79 N 58 59 E 1077.28 N 1797o10 E 2095o26 N 59 3 E AKCO ALASKA ZNCo 3Z-06 KUPARUK NORTH SLOPE, ALASRA COMPUTATION DATE: S-HAY-89 PAGE 4 DATE OF SURVEY: 22-APR-89 KELLY BUSHXNG ELEVATXON: 76.00 PT · ENGINEER: SCHgARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF sUB-SEA DEPTH TRUE SUB-SEA EASUREU VERTICAL VERTICAL DEPTH DEPTH DEPTH O.OO 0.00 -76.00 76.00 ?6.00 0000 116000 176.00 100'00 276o00 276.00 200*00 376.00 376.00 300,00 476.00 4*76°00 400.00 576.00 576.00 500.00 676000 676.00 600.00 176.00 7%6.00 700.00 '~ I' 8%6.00 876.00 800.00 0 17 0 25 0 49 0 52 0 35 0 15 0 9 0 8 0 8 0 19 0 23 976,,01 976.00 900.00 1076001 1076.00 1000.00 1176.03 1176.00 1100.00 1216003 iZT6.OO 1200.00 1,:iT6.04 1376.00 1300.00 14,76o04 1476.00 1400.00 1516004 1576.00 1500.00 16'/6o04 1676.00 1600.00 1776.04 1776000 1700.00 1876004 1816.00 1800.00 0 29 0 21 0 21 0 7 0 ZO I 49 6 40 9 41 1976.04. 1976.00 1900.00 Z016o05 2076.00 ZO00.O0 2176.05 2176.00 2100.00 ZZ76.US 2276.00 ZZO0.O0 2316.0:5 2376°00 2300.00 24*76°06 2476.00 2400000 2576038 2576.00 2500.00 2617040 2676.00 2600.00 2719.30 2?76.00 2700.00 12 19 2882.73 2876.00 2800.00 16 58 Z988o14* 2916.U0 2900.00 19 46 3095040 3076.00 3000000 22 25 3204018 3176.00 3100.00 25 21 3316066 3216000 3Z00.00 27 41 3430°36 3376.00 3300.00 28 56 3545°02 34*76.00 3400.00 29 31 3659.96 3576.00 3500000 29 33 ~174o 9:5 3676000 3600.00 29 29 3889.16 3116.00 3700000 29 ZZ 4004044 3876.00 3800.00 29 12 COURSE AZXHUTH DEG MXN VERTICAL DOGLEG RECTANGULAR COORDINATES HORXZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/biEST DIST. A~IMUTH FEET OEG/IO0 FEET FEET FEET DEG MXN N 0 0 E 0.00 0.00 0.00 N 0.'00 E N 84 I E 0.00 0.00 0.03 S 0.01 E N 27 1'3 bi 0.05 0.02 0.10 N 0.00 bi N 25 44 bi 0.04 0.00 0.44 N 0.18 bi N. 25 33 bi 0.06 0.00 0.79 N 0.34 bi N 44 54 bi 0003 0.00 1.00 N 0.48 bi N 67 51 bi -0.05 0.00 1.10 N 0.62 W N 44 19 bi -0.14 0.00 1.24 N 0.80 bi N 14 32 bi -0.16 '0.00 1.50 N 0.95 bi N 1'0 59 E 0.05 0.00 1.93 N 0.94 bi N 38 gE N 75 6 E N 88 Z E N 85 8 E N 79 28 E S 13 48 E N 89 34 E 517 2 E 566 0 E N 84 11 E 5 82 57'E S 83 22 E 5 58 2O E S 62 56 E 573 5 E N 59 39 E N 60 37 E N 66 9 E N 61 4 E N 59 58 E N 57 Z8 E N 58 45 E N 58 54 E N 60 Z E N 59 53 E N 59 36 E N 59 29 E N 59 15 E N 58 39 E 0.00'~ 0 E 0.0 2 E 0.1 044 ~ 0.50 0.64 2'.48 N 0.72 bi 1.66 0.46 3.04 N 0.30 E 3.13 0.12 3.19 N 1.87 E 4.28 0.26 3.23 N 3.15 E 5.01 0.64 3.39 N 3.89 E 5.06 0.14 3.24 N 4.0Z E 5.16 0.06 3.07 N 4.ZZ E 5.22 0.13 2.98 N 4.34 E 5.29 0.32 2.66 N 4.58 E 5-83 0.08 2.62 N 5.21' E 6.48 0.14 2.58 N 5.96 E 7.17 0.37 2.59 N 6.73 E 7.59 0.78 2.19 N 7.41 E 7085 0.28 2.09 N 7.75 E 8.06 0.33 1.87 N 8.11 E 9.24 4.92 2.21 N 9.25 E 16.88 4.07 6.22 N 15.79 E 31.11 3.13 12.59 N 28.51 E 50.64 4.03 21.47 N 45.90 E 76.93 3.82 34.16 N 68.94 E 110.18 3040 148.84 2.36 192096 2.91 243.00 2.06 297.02 0082 353.05 0.20 409.64 9020 466.33 5Z2.64 578.64 0.47' N ~2 18 ti 0.86 N 23 14 ti 1.11 N 2Z5 40 1.27 N 9 25 W 1.47 N 1.77 N 32 ZO ti 2.14 N 25 51 ti Z.58 N 16 10 W 3.06 N 5 36 E 3.70 N 30 27 E 4.51 N 44 16 E 5.16 N 48 54 E 5.17 N 51 5 E 5.22 N 53 58 E 5.26 N 55 29 E 5.29 N 59 49 E 5083 N 63 19 E 6050 N 66 34 E %.Z1 N 68 56 E 7.73 N 73 31 E 8.03 N 74. 53 E 8.32 N 16 59 E 9.51 N 76 35 E 16.97 N 68 30 E 31.17 N 66 10 E 50.67 N 64 56 E 76.93 N 63 38 E 50046 N 97095 E 110.18 N 62 44 E 70.75 N 130.98 E 148.87 N 61 37 E 94.14 N 168.56 E 193.06 N 60 48 E 120.07 N 211'.49 E 243.19 N 60 24 E 147.52 N 258012 E 297.30 N 60 15 E 175058 N 306.69 E 353.39 N 60 12 E 204011 N 355.64 E 410005 N 60 8 E . 232089 N 404.59 E 466.83 N 60 4 E 261.55 N 453016 E 523.Z3 N 60 0 E 290.49 N 501.Z5 E 579.34 N :59 54 E RCO ALASKA INC. 1-06 UPARUK ORTH SLUPEt ALASKA COMPUTATION DATE: 5-MAY-89 PAGE DATE OF SURVEY: ZZ-APR-89 KELLY BUSHING ELEVATION: 76.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUg-SEA DEPTH TRUE SUB-SEA ASURbD V~RTICAL VERTICAL DEV UEPTH OePTH DEPTH COURSE :ON AZIMUTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET PEET FEET DEG .119.20 39?6.00 3900.00 N 58 54 E 634.81 .Z35o40 ,076.00 4000.00 N 59 7 E 693.86 ,551oU1 ~176o00 4100.00 N 58 29 E 753.32 ~468o0Z ~Z/6.00 4ZO0.O0 '?:'N 57 38 E 81Z.34 ~584o06 ,376.00 4300.00 31 N 56 50 E 870.93 ~015.56 &5'16.00 4500.00 ~29 $~: N 58 4 E 986.83 ~950.90 ,676.00 4600.00 29 &~ i N 60 Z8 E 1044.23 i046.0Z ,776.00 4700.00 29 38 N 60 10 E 1101.21 i161.04 &876.00 4800.00 29 A7 N 60 59 E 1158.00 N 61 33 E 1216.41 N 60 58 E 1275.19 N 60 8 E 1334.12 N 58 49 E 1393.12 N 57 27 E 1450.75 N 56 29 E 1506.64 N 55 38 E 1561.66 N 55 17 E 1615.87 N 57 24 E 1669.05 N 56 Z8 E 17Z1.52 )Z76o86 ~976.00 4900.00 30 36 )392oU1 50?6.00 5000.00 30 29 ~508o96 5176.00 5100.00 30 32 i625.11 5Z?6.00 5ZO0.O0 30 28 ~?40.63 5376.00 5300.00 29 33 ~855o3Z 5476.00 5400.00 29 6 ~969°64 5576.00 5500.00 28 51 5083.6Z 5676.00 5600.00 28 27 5197o05 5776.00 5700.00 Z7 59 5310.08 5876.00 5800.00 27 30 N 55 52 E 1772.78 N 57 2Z E 1823.92 N 60 31 E 1876.60 N 60 36 E 1929.85 N 61 5 E 1984.1Z N 62 13 E Z090.96 54ZZo61 59~6.00 5900.00 27 6 6535°08 6076.00 6000.00 Z? 29 b6,8.16 6176.00 6100.00 28 0 6761.46 6Z76.00 6ZO0.O0 28 17 6875oZ6 ~b376.00 6300.00 Z8 28 1100°00 ~657~.7Z 6497.7Z Z8 Z3 Z.O2 0.08 0.49 0.60 0.34 0.27 2.29 0.23 0.19 1.42 · 1.00 0.54 0.34 1.11 0.78 0.69 0.35 0.85 0.30 0.79 319.8Z N 549.32 ~ 635.64 N 59 47 E 350.18 N 600.11 E 694.81 N 59 44 E 381.00 N 651.12 E 754.40 :N 5;9 39 E 412.31 N 701.37 E 813.59 N 59 33 E 444.17 N 750.87 E 87Z.41 N 59 Z3 E 476.48 N 799.71 E 930.90 N 59 12 E 508.30 N 848.21 E 988.85 N 59 4 E 537.29 N 897.84 E 1046..3Z N 59 6 E 565.52 N 947.40 E 1103.35 N 59 9 E 593.60 N 996.81 E 1160.17 N 59 13 E 6Z1.51 N 1048.14 E 1218.55 N 59 ZO E 64,9.80 N 1099.69 E 1ZTT.3Z N 59 25 E 678.79 N 1151.04 E 1336.Z8 N 59 28 E 708.73 N 1201.98 E 1395.37 N 59 28 E 739.28 N 1251.07 E 1453.18 N 59 25 E 769.86 N 1Z98.18 E 150~.Z9 N 59 19 E 800.80 N 1344.13 E 1564.60 N 59 12 E 831.95 N 1389.07 E 1619.16 N 59 4 E 861.48 N 1433.68 E 1672.60 N 58 59 E 890.22 N 1477.89 E 1725.30 N 58 56 E 0.44 918.9Z N 1520.77 E 1776.84 N 58 51 E 1.82 947.50 N 1563.57 E 1828.25 N 58 ~7 E 0.52 974.57 N 1608.89 E 1881.04 N 58 47 E 0.81 1000.67 N 1655.33 E 1934.Z9 N 58 50 E 0-66 1027.19 N 1702.7Z E 1988.56 N 58 53 E 0.00 vl~O77.Z8 N~797.10 E zogs.z6 N 59 3 E ~,RCO ALASKA .[NC. $1-06 LUPARUK ~IORTH SLOPE~ ALASKA MARKt:R TOP KUPARUK C BASt: RUPARUK C TUP KUPARUK A BASE KUPARUK A GCT LAST READ.[NG PBTU COMPUTAT.[ON DATE: 5-1qAY-89 KELLY BUSHI'NG ELEVATION,.* 76.00 ET ENGTNEE:~; SCHblARI'Z INTERPOLATED VALUES FOR CHOSEN HORIZONS ~URFACE LOCATION = PRUDHOE BAY~ $EC31~ T13N~ RgE .MEASURED I..1EPTH 6840.00 6945.60 6984°00 7100.00 TVD FROH KB SUB-SEA RECTANGULAR COORD.[NATES NORTH/SOUIH EAST/blEST 6186°46 6110.46 977.30 N 6198.82 6122.82 980.52 N 6Z30.61 6154.61 988.79 N 6345.02 6269.0Z 1019o0Z N 6437.89 6361.89 1 043.0.7 N 6471.67 6395°67 1051.58 N 6573. ?Z 6697.72 1077. Z8 N 1613.T3 E 1619.4~6 E 163,~0 19 E 1688.01 E 1T3Z. 15 E 174.8.30 E 1797o10 E ILRCO ALASKA INC. 3:[-06 &UPARUK MURTH SLOPE! ALASKA TOP KUPARUK C BASI: KUPARUK TOP KUPARUK A BASE KUPARUK A PBTD ID COMPUTATION DATE: 5-MAY-89 PAGE DATE OF SURVEY: II-APR-89 KELLY BUSHING ELEVATION: 76.00 FT ENGINEER: SCH~ARIZ' *~~*~~ STRATIGRAPHIC SUMMARY 0~0~00~ SURFACE LOCATION : PRUDHOE BAY~ SEC311 T13Nt RgE iASUREO DEPTH TVD RECTANGULAR COORDINATES ;.BELON KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 60°00 6186.46 6110.46 977.30 N 1613o73 E 74.00 6198.82 6112.81 980.52 N 1619' 46 E ~-'6710.00 6230.61 6154.61 988.79 N 1634,19 E 6840°00 6345.02 6269.02 1019.02 N 1688.01 E 6984.00 6471.67 6395.67 1051.58 N 1748.30 E 7100.00 6573.71 6497.72 1077.28 N 1797.10 E FINAL WELL LOCATION AT 1RUE SUB-SEA REA~UREO VERTICAL VERTICAL DEPTH DEPTH DEPTH llUU.UU 651'3.71 6497.72 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 2095o16 N 59 3 E SCHLUMBERGER O l REC T l ONAL SURV E Y COMPANY ARCO ALASKA INC. WELL BI-OG F I ELD KUPARUK COUNTRY USA RUN ONE ot::::i~E LOOOEO 22 - APR - 89 REFERENCE ?331'7 WELL' §I-06 (262' FSL, 85' FWL, SEC 31, T13N, R9E, UM) SCALE = 1/SO0 IN/FT 2OOO ISOO 1000 ~ou~H - 1 ~00 -1000 SOO 1000 I~OO 2000 2500 HO~ONTAL PROJECTION W~LL: 34-06 - (262' FSL, 85' FWL, SEC 31, T13N, RgE, UM) - 1000 243. -~00 0 0 5OO 1000 1 ~00 VENAL PROJECTION 2000 2,500 9000 69. pROJECTION ON V£RTICt:II- PLRNE 69. - 249. SCRLE. O IN ¥£R'~ICRL ~P't'HS HORIZ SCALE = I/S00 IN/FT T Yp; of Request: 'Name of Operator STATE OFALASKA 0 1{ 1 A 1. , ALASKA OIL AND GAS CONSERVATION COMMIS~I .ON REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate Plugging Perforate X Pull tubing , Alter casing Repair well 5. Type of Well: Development ARCO Alaska. Inc.. Exploratory .... 3. Address Stratigraphic P. O. Box 100360., Anchorage, AK 99510. , Service '4. Locaiion of well at surface 262' FSL, 85' FWL, Sec. 31, T13N, RDE, UM At top of productive interval 1239' FSL, 1699' FWL, Sec. 31, T13N, RDE, UM At effective depth 1314' FSL, 1833' FWL, Sec. 31, T13N, RDE, UM At total depth 1339' ~SL~ 1882' FWL, , Sec. 31~ T13N, ,RDE~ ua ,, , 12. Present well condition summary Total Depth: Pull tubin9 Other 6. Datum elevation (DF or KB) 76' RKB feet 7, Unit or Property name Kuparuk River Unit , 8, Well number 31-06 9. Permit number/approval number 9-1030 10, APl number so-029-21935 .. 11, Field/Pool Kuparuk River Oil Pool ,, measured 71 00' feet Plugs (measured) None true vertical 6574' feet Effective depth: measured 6 9 8 4' feet Junk (measured) None true vertical 6472' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' I 6" 254 Sx CS II 1.1 5' 1 1 5' Surface 3525' 9-5/8" 563 Sx AS III & 3460' 3402' Intermediate 342 Sx Class "G" Production 7 0 3 3' 7" 250 Sx Class "G" & 7 0 6 6' 6 5 4 4' Liner 175 Sx AS I Perforation depth: measured 6665'-6673', 6721'-6736', 6743'-6772' true vertical 6191 -61 98, 6240 -6254, 6260 -6285 ~,,~,,\ Tubing (size, grade, and measured depth) ~._ 2 7/8", 6.5# J-55 AB mod. tubing with tail set @ 6594' MD~-,~, I Packers and SSSV (type and measured depth) I Otis 10 TR Ss,s,v @ 1,8231,,,MD, i AVA RHS, pkr @ 6522' MD .... 1131 stimulation Or cement squeeze summary ~ initial perforations in C sand; initial perforations in upper A sand I ~ Intervaistreated (measured) '' ..................... 6665'-6673' (C sand), 6721'-6736' (A sand) Treatment description including volumes used and final pressure .. Perforated at 6 spf with 0° phasing 14. Reoresentative ~)ailv' Averaoe Production or Inlection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 0 4 4 1 4 6 5 0 1 4 0 0 · , ,Su,bs,,equent to operat, i0n 1 0 81 1 4 7 0 0 1 3 8 0, 15, Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run __ I . Daily Repo,rt of Well Operations * Oil .~. Gas ..... Suspended __ 171'1 hereby'~.,ertify thai"tl~e f°regoin~"is trl~' and'correct to th~ D~;t of my knowledge. Form 1-0-404 R~06/15/8~ ' ' ' " Operations En~3ineer 171 174 Service SUBMIT IN DUPLICATE ifl~i II~l!l ti~RCO Alaska, In~O ~ WELL SERVICE REPORT Subsidiary of Atlantic Richfield Compa~... C OR . ~ / IO E ONA E~ T TIM~ [-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots OIL AND G/~ C,C)NSERVATION COMM~I'~d~ APPLICATION ,, FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Alter casing _ Change approved program_ SuSpend _ Operation Shutdown _ Re-enter suspended well _ Repair well Plugging _ Time extension _ Stimulate_ Variance_ Perforate ~ Other_ 6. Datum elevation (DF or KB) 2. Name of Operator I Pull tubing _ Type of Well: Development Exploratory Stratigraphic Service i R9E, UM ARCO Alaska. Inc. 3. Address . P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 262' FSL, 85' FEL,Sec. 31, T13N, R9E, UM At top of productive interval 1239' FSL, 1699' FWL, Sec. 31, T13N, R9E, UM At effective depth 1314' FSL, 1833' FWL, Sec.31, T13N, R9E, UM At total depth 13391 FSL, 1882' FWL, Sec. 31r T.13N,. 