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1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Friday, August 25, 2023 6:12 AM To:Regg, James B (OGC) Cc:Bo York; Oliver Sternicki; PB Wells Integrity Subject:OPERABLE: Producer 14-05A (PTD #1920010) passed warm TIFL Mr. Regg, Producer 14‐05A (PTD #1920010) was brought online on 08/23/23 and a passing warm TIFL was performed on 08/25/23. The passing TIFL indicates two competent well barriers and the well will be classified back to OPERABLE. Please respond with any quesƟons. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: PB Wells Integrity Sent: Saturday, August 12, 2023 2:13 PM To: jim.regg@alaska.gov Cc: Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Producer 14‐05A (PTD #192001) Sustained Casing Pressure IA Over NOL Mr. Regg, Producer 14‐05A (PTD 192001) was reported by operaƟons on 08/10 with IA casing pressure ~2300 psi over NOL. A subsequent TIFL failed on 08/12. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Please see aƩached document with TIO plot. Plan Forward: 1.Downhole DiagnosƟcs: Warm TIFL 2.Well Integrity: Further acƟon as needed. Please call with any quesƟons or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 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. PBU 14-05APTD 1920010 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Saturday, August 12, 2023 2:14 PM To:Regg, James B (OGC) Cc:Bo York; Oliver Sternicki Subject:UNDER EVALUATION: Producer 14-05A (PTD #192001) Sustained Casing Pressure IA Over NOL Attachments:14-05.docx Mr. Regg, Producer 14‐05A (PTD 192001) was reported by operaƟons on 08/10 with IA casing pressure ~2300 psi over NOL. A subsequent TIFL failed on 08/12. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Please see aƩached document with TIO plot. Plan Forward: 1.Downhole DiagnosƟcs: Warm TIFL 2.Well Integrity: Further acƟon as needed. Please call with any quesƟons or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual 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 the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is 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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y Samantha Carlisle at 10:45 am, Feb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• • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, September 11, 2017 5:21 PM To: Regg,James B (DOA);Wallace, Chris D (DOA);AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J;AK, OPS EOC Specialists;AK, OPS FS3 DS Ops Lead;AK, OPS FS3 Facility OTL;AK, OPS FS3 Field OTL;AK, OPS FS3 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;G GPB FS3 Drillsites;Odom, Kristine;Vandergon, Mark A; Vohra, Prachi Subject: OPERABLE: Producer 14-05 (PTD#1920010)Well barriers restored, MIT Passed All, Producer 14-05 (PTD# 1920010)was made under evaluation due to sustained inner annulus casing pressure over NOL. Dummy gas lift valves were set and the well passed a MIT-IA on 9/11/17. The passing pressure test confirms two competent well barriers. At this time the well is reclassified as Operable. Plan Forward/Work Completed: 1. Slickline: Set dummy valves - Complete 2. Fullbore: MIT-IA - Pass 3. Slickline: (Pending) Set TTP & LDL 4. Well Integrity Engineer: Additional diagnostics as needed Please respond with any questions, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 -P Cell 907-980-0552 SCANNED 3 y 2017 Harmony 4530 i • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday,August 18, 2017 4:06 PM To: Regg,James B (DOA);Wallace, Chris D (DOA);AK, OPS EOC Specialists;AK, OPS FS3 DS Ops Lead;AK, OPS FS3 Facility OTL;AK, OPS FS3 Field OTL;AK, OPS FS3 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;G GPB FS3 Drillsites;Odom, Kristine;Vandergon, Mark A;Vohra, Prachi;AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington,Aras J Subject: UNDER EVALUATION: Producer 14-05 (PTD#1920010) High Inner Annulus Pressure Over NOL All, Producer 14-05 (PTD# 1920010)was reported to have sustained outer annulus casing pressure over NOL on 08/16/17 indicating a lack of two competent wellbore barriers. The pressures were confirmed to be TBG/IA/OA=407/2040/541 psi. At this time the well is classified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan Forward: 1. Wellhead: Test PPPOT-IC &PPPOT-T 2. Slickline: Set dummy valves 3. Fullbore: MIT-IA 4. Slickline: (Pending) Set TTP & LDL 5. Well Integrity Engineer: Additional diagnostics as needed Please respond with any questions, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 SCANNED AUG 2 3 2Q17 i • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday,July 16, 2017 8:48 AM To: AK, OPS EOC Specialists;AK, OPS FS3 DS Ops Lead;AK, OPS FS3 Facility OTL;AK, OPS FS3 Field OTL;AK, OPS FS3 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;G GPB FS3 Drillsites; Odom, Kristine;Vandergon, Mark A;Vohra, Prachi; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington,Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer 14-05A (PTD# 1920010)Well Barriers Confirmed Attachments: Producer 14-05A (PTD#1920010)TIO Plot 2017-07-16.docx All, Gas lifted producer 14-05A(PTD#1920010) passed a warm Tubing Integrity Fluid Level (TIFL)test on 07/15/17, confirming two competent well barriers. At this time the well is classified as Operable. Work Completed: 1. Downhole Diagnostics: Cold TIFL—Failed 06/29/17 2. Operations: POP well after common line work is completed—Completed 07/14/17 3. DHD:Warm TIFL—Passed 07/15/17 Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 s�,p1N�E® AUG 2017 C:(907)943-0296 H:2376 • : AK, GWO Well Integrity Engineer Sent: sday, June 29, 2017 3:03 PM To: AK, OPS •SM; AK, OPS FS3 Facility OTL; AK, OPS FS3 Field OTL; AK, OPS FS3 DS Ops Lead; G GPB FS3 Drillsites; Cismoski, r•., '• Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Pros :+ rollers; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; 'chris.wallace@alaska.gov'; Vohra, Prachi Cc: AK, GWO DHD Well Integrity; AK, GWO S ' -II Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Dempsey, Davi• c,.,ibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternic , S 'ver R; Worthington, Aras J Subject: UNDER EVALUATION: Producer 14-05A (PTD# 1920010) In nnulus Pressure above the NOL All, 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, June 29, 2017 3:03 PM To: AK, OPS FS3 OSM;AK, OPS FS3 Facility OTL;AK, OPS FS3 Field OTL;AK, OPS FS3 DS Ops Lead; G GPB FS3 Drillsites; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists; AK, OPS Prod Controllers; Regg, James B (DOA); Wallace, Chris D (DOA); Vohra, Prachi Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J Subject: UNDER EVALUATION: Producer 14-05A (PTD# 1920010) Inner Annulus Pressure above the NOL Attachments: 14-05A.pdf SCANNED JUL 1 12017, All, Gas lifted producer 14-05A(PTD# 1920010) was reported to have sustained inner annulus pressure above the NOL on 6/28/17. The pressures were reported to be T/I/O=SI/2210/400psi. A subsequent cold TIFL failed on 06/29/17 indicating a lack of two competent barriers in the wellbore. At this time the well is classified as Under Evaluation and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1. Operations: POP well after common line work is completed 2. DHD: Warm TIFL 3. Well Integrity Engineer: Additional Diagnostics as needed. Please reply with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 w 1 • • • 4,000 3,800 3,600 - 3,400 - 3,200 - 3,000 2,800 - 2,600 - 2.400 _ 2,200- 2,000- 1,800- ■ ■ Es • ■ • • ■ Es ■ ■ ■ ■ ■ ■ ■ e ■ ■ ■ ■ • 1,600 - 1,400 1,200 1,000 800 - 600 400 200 - 03/29/17 04105;17 34,'12!17 04/19%17 04/26117 3503'17 2 r�lZ-op � ZC0c4% O Gyrodata Incorporated 23000 Northwest Lake Dr. • Houston,Texas 77095 Precision Wellbore Placement T: (281) 213-6300 e F: (281) 213-6301 RECEIVED FEB 17 20W AOGCC swiss JUL 18 2016 SURVEY REPORT BP Exploration Drill Site: 14 #14-05A Wellhead Prudhoe Bay, North Slope Borough, AK AK0116GCM108 19 January 2016 RIGHT PLACE FIRST TIME ccia,www.gyrodata.com Gyrodata Incorporated 0000 Northwest Lake Dr. g1vro/cIata Houston, Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 February 15, 2016 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: Drill Site: 14, Well #14-05A Prudhoe Bay, Alaska Enclosed, please find one (1) copy, and one (1) disk of the completed survey for the above referenced well. 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O X - 1-+ WO (II Ca -J N O N 1- M N +, O (1400T/6aP) AII213AJS D lDOa Survey QC - RGS-CT Continuous Specification Sheet y I + 0. .`' • SURVEY QUALITY CONTROL- SPECIFICATION DATA PRE-JOB CALIBRATION VERIFICATION (ROLL TEST) System Parameter dGx dGy dmbo Mean Gravity Error * Stdev Gravity Error Standard Deviation 0.004 0.004 0.004 -0.00031 0.00004 Tolerance 0.033 0.033 0.087 0.00591 0.00720 GYRO?VERIFICATION (ADVANCED INITIALISATION) Gyro Compass Parameter Gyro noise dGx dGy dmbo Max corr coef Standard Deviation 0.050 0.005 0.006 0.000 0.19 Tolerance 0.141 0.033 0.033 0.087 0.45 Initialisation inclination standard deviation 0.08 Initialisation azimuth standard deviation 0.37 Initialisation azimuth uncertainty in percent of error model -Tolerance < 100% 37% ACCELEROMETER VERIFICA't N (G. )TAL TEST)- not applicable for 2 . elerometer systems G-Total Test Parameter Mean Gravity Error Mean Gravity Error Standard Deviation Error -0.00086 0.00003 Tolerance 0.00590 0.02639 CALIBRATION Tool Number F0216 Calibration Date 13 Aug 2015 OP! EMPERATURE Calibration range From 29.95 To 119.94 Gyro operating range From 34.58 To 104.18 In-Spec if+/- 2.5°C of Calibration CONTINUOUS DRIFT CORRECTION Linear Drift Uncertainty 0.45 Random Walk Uncertainty 0.11 Tolerance 0.46 Tolerance 0.23 I CONTINUOUS MISALIGNMENT CORRECTION Misalignment Parameter dMx dMy Cross corr coef Standard Deviation Tolerance DEPTH CONTROL. Wireline Company Halliburton Line type 7/32" Encoder SF Halliburton Max Depth (TD) ' 8929 CCL Corrected NO Zero Depth (Rig up) RKB @ 73 ft AMSL Rezero Depth 2.9 Given pup joint depth NA Measured P3 NA Strech cor. At TD divided by TD/1000 .2239 Spec'- 1.5/1000 Dif. Between riqup and rezero depths divided by TD/1000 .3248 Spec'- 2.0/1000 Dif. Between given and meas depth divided by meas/1000 NA Spec'- 2.0/1000 NAL STATION R %of Total stations accepted Tolerance > 80% 100% Consecutive Interval out of Specification Tolerance < 100 m (300 ft) 0 feet SURVEY RUNNING TIME Rig up 