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Home My WebLink About185-014Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 7/1/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240701 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 19RD 50133205790100 219188 6/24/2024 AK E-LINE SetPlug/Cement MPU C-08 50029212770000 185014 6/23/2024 AK E-LINE Leak Point Survey MRU M-34 50733206260000 214027 6/25/2024 AK E-LINE Tubing Punch Revision Explanation: There are additional images added to the final report and a few new .las files. In the Emeraude folder there are 2 new .las files and in the Field Data folder the RIH and POOH are new .las files Please include current contact information if different from above. T39100 T39101 T39102 MPU C-08 50029212770000 185014 6/23/2024 AK E-LINE Leak Point Survey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.01 12:56:17 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector MPC-08 (PTD# 1850140) Failed MIT-IA Date:Tuesday, September 5, 2023 8:30:53 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, September 1, 2023 11:35 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: Injector MPC-08 (PTD# 1850140) Failed MIT-IA Mr. Wallace, On 9/1/2023 WAG injector MPC-08 (PTD# 1850140) failed an MIT-IA to 3500 psi during the under evaluation monitoring period. The well is now classified as NOT OPERABLE and will be shut in until well barriers are restored with a passing MIT-IA. Please respond if there are any additional questions. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, August 4, 2023 1:43 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: UNDER EVALUATION: Injector MPC-08 (PTD# 185-014) Anomalous IA Pressure Mr. Wallace, MPC-08 (PTD# 185-014) went under evaluation on 7/11/23. The well passed a PPPOT-T on 7/12/23. During our monitoring period injection rates have been variable and the well temporarily shut in during a field shutdown. Per our conversation we will role the clock for an additional 28 days of monitor starting on 8/8/23. Attached is the 30 day TIO. Please respond if there are any additional questions. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, July 11, 2023 3:58 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: Injector MPC-08 (PTD# 185-014) Anomalous IA Pressure Mr. Wallace, WAG Injector MPC-08 (PTD# 185-014) Inner Annulus was bled on 7/5/2023 from 1950 psi to 1000 psi. The well has now risen to 1480 psi indicating possible TxIA communication though injection rates have been variable and the increased IA pressure could be due to thermal changes in the well. The well recently passed a witnessed MIT-IA to 2093 psi on 5/27/23. The well is now classified as UNDER EVALUATION and is on a 28-day clock for diagnostics and resolution. The well will remain online during initial diagnostics. Plan Forward: 1. Monitor 2. PPPOT-T Please respond if there are any additional questions. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector MPC-08 (PTD# 185-014) Anomalous IA Pressure Date:Tuesday, August 8, 2023 8:40:28 AM Attachments:MPC-08 TIO.docx From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, August 4, 2023 1:43 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: UNDER EVALUATION: Injector MPC-08 (PTD# 185-014) Anomalous IA Pressure Mr. Wallace, MPC-08 (PTD# 185-014) went under evaluation on 7/11/23. The well passed a PPPOT-T on 7/12/23. During our monitoring period injection rates have been variable and the well temporarily shut in during a field shutdown. Per our conversation we will role the clock for an additional 28 days of monitor starting on 8/8/23. Attached is the 30 day TIO. Please respond if there are any additional questions. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, July 11, 2023 3:58 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: Injector MPC-08 (PTD# 185-014) Anomalous IA Pressure Mr. Wallace, WAG Injector MPC-08 (PTD# 185-014) Inner Annulus was bled on 7/5/2023 from 1950 psi to 1000 psi. The well has now risen to 1480 psi indicating possible TxIA communication though injection rates have been variable and the increased IA pressure could be due to thermal changes in the well. The well recently passed a witnessed MIT-IA to 2093 psi on 5/27/23. The well is now classified as UNDER EVALUATION and is on a 28-day clock for diagnostics and resolution. The well will remain online during initial diagnostics. Plan Forward: 1. Monitor 2. PPPOT-T Please respond if there are any additional questions. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector MPC-08 (PTD# 185-014) Anomalous IA Pressure Date:Tuesday, July 11, 2023 4:03:35 PM Attachments:MPC-08 Under Evaluation TIO_Schematic.docx From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, July 11, 2023 3:58 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: Injector MPC-08 (PTD# 185-014) Anomalous IA Pressure Mr. Wallace, WAG Injector MPC-08 (PTD# 185-014) Inner Annulus was bled on 7/5/2023 from 1950 psi to 1000 psi. The well has now risen to 1480 psi indicating possible TxIA communication though injection rates have been variable and the increased IA pressure could be due to thermal changes in the well. The well recently passed a witnessed MIT-IA to 2093 psi on 5/27/23. The well is now classified as UNDER EVALUATION and is on a 28-day clock for diagnostics and resolution. The well will remain online during initial diagnostics. Plan Forward: 1. Monitor 2. PPPOT-T Please respond if there are any additional questions. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 25, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC C-08 MILNE PT UNIT C-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2023 C-08 50-029-21277-00-00 185-014-0 G SPT 6640 1850140 1660 4393 4395 4396 4396 0 0 0 0 4YRTST P Adam Earl 5/27/2023 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT C-08 Inspection Date: Tubing OA Packer Depth 693 2198 2110 2093IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230531194136 BBL Pumped:5 BBL Returned:3 Tuesday, July 25, 2023 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg qq DATE: Wednesday, May 29, 2019 e�%l S,v/ 1� SUBJECT: Mechanical Integrity Tests P.I. Supervisor I r I g tY HILCORP ALASKA LLC C-08 FROM: Brian Bixby MILNE PT UNIT C-08 Petroleum Inspector Sre: Inspector Reviewed B-%7'7 P.I. Supry NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT C-08 Insp Num: mitBDB190528113215 Rel Insp Num: API Well Number 50-029-21277-00-00 Inspector Name: Brian Bixby Permit Number: 185-014-0 Inspection Date: 5/28/2019 ' Well C-08 PTD 1850140 BBL Pumped: Packer Type lnj w T� Type Test SPT Test psi 08 - BBL Returned: Depth Pretest Tubing 2447 ]A 1048 OA 0 Initial 15 Min 30 Min 45 Min 60 Min 2447 111. 2446 1910 H3� 1345 0 --__ 0 _.._ o. 6640 1660 0.8--- Interval 4YRTST P/F Notes: P Wednesday, May 29, 2019 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg / r DATE: Thursday,June 04,2015 P.I.Supervisor . l lj 6!"I/ SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC C-08 FROM: Jeff Jones MILNE PT UNIT KR C-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR C-08 API Well Number 50-029-21277-00-00 Inspector Name: Jeff Jones Permit Number: 185-014-0 Inspection Date: 5/5/2015 Insp Num: mitJJ150505154717 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well c-osiType In j G TVD 6640 TTubing 3514 r 3514 -! 3513 -7 3513 - PTD 1850140 - Type Testi SPT Test psi 1660 IA 561 2182 - 2098 2073 Interval OTHER P/F P .- OA 11 11 - 11 - 11 Notes: 1 8 BBLS diesel pumped. I well inspected,no exceptions noted - SCANNED JL .1 3 ZU'1 Thursday,June 04,2015 Page 1 of 1 Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday,April 30, 2015 7:28 AM To: Wallace, Chris D (DOA); Regg,James B (DOA) Cc: Chris Kanyer;Alaska NS - Milne - Field Foreman;Alaska NS - Milne - Wellsite Supervisors Subject: Injector MPC-08 (PTD# 1850140) Ready For Injection Attachments: image001 jpg All, Injector MPC-08(PTD# 1850140) had a passing pre MIT-IA on 2/17/2015 but was unable to brought on injection long enough for stabilization and was subsequently shut-in. MPC-08 had another passing pre MIT-IA on 4-29-15 and is now ready to return to injection for stabilization and compliance testing. Plan Forward - Milne Operations 1) Place well on injection. Use caution,annuli are fluid packed. 2) AOGCC MIT-IA when well is on injection and thermally stable. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com SCANNED MAY 0 4 2015 3800 Centerpoint Drive, Suite 1400 I Anchorage,AK 99503 Ilileorp -Ata4as 1.1A: 1 Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, March 17, 2015 11:16 AM To: Wallace, Chris D (DOA);Alaska NS - Milne - Field Foreman;Alaska NS - Milne - Operations Leads Cc: Alaska NS - Milne -Wellsite Supervisors; Regg,James B (DOA); Chris Kanyer;Anthony McConkey; Keith Elliott Subject: Injector MPC-08 (PTD# 1850140) Long Term Shut-In Attachments: image001 jpg; image003 jpg All, Injector MPC-08 (PTD# 1850140) had a passing pre MIT-IA on 2/17/2015 but was not brought on consistent injection long enough for stabilization. The well was last shut in on 3/5/2015 and is not expected to return to injection in the short term.The well will remain on the quarterly Long Term Shut-In Injector report until it is ready to return to injection for stabilization and compliance testing. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 sus. Ifilcorr �lwrl►a.l.lt: rom: Wyatt Rivard - .t: Saturday, February 21, 2015 11:25 AM To: 'c ' .wallace@alaska.gov'; Alaska NS - Milne - Field Foreman; Alaska NS - Milne - Operations Leads; Alaska NS - Milne - We le Supervisors; 'jim.regg@alaska.gov'; Chris Kanyer Subject: Inje • PC-08 (PTD # 1850140) Ready For Injection All, Injector MPC-08(PTD#1850140) has . sassing pre MIT-IA on 2/17/2015. Well has been shut in for reservoir management and is out of its 4 year MIT in : al.There are no known integrity issues.Well is ready to return to injection for stabilization and compliance testing. Plan Forward -Milne Operations 1) Place well on injection. Use caution,annuli are fluid packe•. 2) AOGCC MIT-IA when well is on injection and thermally stable. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 1 Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Saturday, February 21, 2015 11:25 AM To: Wallace, Chris D (DOA);Alaska NS - Milne - Field Foreman;Alaska NS - Milne - Operations Leads;Alaska NS - Milne -Wellsite Supervisors; Regg,James B (DOA); Chris Kanyer Subject: Injector MPC-08 (PTD# 1850140) Ready For Injection Attachments: image001 jpg All, Injector MPC-08 (PTD#1850140) had a passing pre MIT-IA on 2/17/2015. Well has been shut in for reservoir management and is out of its 4 year MIT interval.There are no known integrity issues.Well is ready to return to injection for stabilization and compliance testing. Plan Forward - Milne Operations 1) Place well on injection. Use caution,annuli are fluid packed. 2) AOGCC MIT-IA when well is on injection and thermally stable. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive, Suite 1400 I Anchorage,AK 99503 Hiktrp la4 w, 1.I,t: %MINED M A- 1 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 ° g/ December 30, 2011 P Mr. Tom Maunder ' 40' Alaska Oil and Gas Conservation Commission .,. 333 West 7 Avenue .w, Anchorage, Alaska 99501 r`a Subject: Corrosion Inhibitor Treatments of MPC -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPC -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, • Mehreen Vazir BPXA, Well Integrity Coordinator m:vr .•, s2-; u wi. r.a 371?ixnr�. r, +. .:.0 :. .. ' a ..« m�e. „w..n, =, ?'ex- N,aa,mr e.. r ...., -s rrr- ,.w+ppW "'?ESwe !'- ., ^4i. ,,•w+ ,..: «,- -. ... �. :. . _ - 'u _ • 1 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPC -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPC-01 1811430 50029206630000 Sealed conductor NA NA NA NA NA MPC-02 1821940 50029208660000 Sealed conductor NA NA NA NA NA MPC-03 1820500 50029207860000 Sealed conductor NA NA NA NA NA MPC-04 1821260 50029208010000 Sealed conductor NA NA NA NA NA MPC -05A 1842430 50029212440100 Tanko conductor NA NA NA NA NA MPC-06 1842410 50029212570000 Tanko conductor NA NA NA NA NA MPC-07 1850020 50029212660000 Tanko conductor NA NA NA NA NA . ---3 MPC -08 1850140 50029212770000 Tanko w/o top NA NA NA 3.4 10/9/2011 MPC -09 1850360 50029212990000 Tanko conductor NA NA NA NA NA MPC-10 1850150 50029212780000 Tanko conductor NA NA NA NA NA MPC -11 1850590 50029213210000 Tanko conductor NA NA NA NA NA MPC -12A 1990910 50029213730100 Tanko conductor NA NA NA NA NA MPC -13 1850670 50029213280000 Tanko conductor NA NA NA NA NA MPC-14 1850880 50029213440000 1.8 NA 1.8 NA 5.1 8/31/2011 MPC-15 1851030 50029213580000 Sealed conductor NA NA NA NA NA MPC-16 1851100 50029213640000 Sealed conductor NA NA NA NA NA MPC-17 1852630 50029214730000 Tanko conductor NA NA NA NA NA MPC-18 1852690 50029214790000 Abandoned NA NA NA NA NA MPC-19 1852960 50029215040000 Tanko conductor NA NA NA NA NA MPC-20 1890150 50029219140000 Tanko conductor NA NA NA NA NA MPC-21 1940800 50029224860000 4.6 NA 4.6 NA 8.5 8/29/2011 MPC -22A 1951980 50029224890100 38 NA Need top job MPC -23 1960160 50029226430000 1.9 NA 1.9 NA 17.0 8/28/2011 MPC -24 2010940 50029230200000 1.6 NA 1.6 NA 20.4 8/28/2011 MPC -25A 1960210 50029226380100 1.7 NA 1.7 NA 17.0 8/28/2011 MPC-26 1952060 50029226340000 1.8 NA 1.8 NA 17.0 8/28/2011 MPC -28A 2051630 50029226480100 1.6 NA 1.6 NA 10.2 8/29/2011 MPC-36 1980010 50029228530000 4.5 NA 4.5 NA 45.9 8/29/2011 MPC-39 1972480 50029228490000 5.5 NA 5.5 NA 49.3 8/29/2011 MPC-40 2002130 50029228710000 0.75 NA 0.75 NA 5.1 8/29/2011 MPC-41 2010780 50029230140000 0.5 NA 0.5 NA 8.5 8/31/2011 MPC-42 2040280 50029231960000 1.5 NA 1.5 NA 13.6 8/30/2011 MPC-43 2040390 50029232000000 3.3 NA 3.3 NA 30.6 8/30/2011 3Q2011 Not Operable Injector Report 0 0 Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator @bp.com] Sent: Thursday, November 24, 2011 9:59 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 3Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 3Q2011.zip Tom, Jim, Phoebe and Guy, Attached is the 3Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 3Q2011.zip» -, .‘ 0 % . q7,4_,.) Notes on wells: Removed from Quarterly Injection Report: MPF -74 (PTD #1961080): Long term shut in that was returned to service. Passed MIT -IA on 09/11/11. Added to Quarterly Injection Report: 09 -36C (PTD #1951140): Leak found in tubing patch 13 -17 (PTD #1820260): Well reclassified while flowline repair is being performed END 3- 43/P -36 (PTD #1931700): Surface casing leak discovered post Brinker treatment 7 - MPC -08 (PTD #1850140)Long term shut in requiring MITIA to be compliant MPF -89 (PTD #2050900): Surface casing leak MPF -99 (PTD #2061560): Long term shut in requiring MITIA to be compliant NGI -10 (PTD #1760690): TxIA communication when on gas injection, AA for IAxOA communication. R -02 (PTD #1781000): Identified TxIA communication with leak detect log S -09 (PTD #1821040): Shut in for rig workover to replace tubing U -04A (PTD #1920270): Starting head leak with a Furmanite repair failure Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/28/2011 • • NOT OPERABLE: MPC -08 (PTD #1850140) TIO wa wrcm ..aro 3000 • icy 2,000 OP. OM 000: 1,000 07me113 COMM 07/23111 07/311m 0•436 /11 09113111 0B2V1l 0127111 oAN3n1 01/10/11 01/17 /11 08/21/11 1001111 RE: NOT OPERABLE: MPC -08 (PTD #1850140) Cancel UIC MIT -IA until on injection Page 1 of 1 • • Maunder, Thomas E (DOA) From: Reynolds, Charles (Alaska) [Charles. Reynolds ©bp.com] Sent: Wednesday, October 05, 2011 7:44 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); Stone, Christopher; McEntyre, Scott R Subject: RE: NOT OPERABLE: MPC -08 (PTD #1850140) Cancel UIC MIT -IA until on injection All, Injector MPC -08 (PTD #1850140) is a WAG injector due for UIC compliance testing but remains shut in. There are no plans to utilize the well for injection due to lack of production off take. The well has been reclassified as Not Operable until it is required for injection support. There are no downhole integrity concerns known with the well. The well has been added to the quarterly report of shut -in injectors sent to the AOGCC. The plan forward for the well is as follows: 1. Production Engineer: Notify Well Integrity Coordinator when injection is needed 2. Fullbore: MITIA pre- injection 3. Well Integrity Coordinator: Reclassify well as Under Evaluation �� d, 4. Operations: Place well on injection 5. Fullbore: AOGCC witnessed MIT -IA once thermally stable Please call Well Integrity with any questions or concerns. Charles Reynolds Filling in for... Mehreen Vazir :A rt F . r' { ..,i r, v . WI ��t,ri�rrn tvr�.i fF:r7'q% Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 10/6/2011 • MEMORANDUM To: Jim Regg `.~c?y~ ~ (~~1~-~`~~ ~ P.I. Supervisor CC FRO1Vt: Bob Noble Petroleum Inspector C State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 10, 200? SliBJECT: Mechanical Inteb ity Tests BP EXPLORATION (ALASKA) INC C-08 MILNE PT UNIT KR C-08 Src: Inspector N(1N_f'[1NFTT)T,NTTAT, Reviewed By: -~ P.I. Suprv J Jf`-- Comm Well Name: MILNE PT UNIT KR C-OS API Well Number: ~0-029-21277-00-00 Inspector Name: Bob Noble mitRCN07 1 008 1 7 522 6 Insp Num: Permit Number: 185-014-0 Inspection Date: t0i8/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~~~ C-os 'TYPe Inj. ~ w 1 TVD I 66ao ~ IA ~~ zo I i9oo /~ i Is7o ~ - 1s7o P T y Issolao TypeTest SPT 'i Test psi L _ i I9oo `~ OA ` o o ~ ~ o - o y Interval 4YRTST P/F P ~ Tubing I, 2aoo ~ z4oo zaoo ~ zaoo j Notes: 7 ; ~~ ;tea-.. rr?sSL~~ ~~ ~4~~~F~s~ r ~:~' ~ ~ ~ Nay ~; ~{~~~' Wednesday, October 10, 2007 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich DATE: October 14, 2003 Commissioner THRU: Jim ~egg . ~'~¢~¥~ ~®SUBJECT: MechanicaIBPx Integrity Test P.I. supervisor ~' MPU C Pad FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL P.T.D.I Notes: WellI P.T.D.I Notes: Packer Depth Pretest Initial 15 Min. 30 Min. c-o2I TY.,,~.l s i T.V.D. [~0 ]mub~ng]2250 12250 I 2250 ]2250 I,nt~rv~,] 4 182-194 ITypetestl P ITestpsil 1585 I Casingl 0 I 25001 24501 24501 P/F I T~,~,ni.I s I T.¥.D. I~o I Tu~i,,l~00 I~,0~ I ~0~ I~0~ I,**rv*l , I C-08 ITypetestl' P ITestpsil 1660 I Casingl 0 I 24401 24201 24101 P/F 185-014 w,I o-~ IType,ni.I ~ I T.V.D. I~ ITubingl 3~oo I~oo I ~oo I.oo I,nterva, I 4 P.T.D.I 196-029 ITypetestl P Imestpsil 1695 I Casingl 0 1250012400124001 P/F I ~P Notes: WellI I Type Inj. P.T.D. I Type test Notes: WellI Type Inj. P.T.D. I Type test Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs MPU C Pad and witnessed the routine 4 year MIT on well C-02, C-08 and C-28. The pretest tubing and casing pressures were observed and found to be stable. The pressure tests were then performed with all 3 wells demonstrating good mechanical integrity. M.I.T.'s performed: _3 Number of Failures: 0 Attachments: Total Time during tests: 3 hours .cc: MIT report form 5/12/00 L.G. 2003-1014_M IT_M P U_C-28_cs.xls 10/23/2003 STATE OF ALASKA ALASK IL AND GAS CONSERVATION COM ,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Acidized Well 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 52' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 780' NSL, 2325' WEL, Sec. 10, T13N, R10E, UM MPC-08i 9. Permit Number/ Approval No. At top of productive interval 185-014 95-080 4624' NSL, 1199' WEL, Sec. 9, T13N, R10E, UM 10. APl Number At effective depth 50- 029-21277 4748' NSL, 1345' WEL, Sec. 9, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 4794' NSL, 1408' WEL, Sec. 9, T13N, R10E, UM Sands 12. Present well condition summary Total depth: measured 9620 feet Plugs (measured) true vertical 7133 feet Effective depth: measured 9495 feet Junk (measured) true vertical 7031 feet Casing Length Size Cemented MD TVD Structural Conductor 55' 13 3/8" To surface 90' 90' Surface Intermediate Production 9553' 7" 700 sx Class "G" 9588' 7101' Liner Perforation depth: measured 9170'-9184', 9228'-9248', 9259'-9265', 9348'-9402' RECEIVE[:) true vertical 6773'-6783', 6817'-6833', 6841'-6846', 6912'-6959' ,JUi~J ()~ 200! Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80, NSOT to 9029' Alaska Oil & Gas Oons. Comrnissior: Packers and SSSV (type and measured depth) 7" x 3-1/2" Baker 'S-3' packer at 8992' Anchorage 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service Water Injection [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Michael Williams ~"~ ~ ~ Title Technical Assistant Date ~/.~'"',~/ ~:ii: i :: ::i:ii :i::i ':. i::::::: ' i : preparedByName/Number: De~Vaynel'Schn~rr564-5174 · "~ _ _ i .... _',l. i.- Submit In Duplicate Form 10-404 Rev. 06/15/88 ORIGINAL 11/15/2000 ACID MPC-08 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS SUMMARY MIRU DS CTU #3. PU 2.5" JSN. ON LINE WITH WATER DN COIL AT 3000'. WASH TO 9450' (NO TAG). DID NOT SEE ANY FILL OR BRIDGES. SWITCH TO ACID, PUMP 14 BBLS 15% HCL/10% XYLENE FROM TT TO 9400'. LET ACID SOAK. PUMP AWAY. POH, FP COIL. RD DS CTU #3. RETURN WELL TO INJECTION. Fluids Pumped BBLS. Description 130 2% KCL (DOUBLE SLICK) 40 6O/40 MEOH 14 15% HCL/10% XYLENE (90/10 DAD) 184 Total MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I.' Supervisor DATE: May 19, 2001 FROM: John Crisp, Petroleum Inspector SUBJECT: Safety Valve Tests Milne point Unit C Pad May 19,2001' I traveled to BP's Milne Point Field to witness Safety Valve System tests. Lee Hulme was BP Rep. in charge of SVS tests. Testing was conducted in a safe & efficient manner. This Pad is on 3 month test cycle due to failure rate above 9.9%. i reviewed the 8/12198 supplement to the 3/30/94 SVS policy to discuss BP's options for keeping the wells with leaking Surface Safety Valves producing & injecting. Lee Hulme stated that servicing & repair of the valves could not be accomplished immediately. After review of the AOGCC Policy Supplement, i told Lee that the wells could stay on line if someone trained in Drill Site Operations manned the Pad. I requested the Pad be manned immediately & until the valves were repaired & re-tested. The AOGCC test report is attached for reference. Wells #7,8 & 25 were serviced & re-tested OK 5-20-01. Wells ~,6 & 14 were shut in for repairs. SUMMARY: I witnessed SVS testing in Milne Point Field. 12 wells, 24 components tested. 6failures witnessed. 25% failure rate. 20 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc cc; NON-CONFIDENTIAL SVS MPU C Pad 5-19-01jc Alas~.a Oil and Gas Conservation Commis~. Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/U~ad: Mill~e Point Unit C Pad Separator psi: LPS 140 HPS 5/19/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE C-01 1811430 140 "100 110 P P oIL C-02 1821940 C-03 ' 1820500 lZ~0 ' 100 95 p P '" OIL C-04' 1821260 140 100 " 110! P ' '4 ...... 'OIL C-05A 1842430 140 100 100 p p OIL C-06 i84241'0 4300 2000 " '19501 P 4 WAG ~-07 1850020 140 100 95! P 4 OIL C-0~' ' ' 18501~0 '4300 ' 2006 .... 1900 P 4 WA~ C:o9 185o36~ '14o 'i0o ' lO5! p p OiL C-13 1850670 C-14 1850880 ' 140 ' '100 100 p 4 " OIL , , C-15 1851030 . C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 140 100 951 P P ' ' .0i~ C-23 1960i60 ............... C-25A 1960:~i0 4300 2000 1900 P 4 ' " wA~; C..26 .. 1952060 ......... c-28 1960290 c-3,6... 1980610 ....... C-39 1972480,' .... C..40 2002130 C-10 1850150 4360 "'2000 1850! P "P wAd Wells: 12 Components: 24 Failures: 6 Failure Rate: 25.00o, t]~1 ~0 Day Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU C Pad 5-19-01jc . . MEMORANDUM State of Alas ka Alaska Oil and Gas Conservation Commission TO: Dan Seamount 0.7:) DATE: July 12, 2000 Commissioner' ! /10/;;;(::) THRU: Blair Wondzell, @~ P. I. Supervisor . ef ~(dJ FROM: Jeff Jonei I::!tl SUBJECT: Safety Valve Tests , / Petroleum I sp c r Milne Point Unit B & C Pads JulV 9. 