12. Present well condition summary Total Depth: measured 71 0 0' feet true vertical 6 5 74' feet measured 6 9 8 4' feet true vertical 6 4 7 2' feet Effective depth: RKB 76 feet 7, Unit or Property name Kuparuk River unit 8, Well number 31-06 9, Permit number 89-3l) 10, APl number .;o.029-21 935 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 8 0' 1 6" Surface 3 5 2 5' 9 5/8" Intermediate ProduCtion 7 0 3 3' 7" Liner Perforation depth: measured 6743'-6772' true vertical 6260'-6285' Tubing (size, grade, and measured depth 2 7/8", 6.5#, J-55 set at 6594' ' Packers and SSSV (type and measured depth) Otis 10 TR SSSV ~ !823', ..AVA RHS Pkr ~ 6522' Attachments Description summary of proposal _ Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 254 Sx CS II 1 15' 1 1 5' 563 Sx AS III & 3460' 3402' 342 Sx Class G 250 Sx Class G 7066' 6544' 175 Sx AS I 13. Add perforations to the A Sand in.terva.! . 14. Estimated date for commencing operation November. 1989 16. If proposal was verbally approved Name of approver /~; /~i,/~/¢/, 15. Detailed operation program X Status of well dassification as: Oil x Gas Date approved Service . 17. I hereby certify that the foregoing is true and correct to the_best of my knowledge. (~ ' -" FOR COMMISSION I(~E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test._ Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED . ,,,,,,,~ n Sg!ltt RECEIVED NOV 2 91989 !:~Jas~ Oil & Gas Cons, ~ ~ohora~! BOP sketch_ Suspended _ SUBMIT IN TRIPLICATE Kuparuk Well 31-6 Application for Sundry Approval November 2, 1989 . The estimated BHP is 2300 psig at-6200' ss based on data taken on 10/3/89. . , No workover fluids will be required for perforating. Ther will be a lubricator with a 5000 psig rate~ BOP used during the perforating work. Nask~ 0it & GaS ConS, Commission Through Tubing Perforating Procedure Kuparuk Well 31-6 AFE #AK409S · . . . . MIRU slickline unit and pressure test equipment. Shut in well. RIH and tag fill· POOH. *** NOTE *** If the tag is at a depth of 6760' MD RKB or deeper, no ¢leenout Is necessary. Otherwise, a CTU cleanout should be performed prior to perforating. RDMO Slickline unit. MIRU perforating unit and pressure test equipment. RIH with 2-1/8" through tubing perforating gun and tie in depths with the following logs: DIL/SFL dated (4/17/89) CET dated (4/21/89) Open well at choke for a 300 psig underbalanced condition and retie in depths. Once well is retied in, perforate the following interval at 6 SPF (0° phasing): 6665'- 6673' MD' RKB 6721'- 6736' MD RKB *** NOTE *** (Cl Sand) (A3 Sand) Any of the following charges are acceptable for Well 31-6: Atlas Wireline Halliburton Schlumberger Silverjet (2-1/8") Dynastrip (2-1/8") Enerjet (2-1/8") 16.0 grams 20.5 grams 13.5 grams 8, 9, 10. Shut in well/POOH. RDMO pedorating unit. Return well to production. 1. SO00 PSi 7" WELkHEM:) CONNECTOR: 2. sooo Psi WIRELIN[ RAMS C~ARIABLE: SIZE:) 3. 5000 PSI 4 1/6- I. UORIC~TOR 4. 5(X)O PSI 4 1/6" IrkOW TUBE PACK-Orr 2 NIRE:L I_1~_ 80P EOUI~NT OIL AND GA.S ~RVATION APPLICATION FOR SUNDRY APPROV _ L , 1'. Type of-i~eqUest: Abandon'_ SUspend_ Operation Shutdown_ Re-enter suspended Well_ Alter casing _ Repair well Plugging _ Change approved program .~. Pull tubing .. 2. Name of operatOr 5. Type of Well: Development .~. ARCO Alaska. lnG, Exploratory _ 3. Address Stratigraphic _ P. Or Box 100360,. Anchorage, A.K 99~.1Q .. Service .. _ 4. Location of well at surface 262' FSL, 85' FEL,$ec. 31, T13N, R9E, UM At top of productive interval 1239' FSL, 1699' FWL, Sec. 31, T13N, R9E, UM At effective depth 1314' FSL, 1833' FWL, Sec.31, T13N, R9E, UM At total depth 1339' FS.L, 1882' FWL, Sec. 31, T13N, R9E, UM 12. Present well condition summary Total Depth: measured 71 0 0' feet Plugs (measured) true vertical 6 5 7 4' feet None Effective depth: measured 6 984' feet Junk (measured) true vertical 6 4 7 2' feet None Casing Length Size Cemented Measured depth Structural Conductor 8 0' I 6" 254 Sx CS II 1 1 5' Surface 3525' 9 5/8" 563 Sx AS III & 3460' Intermediate 342 Sx Class G Production 70 3 3' 7" 250 Sx Class G 7 0 6 6' Liner 175 Sx AS I Perforation depth: measured 6743'-6772' true vertical 6260'-6285' Tubing (size, grade, and measured depth 2 7/8", 6.5#, J-55 set at 6594' Packers and SSSV (type and measured depth) Otis 10 TR SSSV @ 1823'r AVA RHS pEr,~ 6522, , 13. Attachments Description summary of proposal _ Detailed operation program X Convert well from Oi! producer to water injector.. 14. Estimated date for commencing operation 115. Status of well classification as: November. 1989 I Oil X Gas 16. If proposal was verbally approved I Name of approver Date approved I Service .... 17. I hereby certify that the foregOing is true and' COrrect to th~best of my kn°wledge. Signed ,/~f,/Z~a ~' x~),~.z~-~~ Title ~V/c-" ~)~~ ~_~.'/~ ~/ ..... FOR C~IS~USE ONLY COnditions of aPproval: Notify CommisSion so representative may witness Plug integrity __ BOP' Test._ Location clearance.._ Mechanical Integrity Test__ Subsequent form require ORIGINAl. SIGNED BY Approved by the order of the Commission LONNIE C SMITH Time extension _ Stimulate_ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) RKB 76 feet 7. Unit or Property name Kuparuk River Unit . 8. Well number 31-06 9. Permit number 10. APl number so-029.21 935 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool True vertical depth 115' 3402' 6544' RECEIVED OCT 0 6 ]989 Alas~ 0il & Gas Cons. Commission Anchorage BOP sketch_ Suspended _ IApproval No.?~..g~ I ~..oroved CoPY SUBMIT IN TRIPLICATE Form 10-403 Rev 5/03189 0 © Well 31-6 Conversion to Water Injection I . . e Wireline BOPE will be used in conversion of the well to water injection. The static bottomhole reservoir pressure is estimated to be 3000 psig based on recent measurements in adjacent wells. No workover fluids will be used. RECEIVED OCT o 61..§tg ;~Jaska Oil & Gas Cons. Commission Anchorage III i I~ · . 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE: 2. 5000 PSI WIRE:LINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/$" LUBRICATOR 4. .5000 PSI 4 1/6" FLOW TUBE PACK-OFF H ] REL ] NE BOP EGU ] PHENT i il~~ · A ~,-~, OIL AND GAS CONSERVATION COMMI~N Pull tubing ~ ARer ca~ng ~ ~e~r ~11 ~ Pull tuoing ~ ~ner ~ C o m a 1 e ~ · , , , r Name of Operator 6. Datum elevation (DF or KB) ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK . 4. Location of well at surface ! 5. Type of Well: I Development ~ I Exploratory .._ ! Stratigraphic 9 9 51 p- o 3 6 oService ! · , RKB 76 ' 7. Unit or Property name Kuparuk Rtver Unit 8. Well number 262' FSL, 85' FWL, Sec.31, T13N, RgE, UN At top of productive interval 1239' FSL, 1699'FWL, Sec.31, T13N, RgE, UN' At effective depth 1314' FSL, 1833'FWL, Sec.31, T13N, RgE, UN At total depth 1339' FSL, 1882'FWL, Sec.31, T13N, RgE, UN 12. Present well condition summary Total depth: measured true vertical Effec~tive depth: measured true vertical 7100' ND feet 6574' TV~eet 6984' MD ~ 6472' 'TV~eet Plugs (measured) 31 -6 9. Permit number/approval number 89-38/9-345 10. APl number 50-- 029-21935 11. Field/pOOl Kuparuk River · None Junk (meaSured) N o n e Casing Length Structural Conductor Surface 8 0' 3525 ' Intermediate Production 7033 ' Liner Perforation depth: measured 674'3'-6772' MD true vertical 6260'-6285, TVD Tubing (size, grade, and measured depth) Size I 6" 9 -5/8" 7" Cemented Measured depth True vertical depth 254 sx CS II llS'ND 5.63 sx AS III & 3460'ND 342 sx Class G 250-sx Class G' & 7066'ND 175 sx AS I 2-7/8", 6.5#, J-55, w/tail ~ 6594' MD Pac~mandSSSVOypeandmeasuredde~h) Otis 10 TR SSSV ~ 1823' MD, AVA RHS pkr ~ 6522' MD 13. ~imul~ionorcementsqueezesummary Alaska 0il & Gas Cons. Commission Anch0ra~., 115'TVD 3402'TVD 6544'TVD I nte~a~s treated (measured) Treatment description including volumes used and final pressure 14. N/A Representative Daily ~,vera 'e production or InjeCtion Data Oil-Bbl Gas-Md Water-Bbl ~ Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation · 15. Attachments ' Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ 17. I hereby certify that theforegoing is true and correct to the best of mY knOWledge. 16. Status of Well ClassificatiOn as:,~ I oi, & Gas_. suspended__ .: Service Form 10-404 Rev 06/15/88 Title Area Drilling Engineer SW01/8 feet Pool Date SUBMIT IN DUPLICATE ARCO Oil and Gas Company Instmcfiooe: Prepare and submit the 'laitlM ReI~' or~ the first Wednesday.after · wall Is spudded or workover ol~ratlona are atlrtod. Doily work prior to sPuddln~u,,hould~ be wammadzed on the fomt giving Ineluelvo d,&taa only. . District ~CO A[J~FJ~ [NC. Field KUPARUK RIVER Auth. or W.O. no. AK4095 _._ IC~unty. parish or bormJgh NORTH SLOPB Leale or unit ~L: 25521 Title ' " CO~ZON8 Operator ~CO Spudded or W.O. begun ACCEPTED Date and depth as o! 8:00 a.m. APl: 50-029-21935 Well Hlttory- Initial Report - Dally 05/17/89 ( TI): 7100 PB: 6979 SUPV:JP 3 I-6 JWell no. JARCO W.I, Complete record for each day reported NOEDZC ]. RXHW/ 2-7/8" COI~LETXOH 7"% 7066' M~:11.5 N&C1 MOVE RIG TO 3I PAD. ACCEPT RIG AT 1300 IIR 5/16/89. MOVE RXG OVER 3X-06. N/D M~STER vALV~ AND N/U 7# BOP. T~ST 8AM~. R/U SOS AND PBRF W/ 4-1/2# GON8 43C OLTRAPACK~DX CIIARGB8 0 4 SPF.& 90 DEGREE PHASING. PEPX F/ 6752-72 AND 6743-52 R/U AND RUN 2-7/8" COMPLETION. OTIS SSSV 0 1823', AVA RHS PKR % 6522', TUBING TAIL ~ 6594' DAILY:$59,973 C0M:$855,806 BTD:$855,806 EFC:$1,490,000 The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pagan 86 and 87. Date . I Title AR3B-459-1-D INumber all dally wall hlstor/forml contecutlvely as they are prepared for oach well. Page no. I · © ARCO Oil and Gas Company Dally Well History-Final Report Instructions: Prepare and submit the "Final I~lport" on the first Wednesday after allowable has been eatlgned or well la Plugged, Abandoned, or Bold. "Final Report" should be submitted also when operations are suspended for an Indefinite or appreciable length of time. On workoverl when an official teat Ii not required upon completion, report completion ~and representative test data in blocks provided. Tl~e "lqnnl Report" form may be used for reporting the entire operation if space is available. ' ' District ARCO ]tLASKA :INC. Field KOPAROK RIV;-R Auth. or W.O. no. ~K4095 Operator ARCO Spudded or W.O. begun ACCEPTED Date and depth as of 8:00 a.m. 05/18/89 ( TD: 7100 PB: 6979 SUPV:LP County or Parish NORTH SLOPE Lease or Unit ADL: 25521 Title COMPLETIONS 50-029-21935 Complete record for each day reported NORDIC ! 10) IAcoountlng coat center code 8tats ~_~.