1/19/2016 9:50:00 PM Rig down 1/20/2016 10:00:00 AM Start Inrun 1/19/2016 10:25:00 PM Field Survey Presented End outrun 1/20/2016 9:40:00 AM Lost Time Comments SURV-Q163 December 2011 Page 1 of 2 Created:10-Feb-16 10:56 AK0116GCM108 Survey QC - RGS-CT Continuous Specification Sheet gym 1110111111111111Ma .11111i1111•1111111. ACCEPTANCE Accept NAME AND DATE Yes/ No Pre-job calibration verification (roll test) YES Click here to enter text. Gyro Verification (Advanced Initialisation) YES Accelerometer verification (G-Total Test) YES Operating temperature within calibration range (+/- 2.5°) YES SIGNATURE Continuous Drift Correction YES Click here to enter text. Continuous Misalignment Correction NT Depth Control Individual Station Report v to Note : Any modifications or amendments to this sheet must be reported to the client representative and the Gyrodata survey focal point. SURV-Q163 December 2011 Page 2 of 2 Created:10-Feb-16 10:56 AK0116GCM108 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday,July 22, 2015 1:22 PM To: AK, OPS FS3 OSM;AK, OPS FS3 Field OTL;AK, OPS FS3 Facility OIL;AK, OPS FS3 DS Ops Lead;AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC EOC IL;G GPB FS3 Drillsites; Chou,Irwin;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer;AK, D&C DHD Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg,James B (DOA) Subject: OPERABLE: Producer 14-05A (PTD#1920010) MIT-IA Passed All, Producer 14-05 (PTD#1920010) passed a MIT-IA on 07/21/2015 following slick line work. The passing test confirms two competent barriers in the well. The well is reclassified as Operable. • Well status is Operable • Annuli are fluid packed • A 55SV is not required Please use caution while placing well on production due to fluid packed annuli and the potential for annular fluid expansion. Thank you, Kevin Parks SHIED JUL. 2 7 2015 (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator G`/�/ Global Wells �/�/ Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Inte• , Coordinator Sent: Saturday, July 04, 2015 9: M To: AK, OPS FS3 OSM; AK, OPS FS3 Fl- : •TL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Team Lead; AK, D&C Wire - •aerations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr, ^ - OPS PCC EOC TL; G GPB FS3 Drillsites; Chou, Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integre •ineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, es B (DOA) (iim.regg@ialaska.gov) Subject: NOT OPERABLE: Producer 14-05A(PTD #1920010)TIFL Failed All, 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, July 04, 2015 9:56 AM To: AK, OPS FS3 OSM;AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Chou, Irwin; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: NOT OPERABLE: Producer 14-05A (PTD #1920010) TIFL Failed Attachments: image001.png; image002.png All, Producer 14-05A(PTD#1920010) failed a TIFL on 07/04/2015 following gas lift work. The failing TIFL indicates a lack of two competent barriers in the wellbore. The well is reclassified as Not Operable until tubing integrity is restored and verified. Proposed plan forward: 1. Slickline to dummy gas lift valves and MIT-IA 2. APE to evaluate for LDL if MIT-IA Fails Please call with any questions or concerns. 2015 Thank you, Sante JUL 0 6 Kevin Parks (Alternate: Whitney Pettus; BP Alaska-Well Integrity Coordinator Globalrganization Wells G V}I i V O Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, DDCme ri Coordinator Well., g ty Sent: Monday, June 15, 9:07 PM To: AK, OPS FS3 OSM; AK, OPS S Ops Lead; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug , nil, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; u, Irwin; AK, OPS FS3 Facility OTL; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Proje -II Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; 'Regg, James B (DOA) (jim.regg ka.gov)'; Sternicki, Oliver R; Pettus, Whitney; Weiss, Troy D; Morrison, Spencer Subject: UNDER EVALUATION: Producer 14-05A (PTD #1920010) Inner Annulus e -=•ed MOASP All, 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, June 15, 2015 9:07 PM To: AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Chou, Irwin; AK, OPS FS3 Facility OTL; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA); Sternicki, Oliver R; Pettus, Whitney; Weiss, Troy D; Morrison, Spencer Subject: UNDER EVALUATION: Producer 14-05A (PTD #1920010) Inner Annulus exceeded MOASP Attachments: image001.png All, Producer 14-05A(PTD#1920010) inner annulus exceeded MOASP on June 13, 2015. Pressures were confirmed on June 14, 2015 to be T/I/O = 2470/2480/330 psi. A subsequent warm TIFL performed on June 15, 2015 failed, demonstrating a lack of two competent barriers in the wellbore. At this time, the well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Downhole Diagnostics: TIFL— FAILED 06/15/15 2. Slickline: Change out orifice gas lift valve 3. Downhole Diagnostics: TIFLSCANNED JUL U 2015 4. Well Integrity Engineer: Additional diagnostics as needed Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GVVGsobal d1. Ogantat i WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~'C~'~/ File Number of Well History File PAGES TO DELETE RESCAN ~,'~~Color items -Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA n Diskettes, No. Other, No/Type OVERSIZED , , , , · n ' Logs 'of various kinds . n Other Complete COMMENTS: Scanned by: Beverly Dian athan Lowell ,,, , , , , , TO RE-SCAN Notes: · Re-Scanned by: Beverly Dianna Vincent ~a owell • • rl"q. l 4- -c-sA- Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] Sent: Wednesday, August 15, 2012 3:12 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; G GPB FS3 Drillsites Cc: AK, D &C DHD Well Integrity Engineer Subject: OPERABLE: Producer 14 -05A (PTD #1920010) Competent Barriers Confirmed All, Producer 14 -05A (PTD #1920010) passed an MIT -T and CMIT -TxIA on 08/14/2012. The passing tests confirm two competent barriers to formation and the well is reclassified as Operable. The well may be placed on production whenever convenient for Operations once the down hole plug is pulled. Thank you, Mehreen Vazir SCANNED MAY 0 7 2013 BPXA Well Integrity Coordinator From: AK, D &C Well Integrity Coordinator Sent: Thursday, August 02, 2012 7 :59 PM To: 'Schwartz, Guy L (DOA)'; 'Regg, James B (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Tea Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; G GPB S3 Drillsites; AK, OPS GC1 OSM; AK, OPS GC1 Field 0 &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Leas, AK, OPS Prod Controllers Cc: AK, D &C Well Integrity Coordinator; Wills, Shane M; Arend, Jon (NORTHERN SO ONS LLC) Subject: NOT OPERABLE: Producers with Sustained Casing Pressure During Pror. on All, The following producers were found to have sustained casing pressu - on the IA during proration. The immediate action is to perform a TIFL on each of the wells to evaluate for IA repress. ization. If the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well with a plan forwa :. 06 -19A (PTD #2081020) 14 -05A (PTD #1920010) F -43 (PTD #1910750) All the wells listed above are reclassified Not Operable until start -up operations commence and are stable or the well passes a pressure test confirming integr . After start-up, the wells will be reclassified as Under Evaluation with POP parameters to prevent any over -press e incidents if integrity has not been confirmed. Please call with any questions or •ncerns. Thank you, 1 STATE OF ALASKA ALASKA IDAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations 0 Stimulate ❑ Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waived] Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ • 192 -0010 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 * 50- 029 - 20327 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028312 L PBU 14 -05A 10. Field /Pool(s): ` PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 9380 feet Plugs (measured) 8961 (TOC) feet true vertical 9237.53 feet Junk (measured) 9330 feet Effective Depth measured 9336 feet Packer (measured) 3747. 7573 7592. 7651 8380 feet true vertical 9199.43 feet (true vertical) 3747, 7567 7586. 7645 8380 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 20" 94# H -40 30 - 114 30 - 114 1530 520 Surface 2707' 13 -3/8" 72# NT -80 29 - 2736 29 - 2736 4930 2270 Production 7902' 9 -5/8" 47# L -80 28 - 7930 28 - 7924 6870 4760 Liner 3832' 7" 26# L -80 3747 - 7579 3747 - 7573 7240 5410 Liner 1796' 7" 29# 13CR80 7584 - 9380 7578 - 9238 8160 7020 Liner Perforation depth: Measured depth: SEE ATTACHED - - 9 t - — True Vertical depth: _ ' i ,, ' — - asp Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# L -80 23 - 31 23 - 31 4 -1/2" 12.6# 13Cr80 31 - 8443 31 - 8418 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Packer 3747 3747 7" Baker JM -ZXP Packer 7573 7567 7" Baker H- Isolation Packer 7592 7586 4 -1/2" Baker S -3 Perm Packer 7651 7645 4 -1l2" TIW HBBP -R Packer Q�,�$� 8360 12. Stimulation or cement squeeze summary: \�Mi#.�1' Intervals treated (measured): SAP 3 ?MI Treatment descriptions including volumes used and final pressure: Oil & Gas Cons. �,a( jSSiOn 13. Representative Daily AveAWP1 . g&on or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 234 7,512 6,650 360 Subsequent to operation: 399 13,300 5,476 332 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 „ Service p Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: 011 , la Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGO GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed N : - Joe Last Zik 4 Title Petrotechnical Data Technologist Signatk = 'ai • Phone 564-4091 Date 9/30/2011 Form 10 -404 Revised 10 /20TUBDMS OCT 03 7L 1.3Q.(I 4 _ 9 1 o / ,, Submit Original Only • 14 -05A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 1I �1 1 �..,: .. .., w`T"i�,f * ,.: , . 9/4/2011; ** *WELL SHUT IN ON ARRIVAL'" * *(E -LINE POSISET PLUG, DUMP BAIL CEMENT) INITIAL T /I /O = 2400/2000/500 RIH WITH 2.125 POSISET PLUG. PLUG SET CENTER ELEMENT AT 8964', PLUG TOP AT 8962' RUN 1 OF 3 CEMENT DUMP BAILED ON TOP OF POSISET PLUG AT 8962' MD. CEMENT BAILER - 32 FT,4 GALLONS - 2.7 FT CEMENT FINAL T /I /O = 2420/2000/500 MASTER =O, SSV =C, WING =C, GLT =C, SWAB =C, TREE CAP ON AND TESTED. IDSO NOTIFIED. 