2000: I traveled to BP'S Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU 8-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU 8 Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. '3 Jt-1O~ r~-h-7i- 21 well houses were inspected, no failures. ---'tf' Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc . . Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones Submitted By: Date: FieldlUnit/Pad: Kuparuk River/MPU/C-Pad Separator psi: LPS 140 HPS 7/9/00 ~ ,/ : JVell Data' ", I '. .' "'., '.. ~..., " P.l .". :' i" '¡'(Ol "l.',.. .:11 S l":'!" . ,S~.'\(,1 ' ,[ t", '. ,; \.; J..' ~~ I '~Yell~,Tyþè\'" '. ,.. lots' """'.: '\i..;~~.~~I:,>,,' ~:ulr '.' ,-~'\ i ,'.. ,;"',n . . .:.p ... ,'~:', 1:."~'~):.'..:..,:.~,~{'7',.: Well Permit Sepal' Set LIP Test Test Test Number NUlnber PSI I)SI Trip Code Code Code Oil, WAG, GINJ, GAS or CYCLE ;<If}.Q '1!'~\~1<~1 1811430 140 100 95 P P OIL C-03 1820500 140 100 95 P P OIL C-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 P P OIL C-08 1850140 C-09 1850360 140 100 120 P 4 OIL C-13 1850670 C-14 1850880 140 100 100 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 140 100 95' P P OIL C-23 1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 C-28 1960290 4000 2000 2000 P 43 WAG C-36 1980010 C-39 1972480 C-02 1821940 4000 1900 P P WAG C-06 1842410 4000 1900 P 4 WAG 12 Components: 23 Failures: 6 Failure Rate: 26.0%090 Day We lis: Remarks: Wells # C-02 & C-06 are listed as water injection wel1s, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap o-ring leaked. The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these items corrected. 8/7 lOa Page 1 of] VI v7irqrn.xls --~"- STATE OF ALASKA ALASKA O,-AND GAS CONSERVATION COMIv,,$-SION REPORT OF SUNDRY WELL OPERATIONS :1. Operations performed: [] Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other Change to Water Injector 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 780' NSL, 2325' WEL, Sec. 10, T13N, R10E, UM At top of productive interval 4624' NSL, 1199' WEL, Sec. 9, T13N, R10E, UM At effective depth 4748' NSL, 1345' WEL, Sec. 9, T13N, R10E, UM At total depth 4794' NSL, 1408' WEL, Sec. 9, T13N, R10E, UM Plugs (measured) Junk (measured) Length Cemented 13 3/8" To surface 12. Present well condition summary Total depth: measured 9620 feet true vertical 7133 feet Effective depth: measured 9495 feet true vertical 7031 feet Casing Size Structural Conductor 55' Surface 5852' 9 5/8" Intermediate Production 9553' 7" Liner 5. Type of well: [] Development [] Exploratory [] Stratigraphic [~ Service 6. Datum Elevation (DF or KB) KBE = 52' 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-08i 9. Permit Number / Approval No. 85-14 95-O8O 10. APl Number 50-029-21277 11. Field and Pool Milne Point Unit / Kuparuk River Sands 150 sx Permf 'E'/920 sx Class 'G' 700 sx Class "G" MD TVD 90' 90' 5887' 4518' 9588' 7101' Perforation depth: measured true vertical 9170'-9184',9228'-9248',9259'-9265',9348'-9402' 6773'-6783',6817'-6833',6841'-6846',6912'-6959' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80, NSCT to 9029' Packers and SSSV (type and measured depth) 7" x 3-1/2" Baker 'S-3' packer at 8992' 13. Stimulation or cement squeeze summary Intervals treated (measured) Change to WAG injector Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: 5. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure I16. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection 17. I hereby certify that the fo. regoing i~ true and correct to the best of my knowledge Terrie Hubble _ _ _ Title Technical Assistant III J Prepared By Name/Number: Date 0~'~ '(~? Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate~ SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPC-081 Rig Name: N-4ES AFE: 330141 Accept Date: 05/29/95 Spud Date: ..... Release Date: 06/08/95 05/30/95 Move in, rig up, berm rig and thrash tank. Scope up derrick. Nipple up hard lines to tree and test to 2000 psi. Take on 12 ppg brine. Rig up Lubricator and pull BPV. Rig down lubricator. Bleed annulus to 530 psi. Monitor tubing and annulus. Built from 530 psi to 1230 psi in 35 minutes. Bleed well volume, 8.4 ppg water from tubing. Flowing through choke. Shut in well and monitor psi. 05/31/95 Continue to monitor 3-hour build up. Continued to flow well. Shut in well for 1 hour to check progress. Continue to flow well. 06/01/95 Continue to monitor pressure build. Kill well with 12# NaBr circulated down tubing with returns to kill tank. Monitor well, static. Set TWC. ND tree and adapter flange. NU BOPE. Test BOPE to 250 / 5000 psi, annular to 250 / 3000 psi. Witnessing waived by John Spaulding - AOGCC Field Inspector. RU Lubricator. Pull TVVC. RD Lubricator. Pick up landing joint. Screw into hanger. BOLDS. Pull hanger to floor with 12K over. Lay down hanger. Circulated around once through choke and gas buster. Monitor well - slight loss. Spot Xanvis pill on bottom. Pick up weight. Start POH laying down 3-1/2" BTC completion. 06/02/95 Finish laying down 3-1/2" BTC tubing, SSSV, GLM's and seal assembly. Recovered 128 SS bands. Install wear ring. Strap and caliper 4-3/4" DC's. Make up FTA #1. SLM drift, and pick up 3-1/2" drill pipe to 6704'. Well started flowing slightly from annulus. Shut in for 15 minutes. Open choke, well flowing slightly from annulus. Circulate down tubing at 2 bpm while holding 100 psi back pressure. Pumping 12#. Recovered _+ 30 bbls 11.7+, with some crude oil from top of hole. Continue circulating with 12#, weighting returns from _+ 11.9# to 12#. Monitor well. FL dropping slowly. Operations Summary for: MPC-,..,, 06/03/95 Service rig, well remained static. Finish picking up drill pipe and RIH with FTA #1 to 8959'. Circulate at 3 bpm w/650 psi. Condition and weight up fluid to 12.1#. Heat fluid and wellbore. Pick up weight. Spear fish at 8989'. Straight pull to 100k over and jar at 75k over to release packer. Sting out of lower packer. CBU through choke and gas buster. Circulate out some crude from bottom. Monitor well, slight flow. Circulate and raise weight to 12.2#. Apparently packing off around packer occasionally. Working pipe to keep from losing too much fluid. Monitor well, slight loss. POH slow. 06/04/95 Finish POH with FTA #1 and fish, lay down same. Recovered upper packer and lower seal assembly. Make up FTA #2 and start RIH. Continue RIH to top of packer at 9288'. CBU, mill packer at 9288'. Push packer down to 9350', tubing tail at 9374'. Circulate to clean up and heat fluid to 100°. Monitor well, static. POH, lay down FTA #2. Clean junk baskets. Strap and make up FTA #3. Start RIH on drill pipe. 06/05/95 Finish RIH with FTA #3. Spear packer at 9352' and work free. CBU, POH, lay down fish and FTA #3. Make up FTA #4. RIH, wet and slow. CBU and heat fluid. Wash and rotate to clean out fill from 9372' to 9486'. Pump 40 bbl Xanvis sweep while reciprocating and rotating pipe. Recovered frac sand and debris. Monitor well, static. Attempt to POH, pulling 40k over at 9420'. CBU at 5 bpm with 1500 psi, no drag. 06/06/95 Finish POH, lay down FTA #4. Recovered 2 sets wireline tools stuck in washpipe. Make up BHA #5. RIH to 9486' Circulate Xanvis sweep around at 6 bpm w/1800 psi. Circulate until clean. Monitor well, static. POH, lay down BHA #5. Recovered __.50# metal in boot baskets. ND flow nipple. NU perf flange. RU atlas and lubricator. RIH with Atlas Wireline. Tie in to SOS DIL/SFL/GR dated 02/08/85. Perf with 4" Alpha Jet guns at 4 spf, 32 gm RDX charges, 0.5" EHD. Run #1: 9382' - 9402', POH, ASF, no fluid loss. Run #2: 9368' - 9382', POH, ASF, 2 bbl loss. Run #3: 9348' - 9368', start POH, all but on shot fired. 06/07/95 Run #4: 9170' - 9184, POH, ASF. RIH with 6" GR and JB to 9160'. Rig down atlas. ND perf flange, NU riser and flowline. Make up BHA and RIG to 9125'. Rig up and reverse circulate Xanvis sweep. Check flow for 15 minutes. POOH, laying down drill pipe. Rig down kelly and swivel. Pull wear ring and rig up for 3-1/2" tubing. Page 2 Operations Summary for: MPC-~,., 06/08/95 RIH with 3-1/2" completion assembly. Make up hanger with TWC and landing joint. Land tubing, RILDS. Rig down landing joint. ND BOP, NU adapter flange and tree. Test hanger seals and adapter flange. RU lubricator, pull TWC, rig down lubricator. Bullhead 18 bbls diesel down tubing. Test tubing. Rig up lubricator, set BPV, rig down lubricator. Clean pits and secure cellar. Release rig. Page 3 Pr. Audho~ l~.v Drillin! ! .... Well: M'PU G~3ed TO: g~tEI' PBD: 9508' ~: ..... ~ ~o~ ~P~loA) G~: ~", ~ L~ ~ 9~' ....... ~ .......... ~ ~, ~ gJl~ ~i~; N/A E;PM'. ~A ['~'M~ ~A ~i: NtA ~ Pump ~tw: NIA ~w Pump ~ FI~ Ty~ I b~mn~: ~: BB L~s~: J ~J]i,, ~ .... l' I'''" "'' P'"'""': A~ D~ian'. , ................. ,,,n. ..... , . ,. ....... Mi~ D~ ....... ~tg; Hm: ~ ROP: ~A ~A ...... ~/A ~le~n Dat~ ~umo;- Volume: Type Flu~: Inj~l~n CC.~ I~'e: ~A ~Pre~,ure: N/A .... Well: /C~mu~vo D~I~ Volvo: N/A ~ V~nle; N/A Volumo; ~A , . ..... , ............... ....... ~ ............................ F~,~ Ii ,,~ ts .. ........ ID, L w~t., In~ H~d,. ~ i ~]rna: BPX IRa~,d: 0 g~lU~d: ~S~e: ...... -:~[,,,~...Du~ . I~° "FITM Daily: N/A c~umum~: N/A '--I'~Tago N/A rap: S~od: S~etvlaOP. Da~ ........................... ----No Accldent~ .... No Spills .... ... , ,,, ,, ,...---~ , .-,., , ...... ........... , .......... r , .................................. . ~hipp~ dSO ~ ul iilLu~ud12,2~ NuB~ tv A-Pad ~I~,'~e. Adjusted ~ily ~mul~live ~s~ -$117,0~. ,,. ,.,,~., ............... ~n~et~ ~11 ~ver 4 days ahead ~t we, ~n and $~24M ~r AFE. = = , ,~,.. ............ 2 days ~ing well to ~a~ Ui Ii.' ~er ~ a~a~. .... . ............ - ..... _,.,,, ...... ,,, ........ ....... . .[ ....... · , ,, .. ................ ,z ........ Ce~,~c.~or: NAJaQF.I,3 4es I'h~ae: 6476 ' IDa~ $q 0~ ~'~")'~ I~- ~ ~ : ~ Well t~ r ~ral~n a[ 0600~ C~i~ P~ J Interm~iate (pr~u~i~) C~; ~, ~ L~0 P~-~'~i~, ~A IPedorm~ lnt~l~ 917u'-~ Isur~ C~. ~;- ~A' ILasl ~ Teat: ~a J~,3JLmerS~e: ~'A IS~'. N/A I(~l'"' '~TA l~i: N/A JS~Pu~a..,. NiX I~~.,;:' N/A -,- I ~ / I ..... I FIIJ~ I~, Ib~ L~S ~Bd ' -e~ ' I ~ ~ , .... i.'~F~' · t . ..-';; .... , ' ; . ~_N ~ ,,, I ~at: J~: '~jWa~ht: 12. J2 ...... V ~: 3B jl'V~l '. tN A Shlorides'. ' ' JN,'A Fiu~ ~', ,NtA ........ ~amP ~)', J. '~A E~ (OBM)'. N/A J · ~ % ~aR A JB~ - . it .. ....... I ",* I ......I I,,'~I~..;N~, 1~'*: .~, Iu~*: ~'~' 'P~; ~, 17.'"'' .~, 'P'"~; ' ]~","'"~- IM"I ~h ~', HIS" ' - R~' RPM'. ~-; e~' ' ~&]~Num:~A I~ize; ~A I~ ' ~;;A i~y~ N/A I~ N~A "F~A: I~ In; N/A 2'3.3o-0230 I NO' .... No Accidents ........ wt 3.5" ~,,pl~'juu a~ l.~r Tub[r~ Detail Pa~k~r ~ 8~2' & ) g029', MU h~er & ~ jr, PU ~; ~k, 5Ow~; 47k. La~ h~. Ri~$,LD ~ il. ND BQPE, NU ada~erf~ & tr~, Test h~er se~ ai~ adapler I~n~ to 5000 p~i V 30 min~, Tu~I ~ min--UK. ~nu I'~'~. 'r,u~'~. nu ~u~. ~ls die~l ~ 2,~ bpm wt 4B0,.-~16~ p~l. ~ll~d !8 ~m w/~300 psi, D~ palm' seiih~ r~. ~t paget aha affect ~0 t~l tubi~ to 4500 p~i. Lo~t aRempted ~o a~ij~l times w/aame re~s. W~ ~00 ~1. ~m 7S p~ In a0 min. Bled ~nn~k~ la 13a0 p~i. 80 ~i h 30 m~3. Wi~s~ MIT j~['~d ~ ~ A,~s-A~CC ~ I~p~or, B~ ~ armulus lo 0 mi a~ t~ to RU lubl~atuh ~[ BPV, RD iubr~or. Se~m gellur, ¢lua,li[~ pitu, STAllE DF ALASKA, M..~$KA OIL AN]) Flt, LD y UNIT.r PBdD Miln*' F~)int, r~,-P~d &,, 8:9 5 t~500 I 3.5- i ~.5m:, I ..... 1,7oo i I &l,g413~R FLLIliD: ,~ I, LT WATER 0.3=_ ~,,-' 4 4- - Yea.- Pn, Jd~ Bay Dr[llino., AtT'N~' ~1-41 IH*J';'xtN: W~ll: MPU C-08i l~t~: ...... , /wo ¢~ts: ..... '--- / W~l ~_.~.0 ~mi~'~ ..........,~'~-{I,,/d~tv), 0900 ~ ~29/95 j R~ ~i~ {hrMma); N/A ' Fb~ jRu~ NaCPBr [~or ~-' ' D~ 36 J tmal.. 212 J rmi~. _05 .I{a~m _2295" ,503' _ I!y~: J bala.~u; Lo~s: aau L~; I Co.t: t~: RI.iA I~.~' ....... J,, BNA No; Bit &] Bit ~m: N/A M~ i Depth lout: NtA , . J~3t,~: N1A V~JJUl?lkL Rmi 800 J Fual !Uoo~: ~at J Soutoo: BPX Cuttin[:t$ Dafa DalJy; ~A ¢ umulmlvo: NIA gRgite: Last BOPE Taah 5/31195 ]L~I BOP Ddll: G/6195 La~t ~I! Drill: 0~ {tgb IS~II [Y~)I N 0&Cs-0~0b 0800-0915 ~qlfi.lOl,r, ld15-1."L'1,'3 J I',E~-I/lid BHA Lsnglh: bU9 /4' Date La~t lnsPeCl~; On Jara: ~A N/A H,l. NiA JRt' ~A N/A ~A J~n~.n: NIA - Inl~ion gala - ' ~ 2~ ~ ' J jO~ily V, mm~: M,~ JCummu~vo I I .... ,.,~J yolu~; .N/A i if~eeze Prot~ Ruid: ~A I Funl lb'l, WaJei: i 4 I~ )"' W~r ~A rap; 34 "f WilSon: ~0 ChllIF~or: 13 'F ~a[aJ~P D~I~ ~S Drill: 6/5t95 j~pe ~1i: Reda fl~ Vobme (O~s.): N/A N!A ~A 1'/¢Ja-P4L,VO: Op,~"~Jur~ Frum 0600 t~ 0800 .... No Accidents .... No Spills .... Run ~: Flnloh POH. ASF, Run #4.9170'-~4'. PON. ASF, Run #5; 6'" GR / JB lo gl 60', POH. Small a~'n0unl l.~rl debfls, RD Atlas, ND pad flange, NU riser & llcmline, MU BHA. RIH ~ 9q60'. HU ~ revere ¢~tc. 4U ~1s xanvis a~un~ ~ 3 ~ wi 560 psi, Monitor ~ell.-OK, I-'~H. LDDP. PU Kelly A make Slip 60' of dnlling tine R.ish LDDP & BHA, iOlear floor, RD kelly and swivel, Pull wear rir~.. RU to run lbg. PU packer. Prudhoe 8a_v ~ ~ Dai", C.,r~lel~. __~/orl~var R.eO~ MPU O-~i , o' 95Lin' PaD: 950~' ,,',1'r'''~'~f,', . , '~j; , 9486' R~ ~ tl~rld~): ~0 ~ ~ Rig Rel~ (KrMae); NIA FEJI~ Ty~o', ............. .... balen~ Loss: BB~ ~s~L...,... I C~[; ' ~ WeIg"t'.I~ ~lTM 2B 1PV~YP: N/A :h~iden: . i.._ ' , jlemp(~t,: 76~ IE~. (~M): NIA' B~ D~r~tlon: RHA ~' M~I, XO, ~--~ ba~els,-~ sub, ~mpe~ sub, ~1 j~, 10-4,75" ~, XO, C~ ~r~, . . .lL__ ,~, ,~[, ....... · [&l~Num; NiA ~li~n' ~A Mnkn: N/A ly~: ~A INa: N/A .... · , ~t: NtA NIA NIA N/A ~' ,, ,, ,~fA WL; ~tA ~nd~n; NtA inje~iun D~ . W*~' · .... jC~mul~ D~i~ V~lume: NIA ~ Vulume, Fr~'Pin~ FI.M: N/A .. ..... ~,y.~l~.~ter DNa ;U0{ 900 I Fu~ F~el ' IDrt.'Wnter BPX IR~v'd: 43~0 JOri. Water 17 L~ U~ed; .... ., gallU~,. ~ J~ur~ .... W~d S~; 2 CNII Faaer: 38 ....... . .... ;E.'Z..:.'..s~.t~ o~ ..... . .. L~,D,,~: e~,~'IS~'(Y'~)? ' ~ 'IV~,~." ~'.): ~.--~ S~,~: N/*In~;~? ~- ....... , T i ,1 , [ -i , , T~ CJpnrat~n P~ ~e Hrn, O~rd~16 From 0~ m ~ .... ~ ~id~n~, .... ~o ! .... nr~.l~ m.N~ $ Fbd~h POH. LD FTA ~4. R~vw~'3 ~u[6 wire,lie t~b ~uklllw~h ,,,,, .... . . 14~]-1~{~] ~L'~ ~k~ ~ He~ir~el ~1 ~t~r, Fire Dria-Motor~-~ "3'7~'.1~ ~~ ~ C~c X~vb ~eep amu~ ~ 6 Opm w/1~0 psi, ~i~c fia c~an, ~n~or 1900 24~: ~O~ 5 POi t. LD ~ tA · 5. R~o~ I ~ meta~ in ~t ~e~. Ol DriP: O~ ~ ~, 24o~o 13o L~E~ 1.~ ND flnw nixie. Ntl ~d fi~ RU Atlas a~ k~i~tor. I e~ I~ ~ 1~0 013~b4~ L~E~ ' Z.~ RIH wl Al~3n ~. ~e ~ to SQ~ Dfl./~FI IGR ~1~ ~,~R. Pe~ w/4" A~ 4 8pl, 32 gm RDX d'~a~-ge~, 05" ~D, ' ' ......... Run ~t: ~2'-~', POH, A~F, ~ flu~ ~ss. . ~_~ _n~: ,,, ............ Prudho.e B~ Dr ~ Da~"' ~!etJon/War;koy..er...L:~.. I 'rop ol Fill: W~li: MPU C,-O~i 'I'D: 9581:1' i:UU.' 950B' 9486" Gontrac~or. NABOBS 4e~ rhone: 647.5 i1..)a~ $21 ,ag0 l'OJ~m r~m~.,.-.e"~?",-...~"" I r.,xnm. ............. ............................. t.c'~,~a** IWO co~s IW"" {x"-,il" $0 I lmormo~to ¢ro~u~t~on)' c~-¢ --- 5.... Dp~rmlen al 06/au:: CBI. J I~i:,,,/[3~,uil, ~ -, ~-,.~ L-~O ~') 958EP H[~ Ac.c.~ (hr/daf.? 0~00 @ 5/29/95 Rig Release {hr/d'at~i! Nt^ 0. ..... ..... I '0'0 -. . BHA Do~lp~om ~A ~- ~er, F~, ................................... ~,, ,, ,, , ........ : ..... .-1, ,.~..~. . · M,ll ~h Ftg: Hra: . I ROP: .. IRPM' .--' ' IWt' ICondlt~n: N/A I I Mil D~th Ftg: Hr~: N/A ............. Om: N/A N/A ROP: ~A R~ N/A t, ~A . N/A lni~l~n ~urce: Volume: ....... ~"~'~ R~: inje~n CC-~ ~to; W~ll'. ICuinniu~ive D~ly Vulumu. ~A fr~a Prat~ ~ ~---. ...... Volume; ....................................... ................... FU~ t 200 ' "1'~ [¢u~ ~ I' )"~ w~t.~ 19 Lake D~Iy, ..................... ~A p O~b'Rh- C~um¢la!i~"; C~i~,, ' .... One Accident .... No 5pill~ .- - ~-~ R~9 .5 9erv~ rig. m~'ln~l~ ~,~_~,~l{ 1.5 ~S~HIHw/FIA~3, PU~;155k;~O~;8~, '-- · ~1~1~ WI't~N 1,5 CBU, lnan.1~3 FI,~R ~.5 ................ · .~ .................. , ....... 1~16~ ~UT 1.5 MU 1~0 17~ RI~$ 1 Slip 42' A m~ 1~' df~l~ I~e. ~ ................................ . ............. ~mmfl~ (~ N~{)tll 9 W~h & m~ to clean ~ fi~ ~ 937~ ~ 9~6'. ................. oL~u.~ ~O~ ? ;I ~ 4U ~ xfl~ sweep ~ 4 ~ wt 10~ ~l whm~ r~pro~l~ · ~stl~ p~. R~o~r~ lr~ ~a~ :nd dob~. ~Dr ~11 stat~. PLJ ~: 16~: SO ~: ~. o~o ~N o~ 2 ALempl to POH;-~lJi~ 40k over ~ ~20'. CBU ~ 5 ~m wl 15~ ~--No Drag, i .... ~o~'G~ w&~ mmi~ dr~li~ a~ w/hydrm,lb ,ne ranter when ;0wer yoke b~e, R~ebod ~ on Hghl I~fle finger. ~ la MP M~E. R~-~i~ A'm~ee a~ ~ume~ .......... , ........... Prudhoe Bay_..Dr D~" .[[ - m · ~ ',)mi -- - ..T.. ------j j- - ~E No; 330141 JRuf~rt N~: f .~L.:..,,t.O;. 6/4/95 C~mphl~n D~y'~ ~,' ,~l~J~;-'- ..... 'IA iWoll: MPU C 0~! ' 958~' " PBD: 950B' ]T~ Fill: 9390' ' ' iml ~.., Idn~te,' ....... ['¢,~ Come: $349,228 w., r~,~.. 0 ope.~'~on at oeoo, Rill w/.S~w IInte~m~l~o~iz~,,,'D,~,.,u, Preuuc~ Li""'na~ N/^ i p,,,fo,.a~ I;,t,vl.' ~,2e'..~' Sur~ Cr, g. ~iza/Demh ...... l ~;.-'u/CJm'~[Jl ..... Rig Aoo~i (hr/da~): O~4XJ ~1 5/~9~5 Rig Release {hr/dAle)": N/A Pomp t,~.~ I_i~er~iz~:Sx'lO BPM, ~ GIPM: 160 ~1-1100 t,l~a I,~. 2 Liner Size: I~/,~, SPM; NtA C-~M: N~A pal: "N/A EIk,-,,,r Pump i~te: 4 0 Slow Pump p~l: $00 ~IM¢.~' Lq$$: ]FIuH:I i .s.,t: Lo~.~[ .... ~'~= De~r~;~,,. ~A ~; ~11 ~O mill, PET e~, ~ ~, T~p ~nn ~ub, 9~t ~s, ~, ~r jam, OU ~, 19~,75" DC ~A ~: ~r, Fro, ~ ~. ~p Sub, ~m~r jars, Oil ~, 19-4.75" ........ ,' .r.: I "" - Out; NtA N/A NIA NIA ~A ........ ,,, ' - ................ I Dai~ V~lume; N/A ......... Fr~ ['~*~ t'lu~: -,.' . ~ ,, , ...... Fuel & W~er Daa ....... Fuel t ~00 I Furl [Fuot J~i,[ w.~ 19 ]D~. Waer U~ed: ~J B~u~e. BPX iR~v.d; 0 gallua~ /s~;;,.- ...... N-/~- :' w..,,~, o.t. . o.,~: ~* c~'''''"~*"~': ~* c..,,..',,,~ . ~s Safatv~ ~o ~n ~P~ ~ Hr~. ~abn~ Fram ' .... No A~idents- ":":No Spills .... .. ~0-1~30 PL~H 5 Finish POH w/~A ~1 & Ii,h, LD ~au~, 1130-1~ PL~ 2 MU ~A82 & SI~ RIH. ......... ~-~ n~ ,5 ~l~ 42' D~ i~e, 1~0 1~0 ~LCON i 5 CRIJ PIJ~: 150k:SO~:UTk. ~;~'~0 "pL~P~ , ~.g' Mill ~ ff 92~' .. 90.~,. Pu~ pkr d~n m ~'~0'. ~g tail ~) ~0/4'. ................ 2130-2,i00 P~P~' ~.~ CJm~cE~nup& h~mflt~td 110~ Mdnit0tweJl--StS~. ~illdrill.-- .............. ~0- PL--P~' 3,5 POH, LD FTA ~2, Clean ~ ~k~, ~ ~t~. ' ...... ............. n~;~;~n i,~_;,~;; 2.5 ~p ~ MU ~A ~3. ~aK RIH on DP, .... .......... ~.... ....... · ,,, .., ................... ~ i~,_ [ ;.~.i ,.. ,.,.. =. , ,,, r,,..., ......... ........ ~,,. ,r.,, ... . ~.,.. . Prt~dhoe Rav_D. rillin¢l,. ~---- Da~' Well: MPU O-{~i 41)'. 95U8' PBD: 9508' ' ..... ~Tupui Fill; 9390' I , ~m~o~:' ~0.~ 4~ '~"~ 0475 !"."~ ~3,20~ I~=m~ ~,3sa I~,'m ........... ................ I~nata: lWO C~: W~ll ~M:. '~lon Liner: NIA JPe~or=~ lnt~; '~'~'-g3~ Sgda~ ~, ~al: ~A ' J~ C~ T~: S~e/D~thJ ..,.,_. R~ A~ (hrtdele): ~00 ~ ~2~5 ~ Rebate ~r~ate): Pump ~.I ~,~S~e;Bxi0 SPM; ~A" ~. ~/A pml, N/A ~Pum~'~' 30 ~wPumppm~ 5~0 .... ~ ~, 2 Liner Size: N/A ~M: ~/'A ~M: N/A ~i? N/A 3~ Pump R~e; 4'0 ~ Pump ~ 760 .,-L FIt[M ~: j bal~: Lo~s: OB Luw~ ~ ""0~':",'1'"' "I"'""",* ,.,,;"h~"~'._...., ~A'"~-¢uid_ L~,: ~A BHA D0~f~¢~: ~A ¢~, Spear, ~sr e~en~ion, St~ ring, ~ su~, ~r ......... .... . .._~. m, ~&~um:~/A sb~: ~/A a~: N/A=.--.-IT~;....N/A '~"~ '- Out: N/A ~A N/A ~A N/A ~A NfA 0~: NtA NIA NIA ~A ..... ,, .i · · ~: .......... =, JC~mul~o D~i~ Volume: N/A t r~ze ~r~ed Flu~: ............. ... ............. .............&m Fu~ J Fu~ RP~ JFue~ JDrl. Water JDrl. W~ UfoS: 1300 ~lSou~; , ___ in~¢d: 0 ga~JtJ,~: 17 , La,~JJ'~": ~,1J~5 I~IIi(Y~)' N [V0lgmo{~J~.): NJA Fy~*~jj: N/A I ................ .... No A~Idents .... Ne SpIlI~ .... ~o.~ R~S ~ ~dg.W~N m~ed '~-~ PL PBR ~ R~h'PU DP & RIH ~ ~A ~1 I~ ~.le~ ~ ~ 7,6 C~o t~ 3 ~ w/~0 ~i, Cv~l~u a~ wi up ~lu~ Iv 12,1fl, ~ai Ibid & w~l~ru, PU wi; 13~; ~ wi. 60L ................... 1~-17~ P~PBR t ~ fish ~ 8989', ~mig~ ~fl to 1 ~ Ot lower I/oo-la~ ~L~N 2 ~DU t~ ~oke & gas ~er. Ci~ ~ some ~e fl boE0m. 19um1~I WEL~N .75 ~itorwe~s~Mfl~. SITP & CP'. ~-~ ~N 7.S CIm & rnhe ~ 1o 12.2~. A~arently p~n to ke~ lmm ~ir~ too ~ f~U. MonEor wull--~ ~. ~~,---~L~ 2.5 PQH sbw. Dragg~ 5-t~ T~i~ to sw~, PU ~: 145k; 80 ~: 85k, ............... ~ " m~h~qTb~"~% ............................................................. .................................. ............ L ............. M~erialm~: 8~ sxs Na~ .......................................... .... Pn4dhoe l~'w Drill{no ~--~_ . ~" O__c'~IO. ti0n/Work0vor Roport AFE NO' 3301'4,1 R~I~ No'" ' o' 6t~!]B Oomplot.k,n Day., ' ' Supv Inl~' YA }..r,.--. ...... ~__., .......... .,son/me H~g , jRi{.m13,.,.,lh ~", ;,'n.~ L-UU ~ ~P-~~ ,-.--~A--- JP. dura~ Intrv{; ~8'-U'3~8' JSu;Jmum C.r.u, mi;' NIA JL~t ~g Ted: N/A .],. .... t~. ...... ' - " ~ a~.C~l~i (hda~): . 0900 ~ 5/2gt95 J rl~ RaJe~ [b'ld~te): NIA . ........ fi-I[F~' ''k,~.~,~,~ love, N/A Oaly 8 ,.{ Tm,~l 27 ]Daily ~12,560 [Cum $306,360 f'il{k{ JTyr~: ....... Jba{ar,~e: Loss: U,-,w Lo~s: , ~.~st: ICost: Dah~ {Wn~'jh,: ~R {Ws: 20 I"V/YI':N tA ~laridea: N/A iFluid Loss: N/A ~T. mpipi,): NJA IE'$' {OBM,: NJA ~ Wtr: N/A BHA De~rlD~ion: FT'A #1: Spsa~. ~r eaen."..~,n, ~tep ~Jn0, h--'l, ar~ mill, ~Jrnpnr jnm, ~1J~irn, 1.q--4.7~ DC · . Fu~ f)00 ] Fue i~ot mi. v/~r u'& w~F-- i · '~ i-'{'- '- w~ ~ u~ I .... ~,~ umum~:~ cq~.; s~aop ~ .i,'.:,: .... N/A i~, HtS'~I:"~/a~5 {~t Fire Dd{: 5/3{~51 ~ ~ ~.: ~'S~IiD~II: ~/1/Y5 lsPi,_~)~ N ~A .... No leoidents .... No - - - ~,v~ ,~. S~al drill, h~i wear r{~. ~r~ ~d ~r 4,75" DC's. MU ~A ~1, ~, drY, & PU 8,5" DP ~ 0704'. ~ flow~ s~y ~ ~nulus. ~t in. 15 ~n SITP & CP. 0 ~i ~en ~e~u~. P[impi~ 12~. R~w~ + aD ~Lq 11.7% ~h ~ em~ all Imm ~ ~le. C~lmm dm w~ 12~, wn~ln0 retu~n~ from + 11.fl~ ,,.12,. MDn~r FL drop~ s~. Material ml'4ed: 180 $¥$ NL~F{r prudl'~3e Bay D~ ~ ---_ D~jil' · '",¢--"~.tk3n ¢kove. r Re.oort,. MPU C-06i !'D; 6,588' PBD: ~u[ra~r; ~ORS 4Eg ~n.; 6475 !Daily JC~: "1~ ~e ~o,~) ~: 7", 26~ L-80 ~ 9~' pUm~J ~.1 Li~Size:Sxl0 GPM: ~A ~ NrA ~i'. N/A G~PumpR~e: .................. ~t: ~A ~ ~A NIA ~A N/A N/A In~n .............. ICaJmmu~l~ ' ' Volume: g~ .... ......... ~'1~1 ~ W~ I)~I~ ,,. 10/0 ann& 10~q. Fi~ In.or, D~ 2~3~130 ~E 1 RU lu~or, Pull~, RD ~or, .... ,, ,,.~= ...... on ~om, PU ~; 7~7S0 wi; ~~ P~ T~ 1 ~ PQH lay~ down 3,5" BTC ~mp~tion, ~ ~1 .~ .......... - ......... R~N~ 20~ bbl~ 12~ NuBr hum A-P~', .... i · ,. ,,ri I ~rudhee.._l~ayDrjltinm ~---- D~. · '9.r~'~let~oWWorkovP. r R~.pnrt Woll: MPU C-081 ' 9688' PBD: 9StiB' Tap of RiP 9~90' ' ' one' D ~r~r: N~RB 4FR ~ ' 6~7~ L~ $i9,390 I~""'~'~ ~1~ UU4 ~n a ~: ~OW WELLTO DRAW DO~ BHP({~i~ ~}~ ~t{un Lin~c N~A {~orated Int~: ~aa~a~u' 9~dace C~. pal: ~l~th{ ' i~mD ~.1 D~tsize:bxlo SPM: ~A ;GPM: ~A psi: NIA ~Pa.p~, NtA ~ ~. 2 Un~ Size: NfA ~SPM, ~A ~M; ~A p~i; ~A" ~ I .,. ,I '"'" ~ Welg~12.1 ...... 2B {PV~P: N :.,~ ~ N/A NtA NtA ......... .......... ,,, ,, ,,,, , r , B~: N/A [~HA L~n~h: N/A ! ....... m~.: ~A ~A NIA { ~A ~A ~A ...... · ,,, INn: Oui. N/A N/A NtA N/A ~A .~ ~,.,._,~.~:..--...- .... ~{~t~n Data ............... Sour~c MPU C.~81 Voru~ T~a F~id: W~ In{~n MPU Woll; I ~"~ .,,-- ~a~ Volume: , ,, ~ ................................. ~ '" ~ ~uo . ~ u~x I~"~ I~ w~., lU~. U~d; ~ I~r~; irked; 0 Lake I NO..A~CID~NT~- NO ~tP~LLS- nr~/nn Ki -wi I ~NT, TO M~OR 3-~UR BUILD UP 'FIN~ ~, PSI, ~R =10~ C~= 1~ (BUILD HAlE OF 10 PSI,PER 15 MIN,) ~ TOT~ OF 11~B~ ~OW ................. "'~ c~-0' ~ ~ .............. i 5.'~' '~'N ~J' i'0'i 'COW'W'~': ..... ~-~!30 ~-~ 1 ~HI IT IN WFI i FOR ! -Hng. TO CHF~ P~~SS YOTA'[ '~AO~0 B~. F~ la~ HR. PERIOD TOTAL ~ W~l'~' ~'~1~7 B~. T~. ~1 BUll T F~ TO , m,, ,, , 21~-~00 ~-~ B.5 CO~. TO ~OW WE~, F~D ~t ~'~;'~ THI~ PFR~D )TOTAl FOR WFJl = 2~ aBL 3-HRS T~, BUILD UP J 0315'1'~ =740 ~0~0 0345- 840 ~870 ~15~80 ~30~10 ,,m,, ,,, m ,, ,TOTAL FLUID FOR 24 HRS, PERI~ - 1361 BBL, TO~A~-~R WELL=~2~ ............................. :.;:. - . ................................. ~ .... i ................ . !I ........ :::",'J,' STATE OF ALASKA OIL AND GAS ¢..gO[q~EFIVATION COMMI~ON ~ Tut i~1~ OPERATION; D~fg; ,. WOW.~r; & DATE: .. 