= iwo,,.o. Old TO I New TD I Released rig I Date I Classifications (oil, gas, etc.) 05/16/89 I otal number of wella (active or Inactive) on thla, oat center prior to plugging and bandonment of this well our ' IPrior Matua'lf"i' ~, I 13:00 I RIG RELEASED 7"0 7066' MN:ll.3 N&C1 SERVICE RIG. M/U AND T~ST OTIS SSSV TO 5000 PSI. RIH AND LAND TO~BING. PRESS TEST TOBZNG TO 2500. SET PACKER. PRESS ANNOLOS TO 1500 PSI. RELEASE PER **SHEAR CHECK VALVE AT 3400 PSI. TEST SSSV 15 MIN. SHEAR BALL AT 3300 PSI. PULL LANDING JOINT. SET BPV. N/D BOP. N/U TREE AND PACKOFF. TEST TO 5000PSI. DISPLACE N~LL WITH 253 BBL DIESEL. SZTP 1,000 PSI. TEST ORIFICE VALVE - OK. SET EPV~ND SECURE WELL. RELF,~.~E RIG AT 1630 BR 5/17/89. DAILY:S114,434 CUM=$970,240 ETD=S970,240 EFC=$1,490,000 RECE, IYED UUN o 7 ~.las~ 0il .& Gas Cons. Commission ,, Anchorage IPB Depth Kind of rig Type completion (single, dual, etc.) Producing method Official reservoir name(a) Potential test data well no. Date Reservoir Producing Interval 011 or g~'l Teat time Production oil' on test Qaa per day Pump size, SPM X length "~hoke size T.P. C.P. Waier % '(~'OR Gravity AIl'owable Effective date corrected ,., , , The above is correct For form preporafi~/".~nd distribution, see Procedures Ma~0'al, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C rNumber ell dally well hlatory form! conlecutlvely aa they are prepared for each well. Page no. Olvldon ol A#antMRlehf~ldCompmy [ ! ALA 'KA OIL AND GAS CONSERVATION COMMIsS ioN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown _~_ Re-enter suspended well ~ Plugging __ Time extension __ Stimulate ~ Pull tubing __ Variance m Perforate ~ Other 2. Name of Operator ARCO Alaska, Inco 3. Address Po0, Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development _~. Exploratory m Stratigraphic ~ Service ~ 4. Location of well at surface 262' FSL, 85' FWL, Sec. 31, T13N, RgE, UM At top of productive interval 1120' FSL, 1750' FWL, Sec. 31, T13N, RgE, UM (approx) At effective depth 1271' FSL, 1856' FWL, Sec. 31, T13N, RgE, UM (approx) At total depth 1298' FSL, 1904' FWL, Sec. 31, T13N, RgE, UM (approx) 6, Datum elevation (DF or KB) RKB 76' 7, Unit or Property name Kupar`uk River' Unit 8. Well number 31-6 81~_P3~mit number 10. APInumber 50-- n~-?l~ 11. Field/Pool Kupar`uk River` 0il Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 71 O0 'MD feet 6571 ' TVD feet 6984 'MD 6469 ' TVD feet feet Plugs (measured) Junk (measured) None None feet Casing Length Structural Conductor 80 ' Surface 3525 ' Intermediate Production 7033 ' Liner Perforation depth: measured None Size 16" 9-5/8" 7" Cemen~d Measureddepth 254 sx CS II 115'ND 563 sx AS III & 3460'MD 342 sx Class G 250 sx Class G 7066'MD True vertical depth 115'TVD 3403 ' TVD 6541 ' TVD true vertical None RECEIVED Tubing (size. grade, and measured depth) None Packers and SSSV (type and measured depth) None MAY -/, :t 9 ,Oil ~: t~as Con&. 13. Attachments Wel 1 History Description summary of proposal __ 14. Estimated date for commencing operation May 1989 16. If proposal was verbally approved Name of approver Date approved Detailed operations program ~ BOP sketch 15. Status of well classification as: Oil ~ Gas ~ Suspended __ Service 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. 076/5A~ Date V//(~"~//'~ ¢] I Approval No, F~.,.~~ Date ,-,'~--~ '--~ ~' SUBMIT IN TRIPLICATE Signed F~' ~-.,"~¢.,~P_~v,~ Title Area Drilling 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 required 10- '~/-~ ORIGINAL SIGNED BY ApProved by order of the Commission LONNIE C. SMITH Commissioner Form 10-403 Rev 06/15/88 © ARCO Oil and Gas Company O Well HIitory- Initial Report - Dally Inalmcliona: prepare and submit the "lttlliM R~aorl~: ogt~ tho flret Wednesday after a well la spudded or workover oparatlonl ara tttflad, Dally work prior to aPuddlng- ~hould~ Do summarized on the form giving IncluMve dltOl only. Operator . Spudded or ~.~"l~gun Date and del~ aa of 8:00 a.m. IComplete record for eaoh day reported DCYCL' ! 4 04/12/89 ( ,) 'fi:): 236' ( 36) 8OPV: CD 04/13/89 ( ) TI): 2844' ( 2 10S) $OEV:CD 04/14/89 ( ) TI): 34'/9' ( 1359 S~V: ZR/SF 04/15/89 ( TD: 5401'( S~E)V:ZR/SP. ARCO W,I. 04/16/89 ( ~) TI): 6690'( 11899 SUPV:ZR/SP 04/17/89 ( ;) TD: 7100'( 109 SO1)V:ZR 04/18/89 ( ) TI:): ?100'( O) SOPV:ZR I,K)VBRIG FROM 31-10 TO 3I-6. N/U DIVBRTIR SYSTBM. P/U AMD STRA~ BHA. TBST DIVBRTBR SYSTID4, DRILL PROM 1150236'. ACCRFT RIG AT 003OHM SFUD AT 0430 HR. DAILY:$30,3S0 C0~:$30,350 HTD:$30,350 BPC:$1,490,000 DRILLING 9-$/6#0 3460' MM: 9.3 VIS: 50 DRILL FROM 236-2449. CZRC AND 80RVB¥. ~OOH ¢/O BHA. DRZLLAHD KZCK OFF FROM2449-2844. DAlLY:S62,980 ¢0M:$93,330 ETD:S93,330 BRC:$1,490,000 NU BOPS STACK 9-5/8#0 3460' MM: 9.4 VZS= 45 DRLD TO'3479'. CB~, SHORT TRZP. CIRC AND CC)ND HOLB. POOH. LD BHA. Rg AND RUlt 9-$/8# CSG#/ PC AT 3380' MiD FS AT 3460'. C:MT #/ S63 SXS OP AS ZIZ AT 12.7 PPG. CMTW/ 3.42 sx.q OF CL 'G# CHTAT 15.8 PI)G. ¢ZF AT 02~0S HR, 4/13/89 ND RISER AND. DZVERTBR. R~AHD PRP. rORM TOP JOB AT 15.8 PPG. N~ BOPS. 8TACK. DAZLY:$199,670 CUM~$293,000 ETD:S293,000 BP¢:$1,490,000 DRILLING 9-S/8#I 3460' MM: 9.1VZS: 36 -.*~~TEST BOF'S. N/U BHX AND TZH. DRILL O~T shes + 10' ~.~b, 965 COM:$362,965 BTDt$362,965 BP¢:$1,490,000 DRzLLING'~: 9-5/8#0 3460' MM:Il.3 VZS: 41 DRILL FROM S401 TO 650;. COM. DRO~ S~RVB¥ AHD POOH. C/O BHA RZH. CUT AHI) S~ZP DRILL ~Z5R. FZHZSH RZH. DRZLL FROM 650? TO 6690. D&Z~Y:$?S,Q4? COM:$438,012 ZTD:$438,012 ZPC:$1,490,000 POOH 'LO LOG 9-5/6"9 3460' MM:11.4 VIS: 40 DRILL PROM 6690 TO 7100. COM. SHORT TRIP. ¢CM, 8ORVBY AHD SPOT FZLL. POOH TO LOG. DAILY:SSS, 182 CI~.f:$493,194 BTD:$493,194 RPC:$1,490,000 CCIRC, PRBP TO C::HT 7#C86 9-S/8"9 3460' MM:11.3 V28:47 ROH TRZPLBCOHBO LOGS, DZL/SrL/GR/FI~/Cl~,/CAL/SP. TIH W/ BHA, CIRC AND COBD HOLB, TOH, LDDP, ReA Hi:) RUN 7" CASZHG TO BOTTON, NO FROBLBHS, CIRCA ND CONDITZON '~CEMENT. DAILY:$2S7,703 CUM:$7S0,897 BTD:$?S0,897 BPC:$1,490,000 The above j~corroct For form proparel~ and dlatributld~'-...,;~ see Procedures MJlhuel, Section 10, Drilling. Pages 86 and 87. AR3B-459-1-D - ~¥~, .- ~ ~ oil ~ 6~s ConS.. ~.~mtssto~-' I~',~-dlily well ~9_~n.outivolv 88 ~ey ~ pm~md ~W~h ~oll7 iPago no. ARCO Oil and Gas Company Dally Well History-Final Report Instructions: Prepare and submit the "Flall~Rll~Ort" on the first Wednesday after allowable hse been sellgned or well Is Plugged. Abandoned. or 8old. "Final Report" should be submitted afllO%v/~lft operations are suspended for an indefinite or appreciable length of time. On workoverl when an official test II not required upon completion, report completion and representative test data In blocks provided. The "Flail Relmrt" form may be uled for reporting the entire operation if space is available. __ I Accountlng cost center code District 1 State .~RCO .zI~ASK~ 3'NC. I ~ Field ICounty or Parish NORTH SLOPE Lease or Unit Title ADL: 25521 DRILL KUPARUK RIVER ~ ~? ~Iiwell no. Auth. or W,O. no. AK4095 Operator Spudded or W.O. begun SPOD Date and depth as of 8:00 a.m. Old TD Released rig IA.R.Co. Date 04/19/89 ( 'I'D: 7100 PB: 6984 SUPV:ZR 3~I: 50-029-21935 W.I. ITotal number of wells (eotlve or Inaotlve) on thlsl Icoet center prier to plugging encl labandonment of this well 55. 8533 IHo,, , I Prior etItu. ~f I W.O. / I 04/12/89 / 04 ;~9 I . Classifications (oil, gas, etc.) Complete record for each day reported DOYON 14 RIG RELEASED TO WEST SAK 7"e 7066' MW:11.3 N&C1 CCM. CEMENT CASING WITH 250 SX CLASS 'G'. DISPL~BAND BUMP PLUG WITH 11.3 BRINE. ClP AT 0915. TESTED CASING TO 3500 PSI. N/D CEMENT HEAD AND N/U TBG SPOOL. CLEAN PITS AND RIG e 1530 ll~S, 4/18/89. DAILY=S44,936 CUH:$795,833 ETD:S795,833 8) RECEI,VED BFC:$1,490~000 MAY -/: tg;~q Alaska Oil .& Gas Cons. Cc~misslon , ~ ~chorage JNew TO I PB Depth Date IKInd of rig I Type completion (llngle, duel, etD,) Producing method Official reeervolr name(a) Potential test data Well no. Date Reservoir Producing Interval 011 or galTilt time Production OII on teat Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The abov~/l~ ....~'.°ct ~ IDate~L///~ , JTltle For form prepara~oj3/and distribution, see Procedures M"Enual, Section 10, Drilling, Pages 86 and 87. AR3B~5~3-C INumber III dilly well history fermi oon~eoutlvely I Page no. they are prepared for eloh well. J ~ Olvlllee M Atllntl~MMIMdComp4ny ~ ARCO Alaska, Inc. Date: May 12, 1989 Transmittal #: 7468 RETURN TO: Transmitted herewith are the following items. one signed copy of this transmittal. 31 - 0 6 Cement Evaluation Log ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Please acknowledge receipt and return 4-21 -89 5290-6979 Alaska OJi'&'Gas Cons. Commission Anchorage Receipt Acknowledged: Date' D__iSTRIBUTION: .~ - ~..~s~pia) Drilling NSK ARCO Alaska, Inc. Date: April 24, 1989 Transmittal #: 7461 RETURN TO: ARCO Alaska, Inc. 'Attn: Brenda K. Miernyk 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. 31 - 1 6 OH LIS Tape and Listing 3 - 1 7 - 8 9 # 7 31 9 0 3 ! - 1 I OH LIS Tape and Usting 4 - 0 8 - 8 9 # 7 3 2 6 9 31 - 1 0 OH LIS Tape and Listing 4 - 1 3 - 8 9 # 7 3 2 8 5 31 - 0 6 OH US Tape and Listing 4 - 2 0 - 8 9 # 7 3 2 9 0 Receipt Acknowledged: DISTRIBUTION: Gas Con.'~. Commission Anchorage . Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: April 24, 1989 Transmittal #: 7458 RETURN TO: ARCO Alaska, Inc. - Attn: Brenda K. Miernyk 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. . 5" Dual Induction 4-1 7-89 3459-7083 . ~ii?~.. ~ 2" Dual Induction 4 - 1 7 - 8 9 3 459 - 7083 Cyberlook 4-1 7-89 6390-7030 2" & 5" Raw FDC 4-1 7-89 5490-7057 '6 2" & 5" Porosity FDC 4-17-89 5490-7057 31 - 1 0 5" Dual Induction 4 - 1 0 - 8 9 3411 - 7080 31 - 1 0 2" Dual Induction 4 - 1 0 - 8 9 3 411 - 7080 31-1 0 Cyberlook 4-1 0-89 6450-7050 31-1 0 2" & 5" Raw FDC 4-1 0-89 6450-7050 31-1 0 2"& 5" Porosity FDC 4-1 0-89 6450-7050 31-1 I 5" Dual Induction 4-03-89 1000-6720 31-1 1 2" Dual Induction 4-03-89 1000-6720 31 - 1 I Cyberiook 4 - 03 - 8 9 61 50 - 6700 31-11 2" & 5" Raw FDC 4-03-89 6150-6694 31 - 1 I 2" & 5" Porosity FDC 4 - 03 - 8 9 6150 - 6694 Receipt Acknowledged: DISTRIBUTION: State of Alaska(+sepia) ........................... Date NSK Drilling L. Johnston package) D&~t~lchom~e April &, 1~69 Telecopy. t (907)276 7542 Dear Hr. Wtn£~ee ~ Enclosed is the approved application for permit to drill the above re~-~d weil. ~ne pe.~t to drill does nsc e~mp~ you ~rou obtaining additional pernuts required by 1F. ~ O~her 8OVe~ncal apncies, and ~es not au~rize c~~cins drill!~ oPeract~s ~til all other required ~~~i~ denominations ar~ ~. To aid us ~ s. ehedultng Eteld york, please notify chis office 24 hou~,a, prior to ¢~~nc~ installation o~ ~b bl~t prev~tion equimac 8o tha~ a ~epFes~attve of the C~/mmion my be pre~n~ to withes tesClns o~ ~e ~ul~nc be~ore the surface cas~ shoe ~ ~illed. ~e~ a ~ver~er syo~ ~s required, please als? notify ~his o~Ce 2~ hours prior ~o C~ncins eq~~~2 ~alla~on so C~ the ~olf~ ~y witness testing be~0ze drill.S ~~ ~he shoe o~ ~e e~~ecor pipe, ~aska: Oil ~d Oas C~eFvaCion C~ssion ~los,d~e Depar~en~ o~ Fish &Oame, H~itat Section w/o encl. ~Par~nt o£ Environmental Conservation w/o enel. .' ~ STATE OF ALASKA CO~>~. iSSiON,,,,,, ALASKA OTE~AND GAS CONSERVATION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill []1 lb. Type of well. Exploratory ~ S.tratigraphic Test ~ Development Oi~ Re. Entry .ri Deepen[]! Service ~ DeveloPement Gas ,~ Single Zone,[~ Multiple Zone 2 Name o_f OPerator 5. Datum Elevation (DF or KB) 10. Field and Pool '~R'C'0' ATas~ka, Inc. Pad 40' KB 76 feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River 0il PoD! P.0. Box 100360, Anchorage, AK 99510-0360 ADL 25521 ALK 2557 4. Location of well ai surface ' 7. UMt or property Name 11. Type Bond(,e 20 ^^c 2s.02s) 262'FSL, 85'FWL, Sec.31, T13N, RgE, UN Kuparuk River Unil; Statewtde At top of productive interval 81 Well nurpber ' Number 1120'FSL, 1750'FWL, $ec.31, T13N, RgE, UM 31-6 No. U-630610 l~.t0t~)~l depth g. Approximate spud d~,te Amount L, 1944'FWL, Sec.31, T13N, RgE, UN 04/10/89 $200,000 12. Distance to nearest 13~el~i~ta.