'JOB IN PROGRESS * ** 9/5/2011; ** *WELL SHUT IN ON ARRIVAL, CONTINUED FROM 4- SEP -11 WSR * * *(E -LINE, DUMP BAIL CEMENT) INITIAL T /I /O = 2450/2000/500 RUN 2 OF 3, CEMENT DUMP BAILED 4 GALLONS AT 8964' MD. RUN 3 OF 3, CEMENT DUMP BAILED 4 GALLONS AT 8963' MD. 3 OF 3 CEMENT €RUNS COMPLETE. ALL RUNS WERE PERFORMED WITH 4 GALLONS OF CEMENT AND A 32 FT CEMENT BAILER. EXPECTED TOP OF CEMENT 8960 FT ELM FINAL T /I /O = 2400/2000/500 {MASTER =O, SSV =C, WING =C, GLT =C, SWAB =C, TREE CAP ON AND TESTED. ;WING TAGGED KEEP SI FOR 5 DAYS. DSO NOTIFIED. ** *JOB COMPLETE * ** 9/12/2011 ** *WELL S/I ON ARRIVAL * ** :RUN 3.50 CENT, TEL, 1.50 SAMPLE BAILER, LOC. TT @ 8413' SLM 8427' ELMD +14' CORRECTION TAG HARD BOTTO M 8947' SLM 8961' CORRECTED E - DEPTH (top of cement) ** *WELL LEFT S/I ON DEPARTURE DSO NOTIFIED * ** FLUIDS PUMPED BBLS 2 DIESEL 2 TOTAL FLUIDS PUMPED GALS 12 CEMENT 12 TOTAL TREE = MCEVOY SAFETY NOT HIW HBBP PKRS HAVE REDUCED WELLHEAD = GRAY • TEST PRESS L/T E CASES). CONTACT WIE x5102 PRIOR ACTUATOR = AXELSON 14-05A TO PRESSURE TESTING * ** ORIGINAL WELLBORE NOT KB. ELEV = 73' SHOWN BELOW 9-5/8" CSG SHOE'"' CHROME TBG &LNR BF.ELEV= KOP = 8106' 2213' -- -I4 - 1/2" HES X NIP, ID = 3.813" 1 Max Angle = 30° @ 8827' 20" CONDUCTOR 124' ' Datum MD = 8959' 94#, H -40, 2378' J - 19 - 5/8" FO CEMENTER 1 Datum TV D = 8800' SS ID = 19.124" . II 2505' H9-5/8" FO CEMENTER 19-5/8" CSG, 47 #, S -95 XO TO L -80 H 2354' GAS LIFT MANDRELS 113-3/8" CSG, 72 #, NT -80, ID = 12.347" H 2736' Q ST MD 1VD DEV TYPE VLV LATCH FORT DATE 1 3701 3700 0 MMG SO RK 20 09/24/08 9 -5/8" X 7" ZXP LNR PKR , ID = 7.50" I — I 3747' 2 5802 5799 0 KBG2LS DMY INT 0 09/24/08 19 -5/8" X 7" HMC LNR HGR , ID = 6.313" H 3761' 3 6991 6986 4 KBG2LS DMY INT 0 03/06/99 6'l � ' 4 7620 7614 3 KBG2LS DMY INT 0 05/31!99 17" LNR XO RN, ID = 6.056" H 3767' * M 7573' H9 -518" X 7" JMZXPTIEBK PKRw/ SEALS, ID = 6.056" 1 17" LNR, 26 #, L -80 IBT, .0383 bpf, ID = 6.056" I - 1 7579' 7584' H 9 -5/8" X 7" BKR TIEBACK SLV, ID = 7.50" I 7592' 1 - 19 - 5/8" X 7" BKR H- ISOLATION PKR, ID = 6.25" 1 Minimum ID = 3.725" @ 8430' � • 4 - 4 7507 I-- 19-518" X 7" BKR FLEX LOCK HGR, ID = 6.312" 4 -1/2" PARKER SWN NIPPLE i•4 ��� ��„ 7651' H 7" X4 -1/2" BKRS -3 PKR ID= 3.875" 1 x i i i 1 7684' I - 14 HES X NIP, ID = 3.813" 1 4 -1/2" TBG, 12.6 #, 13C FOX, —1 7703' � A .0152 bpf, ID = 3.958" V ► -4 7709' H 7" X 4-1/2" UNIQUIE OVERSHOT 1 14 -1/2" TBG STUB I-I 7706' N 0 MILLOUT WINDOW (14 -05A) 7901' - 7930' • 9 -5/8" CSG, 47 #, L -80, ID = 8.681" I 7901' V N *. 8316' — 14 -1/2" PKR SWN NIP, ID = 3.813" 1 • • • • • 8380' — 17" X 4-1/2" TM/ HBBP PKR, ID = 4.00" 1 ••• V..*** • 8410' H 4 -1/2" OTIS X NIP, ID = 3.813" 1 ,••••••• •••••• ♦, • � • � • � • � • � • � • � • �i 4 8430' J - 112" PKR SWN NIP, ID = 3.725" 1 ,, ••••••••• .••••••••4 .:.:.:.:.:.:: 19 -5/8" CSG, 47 #, L -80 XO TO S -95 H 8195' 1 — ►•• 8443' I- 1 4 -1/2" WLEG, ID = 3.958" ►••••• O •ii•Oii! 1 8423' I ELMD TT LOGGED ' ► 09/04/11 ■ •• •• •• •• i• 8954' CMT TOP (9/5/11) 19-5/8" CSG, 47 #, S-95, ID = 8.681" 1.--L, 8632' , " • ••••••• •• • 8962 — 2 - 1/8" POSISET ► :•:•: +:•:• PLUG (9/5/11) PERFORATION SUMMARY ► • •••i 9Q44' • • REF LOG: BHCS ON 01/31/92 '•'•'•'•'�' ANGLE AT TOP PERF: 30° @ 8878' 4 -1/2" TBG, 12.6 #, 13CR -80, 8443' 9330' FISH - PIECES ��� OF GRAPPLE Note: Refer to Production DB for historical perf data .0152 bpf ID = 3.958" 4rrr* ■* SIZE 1 SPF ( INTERVAL 1Opn /Sqz1 DATE ' l a. • '� ?r�� (06/06/84) ' err_ • ���.�� SEE PAGE2 FOR PERFORATION DATA 17" MARKER JOINT I — { 8586' I lrr� :■rrII, 1 1 1 1 I PBTD H 9336' fir Afar 17" LNR, 29 #, 13CR -80 FOX, .0371 bpf, ID = 6.184" I-I 9380' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/24/79 PRK 171 ORIGINAL COMPLETION 09/18/11 TTR/ PJC ELMD TAG (09/04/11) WELL: 14 -05A 08/04/85 - NI ES RWO 09/18/11 SRD/ PJC SET POSISET (09/05/11) PERMIT No: '1920010 02/05/92 - N2ES SIDETRACK (14 -05A) AR No: 50- 029 - 20327 -01 03/06/99 N9ES RWO SEC 9, T10N, R14E, 1614' FNL & 1154' FEL 03/18/09 RRK/SV ADPERF (03/08/09) 05/31 /11 SCG/ PJC GLM CORRECTION BP Exploration (Alaska) • 'I 4 -05A • ] i x - 0 . • L_. , :: • • PERFORATION SUMMARY •••••••• ••••• REF LOG: BHCS ON 01/31/92 •••••••••••• ANGLE AT TOP PERF: 30° @ 8878' O• Note: Refer to Production DB for historical pert data 00•••••••••• • • •••• • it. SIZE SPF INTERVAL Opn /Sqz DATE • •• •• •• •• •• ••: If/ 3-3/£3" 4 8773 8787 S 04/27/95 . • • • • • • • • • • • • ' i/1. 3 -3/8" 4 8793 - 8807 S 04/27/95 1 •••••1 Iv/ 2 -7/8" 4 8878 - 8890 0 09/04/03 '••••••••••••. 2 -7/8" 4 8894 - 8902 0 09/04/03 ■•.••••••••V 2 -7/8" 6 8894 - 8902 0 03/08/09 : 2 -7/8" 4 8908 - 8918 0 09/04/03 i • • ■ • ••••••� 2 -7/8" 6 8908 - 8918 0 03/08/09 • • • • • • 3 -3/8" 4 8921 - 8932 S 12/01/93 -Ad ❖ + + .: • : : 2 -7/8" 6 8921 - 8933 0 03/08/09 • 3-3/8" 6 8923 - 8933 0 04/16/99 O• i •••••. 3-3/8" 4 8937 - 8947 S 02/20/93 ••••••••••••. 3-3/8" 6 8938 - 8940 0 04/16/99 ,•�•••••!•!• =' 3-3/8" 4 8947 - 8964 S 02/10/92 3-3/8" 4 8972 - 8982 5 02/10/92 = nrw, 3-3/8" 4 8988 - 8994 S 02/10/92 -alum iiii•:� • DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/24/79 PRK 171 ORIGINAL COM PLEfION 09/18/11 TTR/ PJC ELMD TAG (09 /04/11) WELL: 14 -05A 08/04/85 NI ES RWO i 09/18/11 SRD/ PJC SET POSISET (09/05/11) PERMIT No: 1920010 02/05/92 N2ES SIDETRACK (14 -05A) AR No: 50- 029 - 20327 -01 03/06/99 N9ES RWO SEC 9, T10N, R14E, 1614' FNL & 1154' FEL 03/18/09 RRKISV ADPERF (03/08/09) 05/31/11 SCG/ PJC GLM CORRECTION BP Exploration (Alaska) • f& ►4 -os,- lf zoo i0 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] C7� /3 /f � Sent: Thursday, August 02, 2012 7:59 PM tl To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS3 OSM; AK, OPS FS3 S Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; G GPB FS3 Drillsites; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers Cc: AK, D &C Well Integrity Coordinator; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Producers with Sustained Casing Pressure During Proration All, The following producers were found to have sustained casing pressure on the IA during_proration. The immediate action is to perform a TIFL on each of the wells to evaluate for IA repressurization. If the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well with a plan forward. 06 -19A (PTD #2081020) 4 -05A (PTD #1920010) ✓ F -43 (PTD #1910750) All the wells listed above are reclassified as Not Operable until start-up operations commence and are stable or the well passes a pressure test confirming integrity. After start-up, the wells will be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents if integrity has not been confirmed. Please call with any questions or concerns. Thank you, SCANNED MAY 0 7 2013 Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWelllntegrityCoordinator (a�BP.com 1 03/24/11 Scger NO. 5709 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambel Street, Suite 400 Alaska 00 & Gas Cone Comm Anchorage, AK 99503 - 2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 01 -20 BBSK -00054 PRODUCTION PROFILE ?"_jams ' pr.m.t ] 1 09-46 BMSA -00006 PRODUCTION PROFILE . _ ' 1GTi 1 14-05A BBKA -00090 PRODUCTION P • OFILE fe ' G t V 1 12 -30 BBSK -00055 LDL 03/06/11 1 W 1 , D -22C BCRD -00086 SCMT ♦ , — _ 03/04/11 __ , ♦ , - d_ 1 09-02 BBSK -00052 PRODUCTION PROFILE ,'TGTTi'xt. 1 09-41 BBSK -00053 PRODUCTION PROFILE "jj 11� � r� 1 15-05A BCRD -00084 SCMT L"t$.�Gt, ' - n�3` 1 H -15 BCRD -00083 USIT .- h 02/11/11 6, '' 1 1 F -35 BG4H-00037 PRODUCTION PROFILE , " (j i 02122111 1 + Off 1 Z -31 BJOH -00009 INJECTION PROFILE tJ e a 02/12/11 1 �i,r, 1 ID 06 -16 BCRD IO -00090 PRODUCTN PROFILE - 03107/11 1 V 1 X -17 BJOH -00008 RST i�(i._ /4,5 02/11/11 1 1 H-20 BBSK-00051 RST 06 -20A BNWP -00003 RST Jo - b 3 - 02/13111 1 J"Y 1 _ 02117/11 1 Oif � 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gemini] Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 III 4 MAR 2 5 2011 ..., qq %8 4 3 A " , t t BP Exploration (Alaska) Inc. - _.r-._.... _... Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 _... :, w Dec 07, 2009 ~~~~ ,JAR ~ ~ `Zak r Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 ~a"- ~~~ Subject: Corrosion Inhibitor Treatments of GPB DS 14 ~ (,~ -- ~~~" Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-14 Date: 12/05/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 14-OtA 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA 14-03A 1961290 500292031901 Sealed Conductor NA NA 14-04A 1961640 500292032001 Sealed Conductor NA NA 14-05A 1920010 500292032701 Sealed Conductor NA NA 14-06A 2040360 500292032801 Sealed Conductor NA NA t4-o7 1780660 500292032900 Sealed Conductor NA NA 14-08A 2022100 500292033001 Sealed Conductor NA NA 14-096 1820340 500292053402 Sealed Conductor NA NA 14-to 1801300 500292052800 Sealed Conductor NA NA 14-11A 2051260 500292052901 Sealed Conductor NA NA 14-12 1811090 500292063100 Sealed Conductor NA NA 14-13 1811010 500292062400 Sealed Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA 14-15 1810840 500292061100 Sealed Conductor NA NA 14-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-18B 2071290 500292055102 Sealed Conductor NA NA 14-19 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25!2009 14-28 1820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 14-30 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA 14-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 14-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 14-40A 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11!24/2009 OPERABLE: 14-OSA (PTD #1920010) Tubing Integrity Restored Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, September 27, 2008 7:20 PM ~e~~ 1~~~3~tp,, To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Rossberg, R Steven; Engel, Harry R; Daniel, Ryan; NSU, ADW Well Operations Supervisor Cc: Holt, Ryan P (ASRC); Bommarito, Olivia O; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 14-05A (PTD #1920010) Tubing Integrity Restored Follow Up Flag: Follow up Flag Status: Blue AI 1, Well 14-05A {PTD #1920010) recently passed a TIFL after changing out gas lift valves proving tubing integrity has ,, been restored. Therefore the well has been reclassified as Operable. "~ Please let us knave if you have any questians or concerns Thank you, Anna ~u6e, ln. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 agar: (907} 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, September 12, 2008 7:09 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr Central (GCi/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Rossberg, R Steven; Engel, Harry R; Daniel, Ryan; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot; Bommarito, Olivia 0 Subject: UNDER EVALUATION: 14-05A (PTD #1920010) Sustained Casing Pressure on IA All, Well 14-05A (PTD #1920010) has been found with sustained casing pressure on the IA. The TIOs were 2380/2310/410 when a TIFL was attempted on 09/10/08. The test was not completed due to tank issues. However, during the TIFL, the IA pressure was bled to 1960 psi. A monitor on 09/12/08 found the TIOs were SSV/2310/400, indicating the well has TxIA communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. '~-"` The plan forward for the well is as follows: 1. D: TIFL -ATTEMPTED 2. F: MIT-IA to 3000 psi A veal-bore schematic and TIO plot have been included for reference. ~ 10/13/2008 OPERABLE: 14-OSA (PTD #1920010) Tubing Integrity Restored Page 2 of 2 Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 10/13/2008 ~ 001 +u+a PBU 14-OSA TIO Plot PTD 192-001 as-~a.. as-.-u~ ~a~s~aaaa-.-Eaa-sa-aa-.a-~a-a~a-a~ .. 162(Zc~~ 0,01.11) ?,fjl II) 1,000 • 0611108 06/21108 06118/08 07111510$ 07!12!08 0711910$ 0716108 0$102108 0810910$ 08116108 08123108 081~010S 09106/08 TREE = GRAY GEN 2 WELLHEAD GRAY ACTUATOR AXELSON~ KB ELEV 71'~ _ BF ELEV ~ ~. ~ .1 KOP= 8106'1 Max Angle = 30 @ 8827' Datum MD = 8959' Datum TV D - -8800' SS '~ 14-OS 13-318" CSC, 72#, L-80, ID = 12,347" ~-i 2736' r 9-5f8" X 7" ZXP PKR w J HMC HGR , ID = 6.056'° 374T 7" SCAB LNR, 26#, L-80 IBT, .0383 bpf, ID = 6.276°' ~ 75$4' 4-112" TBG, 12.6#, 33CR-NSC, .0152 bpf, ID = 3.958'° 7709' Minimum I = 3.725" 8430' 4-1 /2" PARKER SWN NIPPLE ~4-112" TBG, 12.6#, 13CR-80, .0152 bpf ID = 3.958" ~-~ 84Q,3 9-5f8" CSC, 47#, L-80, ID = 8.681" 8632' PERFORATION SUMMARY REF LOG: BRCS ON 01f31f92 ANGLE AT TOP PERF: 30° @ 8878' Note: Refer to Production DB far historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-3f8" 4 8773 - 8787 S O4f27f95 3-318°' 4 8793 - 8807 S O4f27f95 2-7f8" 4 8878 - 8890 O 09f04103 2-7f8" 4 8894 - 8902 O 09/04/03 2-7/8" 4 8908 - 8918 O 09104!03 3-3l8" 4 8921 - 8932 S 12101 i93 3-3f8" 6 8923 - 8933 O 04116(99 3-3r'8" 4 8937 - 8947 S 02(20f93 3-3f8" 6 8938 - 8940 O 04l16f99 3-3f8" 4 8947 - 8964 S 02f14f92 3-3f8" 4 8972 - 8982 S 02110192 3-3f8" 4 8988 - 8994 S 02/10f92 33~~ 4-1f2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3701 3700 0 KBG2LS DMY RK 0 07/21f08 2 5802 5799 0 KBG2LS DMY INT 0 07/21f08 3 6991 6986 4 KBG2LS DMY INT 0 03f06f99 4 7820 7614 3 KBG2LS DMY INT 0 05/31f99 STD -j 9335' 7" LNR-TIEBACK, 29#, 13CR-80, .0371 bpf, ID = 6.184" ~--_~9380'- DATE REV BY COMMENTS DATE REV BY COMMENTS 1979 ORIGINAL COMPLETION 08/05ffl8 MSSIPJC GLV CIO {7f21108) 03!03199 LAST WORKOVER 09101f08 GJFIPJC GLV CIO {08!04f08) 01/02f02 RNTTP CORRECTIONS 02f19f07 JMC(PAG SCAB LNR CORRECTION 2 06f17f07 JLJIPJC GLV C(O 08f18107 KSBlPJC GLV C/O 7573' ~ 9-5f8" X 7" ZXP TIEBK PKR, ID = 6.056" 7651' 7" X 4-112" BKR S-3 PKR, ID = 3.875" 7702' 1 4-1f2" UNK2UIEOVERSHOT $316° -~4-1/2" PKR SWN NIP. ID = 3.813" 83$6' - 7'° X 4-1f2" TNV HBBP PKR 8410' 4-1f2°' OTIS X NIP, iD = 3.813°' $4,3Q' 4-1f2" PKR SWN NIP, ID = 3.725" $ 3' 4-1/2" WLEG, ID = 3.958 $427° ELMD TT LOGGED 02f09192 MILLOUT WINDOW 7901' - 7930' 9044' EST TOP OF CEMENT 9330° FISH -GRAPPLE LOST IN STA #5 - 09f16f94 9330' 1{3) 1/2" X 1l2" X 1/8" PIECES OF GRAPPLE PRUDHOE BAY UNIT WELL: 14-05A PERMfC No: 1920010 API No: 50-029-20327-01 SEC 9, T10N, R14E, 1473.6' FEL & 1003.62' FNL BP Expioratlon {Alaska) OPERABLE: 14-OSA (PTD #1920010) Tubing integrity restored Page 1 of 2 • • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ l ~~ t3(c~~, Sent: Wednesday, July 30, 2008 9:22 AM C To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Roschinger, Torin T.; Bommarito, Olivia O; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 14-05A (PTD #1920010) Tubing integrity restored Follow Up Flag: Follow up Flag Status: Blue Hi all, Well 14-05A (PTD #1920010) passed a~MIT-IA on 07(29108 after dummying aff the gas lift valves proving integrity has been restored. The well has been reclassified as Operable and may be br~oug afon line when canvenient for operations. Please be prepared for the lA pressure to increase due to thermal expansion as the IA is liquid ,~ packed. From: NSU, ADW Well Integrity Engineer Sent: Sunday, July 13, 2008 12:12 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GCl/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Winslow, Jack L.; NSU, ADW Well Integrity Engineer; Bommarito, Olivia O Subject: UNDER EVALUATION: 14-05A (PTD #1920010) for Sustained casing pressure due to TxIA Comm Hi all, ,/ Well 14-05A (PTD #1920010) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/iA/OA equal to SSV/2420/400 psi on 07/11/08 The well originally passed a TIFL on 06/30/08 but due to repressu_ rization after the initial TIFL, the artificial lift line was isolated and a second TIFL was conducted. On 07/11/08, a TIFL failed on overnight build up rate confirming TxIA communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. Operations may allow the IA pressure to continue to increase or may return the well to production once the facility is online while classified as Under Evaluation. The plan forward for the well is as follows: 1. DHD: TIFL -FAILED 2. Slickline: Dummy off gas lift valves 3. DHD: Re-TIFL post dummy gas lift valves 10/13/2008 OPERABLE: 14-05A (PTD #1920010) Tubing integrity restored Page 2 of 2 • ~ • A TIO plot and wellbore schematic have been included for reference. Please call with any questions. Thank you, Anna ~u6e, ~P. E. Well Integrity Coordinator GPB Wells Group Phone: {907} 659-5102 Pager: (907) 659-5100 x1154 10/13/2008 N M r ~ i 0 O N U ~ ''~ ~yL T ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ • ^ ° ° a o o v ~ cYr © O 0 f 0 Q e 0 a r~ co 0 0 N CL~ O a 00 0 0 0 c a a ~~ cv TREE = GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV.- 7~.. BF. ELEV = ~~-~~~~~~ KOP = 8106' Max Angle = ~ 30 @ 882T ~~ Datum MD = 8959' - Datum T'v D = 8800' SS ~ 1 13-318" CSG, 72#, L-80, ID = 12.347" ~--~ 2736' t" 9-5/8" X 7" ZXP PKR w (HMC HGR , ID = 8.056" 3747 7" SCAB LNR, 26#, L-8d IBT, .0383 bpf, ID = 6.276" k-~ 7584' 4-1/2" TBG, 12.6#, 13CR-NSC, .0152 bpf, ID = 3.958" 7709 Mrlnimum !®- 3.725°' @ 8430° 4-~12`~ PARKER swrv (VIPPLE '14-1i2°' TBG, 12.8#, 13CR-80, .0152 bpf ID = 3.958" ~ $443' ~, 9-5i8" CSG, 47#, L-80, 1D = 8.681" 8632 PERFORATION SUMMARY REF LOG: BRCS ON 01131(92 ANGLE AT TOP RERF: 29' @ 8773' Note: Refer to Production DB for historicak perf data SIZE SPF INTERVAL OpnlSgz DATE 3-3!8" 4 8773 - 8787 S 44/27195 3-3/8" 4 8793 - 8807 S 44/27195 2-7l8"' 4 8878 - 8894 O 09104(03 2-718" 4 8894 - 8902 O 09I04i03 2-718" 4 $908 - 8918 O 09;04103 3-3(8" 4 8921 - 8932 S 12/01/93 3-3J8" 6 8923 - 8933 O 04/18/99 3-318" 4 8937 - 8947 S 02/20!93 3-318" 8 8938 - 8940 O 04116/99 3-318" 4 $947 - 8964 S 42110/92 3-318" 4 8972 - 8982 S 42/10/92 3-3?8" 4 8988 - 8994 S 02!10/92 PBTD 7" LNR-TIEBACK, 29#, 13CR-$0, .0371 bpf, ID = 6.184" 7573' ~ 9-518" X 7" ZXP TIEBK PKR, ID = 6.0,56" 76508 ~ 7" X 4-1l2" BKR S-3 PKR 77(}2' 4-1(2" UNIOUIEOVERSHOT (3) 112" X 112" X 118" PIECES OF GRAPPLE I DATE REV BY COMMENTS 1979 ORIG9NAL COMPLETION t73J4S199 LAST WORKOV ER ~~~--~--~- 01102(02 RN/TP CORRECTIONS 09104103 BJMIKK ADPERFS 05f3i106 DTM WELLHEAD CORRECTION O8r25i06 KSB(PAG GLV CIO DATE REV BY COMMENTS 02;18;07 JDNUPAG _ SCAB LNR CORRECTION 02;19!07 JMCIPAG SCAB LNR CORRECTION 2 OBf17/07 JLJIPJC GLV C10 OB/18.x0? KSBIPJC GLV CIO PRUDHOE BAY UNIT WELL: 14-05A PERMIT No: 19'2001 d API No: 50-029-20327-01 SEC 9; T10N; R14E, 1473.6' FEL & 1003.62' FNL BP Exploration {Alaska) 2213 (-'I4-112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3701 3700 1 KBG2LS DOME RK 16 08/18107 2 5802 5799 5 KBG2LS SO INT 20 08(18107 3 6991 8988 4 KBG2LS DMY INT 0 03/06/99 4 7620 7814 3 KBG2LS DMY INT 0 05/31J99 10/23/07 Schlumbepger NO. 4459 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SGt~NED OCT 312007 Company: State of Alaska Alaska Oil & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Aurora, Milne Pt.,LisburnE J b# L D Well 0 og escriptlon Date BL Color CD F-48 11846815 USIT 1'1/-- 01 ¡~ 10/12/07 1 G-19A 11890315 US IT ;'-1'1- to' 1 09/30/07 1 NGI-13 11890313 USIT I )-r.f' I~ -rAt 09/30/07 1 MPE-30A 11855817 USIT .Q-OI - 0 t! 10/01/07 1 - F-11 B 11649954 MCNL ;:) cf-I - I C>¡ t.. ('# 15 S-::t3 03/22/07 1 1 W-12A 11418301 MCNL l'ì1!'-I'2fg "/~"-:¡l..J 09/10/06 1 1 11-27 11637127 RST i~lb - 14"1f tl ) ç..ç-"'":}(., 06/05/07 1 1 02-22A 11216214 MCNL :Jtn - h ~O¡ -ä I"'~ .J- -..;- 10/02/06 1 1 01-16 11630486 RST r l'ir-dO'X ""'/.c;;-.-;-1-:;j' 06/28/07 1 1 01-14 11801086 RST I" ~~_ f'-I":/.-? tt I ~-~ -1-'-1 07/07/07 1 1 L5-05 11767129 MCNL 'A ;..- -:::} -~)<nc. f :: ,~dO 06/17/07 1 1 D-21 11626119 RST I 'ïr;:) - 1")5,;:) ... ~x , 09/12/07 1 1 14-15 11221550 RST 17/ - Ó'71'-1 .,. I~.'" "X;-I 03107/06 1 1 D-18A 11695074 RST ;:)b/-1Ò'?J -- l~:--' 75 08/28/07 1 1 14-05A 11813055 RST ,-D¡:.1 - hO I ·1~.g r.-, 06/11/07 1 1-2310-15 11846802 RST Ù1.{\_ lq'-I'-/::V;r 'It ,< :-'5155 08111/07 1 S-03 11223120 RST I '7r 1 - I c>,. 1"1 'É t "" ~~'-I 06/13/06 1 1-09A1L-21 11849930 RST IC\~ -Ö;;JG 'it- I~S-+~ 08/04/07 1 1 P2-19A 11649963 MCNL _'1/'i'+- (')1.;) · 15"5?d 04/22/07 1 1 OWDW-NW 11211370 RST lJ "U' ,.-, -VI" $'I. I'SS9-1 02/28/06 1 1 K-01 11695073 RST I~~- :::J/ ...- /601-ò 08/27/07 1 1 11-32 11630498 RST D,Lj- I~I #> /~SL.,cq 09/03/07 1 1 3-25B/L-27 11630490 RST .Qö~ - ()~ I .... ~<:7_~ 07/26/07 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~~:"::;"AK ""~"iL Received by: G d Date Delivered: . . 14-05A (PTD #1920010) UNDER .DATION for sustained casing press.