6t31 Ddg O~nl~a?.az~*:~_. NmL~r~ ~ N~, -'~....i.L.~ PTD ~ U~ OG8 IliO I'~J R§¢/.'~475 ' ~'...,;~,:~I:~:.~.~ .....';,*:,';,;,~h?'~'~:~,.,..:~X~;~-..' .*' ~' · ~ ;,~- ~..~ ~ .' ,:. :, *:~:::'r:' :- " ,~v:h?'. ",' ,,, *~', -'?~:~:: :;: FX~A"" ,,,,~.',,.,''. Alarm Tri~ Tank PI~ ~M I~ Y~ Y~ ~ ~t~h ~. ~; ~ ~ Y~ j if ~ur ~11 w ~ (e~ by ~ i~ ~fl tP ~n'~ ~ (='.,~.~ O~e P. i. ~vi~ at 379-1433 mimq . _ _ Il1 IrT ..~ Il I .-- ~: Ti}ht~n~ J~ ~t ~ ~{tMd ~ 11" { ~3 ~ ~ }lAn~ ..... gENT / / \ ,,, · 6-22-9§ ; 7:37.~ ' IS ... Prudhne..Bav Drillinfl ..----._ Iw"": ~"~'~': .~o.~,~ F~: ~s ~ ' ~~ ' ~,,,, I_~me $167,~ I~. $167,444 IG ~ .... I t~; ~ w~ r~; ~0" R~ ,~I (hr/dB~): ~ ~ 5/29~5 Hig ~1~ (hr~); NIA ...... Pumpl~.~ Uner~,:Bx'10 ~PM; N/A !GPM: 'N/A ~i, ~ 8~Pumpl'~n: N/A- L~wPu~: N/A ~ ~.2 UnarSEa: N/A "'~PM: N/A ~PM: ~/A P~ NIA SbwPumpRa.: ~A (p~): . ~TT[ BI ~ D~n: " '-- , ..... ,m~ ... ~s.~ - ~. . .u ,m, ~ ~: N/A ~ m ~: ~A O~e L~t ~n,~; NfA ~u~ ~ d~: NIA ""' ~'~'"~ ~"'~ ~;~ .... ~': "~ F": ~ '1~" "'* f~'~':--- I~'": Om: NIA ~A NtA ~A ~A ~A ~A ..... ,,.. . .,~ .~.,..,,,:~ .~.: ~ ,.-.: ,,A F,~: ,,~ i~r.'~ ,,~ f-~.~: ....... I~,*,.,~ .,~ ..... [,~lbn D~ ......... ~ur~ Vnbim,' ly~Fiu[d; Inl~, CC ~ ~te: N/A g .[, Wall; , ........ /C~mulmb~ '" Dai~ ~lume: N/A .~ ... 1.~d..~ ,-~ T --~ :- ....... ' Volume; ~A ,., Fu~ jFU~ ' 1'IFuel n ID'I. Wal~ J~. W~r'-' IU~; .. aB0, ~J Sour~; ~PX IRa'S: ',. a~lu,ed: J S~rage ........ I ~ Wombat [~,~ sx, nm. ~/~s,~'1~" ~)~ ~'/~,m. C~':~: ~ .........'lT~o s~,i: i..-,. . ~e Op~atian :P~ ~a Hra. ~at~ns F~ ~0 iT1 ........... nrta0 ML~J ~ ML~U BERM RIG & TH~ T~K, SCOPE UP DERRICK, o~nnO ~L.WLLL 4 [NiP~E UP ~D Lii~E$ ~0 TREE & ~ST TO 2000 PS1, TAKE ~ 12 P~. BRINE RIG UP LUBRICATOR & PU~ g~, RIG ~W~'LUBHICATOR i ~, PSi - 1~ 810P-1~0 ......... 1~i~u ~-~ .b BLEED~NUL~ IO ~0P~I, (~B~ ~UlDBAC~) {~HUTIN) ..... 1~ 1~0 ~WL .5 M~ITOlt 'i~'["A~ULU~UUILI }/~0~I, TO12~P~I,'IN'~-MIN, 14~4oo ~-~ ~ 4 ni FFn w,TI. I. vC~. UML, 0.4 igi%"~' I']'~'b'r H~ 'r ~. FLOWING THR~ C~KE' W/ "~" PRI. AV~. OF 35--~ RR!. PER. '[[~FLUID.FOH A I O I~ Ct ~B~ ~'~ ~-~' "='-~ ~UT IN ~ ~D M~ PSi. BUILT ~ROM 0 .1~0 T~. P~. IN ................. m,i,., ........ ANNULU~ - 130 P~I, TO 1~0 ~1, ......... ..... ........ . .......... ............ ,, , ...... .... ......... .......... .... . ....... ........... [ ........... ....... LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 12 June 1995 Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION MPD-02A 1 PLS FINAL BL + RF Run # 1 Run # 1 ECC No. 6266.01 6442.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and r. eturn to~ Petrotechnical Data Center BP Exploration (Alaska) Ina 900.~st Benson Boulevard ~~Alaska 99~08 , --'-" .......... -:---':- '- --~ 1 6 1995 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate Change approved program __ Pull tubing x Variance Perforate __ Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 780' NSL, 2325' WEL, SEC. 10, T13N, RIOE At top of productive interval 4624' NSL, 1199' EWL, SEC. 9, T13N, RIOE At effective depth 4710' NSL, 1309' EWL, SEC. 9, T13N, RIOE At total depth 4794' NSL, 1408' EWL, SEC. 9, T13N, RIOE 5. Type of Well: Development Exploratory __ Stratigraphic Service x 6. Datum elevation (DF or KB) KBE = 52' 7. Unit or Properb/name Mi/ne Point Unit 8. Well number MPC-8 9. Permit number 85-14 10. APl number 50- 029-21277 11. Field/Pool Mi/ne Point- Kuparuk River feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 55' Surface 5852' Intermediate Production 9553' Liner Perforation depth: 962O 7133 939O 6944 Size feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 13-3/8" 9-5/8" To surface 90' 90' 15o sx PF "E'Y920 sx "G" 5887' 4518' 7" 700 SX Class "G" 9588' 7107' measured 9170'-9184', 9228'-9248', 9259'-9265', 9374'-9402', 9348'-9368' RECEIVED true vertical 6773;6783', 6817;6833', 6841;6846', 6932;6959', 6912;6927' APR 2 4 1995 Tubing (size, grade, and measured depth) 3-1/2" 9.3# L-80 tubing to 9317' MD Nasl,,a t:)il & Gas Cons. Commissl0r ' Anch0ra~i~ Packers and SSSV (type and measured depth) BOT HB packer @ 9012' MD; BOT 2B packer @ 9293' MD; Camco WRDP SCSSV @ 1880' MD 13. Attachments Description summary of proposal × Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: 6/20/95 16. If proposal was verbally approved Oil__ Gas __ Suspended __ Name of~ Date approved Service Water Injector 17. I h--'~reb~ce¢Ify tJ:lat t_he foregoirjg is true and corr~~of my ~ge.-- ~ Signed ~ -E ~)~ Title Drilling Engineer Supervisor ~. ~ " FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval Plug integrity BOP Test *'"" Location clearance Approved Copy Mechanical Integrity Test Approved by order of the Commission Subsequent form required 10- Date Original Signed P.~, David W. Johnston Returned Commissioner Date ¢/~ 5""/,/~ S-''' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Mw C-08i RWO SUNDRY INFORMA£1ON Objective' The objective of this workover is to convert C-08i from water to WAG injection well with new 3-1/2" 9.2# L-80 EUE AB-Mod tubing and a 7" latch type packer. Also, the existing straddle assembly along with some unretrieved wireline fish need to be removed to optimize the injection rate during this RWO. This C pad WAG injector is critical for fulfilling future MPU gas disposal requirements and 5 mmcfd of gas injection capacity is needed from MP C-8i. Scope' 1. Pre- rig' Shut-in well minimum two weeks before rig move and obtain static pressure survey w/Amerada gauges. Pull bottom GLM @ 8,960'MD for well kill operation. Record SITP and SICP. Install BPV. Remove wellhouse and flowline for Nabors 4ES rig move. 2. MIRU Nabors 4ES workover rig. Perform well kill operation before ND tree and NU BOP. . Pull existing 3.5" 9.2# L-80 BTC tubing w/SSSV, 10 GLMs and seal assembly. Retrieve the straddle packers assembly. Clean out wellbore and millout junks to PBTD. . . . Perform wireline conveyed perforations at Kuparuk sands. RIH with 7" latch type packer on new 3-1/2" 9.2# L-80 A/B-MOD tubing and standard 3-1/2" tailpipe. Freeze protect the well before setting the tubing packer. ND BOP and NU tree. RDMO Nabors 4ES. Tlmina; -- Nabors 4ES will be making a well to well move from C-09 to C-08i on approximately 6/20/95. This workover should take approximately ~ rig time. MIRU / Kill well/ND_NU 2 days Pull 3-1/2" old tubing and L/D same 2 days Fish Straddle assembly 5 days (Note: the fishing operation may encounter similar problem as MP C- 09 for retrieving the straddle packer--BOT "2-B" packer) Cleanout wellbore 2 days Complete well w/3-1/2" new tubing 2 days Total' 13 days RECEIVED APR 2 4 i995 Alaska 0il & Gas Cons. Commission .AllCh0ra~ .'n DH, April 18, 1995, 3:11 PM WELL No. C-8 COMPLETION SKETCH MILNE POINT UNIT (I) APl No.: 50-029-21277 PERMIT No.: 85-14 COMPLETED: 2/13/85 LAST WORKOVER: N/A NOTES: 1. ALL MEASUREMENTS ARE FROM KDB OF ALASKA UNITED #3 KDB-SL = 52' KDB-GL = 35' 2. MAX. /_ = 52.0' @ 2900' 3. K. 0.P. = 500' 4. SLANT HOLE: YES 5. MIN, /_ = 36' @ 9400' 6. TREE TYPE: FMC 3 1/8", APl 5000# WiTH 3 1/2' 8 RD. TREETOP CONNECTION. 7, MIN. RESTRICTION IS @ 8. COMPLETION FLUID: 10.2 PPG NoCI-NoBr 9. FRACTURE STIMULATION: 6-22-85 LOW'ER KUP (2) 54,000 LBS 16-20 ISP FMC TUBING HANGER W/ 3 1/2' 'H' BPV PROFILE ~3 1/2", 9.2# L-80 BUTTRESS TUBING (2.992' I.D., 2.867" DRIFT) ~1880' 2225' 3228' 4136' 5073' 5702' 6364' 6999' -- 7664' 8296' ~8960' CAMCO W/WRDPI- TRDP-IA- SSA-SSSV LOCKED OUT GLM (~-'~---- POSS FLOW CUT~ CKING DUM~~ GLM CLM ',, CAMCO ~ ~/2" GLM ~ KBUG GLM GLM~LM /RECEIVED / Alaska 0il & Gas Cons. Commission GLM / Anchora, '~ PERFORATION DATA 12 SPF, 120' PHASING, 5" GUNS (ALL DEPTHS FROM DIL LOG 2-8-85) MIDDLE KUP' 9170'-9184' MD 6773'-6783' TVD L-8 9228'-9248' MD 6817'-6833' TVD L-9 9259'-9265'. MD . 6841'-6846' TVD LK-2 9374'-9402' MD 6932'-6959' TVD 4 SPF, O' PHASING, 2 5/8" GUNS (ALL DEPTHS FROM DIL LOG 2-8-85) | LK-1 - 9348'-9368' MD 6912'-6927' TV-O SLICKLINE TOOL STRING/FISH ~ BOT PBR, SEAL ASSEMBLY (3.00' ID) ----'-----9012' BOT 'HB' PACKER (2.890" ID) ~9048' CAMCO 'W-l' NIPPLE (2.812" ID) 9085' ~ 9126' CAMCO 'MMG-2' (;AS LIFT MANDREL 2.92" ID, 1.5' VALVES CAMCO 'MMG-2' (:;AS LIFT MANDREL 2.92" ID. 1.5" VALVES 91'65' BLAST JOINT (19.4"TOTAL LENGTH, 4.250' OD, 2.992' ID) ~9222' BLAST JOINT (38.30' TOTAL LENGTH, 4.250" OD. 2.992" ID) ~BOT 'GL' SEAL ASSEMBLY (5.00" ID) 9293' DOT '2B' PERMANENT PACKER (5.875" OD. 4.00" ID WITH 5.7' LONG MILLOUT EXTENSION 5.00' OD. 4.408' ID) · o 9,315' CAMCO 'D' NIPPLE (2.750" ID) " 9517' TUBING I'AIL E-LINE FISH NOTE: CONVERTED TO INJECTION 4/28/86 CONOCO ,uc. ANCHORAGE DIVISION 9390' 9508' 9588' TAGGED FILL 7/90 PBTD (CASING MEASUREMENT) T', 26// L-80 BTRS (6.276" ID, 6.151' DRIFT) I APPROVED BY: HDS DATE: 7-20-9.3 DRAFTED BY: SJN CAD FILE: WCOC8 '~ MPU C-8i Proposed Completion FMC Tubir~ Hm'~er w/3-1/2' 'Id' BPV I~C~. Conductor Casing 9-5/8" 36~ K-55, BTRC 15,887' MDI Surface Casing 3-1/2" Threaded L-80 Tubing AB-MOD connections 9.3 ppf, 2.992" i.d. Tree: FMC 3-1/8', APl 5K w/3-1/2" 8rd treetop connection KDB-SL 52' KDB-GL 35' KOP @ 500' Max Hole Angle: 52° @ 2,900' MD Latch Type Packer ( i.d. > tbg i.d.) Camco 'D' Nipple (2.75' i.d.) Tubing Tail w/WL Reent¢/: Guide - 9,000' MD ! / 7", 26#, L-BO Butt. Csg ./9,588' MD L I ' DATE 4/12/95 REV. BY DKW COMMENTS COMPLETION DATE WORKOVER DATE Completion Fluid = x.xx ppg F EICEIVED STIMULATION SUMMARY Lower Kup - 6/22/85 54000 lbs 16/20 ISP AF PERFORATION SUMMARY REF: LOG: DIL 2J8/85 SIZE SPF INTERVAL OPEN/SQZ'D 5" 12 120~ 120° 12 120~ 12 120~ 9,170' - 9,184' (6,773' - 6,783') 9,228' - 9,248' (6.817' - 6.833') 9,259' - 9,265' (6.84 I' - 6,846') 9,374' - 9.402' (6,932' - 6,959') open open open open LK-1 perforated at 4 9,348' - 9,368' MD (6,91Z - 6,927" TVD} · Reference Log: DIL 2/8/85 ~CURRENTPBTD I 9,508'MDj MILNE POINT UNIT WELL C-8i APl NO: 50-029-21277 . BP EXPLORATION (AK) :{ 2 4 1995 Gas Cons. Commission Anchora~. ~, /, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging Time extension __ Stimulate .__ Change approved program __ Pull tubing __ Vadance __ Perforate __ Other x 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory __ Stratigraphic Service 4. Location of well at surface 780' FSL, 2325' FEL, Sec 10, T13N, RIOE, Umiat Meridian, North Slope Borough At top of productive interval 4624' FSL, 1199' FWL, Sec 9, T13N, RIOE, Umiat Meridian, North Slope Borough At effective depth 4710' FSL,. 1309' FWL, Sec 9, T13N, RIOE, Umiat Meridian, North Slope Borough At total depth 4794' FSL, 1408' FWL, Sec 9, T13N, RIOE, Umiat Meridian, North Slope Borough 6. Datum elevation (DF or KB) 52' KDB 7. Unit or Property name Milne Point Unit 8. Well number C-8 9. Permit number 85-14 10. APl number 50- 029-21277 11. Field/Pool Kuparuk River Field feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9620 feet Plugs (measured) 7133 feet 9390 feet Junk (measured) 6944 feet Casing Length Size Cemented Measured d~l~ True vertical depth BKB Structural Conductor 55' 13-3/8" To Surface 90' 90' Surface 5852' 9-5/8" 150 sx Permf E 5887' 4518' Intermediate 920 sx Class G Production 9553' 7" 700 sx Class G 9588' 7107' Liner Perforation depth: measured 9170-9184, 9228-9248, 9259-9265, 9374-9402, 9348-9368 R E C E IV E D true vertical 6773-6783, 6817-6833, 6841-6846, 6932-6959, 6912-6927 MAR 2 ~ 1994 Tubing (size, grade, and measured depth) 3-1/2" 9.3 #/ft L-80 9317' ~l~Si~ U~I & Gas Cons. Commissi~ /L, lchorage Packers and SSSV (type and measured depth) BOT HB Pkr 9012', BOT 2B Pkr 9293', Camco WRDP SCSSV 1880' 13. Attachments Description summary of proposal__ Detailed operations program × BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: April 15, 1994 16. If proposal was verbally approved Oil__ Gas __ Suspended Name of appr?ver / Date approved Service Waterflood Injection 17. I hereby certify, that thetregoing is true and correct to the best of my knowledge. Signed (,~j /'~0¢-~ Title ,~'"-~0¢ q"--,,~ N ~vl,,l~,~ '~ FOR COMMISSION USE ONLY Date 14 Mar 94 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10-/4 C) Original Signed By Approved by order of the Commission David W. Johnston Form 10-403 Rev 06/15/88 ~ppruv~d COpy J Approval No. ~ F'" O ? ~' Commissioner Date ')/" Z r',//P C,/ SUBMIT IN TRIPLICATE DRAFT Slickline Procedure For C-8 March 3, 1994 RECEIVED M, R 2. 1 1994 U~I & Gas Cons. Commission Anchorage HISTORY The C-8 water injection well failed a MIT on 12-21-92. On 7-4-93, a 42' fish (two slickline tool strings) was retrieved from the well leaving the elastomer pack-off seal, some JDC latch dog fragments and a 3 1/2" F-Tubing Stop. On 7-16-93, the F-Stop was retrieved and a D-N-D Holefinder was run to a depth of 8979'WLM. The tubing was then pressured up 1000 PSI over SIWHP. For an unknown reason, the tubing and casing pressures stabilized for 30 minutes with 1000 PSI differential. On 7-19-93, the well passed a witnessed MIT and was placed on the Casing Pressure Resolution Plan (Conoco) six month test cycle. On 2-9-94, the C-8 marginally passed a MIT and the inspector asked that the operator submit a plan to repair the pressure migration. OBJECTIVE The objective will be to use a slickline conveyed plug (D-N-D Holefinder) to identify the leaking interval. If a dummied off GLM is suspected, replace the dummy valve and retest. If the problem is other than a leaking GLM, consult engineering for a path forward. SPECIAL SAFETY CONSIDERATIONS Beware of pressurized lines. Close the front casing valve where present due to a potential safety hazard. PLANNED OPERATION 1. Spot a bleed trailer and heater on the well and assemble scaffolding. 2. Hold a pre-job safety/environmental meeting with CAMCO including the job outline. 3. MIRU the CAMCO slickline unit with a 1 3/4" typical tool string with hydraulic jars.. 4. Cap SSV 5. Hook up unit hydraulics to the SCSSV control line. 6. RIH and pull WRDP. 7. With the well on minimum injection, RIH with a tubing brush to clean tubing walls prior to running the D-N-D Holefinder. 8. RIH with a 2.72" gauge ring to 9100' RKB. 9. RU the D-&-D holefinder for 3 1/2" tubing. RIH to 9030' RKB. 10. Record the pressure On the 3 1/2"x 7" annulus and using the module methanol pump, pressure up the tubing 1000 PSI over the SIWHP. If the casing pressure increases to near or equal to that of the tubing, repeat step 10, stopping below each GLM until the leak is isolated and then move on to step 11. If the tubing maintains the 1000 PSI increase, continue to raise the pressure 1500 PSI above the original S/I. If the tubing holds pressure for 30 minutes then it will be assumed that the leak is in the packer. POOH. Move to step 14. 11. Once the leaking interval is identified, POOH. Re-dress and RIH to the collar stop below the leaking interval and repeat step 10 at 100' (3 collars) per stop until the leaking interval is located. If the leaking interval is in tubing rather than a dummy valve, move on to step 14. 12. If a dummy valve is suspected of leaking, pull and inspect the 1" DV. Re-pack and set the DV. RIH with the test tool and re-test the tubing. If the tubing tests to 1000 PSI over SIWHP, RDMO well and place it back on injection. If the leak is persistent move on to step 14. 13. Perform a witnessed MIT. 14. RDMO. Consult engineering for path forward. RECEIVED MAR 2 1 1994 Alaska Uil & Gas Cons. Commission Anchorage H:\GROUP\PRODUCTN\PSWELLS\WELLFILE\CSTBGLEK.LEN CONOCO.) : . Conoco inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 December 17, 1993 Mr. Russell A. Douglass Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglass, Pursuant to our December 15, 1993 meeting, please regard this letter, as Conoco's request to cancel the following Applications for Sundry Approvals, Form 10-403: Well Approval Date Approval No. E-3 .~, ¢ - o ¢, / '7 4-28-93 93-101 C-8 ~,-,¢'.-,~¢ / ~f 5-18-93 93-117 B-19 2'~-,~-~ 3o 7-01-93 93-170 Please direct any questions regarding this matter to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist CC: Mr. Jack Hartz, AOGCC JHA, WCD/HDS Chevron Occidental E-3 Well File C-8 Well File B-19 Well File DEC 23 ]99;5 ~.~s'~ Oi~ & Gas [;ons. Commission A~chorage Conoco Inc. 3201 c Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 November 8, 1993 Mr. Blair E. Wondzell Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Wondzell, Mechanical Integrity Tests were performed on two Milne Point injection wells (C-8 and E-3) during the third quarter of 1993. Following is the information you requested on these two wells' C-8 C-8, which is on a six month cycle for testing, passed a MIT on August 27. This test was preceded by a series of downhole procedures intended to locate and repair a suspected tubing leak. These procedures, which included running a DND Hole Finder, cost $82,000. E-3 E-3 passed a standard four year MIT on July 19. The cost of this.test was $9oo. Please direct your questions and comments regarding this matter to me at 564-7660. Sincerely, -- _ Tom Yeager SHEAR Specialist RECEIVED N 0V - 9 199~ Alaska 0il & Gas Cons. C0mmis¢0~ Anchorage ... SCHLUMBERGER WELL SERVICE A DI%/---..~N OF SCHLUMBERGER TECHNOLOGY C(~, ORATION Conoco, Inc. 3201 "G" Street, Suite 305 Anchorage, AK 99503 Attention' Dorothy Bourbeau Gentlemen' Enclosed ore 2 BLprints of the. Company Conoco, Inc. Well PLEASE REPLY TO SCHLUMBERGER WELL SERVICESPouch 340069 Prudhoe Bay, AK 99734-006. Attn: Bernie/Shelley Injection Profile, Run 1, 10/26/93 MPU C-8 c~)&O --~57 3 State Alaska County North Slope 1BL prints, 1RF Sepia Chevron Production Company 1301HcKinne¥ Houston, TX 77010 Attn: Gary Fors~hoff 713/754-5618 Field Hilne Point Additional prints ore being sent to: i BLprints Conoco, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb, OF 2018 EPT_ on: i 1BIprints Conoco, Inc. 1000 South Pine Ponca City, OK 74602-1267 Attn: Janet Webb? 1239 EB ERS ../ Cnmmi m.~i mn . : 3001 Porcupine Drive ~'..Anchorage, AK 99501 Attn: Larry Grant prints The film is.returned to Conoco, Dorothy Bourbeau 1BL prints, 1RF Sepia OXY U,S,A,, Inc. 6 Desta Drive~ Suite 6002 Midland~ TX 79705 Attn: John Curtal qlS/6RS-SRO~ ~prints " tD NOv ~Chorago ~is~;OO' Receded 67: Da~e~ We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES $w$- t 327.F CH (7 BL/3 RF) Raymond N. Dickes DISTRICT MANAGEN Conoco Inc. 3:201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 May 28, 1993 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MPU C-8; REPORT OF SUNDRY WELL OPERATIONS Dear Mr. Wondzell, Attached are duplicate copies of the Report of Sundry Well Operations, Form 10-404, for attempting to repair a tubing leak in Milne Point Unit Well C-8. Please direct any questions or concerns regarding this form to me at 564-7660. SHEAR Specialist Att: cc: JHA, TJY, WCD/HDS Chevron Occidental C-8 Well File R'E' EIVED JUN - 8 199,5 Alaska 0ii & Gas Cons ..... Anctioi~ge ~ STATE OF ALASKA ~_., ALAS~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation shutdown M Stimulate Plugging M Perforate ~ Pull Tubing __ Alter casing __ Repair well X Other __ 5. Type of Well: 6. Datum elevation (DF or KB) 1. Type of Request: 2. Name of Operator Conoco Inc. Address 3201 C Street, Suite 305 Anchorage, AK 99503 Location of well at surface 780' FSL, 2325' FEL, Sec. 10, T13N, R10E, U.M. At top of productive interval 4624' FSL, 1199' FWL, Sec. 9, T13N, R10E, U.M. At effective depth 4710' FSL, 1309' FWL, Sec. 9, T13N, R10E, U.M. At total depth 4794' FSL, 1408' FWL, Sec. 9, T13N, R10E, U.M. Development .... Exploratory Stratigraphic Service X 52' KDB feet 7, Unit or Property name Milne Point Unit 8. Well number C-8 9. Permit number/approval number 85-14/93-027 10. APl number 50-029-21277 11. Field/Pool Kuparuk River Field 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 55' Surface 5852' Intermediate Production 9553' Uner Perforation Depth: measured 9620' feet Plugs (measured) 7133' feet 9390' feet Junk (measured) 8222' 6944' feet Size Cemented Measured depth 13-3/8" To Surface 90' 9-5/8" 150 sx Permf E 5887' 920 sx Class G 7" 700 sx Class G 9588' 9170-9184', 9228-9248', 9259-9265', 9374-9402', 9348-9368' True vertical depth 90' 4518' 7107' true vertical 6773-6783', 6817-6833', 6841-6846', 6932-6959', 6912-6927' Tubing (size, grade, and measured depth) 3-1/2" 9.3#/ft, L-80, 9317' Packers and SSSV (type and measured depth) CAMCO WRDP SCSSV @ 1880'; BOT HB Pkr @9012', 2B Pkr @9293' 13. Stimulation or cement squeeze summary Intervals treated (measured) RECEIVED Treatment description including volumes used and final pressure J u N - 8 199& 14. Prior to well operation OiI-Bbl Representative Daily Average Production or Injection Data ~ 0Il & uaS Cons. Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Anchorage 2114 BWPD 2780 2174 Subsequent to operation 2194 BWPD 2950 2966 15. Attachments Copies of logs and Suweys run Daily Re~)ort. of Well__Operations 17. I hereby e~iht that the f~ue and Signed '~ -~ [,,.~'~ g~- Form 10-404 Re'~ ~"q/15/88 ,~ 16. Status of well classification as: Oil Gas Suspended Service Waterflood Iniector correct to the best of my knowledge. Title SHEAR Specialist SUBMIT IN DUPLICATE MAY 25 '98 12:10 PAGE.006 CONOCO INC. PROJECT; ACTIVITY AT REPORT TIME: DAILY WELL ACTIVITY REPORT ALASKA AFE / FACI Li'l'-Y: WEATHER: ACTIVITY DAYS CUM/PLAN.: TEMP/WC:"Z~//0 ~F MD CURRENT DEPTH: SERVICE PERSONNEL' NO. ~H (; ~ ~ T~,"c3U~ .~ ~_-~-~.~"t~ ... "~-_~-~ .'H' FLUID TYPE/DENSITY; - - PPG I LOSSES TODAY/CUM. t RIG SAFETY PERFOR, ,M~,. NCE DAYS WITHOUT ! ENVIRONMENTAL INCIDENTS DAYS WITHOUT YEAR TO DATE LAST DOPE TEST DOPE TEST DUE ALL DALLY COSTS ! Ao¢cc..v.!SLT_t ................... 1 .... ENGINEI~-R ~iLLS SCSSV PLUG DESC. COST .SUMMARY PR EVIOU,?, TOTAL P~NNED BBLS J CUM. FLUIDCOST; $ $ ..... ;~n. TOTAL Alaska 0il & GasCons< uomm,=o .... COST 'Fu"iC, iOTS. g~ $ DALLY TROUBLE $ $ $ $ CUMULATIVE ~AY 25 ~9~ 12:0~ PAGE.005 CONOCO INC. PROJECT: ACTIVITY AT REPORT TIME: DALLY WELL ACTIVITY REPORT ALASKA AFEI FACILITY: DAYS CUM / PLAN.* [ WEA?HER:~JO~,I,,,..[~J.._~_~IL-,[ [fl,~.~TF--MPIWO'.,-[p [ ~ °F ACTIVITY DAYS WITHOUT YFAR TO DATE ENVIRONMENTAL INCIDENTS DAYS WITHOUT YEAR TO DATE iLAST BOPE TEST .T~_S..T_R_U~_ I AOGC¢ VISIT? ENGINEER IPILLS SCSSV PLUG DESC. BBLS I cuM. FLUID COST: BPV IN~_~'~ COST SUMMARY DAILY CUMULATIVE PREVIOUS TOTAL $ $ PI,.ANNEO $ $ TROUBLE $ TOTAL $ $ JU~t,~ ~- on laa~,,,,,,, AFE COST $ Alaska .0ii'.& '~I$-C0ilS. uommi~_lon' , EST. FINAL ......... ' .... · 4I~I;~ui au. CONOCO INC. DAILY WELL ACTIVITY REPORT P~GE. 004 ALASKA I ACTIVITY AT REPORT TIME: MD ACTIVITY I~ "8 SERVICE PERSONNEL . NO. FLUID TYPE/D, ENSITY;~..~._~'91 RIG SAFETY PERFORMANCE DAYS WITHOUT ,. YEAR TO DATE LOSSESTODAYtCUM. ~ / ALL DAILY COSTS PILLS · $ SCSSV OPEN/CLOSED BBt_E, CUM. FLUIDCOST; $,,,j~ll~~. J BPV IN/OUT PLUG DESC. COST SUMMARY DALLY CUMULATIVE ENVIRONMENTAL INCIDENTS DAYS WITHOUT YEAR TO DATE LAST BOPE TEST BOPE TEST DUE ~£EE I~V E"L) $ J U N "~-' 8s i99~ PREVIOUS TOTAL PLANNED TROUBLE TOTAL AOGOO VISI~ ENGINEER -' Alaska 0/I & Gas Coas. Commissim'~ AF~ COST Anchoraj;le CONOCO INC. WELD,, .~_... -- ~' ~,o~c-r~'-...