~e.-}o ne~§e.~;~ell 14. Number of acres in propert~ 15. 7171717P~)(~P2O~Sl~ depth(aoan~'vo) pr°pertL~l~)e 1220' feet f/surf t:o 1240' feet 2560 6506'TVD feet 16. To be com~ t q for deviated wells 30.5 17. Anticipated pressure Kickoff depth ~ feet Maximum hole angle o Maximum surface 2020 ~)s~ ^t tota~ (~em~ (TVO) 6136300 i8. Casing program Setting Depth .. " size Specifications ToP Bottom Quantity of cement ' Hole Casing Weight Grade Coupling Length MD TVD MD TVD (Include stage data) z~,, 16- 62.5~ H-40 Weld 8( ' 37' 37' 117' 117 :!:200 cf /2'~/~" ~J-5/~¥' 36.0~ J-55 BTC 3422' 3'7~ 37' 3459'" 3411 563 sx CS III , . iHF-ER ~'~ ~,, Cla~ C. 8-1/2~' 7" 26.0~ J-55 .B,TC, 7016' ~6' 36' 7052' 650~,' ~nn HF-ER~ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor iSn~reframC~diate RECEIVED Production Liner MAR 2 ?." Perforation depth: measured ~j~JJ true vertical * :i~t~i~i 20. Attachments Filing f'ee [] Property plat ~' BOp Sketch ~r Diverter Sketch i~, Drilling program ~' , Drilling fluid program ~ Time vs depth plot [] Refraction analysis ~ Seabed report [] 20 AAC 25,050 requirements 21. I hereby~certify that the foregoing is true and correct to the best of my knowledge d~/,,'~ (~~ Area Drilling Engineer Signe Title Date Commission Use Only ~J i L) PDt/OS9 Permit Number I APl number I Approval date l see cover letter ~ ~.-_~,~ 50- O .Z. ~'- ;2,:~,/~ ~,5' 04/04/89 .,. for other requirements Conditions of apl~roval Samples required [] "Yes ,,~lii[ No Mud I°g required ~ Yes ~ No Hydrogen sulfide measures [] Yes ,j;~'N~, Directional survey required ~]~Yes [] No Required working.,pr, qssure [or..Be~ ..~2M; ~ 3M; 'i-I 5M; [] 10M; E;., 15M Other: //~.,~///~, / / ' ~,~ -~- , by order of Approved.. by{~ ~ ,.~/. ..(- ~ ~,~__~~~. . Commissioner. the commission Date 'GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. MIRU, 2. Install FMC diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8%" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8%" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. 23. Perforate remaining zones. OEGASSEIII MUO CLEANIIII R. ECEiV'.ED SHALl SHAKERS STI STIIII STIR MUO CENTRIIIUGi © WELL3I-6 DRILLIN¢~FLUID ?RO~RAM 9-5/$" Surfacm CaSins Co Wmight,Up 9.0-9.8 8.7'9.2 Weight Up ~o TD 9.9 PV 15-30 5-15 20-40 8-12 Viscosity 50- lO0 35-40 35-50 2-4 3-5 LO Hinute Gal 15-30 4=~ Filtrate A~I 20 tO-20 pH 9-10 9.$-t0.5 9.0-t0.$ Solids 10.* 4-7 12 - Triple Tandem Shale Shakmr - 2 Mud Cleaners - Centrifuse - Desasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid A$itacors Notes: Drillin$ fluid practices viii be in accordance vith the appropriate relulacions stated in ZOAAC 25.033. ~axiaua anticipated surface pressure is calculated usin$ a surface casin$ leak-off of t3.$ pp$ EHW and a S&i iradient of .Il psi/ft, This shovs chac formation brsakdovu vould occur before a surface pressure of 3000 psi could be reached. TherefoFe, Ai¢O Alaska, Inc. rill cesc our SOP equipuenc co 3000 poi. A£Cer ?6 ' of departure, there are no veil bores vithia 200' of this proposed veil. In accordance with Aces ZnJeccion Order No. 2, tXGili~ ~ &~:~:,~, .,1_.~1 in ;~eFve. pits The annulUsViil b· ~e~c vXch a usu freesias fluid duties any extended shucdovu in disposal operations. ~e a~ulus will be sealed ~Xch ~7~ sx o~ ceuenc ffo~loved by arctic pac~ upon co~leCion of the fluid disposal. JTZ/14 ih 350. 3;00. 250 - 200 - 150 - 100 - 5O 5O 250 200 150 100 50 0 I I I / I I I ...... .... i '-"'"---~ x;og ! I I /'~4 / 50 1 O0 150 200 250 i 250 200 150 100 50 0'. 50 58 _ 200 150 100 50 I 100: 1 50 i 200 i 250 50 © KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC DESCRIPTION e. 4 Cx~ 11,1m ONERI'~ 8~ ~ A v~ MAINTENANCE & OPERATION _,1 I 3 2 1. UPON INITIAL INSTALLATION. OI,,O6E PfIEVEN'I"ER ANO VERIFY TI,,IAT VALVE OPF. N~ PROPF..qLY. 2. CLOSE NqNUt.AR I~1~ ~ ~OW AIR I'HI:IOJ~ 01VERTER LINES EVERY 12 HOUF~ 3. Ct.~ ANNULAR I~~T~q N ~ ~ THAT AN INFLUX C~ ~ Iq,,U~ 0111 (2M I~ 0ET~TEO. OPEN AR~RIATE VALVF,, TO ACHIEVE DOWNWlNO 01VEFISlON. DO NOT SHUT IN WELL UNDER ANY CIRC~UM~TANC~Em I I 4 2 1 & 7. & O, IL 13, 14N, Xf lob ARGO ALASKA, ]:no.© Pad 3I. 14ell Not ~ ~vlsed PPo~.osal Kupe~uk FI · I d.- Noe h ope, Al as a RKB ELEVATIGN~ 7'6' 1000 2000 m 3000 4000 5000 GOOO. 7000 B/ PERHAFROST TVD-1661 T~ UGNU SNDS TVD=2246 KOP TVD-2440 TIID-2440 DEP-O 3 BUILD 3 OEO 9 T/ 14 sAKPYNI~0 F~VD"2811 T"D"2813 DEP"36 15 2! K-12 TVD-3211 THD-3234 DEP"163 2?' EOC / 9 5/8" CSG PT TVD-3411 THD'3459 DEP-265 K-lO TVD-3496 THD-3557 DEP-315 K-5 TVD-4636 TIID-4881 DEP-g88 AVERAGE ANGLE 30 DEG 32 TARGET TVD-6136 THD-6623 DEP"1873 T~ ZONE A TVD"6229 TFID-6731 DEP"1928 B/ KUP SNDS TVD-6334 TIID-6852 DEP-1990 TD (LO0 PT) TVD-6$06 THD'?052 DEP'2092 1 000 2000 VERTICAL SECTION 3000 HORIZONTAL PROJEOT ION SCALE 1 IN. - 1000 FEET I , .P_od 31. Well No~ 6 Revleed Pr'opoeol KupePuk Fl*id, Nor, f:h Slope. Aleelco SURFA(,'E LOCAT ! ON, 262' FSL. SS' F1~1. SEC. 31. T13N. RSE I 3000 2000 _ 1000 . O a 1000 . WEST-EAST 1000 0 1000 2000 3000 , , I ,, i , I Ii N 62.DEG 44 HI N E 1 873' (TO TAROET) TD LOCATIOtl, 1220' FSL. 1944' Fgl.. SEC. 31. T13tl, RgE TARGET TVD-613,~ TI'ID-SS23 DEpm 187'3 NORTH TARGET LOCAT I ON, 1.120' FSL. 1750° SEC. 31. TI3N. RGE ,~ ~U~vE~ ~TES ~~ ~ r I. C~~TES ARE A.S.E ~ zONE 4. 2. ~CTION LINE DISTANCES ARE TRUE. ~ ~ZONTAL POSITIONS ~SED ON ON-PAD CONTROL ~R L.H.D. ~ ASSOC. 4. ~ICAL POSfflONS BASED ~ TBM 5[ - 4 PER LHD & AS~C. ~ ~ ELEVATES INTERPOLATED FROM S/C DWG. CED- RlXX - ~O50 rev. ~ LOCATED IN PROTECTED SEC. 51,TI5 N, R9E, U. MER. LOCATED IN PROT~D~C.~TIS~ RaE~ U. MER. 1- Y= 6,007,285.50 LAT. 70025'52.0592" 9- Y= 6,007,121.00 LAT. 70~25'50.44~ X= 508,056.44 LONG. 149°56'03.596" X- 507,867.91 L~G, 149~56'09,134~ 179' F~L, 345' FSL 0G. 33.6', PAD 39.9' 180' FSL, 10~ FEL 0G, 35.0', PA~ 39,9' 2- Y= 6,007,269.06 LAT. 70°25'51.8978" 10- Y- 6,007,104.59 ~T. 70~25'50.2821~ X= 508,037.66 LONG. 149°56'04.148'' X= 507,849.11 LONG. 149~56'09,686" 160' F~L, 328' FSL 0G. 33.7', PAD 39.9' 164' FSL, 29' FEL 0G. 35.0, PAD 40.0 3- Y= 6,007,252.70 LAT. 70°25'51.7370" 11- Y= 6,007,088.16 ~T, 70~25~50.1206" X= 508,018.80 LONG. 149°56'04.702'' X= 507,830.23 LONG. 149°56'10.240" ~ 141' F~L, 312' FSL 0G. 33.7', PAD 40.0' 147' FSL, 48' FEL 0G. 35.0, PAD 40.1 I 4- Y= 6,007,236.23 LAT. 70°25'51.5752" 12- Y= 6,007,071.76 LAT. 70o25'49.9595" X= 507,999.99 LONG. 149°56'0'5.255 X= 507,811.32 LONG, 149°56'10.796" 122' F~L, 295' FSL 0G. 33.8', PAD 40..0' 131' FSL, 66' FEL 0G. 35.0, PAD 40.1 5- Y= 6,007,219.81 LAT. 70°25'51.4139" 13- Y= 6,007,055.32 LAT. 70°25'49.7981" X= 507,981.16 LONG. 149°56'05.808" X= 507,792.36 LONG. 149°56'11.353" 104' F~L, 279' FSL 0G. 33.9', PAD 40.0' ].15' FSL, 85' FEL 0G. 35.0', PAD 40.1' 6- Y= 6,007,203.20 LAT. 70°25'51.2507" 14- Y= 6,007,038.82 LAT. 70025'49.6359" X= 507,962.12 LONG. 149°56'06.367'' X= 507,773.63 LONG. 149°56'11.903" 85' F~L, 262' FSL 0G. 34.0', PAD 39.9' 98' FSL, ].04' FEL 0G. 35.0, PAD 40.1' 7- Y= 6,007,186.78 LAT. 70°25'51.0895" 15- Y= 6,007,022.42 LAT. 70°25'49.4749'' .. X= 507,943.27 LONG. 149056'06.920'. X= 507,754.83 LONG. 149°56'12.455" 66' F~L, 246' FSL OG. 34.2' PAD 39.8" 82' FSL 123' FEL 0G. 35.0', PAD 40.2' , ' 8- Y= 6,007,170.37 LAT. 70025'50.9282" 1~ Y= 6,007,006.02 LAT. 70°25'49.3137'' X= 507,924.40 LONG. 149056'07.475'' X= 507,736.04 LONG. 149°56'13.007'' 47' F~L, 230' FSL 0G. 34.5', PAD 39.8' 65' FSL, 142' FEL 0G. 35.0', PAD 40.2' I II :, ~ o,,.,,~c~ F~R. ~k ARCO Alaska, Inc. ; ~ ~~~~~. Iml' ~ ! DATE 12.22.85 r ,~ ~ o~w. w. DRILL S,TE CONDUCTO" R ~CKED~ ll~"ff. ~,.~ ~e... AS-BUILT LOCATIONS - TM ~~. ' _ i~ ~._!~~ ~-''~~_~ ~ ~Arcr,c 8oulevard. Suite 20 i. Anchorage, Alaska 99503 as ,.o. .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 ,' 'iCHORAGE i- , ': . ALASK" Re: THE APPLICATION OF ARCO ) ALASKA, INC. for an order ) granting an exception to ) Rule 4(c) of Conservation ) Order No. 173 for wells to ) be drilled from 15 drill ) pads in the Kuparuk River ) Field· .) Conservation Order No. 209 Kuparuk River Field Kuparuk River Oil Pool May 23, 1985 IT APPEARING THAT: I · ARCO Alaska, Inc., by letter dated April 30, 1985, requested the Alaska Oil and Gas Conservation Commis- sion to issue an order granting an exception to Rule 4(c) of Conservation Order No. 173 to allow surface casing to be set as deep as 4150 feet true vertical depth in development wells to be drilled from drilling pads IR', 2A, 2H, 2T, 3A, 3B, 3C, 3F,,.:3Z, 3J, 3K, 3M, 3N, 30 and 3Q. · Notice of public hearing was published in the Anchorage Times on May 7, 1985. There were no protests to the request set forth in the notice of public hearing· FIND INGS: I · The Ugnu sands and the West Sak sands are hydrocarbon- bearing and potential reservoirs in some areas of the KUparuk River Field· · The West Sak sands are or could be hydrocarbon-bearing in the area of drilling pads 1R, 2A, 2H, 2T, 3A, 3B, 3C, '3F, 3I, 3J, 3K, 3M, 3N, 30 and 3Q. · The oil in the West Sak and Ugnu sands has a low solution GOR and has no known gas-oil contact. Conservation 0 ..... - r No. 209 Page 3 May 23, 1985 NOW, THEREFORE, .IT IS ORDERED: Development wells to be drilled to the Kuparuk River Oil Pool on drilling pads iR, 2A, 2H, 2T, 3A, 3B, 3C, 3F, 3I, 3J, 3K, 3M, 3N, 30 and 3Q may be drilled to a.maximum 4150 feet true vertical depth before surface casing is set provided that conductor casing is set and cemented in accord with Conservation Order No. 173, a diverter system is used in accord with 20 AAC 2§.0.35(b)(1) and a drilling fluid of at least 9.0 pounds per gallon is used in the drilling. DONE at Anchorage, Alaska and dated May 23, 1985 Alaska Oil and Gas Conservation Commission Alaska Oil and Gas Conservation Commission · Smi ~, ~mmi s s i one r Alaska Oil and Gas Conservation Commission CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (8) (3) Admin ;{O/Pr. _~;a~_/;~ 9. ' (9 -~hru~ 10. (10 and 13) 12. 13. (4> Casg (14 thru 22) (23 thru 28) (6) O~ER (29 th~ 31~~ Geology_: gngine~rin~: ..-- rev: 01/30/89 6.011 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. l~or 29. 30. 31. 32. Company //-~.,L%_ /~)~. , ,~./~., Is the permit fee attached · ' el · · · · · e i e e e e . e e ~ e · · · · e · · · · · · · I e e e e · · · · · 2. is well to be located in a defined pool ............................. 3. is,.w~l located proper distance from property line . .. 5. Is su.~i~ient undedicated acreage available in this'pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ....................... Lease & Well No. ~~ YES NO -- Does operator have a bond in force ~ eeee®eeeeeeeeeeeeeeeeeeeeeeeeeeee. Isa conservation order needed ...................................... Is administrative approval needed eee.eeeeeeee.eeeeee.eeeee®®eeeleeel Is the lease number appropriate ............. ........................ ~ Do the well 'have unique and number '~ es a name ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to ...... serve as an underground source of drinking water ..................... ,~ ,, Is enough cement used to circulate on conductor and surface ......... ,~ Will cement tie in surface and intermediate or production strings ... Will cement cover all kno-~ productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ' · · eeeeee®eeeeeeeeeeeeeeee.ee . Is a diverter system required ....................................... ~ Is the drilling fluid program schematic and list of equipment adequate -~ Are necessary dtagrum~ and descriptions of diverter and BOPE attached..,4~ Does BOPE have.sufficieut pressure rating - Test to 30~). psig .. ~ Does the choke mauifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphicwells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. , , INITIAL CEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , P o/oo t-o, /,'./Co Additional Remark~: o . . 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. ~ ~L~SKA cotqPUT~.#G CENTER · .......SCHLU#BERGER*~ ........ COMPANY NANE : ARCO ,ALASKA 14ELL NAME : FIELD NAI4E : KLtPAR~ BOROUGH : SLOP E STATE AP! HUMBER : 1935 REFERENCE NO : 73290 TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COHPUTING CENTER 20-APR-1989 I:2:12 PAGE: ~f~ REEL HEADER SERVICE NAME : EDIT DATE : 89/0¢/20 ORIGIN : FLIC REEL NAHE : 73290 CONTINUATION ~ : PREVIOUS REEL COMMENT : ARCOt'KUPARUK~ 3 I-6t API ~50-029-Z1935 ,O:** T APE HEADER SERVTCE NAME : EDIT DATE : 89~:0'4/20 :ORIGIN : TAPE NAME : 73270 CONTINUATXON # : 1 PREVIOUS TAPE CQMHENT : ARCO~ KUPARUK~ 3 X-6~ AP~ I50-OZ~Z]~35 · ~ F:I.L E HEADER FILE NAME SERVICE : FLZC VERSION : OOTAO2 DATE :' 89/O~'4t*ZO MAX eEC SXZE : FILE~TTPE. : LO LAST FILE SCHLUMBERGER HELL SERVICES · , COMPANY NAME: ARCO ALASKA INC. td ELLr: 3 I-6 F I ELD;: KU P A RUK BOROUGH: NORTH SLOPE STATE: ALASKA API NUMBER: 50-029-21935 LOCATION: ZOZ" FSL~ B5" FWL SECTION: 31 TOI~INSHIP: PER:NANENT DATUM: IqSL ELEVATION: O. RANGE: 9E TAPE VERIPICATION LISTING 20-APR-1989 12:12 CHLUMBERGER ALASKA COMPUTING CENTER PAGE: LOG MEASURED FROM RKB ELEVATIONS KB: 76. ABOVE PERMANENT DATUM DF: 75. GL: 4.0. DATE LOGGED: 1T-APR-89 TO DRILLER: TO LOGGER: 7089. CASING: 9 5/8m a DRILLER DEPTH OF 34.59 AND LOGGER DEPTH OF 34.59 BIT SIZE: 8 TYPE FLUID ZN HOLE: WEIGHTED POLY~qER OENSITY: ."11.4. VISCOSITY: 4.0. PH= 9. FLU~O LOSS: ~.6 C3 MUD RESiSTiVITY: 3.8 a 66. FILTRATE RESISTIVITY: 3.9 MUD CARE RESISTIVITY: TZ~E CIRCULATION ENOEO: 0~:00 1T-APR TIHE,LOGGER ON BOTTOM:. 09:Z07:~ 1T-APR MAXIMUM TEMP LOGGING ,DISTR~CT: ~' PRUDHOE BAY LOGGING ENG~N~ER: FRITZEE g ZTNE S S: RUNJE/BE AL TOOL NUMBERS: SGC-JC 2626 PGC-JA 1053 DIC-DA Z.191 I EH-B D "14 48 CNC-A 14.49 PGS-H8 508 OIS ,.,,-EL 2140 NLM-BC 1329 FIELD REMARKS: 1Z/Z# STANDOFFS AND CAULIFLOWER BULLNOSE USED ON OIL. MATRIX DEHSITY = 2°65 G/CLot FLUID DENSITY =: ].0 G/CC. NEUTRON HATRIX : SANO~ HOLE CORRECTION : CALIPER. HAXIMUM DEVIATION = 30.9 DEGREES a 42'99 FEET. INTERVALS LOGGEO AT CLIENT*S REQUEST. AN EXTRA REPEAT gas MADE TO IMPROVE SKIO CONTACT. DATE JOB STARTED: ZO-APR-B9 JOB REFERENCE NO: 73290 LOP/RNA: J. KOHRING THIS DATA HAS NOT BEEN OEP'TH SHIFTED - OVERLAYS FIELD PRINTS IS TAPE VERIFICATION LISTING CHLUHBERGER ALASKA COHPUTING CENTER 20-APR-1989 12:1Z PAGE: SCHLUMBERGER LOGS INCLUDED WITH THIS FILE (EDIT,,,O01): (SEE FILE EDIT. OOZ FOR 1.2m SAIl. PLED FDC/CHL DATA) DUAL INDUCTION SPHERICALLY FOCUSED LOG (.DZL) FIRST TO LAST 'READ/NG: T081e TO 3459' FORMATION DENSITY COMPENSATED LOG C,,FDC) FIRST T~, LAST *Y~EAOING: '* 7056' TO 6388' AND 5811m TO 5488' COMPENSATED NEUTRON LOG (.CNL) FIRST TO LAST READING: 7041' tO 6388' AND 581Im TO 5488° GAPIMA RAY IN CASING (:.CSG) " : FIRST TO LAST READING: 3464' TO- 935' TABLE TYPE : CONS, TUNI VALU DEFI CH . ' ARCO ALASKA INC- COMPANY NAME FN KUPAR'UK FIELD MANE gN 3 I-6 WELL NAME NATI USA NATION STAT ALASKA STATE OR PROVINCE COUN NORTH SLOPE COUNTY FL Z6Ze FSL. 85' FML FIELO LOCATION SECT 31 SECTION TOWN 13N TOUNSHIP RANG 9E RANGE ENG! FRITZKE E'NGINEER~ S NA~E SON 5.4835.3 SERVICE ORDER NUMBER APIN 50-029-Z1935 AP! SERIAL NUMBER TABLE TYPE : CURY DEPT TENS ILO ILM SFLU SP GR TENS DPHI R'HOB. DEPTH CHANNEL NAME TENSION IL-DEEP RESISTIVITY IL-M EOIUH RESISTIVITY SFL UNAVERAG~D SPONTANEOUS POTENTIAL GAHM*A' RAY TENS. ION OENSITY POROSTTY SULK DENSITY TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER ZO~APR-1989 12:12 PAGE: DEF! DRHO DELTA "RHO FFDC FAR FDC COUNT RATE NFDC NEAR ROC COUNT RATE CALZ CALTP~ GR GARMAi~ RaY TENS TENSION NPH:X NEUTRON POROSITY TNPH THERHAL NEUTRON POROSITY TNRA ~' CAL]:BRATEO THERMAL. NEUTRON RATIO NPOR NEUTRON POROSITY OUTPUT FRON AN APPLICATION PROGRAM RCNT RAM CORRECTED NEAR THER#AL COUNTS RCPT RAN CORRECTED FAR THERWIAL COUNTS CNTC CORRECTEO NEAR THERMAL COUNTS CFTC CORRECTEO FAR THERMAL COUNTS CALl CALIPER GR GAHMA RAY TENS TENSION GR GAtq'PIA:'iRAY DATA FORMAT SPECIFICATION RECORD ~ · ~ SET 'TYPE - 64EB ~ TYPE, REPR CODE VALUE 1 66 0 2 66 0 3 73 11.2 4. 66 5 66 6' 73 7 65 8 68 0.5 9 6.5 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1.. 0 66 0 ,IS TAPE VERIFICATION LISTING 20-APR-Z989 12:12 ;CHLUMBERGER ALASKA COHPUTING CENTER · ~ SET TYPE - CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER'~ LOG TYPE CLASS HOD NUMB SAMP ELEM CODE (HEX) DEPT TENS'DZL ILD OIL 1LM 'DZL SFLU'DZL SP 'DZL ~R TENS FOC DPHI FDC RHOB FDC DRHO FDC FFDC.FDC NFDC FDC CALl FDC GR FOC TENS~CNL NPHI~'CNL 'TNPH~'CNL TNRA CNL NPQE'CNL RCNT CML RC~T CML CNTC CNL CFTC CNL CALl .CML GR CNL TENS CSG GR CSG FT 54*8353 00 LB 54*8353 00 OHMM 54*8353 O0 OHPlM 54*8353 00 OHHM 548353 00 nv 548353 O0 GAPI 54*83:53 O0 LB 54*8353 O0 PU 54*8353 O0 G/C3 548353 O0 G/C3 · 5483'53 00 CPS ' 548:35~3 O0 CPS 54.83, 3 O0 ZN * 54.831~' 0,0 GAPI 548353 O0 'LB 54*8353* O0 pu 5,r,.835~ oo p u 54. 8 3 5~ 00 54,835',~ 0.0 ' PU 54.83~3 0 o CPS 54.83~ CPS 54*8353 CPS 54*8353 CPS 54*8353 I N 54* 8353 ~' GAPI 548'353 LB 54*8353 GAPI 548353 O0 O0 O0 00 O0 O0 O0 O0 000 O0 0 I 1 000 O0 0 I 1 000 O0 0 I 1 000 O0 0 I 1 000 O0 0 I 1 000 O0 0 I 1 000 O0 0 I 1 000 O0 0 I 1 000? O0 0 I 1 0'00~!. O0 0 I 1 000:O0 0 I 1 000 O0 0 I 1 OOO O0 0 1 1 000 00~ 0 I 1 000 O0 0 1 1 000 O0 0 I 1 000 .~, O0 0 1 1 000 O0 0 I 1 000 ' O0 0 I 1 000 ,:~ O0 0 I 1 000 00 0 I 1 000 O0 0 I 1 000 O0 0 I 1 000 O0 0 I 1 000 O0 0 I 1 000 O0 0 I 1 000 O0 0 I 1 000 00 0 I I I 4, 68 0000000000 I 4, 68 0000000000 I 4. 68 0000000000 I 4. 68 0000000000 I 4 68 0000000000 I 4, 68 0000000000 I 4. 68 OOO0000000 I 4, 68 O0000OO000. I 4, 68 0000000000 I 4, 68 O000OO0000 I 4, 68 0000000000 I 4, 68 0000000000 I 4, 68 OOOO000000 I 4, 68 0000000000 1 4, 68 0000000000 1 4, · 68 O0000000OO I 4, 68 0000000000 I 4. 68 0000000000 I 4, 68 0000000000 I 4. 68 0000000000 I 4 68 0000000000 I 4, 68 0000000000 I 4, 68 0000000000 I 4, 68 0000000000 I 4, 68 0,000000000 I 4, 68 O000000OO0 I 4 68 0000'000000 I 4, 68 0000000000 PAGE': DATA DEPT. SFLU. DIL DPHX. FDC N'FDC. FDC NPHI.CNL RCNT.CNL CALI.CNL DEPTo SFLU.DIL DPHI.FOC NFOC.FOC NPHI.CNL RCNT.CNL CALIoCNL 7100.000 2.605' 19.554* 754*.500 35.195 1798.527 6.570 7000,000 3.4.70 11.04.4. 57O.000 3.4*.970 2027.053 8.906 TENS'OIL 2110'000 ILO?OIL .2.318 SP.DIL -11.5:00 GR-.OXL 88'063 R'H!OB.FOC Zo161 DRHO-FOC 0.039 CALi*FOC :6.570 G.R,FDC 88°063 TNPH.CNL 32.925 THRU-CML 2'931 RCFToCNL 587.706 CNTC,CNL 1852.998 GR.CNL 88-063 TENS-CSG -999.250 TENS*OIL 3890. 000 ILO. OIL 3.068 SP. OiL -10.766 GR. OIL 90. 563 RHOBoFOC 2.468 DRHO~ F'DC 0.013 CAL! *FOC 8,, 906 GR:.F DC 90. 563 TNPH.CNL 35.&73 TNRA.CNL 3.083 RCFT.CNL 636. 807 CNTCoCNL 2110'054* GR'CNL 90.563 TENS.CSG -99'9.250 ILN.DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CML GR.CSG ILH.DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTCoCNL GR.CSG Z.335 2110.000 1024.000 2110'000 31.925 64*3°758 -999.150 3.219 3890.000' 453.500 3890.0'00 36.112 691.753 -999.250 ,IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER ZO-APR-1989 12:12 PAGE: DEPT. 6900.000 TENS.OIL SFLUoDIL Z.Z05 SPoDIL DPHI.FDC 12o891 RHOB.FDC NFDC.FDC 605.000 CALZoFDC NPHIoCNL 44o9i8 TNPH.CNL RCNT.CNL 1806o219 RCFT.CNL CALI.CNL 9o266 GRoCNL DEPT. 68000000 TENS.DZL SFLU.DIL 100780 SPoDIL DPHIoPDC 16.857 RHOE.FDC NFDC.FDC 582.500 CALZoFDC NPHI.CNL 310119 TNPH.CNL RCNToCNL 2244.720 RCFT.CNL CALIoCNL 8.656 GR.CNL DEPT. 6?00.000 TENS.OIL 5'FLU.DZL 3.729 SP.DIL DPHI.FDC 2.644 RHOB.FDC NFDC.PD~ 530-500 CALI.FDC NPHZ.CNL 32.761 TNPH.CNL RCNT.CNL 2181.624 RCFToCNL CALI.CNL 9.242 GR.CNL DEPT. SFLU. DIL DPHZ.FDC NFDC.FDC NPHZ.CNL RCNT'CNL CALI.CNL DEPT. SFLU.DIL DPHi. POC NFDC.FOC NPHIoCNL RCNToCNL CALZ.CNL DEPT. SFLU.OIL OPHI.FDC NFDC.PDC NPHI ,CNL RCNT oCNL CALIoCNL 6600.000 TENS.OIL 1.952 SP.DIL 17.248 RHOBoFDC 593.000 CALZ.FOC 46.710' TNPH-CNL 1721.472 RCFT.CNL 9.898 GR-CNL 65.00.000 TENS.OIL 2.499 SP.DIL 17.085 RHOB.FOC 6190500 CALI'FOC 47.439 TNPH.CNL 1603o138 RCFT"CNL 9.695 GR.CNL 6400.000 TENS.OIL Z.099 SP.OIL 13.902 RHOB.FDC 610.500 CALI'FDC 44.964 TNPH..CNL 1170.072 RCFT.CNL 10.500 GR.CNL DEPT. 6300.000 TENS.OIL 5FLU.OIL 1.212 SP.DIL DPNZoFDC -9990250 RHOB'.FDC NFDC.FDC -999.250 CALI.FDC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL 3770°000 ILO.OIL Z.214 ILN.DZL -12g'166 GR.DZL 92.563 TENS.FDC 2.437 DRHO. FDC 0.029 FFDCoFDC 9.266 GR.FDC 92.563 TENS.CNL 42.876 TNRA.C#L 3.656 NPOR.CNL 475.038 C#TC.C#L 18600307 CFTC.CNL 92.563 TENS.CSG -999.2:50 GR.CSG 3634.000 -19. I56 2.365 9.898 43.946 451.771 114.250 3510.000 ILO.OIL 8.750 ILM.DIL -28.1562372 D:iGRH :OIL 71o938 TENSoFOCF . R 0 FDC -0.003 FDC.FDC 8.656 GR.FDC 71.938 TENS.CNL 29.365 T#RA.C#L 2.827 NPOR.CNL 785.271 C#TC.CtIL 2366.332 CFTC.CNL 71.938 TENS.CSG -999.250 GR.CSG 3710.000 ILD.D!L 3.120 IL#.DIL -15.406 GR°DIL 79.688 TENS.FDC 2.606 D'R'H:O ~ FDC ' 0"025 FFDC.FDC 9.242 GRoFDC 79.688 TENSoCNL 34.219 T#R A. CNL 2 o '984 NPOR. CNL 671.080 CiiTC'CI~IL 2183.488 CFTC.CNL 79.688 TE,'NS*CSG -999.250 GR.CSG ZLD.DIL .6R'OIL DRHOo FDC R .F'DC A.CNL C', C,,CNL TEN$.CSG 3510o000 ILO. OIL 2.011 ILMoOIL -33.844 .,GRoDZL 127.375 TENSoFDC Z.368 DRHO-FDC 0-018 FFDC°FDC 9.695 GR°F:DC 127.375 TENSoCNL 46, 513 TNR A°CNL 3.829 NPOR .CNL 395'644 C#TC~CNL 1734.491 CFTC.CNL 127' 375 TENS-CSG -999.250 GRoCSG 3,480.000 ILDoDZL ,1.758 ILM.DIL -40.3'15 iGR'DZL 106.625 TENS-FDC Z.421 DRHO. FDC 0.028 FFDC.FDC 10.500 GR.FDC 106.625 TEN$.CNL 45'062 TNRA.CNL 30760 NPOR.CNL 437-962 CNTC-CNL ' 17560619 CFTCoCNL 106.625 TENS.;CSG -999.250 GR.CSG 3480.000 ILo.OIL 1.651 ILM.DIL -29.594 GR.DIL 386.750 TENS.FDC -999.2.50 ' DRHO. FDC -999.250 FFDCoFDC -999.250 GR.FDC -999.250 TENS.CNL -999.250 TNRAoCNL -9990250 NPOR.CNL -999.250 CNTC.CNL -999.250 CFTCoCNL 1.771 ILM.DIL 114o250 TENS. FDC 0.000 FFOC.FDC 114.250 TENS.CNL 3.806 NPOR.CNL 1788.309 CFTCoCNL -999.250 GR.CSG 2.297 3770.000 5O8.25O 3770.000 42.860 525.452 -9990250 9.ZOZ 3510.000 552.000 3510.000 30.ZZT 891.140 -999.250 3.336 3710.000 332.000 3710.000 33.039 728.795 -999.250 1.845 3634.000 565.000 3634.000 44.354 492.201 -999o250 Zo101 3510.000 586.500 3510.000 49.075 458.716 -999.250 1.838 3480.000 5Z8o000 3480.000 43.212 471.630 -999.250 1.615 -999.250 -999.250 -999.250 -999.250 -999.250 .IS TAPE VERIFICATION LISTING ,CHLUPIBERGE'R ALASKA COMPUTING CENTER CALI.CNL -999.250 GR.CNL DEPT. 6200.000 TENSoDIL SFLU. DIL 3.