- TxIA communication Regg, James B (DOA) ¡¿eft ~1111V7 Page 1 of 1 NSU, ADWWelllntegrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Wednesday, August 15, 2007 1: 15 PM Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC) Subject: 14-05A (PTD #1920010) UNDER EVALUATION for sustained casing pressure - TxlA communication Attachments: 14-05A.pdf From: Sent: To: All, Well 14-05A (PTD #1920010) has been found to have sustained casing pressure on the IA. The TIO pressures were 2400/2250/400 psi on 08/14/07 at which time the well failed a TIFL. The well has been classified as Under Evaluation and placed under a 28-day clock. Due to a high shut-in tubing pressure, the well can be placed back on-line to restrict the lAP to flowing tubing pressure. The plan forward for this well is as follows: 1. D: TIFL - FAILED 2. S: C/O GL Vs 3. D: Re-TIFL A well bore schematic has been included for reference. «14-05A. pdf» Please call with any questions or concerns. SCl~fiNfJJ AUG 2 3 2007 Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 8/17/2007 TREE = GRAY GEN 2 WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = 19-5/8" X 7" ZXP PKR w I HMC HGR , 10 = 6.056" I T' SCAB LNR, 26#, L-80 IBT, .0383 bpf, 10 = 6.276" I 4-1/2" TBG, 12.6#, 13CR-NSC, .0152 bpf, 10 = 3.958" -f 7709' Minimum ID = 3.725" @ 8430' 4-1/2" PARKER SWN NIPPLE 14-1/2" TBG, 12.6#, 13CR·80, .0152 bpf 10 = 3.958" 19-5/8" CSG, 47#, L-80, 10 = 8.681" I 8632' 8443' ÆRFORA TION SUMMARY REF LOG: BHCS ON 01/31/92 ANGLE AT TOP ÆRF: 29' @ 8773' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 8773 - 8787 S 04/27/95 3-3/8" 4 8793 - 8807 S 04/27/95 2-7/8" 4 8878 - 8890 0 09/04/03 2-7/8" 4 8894 - 8902 0 09/04/03 2-7/8" 4 8908 - 8918 0 09/04/03 3-3/8" 4 8921 - 8932 S 12/01/93 3-3/8" 6 8923 - 8933 0 04/16/99 3-3/8" 4 8937 - 8947 S 02/20/93 3-3/8" 6 8938 - 8940 0 04/16/99 3-3/8" 4 8947 - 8964 S 02/10/92 3-3/8" 4 8972 - 8982 S 02/10/92 3-3/8" 4 8988 - 8994 S 02/10/92 14-05A SAFETY OTES: FHLITIW HBBP PKRS HAVE REDUCED TEST PRESS. IN SOM E CASES. CONTACT WIE x51 02 PRIOR TO PRESSURE TESTING. CHROM E TBG. 2213' 1-14-1/2" HESXNIP,ID=3.813" I ST MD TVD 1 3701 3700 2 5802 5799 3 6991 6986 4 7620 7614 GAS LIFT MANDRELS DEV TYÆ VLV LATCH 1 KBG2LS DOME RK 5 KBG2LS SO INT 4 KBG2LS DMY INT 3 KBG2LS DMY INT PORT DA TE 16 06117/07 20 06/17/07 o 03/06/99 o 05/31/99 -19-518" X 7" ZXP TJEBK PKR, !D = 6.056" -17" X 4-1/2" BKR S-3 PKR I 7702' -14-1/2" UNIQUIEOVERSHOT I -14-1/2" PKR SWN NIP, 10 = 3.813" IT' X 4-1/2" TIW HBBP PKR I 8430' -14-1/2" PKR SWN NIP. 10 = 3.725" 8443' 8427' -14-1/2" WLEG, 10 = 3.958"1 H ELrVID TT LOGGED 02/09/92 MILLOUT WINDOW 7901'·7930' -1 EST TOP OF CEMENT I FISH - GRAPPLE LOST IN STA #5 - 09/16/94 (3) 1/2" X 1/2" X 1/8" PIECES OF GRAPPLE 06/08194 17" LNR-TIEBACK, 29#, 13CR-80, .0371 bpf, 10 - 6.184" DATE 1979 03/03/99 01/02/02 09104/03 05/31106 08125106 REV BY COMMENTS ORIGINAL COM PLEfION LAST WORKOVER RNlTP CORRECTIONS BJl'vllKK ADÆRFS DTM WELLHEAD CORRECTION KSB/PAG GLV ClO DATE 02/18/07 02/19/07 06117/07 REV BY COMMENTS JDMlPAG SCAB LNR CORRECTION JMClPAG SCAB LNR CORRECTION 2 JLJ/PJC GLV (')0 PRUDHOE BAY UNrr WELL: 14-0SA ÆRMrr No: "1920010 API No: 50-029-20327-01 SEC 9, T10N, R14E, 1473.6' FEL & 1003.62' FNL BP Exploration (Alaska) ~_..."", ~..,..,....,......,. ,.,·w';·" ......... Schlumberger cn JUN ~ '1 ¿{}t)1 st;ANN~ NO. 4306 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1'19-00 I Field: Prudhoe Bay \I D We Job# Loø Description .Date BL Color C L3-12 11695062 PRODUCTION PROFILE 06/06/07 1 GNI-03 11637128 PRESS/TEMP SURVEY 06/06/07 1 Y-11C 11661151 MEMORY INJECTION PROFILE 06/01/07 1 C-31B 11745223 MEMORY PROD PROFILE 05/31/07 1 05-30 11801067 LDL 06/01/07 1 13-29L1 11686753 LDL OS/28/07 1 Y -05A 11628778 MEMORY INJECTION PROFILE OS/28/07 1 L5-23 11661153 MEMORY PROD PROFILE 06/05/07 1 H-37A 11594506 PPROFIIPROF 06/05/07 1 Y-35A 11661152 MEMORY PROD PROFILE 06/03/07 1 N-15 11637129 PRODUCTION PROFILE 06/13/07 1 01-07A 11626098 PRODUCTION PROFILE OS/28/07 1 13-29L 1 11686753 LDL OS/28/07 1 04-24 11773112 PRODUCTION LOG 05/19/07 1 12-19 11637343 LDL 06/13/07 1 G-23A 11638639 LDL 06/03/07 1 14-05A 11813055 PPROF W/RST BORAX 06/11/07 1 K-12A 11745224 MEMORY PROD PROFILE 06/02/07 1 P2-19A 11661154 MEMORY PROD PROFILE 06/06/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 3-41/K-39 11813054 INJECTION PROFILE 06/08/07 1 3-4l1K-39 11813054 INJECTION PROFILE 06/09/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 Z-13A 11649962 MEMORY PROD PROFILE 04/21/07 1 W-17A 40012333 OH EDIT MWD/LWD 09/19/05 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: " n H\! ? ,11 ZOO] Received by: gtf 06/18/07 . . ~ ~ (STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 SuspendD Operation ShutdownD Perforate ŒJ WaiverD OtherD Alter CasingD Repair WellD Plug PerforationsD Stimulate D Time ExtensionO Change Approved ProgramD Pull TubingD Perforate New PoolD Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 192-0010 Development Œ) Exploratory D 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD ServiceD 50-029-20327-01-00 7. KB Elevation (ft): 9. Well Name and Number: 73.00 14-05A 8. Property Designation: 10. Field/Pool(s): ADL-028312 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 9380 feet true vertical 9237.5 feet Plugs (measured) None Effective Depth measured 9044 feet Junk (measured) None true vertical 8946.5 feet Casing Length Size MD TVD Burst Collapse Conductor 84 20" 94# H-40 30 - 114 30.0 - 114.0 1530 520 Liner 1796 7" 29# 13CR80 7584 - 9380 7577.9 - 9237.5 8160 7020 Production 7873 9-5/8" 47# L-80 28 - 7901 28.0 - 7894.7 6870 4760 Surface 2707 13-3/8" 72# L-80 29 - 2736 29.0 - 2736.0 4930 2670 Perforation depth: Measured depth: 8878 - 8890,8894 - 8902,8908 - 8918,8923 - 8932,8932 - 8933,8938 - 8940 True vertical depth: 8802.81 - 8813.19,8816.66 - 8823.58,8828.77 - 8837.43,8841.76 - 8849.55,8849.55 - 8850.41,8854.74 - 8856.47 Tubing ( size, grade, and measured depth): 5-1/2" 17# L-80 @ 23 - 31 4-1/2" 12.6# 13Cr80 @ 31 - 7709 r::. \' 'E. 0 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 7651 C E.. C t:.. \ V 4-1/2" TIW HBBP-R Packer @ 8380 f"' "\)~ 7" Baker H-Isolation Liner Packer @ 7592 \) T.u 12. Stimulation or cement squeeze summary: co\1\f\\\!.S\ Intervals treated (measured): Q\\ &. GaS \,o"s. Treatment descriptions including volumes used and final pressure: ~\as'l..a ~"t"ota\\e 13 Reoresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casino Pressure Tubing Pressure Prior to well operation: 126 2.5 2867 1200 509 Subsequent to operation: 274 7.7 4550 1100 591 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ] ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D OilŒ) GasD WAG D GINJD WINJD WDSPLD Daily Report of Well Operations. X Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Garry Catron NI A Printed Name Garry Catron Title Production Technical Assistant Signature 13 ~ C Phone 564-4657 bate 1/19/04 :'jt;Ai\!~E[) JìU! 2 1 2004 0 R \ G IÇ»?j.i.'J~~. (°.::,.;: Jlfr~f.#I ~ \1" ~@~ Form 10-404 Revised 12/2003 ' r'\~' 'lJ~ ~ Ab..],) .. r . . . ,( ( 14-05A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/23/03 DfT w/dmy gun, tel sb to 9027 09/04/03 Add Perfs: 88781-8890' 4 SPF, 8894'-8902' 4 SPF,8908'-89181 4 SPF. FLUIDS PUMPED I BBLS : No Fluids Pumped I 0 TOTAL Page 1 . ( ( 1REE = GRA Y GEN 2 WELLHEAD = WCBlOY 14 0 SA SAFETY NOTES: FHUTIW!-SSP PKRSHAVEREDUCED ACTUA. TOR = AXELSON - TEST PRESS. IN SOME CASES. CONTACT WlE x51 02 KB. a.EV = 71' PRIOR TO PRESSURE TESTING. CHROMETOO. BF. a.EV = KOP = 81 06' rvtlx Angle = 30 @ 8827' 4-1/2" HES X NIP D = 3813" D:ltum MD = 8959' ' . D:ltum TVD = 8800' SS Gt\S LIFT MA.Nœa.S 13-318" CSG 72# L-80 ID = 12.347" MD TVD DEV TYPE VL V LATCH FORT DATE , , , 3700 3700 1 MMG ~ 5801 5799 5 KBG2LS INT Minimum ID = 3.725" @ 8430' 6991 6986 4 KBG2LS INT 4-112" PARKER SWN NIPPLE 7620 7614 3 KBG2LS INT TOPOF7" LNR-TEBACK 7650' 7" X4-1/2" BAKERS-3 PKR 4-1/2" Q-IROMEOVERSHOT 4-112" TBG,12.6#,13-CR-NSC, 0.0152 bpf,lD = 3.958" TOPOF 4-1/2" TBG H 4-1/2" PARKER SWN NP, ID= 3.813" -I 7" X 4-1/2" TIW HBBPP¡<R I 4-1/2" OTIS X NIP, 10 = 3.813" -i 4-1/2" PARKERSWN NIP, ID = 3.725" I 4-112" TBG, 12.6#, 13-CR-80, 0.0152 bpf ID = 3.958" 9-5/8" CSG, 47#, L-80, 10 = 8.681" 8632' MILLOUT WINDOW 7901' - 7930' ÆRFORA TION SUMMARY RB= LOG: BI-CS ON 01/31/92 ANGLE AT TOP PERF: 30 @ 8773' Note: Refer to Produetion DB for historical perf data SIZE SFF INTERVAL Opn/Sqz DA 1E 3-3/8" 4 8773 - 8787 S 04127/95 3-3/8" 4 8793 - 8807 S 04127/95 2-7/8" 4 8878 - 8890 0 09/04/03 2-7/8" 4 8894 - 8902 0 09/04103 2-718" 4 8908 - 8918 0 09/04103 3-3/8" 4 8921-8932 S 12/01/93 (3)1/2"X1/2"X1/8" 3-3/8" 6 8923 - 8933 0 04116/99 PIS:::ES OF GRAFPLE 3-3/8" 4 8937 - 8947 S 02/20/93 06/08194 3-3/8" 6 8938 - 8940 0 04116/99 3-3/8" 4 8947 - 8964 S 02/10/92 3-3/8" 4 8972 - 8982 S 02/10/92 3-3/8" 4 8988 - 8994 S 02/10/92 7" LNR-TlffiACK, 29#, 13-CR-80, 0.0371 bpf, ID = 6.184" DATE REV BY COMMENTS DA 1E RBI BY COMMI3'JTS FRUDHOE BA Y UNIT 1979 "2.{7..¥7Q ORIGINAL COMPLETION Wa.L: 14-0SA 03/03/99 LAST WORKOVER PERMIT No: 1920010 01/02/02 RN'TP CORRECTIONS API No: 50-029-20327-01 09/04/03 BJM'KK ADÆRFS SEC 9, T1 ON, R14E, 1473.6' ÆL & 1003.62' FN... BP Exploration (Alaska) "~' STATE O FALASKA "~' ALAS'K~ OIL AND GAS CONSERVATION CC~,v,MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonE~ SuspendF1 Operation Shutdown[--1 Perforate[] Variance[]] Annuar DisposalF'l After Casincl[~] Repair Well[~] Plu.Q Perforations~--I Stimulater~ Time Extension[-1 Otherr-~ Change Approved ProgramD Pull Tubing[]] Perforate New Poolr--] Re-enter Suspended Well[~ ADD PERFS 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development [ ExploratoryO 192-001 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic E~ Service ~] 50-029-20327-01-00 7. KB Elevation (ft): 9. Well Name and Number: 73.00 14-05A 8. Property Designation: 10. Field/Pool(s): ADL 028312 Prudhoe Bay Field ! Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 9380 feet true vertical 9238 feet Plugs (measured) Cement Top @ 9044'. Effective Depth measured 9027 feet Junk (measured) true vertical 8932 feet Casing Length Size MD TVD Burst Collapse Conductor 74' 20" 124' 124' 40K 520 Surface 2686' 13-3/8" 2736' 2736' 80K 4760 Intermediate 7851' 9-5/8" 7901' 7895' 80K 6280 Sidetrack Liner 1796' 7" 7584'-9380' 7578'-9238' 80K 7020 Scab Liner 3837' 7" 3747'-7584' 3747'-7578' 80K 7020 Perforation depth: Measured depth: Open Perfs 8878'-8890', 8894'-8902', 8908'-8918', 8923'-8933', 8938'-8940' Sqzd Perfs 8773'-8778', .8940'-8964', 8972'-8982', 8988'-8994'. True vertical depth: Open Perfs 8803'-8813', 8817'-8824', 8829'-8837', 8842'-8850', 8855'-8856'. Sqzd Perfs 8712'-8716', 8856'-8877', 8884'-8893', 8898'-8903'. Tubing: ( size, grade, and measured depth) 4-1/2" 12.6# 13-CR-80 TBG @ 8443'. Packers & SSSV (type & measured depth) 9-5/8" x 7" Baker S-3 PKR @ 7650'. 7" x 4-1/2" TIW HBBP PKR @ 8380'. 4-1/2" HES X Nipple @ 2213'. 