~ ,~ -~~, ACTIVITY AT REPORT TIME: DALLY WELL ACTIVITY REPOR'~''~' ALASKA ACTIVITY FLUIDTYPE/DENS1TY; PPG I LOSSESTODAY/CUM, I RIG SAFETY PERFORMANCE 1 ]' DAYS WITHOUT YEAR TO DATE , LA,3T BOPE TEST BOPE TEST DUE AOGCC VISIT? ENGINEER ALL DAILY COSTS $ $ PILLS BBLS I CUM. FLUID COST: $ $CSSV OPEN/CLOSED BPV tN/OUT PLUG DE[SC. COST SUMMARY PREVIOUS TOTAL DAI ~.Y t CUMULATIVE TROUBLE[ $ IS AFE COST EST. FINAL~O~T $.. _/ Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 May 11, 1993 Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MPU C-8; APPLICATION FOR SUNDRY APPROVAL Dear Mr. Johnston, Attached are three copies of our Application for Sundry Approval, Form 10-403, for pulling tubing in Milne Point Unit injection well C-8. This procedure is being performed to address the excess casing pressure occurring in this well. Please direct any questions regarding this application to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist Attachment cc: CVL, JHA, TJY Chevron Occidental C-8 Well File , STATE OF ALASKA " ALA~ OIL AND GAS CONSERVATION COM~iON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon m Suspend __ Operation shutdown Re-enter suspended well m Alter casing Repair well __ Plugging_ Time extenfion__ Stimulate Change approved program Pull tubing x Variance Perforate Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development m 52' KDB feet 3. Address Exploratory__ 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic__ Milne Point Unit Sen~ice X 4. Location of well at surface 8. Well number 780' FSL, 2325' FEL Sec. 10, T13N, R10E, U.M. C-8 At top of productive interval 9. Permit number 4624' FSL, 1199' FWL, Sec. 9, T13N, R10E, U.M. 85-14 At effective depth 10. APl number 4710' FSL, 1309' FWI~ Sec. 9, T13N, R10E, U.M. 50-029-21277 At total depth 11. Field/Pool 4794' FSL, 1408' FWL, Sec. 9, T13N, R10E, U.M. Kuparuk River Field 12. Present well condition summary Total depth: true measured vertical 9620' 7133' feet feet Plugs(measured) P,E EIVE[ Effective depth: measured 9390' feet Junk (measured) 8222' MAY true vertical 6944' feet Alaska 0il & Gas Cons. C0ml Casing Length Size Cemented Measured depth True v~i~j~ Structural Conductor 55' 13-3/8" To Surface 90' 90' Surface 5852' 9-5/8" 150 sx Permf E 5887' 4518' Intermediate 920 SX Class G Production 9553' 7" 700 sx Class G 9588' 7107' Uner Perforation Depth: measured9170-9184', 9228-9248', 9259-9265', 9374-9402', 9348-9368' true vertical6773-6783', 6817-6833', 6841-6846', 6932-6959', 6912-6927' Tubing (size, grade, and measured depth) 3-1/2" 9.3#/ft, L-80, 9317' Packers and SSSV (type and measured depth) CAMCO WRDP SCSSV @1880';BOT HB Pkr @9012', 2B Pkr @9293' 13. Attachments Description summaryof proposal X Detailed operations program m BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: August 15, 1993 16. If proposal was verbally approved Oil __ Gas Suspended Name of =pprover ! Date approved Service Waterflood Injector 17. I hereby c~rtifythatl he foregoing is true and correct to the best of my knowledge. / Signed (~l~ /,,~J J.H. Andrew Title Sr. Production Engineer Date May 9, 1993 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness/I Appr°val No. ? Plug integrity__ BOP Test Location clearance Mechanical Integrity Test ~'~ "~uubsequent form required 10- ~(~ . .~o~.O,jO(~ Approved by order of the Commission [~avid W. ,.JohRStOR Commissioner Date~,,~1, - / ~,~/ ~'~ SUBMIT IN TRIPUCATE '~ Form 10-403 Rev 06/15/88 Milne Point Unit C-8 Workover Procedure Summary le RU wireline unit. GIH with BHP gauge and measure reservoir pressure. POOH and RD wireline. Calculate kill weight fluid required for workover. 2. RU tanks with completion fluid, Kill well. 3. MIRU workover rig.-ND tree, NU and test BOPs. · 'MU landing joint and PU to sting out of BOT PBR assembly at 9012'. circulate 10.2 ppg packer fluid remaining from the 3- 1/2" x 7" annulus with new kill-weight completion fluid. · POOH and LD 3-1/2" Btrc produCtion tubing. e PU redressed PBR seal assembly, 1 jt tubing, X-nipple preloaded with ball shear setting sub, and Otis HVT packer with SAN seal anchor. · TIH on 2-7/8" 8rd EUE API Mod tubing with Seallube thread sealant. · PU pressure-tested SCSSV assembly and space out to land at least 500' below the surface. · Land PBR seal assembly. PU and space out completion. Circulate inhibited fluid. Freeze-protect tubing and casing with methanol. 10. Land and lock down hanger. Pressure test 2-7/8" x 7" annulus. 11. Set packer. Pressure test 2-7/8" x 7" annulus to 2000 psig for State MIT. 12. ND BOPs. NU and test tree. 13. RD workover rig. 14. Return well to waterflood injection service. Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 January 27, 1993 Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: APPLICATION FOR SUNDRY APPROVAL Dear Mr. Johnston, Attached is an Application for Sundry Approval, Form 10-403, for locating and, if possible, repairing a leak in the tubing string of Milne Point Unit Well C-8. This well is one of the Milne Point water injectors that Was recently identified by our Casing Pressure Evaluation program as having excess casing pressure. Please direct any questions regarding this application to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist Attachments CC: CVL, JHA, TJY Chevron Occidental C-8 Well File RECEIVED JAN ~: 8 ~'~.~ ,Alaska Oil & Gas Cons. ~ornmissio~ Anchorage STATE OF ALASKA ALA$~ OIL AND GAS CONSERVATION CO M Ml,~b-q~ON ' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend .,~ee'ration shutdown __ Re-enter suspended well__ Alter casing __ Repair we-~-_~_''~''' Plugging__ Time extention__ Stimulate Change approved program Pull tubing __ Varianc~rforate Other t_X'~:~'~~~' 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development__ 52' KDB feet 3. Address Exploratory__ 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic__ Milne Point Unit Sen~ice x 4. Location of well at surface 8. Well number 780' FSL, 2325' FEL, Sec' 10' T18N' R10E' U'M'RE(E VED At top of productive interval 9. Permit number 4624' FSL, 1199' FWL, Sec. 9, T13N, R10E, U.M. 85-14 At efective depth ,]AN ~ g ~,~,~'~ 10. APl number 4710' FSL, 1309' FWL, Sec. 9, T13N, R10E, U.M..laska~ 50-029-21277 At total depth Oi~ & GaS C01]S. ~ Anchorage 11. Field/Pool 4794' FSL, 1408' FWL, Sec. 9, T13N, R10E, U.M. Kuparuk River Field 12. Present well condition summary Total depth: measured 9620' feet Plugs (measured) true vertical 7133' feet Effective depth: measured 9390' feet Junk (measured) 8222' true vertical 6944' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 55' 13-3/8" To Surface 90' 90' Surface 5852' 9-5/8" 150 sx Permf E 5887' 4518' Intermediate 920 SX Class G Production 9553' 7" 700 SX Class G 9588' 7107' uner Perforation Depth: measured9170-9184', 9228-9248', 9259-9265', 9374-9402', 9348-9368' true vertical6773-6783', 6817-6833', 6841-6846', 6932-6959', 6912-6927' Tubing (size, grade, and measured depth) 3-1/2" 9.3#/ft, L-80, 9317' Packers and SSSV (type and measured depth) CAMCO WRDP SCSSV @1880';BOT HB Pkr @9012', 2B Pkr @9293' 13. Attachments Description summaryof proposal X Detailed operations program__ BOP sketch -- 14. Estimated date for commencing operation 15. Status of well classification as: February 15, 1993 16. If proposal was verbally approved Oil Gas Suspended Name of a[ prover I Date approved Service Waterflood Injector 17. I hereby ce tifythat~e foregoing is true and correct to the best of my knowledge. / Signed ~ ~J /-/~%~j J.H. Andrew Title Sr. Production Engineer Date Jan 25, 1993 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. Plug integrity__ BOP Test Location clearance ~ ~ ~=-aI Mechanical Integrity Test __ Subsequent form required 10- '--/~-/- ..... :... C?? ~ Approved by order of the Commission David ~'~. ~-OhP..S~:OFI Commissioner el Ir~l~alT I1~1 T=IDI Form 10-403 Rev 06/15/88 Proposed Slickline Procedure for C-8 OBJECTIVE The C-8 water injection well failed a MIT on 12-21-92. The well was subsequently S/I and freeze protected at the request of Conoco Engineering. The objective will be to locate the leak and repair it if possible. The packer was tested and the leak is apparently in the tubing string. SPECIAL SAFETY CONSIDERATIONS Beware of the pressurized lines. Do not venture below 8000' MD due a fish in the hole. PLANNED OPERATION 1. The night prior to the slickline work, bleed the 3 ½" X 7" annulus to 0 PSI. 2. Hold a pre-job safety/environmental meeting with CAMCO including the job outline. 3. MIRU the CAMCO slickline unit with a 1 3/4" typical tool string with hydraulic jars. 4. Cap SSV and isolate SCSSV. 5. Pull the WRDP from 1880'RKB. 6. RU a OTIS T O test tool for 3 W' tubing (tubing collar stop type). 7. RIH to 7700'WLM and set the test tool in a collar below the GLM at 7664'RKB. 8. Record the pressure on the 3 W'X 7" annulus and using the module methanol pump, pressure up the tubing 1500 PSI over the SIWHP. If the casing pressure increases to near or equal to that of the tubing, repeat step 8, stopping below each GLM until the leak is isolated and then move on to step 9. . 10. 11. If the tubing maintains 1500 PSI, increase the pressure to 2500 PSi. Hold 2500 PSI for 30 minutes. If the tubing holds pressure for 30 minutes then it will be assumed that the leak is below 8200'RKB. Move on to step 11. Once the leaking interval is identified, POOH. Re-dress and RIH to the collar stop below the leaking interval and repeat step 8 at 100' (3 collar) per stop until the leaking interval is located. If the leaking interval is strictly in tubing, Move on the step 11. If a GLM is suspected of leaking, pull and inspect the 1" DV. Re-pack and set the DV. RIH with the test tool and re-test the tubing. If the tubing tests to 2500 PSI. RDMO well and place it back on injection. If the leak is persistent move on the step 11. RDMO slickline. Then utilize CAMCO E-Line to pinpoint the leak and set a 20' pack-off across the leak. It is not advisable to set a pack-off closer than 100' above the fish. WELL No. COMPLETION MILNE POINT C-8 SKETCH UNIT (I) APl No.: 50-029-21277 PERMIT No.: 85-14 COMPLETED: 2/13/85 LAST WORKOVER: N/A NOTES: 1. ALL MEASUREMENTS ARE FROM KDB OF ALASKA UNITED //3 KDB-SL = 52' KOB-GL = 35' 2. MAX. /_ = 52.0' @ 2900' 3. K.O.P. = 500' 4. SLANT HOLE: YES 5. MIN. /_ = ..36' @ 9400' 6. TREE TYPE: FMC 3 1/8", APl 5000// WITH .3 1/2" 8 RD. TREETOP CONNECTION. 7. MIN. RESTRICTION IS @ 8. COMPLETION FLUID: 10.2 PPG NoCI-NoBr 9. FRACTURE STIMULATION: 6-22-85 LOWER KUP (2) 54,000 LBS 16-20 ISP FMC TUBING HANGER W/ 3 1/2" 'H' BPV PROFILE ~3 1/2", 9.2# L-80 BUTTRESS TUBING (2.992" I.D., 2.867" DRIFT) ~ 1880' CAMCO W/WRDPI-TRDP-IA-SSA-SSSV LOCKED OUT ~ 2225' GLM ~ 3228' CLM --4136' GLM -- 507,3' GLM ~ 5702' GLM CAMCO 3 1/2" ~ 6364' GLM KBUG GLM ~ 6999' GLM ~ 7664' GLM 24' FISH 43' TWO SLICKLINE TOOLSTRINGS LATCHED ~ 8296' GLM TOGETHER ~960' GLM PERFORATION DATA 12 SPF, 120' PHASING, 5" GUNS (A'LL DEPTHS FROM DIL LOG 2-8-85) MIODLE KUP 9170'-9184' MD 677.3'-678.3' TVD L-8 9228'-9248' MD 6817'-68.3.3' TVD L-9 9259'-9265' MD 6841'-6846' TVD LK-2 9374'-9402' MD 69.32'-6959' TVO 4 SPF, O' PHASING, 2 5/8" GUNS (ALL DEPTHS FROM DIL LOG 2-8-85) LK-1 9348'-9368' MD 6912'-6927' TVD -SLICKLINE TOOL STRING/FISH E-LINE FISH NOTE: CONVERTED TO INJECTION 4/28/86 CONOCO INC. ANCHORAGE DIV1SION PBR, SEAL ASSEMBLY (3.00" ID) -'-------9012' BOT 'HB' PACKER (2.890" ID) CAMCO 'W-I' NIPPLE (2.812" ID) CAMCO 'MMG-2' GAS LIFT MANDREL 2.92" ID, 1.5" VALVES CAMCO 'MMG-2' GAS LIFT MANDREL 2.92" ID, 1.5" VALVES BLAST JOINT (19.4' TOTAL LENGTH, 4.250" OD, 2.992" ID) BLAST JOINT (58.30' TOTAL LENGTH, 4.250" OD. 2.992" ID) 'CL' SEAL ASSEMBLY (3.00" ID) 929,3' BOT '2B' PERMANENT PACKER (5.875" OD, 4.00" ID WITH 5.7' LONG MILLOUT EXTENSION 5.00" OD, 4.408" ID) 5' CAMCO 'D' NIPPLE (2.750" ID) 9317' TUBING TAIL 9390' 9508' 9588' TAGGED FILL 7/90 PBTD (CASING MEASUREMENT) 7", 26// L-80 BTRS (6.276" ID, 6.151" DRIFT) APPROVED BY: HDS DATE: 03/16/92 DRAFTED BY: SJN CAD FILE: WCOC8 STATE OF ALASKA A~KA OIL AND GAS CONSERVATION COM¥-w~SION APPLICATION FOE SUNDRY APPROVALS 1. Type of Request: Abandon .... Suspend. Operation shutdown Re-enter suspended well Alter casing ~ Repair well ~ Plugging m Time extention ~ Stimulate ~ Change approved program ~ Pull tubing ~ Variance x Perforate Other ~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KI~ Conoco Inc. Development__ 52' KDB 3. Address Exploratory__ 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic Milne Point Unit . Serxice X 4. Location of well at surface 8. Well number 780' FSL, 2325' FEL, Sec. 10, T13N, R10E, U.M. ~ C-8 At top of productive interval R'IL, (~ ~ ! V E D 9. Permit number 4624' FSL, 1199' FWL, Sec. 9, T13N, R10E, U.M. 85-14 At effective depth J,~ [~ 2 8 i~9~ 10. APl number 4710' FSL, 1309' FWL, Sec. 9, T13N, R10E, U.M. 50-029-21277 At total depth Alaska 0il & Ga~ G0ns, Cortl~ ~ut~. Reid/Pool 4794' FSL, 1408' FWL, Sec. 9, T13N, R10E, U.M. A~ich0r~ Kuparuk River Field 12. Present well condition summary Total depth: measured 9620' feet Plugs (measured) true vertical 7133' feet Effective depth: measured 9390' feet Junk (measured) 8222' true vertical 6944' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 55' 13-3/8" To Surface 90' 90' Surface 5852' 9-5/8" 150 sx Permf E 5887' 4518' Intermediate 920 SX Class G Production 9553' 7" 700 sx Class G 9588' 7107' uner Perforation Depth: measured9170-9184', 9228-9248', 9259-9265', 9374-9402', 9348-9368' true vertical6773-6783', 6817-6833', 6841-684~, 6932-6959', 6912-6927' Tubing (size, grade, and measured depth) 3-1/2" 9.3#/ft, L-80, 9317' Packers and SSSV (type and measured depth) CAMCO WRDP SCSSV @1880';DOT HB Pkr @9012', 2B Pkr @9293' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: February 15, 1993 16. if proposal was verbally approved Oil. . Gas Suspended Name of a[ prover J Date approved Service Waterflood Injector .... 17. I hereby ce tifythat~l~e foregoing is true and correct to the best of my knowledge. Signed ~ N~ /'~V/A~J J.H. Andrew Title Sr. Production Engineer Date Jan 25, 1993 FOR COMMISSION USE ONLY Plug integrity__ BOP Test Location clearance -~Off - '~' '~''~ ..... ~:'~'~'~'~ ~ '"'~).~"7/ Mechanical Integrity Test~ Subsequent form required 10- ~:.'::~'_ :i :-i~i;~ ~!~ _~ ~ Approved by order of the Commission David ¥¥'. johnston Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Proposed Slickline Procedure For C-8 OBJECTIVE The C-8 water injection well failed a MIT on 12-21-92. The well was subsequently S/I and freeze protected at the request of Conoco Engineering. The objective will be to locate the leak and repair it if possible. The packer was tested and the leak is apparently in the tubing string. SPECIAL SAFETY CONSIDERATIONS Beware of pressurized lines. Do not venture below 8000' MD due to a fish in the hole. PLANNED OPERATION 1. The night prior to the slickline work, bleed the 3 1/2"x 7" annulus to 0 PSI. 2. Hold a pre-job safety/environmental meeting with CAMCO including the job outline· 3. MIRU the CAMCO slickline unit with a 1 3/4" typical tool string with hydraulic jars. 4. Cap SSV and isolate SCSSV. 5. Pull the WRDP from 1880'RKB. 6. RU a T O test tool for 3 1/2" tubing (tubing collar stop type). RIH to 7700'WLM and set the test tool in a collar below the GLM at 7664'RKB. Record the pressure on the 3 1/2"x 7" annulus and using the module methanol pump, pressure up the tubing 1500 PSI over the SIWHP. If the~casing pressure increases to near or equal to that of the tubing, repeat step 8, stopping below each GLM until the leak is isolated and then move on to step 9. · · If the tubing maintains 1500 PSI, increase the pressure to 2500 PSI. Hold 2500 PSI for 30 minutes. If the tubing holds pressure for 30 minutes then it will be assumed that the leak is below 8200'RKB. Move on to step 11. 9. Once the leaking interval is identified, POOH. Re-dress and RIH to the collar stop below the leaking interval and repeat step 8 at 100' (3 collar) per stop until the leaking interval is located. If the leaking interval is strictly in tubing, Move on to step 11. 10. If a GLM is suspected of leaking, pull and inspect the 1" DV. Re-pack and set the DV. RIH with the test tool and re-test the tubing. If the tubing tests to 2500 PSI. RDMO well and place it back on injection. If the leak is persistent move on to step 11. 11. RDMO slickline. . _ Then utilize CAMCO E-Line to pinpoint the leak and set a 20' pack-off across the leak It is not advisable to set a pack-off above the fish. R~'~ Alaska Oi~ a Gas Co~s. u~.~.~, Anchorage ..~_~ STATE OF ALASKA ~ ~'--~ i-- ; .~ ALASKA OIL AND GAS CONSERVATION COMMISSION ' ' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown __ Re-enter suspended well __ Pluggj.ng __ Time extension __ Stimulate __ Pull tubing 2t. Variance __ Perforate __ Other __ 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Suite 200, I 5. Type of Well: Development Exploratory 9 9 5 0 3 Stratigraphic Anchorage, AK] Service T13N, RiOE, U.M. T13N, R10E, U.M. T13N, R10E, U.M. T13N~ R10E~ U.M. 4. Location of well at surface 780' FSL and 2325' FEL, Sec 10, At top of productive interval 4624' FSL and 1199' FWL, Sec. 9, At effective depth 4710' FSL and 1309' FWL, Sec. 9, At total depth 4794' FSL and 1408' FWL~ Sec. 9~ 12. Present well condition summary Total depth: measu red 9620 ' true vertical 7133 ' 6. Datum elevation (DF or KB) 52' KB 7. Unitor Property name Milne Point Unit 8. Well number 6-8 9. Permitnumber 85-14 10. APInumber 50-- 029-21277 11. Field/Pool Kuparuk River feet Plugs (measured) feet feet Effective depth: measured 9390 ' true vertical 6944 ' feet Junk (measured) 8222 feet Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 55' 5852' 13-3/8" To Surface 90' 90' 9-5/8" 1150 SX PERMF E 5887' 4518' 920 SX Class G 7" 700 SX Class G 9588' 7107' 9553' measured 9170'-9184', 9228'-9248' 9374'-9402' 9348'-9368' true vertical 6773'-6783' 6817'-6833' 6932'-6959' 6912'-6927' Tubing (size, grade, and measured depth) 3-1/2" L-80 9317 ' BOT HB @ 9012 , BOT 2B @ 9293' Packers and SSSV(type and measured depth) Packers - ' _.~.. SCSSV CAMCO WRDP- 1/TRDP-1A 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch ,~. ~v~' .... 14. Estimated date for commencing operation 15. Status of well classification as: December 5, 1990 16. If proposal was verbally approved Oil __ Gas __ Suspended __ Name of approver Date approved Service Water Ini ector 17. I hereby ce~rtify that tl~ foregoing is true and correct to the best of my knowledge. /L, Signed k._J,¢¢ /~0~ J.H. Andrew Title Production Engineer Date 11/26/90 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ B~O P/Test __ Location clearance __ Mechanical Integrity Test>~. Subsequent form required 10- / \ ORIGINAL SIGNED B'f LONNIE C. S~,!T~4 Approved by order of the Commission Aoproved O~opy Ret4.tr_n~9.~,% Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MPU C-8 Workover Procedure Summary · 3~ 4. 5. 6. · 8. 9. 10. Monitor SITP to determine reservoir pressure. MIRU workover rig on well. Kill well with NaBr/NaC1 brine (density determined by SITP). ND tree, NU and test BOP's. PU to release sting out of BOT PBR assembly at 9012'. POOH and LD 3-1/2" production tubing. TIH with redressed PBR seal assembly, new 3-1/2" EUE 8rd production string and new SCSSV. Hydrotest connections while TIH. Freeze protect. Space out, land and test hanger. ND BOP's. NU and test tree. RU slickline. GIH and pull tubing plug. RD slickline. Return well to waterflood injection service. SCHLUMBERGER WELL SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 T COMPANY AK OIL ~,, GAS ~r'~TqERVAT!ON COMM SSiON LOCATION ' 3001 PQR'iU~!NE DR. A~ENTION .... ~ ........ COMPUTING CENTER PRINT CENTER WELL NAME MiLNE PO SERVICES . 1 PL ADVISOR REPJORT · ~/~,~T~'~ or, TNT UNiT C-8 WELL NAME . SERVICES · 1 PL ADVISOR REPORT NO. OF BOXES' ALL IN ONE POX JOB NO. . .. 73975 ADD'L TAPES · -- NO. OF BOXES' ALL iN ONE ~ ~'' ,JOB NO. · 739~4 ADD'LTAPES ' -- WELL NAME .~/MILNE POINT UNIT C-12 SERVICES · 1 PL ADVISOR REPORT WELL NAME ~/ MILNE POINT UNIT C-ii SERVICES · 1 WF/PL ADVISOR REPORT NO. OF BOXES' ALL IN ONE BOX JOB NO. · 73959 ADD'L TAPES ' -- · WELL NAME ' M!LNE POINT UNiT C-IS SERVICES · i PL ADVISOR REPORT NO. OF BOXES: ALL ""~ ONE BOx 'JOB NO. ' 73973 ADD'L TAPES ' -- WELL NAME / MILNE POINT UNIT'C-15 SERVICES · 1 WF/PL ADVISOR REPORT NO. OF BOXES' ALL vN ONF.-,,~C~L, ~_I~9 NO. OF BOXES: ;AL7.~ IN ON£ .m-OX KF.. JOB NO. · 77~;~ ~ ~G~ JOB NO. · 739~6 ~ L ~ ~~~$~tO~ ADD'L TAPES · - - ADD'L TAPES · -- -- -Ancho~~ SCHLUMBERGER COURIER: DATE DELIVERED: RECEIVED BY:--.- ~----'- -' ....... -'--~--%'-- PL ADVISOR Production Logs Interpretation Using a Global Solver (V3) MPU C-8 Company - CONOCO, INC. Field - MILNE POINT Logging date - JUL 13,1990 Processing date - JUL24,1990 Reference - 73974 Schlumberger Well Services Alaska Division Computing Center 500 West International Airport Road Anchorage, Alaska 99518 907/562-2654 CONOCO, INC. Milne Point MPU C- 8 Production Logs 13-Jul-90 INTERPRETATION SUMMARY Data From Continuous Flowmeter Surface Injection Rate- 1430 BWPD Zone Injection Water % of Interval BPD Total GLMs 9085 - 9095 0 0.0 9126-9136 15 1.0 LK-1 9348-9368 1120 77.2 LK-2 9374-9402 315 21.8 Total Injected Water 1450 100.0% ®The well is deviated 52 degrees. ®The GLMs are not taking any water. Therefore the middle KUP, and L-8 / L- 9 were not evaluated. ®The LK - 2 Sand is just about covered with fill. lO (GAPI) ~0 9100 9150 9200 9100 9150 9200 GAMI~,4A RAY '1990 WAYER VELOCITY ~ER -200. (F/MN) 40. CONOCO, INC. Milne Point MPU C- [J~' Production Logs 13-Jul-90 COMPUTED CUMULATIVE INJECTION RATES At Down hole conditions Zone Depth Depth Total Water Oil Gas Global # DH Rate DH Rate DH Rate DH Rate Into- Feet Feet Bpd Bpd Bpd Bpd herence 1. 9374.0 9368.5 317. 317. 0. 0. 0.003 2. 9348.0 9340.5 1436. 1436. 0. 0. 0.006 3. 9318.0 9133.5 1436. 1436. 0. 0. 0.040 4. 9126.0 9094.5 1436. 1436. 0. 0. 0.337 5. 9087.0 9050.5 1450. 1450. 0. 0. 0.004 COMPUTED FLOW DESCRIPTION Assuming a I - 11/16" tool presence Zone Water Gas Mixture Friction Liq/Liq Gas/Liq Inject # Holdup Holdup Density Gradient Slip vel Slip vel Regime Gr/cc Gr/cc Ft/mn Ft/mn 1. 1.000 0.000 0.970 0.000 0.00 0.00 WATER 2. 1.000 0.000 0.970 0.000 0.00 0.00 WATER 3. 1.000 0.000 0.970 0.026 0.00 0.00 WATER 4. 1.000 0.000 0.970 0.026 0.00 0.00 WATER 5. 1.000 0.000 0.970 0.026 0.00 0.00 WATER CONOCO, INC. Milne Point MPU C- 8 Production Logs 13-Jul-90 PRODUCTION LOG MEASUREMENTS Zone Depth Spinner Thermo # #1 #1 Feet Ft/mn DegF 1. 9374.0 6.98 99.816 9368.5 99.816 2. 9348.0 30.67 99.870 9340.5 99.868 3. 9318.0 129.33 99.668 9133.5 99.144 4. 9126.0 128.74 99.130 9094.5 99.080 5. 9087.0 130.59 98.940 9050.5 98.826 MEASUREMENT RECONSTRUCTION QUALITY Measured minus Reconstructed values Zone Spinner Thermo # #1 #1 Ft/mn DegF 1. -0.01 0.000 2. -0.01 -38.939 3. -0.08 -0.194 4. -0.67 0.007 5. 0.01 -0.576 CONOCO, INC. Milne Point MPU C- Production Logs 13-Jul-90 PL Advisor Program Parameters for Zone 1 (at downhole conditions) Zone bottom depth ................................................ 9374. Feet Zone top depth .................................................... 9369. Feet Pipe internal diameter .............................................. 6.276 Inches Pipe Deviation ..................................................... 52.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 5293. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .................................................... 0.7200 Cp Reservoir fluid temperature ......................................... 150.0 DegF Minimum water rate ............................................... 317.0 Bpd Maximum water rate ............................................... 2000. Bpd Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.8250 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft./mn DegF PL Advisor Program Parameters for Zone 2 (at downhole conditions) Zone bottom depth ................................................ 9348. Feet Zone top depth .................................................... 9341. Feet Pipe internal diameter .............................................. 6.276 Inches Pipe Deviation ..................................................... 52.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 5293. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .................................................... 