&OT SP.DIL DPHZ.FDC -999.250 RHOB.FDC NFDC.FDC -999.ZS0 CALI.FDC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL C AL Z. CNL -999. Z 50 GR . CNL DEPT. 6100.000 TENS.DIL SFLU.DZL 3.908 SP.DIL DPHZ.FOC -999.250 RHOS.FOC NFDC. FOC -999.250 CALI.FOC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999.250 GR.CNL DEPT. 6000,000 TENS.DIL SFLU. O/L 3.16Z SP. OPHI.FOC -999.250 RHOB.FOC NFDC.FDC -999.2 SO' CAL!. FDC NPHZ'CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALZ'CNL -9990 Z 50 GR. CNL DEPT. 5900.000 TENS.OIL SFLU.D~L 4.014 SP.DZL DPNZ.FDC -999:'250 RHOB.FDC NFDC.FDC -999'250 CALZ.POC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL C AL ! . CNL -999. Z 50 G'R oCNL DEPT. 5800'000 TENS..DIL SFLU.DZL 5.891 SP.DIL DPHi. FDC 14.222 RHOB.FDC NFDC.FDC 599.000 CAL!.FOC NPHZ.CNL 32.633 TNPH.CNL RCNT.CNL 2048.327- RCFT.CNL C ALI'. CNL 1 O' 3 Z O' GR. CNL DEPT. 5700.000 TENS.OIL SFLU. OZL 4.431 SP.OIL DPHI.FOC 14.568 RHOB..FOC NFOC.FDC 59Zo000 CALI.FOC NPHI.CNL 37.709 TNPH.CNL RCNT.CNL 2073o154 RCFT.CNL CALI.CNL 9.602 GR.CNL DEPT. 5600.000 TENS.OIL SFLU.DIL 4.191 SP.DIL DPHIoFDC 12.886 RHOB.FDC NFDC.FDC 589.000 CALI.FDC NPHI.CNL 35.&46 TNPH.CNL 20-APR-1989 12:12 -999.250 TENS.CSG 3370.000 ILD.DIL -44.313 GR.DIL -999.250 DRHO.FDC -999.250 GR. FDC -999.250 TNRA. CNL -999.250 CNTC.CNL -999.250 TENSoCSG 32700000 ILO. OIL -45.250 GR. DIL -999.250 DR UO,. FDC -999.250 ~-FDC -999.250 TNR&.CNL -999.250 CNTiC.CNL -999.250 TEIISeCSG 3Z20.000 IL~D.DIL -48.094 ~.DZL -999.250 DR~.FDC -999.250 O~' FDC -999. 250, TNR~.CNL - 999. Z5 Or CNTE'CNL -999.250 TEHS. CSG 3170.000 ILD-DIL · ' OIL -46.844 GH~:FDC -999'250 DR -999' 250 G'R. FDC -999. 250 TN CNL -999.250 CNTC.CNL -999.250 TENS..CSG 296:0'00:0 ILO. DEL -46.781 GR.DZL 2.415 DRHO:~ FOC 1. O. 320 GR,.. F DC 34,402 TNRA. CNL 624. 189 CNTCe CNL 86.875 TENS. CSG 2910.000 ILD-OZL -56.500 GR. DZL 2'410 DRHO'FDC '9.602 GR. FDC 37.164 TNRA'CNL 6ZZ- 230 CNTC' CNL 83.813 TEN$.CSG 2880.000 ILO. DIL -53.688 GR.OZL 2.437 OR~,: FDC lO.227 :FDC 34.794 TNRA.CNL -999.250 Z.862 145.875 -999.250 -999.250 -999.250 -999.250 -999.250 3.218 116.625 -999.250 -999.250 -999.250 -999.250 -999.250 3.325* 103.563 -999.250 -999.250 -999.250 -999.250 -999.250 3.410 98.000 -999.250 -999.250 -999.250 -999.250 -999.250 6.066 86.875 0.018 86.875 3°064 Z141.691 -999.250 3.692 83.813 0.012 83.813 3.290 2132.99I -999.250 3.768 86.938 0.018 86.938 3.217 GR.CSG ILM.DIL TENS.FDC FFOC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM.OIL TENS.FOC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM.OIL TENS.~DC FFOC.FDC TEN$.CNL NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.FDC FFDC.FOC TENS.CNL NPORoCNL CFTCoCNL GR.CSG ILM.OIL TEN$o~DC FFOC.FDC TENS.CNL NPOR.CNL CFTC .CNL GR .CSG IL).OIL TENS.FDC FFDC.FDC TENSoCNL NPOR.CNL PAGE: 7 -999.250 Z.929 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.232 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.368 -999.250 -999.250 -999.250 -999.250 -999°250 -999.250 3.425 -999.250 -999.250 --999.250 -999.250 -999.250 -999.250 4.218 2960.000 5ZZoO00 2960o000 35'016 700--885 -9990250 3.943 2910.000 521.500 2910.000 37.104 666.765 -999.250 3.862 Z880.000 494.250 2880.000 35.484 .IS TAPE VERIFICATION LISTING iCHLUNBERGER ALASKA COMPUTING CENTER RCNT.CNL ZOZ3.171 RCFT.CNL CALI.CNL 10.Z2T GR.CNL DEPT. 5500.000 TENS.DIL SFLU.DZL 3.23T SP.DZL DPHI.FDC 14.433 RHOB.FDC NFDC.FDC 620.000 CAL/.FOC NPHI.CNL 36.293 TNPH.CNL RCNToCNL 1866.602 RCFT.CNL CALI.CNL 11. 680 GR.CNL DEPT. 5400.000 TENS.DIL SFLU.DIL 3.155 SP DIL DPHI.FDC -999.250 RHOB:FDC NFDC.FDC -9'99.250 CALZ.FDC NPHI.CNL -999.250 TNPHoCNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999.250 GR.CNL DEPT. 5300.000 TENS.DZL SFLU. DIL 3.132 SP.DZL DPHI.FDC -999.250 RHOB.FDC NFDC.FDC -999.250 CALZ.FDC NPHT.CNL -999o250 TNPH.CNL RCNT. CNL -999.250 RCFT.CNL CALI.CNL -999.250 GR.CNL DEPT. 5200.000 TENS.OIL S FLU. OIL 3. 729 DPHI.FDC -999.250 RHOB.FDC NFDC.PDC '-999.250 C:ALI.FDC NPHI.CNL -9'99o250 TNPHoCNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999o250 GR.CNL DEPT,, 5100.0'0'0 TENS.DIL $,FLU.OIL 3.558 SPoDZL DPHZ.PDC -999.250 RHOBoFOC NFDCoFDC -999.250 CALI.FDC NPHI.CNL -999. 250 TNPH.CNL RCNT.CNL -999o250 RCFToCNL CALI .CNL -999. 250 G'R. CNL DEPT.. 5000.000 TENS.OIL SFLU.DZL 4.305 SP'DIL DP:HI. F'DC -999.250 RHOB.FDC NFDC.FDC -999o250 CALZ.FDC NPHI.CNL -999. 250 TNPH.CNL RCNT.CNL -999o250 RCFT.CNL CALI.CNL -999.250 GR.CNL DEPT. 4900.000 TENS.OIL SFLU.DIL Zo529 SP.DIL DPHI.FDC -999.250 RHOBoFDC NPDC.PDC -999.250 CALZ.FDC Z0-APR--1989 12:12 646.648 CNTC.CNL 86.938 TENS.CSG 2870.000 ILD.DIL -53.844 GR.DIL 2.412 DRHO. FDC 11.680 GR.FDC 36.741 TNRA.CNL 536.594 C#TC.CNL 93.875 TE:NS.CSG 2118.975 -999.250 3.149 93.875 0.03Z 93.875 3.328 1918o714 -999.250 2894.000 ILO.OIL Z.866 -45.344 GR.DXL 94.438 -999.250 DRHO.FDC -999.250 -999o250 ~*:'GR.FDC -999.250 -999. 250 T#~AoC#L -999.250 -999. 250 C#TC oCNL -999.250 -999.250 TENS.CSG -999.250 2854°000 ILO.OIL -38. Z! 9 GR.DZL - 999. ZSO DR'HO.FOC -999.250 GR. FDC -999.250 T#RA.CNL - 999. 250 CNTC. CNL -999. 250' TENS.CSG 2.695 98.625 -999.250 -999.250 -999.250 -999o250 -999.250 283,4.000 ZLD.DZL 3.124 -56.250 GR.DZL 9~.688 -999.250 DR~;RO.FDC -999.250 -999.250 .FDC -999.250 -999.250 T~RA.CNL -999.250 -999.250 CI!TC.CNL -999.250 -999.250 TENS.CSG -999.250 ZLDoDIL GR.DZL ZLDoDIL 'GR.DIL DRHO.FDC ' GR.FOC TNRA..CNL CNTCoCNL. TENS.C SG ILO.OIL GR.DIL ORHO.FDC 'GR.FDC 2824.000 -51.031 -999.250 -999o250 -999o250 -999o250 -999.250 ZTIO.O00 -75.000 -999o250 -999.250 -999.250 -999.250 -999o250 2680.000 -56.563 -999.250 -999.250 3.032 89.188 -999.2'50 -999.250 -999.250 -999.250 -999.250 3.804 133.500 -999°250 -999.250 -999o250 -999.250 -999o250 2.352 100.688 -999.250 -999.250 CFTC.CNL GR.CSG ILM.DZL TENS.FOC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM. DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG IL#.DIL TENS.FDC FFDCIFDC TENS.CNL NPORoCNL CFTC.CNL GR.CSG TENSoFDC FFDC.FDC TENS.CNL NPOR.CNL CFTCoCNL GRoCSG ILM.DIL TENS.FDC FFDCoFDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILN. DIL TENSoFDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM.OIL TENS.FDC FFDC.FDC TENS.CNL PAGE: 688.712 -999.250 3°203 2870.000 544.500 28T00000 36.641 588.701 -999.250 2.909 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 Z.837 -999.250 -999.250 -99:9.250 -999.250 -999.250 -999°250 3.155 -999.250 -999.250 -999.25:0 -999.250 -999.250 -999.250 3.043 -999.Z'50 -999.250 -999.250 -,999.250 -999.250 -999.250 3.846 -999.250 -999'250 -999.250 -999.250 -999.250 --999.250 2.338 -999.250 -999-250 -999.250 IS TAPE VERIPICATION LISTING 20-APR-1989 12:12 CHLUMB~RGER ALASKA CO~qPUTING CENTER NPHI.CNL -999.250 TNPH.CNL -999o250 TNRA.CNL RCNT.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 GR.CNL -999.250 TENS.CSG DEPT. 4800.000 TENS.OIL 2600.000 ILO.OIL SFLU.'OIL 1.943 SP.DZL -48.813 GR.DIL OPHZoFDC -999.250 RHOB.PDC -999.250 DRHO. PDC NFDCoFDC -999.250 CALI.FDC -999.250 GR. POC NPHZ~'CNL -999.250 TNPH.CNL -999.250 TNR:'A.CNL RCNT.CNL -999.250 RCFT.CNL -999'250 CNTC.CNL CALI.CNL -999.250 GR.CNL -999.250 TEN$.CSG DEPT. 4TO0.O00 TENS.OIL Z640.000 XLD. OIL SFLU. DZL 2.363 SP.DZL -&T. Z81 ~.DXL DPHZ.FDC -999.250 RHOB.FOC -999.250 DR~,FDC NFDC.FDC -999.250 CALI.FDC -999.250 G~.FDC NPNI.CNL -999.250 TNPH.CNL -999.250 TNR~.CNL RCNT.C#L -999.250 RCFT.CNL -999.250 CN~.C#L CALX.CNL -999.250 GR.CNL -999.250 TE~.CSG DEPT. 4600.000 TENS.OIL 2624.000 ILD.DIL FLU, DXL 3.13T S P. DXL -52.156 ~. D'IL DPHX"FDC ' -999..250 RHOB'~FDC -999.250 DRND.FDC NFDCll=DC -9990250 CALI.FDC -999.250 GR. FDC NPHI.CNL -999.250 TNPH.CNL -999. 250 TN~.CNL RCNT.CNL -999.250 .RCFT.CNL -999.250 CNTC. CNL CALI.CNL -999.250 GR.CNL -999.250 TE~IS.CS6 DEPT. 4500.000 TENS-OIL 2524.000 OIL SFLU-OIL 3.869 SP.DIL -63.Z50 OXL DPHI.FDC -999.250 RHOB.PDC -999.250 PDC NFDC.FDC -999.250 CALI.FDC -999.250 NPHI.CNL , -999-250 TNPHoCNL -999.250 NL RCNT.CNL -999.250 RCFT.CNL -999.250 CNT~.CNL CALI.CNL -999.250 GR.CNL -999.2'50 TE~,,CSG DEPT. 4400.000 TENS.OIL Z504o000 ILD.DIL SFLU.OIL 3.72.2 SP.DZL -64'°563 OR.OIL OPHX.~DC -999.250 RHOB.FDC -999.250 DR~D.FDC NFDC.PDC -999.250 CALZ'FOC -999'250 G:R.PDC NPHIo'CNL -999.250 TNPH. CNL -999.250' TNR~.CHL RCNT'CNL -999°250 RCFT.CNL -999.250 CNTC.CNL CALI.CNL -99'9.250 GRoCN'L -999.250 TENS. CSG DEPT. 4300.000 TENS.OIL 2~70.000 ILO. OIL 5FLU.DZL Z.977 SP.DZL -67.750 GR. DZL DPHI.FDC -999.250 RHOB.FDC -999,250 DRH'O~FDC NFDC.FDC -999.250 CALI.FDC -999.250 GR'FDC NPHZ.CNL -999.250 TNPH.CNL -999.250 TNRA. CNL RCNT.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 GR.CNL -999.250 TEN$.CSG -999.250 -999.250 -999.250 1.993 96.688 -999.250 -999.250 -999.250 -999.250 -999.250 2.33T 80.8T5 -999.250 -999.250 -999.250 -999.250 -999.250 3.025 95.938 -999.250 -999.250 -999.250 -999.250 -999.250 3. 569 95.313 -999.25:0 -999.250 -999.250 -999.250 -999.250 3.499' 90.813 -999.250' -999.250 -999.250 -9'99.250 -999.250 3.037 85.313 -999.250 -999.250 -999.250 -999.250 -999.250 NPORoCNL CFTC.CNL GR.CSG ILA.DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC. CNL GR.CSG ILM.DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG IL~.DIL TENS .FDC FFDC. FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILA.DIL TENS.FDC F FOC. F'DC TENS.CNL NPOR.CNL CFTC.CNL GR .CSG IL~.OIL TENSoFDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR..CSG ZLRoDIL TENS.FOC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG PAGE: 9 -999.250 -999.250/ -999.250 Z.011 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 Z.313 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.969 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.533 -999.250 -999.250 -999.250 -999.250 -999.250 -999-250 3.594 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 Z.943 -999.250 .-999°250 -999°250 -999.250 -999.250 -999o250 IS TAPE VERIPICATION LISTING ZO-APR=1989 12:12 CHLUMBERGER ALASKA COHPUTING CENTER DEPT. 4200.000 TENS.OIL 2354.000 ILD.DIL 3.855 SFLU. OIL 3.6 55 SP .DZL -67.938 GR.DIL 8 T. 688 DPNI.FDC -999.250 RHOB.FDC -999.250 DRHO.FDC -999.250 NFOC.FDC -999.250 CAL'I.FOC -999.250 GR.FDC -999°250 NPH%. CN'L -999. 250 TNPN.CNL -999. 250 T#RA.CNL -999. 250 RCNT.CNL -999.250 RCFT.CNL -999.250 CNTC.C C -999.250 CALI.CNL -999.250 GR.CNL -999.250 TENS.CSG -999.250 DEPT. 4100.000 TENS.DIL 2510o000 ILD.DIL 3.491 5FLU. DZL 3.554 SP.DIL -68.563 ~GR.DIL 91.875 DPHZ.PDC -999.250 RHOB.FDC -999.250 DRHO.FDC -999.250 NFDC.'FDC -999.250 CAL'I.FOC -999.250 ~'GR.FDC -999.250 NPflI~CNL -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 RCNT.CNL -999,250 RCFT.CNL -999.250 C~C-CNL -999.250 CALI.CNL -999.250 GR.CNL -999.250 TE#S.CSG -999.250 DEPT. 4000.000 TENS.DZL Z360.000 ZLD.DZL SFLU.DIL 3.664 SP.DZL -71~813 6R.DZL DPHZ.FDC -999.250 RHOB.FDC -999o250 :FDC NFDC.PDC -9'99.250 CA,LZ'FDC -999.,250 FDC NPNI.CML -999.250 TNPH.CNL -999.250 ~.CNL RCNT.CIL -999.250 RCFT.CNL -999.250 . .CNL CALI.CN:L -999.250 GR.CN:L -999o250 'CSG DEPT. 3900.000 ~TENS.O'IL Z254..000 ILO.OIL SFLU. DZL 4. 916 SP. OIL -73* 250 GR. DZL DPHI.FDC -999.250 RHOB.FDC -999.250 DRHO.FDC NFDC.FDC -999.2'50 CALZ.FDC -999.250 R. FDC NPH]~.'CNL -999.250 TNPH,-CNL -999.250 RCNT jC'NL -999. Z 50 RCFT.CHL - 999. 