12. Stimulation or cement squeeze summary: ...... Intervals treated (measured): Treatment descriptions including volumes used and final pressure: , 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 126 2550 2927 500 Subsequent to operation: 408 11669 6171 458 14. Attachments: 15. Well Class after proposed work: ExploratoryE]] Development~ Service[]] Copies of Logs and Surveys run _ 16. Well Status after proposed work: Oil[] Gas[~ WAG[-'l GINJE] WlNJ[--] WDSPL[~ Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr Printed Name DeWavne R. Schnorr ~ Title Techical Assistant Signature ~~'~~~~~ Phone 907/564-5174 Date Sept25,2003 Form 10-404 Revised 2/2003 14-05A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08~23/2003 PERFORATING: DRIFT/TAG 09~04~2003 PERFORATING: PERFORATING 09/21/2003 TESTEVENT --- BOPD: 313, BWPD: 5,416, MCFPD: 9,429, AL RATE: 0 EVENT SUMMARY O8/23/O3 ***FOUND WELL FLOWING ON ARRIVAL***(PERFORATING). DRIFT W/2 7/8" DUMMY GUN, TEL, SAMPLE BAILER (EMPTY). LOC TT @ 8412' SLM + 15' CORR - 8427' ELMD. TAG TD @ 9027' CORR ELMD (TARGET DEPTH IS 8914'). 09/04/03 ADD PERFS: 8878'-8890', 8894'-8902', and 8908'-8918'MD. (TIE-IN LOG CNL- 2/9/92). GUN: 2 7/8" HSD 2906 POWERJET, 15 GR HMX, 180 DEG PHASE, 4 SPF. 09/21/03 TESTEVENT --- BOPD: 313, BWPD: 5,416, MCFPD: 9,429, AL RATE: 0 FLUIDS PUMPED BBLS 2 DIESEL FOR P/T OF SURFACE EQUIPMENT 2 TOTAL ADD PERFS O9/O4/2OO3 THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2-7/8" PJ2906 POWERJET GUN, LOADED @ 4 SPF, 180 DEGREE PHASING, RANDOM ORIENTATION. 8878'-8890' 8894'-8902' 8908'-8918' Page I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Pedorate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1613' FNL, 1152' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 1241' FNL, 1387' FEL, Sec. 09, T10N, R14E, UM At effective depth At total depth 1004' FNL, 1474' FEL, Sec. 9, T10N, R14E, UM 5. Type of Well: Development__X Explorato~__ Stratigraphic__ Service__ 6. Datum elevation (DF or KB feet) RKB 73 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-05A 9. Permit number / approval number 92-01 10. APl number 50-029-20327-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured true vertical 9380 feet Plugs (measured) 9238 feet Tagged PBTD @ 9033' MD (8/19/1999) Effective depth: measured true vertical Casing Length Conductor 124' Surface 2664.8' Production 8560.8' Liner 1796' Scab Liner 3837' 9033 feet Junk (measured) 8937 feet Size Cemented Measured Depth True vertical Depth 20" 300 sx As 124' 124' 13-3/8" 4234 Sx PF 2736' 2736' 9-5/8" lOOO Sx G 8632' 8588' 7" 425 Sx C~ass G 7584' - 9380' 7578' - 9238' 7" 546 Sx Class G 3747' - 7584' 3747' - 7578' Perforation depth: Tubing (size, grade, and measured depth) measured 8922' - 8932'; 8937' - 89410'. true vertical 8841' - 8850'; 8854' - 8857'. 4-1/2", 12.6~, 13OR-NSC Tbg ~ 7709' MD; 4-1/2", 12.6~, 13CR-80 Tbg Packers & SSSV (type & measured depth) 7' x 9-5/8' zxP PACKER @ 3747' MD; 7"JMZXP tieback PACKER @ 7573' MD; 7' TIW HBBP PACKER @ 8381' MD. 4-1/2" HES X NIP @ 2214' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 154 Representative Daily Average Production or Injection Data Gas-Mci Water-Bbl 385 260 783 5099 Casing Pressure Tubing Pressure 261 287 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~.,~_~ ~, ~ Title Arco Engineering Supervisor Erin Oba Date Prepared by Paul Rauf 265-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE /~(~_., 14-05A DESCRIPTION OF WORK COMPLETED FB MUD ACID STIMULATION Date Event Summary 8/19/1999: 8/24/1999: RIH & tagged PBTD @ 9033' MD. Performed a Fullbore Mud Acid Stimulation Treatment as follows: MIRU & PT'd equip. Pumped stimulation fluid sequence FB to treat the open perforation intervals located @: 8922' - 8932" MD (Zone 4) Ref Log: BHCS 1/31/1992, 8937' - 8941" MD (Zone 41 Pumped: (a) 150 bbls of 2% NH4CL w/50 lbs / Mgal Citric Acid @ 1-5 bpm, followed by (b) 50 bbls of 50% Diesel, 50% Xylene @ 5 bpm, followed by (c) 100 bbls of 12% HCL - 10% Xylene - 3% Acetic Acid @ 5 bpm, followed by (d) 50 bbls 9% HCL- 1% HF - 3% Acetic Acid @ 4 bpm, followed by (e) 49 bbls of 12% HCL - 10% Xylene - 3% Acetic Acid @ 4 bpm, followed by (f) 196 bbls of 2% NH4CL w/50 lbs / Mgal Citric Acid @ 4 bpm, followed by (g) 140 bbls of Crude @ 4 bpm, followed by (h) 10 bbls Diesel, followed by (i) shutdown RD. Returned well to production & obtained a valid well test. STATE OF ALASKA ALASKA UlL AND GAS CONSERVATION COiVlMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Pull Tubing 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1614' SNL, 1154' WEL, SEC. 09, T10N, R14E, UM At top of productive interval 1241' SNL, 1387' WEL, SEC. 09, T10N, R14E, UM At effective depth At total depth 1002' SNL, 1471' WEL, SEC. 09, T10N, R14E, UM [] Stimulate [] Plugging [] Perforate [-qAIter Casing []Repair Well []Other 5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) 73' RKB 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 14-05A 9. Permit Number / Approval No. 92-01 10. APl Number 50-029-20327-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9380 feet true vertical 9238 feet Effective depth: measured 9335 feet true vertical 9199 feet Casing Length Size Structural Conductor 124' 20" Surface 2663' 13-3/8" Intermediate Production 8559' 9-5/8" Liner 1796' 7" Scab Liner 7" Plugs (measured) Junk (measured) 9044' Cement Retainer and Cement Plug 9370' Grapple dropped in hole (02/92) Cemented M D TVD 300 sx Arcticset 124' 124' 4234 sx Permafrost 2736' 2736' 1000 sx Class 'G' 8632' 8588' 425 sx Class 'G' 7584' - 9380' 7578' - 9238' 546 sx Class 'G' 3747' - 7584' 3747' - 7578' Perforation depth: measured true vertical 8773'-8787', 8793'-8807', 8921'-8932', 8937'-8947' 8712'-8724', 8729'-8742', 8840'-8850', 8854'-8863' ORI61NAL Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13Cr to 7709'; 4-1/2", 12.6#, 13Cr80 tubing 7712' - 8443' Packers and SSSV (type and measured depth) 4-1/2" SSSV Nipple at 2213'; Baker 7" x 9-5/8" ZXP packer at 3747'; 7" JMZXP tieback packer at 7573'; 7" TIW HBBP packer at 8380' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data RECL iV'ED APR '] 4 1999 Prior to well operation: Subsequent to operation: 5. Attachments I-q Copies of Logs and Surveys run [] Daily Report of Well Operations Oil-Bbl Gas-Mcf Water-Bbl j16. []Oil Status of well classifications as: I--I Gas I~ Suspended Service 7. I hereby certify that the f~regoing is true and correct to the best of my knowledge s, n d Terrie Hubble .... . -- _ Title Technical Assistant III Prepared By Name/Number: Casing Pressure Tubing Pressure Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Facility PB DS 14 Progress Report Well 14-05A Page 1 Rig Nabors 9ES Date 08 March 99 Date/Time 06 Feb 99 19:00-03:00 07 Feb 99 03:00-06:00 06:00-06:00 08 Feb 99 06:00-15:00 15:00-06:00 09 Feb 99 06:00-06:00 10 Feb 99 06:00-23:00 23:00-23:45 23:45-06:00 11 Feb 99 06:00-15:00 15:00-15:30 15:30-16:30 16:30-19:30 19:30-21:00 21:00-02:00 12 Feb 99 02:00-03:00 03:00-06:00 06:00-12:00 12:00-21:00 21:00-01:00 13 Feb 99 01:00-04:30 04:30-06:00 06:00-07:00 07:00-09:30 09:30-10:00 10:00-12:00 12:00-22:30 22:30-23:30 23:30-00:30 14 Feb 99 00:30-01:00 01:00-06:00 06:00-11:30 11:30-12:45 12:45-13:30 13:30-16:00 16:00-17:00 17:00-20:30 20:30-21:30 21:30-02:30 15 Feb 99 02:30-04:00 04:00-06:00 06:00-07:00 07:00-12:30 12:30-13:30 13:30-14:30 14:30-18:30 18:30-19:30 19:30-21:30 21:30-22:00 22:00-00:00 16 Feb 99 00:00-02:00 02:00-03:00 03:00-04:00 04:00-06:00 Duration 8hr 3 hr 24 hr 9hr 15hr 24 hr 17hr 3/4 hr 6-1/4 hr 9 hr 1/2 hr 1 hr 3 hr 1-1/2 hr 5hr 1 hr 3hr 6hr 9hr 4 hr 3-1/2 hr 1-1/2 hr 1 hr 2-1/2 hr 1/2 hr 2 hr 10-1/2 hr 1 hr lhr 1/2 hr 5hr 5-1/2 hr 1-1/4 hr 3/4 hr 2-1/2 hr lhr 3-1/2 hr lhr 5 hr 1-1/2 hr 2hr lhr 5-1/2 hr 1 hr lhr 4hr 1 hr 2hr 1/2 hr 2 hr 2 hr lhr 1 hr 2 hr Activity Rig moved 20.00 % Rig waited · Assessed situation Rig moved 90.00 % Rig moved 95.00 % Rig waited · Unable to work derrick Rig waited · Weather Rig waited · Weather Held safety meeting Installed Drillfloor / Derrick Rigged up Drillfloor / Derrick Held safety meeting Circulated at 0.0 ft Serviced Top drive Retrieved Hanger plug Circulated at 4200.0 ft Installed Hanger plug Rigged down Xmas tree Rigged up BOP stack Tested BOP stack Repaired Kelly cocks Retrieved Hanger plug Made up BHA no. 1 Fished at 40.0 ft Circulated at 4200.0 ft Pulled BHA Rigged up Completion string handling equipment Laid down 4186.0 ft of Tubing Installed Wellhead connector Made up BHA no. 2 Serviced Top drive R.I.H. to 2000.0 ft Singled in drill pipe to 4150.0 ft Washed over string at 4395.0 ft Circulated at 4180.0 ft Pulled out of hole to 200.0 ft Pulled BHA Made up BHA no. 3 Serviced Top drive R.I.H. to 4200.0 ft Fished at 4369.0 ft Pulled out of hole to 3000.0 ft Pulled out of hole to 445.9 ft Laid down fish Serviced Top drive Made up BHA no. 4 R.I.H. to 4035.0 ft Installed Tubing handling equipment R.I.H. to 4364.0 ft Fished at 4371.0 ft Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Progress Report Facility PB DS 14 Well 14-05A Page 2 Rig Nabors 9ES Date 08 March 99 Date/Time 06:00-16:00 16:00-06:00 17 Feb 99 06:00-16:30 16:30-17:15 17:15-06:00 18 Feb 99 06:00-07:00 07:00-08:15 08:15-08:45 08:45-11:30 11:30-12:30 12:30-16:00 16:00-18:00 18:00-20:00 20:00-20:30 20:30-23:00 23:00-01:00 19 Feb 99 01:00-05:00 05:00-06:00 06:00-09:00 09:00-10:30 10:30-12:00 12:00-15:00 15:00-16:30 16:30-21:30 21:30-03:00 20 Feb 99 03:00-05:00 05:00-05:30 05:30-06:00 06:00-14:30 14:30-15:30 15:30-19:00 19:00-20:00 20:00-21:00 21:00-01:30 21 Feb 99 01:30-02:00 02:00-03:00 03:00-04:30 04:30-05:00 05:00-06:00 06:00-09:00 09:00-10:00 10:00-13:00 13:00-14:00 14:00-15:00 15:00-16:00 16:00-16:30 16:30-17:00 17:00-17:30 17:30-18:00 18:00-05:00 22 Feb 99 05:00-05:30 05:30-06:00 06:00-07:30 07:30-18:30 Duration 10 hr 14 hr 10-1/2 hr 3/4 hr 12-3/4 hr 1 hr 1-1/4 hr 1/2 hr 2-3/4 hr lhr 3-1/2 hr 2hr 2hr 1/2 hr 2-1/2 hr 2 hr 4 hr 1 hr 3hr 1-1/2 hr 1-1/2 hr 3 hr 1-1/2 hr 5 hr 5-1/2 hr 2hr 1/2 hr 1/2 hr 8-1/2 hr 1 hr 3-1/2 hr lhr lhr 4-1/2 hr 1/2 hr 1 hr 1-1/2 hr 1/2 hr lhr 3 hr 1 hr 3 hr 1 hr 1 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr llhr 1/2 hr 1/2 hr 1-1/2 hr llhr Activity Conducted slickline operations on Slickline equipment - Tool run (cont.., Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Held safety meeting Rigged down sub-surface equipment - Slickline / braided cable Installed Logging/braided cable equipment Conducted electric cable operations Removed Logging/braided cable equipment Rigged up Drillstring handling equipment Held safety meeting Rigged up Variable ram Rig waited: Equipment Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations (cont...) Rigged down