0.7200 Cp Reservoir fluid temperature ......................................... 149.9 DegF Minimum water rate ............................................... 1436. Bpd Maximum water rate ............................................... 2000. 8pd Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.8500 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft./mn DegF CONOCO, INC. Milne Point MPU C- 8 Production Logs 13-Jul-90 PL Advisor Program Parameters for Zone 3 (at downhole conditions) Zone bottom depth ................................................ 9318. Feet Zone top depth .................................................... 9134. Feet Pipe internal diameter .............................................. 2.992 Inches Pipe Deviation ..................................................... 52.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 5293. Psi Gas density ....................................................... 0.1320 Gr/cc Water viscosity .................................................... 0.7200 Cp Reservoir fluid temperature ......................................... 149.7 DegF Minimum water rate ............................................... 1436. Bpd Maximum water rate ............................................... 2000. Bpd Spinner flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.8860 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft./mn DegF PL Advisor Program Parameters for Zone 4 (at downhole conditions) Zone bottom depth ................................................ 9126. Feet Zone top depth .................................................... 9095. Feet Pipe internal diameter .............................................. 2.992 Inches Pipe Deviation ..................................................... 52.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 5293. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .................................................... 0.7200 Cp Reservoir fluid temperature ......................................... 148.5 DegF Minimum water rate ............................................... 1436. Bpd Maximum water rate ............................................... 2000. Bpd Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.8860 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft/mn DegF CONOCO, INC. Milne Point MPU C - 8{ Production Logs 13-Jul-90 PL Advisor Program Parameters for Zone 5 (at downhole conditions) Zone bottom depth ................................................ 9087. Feet Zone top depth .................................................... 9051. Feet Pipe internal diameter .............................................. 2.992 Inches Pipe Deviation ..................................................... 52.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 5293. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .................................................... 0.7200 Cp Reservoir fluid temperature ......................................... 148.2 DegF Minimum water rate ............................................... 1450. Bpd Maximum water rate ............................................... 2000. Bpd Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.8860 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft/mn DegF /~ [ LNE PO I NT UN [ T C-8 COAPLETED ON 2-13-85 6L = 35 MAX. ANGLE , 52 2900' KElP · 500' FHC 3 //8' APl TREETOP CONNECT. MEN. CONSTRICT[ON = 2.75 '0' NIPPLE AP] ND.: 50-029-21277 COHPLET]ON FLUID · 10.2 PPG NoC//NoBr F~.RFORAT 7 ' D LK=~: . 9348-9368' RD FRACTURE STIMULATION: ,~-~. ~4. ooo ,b,. ~-~o 1925' CAMCO TRDP SSSV lID = 2.81~) 4136' 5073' CAI'lCD 3 KBUG GLHS 5702' 6364' E999' 7664 ' 8~96' 8960' 'MMG-2 ' GLM ( ID · 8.92! .~5' A92~2' 2 ELAST JTS. (91 .4' 38.3' ) T,,,., 'CI,,.:,.SE~A~L,.,ASSE fElLY Lf ' U/ -U ' ~I~MAN~NT P~CKER V/ .]LLOUT [XTENS]ON ~3~5' CA.CO 'o' .~,,~, ~17'0 ' ~O~?~G TAIL 9508' PBTD 9588' ?', 26~ L-80 BTRS 16.276 ID, 6.151DRIFTI GEORGE'S '. I COURIER SERVICE 1824s2 I 344-3323 ...... - ADDRESS CITY '- STATE SHIPPER C///'.f' ;k'~'_"~ DATE ZIP ~,.:,' TIME '/, / ....... .. ..:j ',. '.-;, .:. · . CITY STATE "' ':"' ZIP RECEIVED BY '1--1 SAMEp/u ByDAY3PM .~:'i,.:'::.:_ ,, "':',J':': " .I--] ONE HOUR' '%''' '-- ?..:..'.'*~ ~ .. ,..:~.:-., .. - ........ ,~.. , . ........ .. ?: :~::~,~,~,,~ ONE HOUR $ · 24 HOUR $ - .~ - . OTHER $ .......... TOTAL $ '"' / - ,/,~ ~ , I TIME ' i SCHLUMBERGER WELL SERVICES A ~lVl$tON OF ~:::HLUME~£1~GER TECHNOLOGY CC~PORATION TE. XA.5, 772.51 -2 I ?~ JUL I ? lug0 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Aflention: Marc Shannon ~ RElY TO ~-..HLUIdBERGER WELL?ouch 340069 ?rudhoe Bay, AY, 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore 2 Bl. prints of the Company CONOCO, Inc. Well Milne Point Unit C-8 Injection Profile Log, Run 1, 7/13/90 On[ Field Milne ?o~nt Additior~ol prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER County Nmrth Alnn~ qtate A1 a ska ~rints, 1 RF Sepia CONOCO. Tnt: 1000 South Pine Ponca City. OK 74603 Attn: Log Library 1BL prints, 1RF Sepia OXY U.S.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrol *{915/685-5600) _L_~prints, 1RF Sepia Chevron U.S.A. 6001Boll~nger Canyon Road San Ramon, CA 94583-0943 Attn: Priscilla MacLeroy *(415/842-1OO0) 1BL ~riotf~'lRF~"Sepi~ Alas..fa>'Oil & Gas Conser¢~tion s sJ on 3001 Porcupine Drive ~f lknchorage, AK 99501 _.~' ~ttn: John Boyle..~/ The film is returned to Conoco, Log Library. prints prints prints Received by: Date: We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter S.W~,-- ! 3274~ Tom Painter Division Manager (con, ccc_) Conoco inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Mi!ne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Milne Point Unit. There are 19 active and 5 inactive production wells at Milne Point. AC/IVE: .~ _, '~ '-' ~ 'a-ii B-i n_'~, B--..-~, B-6, B-9, ~-~.,, ~ _ , 3, B-15, B-16, C-l, C-2, C-3, C-4, C-5A, C-7, C-9, C-13, C-14, C-16 STATIC: 5-20, B-21, B-22 C-1~7, -~.~-i$ Ail active production wells will be freeze protected by displacing the top 3000' of the tubing with a 1:3 diesel:oil-mixture. The annular fluid levels will be monitored for leaking gas lift valves. If necessary the production casing annulus will be displaced with a diesel:oil m~_xture to at least 3000'. Once the shut-down operation is completed, pressure surveys '~ ~ w~ Be run in all production wells. After the surveys are run BPVs will be installed and all SCSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive water injection wells in the Milne Point Unit. ACTIVE: B,8, B-12, B-14, B-17, B-18 C-8, C-Ii, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-I; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. %~e wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibiter will be displaced into the well. A 50:50 methanol:water mix will be used to carry the inhibitor. if you have any cuestiens on the shutdo~ procedure please ccntact Don Girdler at 56~-7637. Yours very truly, Painter ~v..is ich Manager STATE OF ALASKA ALASK'.~-~OIL AND GAS CONSERVATION COMI¥._.31ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) Conoco Inc. 59' KB feet 3. Ad~ C Street, Std. 200, Anchorage, Alaska 99503 6, U n ~t, o~; Prop,,erty name t,'t'l.Lrte '~'o'rnt Unit 4. Location of well at surface 780' FSL, 2325' FEL, Sec. At t~° of oroductive interval 24'FSL, 1199' FWL, Sec. At effective depth N/A At tg~a~,p~L' 1408' FWL, Sec. 10, T13N, R10E, U.M. 9, T13N, R10E, U.M. 9, T13N, R10E, U.M. 7. Well number 8. Permit number 85-14 9. APl num~)~r9_21277 50-- 10'~°~uparuk River 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9620 feet Plugs (measured) 7133 feet N/A feet Junk (measured) feet Length Size Cemented Measured depth True Vertical depth 80' 16" To Surface 115' 115' 5851' 9 5/8" 2070 Sxs 5887' 4518' 9554' 7" 700 Sxs 9588' 7107' measured true vertical 9374'-02'; 9348'-68'; 9259'-65'; 9228'-48'; 9170'-84' 6932'-59'; 6912'-27'; 6841'-46'; 6817'-33'; 6773'-83' Tubing (size, grade and measured depth) 3½", L-80, 9317' T R SCSSV @ 1925'; Ret..Pkr. @ 9012'; Perm. Pkr. @ 9293' Packers and SSSV (type and measured d~pt'h) 12.Attachments Description summary of proposal ,~ Detailed operations program ~~?'~OP~k~J'c~.~ ....... _~;-" 4 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Date approved 15. I here~]~qertify that the foregoing is true and correct to the best of my knowledge Commission Use Only Date Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by :i '.i. ""' Form 10-403 Rev 12-1-85 ,., Commissioner by order of / /- the commission Date / ~.2¢//~ ¢:,/,'~-.~, · Sub~it in (riplicate MEMORANPUM State of Alaska ALASICA OIL ~ GAS CONSERVATION TH RU: FROM: C. terton DAYE: May 15, 1986 Cha ~a-z FI LE NO.' D. BDF. 38 Lonnie C. Smith , TELEPHONE NO.' Commissioner Bobby D. Foster Petroleum Inspector SUBJECT: Mech. Integrity Test Conoco MPU C-8 Milne Point Field Friday, May 8, 1986: I met Jim Hall, Conoc° representative.,,and7 we went to'well C'-Si 'A pump unit was used to pressure up the x 3~" annulus to 1775 psig. The casing shoe is at 7100' TVD-9588 M.D. The pressure was held for 30 minutes and had dropped to 1690 psig. This pressure drop did not exceed the 10% limit, so I informed Jim that the casing integrity test was approved for injection. 32-001 A(Rev 10-84) STATE OF ALASKA ALASKA'~)'[L AND GAS CONSERVATION C0'I~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ 2. Name of Operator 7. Permit No. Conoco Inc. 85-14 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, Alaska 99503 50- 029-21277 OTHER [] 4. Location of Well 780' FSL, 2325°FEL, Sec. 10, T13N, RIOE, 5. Elevation in feet (indicate KB, DF, etc.) 12. .~2' KB 6. Lease Designation and Serial No. 47437 9. Unit or Lease Name Milne Point Unit 10. Well Number C-8 11. Field and Poo! Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought.on as an oil producing well on 12-3-85, and its suspended status should be removed. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sign~~ ~'/~-~,.///-__.~ - Title ,~//~~/ The space be?'/vq for Commission use Conditions drf Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate i LA(; 00N uNIT BOUnDaRY SCALE: mN ~L[S CONOCO . MILNF' POINT UNIT ' ' ' EXISTING DEVELOPMENT NOTE~: I. STATE PLANE CO.ORDINATES ARE ~NE 4. 2. ALL GEODF_. TIC POSITIONS ARE BASED N.A.D. 1927.' OFFSETS TO SECTION LINES ARE COMPUTED BASED-ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. I t.~CATION IN SECTION WELL I FROM S. L.INE F~0~ E. UNE 1168' 2256' 4. LOCATED WITHIN SECT. 10, T 13 N, RIOE, U.M.,AK. STATE PLANE CO-ORDS. 190RTHINGS 6, 029,450.20 1229' 2459' 6 ,029,509.9:5 c., I 1595'. 2326' 6,029 , 677.42 1'.:.344' .-2494' i 6 ,029,624.Z*/' --I 551' 2254' 6 ,028 ,854.07 C- 6 I 665' 2289' 6 ,028,947.80 -- i 1009' 2396' 6 ,029 ,290. 40 780' · 2325' 2428' 2360' C-9 ! 1114' 894' 6 , 029,062.00 6 ,029 , 395.22 6,029, 176.48 FASTINGS 558,20~. 57 557,999.98 558,131 .06 557,963.42 558,211 .T4 558 , 17.5.18 55a , 065.29 55 8,13 8.49 558 ,031.82 558 , I01 .82 GEODETIC POSITION I LATITUDE LON.GITUDE . 70°29' 27.868"N. 149° 31' 27.056"W~ i 6. I, 85t J.B.S. 7~29' 2~.471"N. 149°~1'3~034"W' I I0.~,~ J.B.~ I ' I * ~°29' 29. 598"N. 149° ~i' 34.0a~"W. ~ ' :--:~- ""-- 70°29'ZI.807"N 14~1' ZB.~7."W. I 3.18,~ 70°29'22.929"N 149°31' 28.007"W. I I 70°29' 26. S07" N 149° ~1' 31. 162"W.: ?0°29' 24. 0SS "N. 70029' 27.340" 70029. 25.18 4" N. i49°31' 29.060"W. I: " 149° ~i' 32.123"W.I ,. I, I~ 149034. 30. 113" W. I ' FIELD BOOK 22 -85 24- 84 . . J.S. 22 -8~ CERTIFICATE OF SURVEYOR : ~-.~. I HEREBY CERTIFY THaT .I AM PROPERLY LOCATION SURVEY MADE eY ME OR UNDER Cons.~ u'~mmissio~ 'C' PA D AS- BUILT WELL lOCATION CONOCO SCALE : I .'SHEET : I' · 400' ! I OF 2 CO,a~ ENTS : Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 October 28, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached are the Sundry Notices for the Milne Point C-3, C-7, C-8, and C-9 wells. Conoco intends to stimulate the above referenced wells. If you have any questions, please call Don Girdler at 564-7637. Very ~ruly yours, ~ R. J. Francis Manager-Engineering DRG/vv cc: MP C-3, C-7, C-8, C-9 Files .._, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. CONOCO, INC. 85-14 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, AK 99503 50- 029-21277 4. Location of Well 780' FSL, 2325' FEL, Sec. 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 6. Lease Designation and Serial No. ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point C-8 11. Field and Pool Kuparuk River 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well I--1 Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The subject well is proposed for a 12-3 mud acid stimulation treatment to improve the productivity from the Middle Kuparuk formation. The 12-3 mud acid treatment has been successful on the Middle Kuparuk formation in offset wells. RECEIVED OCT 0 1985 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~. ~. ~ l~ r~,/.~ ) Title Sr. Production The space below for Commission use Engineer Date 10-28-85 Conditions of Approval, if any: llRl~llli~L SI;I~ED BT I.O,~IE C. SI~ITFI Approved by COMMISSIONER Approved Co,ay By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Page~ 1 of 2 SCHLUMBERGER OFFSHORE SERVICES CONOCO, INC 320L "C" Street, Suite 200 Anchorage, Alaska 99503 A~emticn: Mi/.e Bradshaw A Division of Schlumberger Limited HOUSTON. TEXAS 7700! ].o/111/85 I~'..F.~t.~l~ ~i~_Y TO Pouch 340069 Prudhoe Bay, ~ 9973a ATTN: hrcia Sherburne Gentlemen: Emc!osed ore 3 B.L_prints of the Cc-mpqny GONOG0 liNG Fieid. M/LNR ?OINT ~.RUN ONE, 6/21/85 · County NORTH SLOPE qtote ALASKA Additional prints are being sent to: prints & lRF Coast & Alaska Division _2_20 MAple Court. Suite 284 Veqtur. 3, CA 93003 AT]i~: Phil Salvador % Randy Aitobe!li I BL prints & 2RF Chevron USA INC P 0 Box 107839 AnchoraKe, Alaska 99510 ATTN: J. L. Weaver I BL ~rints & IRF r_g_O];,~i.C O. !NC il~ ~c~z~ ~uilding Ha~s.n on, T~ 77~57 ATTN: Gerald ~el % George Lamb 1 BL_mrints ~~_ax 1267 ~nca ~lity, OK 74603 ATTN' ~. E. Gilli!and/6356RW /_nservation Commission Porcupine Drive {:horace_ A]aska qq501 ~/~ The film is_ RETURNED TO CONOCO We appreciate the privilege of serving you. 1 BL prints & Ghevron USA, iNC . 6OOi Bei!inger Canyon Rd __San Ramone AT~,I: Geese Webb ~_i_I~:rints & iRF _Champlin Petroleum Company 0 Box 1257 Engiewood, CO 80150 ATTN: James T. Laws Jeff DeJarnett __L_BL-orints & 1~ Reading & Bates Petroleum Co 3200 Mid Continent Tower Tulsa: OK 74103 ATTN: C_E. ~m~ry: Jr /1ATE ' ~Ohorago G0. U~lSS/0~ Ve~ truly yours, SCHLUMBERGER OFFSHORE SERV{CES Charles R. Merriman Page 2 of 2 SCHLUM~IERGER-OFFSHORE SERVICES A Division cf Schlumberger Limited 10/16/85 CONOCO, lNG 320L "C°' Street Anchorage, Alaska 99503 AtremT.On- Mike Bra~dshaw Pouch 340069 Prudhoe Bay, ~ 99734 AT~: ~rcia Sherburne TNC printsof The PL, RUN ONE, 6/21/85 , "C/e! i C-8 ,CcunW_~ORTH ST,OPE Additional prints are being sent to: i BL ~r;nts & Cities ~ervice 0ii & Gas Cord P__Q_~o x 939 3akersfleld, iA. 93302 ATTN: Neil Buttram % Jim Quinn prints prints prfnts ~rints prints prints prints The film is We appreciate the privilege of serving you. ,-.c IVED -asKa 0il & Gas Co~s~ CommissJo~ Very truly yours, ^nchora~e SCHLUMBERGER OFFSHORE SERVICES OI~tCT MANAGE~R : John R. Kemp Manager of Alaskan Operations ( cortoco. Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 August 13, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed please find the drilling "well histories" from Conoco's Milne Point Unit wells No. C-5, C-6, C-8, and C-10. These are being sent in response to your request dated August 2, 1985. If you require additional information concerning these well histories, please contact Kent Stolz at 564-7641. Very truly yours, tions : STATE OF ALASKA ,,-~'~.~ ~ ~ ALASKA~' '_ AND GAS CONSERVATION CC 'MISSION ' ONTHLY REPORT = DRILLING AND WOR"KOVER OPERATIONS. il. Drilling well [] Workover operation ~ 2. Name of operator 7. Permit No. Conoco Inc. 85-14 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 50-029-21277 4. Location of Well at surface 780' FSL, 2325'FEL, Sec. 10., T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 52' KB ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well No. CNo. 8 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of July ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Bailed frac sand out of tubing using slickline. MI and RU Coiled Tbg. Unit & pump truck. Mix 200 bbls. 15% NaC1 to 9.3 ppg. Add HEC Polymer. Not able to wash past ±9414'. Displace tbg. w/diesel. 13. Casing or liner run and quantities of cement, results of pressur9 tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run NONF. RECEIVED 6. DST data, perforating data, shows of H2S, miscellaneous data NONE. Well suspended. Alaska Oil & Gas Cons, Cqmrnission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 DRILLING WELL COMMENCEMENTS Kuparuk River Field - N~,~ah Slope Borough, Alaska W.'~_~'- 52.05955% Milne Pt. C No. 8 - CONFIDENTIAL (9802'-Kuparuk River) AFE 10-61-1089 API No. 50-029-21277. Ak. Permit No. 85-14. Elevation: 52' KB. Location: 780' FSL, 2325' FEL, Sec. 10, TI3N, R10E, U.M. 1-26 - Skid rig. Set Hydril & diverter system. NU diverter system. Mix mud. PU kelly. 1-27 - Test diverter system, State of Alaska Rep. present, clean out conductor. Spud in @ 90', PU ~D, ck. battery pack, install vent valve & orient. Drlg. f/90' to 426' & survey (tool failure, test MWD). POOH, service MWD, replace LDC. TIH & orient, MWD o.k. Drlg. f/426' to 612' (w/Mach I Navidrill, only .4° build). POOH & change BHA (w/Mach 3 Navidrill 2.0" bent sub). Ck. out ~D battery pack & orient MWD w/2.0° bent sub. TIH, survey - take tool face (MWD failure) testing surface equip. POOH, check out MWD electronics - could not repair. Change out MWD. Surveys: Depth Angle Direction 542' .4° N12W 1-28 - Install electronics & orient MWD. TIH to 612'. Drill & survey to 1436'. Trip for new BHA (angle building). Replace cracked stb. Drtg & survey f/1436' to 2754'. Surveys: pepth ~ngle Direction 720' 3.2° N64W 905' 8.2° N70W 1081' 14.0° N62W 1231' 18.0° N57W 1386' 21.9° N55W 1562' 25.5° N56W Mud Wt. - 9.1 ppg. Visc. - 38 Alaska United Rig #3 (0-2-0) Depth Angle Direction 1752' 26.7° N55W 1906' 31.8° N55W 2058' 35.5° N54W 2244' 37.6° N55W 2427' 39.7° N56W 2613' 44.0° N56W Kuparuk River Field - North Slope Boro~ugh, Alaska Drlg. Foreman - R. Larkin W.I. - 52.05955% Milne Pt. C No. 8 - CONFIDENTIAL (9802'-Kuparuk River) AFE 10-61-1089 1-29 - POOH, retrieve survey. Change BHA, PU Mach I Navidrill & orient ~D. Change venting valve, re-orient MWD & surface test. TIH. Drlg. & survey f/2754' to 2891' (MWD failure). POOH, change vent valve. TIH & survey. Drlg. & survey f/2891' to 4575'. Surveys: Depth Ang~. Direction Depth A~g~e Direction 2831' 51.2° N52W 3751' 49.4° N42W 3072' 49.4° N49W 4238' 48.7° N40W 3441' 48.2° N48.2W Mud Wt. - 9.2 ppg. Alaska United Rig #3 Visc. - 37 (O-3-O) Drlg. Foreman - R. Larkin Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 8 - CONFIDENTTAL (9802'-Kuparuk River) AFE 10-61-1089 1-30 - Drlg. to 4670'. No differential across Navidrill. Mix pill, POOH to inspect Mach I. Tight hole f/2860'-2725', 670'-930'. Tried unsuccessfully to run back through. Change BHA for wiper trip. Test Navidrill & ~D - o.k. PU BHA for wiper. Cut drlg. line 100'. TIH, wash & ream through bridges ~ 2.5v8', 2841' 3127' 3817' Drill 14' to 4688' for cleanup. Circ. hi visc. sweep POOH or Navidrill~ bole o.k. PU new BHA, test & orient ~JD & TIH. Drl§. f/4685' to 4800'. Note: Trip back to bottom after wiper run improved considerably, no problem w/motor. Surveys: Depth Angle Direction 4702' 49.9° N40W Mud Wt. - 9.3 ppg. Visc. - 40 Alaska United Rig #3 (0-~-0) Drlg. Foreman - R. Larkin ~Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 8 - COl ~ENTIAL (9802'-Kuparuk River) FE 10-61-1089 1-31 - Drlg. f/4800' to~'5439' & survey. (MWD failure)~t~'lng DOT sub. Wireline survey @ 5439', 'inst. depth @ 5339'. Drlg. f/5439' to 5935'. Circ. & condition mud f/logs. Wireline survey @ 5935', inst. depth @ 5800'. Pump pill & POOH, SLM, no tight spot's until I134'. Work pipe up, but could not go down, POOH, very slow, not swabbing. Surveys: Depth Angle Direction 5339' 48.25° N40W 5800' 47.50° N37W Mud Wt. - 9.4 ppg. Visc. - 34 Alaska United Rig #3 (0-5-0) Drlg. Foreman - R. Larkin K~paruk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 8 - CONFIDENTIAL (9802'-Kuparuk River5 AFE 10-61-i089 2-1 - POOH, change BHA. Service MWD. TIH. Tight spot @ 2952', 3675' to 3705', 8' fill. Circ. POOH, f/logs, no tight spots. RU Schlumberger. Log w/LDT-CNL-GR f/5935' to 3000', DIL f/5935' to 119'. RD Schlumberger. LD BHA. RU csg. crew. Run 9-5/8" 36# L-80 Butt. csg. Mud Wt. - 9.6 ppg. Visc. - 43 Alaska United Rig #3 (0-6-0) Drl~. Foreman - R. Larkin Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 8 - CONFIDENTIAL (9802'-Kuparuk River) AFE 10-61-1089 2-2 - Ran 148 jts. & 1 pup of 9-5/8" 36# K-55 Buttress csg; 9-5/8" shoe @ 5887'; float collar @ 5809'; circ. through tight hole f/3694' to 3770' while running csg. Circ. & recip, pipe w/15' strokes. Pumped 40 bbls. 11.0 ppg Sepiolite Preflush; mixed 1150 sks. (403 bbls) of 12.3 ppg Permafrost E cmt. followed w/920 sks (188 bbls.) of 15.8 ppg Class G cmt. w/1.0% CaCl~ & 1.0% CFR-2; displaced w/420 bbls. of 9.6 ppg mud. Pipe stuck off bottomZ@ 180 bbls. of disp. pumped; did not bump plug as disp. pressure reached 3100 psi @ 420 bbls. displaced; displacement was 31 bbls. short; floats held; full circ. throughout job; no cmt. returns to surface. CIP @ 1830 hrs; ND diverter; top cmt. job - 25 sks (9 bbls) of 12.3 Permafrost E cmt. 2-3 - Finish top job. Install speed head & NU BOPE. Test BOPE. Tested 5" pipe rams, upper & lower, blind rams, 2 HCR + manual valves, upper & lower kelly cocks & art valves, & choke manifold to 500 psi & 5000 psi; tested annular BOP to 350 psi & 3500 psi. Also tested function test accumulator & warning systems, test witnessed by AOGCC. PU 8~" BHA & TIH to top of cmt. @ 5326'. Drlg. cmt. f/5326' to 5626'. Wellhead measurements = KB to base flange = 36.35, KB to GL = 37.10. Morning tour - safety meeting & BOP drill w/drilling 2 min. Crown-o-matic ck'd, o.k. 2-4 - Drlg. cmt. f/5626' to 5940'. Tested formation, E~ = 12.2. POOH, change BHA, orient MWD & Navidrill. TIH to 59~0'. Drlg. & surveying to 6575'. Surveys: Depth Angle Direction Depth Angle Direction 5977' 47.2° N37W 6290' 47.8° N41W 6132' 46.2° N37W 6447' 48.1° N43W Evening tour crew safety meeting & BOP drill tripping 5 min. Mud Wt. - 9.2 ppg. Visc. - 32 Alaska United Rig #3 (0-9-0) Drlg. Foreman - R. Larkin · Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 8 - C0¥ ~ENTIAL (9802'-Kuparuk River) YE 10-61-1089 2-5 - Drlg. f/6575' to~99'. Mix pill & POOH into sho.~_~-Disassemble & repair low clutch. TIH w/30' to bottom @ 6699'. Drlg. & surveying to 7731'. Surveys: Depth Angle Direction Depth 6789' . 