250 CALI.CNL -999.250 GR.CNL -999.250 ,CSG DEPT. 3800.000 TENS,OIL ZIZO.O00 ~:LD.DTL SFLU.DZL 3.169 SP.OZL -75o250 ~. GR.DTL DPHZ.FDC -999.250 RHOB.FOC -999o250 DR:HOaFDC NFDC.FOC -999.250 CALI.FOC -999.250 :eRr- FDC NPH! .CNL -99i9r. 250 TNPH.. CNL -999. 250 TIeR A e C#L RCNT. CNL -9':99.25'0 RCFT. CNL -999.250 CN~TC ~ CNL CALZ. CNL -999'2 50 GR .CNL -999.250 TENS.C SG 4.190 910625 -999.250 -999'250 -999.250 -999.250 -999.250 5.021 86.563 -999.250 -999.250 -999.250 -999.250 -999. 250 3.916 99.188 -999.250 -999.25O -999.250 -999.250 -999.250 DE:PT. 3TO0.O00 TENS.D~L 1980.000 Z, LD*DXL 3..484 5 FLU. O! L 3 ol 95 SP. OIL -TT. 250 GR. D IL 93.813 DPNZ. FDC -999.250 RHOB, FDC -999..,250 DRHO.,FDC -99'9.'250 NFDC'POC -999.250 CALZ.,.FOC -999.250 ~GR.FOC -999.250 N.P HI.. C~IL -999.250 TNPH-CNL -999.250 'TNRAoCNL -999.'250 RCNToCNL -999.250 RCFT.CNL -999.25'0 C~TC.CNL -999.250 CALI..CNL -999.250 GR.CNL -999.250 TENS'CSG -999.250 DEPT. 3600.000 TENS.OIL 1985.000 ZLD.DZL Z'9~9 SFLU.OIL 3.6'15 SP.DZL -T6. 813 GR.DIL 94.063 DPHI PDC -999 250 RHOB FOC -999.250 OR,HO~FDC -999.250 * ' ' -999.250 NFDC.FDC -999.250 CALI.PDC -999.250 .GR.FDC NPH~.CNL -999.250 TNPH.CNL -999o250 TIIRA.CNL -999.250 RCNT.CNL -999.250 RCFT.CRL -999.250 CNTC.CNL -999.250 CALI.CNL -999, Z.50 GR,CNL -999.250 TENS.CSG -999.250 ILM.DIL TENS'FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILR.DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILH. DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC .CNL GR.CSG ILM.OIL TENS.FOC FFDC.FDC TENS.CNL NPOR.CNL C FT C. CNL GR.CSG IL~.D. IL TENS.FDC FFDC*FDC TENS.CNL NPORoCNL CFTC .CNL GR.CSG ILR.OIL T E N5. FDC FFOC .FDC TENS'CNL NPOR,CNL CFTC.CNL GR.CSG ILM. OIL TENS. FOC FFDC.FDC TENS .CNL NPOR.CNL CFTC. CNL GRoCSG PAGE: 10 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.388 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.919 -999.250 -999.250 -999.250 -999.250 -999°250 -999.250 4.825 -999.250 -999.250 -999o250 -999.250 -999-250 -999o250 3.T31 -999.250 -999 -999.250 -999.250 -999. 250 -999. 250 3.305 -999.250 -999o250 -999.250 -999.250 -999.250 -999.250 2.859 -999'250 -999.250 -999.250 -999.250 -999.250 -999..250 I;5, TAPE VER]:PTCATION L]:$T::[NG CHLUPlBERGER ALASKA CDHPUTING CENTER 20-APR-1989 12:12 PAGE: 11 DEPT. 3500°000 TENS.OIL 1995.000 ILDoDIL 5.345 SFLU. OIL 4.836 SP.DIL -81.188 GRoDLL 92.188 DPHi*.FDC -999.Z50 RHOB.FOC -999.250 DRHO.FDC -999.250 NFDC.FDC -999.250 CALI.FDC -999.250 GR.FOC -999.250 NPHT'CNL -999.250 TNPH.CNL -999.250 TNR&.CNL -999.250 RCNT.CNL -999°250 RCFT.CNL -999.250 CNTC.CNL -999.250 CALZ.CNL -999.250 GR.CNL -999.250 TENS.CSG 1955.000 DEPT. 3400.000 TENS.D]~L -999.250 5FLU.DXL -999. Z50 SP .DXL -999.2.50 DPHZ.FDC -999.250 RHOB. FDC -999.250 NFDCoPDC -999o250 CALI.FDC -999.250 NPHZ-CNL -999.250 TNPH.C#L -999-2511 RCNT.CNL -999.250 RCI:T.CNL -999.250 CAL[. CNL -999.250 GR.CNL -999. 250 DEPT. $ FLU:' D! L DPHZ, FDC NFDCeFDC ' NPH]L~CNL RCNTiCNL CALZ.CNL DEPT. SFLU.D[L O PH [~:' F O C NFDC' FOC NPHZ,CNL RCNT.CNL CALZ.CNL 3300.000 TENS.OIL -999. Z50 -999. 250 SP. O XL - 9990 250 -999. ZSO RHOB. FOC -999.250 -999.250 CALI.FDC -999.250 -999.250 TNPH. CNL -999.250 -999.2.50 RCFT.CNL -999.250 -999 o Z 50 O R. CNL - 99'9. Z 50 3Z00.000 TENS.DZL -999.250 SPoDIL -999o250 RHOB.FDC -999.250 CALi°FDC -999o250 TNPH'CNL -999'250 RCFT°CNL -999°250 GR.CNL -999.250 -9'99.250 -999.250 -999'2:50 -999.250 -999-250 -999.250 DEPT. 3100.000 TENS.OIL -999.250 SFLU'D~L -999.250 SP.DIL -999.250 DPHI.FDC -999.250 RHOBoFOC -999°250 NFDC.FDC -999'250 CALI.FOC -999.250 NPHI.~NL -999o250 TNPH'CNL -999.250 RCNT,CNL -999°250 RCFT.CNL --999.250 CALI'CNL -999o250 GRoCNL -999'250 DEPT. 300,0.000 TENS.OIL SPL'UoD~L -999.250 SPoDIL DPHZoFDC -999.250 RHOB.FOC NFDC.FDC -999.250 CALI°FOC NPH[.CNL -999°250 TNPHo'CNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999o250 GR°CNL DEPT. 2900°000 TENS.OIL SFLU.DIL -999.25:0 SP.DiL DPH~.PDC -999.250 RHOBoFDC NPDC.FDC -999.250 CALI.FOC NPH~°CNL -999o250 TNPHoCNL RCNToCNL -999.250 RCFToCNL -999.250 -999:°250 -999°250 -999.2S0 -999.250 -999°250 -999.250 -999°250 -999.250 -999°250 -999.250 -999.250 -999.25:0 IL G .DZL DRH '. FDC G .FOC TN~ t. CNL CNT . CNL TE~ ..CSG 1' ,DIL I. OIL Ol I,- F DC FOC ~-CNL CNL CSG OIL OIL FDC . FOC TN .CNL C NTt' C N L 'T E NS. C $ G :1: C:a. D:]:L GR' OIL ORHe'.~OC G~- FOC TN~.CNL~ CNT~o C NL T E N'$,' C $ G ~LD. DZL G'R ° D I L DRH~O,FDC GR' FDC T N e:a. C NL CNTC.CNL -999.250 -999'.250 -999.250 -999.250 -999.250 -999.251) 1980.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1940.000 -999.250 -99'9.250 -999°250 -999.250 -999.250 -999.250 1900°000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 180.0:.000 --999.250 --999.250 --999.250 -999.250 -999. 250 -999.250 1750.000 -999.250 -999.250 -999.250 -999.250 -999.250 --999.250 ILM.DIL TENS.FDC FFDC.FDC TENS°CNL NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.FDC FFDC.FDC TENS.CNL NPORoCNL CFTC.CNL GR.CSG IL~.DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTCLCNL GR'CSG ILM.DIL TENS. FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.FDC FFDC..FDC TENS.CNL NPOR°CNL CFTC.CNL GR.CSG ILM. DIL TENS.FDC FFOC.FDC TENS.CNL NPOR'°CNL CFTC.CNL GRoCSG ILM.OIL TENS.FOe FFOC.FDC TENS.CNL NPOR.CNL CFTC.CNL 5.124 -999.250 -999.250 -999.250 -999.250 -999.2S0 82.813 -999.250 -999°250 -999.250 -999.250 -999°250 -999.250 56.469 -999°250 -999'250 -999.250 -999.250 -999.250 -999.250 49.406 -999°250 -999°250 -999.250 -999.250 -999.250 -999°250 56.906 -999°250 -999.250 -999.250 -999.250 -999.250 -999°250 63.438 -.999.250 -999.250 -999°250 -999.250 -999°250 -999°250 52.594 -999°250 -999°250 -999.250 .. -999.250 -999.250 -999°250 IS TAPE VERIFICATION LISTING CHLUNBERGER ALASKA COMPUTING CENTER CAL~.CNL -999.250 6RoCNL 20-APR-Z989 1Z:IZ -999.250 TENS.CSG 1670.000 DEPT. 2800.000 TENS.OIL -999.250 ILDoDIL -999.250 SFLUoDXL -999° 250 SP.DIL -999o250 GR.DZL -999.250 DPHZ.FDC -999o250 RHOBoFDC -999*'250 DRHO.FDC -999.250 NFDCoFDC -999.250 CALI.FDC -999. Z50 GR.FDC -999'250 NPHZ.CNL -999.250 TNPH.CNL -999. 250 T#RAoCNL -999.250 RCNT.CNL -999.250 RCFT.CNL -999.250 C#TC.CNL -999.250 CALI.CNL -999.250 GR.CNL -999.250 TENS°CSG 1585.000 DEPT. Z700.000 TENS.OIL -999.250 5FLU. DIL -999. Z 50 SP. OIL -999.250 DPHZ.FOC -999.250 RHOB.FDC -999.250 NFOC. FDC -99,9,. 250 CAL! o FDC - 9,99. 250 NPH/. CNL -999,, 250 TNPH. C NL 999. 250 RCNT.CNL -999.250 RCFT.CNL -999. C AL !. CNL -999.250 GR. CNL -99'9.250 DEPT. 2600o 000 TENS .DIL -999. 250 S FLU. ~L -999.250 SPo DIL -999° 250 DPHZ.~DC -999.250 RHOB.FDC -999.250 NFDC. FDC -999.250 CALI.FDC -999o250 NPHZ oCNL -999. 250 TNPHo CNL -999.250 RCNT.CNL -999* 250 RCFT o CNL -999. 250 C AL !. CNL -999 o 250 GR .C#L - 999.250 2500.000 TENS,OIL -9'99.250 -999.250 SPoDZL -999.250 -999.250 RHOB.FDC -999.250 -999.250 CALI'FDC -999.25'0 -999,250 TNPH. CNL -999o250 -999o250 RCFToCNL -999.250 -999°250 GRoCNL -999°250 DEPT. S FLUoD!L DPH! NFDC"~DC NPH~oCNL RCNT.CNL CALI.CNL Z400.O00 TENS°DIL -999.250 -999. 250 S P o DZL -9,99.250 -999.250 RHOB°FDC -999.250 -999.250 CALI.FOC -999.250 -999.250 TNPH. CNL -999.250 -999.250 RCFT.CNL -999,250 - 999.250 GR. CNL - 999. Z 50 DEPT, S FL ti. O ! L D PH ! ,, FDC NFDC'~DC NPH]r,"CNL RCNT, CNL CALI'.CNL 2300,000 TENS.OIL -999.250 -999. Z 50 SP. OIL -9991250 -999.250 RHOBoFOC -999.250 -999o250 CALI.FDC -999. 250 -999.250 TNPH'CNL -999.250 -999.250 RCFT*CNL -999.250 -999. Z 50 GR oCNL - 999.'Z 50 DEPT,,, S,'FLU. OIL DPHZ' FDC NFDCo, FOC NPH!'CNL RCNT-CNL CALZ.CNL I, LDoDZL GR,,DZL DRHOo FDC ~LD. DZL :L GR '#'C CNL TEN S ' C S G ZLDeDZL *:GRLDIL DRHO, F DC 'i.' G R. FDC T#RA.CNL C#TC'CNL TENS*,CSG iGR-DIL FDC T SO i:LD.DIL GR.OZL D RH O. F DC ":GRoFDC TNRA.CNL C#TC.CNL TENSoCSG ZLD.DZL GR ..'OIL ORHO, FDC GR.FDC TNRA.CNL DEPT. 2200.000 TENS.OIL -999.250 SFLU. D,~L -999. Z 50 'SP.OZL -999. Z 50 DPHZ.FDC -999°250 ~HOB.FOC -999.250 NFDC°PDC -999.250 CALI.FDC -999.250 ' NPHZ,CNL -999.250 TNPHoCNL -99'9.25:0 -999.250 -999.250 -999.250 -999.250 -9'99. 250 -999.250 1560.000 -999o250 -999.250 -999.250 -999.250 -999.250 -999.250 1500.000 -999.250 -999.250 -999.250 -999°250 -999.250 -999o250 1430.000 -999.250 -999.250 -999..25O -999.250 -999.250 -999.250 1380.0'00 -999.250 -999.250 -999~250 -999.250 -999°250 -999.250 1340.000 -999.250 -999.250 -999.250 -999.250 -99-9.250 GR.CSG ZLM°DIL TENSoFDC FFOC.FDC TENS.CNL NPOR.CNL CFTC.CNL GRoCSG ILN. DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG IL~.DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM. DIL TENS.FDC FFDC.FOC TENS.CNL NPOR'-CNL CFTC.CNL GR.CSG TEN S. FOC FFDC. FOC TENS.CNL NPOR. CNL CFTC. CNL GR.CSG ILN. DIL TENSoFOC FFDC.FDC TE'NS.CNL NPOR.CNL CFTCoCNL GR.CSG ZLMoDIL TENSoFDC FFDCoFDC TENSoCNL NPORoCNL PAGE: 12 42.906 -999°250 -999.250 -999.250 -999.250 -999.250 -999o250 52.938 -999.250 -999.250 -999°250 -999.250 -999.250 -999.250 35.063 -999.250 -999.250 -999.250 -999.250 -999o250 -999°250 ~9o063 -999.250 -999°250 -999.250 -999°250 -999.250 -999.250 Z5°766 -999°250 -999.250 -999.2,50 -999o250 -999.-250 -999o250 37.375 -999.,250 -999:.250 -999.250 -999°250 -999.250 -999.250 34.500 -999.250 -999°250 -999.25.0 -999.250 -999.250 TAPE VERXFICATION LISTZNG CHLUMBERGER ALASKA COMPUTING CENTER RCNT.CNL -999.250 RCFToCNL CAL!*CNL -999.250 GR' CNL DEPT. SFLU*OZL DPH! oFDC NFDCoFOC NPHX.C, NL RCNT.CNL ' CALZoCNL DEPT, SFLU, DZL DPHZ.PDC NFDC. FDC NPH!. CNL RCNToCNL C ALZ.CNL DEPT. SFLU'DZL O PH!.'FDC N F D C o'F D C NPH [~gCNL R C#TL'C NL CALI,CNL D E P T, .: SFLUoDZL DPHZ,FDC NFDC."FOC NPHZ*CNL R CNT',CNL CALZ.CNL DEPT. 5FLU*OZL DPHI° FDC NFDC ~'FOC NPH~:.CNL R CNT° C N L CALZoCNL 20-APR-1989 12:12 -999.250 CNTC.CNL -999.250 TENSoCSG ZIO0oOQO TENS.DZL -999.Z50 -999.250 SP.DZL -999.250 -999.250 RHOB.FDC -999.250 -999.250 C&LZoFDC -999.250~ -999.250 TNPHoCNL -999o250 -999.250 RCFT.CNL -999.250 -999.250 GR.CNL -999.250 2000.000 TEHS°DZL -999.250 -999.250 SP. DZL -999. Z50 -999,250 RHOB.FDC -999.250 -999'250 CALZ°FDC -999.250 -999.25tt TNPHoC#L --999.250 -999°250 RCFT~CNL -999.250 -999.250 GR .CML -999.250 190'0o000 TEN$.DZL -999.250 SP.DZL -999o250 RHOB.FDC -999.250' CALZ.FDC -999.250 TNPHoCHL -999.250 RCFT'CHL -999°250 GR.CNL -999.250 -999.25'0, -999.250 -99'9.258 -999.250 -999.250 1800o000 TENSoDZL -999o250 -999. Z ~. SP.OZL - 999' 250 -999.250 RHOBoFDC -999.250 -9'990250 CALI'FDC -999o250 -9990250 TNPHoCNL -999.250 -99'9o250 RCFT.CNL -999.250 -9990 250 GRoCNL -999.250 1700.000 TENS.DZL -999.250 -999.'250 SP.OZL -999.250 -9'99 250 Ri-lOB. FDC - 99'0' ZSO -999'. 2 50 C'A'LX. FOC -99'9'2'50 -999°Z50 TNPH. CNL -999.250 -999.250 RCFT.CNL -999'250 ZLD.DTL GR.DXL DR HQo FDC GR. FOC TNR&.CNL CNTC.CNL TE#$.CSG ZI DXL Z.DXL FDC FDC TN! CNL CNL T .CSG ! ,~DXL DR I. FDC .FDC .CNL C .CNL TI ~CSG X~,:DXL ' FDC TN~:CNL CN~.'CNL TE~SoCSG DEPT. 1600'.000 TENS.DXL -999.25.0 SFLU. DX L -999. Z 50 SP ° OZL - 999L~250 DPHT° F'DC -999.250 RHOB ° FDC - 999'~250 NFDC° PDC -999*250 CALZ, FOC -9991;250 NPHZoCNL -999.250 TNPH°CNL -999. 250 RCNT.CNL -999o250 RCFT.CNL -999.250 CALX°CNL -9990250 GRoCNL -999.250 TE#S. CSG DE, PT. 1500.000 TEN$.D~L .-999'250 XLDiDIL $ FLU.'DX L -999.250 SP o DZL -999.250 GR. DZL DPHX.FDC -999.250 RHOB°F'OC -999.250 DRHO. FOC NFDC.FDC -999o250 CALZ.FDC --999. 250 GRo;FDC -999.250 12950000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 12550000 -9990250 -999.250 -999.250 -9990250 -999.250 -999.250 121'50000 -999.250 -999.250 -9990250 -999.250 - 99 9.2 50 -999.250 1165.