Logging/braided cable equipment Rig waited: Equipment Conducted slickline operations on Slickline equipment - Retrival run Installed Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Circulated at 6720.0 ft Flow check Laid down Tubing of 40.0 ft Laid down 4794.0 ft of Tubing (cont...) Circulated at 1926.0 ft Laid down 1926.0 ft of Tubing Rigged down Tubing handling equipment Retrieved Wear bushing Tested BOP stack Retrieved BOP test plug assembly Made up BHA no. 5 R.I.H. to 2000.0 ft Serviced Block line R.I.H. to 2800.0 ft R.I.H. to 6677.0 ft Repaired Top drive Space out tubulars Ran Tubing on landing string to 6722.0 ft Installed Tubing hanger Removed Tubing handling equipment Tested Internal BOPs Tested Drillfloor / Derrick Rigged up Drillstring handling equipment Made up BHA no. 6 R.I.H. to 6780.0 ft Reverse circulated at 6780.0 ft Circulated at 6780.0 ft Circulated at 6780.0 ft (cont...) Washed to 8250.0 ft Progress Report Facility PB DS 14 Well 14-05A Page 3 Rig Nabors 9ES Date 08 March 99 Date/Time 18:30-21:30 21:30-23:30 23:30-02:00 23 Feb 99 02:00-02:30 02:30-04:30 04:30-05:30 05:30-06:00 06:00-08:00 08:00-08:30 08:30-13:00 13:00-15:30 15:30-16:30 16:30-17:30 17:30-20:00 20:00-00:30 24 Feb 99 00:30-05:00 05:00-06:00 06:00-07:30 07:30-09:30 09:30-11:30 11:30-13:00 13:00-14:00 14:00-18:30 18:30-22:30 22:30-03:00 25 Feb 99 03:00-06:00 06:00-09:00 09:00-12:00 12:00-14:00 14:00-17:00 17:00-18:00 18:00-20:00 20:00-06:00 26 Feb 99 06:00-08:00 08:00-09:30 09:30-13:00 13:00-01:30 27 Feb 99 01:30-03:00 03:00-04:00 04:00-06:00 06:00-09:30 09:30-13:30 13:30-15:00 15:00-17:30 17:30-18:00 18:00-20:00 20:00-21:00 21:00-22:30 22:30-04:30 28 Feb 99 04:30-06:00 06:00-07:00 07:00-09:30 09:30-11:00 11:00-12:30 Duration 3 hr 2 hr 2-1/2 hr 1/2 hr 2 hr lhr 1/2 hr 2 hr 1/2 hr 4-1/2 hr 2-1/2 hr 1 hr lhr 2-1/2 hr 4-1/2 hr 4-1/2 hr 1 hr 1-1/2 hr 2 hr 2hr 1-1/2 hr lhr 4-1/2 hr 4 hr 4-1/2 hr 3 hr 3hr 3hr 2hr 3 hr lhr 2hr 10hr 2hr 1-1/2 hr 3-1/2 hr 12-1/2 hr 1-1/2 hr lhr 2hr 3-1/2 hr 4 hr 1-1/2 hr 2-1/2 hr 1/2 hr 2 hr lhr 1-1/2 hr 6 hr 1-1/2 hr 1 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr Activity Circulated at 8240.0 ft Reverse circulated at 8240.0 ft Pulled out of hole to 6117.0 ft Flow check R.I.H. to 8240.0 ft Circulated at 8240.0 ft Reverse circulated at 8240.0 ft Reverse circulated at 8240.0 ft (cont...) Flow check Pulled out of hole to 0.0 ft Rigged up Lubricator Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run (co~ Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Retrival run Removed Slickline unit Installed Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Worked stuck pipe at 7715.0 ft Worked stuck pipe at 7715.0 ft (cont...) Conducted electric cable operations Worked stuck pipe at 7492.0 ft Circulated at 7389.0 ft Washed to 7487.0 ft Circulated at 7487.0 ft Pulled out of hole to 725.0 ft Laid down fish Rigged down Tubing handling equipment Ran Drillpipe in stands to 7000.0 ft Laid down 7000.0 ft of 2-3/8in OD drill pipe Rigged down Drillstring handling equipment Serviced Top drive Made up BHA no. 6 R.I.H. to 4100.0 ft Singled in drill pipe to 7400.0 ft Circulated at 7400.0 ft Pulled out of hole to 900.0 ft Circulated at 900.0 ft Pulled BHA Installed Wear bushing Made up BHA no. 7 R.I.H. to 7300.0 ft Washed over string at 7574.0 ft Circulated at 7574.0 ft Pulled out of hole to 400.0 ft Pulled BHA Made up BHA no. 8 Progress Report Facility PB DS 14 Well 14-05A Rig Nabors 9ES Page 4 Date 08 March 99 Date/Time 12:30-15:00 15:00-15:30 15:30-19:00 19:00-22:00 22:00-01:00 01 Mar99 01:00-01:30 01:30-04:30 04:30-05:00 05:00-06:00 06:00-08:00 08:00-10:30 10:30-14:00 14:00-15:30 15:30-16:30 16:30-19:00 19:00-19:30 19:30-20:30 20:30-22:30 22:30-23:00 23:00-01:00 02 Mar 99 01:00-05:00 05:00-06:00 06:00-06:30 06:30-10:00 10:00-12:30 12:30-14:00 14:00-14:45 14:45-15:00 15:00-20:30 20:30-23:00 23:00-03:30 03 Mar 99 03:30-04:30 04:30-05:45 05:45-06:00 06:00-06:45 06:45-07:00 07:00-07:45 07:45-08:15 08:15-08:45 08:45-09:30 09:30-11:00 11:00-12:00 12:00-15:30 15:30-17:00 17:00-18:30 18:30-20:30 20:30-21:00 21:00-01:00 04 Mar 99 01:00-02:00 02:00-03:00 03:00-06:00 06:00-06:30 06:30-12:00 12:00-16:00 Duration 2-1/2 hr 1/2 hr 3-1/2 hr 3 hr 3 hr 1/2 hr 3 hr 1/2 hr 1 hr 2hr 2-1/2 hr 3-1/2 hr 1-1/2 hr 1 hr 2-1/2 hr 1/2 hr 1 hr 2 hr 1/2 hr 2hr 4hr lhr 1/2 hr 3-1/2 hr 2-1/2 hr 1-1/2 hr 3/4 hr 1/4 hr 5-1/2 hr 2-1/2 hr 4-1/2 hr 1 hr 1-1/4 hr 1/4 hr 3/4 hr 1/4 hr 3/4 hr 1/2 hr 1/2 hr 3/4 hr 1-1/2 hr 1 hr 3-1/2 hr 1-1/2 hr 1-1/2 hr 2hr 1/2 hr 4hr lhr lhr 3 hr 1/2 hr 5-1/2 hr 4 hr Activity R.I.H. to 7400.0 ft Fished at 7500.0 ft Circulated at 7712.0 ft Pulled out of hole to 400.0 ft Laid down fish Retrieved Wear bushing Tested BOP stack Installed Wear bushing Held safety meeting Conducted electric cable operations Conducted electric cable operations Set downhole equipment (wireline) Soak Serviced Top drive Ran Drillpipe in stands to 3809.0 ft Set packer at 3809.0 ft with 0.0 psi Tested Casing Pulled out of hole to 0.0 ft Made up BHA no. 9 Serviced Block line R.I.H. to 7584.0 ft Washed to 7584.0 ft Circulated at 7584.0 ft Pulled out of hole to 0.0 ft Worked on BOP - Top ram Laid down 270.0 ft of Drill collar Rigged up Casing handling equipment Held safety meeting Ran Liner to 3707.0 ft (7in OD) Circulated at 3707.0 ft Ran Liner in stands to 7550.0 ft Ran Liner on landing string to 7584.0 ft Circulated at 7584.0 ft Held safety meeting Cleared Cement pump Pumped Fresh water spacers - volume 20.000 bbl Mixed and pumped slurry - 112.000 bbl Displaced slurry - 179.000 bbl Functioned Liner hanger Circulated at 3747.0 ft Pulled Drillpipe in stands to 3747.0 ft Rigged down Drillstring handling equipment Worked on BOP - Top ram R.I.H. to 2500.0 ft Serviced Top drive R.I.H. to 7100.0 ft Washed to 7440.0 ft Drilled cement to 7637.0 ft Circulated at 7637.0 ft Tested Liner - Via annulus and string Pulled out of hole to 900.0 ft Rigged down Drillstring handling equipment Ran Drillpipe in stands to 7630.0 ft Circulated at 7630.0 ft Facility PB DS 14 Progress Report Well 14-05A Page 5 Rig Nabors 9ES Date 08 March 99 Date/Time 05 Mar 99 06 Mar 99 07 Mar 99 Duration 16:00-21:00 5 hr 21:00-21:30 1/2 hr 21:30-00:00 2-1/2 hr 00:00-02:00 2 hr 02:00-06:00 4 hr 06:00-09:00 3 hr 09:00-11:00 2 hr 11:00-12:00 1 hr 12:00-13:30 1-1/2 hr 13:30-14:30 1 hr 14:30-15:30 1 hr 15:30-16:00 1/2 hr 16:00-18:30 2-1/2 hr 18:30-21:00 2-1/2 hr 21:00-21:30 1/2 hr 21:30-06:00 8-1/2 hr 06:00-13:30 7-1/2 hr 13:30-15:30 2 hr 15:30-17:00 1-1/2 hr 17:00-17:30 1/2 hr 17:30-18:15 3/4 hr 18:15-20:30 2-1/4 hr 20:30-22:30 2 hr 22:30-23:30 1 hr 23:30-01:30 2hr 01:30-02:30 1 hr 02:30-03:30 1 hr 03:30-06:00 2-1/2 hr 06:00-06:30 1/2 hr 06:30-12:00 5-1/2 hr 12:00-13:30 1-1/2 hr 13:30-14:30 1 hr 14:30-17:00 2-1/2 hr 17:00-17:30 1/2 hr Activity Washed to 7670.0 ft Packer worked at 7670.0 ft Pulled out of hole to 3700.0 ft Pulled out of hole to 0.0 ft Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Singled in drill pipe to 770.0 ft R.I.H. to 4500.0 ft Circulated at 4500.0 ft Laid down 700.0 ft of 4in OD drill pipe Circulated at 3700.0 ft Laid down 3700.0 ft of 4in OD drill pipe Rigged up Completion string handling equipment Held safety meeting Ran Tubing to 3900.0 ft (4-1/2in OD) Ran Tubing to 7700.0 ft (4-1/2in OD) Space out tubulars Reverse circulated at 7707.0 ft Installed Tubing hanger Tested Tubing hanger Conducted slickline operations on Slickline equipment - Tool run Set downhole equipment (wireline) Set packer at 7650.0 ft with 4000.0 psi Tested Tubing - Via annulus Installed Hanger plug Rigged down Completion string handling equipment Rigged down BOP stack Rigged down BOP stack Installed Xmas tree Tested Xmas tree Removed Hanger plug Freeze protect well - 150.000 bbl of Diesel Installed Hanger plug MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson,~/~l(~O DATE: Chairman February 21, 1999 THRU: Blair Wondzell, ~,-g~ FILE NO: agskbugf.doc P. I. Supervisor ¢.4'¢_¢/¢-), FROM: Chuck Scheve, 4:...¢ SUBJECT: Petroleum Inspector BOPE Test Nabors 9ES PBU 14-05A PTD # 92-0001 Sund.,av, Febm..ary 2.!, 19..9.9; I traveled to Arco's Drill Site 14-05A Well and witnessed the weekly BOPE test on Nabors Rig 9ES. As the attached AOGCC BOPE Test Report indicates, the test lasted ~..5 hours and there were no failures. The testing went very well with the test procedure being practiced by the Nabors crew allowing the testing to be completed in a minimum number of steps. The rig was very clean and all equipment appeared to be in excellent condition. The location was clean and all extra equipment was properly stored. Summary_.' I witnessed the weekly BOPE test on Nabors Rig 9ES working over Arco's 14-05A well. NABORS 9ES, 2121199, Test Time :~.~..5 Hours, No Failures Attachment: agskbugf.xls X Unclassified ,_ ~ Confidential (Unclassified if doc. removed ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg:~ Workover: X DATE: DrlgContractor: NABORS Rig No. gES PTD# g2-0001 Rig Ph.# Operator: $SD Rep.' John Rawl Well Name: 14-05A Rig Rep.: Larkin/Rod~ers Casing Size: Set @ Location: Sec. T. R. , ,,,, Test: Initial Weekly X Other 2/21/9g 659-4831 Meddian Um. Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Standing Order Posted YES FLOOR SAFETY VALVES: Quan. Pressure Well Sign OK Upper Kelly / IBOP I 250/5000 Dd. Rig OK Lower Kelly / IBOP I 250/5000 Hazard Sec. YES · Ball Type I 250 / 5000 ~ Inside BOP I 25015000 P/F P P P P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. 