49.6° N46W 7338' 7070' 46.6° N48W 7664' Mud Wt. - 9.6 ppg. ~ Visc. - 48 Alaska United Rig #3 (0-10-0) Kuparuk River Field - North Slope Borough, Alaska Angle Direction 46.5° N48W 47.2° N48W Drlg. Foreman - R. Larkin W.I. - 52.05955% Milne Pt. C Mo. 8 - CONFIDENTIAL (9802'-Kuparuk River) AFE 10-61-1089 2-6 - Drlg. & surveying f/7731' to 8921'. POOH, LD Navidrill & MWD, change bits. TIH, 18' fill @ 8903'. Clean out t° bottom @ 8921'. Drlg. f/8921' to 8950'. Surveys: pepth Angle Direction 7946' 45.0° N50W 8130' 45.3° N50W 8444' 43.6° N49W Mud Wt. - 9.9 ppg. Visc. - 38 Alaska United Rig #3 (0-11-0) Depth Angl___~e Direction 8633' 44.4° N50W 8856' 45.2° N50W Drlg. Foreman - R. Larkin Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 8 - CONFIDENTIAL (9802'-Kuparuk River) AFE 10-61-1089 2-7 - Drilling f/8950' to 9620'. Circ. bottoms up. Short trip 15 stds f/9620' to 8170' (had tight spot f/9369' to 9299'). Ream f/9505' to 9620' (had 8' firm fill on bottom). Circ., pumped 90 visc. sweep to clean hole. Mud Wt. - I0.0 ppg. Visc. - 36 Alaska United Rig #3 (0-12-0) Drlg. Foreman - D.L.Mountjoy Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 8 - CONFIDENTIAL (9802'-Kuparuk River) AFE 10-61-1089 2-8 - POOH f/9620' w/tight spots @ 9213' to 9053' and 7640' to 7456'. RU Schlumberger & TIH to 7400', could not get below 7400' w/logging too].. POOH & RD loggers. TIH to 2200'. Cut drlg. line. TIH f/2200' to 9620' bridge @ 7400' ~ , no fill. Circ. & cond. mud. POOH f/9620' w/tight spots @ 921 ' to 9053' and 7640' to 7456'. RU Schlumberger & log w/GR-CCL-DIL-SP-CNL-LDT f/9610' (TD) to 8550'. Logged w/GR-CCL-DIL-SP f/8550' to 5893'. POOH W/logging tool, RD loggers. Surveys: Depth An~le Direction 9560' 33° N43.5W Mud Wt. - 10.2 ppg. Visc.- 37 Alaska United Rig #3 (0-13-0) _ Drlg. Foreman - D.L.Mountjoy Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% M±lne Pt. C No. 8 - CONFIDENTIAL (9802'-Kuparuk River) AFE 10-61-1089 2-9 - TIH to 9608', tight spot 7830'-7890'. Wash 12' fill, 9608' to 9620'. Circ. & cond. hole. POOH f/9620' to surface, LD DP & BHA. Puli. wear ring & change to 7" rams. RU csg. crew. Run 180 its. of 7" 26# L-80 Buttress csg. Lack 63 its. of being on bottom; circ. csg. @ 5890' w/50% returns. Continued to run in ho]e, had ful1 returns to its #30, started losing 1/2 bbl./it until it. #65, then regained full returns until, jt. #120, jt. #120 to #180 losing approxi- mately 1/2 bbl/jt. - . 2-10 - Ran 63 jts. of 7" 26# L-80 Buttress csg. (total 243 jts). Shoe ~/9588', float collar @ 9508, ECP #1 @ 9310, ECP #2 @ 9295', marker it. @ 9006'. ~s_ed-~70 bow spring centralizers and 30 rigid, continued to lose 1/2 bbl/jt until on bottom. C~rc. csg. @ 2 BP}~ with no returns for 1 hour, had 5% returns for last 30 minutes. Pumped 40 bbls. of water w/2 ppb Desco @ 2 BPM w/5-50% returns (8.4 ppg). Test lines, m~xed & pumped 700 sks. C]~ass "G" cmt., 15.8 ppg w/l% CFR-2 andO.3% Halad 24 w/50-100% returns. Displaced cmt. w/362 bbls. of NaCl-BrC1 fl0.2 ppg) w/100% returns, bumped plug w/1200 psi & set ECP's w/3500 psi. Floats held. Cmt. in place @ 2:05 p.m. 2-9-85. RD cementers & tested 7" packoff to 5000 psi. Back out ]~anding it. & LD csg. tools. RU Dresser, run 6.125" gauge ring f/surface to 9460' (run #1). RU gyro & ran f/surface to 9450' ! .... ~o~ ~ ~_r~T. ~/qA7~' ~n ~qo0' (run ~3~. 2-11 - TIH w/CCL & perf gun (run #4), perf. LKo f/9382' to 9402', (run #5) perf. LK~ f/9374'-9382', 'perf. Laminated Zone 925~9'-~5' -(run '#6) TIH to 500' logging unit broke down. Repair unit. TIH w/CCL & perf. gun (run #6), per- forated Laminated Zone 9228'-9248', (run #7) perforated Middle Kup 9170'-91gA', total 768 shots. All shots 120° phased, 5" guns @ 12 spf. TIH-'~'7~-"~ junk basket to 9350' (run #8). TIH w/BOT 2-B permanent pkr, millout extension, 6' sub, Camco "D" nipple, and shear out sub, set pkr. @ 9297'. RD Dresser Atlas. 317~ Change & test ~ rams to 500# & 5000#. TIH w/BOT seal assembly, locator sub, gas lift mandrels, blast its., HB pkr, seal assembly & 91 its. @ 3~" 9.3# L-80 Btrc. tbg. Run tbg. & gas lift mandrels. Alaska United Rig #3 (0-16-0) Drlg. Foreman .- D.L.Mountjoy Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 8 - CONFIDENTIAL (9802'-Kuparuk River) AFE 10-61-1089 2-12 - TIH w/f99 its. (2~0 total in well) of 3~" 9.3# L-80 BTRC tbg. & comple- tion equipment to pkr. @ 9297'. Ran injectivity test, no communication between perfs @ 9402' to 9382' and 9254' to 9265'. Dropped ball set BOT HB pkr. @ 8995' w/2800# sheared PBR when pkr. set. Space out tbg, PU tbg hanger & landing jt; NU control line & test control line, MU displacement lines. Unthaw diesel lines for displacement, repaired electrical plug on diesel, pump, displace tbg. w/diesel. Work tbg. & rotate to get into PBR, ].and tbg. & test tbg. & hanger to 1500# for 15 min., o.k. Pump NaC1-NaBr through filters to storage tank. Attempt to displace mud through 7" x 9-5/8" annulus, ND displacement lines. LD landing it. & tbg. tools. Change rams. ND BOP's. Alaska United Rig #3 (0-17-0) Drlg. Foreman - D.L.Mountjoy Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 8 - CONFIDENTIAL (9802'-Kuparuk River) AFE 10-61-1089 2-13 - ND BOP's. NU tree & test pack_off @ 5000 psi. RU lubricator & pull back pressure valve. Install test plug & test tree to 5000#, test o.k. RD lubri- cator. RELEASED RIG @ 12:30 P.M. on 2-12-85. RIG UP TO TEST WELL. Alaska United Rig #3 (0-18-0) Drlg. Foreman - D.L.Mountjoy ALASKA OIL AND ~A$ CONSERI~ATION.COHMI$$10N /"~' / - Bill Sheffield, Governor 3001 PORCUPINE DRIVE AI~CHORAGE.ALASKA 095014-3Jg2 TELEPHONE(901) 270,"1433 DATE: /~X ~ ~ ~" 'c2, .... / ?,~ ,~ ~o: , ~ c o ~ c. We wish to bring to your attention that the Co~ission has no~'" yet received the following required items on the subject well which our records indicated was completed Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled.well. Please submit the above missing material. ~erel~ Cz.:.( Chart C. V. e Chairman lc:C.024 STATE OF ALASKA ALASKA O~AND GAS CONSERVATION COF,,.,IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I1. Drilling well Workover operation 2. Name of operator CONOCO INC 3. Address 3201 "C" Street, Ste. 200 4. Location of Well at surface 780' FSL, 2325' FEL, Sec. 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 52' KB APL 47434 7. Permit No. 85-14 8. APl Number 50-- 029-21277 9. Unit or Lease Name M~lne Point llnit 10. Well No. C No; 8 ] ]. Fie~d and Pool Kuparuk River Field Kuparuk River For the Month of June ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks RIH w/Otis 3/16" braided line. Located wire @ 370' WLM. Unable to recover. POOH w/tbg. & wireline fish. Retrieve fish. No junk in hole. RIH w/gas mandrels and new SSSV. Land tbg. 13. Casing or liner ru.n and quantities of cement, results of pressure tests Frac: 25,000 gal 4,000 gal 5,000 gal 3,000 gal 2,000 gal 1,000 ~al. 14. Coring resume and brief description Pad 1 ppg slurry 3 ppg slurry 5 ppg slurry 6 ppg slurry 8 ppg slurry None 3,150 gal flush 15. Logs run and depth where run GR-CCL, spinner, and temp. 16. DST data, perforating data, shows of H2S, miscellaneous data ~t~ suspended. Completion report to follow. RECEIVED J U L 1 ,B 19g5 Alaska Oil & Gas Cons. Commission Anch0r~ge 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate John R. Kemp Manager of Alaskan Operations June 17,' 1985 Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attention C. V. Chatterton Gentlemen: Enclosed are the originals and copies of completion reports for Milne Point Unit C No. 6, C No. 8, and C No. 10. These updated completion reports reflect the change in bottomhole location from magnetic to gyroscopic survey. Should you have any questions, please contact Don R. Girdler at 564-7637. Yours very truly, Mana g e ~o~fmIA1 as~an Operations JC/kss Enc cc: D. I. Robertson RECEIVED JUN 2 4 1985 /~,laska 0il & Gas Cons. Commission Anchorage . STATE OF ALASKA ALASKi 'IL AND GAS CONSERVATION ¢ /1MISSION WELL COMPLETION OR RECOMPLETIO -- HEPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED~ ABANDONED [] SERVICE [~ Injection Well 2. Name of Operator 7. Permit Number CONOCO, INC. 85-14 · 3. Addr¢.¢.~ 8. APl Number 3201 "C,' Street, Suite 200, Anchorage, AK 99503' 50_029-21277 z~. Location of well at surface 9. Unit or Lease Name 780'FSL, 2325' FEL, Section 10, T13N, PlOt, UM Milne Point Unit At Top Producing Interval 10. Well Nur~ber 4624' FSL, 1199' FWL, Section 9, T13N, RiOE, UM C No. 8 At Total Depth 11. Field and Ponl 4794' FSL, 1408'FWL, Section 9, T13N, PlOt, UM Kuparuk River Field - 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ' _ - 52 'KBI ADL-47434 KuparUk:--R'iver 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 1-27-85 2-7-85 Suspended 2-18-85I NA feet MSLI One 17. Total Depth (MD*TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9620' - 7133' 9508' - 7041' YES[~ NO[]I 1925 feetMD 1800+ 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 9 5/8" 36# K-55 O' 5887' 12 ~" 1150 Sks Permafrost E 0 920 sks Class G 7" 26# L-80 O' 9588' 8~" 700 sks Class G O 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3~''~ 9297 ' 9297'/9Oll ' * 9170' - 9184' (Middle Kuparuk) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. * 9228' - 9248' (L8) DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED * 9259' - 9265' (Lg) NONE * 9374' - 9402' (Lower Kuparuk-2) * 12 JSPF' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ I Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL :OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. R[CEIVED J U N 2 4 !985; ~!as~a 0it & Gas Cons, Commission Annhnrm~ - ~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ;- - . . . - :- GEOLOGIC MARKERS : -": ' ' FORMATION-TESTS ' NAME Include interval testedl pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KA 4656 3707 DATE SAND BOPD '~WH oAPI WATER INT LA 4922 3877 2-24 LK(2) 48 0 22 0 9374'-9402' MA 5057 3965 2~25 LK(2) 9374'-9402' NA 5448 4225 MK 9170'-9184' OA (West Sak) 5696 4390 L8 60 0 22 0 9228 '-9248' L. Kup. Unconformity 8923 6590 L9 9259'-9265 ' Middle Kuparuk 9170 6773 Lower Kuparuk 9348 6912 -_ 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ I~, /'~~ Title 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 STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CC,.~.~vllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 85-14 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, Alaska 99503 50029-21277 4. Location of Well SURFACE: 780' FSL, 2325' FEL, Sec. 10, T13N, R10E 5. Elevation in feet (indicate KB, DF, etc.) 52' KB I 6. Lease Designation and Serial No. ADL 47434 12. 9. Unit or Lease Name Milne Point Unit 10. Well Number C-8 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent datesl including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The C-8 well was originally completed as a single selective with the Lower Kuparuk (2) (the bottom lobe of the Lower Kuparuk Formation) as the primary sand and the Middle Kuparuk as the selective. We now propose to finalize our completion program by fracture stimulating the Lower Kuparuk (2) then wireline perforate the Lower Kuparuk (1) through tubing. Our objective is to improve the productivity of the Lower Kuparuk (2) so that it will deplete consistantly with the L.K. (1) (on the average the permeability of L.K. (1) is approximately twice that seen in L.K. (2)). On a number of the "C" pad wells the post completiOn flow test left significant fill in the casing. Prior to the fracture treatment each well is to be checked for fill. If the C-8 well has insufficient rat hole remaining (minimum of 35') a coiled tubing unit will be used to clean-out to PBTD. RECEIVED J U N 2 0 1985 Alaska Oil & Gas Cons. Commission f~--~ Anch0rags 14. I her~,by ce~ify that the foregoing is true and correct to the best of my knowledge. m~l,~ Sr. Production Engineer 6-17-85 - Tit,. The space be o ' ' Conditions of Approval, if any: Approved Colby ,R~turned LON~IE C. SMITH By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate John R. Kemp Conoco Inc. Manager of Alaskan Operations June 13, 1985 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 Dear Mr. Chatterton: Attached is the original and two copies of a Sundry Notice to perform remedial work on Milne Point Unit well C-8. If you have any questions, please call Dan Robertson at 564-7635. Yours very truly, ~laskan Operations DIR/vv Chatterton RECEIVED JUN l 4 1985 ~,l~.ska Oil & Gas Cons. Commission Anchorage - STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO._.vllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7..~Per~it No. Conoco inc. ~-14 8. APl Number 3'Ad3d~..3Sl "C" Street, Suite 200, Anchorage, Alaska 99503 50_029-21277 4. Location of Well SURFACE: 780' FSL, 2325' FEL, Sec. 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 9. Unit or Lease Name Milne Point Unit 10. Well Number C No.8 11. Field and Pool Kuparuk Field 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~XX Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10o407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all Pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The C-8 well was drilled to a total depth of 9620' M.D. on February 7, 1985. The well was completed then suspended pending fracture stimulation work proposed for the summer months (refer to 10-403 of 2-8-85). In early May Conoco ran a build-up test on the well in preparation for a fracture stimulation of the Lower Kuparuk. After the build-up test the slickline tools could not be pulled past the safety valve set at 1925' M.D. The line was eventually cut and 3/16" braided line was run to lock open the safety valve. Through a sequence of operations the braided line became stuck below the safety valve and was cut 10' below the surface. There is now approximately 9100' of braided line in the tubing. Conoco now proposes to kill the well and rig-up the Roll'n IV completion rig. The general procedure will be to pull tubing to the safety valve then recover the braided line, replace the safety valve then re-run the tubing. If the braided line does not come out with the tubing (to be determined as soon as possible) we will re-land the tubing and attempt to fish the braided line with a small tubing string (exact string size not yet determined). RECEIVED Verbal approval was given by C. V. Chatterton on June 11, 1985. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed The space below for Commission use JUN i 4 1985 Absk: 0!! & Gas Co.s; CommJssk Sr. Production Engineer A"¢~°-rt~e-85 Title Date Conditions of Approval, if any: Approved by. COMM ISS ION ER Approved Copy ~i~eturne¢! the Commission Date __ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L'T) L= NOTES: 1. Al m®eeuremen~e -,re from KDB of 2. KDB-BL ~ ~ I 3. KDB-GL 8. SIint type hole 7. ~i~,~l,: 3&' ~ ~6o' 8. FMC 3 11i' APl SO00~ tree with 3 1~2'~d. treetop co~ct~ (L7~o" ID) 10. APl No. ~. T.b~ CASING: (D- ~S BS' -~- ?" ~(or L- 8o wr~c PerfMetione: 12 8PF 120' -MILNE POINT UNIT ACTUAL COMPLETION SKETCH COMPLETED ON ?"/12~ / ~ ~ 3.~'" 9-2 , 5073 '"' G 5702 ~"' 7~&4 829&~-- GL~ 89&0 ' '" -- ~o4.$'" Ca~,,eo "g/'!" n;fpl¢ (.'l..SI;" /::'eTD'- ~)50t' A4D (7041'T'VD) TD: ~&'Zo'/'1P(713T'TuD) ,4.0o" ID " ' STATE OF ALASKA (~ ALASKA c' ". AND GAS CONSERVATION CO' "AISSION ¢~ MONTHLY RE 'ORT DRILLING AND woR VER OPERATION$,,/ · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 85-t4 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 50-029-21277 4. Location of Well at surface 780' FSL, 2325' FEL, Section 10, T13N, RiOE, U.M. 5. Elevation in feet (ind._ate KB, DF, etc.) 52 'KB 6. Lease Designation and Serial No. ADL 47434 For the Month of Hay ,1985 9. Unit or Lease Name Milne Point unit 10. Well No. CNo. 8 11. Field and Pool Kuparuk River Field Kuparuk River 12. De, th au e~l of month, footage drilled, fishing iobs, directional drilling problems, spud date, remarks NONE. 13. Casing or Gne~ run arid q~ntities of c~ent, ~esults of pressure tests NONE. 14. Coring re~ume arid b~ief der,~iption NONE. 15. Lc.~s~ run and d~h where run NONE. 1 6. DST data, perforating data, shows of H2S, m~scelJaneous data NONE. Well Suspended. Completion report to follow. ~/~s~rs 0/7 ,~ ~a, Con,~ Anchora~s' Con, miSsion 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DATE ~//~/~r~ ~ NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 Conoco, Inc. 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 Attention: ban Robertson~ SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited - . HOUSTON. TE:XA$ 77001. ~ PLEASE: ill'leLY TO 10 May 85 ~'~ o FF~i i. tc) R~ S[NVIC[S 500 W. International Airport Rd. Anchorage, Alaska 99502 ATTN' Holly Burgan Gentlemen: Enclosed are 2 B[prints of the 2"&5" DIL,LTD/CNL Company Conoco Inc. , Well MPU C-8 Field Kuparuk , County North Slope .Stat~- 'Alaska .on: Additionalprintsarebeingsentto: 1 ~ ~rints & ~ R~olded Sepia Conoco, Inc. Offshore Exploration-E.W.A. Div. P.O. Box 4444 Houston, TX 77252 ATTN' L.A. Din§es C/O Randy Altobelli 1 BL nrints & 1 RFolded Sepia Conodo, Inc. P.E.S. Reservoir Sec. Offshore Buildin$ P.O. Box 2197 Houston, TX 77252 ATTN' O.G. Kiel 1BL prints Conoco, Inc. P.R.D. Reservoir Sec. P.O. Box 1267 Ponca City, OK 74603 ATTN' H.E. Gilliland - 6356 RW 1 BL nrints & 1 RFolded Sepia Chevron U.S.A.~ Inc. P.O. Box 8200 Concord~ CA 94524 ATTN' Dave Engstrom C/O Louis Klonsky 1BL nrin~ & 1 RFolded Sepia Champlin Petroleum Co. P.O. Box 1257 Englewood, CO 80150 ATTN' Dale Bossert 1BL prints & 1RFolded Sepia Reading & Bates Petroleum Co. 3200 Mid Continent Tower Tulsa, OK 74103 ATTN' C. E. Seery, Jr. 1 BL nrints & 2 RFolded Sepia Chevron U.S.A., Inc. P.O. Box 107.839 Anchorage, AK 99510 ATTN' J.L. Weaver 1BL prints & 1 RFolded Sepia Cities Service Oil & Gas Corp. P.O. Box 939 Bakersfield, CA 93302 ATTN' Neil Buttram C/O Jim Quinn The film is returned to Conoco Anchorage Office We appreciate the privilege of serving you. Date' Very truly yours, SCHLUMBERGER OFFSHORE SERVICES Art HUf fman O I ~,TRICT M A NAG ~'11~ CONOCO ~ INC. 3201 "C" Street,Suite 200 Anchorage, Alaska 99503 Attention: Dan Robert son SCHLUMBERGER OFFSHORE SERVICES ^ Division of Schlumberger Limited HOUSTON, TEXAS 77001 PL£A$I=' REPLY TO 10 May 85 ~ W.INTERNATIONAL AIRPORT RD. ~ ANCHORAGE,ALASKA 99502 ATTN:Holly Burgan Page 2 of 2 Gentlemen' Enclosed are printsof the 2"&5" DIL, LTD/CNL Company CONOCO, INC. , We~ MPU C-8 Fie~d KUPARUK , County NORTH SLOPE State ALASKA on: I .; r'~-- Addi~--b-'eing sent to: // 1BL prints & 1RF ALASKA OIL & GAS k 3110 PORCUPINE DRIVE / ~ANCHORAGE, ALASKA 99501/ prints prints prints prints ~.prints prints prints The film is_returned to CONOCO We appreciate the privilege of serving you. SOS--1565-A Received by' D~'t e,:-/x4~-~-'~'n ..... .,>'-'-+' .'.t~ Very truly yours, SCHLUMBERGER OffSHORE SERVICES Art Huffman DISTRICT MANAGER WELL COMPLETI 'N OR RECOMPLETIoN" EPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] sERVicE [~ lrljectiorl Well 2. Name of Operator 7. Permit Number Conoco lac. 85-14 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 50-029-21277 4. Location of well at surface 9. Unit or Lease Name 780' FSL, 2325' FEL, Section 10, T13N, RiOE, UM LOCATI©~qSI Milne Point Unit At Top Producing Interval VERIFIED t 10. Well Number 4773' FSL, 1100' ~, Section 9, T13N, RiOE, UM Surf. ~ I C No. 8 B.H. P- . j 11. Field and Pool At -Total Depth FSL~ ~ F~, Section 9, T13N, RiOE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) t 6. Lease Designation and Serial No. 52' KBJ ADL-47434 Kuparuk River 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore J 16. No. of Completions 1-27-85 2-7-85 Suspended 2-18-85J NA feet MSLJ 17. Total Depth (MD+TVD} 18oPlug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9620'-7135' 9508'-7054' YES E~ NO []J NA feetMD 1800_+.. 22. Type Bectric or Other Logs Run LDT-CNL-GR, GR-CCL-DIL-SP-CNL-LDT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 9 5/8" 36~ K-55 0': 5ggT' 17 1/&" 1150 sks Permafrost ~ O 920 sks Class G 7" 26~/ L-80 0' 9588' 8 1/2" 700 sks Class G 0 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) * 9170'-9184' (Middle Kuparuk) 3 1/2" 8997' 9297'/9Ol1' * 9228 '-9248 ' (L8) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. * 9259'-9265' (L9) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED * 9374'-9402' (Lower Kuparuk-2) None · · * 12 JSPF 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.k, OILLBBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 'F' . 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Date Sand BOPD PWH °API Water Inter~al KA 4656 3603 LA 4922 3773 2-2'4 LK(2) 48 0 22 0 9374'-9402' MA 5057 3861 2-25 LK(2) 60 0 22 ' 0 9374'-9402.' NAL 5452 4123 OA (West Sak) 5696 4286 MK 9170,_9184, L.Cret. Unconfo~m- L8. 9228 '-9248' L9 9259'-9265' ity 8923 6486 Middle Kuparuk 9170 6669 Lower Kuparuk 9348 6807 : · 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~'~'~~~ Tit I e f~~¢'- ~1/~' 1~0~4~ Date ~//~/~",~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for' only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 l Eastman A PETROLANE COMPANY REPORT of SUB-SURF~4CE DIREC TIONA L SURVEY CONOCO, INC. COMPANY Pad C, Well Number: WELL NAME Milne Point, North Slope, Alaska LOCATION JOB NUMBER A0285G0149 TYPE OF SURVEY Gyro Multi-Shot DATE 10-FEB-85 SURVEY BY B JAHN OFFICE Anchorage, Alaska Eastman Whi s t c k (907) 349-4617 P. O. Box 4-1970~Anchorage, Alaska 99509-1970 ~ate: May 2, 1985 Conoco, Inc. 3201 C. Street Suite 200 Anchorage, Alaska 99503 Well Number: Pad C, Well No: 8 Location: Milne Point, North Slope, Alaska Type of Survey: Gyro Multi-Shot Date: 10-FEB-85 Method of Computation: Radius of Curvature Surve~or: B JAHN .Z Job Number: A0285G0149 A~ten: Mr. Dan ~"obe,-~ Dear Mr. Robertson: We are enclosing the original and one copy of the Gyro Multi-~ Shot survey run on the above mentioned well, 'fo ,.date, the following_ di~tribution~ has been ~..~~'~lisl~ed:~..~..,v:.~ A. ]. copy delivered to drilling Y-or in-i-~ouse distribution. B. 9 copies noted [or oil con~l?any reprer:c:ntatives. C. ] cc)pies for E/hr permanenL ':,.'ell files. W~ wish to take this opportunity [-o thank you for using ~.:..~:~r,,-~,~ ...... Whipstock and look forward +'o b~-]ng_ of sr~rvice... .,.n t futur~. c. L n re 1 cc/file cc: L.A. Dinges - Offshore Exp.io]:'at:[on O.G. Kiel - P.E.S. Rr:~ser-voir Section Conoco H.E. Gilliland - P.R.D. ?eservoir Section Conoco William Van A!en ~--'" ' .... - A~ds~,a {)[~ and qas Conservation Co~ission J.L. Weaver - Chevron U.S.A.= ~ Inc. Dave Engstrom - Chevron U.S~.A., I~c. Concord Office Dale Bossert -Champlin [~etro].eum C.E. Seery~ jr. - Readin~[~ and Bate:~ [~?e-t~o]eum Co. Neil BUttram - Cities Sea, vice Oil a~d Gas Corp. Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide CONC~CO, INC:. PAD C:, WELL NO: 8 GMS ._lOB NO: AC)285G0 MILNE PT.~ NORTH C-:LOPE, ALASKA GM'.--: 0-9450 MD '=:IIRVEYOR: B dAHN~ DATE RJN. 08/1U-FEB-.:.o 'F~O BEG A/U NI]: 1566, CAMERA NO: 7'FI, GYRO NO: 6:32 FORESIGFI'F: N78W VERTICAl. SEC:TION CALCLILATED IN F:'LANE OF F'ROF'CISAL DIRECTIr]t",I: N 46 DEG. !5 MIN. W R E C OFi'.£f 0 F S L.i R V E Y RAI]II..iI'._--; OF CURVATLIRE METHOD Eastman / F:O I\IO C: A., ]] I\1F:, PAD C~ WElL NO: 8 GMS m~ '~ m~. ~-- m MILNE F'T NriRTH .=,L.._iFE, AL. AF:;KA ,JOB NO: A02:B5GO14'2 C: t'-I M F' U T A'F I 0 N T I ME DATE (".)7::31: 05 11-MAR-85 F'AGE NO. i TRUE MEA:SURED DRIFT DRIFT CCILIRSE VERTICAL VERTICAL ,.:;I...IBF:EA R E C: T A N G LI L A 'R C: L 0 S U R E DEfC4.E D E F' T H A N G L E Iii I R E C T I 0 N L E N G T H D E P T H S E C T I 0 N T V D C: 0 iD R D I N A T E S D I ,.E;'T A N C E D I R E C T I f'i N S E V E R I' FEET Fl M D bi FEET FEET FEET FEET FEET FEET D M [fO/100 O. 0 0 0 C) 0. O. 00 O. 00 -52.00 0. O0 0.00 ]. (') 0. (]) 45, '._=; 41 2_ 0 E 1 ('). 0 . 100 . c). 0 - 0 .65 4:3 .00 0.4. 9 '='._, (]) .4:2: E 2c30. c) 0 0 0 100. 1 ? 9. 'P 9 - 1.30 147. 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UMF L TAT I ON TIME DATE 07::31: "= - ~.)._, 11-MAR-8~ PAGE NO. 4 ' '1 l R_IE l, SUBSEA R E C T A N O U L A R C: L 0 ':' II R E DOGLE MEASURED DRIFT £RIFT CC;URF;E VERTICAL VERTIC:AL ~' - EEl-IH ANGLE DIR~_.TION LENGTH DEPTH '.=;ECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI FEET D M D M FEET FEET FEET FEET FEET FEET D M DG / 100 '~.~ 4.5('). :'::5 0 N 51 0 W 100. 6645.42 5546.33 65'?:z:. 4.2 3772. :23 N 4067.28 W 5547.29 N 47 '? W 1£)0. 671:--.~.44. 5613.38 ,6667.44 3815.22 N 4118..S~7 W 5614.4:2: N 47 12 W 100. 