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1135°000 -999.250 -999.250 -9990250 -999.250 -999.250 -999.250 1100.000 -999. 250 -999-250 -999.250 -999.250 -999.250 -999.250 1045. 000 -999.250 -999.250 -999.250 -999.250 CFTCoCNL GR.CSG ZLMoDZL TENS.FDC FFDCoFDC TENS.CNL NPORoCNL CFTC.CNL GRoCSG [LM.DZL TENS.FDC FFDCoFDC TENS .CNL NPOR ° CNL CFTCoCNL GRoCSG XLM.DXL TENS°FDC FFDC.FDC TEN S 0 CNL NPORoCNL CFTC oCNL GR.CSG ILR.DIL TEN S. FDC FFDC'FDC TENS. CNL NPORoCNL CFTCoCNL GR °CSG ILM..OIL TENS.FDC FFDC.FDC TENSoCNL NPOR.CNL CFTC.CNL GRoCSG TENSoFDC FFDC.FDC TENSoCNL NPOR.CNL CFTCoCNL GR.CSG [LNoDZL TENS. FDC FFDC.FDC T~NSoCNL PAGE: 13 -999°25O 2To703 -9990250 -9990250 -9990250 -999o250 -999.250 -9990250 31°750 -999o250 -999.250 -999.250 -999.250 -999.,250 -999.250 42 °375 -9990250 -999.250 -999.250 -999°250 -999°250 -9990250 ZB.gZZ -999. Z 50 -999°250 -999'250 -999.250 -9990 -999°2 50 ~.1 °469 -999o250 -999° 250 -9'99 ° 250 -999o250 -999.250 -999. 250 ~8.87'5 -999°250 -999.2'50 -999.250 -999°250 -999.250 -999.250 35.313 -999.25'0 -999°250 -999°250 -999°250 IS TAPE VERIFICATION LISTING CHLUNBERGER ALASKA COMPUTING CENTER ZO-APR-1989 1Z:IZ NPHI.CNL -999.250 TNPH.CNL -999'250 RCNT'CNL -999.250 RCFT.CNL -999. 250 CALZo CNL -999. Z 50 GR. CNL -999. 250 DEPT. 1400.000 TENS.OIL -999.250 S FLtl. DIL -999. Z 50 SP. OIL -999. 250 DPH'Z,PDC -999.250 RHOB.FDC -999'250 NFDC.FDC -999.250 CALI.FDC -999.250 NPtlZ.C#L -999.250 TNPH. CNL -999,.250 'RCNT.CNL -999.250 RCFT.CNL -999'250 CAL!.CNL -999. Z 50 GR .CNL -999.250 1300.000 TENS. DZL -999. 250 SP. OIL -999.250 RHOB. FDC -999.2'50 CAL!'FDC -999.Z50 TNPH.CNL -999. 250 RCFT. CNL -999.250 GR.CNL DEPT. SFLU. DZL DPHI. FDC NFDC. PDC NPH]Eo RCNT.CNL C AL ! ' CNL 1200'000 TENS.OIL -999 .Z$O SP . D':]:L -999. 250 RNOB. F'DC -999.250 CALZ.FDC -999. 250 TNPHoCNL -999.250 RCFT.CNL -999.250 GR.CNL DEPT. SFLU. DZL DPHI.FOC NFDC.FDC NPHZ.CNL RCNT. CNL CALZ.CNL -999.250 -999.. 250 -999"250 -999. - 999. ZSO -999.250 - 999. Z$O DEPT. SFLU.DZL DPH:[' FDC N FDC. FDC NPH! .CNL RCNT.CNL C AL 'T. C'NL -999.250 - 99.9.250 -999.250 -999.250 -999.250 - 999. 250 -999'.250 DEPT. 5FLU. OZL DPHZ.,FDC NFDC. FDC NPHI' CNL RCNToCNL CALZ.CNL 1!00.000 TENS. Or.]~L -999.250 -999.Z 50 SP. OZs.. -999. 250 -999,.250 RHOB.FDC -999.250 -999-250 CALZ.FDC -999.250 -999.2.50 TNPH. CNL -999.250 -999.250 RCFT.CNL -999.250 -999 · Z 50 GR.CNL - 999.250 DEPT. 5FLU.OIL DPHZ.FDC NFDC. FDC NPH~.CNL RCNT. CNL CALI.CNL 1000'000 TENS.OIL --999. 250 -999. ZSO SP. OIL -999. 250 -999.250 RHOBoFOC -999.250 -999.250 CALIoFDC -99~' 250 -999.250 TNPH.CNL -999. -999.250 RCFT.CNL -999.250 -999 o Z 50 GR. CNL - 999, Z 50 934-000' TENS.OIL -999.250 -999. 250 SP. O IL - 999.250 -999.250 RHOB.FOC -99.9.250 -999.250 CALZ.FOC -999.250 -999-250 TNPH.CNL -999.250 -999.250 R'CFT.CNL -999.250 -999. 250 GR... CNL - 999.250 TNRA.CNL CNTC. CNL TENS.CSG ZLD.DIL GR.DZL DRH 0 - F DC GR.FDC T NR A. C N L C:~C.CNL TENS'C SG ZLD.DZL GR.DZL O RH O. F DC G R. FDC T~A.CNL CII;TC.CNL TENS'CSG ZLD.DZL GR.OIL DRHO, GR.FDC T MR ~. C N L CilTC..CNL TENS;CSG ZI.D'DIL DR140 ,~ FDC GR.FDC T~RA.CNL CMTC.CNL TENS. C SG · ILO- OZL GRIDIL DRHO., FDC GR.FDC T NR A. C NL C#:TC, C NL TENS. C SG ZLD.OTL GR'DZL O R HO' F DC GR.FDC T~RA. CNL CRT C. C NL TENS.CSG -999o250 -999.250 1010.000 ' -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 970.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 93 5.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 890.000 -999.250 -999.250 -99 9.. 250 -999.250 -999.25.0 -999.250 845.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 820.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 780.000 NPORoCNL CFTC.CNL GR.CSG ILM.DIL TENS.FDC FFDC. FDC TENS.CNL NPOR. CNL · CFTC. CNL GR °CSG ZLM.DZL TENS. FDC FFDC. FDC TENS.CNL NPOR.CNL CFTC .CNL GR.CSG ILM.OIL TEN S. FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR .CSG IL)I.OIL - TENS.FDC F FDC. FO C TENS.CNL NPOR .CNL CFTC.CNL GR.CSG ILM. DIL TENS.FDC FFOC. FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILMoDIL TEN S. FOC FFDC .FDC TENS .CNL NPOR.CNL CFTC.CNL GR .CSG PAGE: 14 -999.250 -999.250 29.T81 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ZS.422 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5Z.438 -999.250 -999..250 -999. -999.250 -999.250 -999.250 48'344 -999.250 -999. Z 50 -999.250 -999o250 -999.250 -999o250 35.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 Z6.031 -999.250 -999.250 -999.250 -999.250 -999.25'0 -999°250 45.219 END OF DATA IS TAPE VERIFICATION LISTING CHLUMBER*GER ALASKA COMPUTING CENTER ZO-APR-1989 12:12 15 · ~t FILE TRAILER FILE NAME : EDIT .001 SERVXCE : FLIC VERSXON : O01AOZ DATE : 89/04~/Z0 MAX REC SIZE : 1096 F~LE TYPE : LO LAST' FILE · *~ FILE HEADER ~r~ FILE 'NAME : EDIT .002 SERVICE : FLZC VERSZON ". O0},'A02 DATE : 89~0~/20 MAX eec SIZE : XO~6 FILE'L*TYPE : LO'*,~ LAST FILE : ~~ THIS DATA' HAS NOT BEEN DEPTH SH~'FTEO - oV~LAYS FIELD PRZNTS ~~ SCHLUMBERGER LOGS INCLUDED gZTH THIS ,E (EDZT.O02): (SEE FILE EDZT.OOZ FOR 6~ SAMPLED fCNL/GR DATA)* FORMAT/ON DENSITY COMPENSATED LOG (:-FDH) FIRST TO LAST REAO~NG: 70S6'~ TO 638Ze COMPENSATED NEUTRON LOG C.CNH) FIRST TO LAST READING: 70~1~ TO 638Ze TABLE TYPE : CONS TUN! CN FN NN NATI STAT: COUN VALU DEFI ARCO ALASKA /NC. COMPANY NAME KUPARUK FIELD NAHE 3 Z-6 gELL NAME USA NATZON' ALASKA STATE OR PROVINCE NORTH SLOPE COUNTY ::[,5 TAPE VER:I:FICATXON LTSTING CHLUMBERGER ALASKA COIqPUTING CENTER ZO-APR-1989 12:12 PAGE: 16 TUNT VALU DEF]: FL Z6Z' FSL, 85' FML SECT 31 TOMH 13N' RANG 9E ENG! PRITZKE SON 548353 APIN 50-029*-21935 FXELD LOCAT/ON SECT/ON TOWNSHIP RANGE ENGXNEER'S NARE SERVICE ORDER NURBER AP! SERIAL NUHBER FFDC NFOC CALX GR TENS NPHZ TNPH TNRA NPOR RCNT RCFT CNTC CFTC CALI : · GR TABLE TYPE : CURV DEF:[ DEPT DE'PTH CHANNEL HARE TENS TENSZON RHOB BUL; DENSZTY DRHO, DE'LT A~ RHO FAR FDC COUNT RATE NEAR FDC COUNT RATE CALZPER GAHHA RAY NEUT;RON ~ POROSITY THERRAL NEURON POROS/TY CALXBRATED THERHAL NEUTRON RATXO NEUTRON PDROSX'TY OU~UT FROM AN APPLXCATZON ,PROGRAH RAM CORRE T'E'D'" N, EAR'THERHAL~' COUNTS RA ~, CORR E T EDco'FA R THER HAL "COUNTS CORRECTED HEAR *THERMAL 'COUNTS CORRECTED FAR THERHAL COUNTS C A-L ] P ER 6;A*H~ A RAY DATA FORRAT SPECIFICATION RECORD SET TYPE - 64EB ~0 , TYPE REPR CODE VALUE 1 66 0 Z 66 0 3 T3 76 6 66 1 5 66 6 73 7 65 8 68 0.099 9 65; FT IS TAPE VERIFICATION L%STING ~CHLUMBERGER ALASKA CO~IPUTING* CENTER 20-APR-1989 12:12 PAGE: 17 TYPE REPR CODE VALUE 11 66 14 1Z 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 NAME SERV UNIT SER¥%CE API AP% AP% API FILE NU#i NUMB SIZE REPR PROCESS ORDER g LOG TYPE CLASS ROD NUMB SAM~: ELEM CODE CHEX) OEPT FT 548353 O0 00,0 O0 0 2 I "/ I 4 68 O000OO0000 TENS *"FDH LB 548353 O0 OOO O0 0 Z I I ~, 68 O00000OO00 RHOB 'FDH G/C3: 54,83'5]* O0 000 O0 0 2 I !*': I 4 DRHO FDH G/C3 548353~ O0 000 O0 0 Z I I 4 FFDC FDH CPS 548353' O0 OOO O0 0 Z I I 4 NFDC FDH CPS 5483531 O0 000 O0 0 2 I I 4 CALI FDH IN 548353' ** OD 000 O0 0 2 I I 4 GR FDH GAPI 548353 O0 OOO O0 0 g I I 4 TENS CNH LB 548353 O0 000 O0 0 2 I I 4 NPH! CNH PU 548353 O0 000 O0 0 2 1 I 4 TNPH CHH- PU 548353 O0 000 O0 0 2 I I 41, TNRA /CNH 54835'3 O0 000 O0 0 ~Z I 1 4 NPOR CNH PU 548353' O0 000 O0 0 2 I 1 4 RCNT CNN CPS 548353 O0 000 O0 0 2 I I 4 RCFT CNH CPS 54835'3 O0 000 O0 0 Z I I 4 CNTC CNH CP'S 548353 O0 000 O0 0 2 ! I 4 CFTC CNH CPS, ' 5483'5ii3 O0 00'0 O0 0 Z I I 4 CALI' CNH IN 548353 O0 000 O0 0 2 I I 4 GR CHH GAPI 548353 O0 000 O0 0 Z I I 4 68 0000000000 68 O0000OOOO0 68 0.000000000 68 0000000LO%OO 68 0000000000 68 0000000000 68 000'0000000 68 0000000000 68 0000000000 68 0000000000 68 OOOO000000 6 8 0OOOOOOOOO 68 O000O'O0000 68 0000000000 68 000000 Or 000 68 0000000000 68 0000000000 , t~ DATA DEPT. 7095.899 TENS.FOH 2640~000 FOH Z.305 DRHO.FDH FFDC.FDH 88Z.000 NFDC.FDH 796,500 FOH 7.047 GR.FDH T'ENS.CNH Z64,0.000 NPHI.CNH 39.041 CNH 36°666 TNRA.CNH NPOR.CNH 36°666 RCNT.CNH 1942.Z3z~ RC .CNH 586.018 CNTC.CNH CFTCoCNH 641 o910 CALI.CNH 7.047 oCNH 105.Z50 DEPTo 7000.000 TENS.FOH 3864.000 RH[~B. FDH 2.44Z DRHO. FDH PFDC.FDH 46Z.000 NFDC.FOH 5470500 CA[~ioFDH 80977 GRoFDH TENSoCNH 3864.000 NPHI.CNH 35.310 TNPH.CNH 33°692 TNRA.CNH NPOR.CNH 33. 232 RCNToCNH 1971.441 RCFT.CNH 623°490 CNTC.CHH CFTC.CNH 694.850 CAL%oCNH 8.977 GR.CNH 96.875 0.121 105.250 3.169 2001o058 -0.005 96.875 3.108 2049.788 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER DEPT. 6900o000 TEN$.FDH PFDC.FDH 5Z~.500 NFDCoFDH TENS.CHH 3680.000 NPHI.CNH NPORoCNH 44.770 RENT.CHH CFTC.CHH 5ZZ.847 CALI.CNH DEPT. 6800°000 TEN$.FDH FFDC.FDH 601.500 NFDC.FDH TENS.CHH 34Z0.000 NPHZo'CHH NPOR.CNH 31.?75 RENT.CHH CFTC'CNH 839.718 CALI.CNH DEPT. FFDC.FDH TE#$ICNH NPOR.CNH CFTC.CHH 6700.000 TENS.FOH 436°750 NFDCoFOM 3670.0'00' NPHX.CNH 3Z.~75 RENT.CHH 737o033 CALI.CNH DEPT. FFDC.FDH TENS.CHH NPORiCNH CFTCiCNH 6600°000 TENS-FOH 603'500 NFOC.FDH 3484.000 HPHI.CNH 41.g65 RCNT.CNH 496.991 CALI.CNH D E:PT.. FFDC-FDH TENS.CHH NPOR.CNH CFTCoCNH 6500.000 TENS.FDH 582:.500 NFDC.FOH 342:4.000 NPHI'.CNH 43.695 RCNT.CHH 483.961 CALI.CHH DEPT.. FFDCIFDH TENS,.CNH NPOR.CNH CFTC'CNH 20-APR-1989 1Z:IZ DEPT. FFDC.FDH TENS.CHH NPOR. CNH CFTCoCNH 3680.000 RHOB.FOH 607.500 CALI.FDH 43.234 TNPH.CNH 1655.696 RCFT.CNH 9.3Z0 GR.CNH 34Z0.000 RHOB.FDH 628.000 CA:LI. FDH 31o34Z TNPHoCNH 2313.021 RCFT.CNH 8.6Z5 GR.CHH 3670.00'0 RMOB.FDH 570.500 CALI.FDH 32.837 T#PH. CNH 2069.164 RCFT.CNM 9.117 GR.CHH 3484.000 R#OB.FDH 616.500 CALI.FDH 44.&39 TNPHoCHH 1768.958 RCFT.CNH 9.703 GR.CHH 34 Z4.000 RH O B. F DH 629.000 CALI.FDH 46.133 TRPH' CHH 1621.Z15 RCFT.CNH 9.641 GR.CNH 6400.000 TENS.FOH 3484.000 RHOB.FDH 526.500 NFOC.FOH 6Z0.500 CALIoFDH 34*84.000 NPHZ.CNH 4.4.32Z T#PH. CHH 43.765 RCNT.CNH 1640.981 RCFToCHH 470.106 CALZoCNH 10.305 GR.CNH 6381.300 TENS.FOH 567.000 NFDC.FDH 34.50.000 NPHZ.CNH 43.864 RCNT.CNH 494.2:56 CALI.CNH END OF DATA 34'5,0. 000 RHOB. FDH 605.000 C'J~L]:. FOH 4,4.864* TNPH;'CNH 172:6.50Z RCFT.CHH 10.359 GR.CNH PAGE: 18 Z.421 DRHO.FDH 0.026 9.320 GR.FDH 88.938 4*3.022 TNRA.CNH 3.569 471.54Z CNTC.CNH 1857.090 88.938 2.361 DRHOoFDH 0.021 8.625 GR.FDH 70.313 31.590 TNRA.CNH 2.839 787.588 CNTC.CNH 2349.833 70.313 2.4*90 DRHO.FDH OoOZ1 9.117 GRoFDH 91.500 33.507 TNRA.CNH 2.979 764.104 CNTCoCNH Z170.147 91.500 2.349 DRHOoFDH 0.010 9.703 GR.FDH 101.375 4.2.172 TNRA.CNH 3.666 4*99.948 CNTC.CNH 1747.421 101.375 Z.381 DRHOoFDH O.OZ8 9.64.1 GR.FDH 131.250 4&o588 TNRA.CNH 3.753 397.635 CNTC.CNH 177Z.04.8 131.250 2.433 DRHO.FDH 0.039 10.305 GR.FDH 101.188 44.3,46 TNRA.CNH 3.709 444.111 CNTC.CNH 17Z6.996 101.188 Z.. 374 ORHO.FDH O. 010 10.359 GR.FDH 1ZZ.1Z5 42.885 TNRfl. CNH 3.743 401.440 CNTC.CNH 177Z.746 1Z2.125 IS TAPE VERIFICATION LISTING 20-APR-1989 1Z:12 CHLU~BERGER ALASKA CO~qPUTI:NG CENTER ~ftt ~ FILE TRAILER FILE NARE : EDIT .OOZ SERVICE : FCIC VERSION : O01AOZ DATE : 89/04/Z0 ~AX REC SIZE : 1096 FILE 'TYPE : LO LAST 'FILE PAGE:' 19 ~$~ TAPE TRAILER SERVICE NANE :* EDIT DATE : 89/04/Z0 I;] R IGT. N~' : FLZC T~PE N~RE : 73Z90 CONTINUATION ~ : 1 PREVIOUS TAPE : CO~ENT : ARCO~ SERVICE NA#E : EDIT DATE : 89/04~/Z0 ORIGIN : FCiC REEL NAHE : 73290 CONTINUATION ~ :' P:REVXOUS REEL C O ~ H E NT : ARCOs KUPARUK. 3 I"-Gt API ~50-ozg-Z1935