6795.34 5678. :3~:) 674:_--:. :34 3856.64 N 416'F~. 21 W 5679.4.:3 N 47 14 W 100. /:,873.17 5740.85 6821.19 387~/:,.34 N 4217.81 W 5742.08 N 47 16 W 100. 67)5:3.05 5800.81 6901.05 :3'.-.-~34.22 N 4264.58 W 5802.1:3 N 47 18 W . ' ..... "-' ..,:,.:,1 10 N 47 2(') W 50. 6993 '75 5',:: Z 9, 7:3 694.1.75 3'.--.~ 52.4. 9 N 4-.~,:, 7. 14. W =' '-" '-' . - 2.48 I .54 1.75 1 2.00 ."). 00 F'R 0,_1E C'I' E D T 0 '1" ti ........... · -' F '-' 'P 2 .=19 2 :-:. 0.. '.--.~,'_-,2('), :35 0 N 51 (:~ W 17(i), 7 i3:3. (:) 1 =;'.-../' .-.' /., L:::--: 7('):::: 1 01 4(:) 13 ':'5 N 4.:, :,.-:, . W 4-1 N 4'7 .-..:, W c)0 I--INAL CLOF;UIRE - DIRECTION: D I .'::; T A N C: E: N 4'7 I]EG:--: 2:3 Mllq'.--; W · 5'F~'2: ::::. 't. 1 F::'E E T _ Eastman I ipstock A PETROLAN£ COMPANY CONOCO, INC. PAD C, WELL NO: 8 GMS dOB NO: AO285G014'9 MILNE PT., NORTH SLOPE, ALASKA GMS, 0-$~450 MD, SLIRVEYOR: B dAHN, DATE RUN: 08/10-FEB-85 90 DEG A/U NO: 1566, CAMERA NO: 79, GYRO NO: 632 FORESIGHT: N78W RECORD OF INTERPOI....ATED SURVEY, Whipstock A t:~'TROLANE CCt~FIItlVY CONriCO, INC. F-'AD C:, WELL NFl'. ':',_. GM8 I'IlLNE PT. , NF~R'I"H SLAPE, ALARKA MARKER ......... CC;DE · NAME dOB NO: AO285G014..9 KA KB KC KiD LA TRUE SUBSEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH FEET FEET FEET LB MA MB NC: N1 4 ~;J6.00 :2:707.2£) 365.5..'C 4705.00 :2:738.58 3686.58 47.97.00 37'27. 10 .2:745. 10 4871.00 3844. 17 377'2. 17 4-922.00 .2:876..94 3824..94 NA NB NC: ND NE 4.971.00 F:';?08.85 3856.85 5057.00 3.965.50 3913.50 5158.00 4032.51 :3.980.51 5268.00 41 £)5.4.7 405:3.47 5:385.00 4182.86 4.1:30. NF OA IDB L. OWER t--..'. UNC:CINF. MKR 1.9 5448.00 4224.66 4172.6,6 %"'-'= 424.9 '-"-' .97 ";'"~ · _ -~ o...,. 0 C) 41 . . . ZT..2' · ~.-- 5538. O0 4284.50 42S2.50 5558.00 42.97.82 4245.82 5585.00 4315.80 ,4263.80 FAULT MKIJP LZ L-8 ~/-. 44. 0 (') 4 .:,...:,.'.:,. 16 4:3 (2):3. 16 56.96.00 4:38'.:.?. 8-/ 4. :337.8'7 · _ .: ..... 1. ¢)(') 448 ('). :2: '? 4. 4'2 :::. :3'.:.> :::':7,2:3.00 6.5.90. 16 65:3'.2:. 16 '.-.-,006.00 664'.-.?. 87 ,.~:.597.87 LK-1 LK-2 b/LK INTERVAL TB 'F/124.00 672:7.66 6685.6,6 '? 170. O0 6772.57 6720.57 '.:.~ 185.00 6,783. 'F/6, 6.7:-_-: 1..96, 7230.00 6,818.6'? 6766.69 .9260.00 6842.05 67'.:.<). 0..=, .9348.00 6911.52 66:5'.-.-,. 52 "'m ---m. -- . -- ,:, 7 o 00 /-, 9':: 1.4 .9 6, :E: 7 '?. 4.9 .946.9.00 7009. 32 6.957. :32 .9620.00 7133. 0] 7081. 0I PAGE NO. R E C T A N G U L A R C: 0 n R D I hi A T E ':'.., FEET 1517..93 N 1821.39 W 1546.6.9 N 1845.65 W 1601.66 N 18.90.56, W 1646.33 N 1.926.13 W ~.676.77 N 1~50.63 W 1705.57 N 1.974.16 W 1755.32 N 2015.52 W 181:3.32 N 206:3..95 W 1876.76 N 2~16.42 W 1.944.65 N 2172.02 W 1 ';? 8 .1.._....°.S N 22 C) 1 .6 (:) W 2002.92 N 2218.?)1 W 2033.85 N 2243.58 W 2045.53 N 2252.87 W 2061.27 N 2265.40 W 2.126. 18 N 2:316.6:2 W '-"-' ') = ':'.=l 30 W .-.-' L ,_, N :22:77 · 0.., ._ . . . 2738.:2:1 N 4. 025.77 W :3774.81 N 4070.:3:3 W 3825.16 N 4131.03 W 3844.21N 4154.14 W 3850.42 N 4161.67 W 3868.55 N 418:3.7~ W 3880.46 N 41.98.2:7 W :3:.~14.52 N 4240.26 W 3.923..9.9 N 4251.95 W :2:.95'~. :]-:5 N 4 ... ? ~,. 61 W 4013.85 N 4:362..92 W C L 0 S i_l R E :_-,TANL. E D I REC:T I ON FEET B M 2370.98 N 50 12 W 2408.04 N 50 2 W 2477.81 N 4'~ 44 W '.--_"533.85 N 49 2'.-7, W 2572.26 N 4? 19 W 2 z-, ():::, ':"-'')' ......... :, N 4'F~ -.," W 26,72.73 N 48 57 W 2747. :36 N 4:2:42 W 282:--:.6,8 hi 48 26 W 2'215.36, lq 48 10 W 2'.--..'61.88 N 48 1 W 2989. 1.9 N 47 56 W 302:2:. 2:3 N 4-7 4 F--: W 3042.'?6 N 47 4.6, W ,':',_ 0/-._ 2.84-N 47 4 ..'-" W 31(2)6.21 N 47 34 W 33.4.4.42 N 47 27 W :.324:'::.04 N 47 ? W 54'? :2:. 8(") N 47 ~ W · ., ...... ,1.:32 N 47 ~4 56:30. (2)3: N 47 12 W 5659.':.-::3 N 47 13 W 566.9.68 N 47 13 W 569:3.23 N 47 ~5 W 5717.02 N 47 15 W 5770..90 N 47 17 W 5785.91 N 47 18 W .~,--m ,-- ~'", "", ' · _ ,:,41. ;~,.-, N 47z.U W 5.92:5:.4! N 47 2:3 W Eastman/. Whipstock A PETRO[ANE COI",IOCO ~ I I',tC. F'A D C:., W E L L N 0: 8 G M S ...I 0 B N 0: A 02 :-]: 5 G,L:) 14 '? MILNE PT. ~, NORTH SI_OPE., ALASKA GMS.., (')-'.:'.."450 MD~ SLiRVEYOR: B ,_IAHN., ]DATE RUN: C)8/1(')-FEB-85 'PO DEG A/U NO: 1566, CAMERA NO: 79', 3YR]J Ni']: 6:"::':2 FORESIGHT: N'78W REC:C~RD OF I NTERF'OLATED SURVEY Eastman ~ ~ ~-~ Whipstock A PETROLANE CONOC0: INC. PAIl C: WELL l',IO: :r.: r3MS IvlILNE F'T. , NORTH :_;LOF'E, ALA'i--;KA ""-"-'=" 45;' d I]1 B N 0: A o.,=: ,--,.'", G,L) 1 C 0 M F' U T A T I 0 N T I PIE DATE 0 7: :2:4: 2224 1 1 -MAR-, .... PAGE NO. IdEA.=. _IRED DEPTH FEET TRUE VERT I C:AL DEPTH FEET SUBSEA VERTICAL DEPTH FEET R E C T A N G U L A R C: 0 0 R D I N A T E S FEET C L 0 S U R E D I S T A N C E lEI I R E C T I i-_1N FEET lEI !"1 10':). O0 2 0 0.01 3 0,:}. 01 400.01 500.01 6, 0,:}. 02 700. 1 1 '.-? 01. :,7:: 7 10,:} :3. 13 100.00 2 0 0.0 0 300.00 4. 0 0.0 C) 600. ()0 700.00 80,:'). 00 'PO0.00 I 0 0 0.0 0 4. 8.0 0 ]. 4 :--:. 0,:) 5.' 4 8.0,:) :3 '1 :--:. 0 0 44.::::. ,:],o 54 8. ,:} 0 64.23.00 74.:--:. ,:)0 848.00 'F; 4 8.00 0.4.'P .=,'""' ,::). 4.3 E 0 92:: S 0.,:,7 E 0 ~=12:: ':' 1.04 E 0.02':: N 0.'74 E ,:}.29 N 1.13 E O..NO~_ ._,o ,:}.84 E c) c>,:-; hi '--' ':}4 W 4. :2:2, N 10.'P1 W ,7; ':')7 1'4 '-"'-' · . ,::.:. · 2 7 W 15.82 N 4.0.72 W C).65 S 41:30 E 1.:-_-:1 S 41 3C) E 1.1'P S 60 53 E 0.$;4 N 87 58 E 1.1/=, N 75 2:-: E 0,177 S 5?/ 1 E :3.20 N 72 '-...' W 11.74 hi 6 8 2222 W 24. '.;.'7 N 68 42 W 4°,_,./=,'=',_, N 68 46 W i 10 6. 1 ::-': 1:210.8 0 1:31 '7. ':;: 4 1 4:.'.:'5.48 15:35.48 1 100. 120 0. 13,:} O. 1400. 15,:} 0. 104.8.0 0 1 14 8. ,:} 0 124. 8.00 1 :B 4 8. ,:"t 0 1 4 4 8.0,:} 68.4.5 N 67 29 W 'P8.?~7 N 65:30 W 1235.14 N 63 2'7 W 176.321 N A2 0 W 222.C:'2 N /=,1 I0 W 16 0,:}. 0,:} 1 70 0.0 0 1 ::: ,:},:). (')0 1 '.-.-;,:} 0. ,:} 0 2000. O0 154. C-::. 0 0 1 ,"-, 48. ,:} 0 174 8.00 18 4,:::. 00 1 '...'7; 4 8. ('l 0 ]. 2323.6 2 N 22226. :2:0 W 1 ,:'"-.2.2 2 I,.I 2 7 l.-.".~ . 2222~: W 192,.61 hi .]227.231 W 229..6(') N :2:81.27 W 27,:'!. ?.:.-, N 4. 40.86 W 271.47 N /:,0 :--:1 W 23223.49 N 5'? 54 W :--280.28 N 57 24, W 445.06 N 5:---: 57 W 517.4? N 5:2:25 W 224-4. ,;i)4. 2 :':: 7:2.74 25,:ii, 4. :_: 0 2644. :3/_.', 2794. '.-.';'P 210 0. ,21) 0 2 20iii. 00 2:30 0.0,:) 2 40 0.0 0 250,:). 00 2315.21 N .504.,:}5 W 360.5'? N 571.15 W 4,::)23.25 N /=,4..]:. 6)2 W 462.04. N 724.,:)4 W _..' .... N :_:216.72 W 594.49 N 57 59 W 675.45 N 57 44 W 761.67 N 57 35 W 858.90 N 57 27 W '.~71.38 N 57 13 W 2600.0C) 2700. O0 22220 0.0 0 2900. ,:}0 3000.00 2548.00 2648.0':) 274:2:. ,:}0 2:2:4:2:. 00 2$.¢42--:. 00 52;9.9'? N 917.89 W 675.18 N 1,:21)13.18 W 752 ~- .... · dF, N 1104 02--: W 827.'P4 N 118'~.24 W '.-.-~ 0 9. '.--;'.-.-' N 12 71.10 W 1096.59 N 56 5C) W 1217.54 N 56 19 W 1336.05 N 55 44 W 1450.21 N 55 ._,=' W lo6o.'26 N ~4 24 W Eastman Whipstock ~ PETROLANE MILNE PT., Nf]RTH SLC*F'E, ALASKA ,JOB NO: A0285G0149 C 0 M P U T A T I 0 hi T I ME DATE 07: :2:4: :2:4 11 -M A R -,_-, ._, F'AGE NO. MEASURED D E F"T FI FEET TRUE VERT I CAL DEPTH FEET SUBSEA VERTICAL DEF'TH FEET R E C ]' A N G U L A R C 0 0 R D I N A T E S FEET C L. 0 c.._, IJ R E D I .:..TAN _.E D I RECT I ON FEET Iii M :=:726./=, '.-.-J :3879.86 40:31. :2:7 4. ! :"::._,':'. 24 43:35 · 55 4. 489.4..2: 46,44.7:_:: 4. 801..55 4-':.-J57.4. l '."""; 109.05 3100.00 :2:200.00 330(:). O0 3400.00 :3500.00 360C). 0¢) 3700. ¢)0 :2::=:00.0¢) 3'POe). 00 400 ('). ("~0 · :. ) 4 .... 00 .:, 148.0 3';' 48.0 :2: :2:4 :=:. 00 :344:=:. 00 3548.00 :3648.00 :2:74:.-=:. 3848.00 :2.v.-}4::3.00 793.01 N 1353.27 W 077.00 N 14.2:3.2::: W 160.71 N 1510.42 W 246.19 N 1586.29 W :2.::32.86 N 1661.70 W 14-21.12 N 17.2:8.4.:3 W 1511.35 N 1:315.82 W 1604.:'2:9 N 1892.77 W 167: 7. ?, 9 N 1967./-,._,':' W 1'7:_--:5. 19 N 2040.55 W 167:_--:.51 N 5:3 44 W 17'F.~2.83 N 53 5 W 1704.89 N 52 28 W ~r .'2'~ 2J17 ..... N 51 51 W 2130.20 N 51 16 W · 2245.:38 N 50 4.4 W 2:2:62.50 N 50 I4 W 2481.2/=, N 49 43 W 2598.72 N 49 1::: W 2711.22 N 4':E: ']9 W 4' 100.00 4' 200.00 4300.00 4400.00 4. 500.00 4. 04-C-:. 00 .414 :E:. 00 4. 24. :'=:. 00 4:348.00 4-4.4. :=:. (:)0 1:--:71.99 N 2112.4.8 W 1'=-./!59.70 N 2184.2:3 W 2047.4.4. N 2254.39 W 2135. 10 N 22.:2.2:.52 W 22::.:":3. ()5 F! 2:=:';-K). 0:3 t,,,I · .',:,22 ._/ Iq .... 27 W 292.:4.50 hi 4. 8 6 W :-.:04~-'- .... :2:7 N 47 45 W :2:155.5.2: N 47 25 W :3264..C:8 N 47 4 W 600 :--':. 01 /:, 154.81 6:2:02 ,, 4-:3 645:3.66 C.).._, ,, ':; ! 6760.20 6914.96 7065.0:3 7211.95 7.: ..... :i. 58 5100.00 5200.00 5:30 c). 00 5400.00 ...... c) U. 00 4. 548.0c") 464. 8. ()0 4, 74:3.00 4 :E: 4 :"::. i:)0 4. '.-? 4. :3.00 50 4. 8.00 514:3.00 · :, .-' 4,:,. 00 5:348. (')0 544:=:. 00 2:7::!().90 hi 2454.70 W '="=":' "- :2.', 1 N 2519 9"~ W ~_ ._~ ... ,_,. . · . ._, 2.4 :=: 0. ,_,':' ~._ I'q 2.~,_ :::_ :::_. 14 W .... "~," "--. 2663 ..-'._:,._, 81 N .2c2) W 2/.:,47.:=:5 N 2742:.47 W 272::2.:. 2:s: N - ,_... ©':''=''--/.. · 11 W 2808.21 N 2916.06 W '--'::2.::2.:4. 1';? N 29.98.26 W '-.-'9~/-, '--'/- N .2:078 0::: W ~. .... · -_,--, u 302.7.`1-2 N 315:=:.:34 W :2.::'::71. :'-':2N 46 44 W 3477.4-0 N 4-6 26 W · :,._,,:,._,. 12 N 4-6 13 W 3698.11 hi 4.6, 4 W .... · :,,=,12. N 46 i W 3'? :=:0. :2:1 N 46 2 W 4c:)48.39 N 46 5 W 4160.:_=:1 N 46 7 W 4267.8:3 N 4/=, ~' W 4374.':.-~8 N 46 1:3 W 7505.2:2: 765:2:. 05 7 :=:01.0:2: 7'74 4. 17 80:=-.:/=,. '.-?S 5600.00 5700.0 c) 58C)0.00 5900.00 60 00.00 554:s:. 00 564:3.00 574:::. 00 5:--:4.8.00 5 ? 4 :=:. 00 · '3(')'P7.'.-.-~6 N .37'39. 16 W :3168. 16 N :2.: :322.:36 W :' ~"'=":' 27 N .2:4 ¢).~ 91 W :=::=:0:3.6.5 N 3484.73 W :2: :2:/_-. :_=',. '2':-.'~ N .2:563.58 W 4482.1.2: N 46 17 W 4590.79 N 46 22 W 4C-,9':-.~.64 N 46 27 W -1-801.82 N 46 32 W 4903.5'=.' N 4/=. :z:7 W _ East n / I ipstock A PETROLANE COMPANY MILNE PT.., NORTH '.SLOPE, ALASKA M E A S U Fi E D DEPTH FEET TRUE VER'r' I CAL DEF'T'H FEE'[ 82:31. (}4 :-':: :77:3.2:0 8512.85 , ::,/.. ,=.; ..: .... .......... 2:1 ,='/ ...... 1~, 6100.00 6200. O0 6300.00 6,400.00 6,500.00 :E:936. 71 ';.? 07 ?':. 7:3 9205. '?'."-.; ':/":":"-" 57 945'7. E, 3 66, 00. C)0 6700.0 (") /_-. :::: 00.00 6,'P 00. C) O 7000.00 'P !57'::?. 70 71 c) l]. (::, 0 ,_lOB NO: AO285GO 14.'.--.~ · =, _IB.:,EA VERT I CAL DEPTH FEET 6, 048.00 6148.00 /:.24.8.00 .6348,. 00 644.8. (.)c) /_-,548.00 664-:"-':. 0C) 674 :::. 00 .6 ::: 4-8.00 6,',:7.; Zl. 8.0 0 704E:, 00 RECTANGULAR C 0 iD R D I N A T E S FEET 34:3:2:. 18 hi 3644.45 W ":: 4 9/.., '-.'~ .... hi 3723 ':":'; W · _ . -- # · · :,._,._,/. 50 N 3799. ~ Z W 3619.£)2 N 3876.13 W 3681.73 N 3'.-.?54.97 W :374. 4..._,'='._.=, hi 4- 033. 16, W :2::30:3.9:3 N 41 C, 5..'2:9 W · ':":'"-";9 (') 1 N 4.172 12 W :2:90 9, 06, N 42:2:3.51 W :3955.24 N 4290.54 W :3'.-.-/99. 7.: 1 Ill 4. :344.96 W COMF'UTAT I ON T I ME f'fATE 07: 34: :34 11-MAR-85 C L 0 S U R E D I STANCE D I RECT I ON FEET D M 5006. :37 N 46 43 W 51C)7.58 N 46 48 W 5204.79 N 46 53 W 5302.99 N 46 58 W 540:_--:.42 N 4'7 3 W 55C):3. :--::--: hi 47 :Et W 5596.79 Iq 4.7 11 W 568:3.18 N 4.7 14. W 5762.24 N 47 17 W 5'.']::-_-:5.4-7 N 47 2£) W PAGE NO. ..2 _ East n Whip . gc k OR [70NT:AL PROJE'~T I ON PAD' ,C. WELL N,O, 8 ~GHS SCALE '.1 IN. - 1000 FEET :. MILtJE PT., NORTH,S[.O.PE. ALASKA ~ -- . . [ . FINAL STATION, : ~595 DEPIH . 9620 ......... '. ~ ...... - - I - ~.'"'~ ' 7- F ..... ~ PAD C, WELL NO, 8 ~GMS i ' ~ MILNE PT.. NORTH $ OPE,i ALASKA: - ~ ................ '1 EASTMAN WHIPSTOCk. INC. .......... F-~ ......... 4 ............ ~ - ~ 000 ! ' r o.'"-F '-VERT'ii'OAE' ....... pROJEC' I' SCALE '! 'I 1,1. ' ' ~2000 FEET ~ . ......... 2000 . ~ 4000 .... i ...... 6000 ..... 2000 ,3000 4000 2000 -VERT'tCAL 5000 8000 · . 9000 , · 6OOO 7'000 4000 ' ' 5000. : SECTION Suggested form to be inserted in ~ach "Active" well folder to check for timely compliance with our regulations. OPERATOR, WELL NAME AND Date ' Required Date Received Remarks Completion Report ~...~__~ , , , ,, , Registorod Survoy Plat . V~., < / -~.3-~~ ~/d.,. Inclination Survey~ ....... ., ..... _~ ~/~ ..... .__ ........ Directi°nal Survey Drill Stem Test RePorts Production Test RepOrts . . · , .... e'~ ....... Digitized Data 7~5 ~~/--~ ~~, , , , "" ,-- STATE OF ALASKA ~. ~ ALASKA,? ". AND GAS CONSERVATION CC '¢IlSSION w-~_~ M NTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well I~ Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 85-14 3. Address 3201 "C" Street, Suite 200, Anchorage, AK 99503 4. Location of Well at surface 780' FSL, 2325' FEL, Section 10, T13N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 52' ~wBI ADL 47434 For the Month of February ,19 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks NONE 13. Casing or liner run and quantities of cement, results of pressur9 tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE 1 6. DST data, perforatin§ data, shows of H2S, miscellaneous data 8. APl Number so- 029-21277 9. Unit or Lease Name Milne Point Unit 10. Well No. CNo. 8 11. Field and Pool Kuparuk River Field Kuparuk River 85 RECEIVED APR Alaska Oil & Gas Cons. Commission None, well is suspended. Completion Report to follow. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Anchorage SIGNED ~'//'/~-~~ TITLE ,-~,~"¢/1'~,,~, /~J-' ~m) f. DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 Submit in duplicate ., .._. STATE OF ALASKA ALASKAC ~AND GAS CONSERVATION COl, ,l ss ONoPERATiONSf MONTHLY REPORT OF DRILLING AND WORKOVER ~. ~rilli-~g ~ ~- Wor---~ove---~ ~ 2. Name of operator 7. Permit No. Conoco Inc 85-14 3. Address 2525 'C' Street, Suite 100, Anchorage, Alaska 99503 4. Location of Well at surface 780'FSL, 2325' FEL, Section 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 52' KB I ADL 47434 8. APl Number X,~jl~ ' 50- 029-21277 9. Unit or Lease Name Milne Point Unit 10. Well No. CNo. 8 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of Januar~v ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 5935' Spud date 1-27-85 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run RECEIVED F E 2 8 1985 6. DST data, perforating data, shows of H2S, miscellaneous data ~Jaska 0il & ~as cons, L;ornmissi0ff Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE Dril 1 ing Supervisor DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Receipt of the following,material RE: which was C ~)ua c_ o transmitted via is hereby acknowledged: QUANTITY DESCRIPTION DATED: RECEIVED · P E ~ £ ~ 1985 , Alaska Oil & C~ Cons. Comrni,.~lo~ AnChoraEe YES//~ to sender NO FROM: Scbiumberccr Com~.~ut~n~. Center 500 [..~. International. A~o Poad Anchorage, At-: 95502 Customer Number, if any: TO: Alaska Oil. & Cas Conservation 3~'JO! ?orcuoine Drive Ancho ra,~..e, f:¥, 95'501 A. ttn: ~2/llf. am %'az~ Alert 1~' U.S.G.P.O. 1984 -- 440-389 Label 11B (1-84) Initials o~ (a~ditional f~e rek'u~$~ I ,~,To Whom & Date ~1. ,'~.To Whom. Date & Ad~ress of Del. Lbs. Postage . , 324,51318 DESTINATION: . of,Addressee or ADent: .,~ -~'. ,.,% / DELIVEIIY WAS ATTEMPTEB Date: Time: Notice Left By: EXPRESS MAIL SERVICE · STATE OF ALASKA ALASKA:'-' L AND GAS CONSERVATION C(~"MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator - 7. Permit No. Conoco Inc. 85-14 3. Address 2525 C Street, Suite 100, Anchbrage~ AK. 99503 4. Location of Well 780' FSL, 2325' FEL, Sec 10, T13N, R10E, U.M. @ Surface 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ' I 12. 8. APl Number 50- 029-21277 9. Unit or Lease Name Milne Point Unit 10. Well Number CNo. 8 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) -: (Submit in Duplicate) Perforate [~ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation []: Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 w~ih a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any : proposed work, for Abandonment see 20 AAC 25.105-170). The C-8 well was drilled to a total dePth of 9620' M.D. on February 7, 1985. It is now proposed that the well be perforated in the Middle Kuparuk 9170' to 9184', 9228' to 9248' 9259' ' . , to 9265 and in the Lower Kuparuk formation 9374' to 9402' A production packer will then be set between the two sands and 3~" tubing with a second production packer will be run. The second packer will be set at ±9100' to effectively isolate the two formations. After completing the Lower Kuparuk sand will be flow tested then the well is to suspended until summer when the Lower Kuparuk will be fractured and additional footaged perforated. Verbally approved by Harold Hedlund on February 8, 1985, 5:30 p.m. RE'CE!VED FEi3 I 1 1985 AlasKa Od & Gas Cons. Commission Anchorage 14. i hereby certify that the foregoing is true and correct to the best of my knowledge. , Signed P' ~¢~o '~~~ (~/~'/' ~;;~'~ Title Productio~t Engineer The space below for Commission use Date 02-08-85 Conditions of Approval, if any: Approved by. COMMISSIONER Approved Copy Retu-:~ed ~ ~ ............. . ...?,~ By Order of the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate M EMORAt, DUM Stat,, of Alaska THRU: Lonnie C. Smith Commas sioner O^ZE: January 28, 1985 mtENO: D.HRH.9 TELEPHONE NO: FROM: SUBJECT: Harold R. Hawkins Petroleum Imspector Witness Function of Diverter, Conoco Inc. C-8, Milne Point KRU, Sec. 10, T13N,R10E,IR~, Permit No. 85-14. Saturday, jJ~anuary 26, 1985: I left ARCO's West Sak ~26 subject of another report, to COnOco's C Pad to witness function testing of the diverter on Alaska United Rig No. 3. I witnessed the function test of the diverter and checked the diverter flow line and valves to divert gas or fluid in different directions. In summary, the diverter system was set up and tested satisfactorily, on Conoco's C-8 well. .. 02-00IA(Rev. 10/79) January 24, 1985 Dan R. Girdler Conoco Inc. 2525 C Street, Suite Anchorage, Alaska 99503-2689 Re: Milne Point Unit, C-8 Conoco inc. Permit No. 85-14 Sur. Loc. 780' FSL, 2325' FEL,_Sec. 10, T13N, R10E, US. Btmhole Loc. 283' FNL, 1425' FEL, Sec. 9, T13N, R10E, US. Dear Mr. Girdler: Enclosed is the approved application for pemit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter survey s. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to 'AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution. of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by'a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 2'4 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Verff~ truly y~qurs C. V. ChattertOn Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMAMISStON lc EnClosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 January 22, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Permit to Drill. applica- tion for Milne Point C-8. A $100 check is being submitted with the permit application to fulfill the permitting fee requirement. If you have any questions, pleaSe call Don Girdler at 279-0611. Very truly yours, John R. K~p Manager of Alaskan Operations DRG/kr cc: MP C-8 Correspondence File RECEIVED JA IV 2 $ Oil & ~s '~ A oor~s. ~nch~rage STATE OF ALASKA ALASKA~IL AND GAS CONSERVATION C~MISSION PERMIT TO DRILL 20 AAC 25.005 ~ ~, SERVICE [] f~ STRATI~RA~I~I~I~[~ SINGLE ZONE ~. '~' '~ MULTIPLE ZONE ~'~',, '~. ~, 9. Unit or lease name ~'~ Milne Point Unit ~ lb. Type of well EXPLORATORY [] DEVELOPMENT OIL IX' DEVELOPMENT GAS [] la. Type of work. DRILL REDRILL DEEPEN 2. Name of operator Conoco Inc. 3. Address 2525 C Street, Suite 100, Anchorage, AK 99503 4. Location of well at surface 780' FSL, 2325' FEL, Sec. At top of proposed producing interval 500' FNL, 1200' FEL, Sec. At total depth 283' FNL, 1425' FEL, Sec. 5. Elevation in feet (indicate KB, DF etc.) ! RKB 52', Pad 17' i 12. Bond information {see 20 AAC 25.025) 10, T13N, R10~ ~1 9, T13N, R10E7 L~/~ 9, T13N, R10E~ GI~ 6: Lease designation and serial no. 47434 10. Well number CNo. 8 11. Field and pool Kuparuk River Type Blanket surety and/or number 8086--15--54 Amount $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 33 mi. NW of Deadhorse miles 38551 @ T.D. feet well ~-~ ~[~' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 9805' (MD) 7320' (TVD) fec. t ~5~,.~)' 1-26--85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 46° l (see 20 AAC 25'035 (c) (2) 3000 psig@ . Surface 3800 psig@__7_32_(~ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole Casing Weight 17~i' ~ 13 3/8~ 12¼" 9 5/8" 8~" 7" 48 36 26 CASING AND LINER Grade Coupling Length H-40 PELP 80 ' L-80 ~ 7 7¢ 22. Describe proposed program: SETTING DEPTH MD TOP TVD 35' I 35' 35' ~ 35' 35' , 35' I MD BOTTOM TVD 115~ 115 5877'I 4600 9805'1 7320 QUANTITY OECEMENT (include stage data) _+110 CF CMT +2900 CF CMT ~ ~CF CMT ~"' Conoco Inc. proposes drilling the subject well as a delineation well in the Kuparuk River field. The mud system will be low solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T.D. will be 10.2 ppg. A 20" 2000 psi diverter will be installed on the 13 3/8" conductor for drilling the surface hole. A 13 3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per state regulations. Maximum surface pressure is based on initial reservoir pressure and C No. 8 is no closer than 120' from another wellbore. The closest wellbore will be C No. 6 which will parallel this wellbore at a distance of 120' from surface to the C-6 kickoff point. Arctic pack will be placed in the 7" x 9 5/8" annulus after disposing J~'test oil and excess drilling fluids. The well will be perforated and completed before releasing the drilling rig. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED(~~-~_~'kx ~_.~__~__ -'-~'~v~--_~w. TITLE Engizleering TecNnicianDATE The space below forComm~T~ 'on use ~ 01-14-85 CONDITIONS OF APPROVAL Samples required I Mud log required I Directional Survey required [-]YES ~.NO i i--]YES F-)-)-~ N O I I~YES I--INO Permit number Approval date APPROVED BY Form 10-401 R~.v 7-1-g0 APl number 50- SEE COVER LETTER FOR OTHER REQUIREMENTS iC'OMMISSIONER DATE January 24, 1985 by order of the Commission Submit in triplicate Ie CEMENTING PROGRAM SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Milne Point No. C-8 Conoco Inc. 2525 "C" Street, Suite 100 Anchorage, Alaska 99503 A. Bo The 13-3/8" conductor will be set at 80' below the surface (115' K.B.), then cemented to the surface with permafrost cement. The 9-5/8" surface casing will be cemented with 900± sacks of Permafrost "E" cement followed by 950± sacks of Class "G" cement. The top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The primary cementing job will consist of 700± sacks of Class "G" cement pumped around the casing shoe (estimated 2000± of annular cement, assuming an AHS=ll"). The secondary cement job will consist of 200± sacks of permafrost type "G" cement followed by 60± barrels of Arctic Pack, pumped down the 7" x 9-5/8" annulus. II. ANTICIPATED GEOLOGY O' - 4500' Surface conglomerates, clay, silt and sand sequences. Estimated base of permafrost at 1700'±. 4500' - TD Predominately shale until the Kuparuk Sands - expected at 7000'± subsea TVD. III. FORMATION EVALUATION A. Sidewall cores to be taken as determined by onsight geologist. Be C~ Wireline logs for the surface hole will include DIL-SFL-LDT-CNL. ., Wireline logs for the 8~" hole from T.D. to ±1000' above the Kuparuk interval will include: Dual Induction Laterolog; Sypherically Focused Log; Litho Density; CNL with GR-caliper. IV. DRILLING FLUIDS A high viscosity gel-fresh water (non-dispersed) mud system O' - 1000' Low solids non-dispersed gel/water mud system I000' - T.D. V. DIRECTIONAL PROGRAM The well will be drilled to a proposed KOP of 500', then build angle in a north 46° west direction. The closest that the C-8 will come to another wellbore is from surface to KOP where the proposed C-8 will be 120' northwest of the existing C-6 well. An MWD tool is to be run while drilling for surveying purposes. Final hole angle will be 46°. PAD C. WELL NO, 8 PROPOSED MILNE PT.. NORTH SLOP ........ , ........ ~ ........... ~ . .. ~ ........ , ............................... . ............ EASTMAN WHIPSTOCK. INC. ...... ~ ......... ~ .... KOP'- TVD=500 TMD=500 DEP=O 1_00~_ ~ ' ' [ 20 - ~ PER ~00 FT ~ ~ ' ' { ._~. - '- · - , ' ; i .... ; .... ' - -:[::- . .. t . .oo.o ........ ':_:i::: ..::;..' ' ' ~ ' ' ' ~ ' I : I ~ i · ~ ...... ; . ~ ~~~~. ~ -! . 6ooo___--:.._~ .... :-.,_.J._:_ ... ~ ; ~ ;: ' , ........ 8000 ,.. o ~ .~ooo ; ~ooo ~ ~ooo~ <0o0 ~ ~ ~ ' ' '; ~ L~ SECT_tON · , ' i___HOR "' -7 ONT..AL , i '~'"a~ALE I IN = 1000 FEET , , ! ~ : CONOCO. !NC. , PAD C. WELL NO~ 8 PROPOSED ' MILNE PT.,iNORTH SLOPE, ALASKA - -_-ASTI1AN WHIPSTOCK. INC. SO00 5000 4000' ~4000___ __ WEST.EAST4 3000--i 2000 ......... N 46 DEO ...... 5768' (TO TARGET) .... TD TARGET TVD-Z020 THD-9,.369 OEP-$r~e.. , '- 4.000 _ ..... ~- ...... ~ ' TARGET LOCATION 500' FNL. 1200' _._.~I~.C. 9,_ 'r_l..3_N_, RI OE ]000 i R:.ECE]VE-D Alaska Oili & Gas ~ons. commission' A,'cti~.~.~.-~ ................... :suR~'~C:E:-L'oC~..'ri6"', .... : ............ ~ ...... ' " -780' FSL. 2325' FEL ~ 'SEC. I0. TI3N. RIOE _ WELL iNO, T.,' ', NORTH · . , NOR O0 " 95' II- N MILNE POINT UNIT EXISTING DEVELOPMENT RECEi 2 3 1985 Alaska & Gas Cons. Anchorage NOTES= I. STATE PLANE CO-ORDINATES ARE Z0ME 4. 2. ALL GEODETIC POSITIONS ARE BASED ON N.A.D. 1927. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. STATE PLANE CO'ORDS~ LOCATION IN SECTION GEODETIC POSITION WELL FROMS. LINE FROM E. UNE NORTHINGS EASTINGS LATITUDE LONGITUDE DATE CHECKED :FIELD BOOK C-I il68' 2256' 6,0?-9,450. 18 558,203.55 I 70°29'27-868"N- 149°31'27-O56" W. 4-20-82 LK. 10-82 1229' 2459' 6 ,029,510. 13 557,999.90 70°29' 28.473"ht 149°31' 253, .0 3 6= W. 12-8-82 L.K. 10-82 C-3 J 1:395' 2326' 6 ,029,G77.35 558, 131 .12 70°29' 30. 108"N. 149° 31' 29.135"W. -4-20-82 L K~. 10-82 C-4 J 1344" 2494" 6 ,029,624.35 577,963.ZI 70°29'29. 599"N. 149° L'.'51''34.089'"W. 2-20-83 B.T. 10-82. c-5 I cJSl' ~z54' G, ozs, S33.44 55g, Zlt.$4 7~'.z.9-Zl.m:,~ ~ J4-?'-51-Z&.g54-,,4 II -I -64- 3.H- c.6 I &GE' ~Z~?' G, oz&.g47.7o 556,17~.21 79'-z~-Zz.c/zS~ 1491'~,~-z&.oc~u~ 11-~-&4 J. ~. 24-$4 7 60' ~'Z E,' J.H. ! 149;-Di- 556, 138.5? 7o'- z9- 24.~54, 558. OG~. 34 7ot Z9 -Z&.~o5 u 55~ 051.77 7~'- 29-z7.54o ~' II -I 594' G.oz,9. ~TG.z-z 149'-31-5o./cz/w ti-, - c -,7l lOC)C/' z'59G' c-¢1 ,,,4' zAz~' JG. oz? 5?5. zz 14 9"- ~ l -$z . t, zs-~uj Ii-i-~M,- J.~. 24-,64 24-~,~ 24 -~- CERTIFICATE (~F SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED ~,ND LICENSED lO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PL.~T REPRESENTS A LOCATION 'SURVEY MADE BY hie OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DE. TAIL~ ARE CORRECT. ENGIN~ AND L~ND SURvEYO.~S 'C' PAD AS-BUILT WELL LOCATION Surve3~¢ d fo.' CONOCO ! SCALE : ! SHEET : !' · 400' I I OF 2 C0~ENTS= CONOCO INC. MILNE POINT UNIT BOP STACK Fill-up Line~ ~-- A nuzar eventer ] --~Flow Line (1) B.O.P. stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. (2) BOPE to be operated on each trip & pressure tested weekly. (3) Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. (4) Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. (5) Choke and kill manifolds shown separately to meet API RP 53 class 5M requirements. RAM 13 5/8" - 5000 --RAM 13 5/8" - 5000 3" - 5000 Side Outlets 2" - 5000 Side Outlets 3" - 5000 Side Outlets RAM 13 5/8" - 5000 11" - 5000 & ~ Con[ ~mmi~ion Anchorage CONOCO INC. MILNE POINT UNIT 20" DIVERTER STACK ' ~ Flow Line Fill-up Line ~ ~ I I Annular P q l Preventer ] 4h ,, * . Valve t I Drilling' [ I Valve ,, , 6 Relief Line b' ~) Spool (' ~ 6 Relief Valve i2o" x ~o" i -' , I 2000 psi ] . ~ ~ Saver Sub ~ ~-, - ' Assembly ~~l ~ "- ! f Starting l I '/ ' " ' ' ' I ~ Head ~ ~'~ I I~g I -':.'- 1. Relief lines.from the drilling spool will be routed for downwind diversion. 2. Hydraulic control system will be in accordance with API specifications and AOGCC regulations. 3. Both HCR valves will open when the preventer closes, then either one may be closed. * Depending on rig contracted, the two 6" lines may be replaced by a single 10" line with a downstream tee. DRG 7-17-84 ALASKA UN ITED RIG NO. DRILLING 3 ,BUTTERFLY., VALVE CLOSED DESANDER SUCTION CLOSED Flow path L;~. ....Lw Solids removal ~ ~ 6 7 Desilter suction (Normal) 8 Cleaned mud to treatment pit 9 Underflow from treatment to suction pit 10 Gravity-flooded suction DEGASSING FLOW PATH Flowline (in) & pass shaker screens Shaker discharge into sand trap (ditch to pit room closed) Sand trap overflow into degasser suction (desander suction closed) Degasser discharge into ditch Overflow returns to degasser suction (underflow butterfly clbsed) Switch desander suction out of degasser tank ALASKA. UNITED RIG NO. 3 DRILLING H CHOKE LIQUID MUD SYSTEM ~-~ Active pits ~ Solids removal function ] 4 each: 6"x 6"centrifugal pumps, 75 hp ~ Reserve pits ~e 16 each: Lightnin' mixers, 5 hp MANIFOLD: Working Pressure 10,000 psi w/ Choke (1) Type ' (2) Manual Choke (2) Type (1) Automat i c CAPACITIES ACTIVE SYSTEM I Sand trap 6 bbl I Degasser tank 56 bbl I Desander suction 54 bbl I Desilter suction 55 bbl I Destlter discharge 66 bbl SUBTOTAL Mud Tank No. I I Common 3B I)bl 2 Suction 122 bbl Mud Tank No. 2 Receiving 184 bbl Discharge 184 bbl Mud Tank No. 3 240 bbl SUBTOTAL -- -- ACTIVE SYSTEM TOTAL TRIP TANK SURFACE VOLUME GRAND TOTAL (Calculated 4" below tank top) (2) HCR valves 237 bbl CHECK LIST FOR NEW WELL PERMITS Company Lease & Well ITEM APPROVE DATE (1) Fee (2) Loc ? Is the permit fee attached ~e eeee®le.e®®eee®~ee®eee®e.eeeee®e®®eee®e®e® e 3. 4. 5. 6. 7. 8. (3) Admin(~./ /- x.~-'~3'~ 9. ~ thru 12) 10. //,3-// ,/~ z 3j~' 11. (10 and f2)' 12. '(13 thru ~21 ~ (5) BOPE 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23, 24. 25. 26. 27. YES NO REMARKS Is well to be located in a defined pool ............................ Is well located proper distance from property line ................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ........... Is well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. Can permit be approved before ten-day wait ....... ................... Does operator have a bond in force ..................... Is a conservation order needed .... Is administrative approval needed ..... Is the lease number appropriate ..ii Is conductor string provided ....................................... Is enough cement used to circulate on conductor and surface ........ Will cement tie in surface and intermediate or production strings .. Will cement cover all known productive horizons .................... Will surface casing protect fresh, water zones ...................... Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore .... Is.old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required., ................................. a~d,~-BOP.~'e~'.ipme~t'attached Does BOPE have sufficient pressure rating - Test to ~tff'~ psig Does the choke manifold comply w/API RP-53 (Feb,78) .................. Is the presence of H2S gas probable ................................. Additional requirements . . levee. .eeleeeeeeeeeeeeeeee~eeeeeeeeeeeeeeee', Additional Remarks' ,,,]1, ~ , N~ 7- sO ff /~ ; 77~FD ,_ Geology:~pgineer~nE: g. WVA~ JKT~HJH~Z~ '- - rev: 10/29/84 6.CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX.' .. No special 'effort has been made to chronologically organize this category of information. .,LIS T~PE V~RIFICATiO,~ LISTIN~ LVP OI~.HOZ VERIFICATION LISTING PAJE I · ~ REEL HEADDR ~ SERVICE NAME :EDIT DATE :~5/0Z/15 ~RIGIN : REEL NAME : CONTINUATiDN · :01 PREVIOUS REEL : CDMMENTS : ~, TAPE HEADER SERVICE NAME :EDIT DATE :85/0Z/15 ORIGIN TAPE NAME : CON~IN~AiIDN PREVIOUS T~P£ : CDMMEN~S : ,~ R~CDRO T'YP~ ~37 O~ ~ FILE HEADER :ILE NAME ,:'EDIT .001 SERViC~ NAME : ~ERSION ) )ATE : 4AX1MUM LENGTH : 1025 :ILE TYPE : 'RE'VIODS FILE INFORMATION RE'£OROS :~.~: iNEM CONT~N'TS UNIT TYPE CATE SIZE CODE ',N : CONOCO ALASKA 000 000 013 065 'N : MPa C-8 0.00 .'000 OZO 065 N : ~U, PARUK RI~ER OOO 00.0 01~ ANG: IOE OOO .000 00.~, 065 0 WN: 13.N 000 .000 004 DUN: N.SLOPE 000. DO0 012 0.65 'TAT: ALASKA 000 000 006 NE'M C~NTENTS UNIT TYPE CATE .SIZE LVP 010.~t02 VERIFICATION LISTING PASE Z ~ SCHLUMBERGER -'~ ~ &LASKA COMPUTING CENTER ~OMPANY = CO.NDCO, INC, NELL : MILNE POINT UNIT 2-8 FI~LO = KUPARUK COUNTY : NORTH SLOPE 80ROUGH STATE : ALASKA J~ NUMBER AT ACC: 700~2 RUN ~ONE, DATE LOGGEO: 01-FE5-.85 LOP: CEW .: SCHLUMBER~E~ : ALASKA OIVISION COMPUTING CENTE2 COMPANY = CONOCO ~ELL = MPU C-8 FI!ELD = KUPAR.UK COUNTY = N.SLOPE STATE = ALASK SECTION = lO ALASKA RIVER LVP OlD.H02 'VERIFICA'TION LISTING TOWNSHIP = RANGE = IOE TAPE D~N$ITY = BO0 BPI JOB ~ 7C~69 BASE LOG: OIL , RUN ~ Z DATE LOG~EO 8 FEB ~5 LDP: T ~ALSTE4D e~ OAT~ FORMAT R~CORD ~ ENTRY ~LOC[S TYPE SIZE R~PR CODE ENTRY ~ 4 7.3 60 ~ 4 .65 .lin ~6 1 ,6~ 1 0 I 65 0 OATUM SPECIF[CAI[ON 5LOCKS MNEM SERVICE S~ERViCE UNIT APl API APl APl FILE SIZ~ ,SPL R~PR IO ORDER ~ LOG TYPE CLASS MOO NO. COOE DEPT S P OIL DI L OIL '2. IL LDT cDT FT O0 000 O0 0 0 OHMM O0 220 O1 0 OHMM O0 IZO OHMM O0 120 MV O0 010 O1 0 0 GAPI .00 310 Ol 0 0 ~API O0 310 Ol 0 0 IN: O0 lBO 0:I 0 0 G/C3 O0 350 02 0 0 G/'C3 0'0 ~55 O1 0 0 O0 %lO O0 O0:O 0.0 0 0 PU O0 890 OO 0 0 PROCESS (OCTAL) I 58 O0000OO0000000 1 58 OO00000000000D: I 58 00000000000000 I 68 0000000000000~ i 58 00000000000000 1 6,8 00-00-000000000:0 1 68 0000000000000~ 1 ~::8 O00000000'O000O' 1 ~,8 0000000000000~ 1 1 68 00,0000 0000000:~ i 68 0~00,000000000.0 LVP 01g. HOZ VER[FICAT'ION LISTING PAtE PEF LDT NCNL LDT CPS FCNL LDT CPS O0 353 O1 0 0 330 31 0 0 330 3'0 0 0 DATA ,:4: DEPT SP RHOB NPHI 9538.0000 SFLU -23.5250 GR 1o4561 DRHO 34.2285 PEF 5.~570 105.062J GR 0.0166' NR~T 2oi348 NCNL DEPT SP RHDB 9500.0000 SFLU -24.7500 GR 1.,5855 DRHO 37.7441 PEF $.3203 ILD 105.0625 GR 0.1172 NRAT 2.~121 NCNL DEPT SP NPHI 9500.0.000 SF~.U -61.8125 GR 2.2969 ORHO 3.1250 IL; 9'7.0625 GR 0.1.611 NRAT 3.0684 NCNL DEPT SP RHOB NPHI 9&O0.O000 SFLU -70.2500 GR 1.2.617 ORND 26'8555 PEF 16.7969 ILD 76.0625 GR 0,.0137 NRAT 1..984~ NCNL D E P T SP R H 0 B NPH I 9300.0000 SFLU -31.2500 GR 30.2246 PEF 5.82~1 ILD 8~,'8125 GR 0.0542 NRAT 3'8~!96 NCNL RI'lOB NPHI 9.200' 0000 SFLU -39. 7500 GR 32.3730 PEF O-.O~SB N:R:~T: 2'6~75 N.CNL DEPT :NPHI 9100,.0000 SF~U -10.9922 GR Z,.~414 DRHO 1. 6035 IL D SR NRAT 3' 2109 : NC NL 2 - 4121 O R H 0 43. 7012 PEF l. 7.03:1 IL0 121.4375 GR 0.. 1016 NR AT: .3.203~ NCNL DEPT NP,H i $900.0000 SFLU 44.48:Z4 PEF 3 ,' 59 77 [ L O 150,. 0'000 $ R ,O. 02'98 NRAT Z. 9 ~ 53 N C N L D E P T S P SFLU I.L ~ ~$ R 15 G R 1 ,6 8 I 68 1 1.9502 ILM 105.0625 CALI 3.2117 RNRA 2248.00.0.0 FCNL 5.468,8 10:5.0625 CALl 3.0117 RNRA 2248.0000 FCNL 2.5820 ILM 9'7.06Z5 CALl 3.B730 RNRA 1625.0000 FCNL 15.8281 ILM 7,6.0625 CALI 2.548B RNRA 266B..0.000 FCNL 4.8789 ILM 88.8125 CALl 2.79,59 RNRA 2165'0000 FCNL 2-94:92 RNRA 2606.0000 PC.NL 1.4932 ZLM 117..7500 CALl ,4..0117 RNRA 196;3.0000 FCNL 121'4375 I 3.6133' RNRA 1.843'0000 F.CNL 2.9824 ILM 150.0000 CA. LI. 3'6992 R.N~A 1839.0000 ,F.CNL 3.7051 .ILM 155..525'0 ALI O0000OO0000000 0000000000000,2 O00000000OO00O 4.5508 8.5000 3.i602 711.0000 ~.,.7656 3.1602' 711.0000 2.7129 4. %053 368.75 O0 8.7109 Z. 6055 i02,~.0000 5.1016 ~ = 0000 2.966,8 0-, 00 O0 9.10t 6 1.36 ¢3 g., ~ 5.3' 1 ~. Z'773 ,¢ 58,. ~ 500 .~g0.7500 3.1738 10 ,. 06Z 5, ~,. 1456 4~4. O00O LVP OlO.HOZ VERIFICATION LISTING PAgE RHOB 2.4434 2RMO NPHI 36.5234 PEF OEPT 8700.0000 SFLU SP -31.8~06 GR RHOB 2. 5117 DRHO NPHI 31.~0~$ PEF DEPT 8500.0000 SFLU SP -48.0313 GR RH.DB 2.4883 ORHO NPHI 31,5406 PEF OEPT 8500.0000 SFLU SP -~:5.8125 GR RHOB -999.2500 ORHO NP.~I -399.2500 PEF D:EPT 8600.0000 SFLU SP -45.5625 GR RHD5 -999.2500 DRHO N.PHI -999.2500 PEF DEPT 8'~00o0000 SFLU 5P -43.31,25 GR RHOB -999. 2500 DRHO NPHI -999. Z500 PEF DEPT 8100.0000 SFLU -50-5313 GR -993.2500 ORHO NPHI -999.2500PEF OEPT R'HOB DEPT SP RHDB NPMI DE:PT BO0:O,.O000 SFLU -51.5313 ~R -999o,2500 ORHO -999.2500 PE~ 7900'0000 S,FLU '~,1.250'0 :GR -99 ~,',gSO0 ORHO -'999. 250.0 PEF - ~ , 750 GR -9,99. :250 O DR H 0 -999. 2500 PEF 7?00.0000 ,'SFLU 0.1025 NRAT .3.23,4~ NCNL i-5523 IL~ 65.½375 GR 0.0103 NRAT 3.B~57 NCNL 3.5156 ZL2 i20.,6875 SR 0.07,42 NR~T 3.1172 NCNL 2.5430 iL3 103.6250 GR -999.,2500 NRAT 3.1504 ILD ll2. JOOO GR -999.2500 NRAT -999.2.5~0 NCNL .Z.~961 110.~375 GR -999.2500 NR~T -999.2500 NCNL 3.2480 IL3 9~..68'T5 SR -999o25:0.0 NRAT -999°2500 NC'~L 3.22.66 ZLD 109-Z500 GR -999,.2500 NRAT -'999'.2500 NCN:L -999° 25'00 NRAT -99'9.2500 NCN.L 3.3955. 'iL2 128.2500 ~R -999.,Z500 NRAT -99:9.2500 NCN'L Z,.0938 IL2 95.8125 GR NRAT NC'~L 2.3574 iLD 3.$223 RN~A 1676.0000 FCNL 1.7158 iLM 65.4375 CALI 2918.0000 FCNL 3.3770 ILM 120.5875 CALl 2.9785 RNRA 2ZZ:6.0000 FCNL 3.0723 ILM -999.2500 CALl -999.2500 RNRA -999.2500 FCNL 3.06~5 -999.ZSOD CALl -999.2500 RNRA -9'99.2500 FCNL 2.,6895 iLM -999-2.5'00 .CALI -999.Z500 RNRA -999°2500 FCNL 3.2910 ,ILM -999.2500 CALl -999.Z50'0 RNRA ,-99'9.2500 FCNL 3°0879 I'LM -99:9' Z5,00 CALI -999. 2500 fRNRA -99'9. 2500 F CN:L - '~J 99. z 5, o o c A L I -~99o ZS:.O0 'RNRA -~99. ZSO0 FCNL 3. 3496 '~ LM '9 99.25,00 C A:LI, -999.2,5~0 RN~A -99'9:"2500. FCN'L 2o15:~3 ILM 500 'C AL I 5,0,0 R N R A ~99.~5D0 FCNL ;2.5.13'7 ILM ,3.~707 540.5000 I.~354 9.0313 2.9727 981.0000 3. '4492 i0.05~7 3 .. 0547 728. 5000 3.1.074 -99'9.2500 -999.t500 -999°£500 3..1387 -999.2.500 -999. 2500 -999.2500 -999.2500 3.375:0 -999.Z500 '-999'2500' -~99'2500 -999.Z$00 '-9:99,,25D0 -99'9'2500 -999.Z500 999.250'0: -ggg,.ZSO0 -999.Z5'00 LVP OlO.H02 VERIFICATION LISTING PA~E 6 SP -49.7813 GR RHDB -999.2500 DRMO NPHI -999.2500 PEF 2EPT 7.500.0000 5FLU RHD6 -'999.°2500 DRHO NPHI -999oZ500 PEF DEPT 7500°8000 SFLU SP -46.3750 GR NPH[ -999,2500 PEF DEPT 7~00o0000 SFLU SP -42.5625 SR RHDB -999.2500 ORMO NPMi -999,2500 PEF OEPT 7300.0000 SFLU SP -4~o 6250 GR RHO~ -999.Z5.00 ORHO NPHI -999,,,2500 PEF DEPT 720'0.0000 SFLU SP -50.8437 GR ,:R'HOB -999,°2500 ORHO NP,HI -999.oZ500 PEF DEPT 'TlO0.OOOO S,FLU "-999. Z500 gRHO NPHI --99r9'2500 PEF ~ ~:P T '? .000.00_6,5. 1810 '30 ~R$ F L U - 99:9' £5 O0 OR ~0 ,-399.Z500 PEF DEPT OEPT N'P:HI 6~00.'0000 SFLU -999,2500 ORHC -999,-2:500 'PEF SF:LU GR ~ '99. Z 5 O 0 P .E r -3:Z-~lg5 'GR - 999. Z 500 iD R HO 102.31Z5 GR -999.2500 NRAT -999.2500 N.CNL 2.~430 ILD 87.1875 GR -'999.2500 NRAT -999.2500 NCNL Z.Z~80 iLD 91.1250 GR -999,2500 NRAT -999.2500 NCNL Z.3711 122.'7500 $R -999.2500 NRAT -999. ZS'O0 NCNL 2.3164 .ILO 98.0625 GR -999°2500 NRAT -99@.2500 NC~L 2.2813 I,LD 99.8125 GR -999,2500 NRAT -999.2500 NCNL Z.96~B -99 9.,~5,00 NRAT 250 0 NC.NL 2:-~336 I'LD 87.~3:75 GR -999. Z500 NRA'T -999.2500 NCNL 2.7,012. i L ~ 86.561:5 GR -999.2590 NRAT -99'9. 2500 N:C NL 86. 875,0 GR 2. ',39 45 I L D 76 . .375' '0 G :iR -- 999. 2500 NRAT - 99 '9,. Z 5 O O N C :N L -999.2500 CALl -999.2500 RNRA -999.2500 FCNL 2.449l -999.2500 CALI -999. Z500 RNRA -999.2500 FCNL 2.3691 ILM -999.Z500 CALI -999.Z500 RNRA -999.2500 FCNL Z.3926 iLM -999.2500 CALI -999,.2500 RNRA -999.2500 FCNL 2 .. 39.65 ILM -999.2500 CALl -999. 2500 R.NAA -999,. 2500 FCNL ,2.4:063 ILM -99'9.2500 CALl -999.2:500 RNRA -9'99.25,00 ~.CNL 3.14,2.6 ILM -999.2500 CALI -999. Z500 RNRA -999.2500 FCNL 2.~309 I'LM -999.2500 CALI ~,NRA FCNL Z o '890,5 '-'i L.M -999:. ~500 CALl -'999. 50:0 RNRA - 9'9 9.2:50::0 F:C NL -999.2500 CALI · R ~ "-999.25,00 ' NRA -99'9.2500 FCNL Z.,.5684 ILM -99'~-,Z500 CALl 999.2500 ~N~A ,'-99:'9:.Z5.0,0 F.:CN:L -999. 250 0 -999. 2500 -999.250'0 2.5273 -999.2500 -999.1500 -999.2500 Z.3789 -999.1500 -999. 2500 -999.25::00 -999.2500 -999.,Z500 -999. 2500 -999.2500 -999.2500 -999.1500 ,-999oZ5~0 -999.25.00 3.199. Z -_'~99.:Z5,0 0 9 '~. Z 50,0 -99:9.2500 2.8613 '2,'5,~30 LVP OiO.HOZ VERIFICATigN LISTING PA,SE 7 gEPT SP RH 06 NPHi DEPT SP RHOB NPHI DEPT SP RHOB NPHI OEPT SP RHDB NPHI DEPT SP R H 0 B N'PHI D EPT '.SIP ~ RH DB NP.HI E P'T P RH g B NPHI OEPT RHOB N P H I · DE 'PT :NP.H I :D.E P T $ P R'HgB N:PHI 6500.0000 SFLU -5q,.5000 SR -999.2.500 DRHO -999.Z500 PEF 5500.0000 SFLU -75. 062.5 GR -999oZ500 OReO -999. 2500 PEF 6½00,.0000 5FLU -48.5313 GR -999.2500 -999. ZSOG PEF 6300.0000 SFLU -49o?B13 GR -999.2.500 DRHO -999. 2500 PEF 6ZO0.O000 SFLU -52.6553 -99'9. 250'0 DR~O -999.2500 PEF 6100o0000 SFLU -58.8125 GR -~99'2500 DRHO -999.2500 PEF 6.0.00'0000 SFLU -66.750'0 GR -99!9.2500 OReO -999.2500 PEF 5900. 0000 SFLU - l 0 o 2 500 l. 3.145 O R hi 0 38.3789 PEP OR~ta 00 O0 S F.L Y 0000 G R 2:363 gRHO 0371 PEF 38.818~ P:F 3.5059 75.9375 SR -999.2500 NRAT -999°2500 NCNL 3.7266 ILD 99.6250 GR -999.2500 NRAT -999oZ500 NC~L 2. 1680 ILO 93.3750 GR -999oZ500 NR.AT -999.2500 NCNL 3.0000 87-'7500 GR '-)99.2500 NRAT -999.250'0 NCNL l. 02.54 .ILD 90.5000 GE -999.2500 NRAT -999.2500 NCNL 3.0391 ILO 67.93'75 GR -999.25O0 NRAT -999.2500 NCNL 9 !. 6875 G R - 999 ' Z 5 O 0 N R ,A T - 999. Z 5 O,O N'C 'N L 3.4~73 ILO 105.t:500 ~R 0.0220 N:R~T 1~.5713 NC~L 7500 C, 0176 NR: AT 595'7 NC~ ~7.257B I:LD 6~.,&.8'75 GR --O.OOrgB N,R.AT 1.1500 N'CN:L 64..8125 S'R 3.3066 ]LM -999.2500 CALi -999.2500 RNRA -999.2500 FCNL 3.1328 iLM -999.2500 CALI -999.2500 RNRA -999.Z500 FCNL ,2.3574 -999.25O0 CALI -999.2500' RNRA -999.2500 FCNL 3.19.1~ ILM -999.25.00 CALl -999.Z500 2NRA -999°25.00 FCNL 2.2090 ILM -999.2500 CALI -999,° 250.0 RNRA -999. ZSO0 ~CNL 3.,2207 ILM -999.2500 CALI -999..2500 RNRA -'999.1500 FCNL -999.2500 CALI -999°2500 ~CNL 62'70 I~M C:,AL~ RNRA 0000 FCNL .Z,. 9!;863 I L N 76',7500 CALI 3. ~7:~i5 RNRA 2012],.00 0 FCNL 6' 7930 I.LM CA ~I RNRA 21,20.-:0000 F C NL ILM CALl F'C NL 3.3867 -999.2500 -999.250'0 -999.25 O0 3.3320 -999.!500 -993.2500 -9'99.2500 -999.2500 -999.2500 -99~.Z500 3. ZO~O -999.2500 -999.2500 -999.2500 -999.2500 -999.2.50'0 -999.2500 3.0605 -999. Z5~.0 -999.2500 -999.2500 :2 .: 73{3'5,, - 999.2500 99'2500 3'.,577~ 536 -,:O0:O0, 554. ]5000 7. ~66A, ' 54,1,0 98., 500,0 4,.,,"~ 063 13. 5078 LYP OIO.H02 VERIFICATION LISTING PAGE DEPT 5~00.0000 SFLU SP -66.0000 GR RHOB 2.2910 DRHC NPHI 41.8457 PEF DEPT $~00.0000 SFLU SP -48.7500 GR RH38 2.2813 ORHO NPHI 42.2363 PEF DEPT 5300.0000 SFLU SP -[14.1875 GR RHDB 2.1309 ORHO NPHI 43.4082 PEF DEPT 5200.0000 SFLU SP -llZ.OOOO GR RHOB 2.0918 ORHO NP~I 40.5738 PEF DEPT 5100.0000 SFLU SP -I1Z.O000 GR RHDB 2.0859 DRHO NPHI 42°7227 PEF D:EPT 5000.0000 SFLU SP -i0..2500 ,gR RHO8 2.1973 DRHO NPHI 41.5992 PEF DEPT 4'~00,. 0000 SFLU O- 2.500 GR 2. 215'8 DRHO N-P ~:I 43.2617 PEF OEPT NP;q I DEP'T ~800,. 0'000 SFLU -2,$. 5156 SR 2.31:05 DRHO 39'794'9 PEF 4700.0000 SFLU SF LU GR R H 0 E F 4SO'O.O000 SFLU -2~..000'0 GR Z't1'72 DRHO 12.4237 36.5875 -O.OOa8 3.5000 5.~609 51.5313 -0.0112 2.3594 2.B437 Oo 0625 -0.0029 2.1113 2.5313 29.0156 -0.0269 1.58~0 3.B6.13 32.2813 -0.0£05 1.7031 55.0313 -0.0111 3,.t199 -0'0073 0.0029 2.~848 5.218'7 -0'001 2.3555 3,09,18 ?2.5000 -0.0O54 2.32.03 5.2930 - '00¢3 ILO GR NC~L iLD N R,~,T NCNL .IL D GR NRAT NC I,IL ILO SR NRAT NCNL 'ILD GR NRAT N:C~L IL3 GR NRAT NCNL ILD GR. NRAT NC NL GR NR~T NCN,L ,i 'L g ~ R:' ~R~T N.C:~L ILO GR NR,~T N,CNL ILg GR N RAT 36.6~75 3.5719 2542.0000 6.1914 51.5313 3.6992 231t.0000 &O.D6,25 3. 7461 2234. 0000 1.20Zl 29.0156 3.5977 233~.D000 1.3232 32.2B13 ,3.5996 22'75.0000 56.03.i3 2250 .... DO00 2.54.37 54.9687 3.7324 1979.0000 Z.8613 50'90.6,2 3°5430 2350.0000 3.4414 72.5000 4.0234 ,45..6250 3'79,49 CALI FCNL ILM CALl RNR~ FCNL iLM CALl RNRA FCN,L CALI RNRA FCNL I'LM CAL~ RNRA FCNL I:LM CALI RNRA FCNL !LM CALI RNRA FCNL IL,M CALi FCNL ILM IL'M CALI RNRA FCNL CALl RNRA 10. -~.609 I3. 1484 3.65~53 695..0000 6.6180 13.~1~i 3.9316 588.0000 i.2871 12 7578 606.0000 12.7513 3,.&055 547.~000 1..%805 3.7051 61~.0000 12.828I 509.50,0'0 3.~41,0 3°96'68 ~9,8. TSBO 3:-72Z .,7 531. ~300:0 .000 0 13.',, ¢ 9'2..2 1797 87,,' 50 9844 LVP OiO.HOZ VERIFICATION LISTING PAi~E NPHI 44.2383 PEF DEPT ¢400.0000 SFLU SP -1,4.5547 GR RHOB 2.1328 DRH~ NPHI 47.02,15 PEF DEPT 4300.0000 SFLU SP -31.2344 GR RHOB 2.1250 DRHO NPHI 42.2852 PEF DEPT 4200.0000 SFLU SP -15.0000 GR RHDB 2.1367 9RHO NPHI 50.7324 PEF DEPT 4100o0000 SFLU SP -38.7813 GR RHDB 2.0801 DRHG NPNI 41.3086 PEF DEPT 4000.0000 SFLU SP -29.2656 GR RHDB 2.1270 ORH'O NPHI ,46.3867 ,PEE DEPT 3500.0000 SFLU S'P -49.2813 GR 'RHDB 2.101.6 DRHG N'P:HI ~1.5527 PEF DEP'T 3B'O0-O.'O00 SFLU R:M~'B 2o33~0 g:R~D NPdI 43'9941 DEPT 3'700.0000 SFLU SP -5.~...00~0 GR ~HDB 2.0547 gRHO NP'H:I 41.1621 PEF DE:PT NP~I iD E P 'T S'P 3500,,.: 0:00',0. :$ :F'L U, -3'5.. 750,0 GR ~.. ,D R H O PEF 3500.0000 SFLU -6!5,.8125 : G,R .2'.0234 OReO 39°6973 PEF S%00.0000 S,FLU -58,'D000 GR Z. :~'+434 NC,~L 3. :8£62 ILD 59. 3438 GR -0.0234 NRAT 2.-8234 NCNL 5.5508 53.~.375 2R - 0.0093 .".,IR AT 2.35.'55 NCNL 3..~613 iLD 59.5938 G R -0.01i2 NRAT 2.3047 NC,~L 7.0547 ILO 4~.78i3 GR · -0.0156 NRAT 1.9844 NC~.L ,5. 7305 ILO 51.5625 GR -0.0059 NRAT 2..1523 NCNL 8..~5172 iLD 45.1250 GR -0'0195 NRAT 1,'9502 N'-C,~L 8.8516 I:LD 50.3125 ~R -0.0171 NRAT 2.4844 NCNL 8.7578 ILO GR 1.7:666 NCNL 7.8867 :ILO 84'000.0 ~R 0,-0073 NR,AT 2'14,06 NCNL 10'r ' 4 ~84 iLO 4 0.1,25.0 G R -0.0386 NRAT I. '7627 NC:NL ,10 . 5 41.81,25 2216.0000 FCNL 3.8184 iLM 59.3438 CALI 3.9512 RNRA 2144.0000 :FCNL 5.7227 iLM 53.4375 CALI ~.6953 RNRA 2029.000.0 FCNL 5.3672 1LM 59.5938 CALI 4.16,4I RNRA Zt50.0000 FCNL 7.1680 ILM 44.7813 CALI 3.63~8 RNRA 216&.0000 FCNL ,5..94I,¢ ILM 61...5625 CALl ~.9121 RNRA 17'95.0000 FCNL 9 o Z 5 7 8 I L M 1.25.0 ,CALl 4~'3:~445 RNRA 2396'0000 FCNL 7.5000 [,~LM,~ 50.3125 CA.LI 7'75~ , RNRA i95 "0.000o FCNL 8'3438 I.LM CALt RNRA 2058.0,000 FCNL ILM: CALI , ,,, 0~81, RNRA 1858,0000 FCNL 10 . 406,3 I L M 2, 03 B . 00.0 O .F ,£ N L ,~ L M C ALI 556.0000 3.9277 13.0703 4.0938 523.5000 5.7227 13.1532 3.0973 545.5000 5.3711 13.~219 4.3750 .~91..0000 7.1953 1,2.8906 3..4258 632.5000 i2.8750 ~.,0000 ¢49.0000 3.6152 1,2.7'0,31 ' 5} , 556. 0000 ,B. 60,16 58'0 ,. :1:5 2,3 2500 10.6953 8-.52'3'4 12' 5859 LVP 013.H02 VERIFiCATIgN LISTING RHOB 2.0605 0R~0 NPHi 4~.6777 PEF DEPT 3300.80O0 SF~U SP -4.5.0313 GR RHgB Z.i289 DRHO NPHI 50.43<9:5 PEF DEPT 3ZO0.OOOO SFLU SP -52.0313 GR RHOB 2.125<9 DRHO NPHI 43.6035 PEF DEPT 3100.0000 SFLU SP -47.2813 SR RHOB 2.1602 :2RHO NPHI 54.39~5 PEF DEPT 3000.0000 SFLU SP -57.0000 GR RHOB Z.2090 gRHO NPHI ~l.ib21 PEF OEPT 2900.0000 SFLU 5P '-'76.5625 GR RHDB -999.2500 NPHI -<999.2500 O.E P: T 2. 'B 00.0 O00 S ;F L U SP -5,.Z500 .~R HO~ -~99.Z5000 DRHO N P H ,-99 <9 ' 250 P E F DEPT 2700.0000 SFLU GR gRHO NP:H[ -999-2500 ::D.:E P T 2. '~00.0 O00 SF L. U SP -8'7' 7500 GR RHO ~R~O NPHI~ PE' O E"P T 2 500 . 00.00 S F L U N.P:.~I -<9:9 9. Z500 P EF :RHgB NPHi DEPT 0::.0000 SFLU 2~ ,~'5625 GR '-'9<99'Z500 :2RHO -'9'99..Z500 PEF 2300.0000 S.FLU -0.0171 NRAT 1.5252 NCNL $.~367 57.7188 SR 0..0015 NR~T 2.3359 NCNL 9.57i9 ILD 57.3750 GR -0.0146 NR,T ,Z.1465 NCNL 8.~14I .iLO 67.1250 GR 0.0034 NRA'T 2.0430 NCNL 9. 8750 I.LD 64.5125 GR 0.0386 NR~T 2.17,19 NCNL I1.2656 ILg 46.~0.63 GR -99<9.2500 NRRT -999.2500 NCNL I O. 960'9 i IL :D 5 'B. 0938 G R - <9 <9 <9 - 250 0 N R ~ T -<99<9. 2500 NCNL 9.8 Z 03 i,L O 55- 6875 GR -99'9.2500 NR~T -'999. Z $ :'0,0 NC:NL 10,.7578 [~a 3,3.<9375 GR -9'99~.2500 NRAT -999.t500 NCNL 19 3.8 .- 99<9..Z500 NRAT -99:9oZ500 NC!~L -99<9.2500 NRA, T -999.Z5D0 NCNL I 0 .. t 3 Z .B I L D 3.8105 2078.0000 ~.5078 57.7188 ~.1680 1787.0000 9.1406 57.37.50 3.7637 1947.0000 g.5641 67.1250 ~.3750 1739.0000 11. 0547 6~+. B125 3. 6387 1869.0000 11.3<906 -999.2500 IZ. 023,6 -~@9.Z500 - ,~ ~'- z 5o o 10.8594 -999'Z500 -99'~- 2500 8. ~359 -999,' 2500 -.999~.:2500 -9<9<9'2500 -~99.~Z5,00 g<gg..ZSO0 -999.,£500 -999: 99, 9 500 7.27 '73 RNRA FCNL I L M CA~.I RNRA FCNL ILM CALI RNRA FCNL ILM CALl RNRA FCNL ILM CALl, RNRA FCNL ILM CALI RNRA FCNL ILM C AL i RNRA FCNL ILM RNRA F£NL. CALl FCNL ILM CA~: I 'RNRA FCN:L R N R A FCN.L 'l.L M 3.5008 $45.5000 7.7188 14.1157 ~16.7500 8..9922 12.9922 3.8535 5O5.0O0O 8 4.3 '7 ~,.ilTZ 2500 10.710'9 13...3515 3.5801 52Z.0000 1~.3825 -999.Z500 -<999'-2500 II.,6563 -99<9.250'0 99'9.2500 -999'2500 - 9 9, 9::' Z' 50 O' -.'99'9 .' 2.5 O0 I0.18 7'5 -99. .ZSO0 -999. 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