250/3500 1 1 2 1 Visual OK OK OK OK OK 250/5000 251/5000 250/5000 250/5000 250/5000 250/5000 N/A P/F Test P Pressure P 250/5,000 P P P P P , , CHOKE MANIFOLD: No. Valves No. Flanges 32 Manual Chokes Hydraulic Chokes 1 250/5,000 Functioned Functioned P/F ACCUMULATOR SYSTEM: . System Pressure 3,000 I P . Pressure After Closure 1,600 I P MUD SYSTEM: Alarm 200 psi Attained After Closure 0 minutes 27 sec. Trip Tank OK System Pressure Attained 2 minutes 20 sec. Pit Level Indicators OK Blind Switch Covers: Master: YEs Remote: YES Flow Indicator OK Nitgn. Btrs: 4 {~2100 Meth Gas Detector OK - Psig. H2S Gas Detector OK ' Number of Failures: 0 ,Test Time: 3.5 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Wdtten or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 III I REMARKS: ~lood test Distribution: odg-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector F1-021L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: agskbugf Chuck Scheve GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'I-i'N: Sherrie NO. 9720 Company: 9/1 2/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 7-6 "7 ~ I I~ PACK OFF GAS LIFT MANDREL 950826 I 1 D.S. 7-6[ O J [ ~TUBING PUNCHER RECORD 950825 I 1 D.S. 7-19 ~ ~ ~--I~ PRODUCTION PROFILE 950822 I 1 D.S. 9-1 -7 ~ O'~ ~o LEAK DETECTION LOG 950822 I 1 O.S. 9-29 ~'5~- ~C~ ~ PRODUCTION PROFILE 950820 1 1 D.S. 14-5A ~ ~ ~O [ PRODUCTION PROFILE 950826 1 1 D.S. 14-6 ~7 ~ ~0 ~ ~'~ STATIC PRESSURE SURVEY 950825 1 1 D.S. 14-31 ~-~ J I ~ PRODUCTION PROFILE 950821 I 1 D.S. 15-14 ~ ~ I 7~ PRODUCTION PROFILE 950824 1 I , SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'I-rN: Sherrie NO. 9471 Company: 5/23/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia -DIR MWD Disk D.S. 2-31 ~ ! -- t O_~ TBG CUTTER RECORD 043095 I 1 D.S. 3-06 ~ ~o- ~ O M.I. INJEC LOG 0421 95 I 1 D.S. 3-31 ~ ~-~ Z_ CNL 050295 I 1 D.S. 7-32 c~ ~_/50 PERFRECORD 042895 I 1 D.S. 9-8 '~L~-'70 PERFRECORD 042995 I 1 D.S. 9-12 '7")-' ~ INJECPROFILE 050395 I 1 D.S. 11-16 ST1 ~'~-7~!~ PERFRECORD 042995 I 1 D.S. 11-23A C~--"~I PERFRECORD 050195 I 1 D.S. 11-28 ~'C~"-"70 LEAK DETECTION 042895 I 1 D.S. 11-35 ~ ~"(¢..~ CNL 050295 I 1 D.S. 11-36Cl' ~- ~ ~ DUAL BUST TDT-P 0501 95 I 1 D.S. 11-36 ~ ~" ~ ~ RST 042195 I 1 O.S. 14-5A c~..... / PERFRECORD 042795 I 1 D.S. 14-22A ~ ~'~,- /~ PERF RECORD 042795 I 1 D.S. 14-28~,~,-- I~ LEAK DETECTION 042995 I I . .D.S. 14-33 ~':,-3-/~T~.~ CNL 0427951 I 1 D.S. 14-43 ~ ~"' J ~)~ DUAL BURST TDT-P 042795 I 1 9.S. 16-12 ~ I'",~ ~ TBG CUTTER RECORD 043095 1 1 D.S. 18-02A C~5 -~O iPERFRECORD 050295 I 1 9.S. 15-19 ' 95176 OUALBURSTTDT-P 050495 I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: ,,, ,, 1995 Alaska 0il & Gas Cons. Commission Anchorage ,-- STATE OF ALASKA ALASKa..~!IL AND GAS CONSERVATION C~ /IMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. BOX 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1614' FNL, 1154' FEL, Sec. 9, T10N, R14E, UM 5. Type of Well DevelopmeNt Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-05A At top of productive interval RE6E~VED 1241' FNL, 1387' FEL, Sec. 9, T10N, R14E, UM At effective depth M~,¥ 2_ ~ 1995 At total depth ~$~f~ Uti & Gas Cons. Commission 1002' FNL, 1471' FEL, Sec. 9, TION, R14E, UM AI1CIlo~i:~ feet 9. Permit number/approval number 92-01 10. APl number 50 - 029-20327-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9380 feet Plugs(measured) 9238 feet Effective depth: measured 9335 feet true vertical 9199 feet Junk(measured) Casing length Size Cemented Measured depth True vertical depth Conductor 124' 20" 300 sx Adicset 124' 124' Surface 2663' 13-3/8" 4234 sx Permafrost 2736' 2736' Production 8559' 9-5/8" 1000 sx Class G 8632' 8588' Liner 1796' 7" 493 cu ft Class G 9380' 9238' Perforation depth: measured 8773-8787'; 8793-8807'; 8921-8932'; 8937-8947' true vertical 8712-8724'; 8729-8742'; 8840-8850'; 8854-8863' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13 CR-80, Tdg@ 8443' MD Packers and SSSV (type and measured depth) 7", TIW HBBP Packer @ 8380' MD; 4-1/2", AVA SSSV @ 2196' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 824 5898 5619 1026 7683 6154 Tubing Pressure 264 294 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 06/15/88 cc: KZ. JWP Title Engineering Supervisor SUBMIT IN DUpLICATE~ 14-05A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 4/27/95: MIRU & PT equipment. Added Perforations: 8773 - 8787' MD (Sag) Ref. Log: BHCS 1/31/92. 8793 - 8807' MD (Sag) Used 3-3/8" carriers & shot 4 spf at 180 degree phasing at underbalanced pressures. POOH w/perf guns. Noted all shots fired. Rigged down. RIH w/perforating guns & shot 28' of add perforations as follows: Returned the well to production w/gas lift & obtained a valid welltest. R'ECEIVED UA Y 2 ~ 1995 Alaska Oil & Gas Cons. Commission Anchore, , G~o~ued ~ W. IntemcHional Aiq~od Road Anchorage, AK 99618-1199 · ATTN: She~e NO. 8945 Company: I Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 9/21/94 Field: Prudhoe Bay Well / Log Description BL RR Sepia RF Sepia Mylar D.$.4-03 '~\ ~ Dg PROD LO~ (9/4/94) 1 1 D.S.7-13 '"'~-K'- ~ TUBG CUT RECORD (9/1/94) 1 1 D.S.9-20 , MI INJECT PROFILE (9~5/94) 1 1 D.S. 13-33 PROD PROFILE (9/3/94) 1 1 D.S. 14-5A ~'Z..- C~ 1' PROD PROFILE (9/1/94) 1 1 D.S. 14-24 ~'~--~ ! .. PROD PROFILE (9/3/94) 1 1 D.S. 16-31~'2..-- ~_~ PATCH SET RECORD (9/6/94) 1 1 ~. , · __ SIGN! PleaSe sign and return copy of this transmittal to Sherrie at the above address. Thank you. o/// e at the ab STATE OF ALASKA ALASKA ~ _ AND GAS CONSERVATION REPORT OF SUNDRY WELL OPr-r ATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate ,,, X Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1614' FNL, 1154' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 1241' FNL, 1387' FEL, Sec. 9, T10N, R14E, UM At effective depth At total depth 1002' FNL, 1471' FEL, Sec. 9, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 73' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-05A 9. Permit number/approval number 92-01 10. APl number 50 - 029-20327-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9380 feet 9238 feet Plugs(measured) PBTD @ 9015' MD (11/30/93) Effective depth: measured 9015 feet true vertical 8921 feet Junk(measured) Casing Length Size Cemented Conductor 124' 20" 300 sx Articset Surface 2663' 13-3/8" 4234 sx Permafrost Production 8559' 9-5/8" 1000 sx Class G Liner 1796' 7" 493 cu ft Class G Measured depth True vertical depth 124' 124' 2736' 2736' 8632' 8588' Perforation depth' measured 8921-8932', 8937-8947' true vertical 8840-8850' 8854-8863' Tubing (size, grade, and measured depth) 4-1/2", 12.6¢¢, 13 Cr 80, Tbg @ 8443' MD MAR 1 6 1994 Naska Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 7", TIW HBBP 9 Cr Packer @ 8380' MD; 4-1/2", AVA SSSV @ 2196' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 883 4728 2972 700 225 908 4482 3265 800 220 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~?~?/~:.~/l-. Senior Engineer Form 10-404 Rev 06/15/88 j RJR cc: J. DeGrev. J. W. Peirce . SUBMIT IN DUPLICATE le e 0 e DS 14-05A Summary of Perforating Operations 12/1/93 Move in and rig up SWS. Pressure test lubricator to 3000 psi. Run in hole, tie in, and perforate from 8921' MD to 8932' MD (ref. 1/31/92 BHCS) at 4 shots per foot. Pull out of hole return well to production. RECEIVED MAR q Co 1994 Naska Oil & Gas Cons. Commission Anchorage PERMIT 92-001 92-001 92-001 92-001 92-001 92-001 92-001 92-001 92-001 92-001 92-001 92-001 9~2-001 92-001 92-001 92-001 92-001 92-001 92-001 92-001 DATA AOGCC Individual Geological Materials T DATA_PLUS Well Inventory BHCA/GR CL L 7847-9081 L 8285-9289 L 8481-9100 L 7400-9320 L 8750-9035 L 7789-9110 L 8562-8961 L 8800-8970 L 8800-9250 L L 8800-8980 L 8800-9000 L 8800-9050 CL CNL DB TDTP DIFL/GR PERF PITS PITS PROD PROD PROD PROD SSTVD L 7789-9110 407 R COMP DATE:02/10/92 DAILY WELL OP R 01/21/92-02/06/92 MWD SURVEY R 7850-8827 SS DIRECTIONAL R 7850-9380 5185 T 7847-9107, OH-DIFL/AC 5324 T 8646-9320, CH-CNTH Page' Date: SCALE 2&5 5 5 5 5 2&5 5 5 5 5 5 5 l&2 1 01/18/94 DATE_RECVD 02/25/92 10/05/92 03/12/92 03/12/92 08/31/93 02/25/92 04/19/93 04/27/93 04/30/92 10/05/92 03/19/93 10/05/92 04/30/92 02/25/92 05/05/92 05/05/92 05/05/92 05/05/92 02/25/92 07/13/92 PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page: 2 Date- 01/18/94 SCALE DATE_RECVD Are dry ditch samples required? yes--And, received? yes ~ Was the well cored.? yes no Analysis & description received? yes no Are well tests required?~y/gst Well is al no Received? yes no Comments ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-4-94 REFERENCE: 5-7 5-23 11-30-93 6-6 11-30-93 6-12A 12-02-93 11-12 12-02-93 11-18 11-29-93 14-2 11-26-93 '14-5A 12-01-93 14-43 12-01-93 16-17 12-03-93 /18-23A 11-24-93 \ 18-23A 12-01-93 %18-23A ' 12-01-93 ARCO CASED HOLE FINALS 11-30-93 Prod Profile~¢l'~?l Dual Burst TDT-P Run Perf Record ~l~m~ztgz Run Perf Record Prod Profilet~c~,~i~.,'~'~/~"~Run Prod Profile.~.~'~ i ~;~{'~'-~ Run PFC/GR/CCL Completion '?~'~ ~c,~ Run Perf Record~-~i~--:i~i',~ Run Tubing GLM Packer Run 1, 5" ~q%'~ ~ ~°ch 1, 5" Sch 1, 5" Sch 1, 5" ~ch 1, 5" I~.-t~:~ ch 1, 1, 5" Sch 1, 5" Sch 1, 5" ~:;"~" ~'{' ..~o Sch Collar ~1~.%~ ~ ?u~.~.~._7~c Run 1, 5" Arias CBT/GR/CCL Color* $ Run 1, 5" '----% Sch USIT lc,&') ~- Color Run 1, 5" ' % Sch Please. sign and return the attached copy as receipt of data. ~),C/-,~, .'- RECEIVED BY-__ .ff--~__~/~.~_~~ ' '41~7s~.. J~/74~~/~~ ~ve A Nice Day! Jo~ E. DeGrey APPROVED ~~ ~Cb°rag° ~/**tb~ ATO- 1~0 ~~$ 0400~ # CENTRAL FILES # CHEVRON # BPX # STATE OF .At.&SKA # PHILLIPS # ANO8 GEOLOGY # EXXON # MOBIL The corrected well name is 14-2 and the corrected API# is 50-029-20318-00. zl ARCO Alaska~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: 1-30 ~-30 ~_5_~4-1 q(- ~4-40 ~ ?..~_~9-13 ~-26 -42 1-12 1-18 ~11-22 ~- 1 ~-1 ~4-~0 ' 0-7 ~7-1~ 7-14-93 7-5-93 7-11-93 7-17-93 7-17-93 7-10-93 7-6-93 7-6-93 7-8-93 7-11-93 7-3-93 7-3-93 7-9-93 ?-4-93 7-4-93 7-8-93 7-2-93 7-16-93 7-16-93 7-5-93 7-6-93 7-9-93 7-13-93 7-12-93 Completion Record Perf Record ~)0~zf~ R~m 1, 5" InJ Profile ~ ~-~c~ Run 1, 5" Perf Record t~,~-i~-~5 R~m 1, 5" Sch Sch Sch Sch Prod Profile ~o-~5% Run. 5" Sch Production Log~'~z-~_]Run 11: 5" Sch PITS/InJ ProflleaUW-'~R,_m 1' 5" Sch Production Log=~>-~R~m 1, l"&5" Sch Completion Record R~m 1, 5"~SSSSch Perf Record ~-~5~q5 R~m 1, 5" Sch Perf Record )%%o-~ ~r~ Ru_n 1, 5" Sch Peri Record%~0-~~ R-n 1, 5" Sch ~ ~tect ~- ~ R~ 1, 5" ~mpleflon Record R~m 1, 5" ~~C~cn ~k ~tect R~n 1, 2" o- ~o~% Sch ~k ~ct ~~o R~ 1, 2"&5" Sch ~ Brat ~ R~m 1, 5"~-~ch Pe~ Record ~-~z~51 R~ 1, 5" Sch ~e-~ ~g- ~P ~%~b~ 1, 5" Sch ~ ~tect ~-%~o R~m 1, 2" Sch Pe~RecordqS~~ R~m 1,5" Sch ~j ~~/~ ~c R,,~ 1, 5'~s~-~o~ZSch Pe~ Record ~10~ I R~ 1, 5" Sch ~ ~tect ~_ ~ ot~ R~m 1, 2" Sch Please sign and return the attached copy ~s receipt of data. ..... Have A Nice Day! Sonya Wallace APPROVED_ _ff~______ ~_~ ATO- 1529 Trans# 93081 # ptm.T.rps # CENTRAL FILES # CHEVRON # CLINT CHAPMAN # BPX # EXXON # STATE OF ~KA # MOBIL * The correct top logged Interval for 11-22 is 380 feet. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE FINALS 1-7-'7%-17 2-20-93 '-,1-9 3-18-93 1.1o-.'7S-L/3 3.5.93 ..~ 1- 24A 2-8-93 I~c~ 2-11-- '7'7-~ 2-23-93 ~0-O~ -2-13~-7-'s 2-13-93 3-1-7 ' 1-6-93 aS --3-9 11-12-92 3-34a-c/7-a 1-25-93 · 4.24-?~-~/~ 3-6.93 ~ ~5-6 2-13-93 5-11--/?-~ 8-13-92 ~.0-t --- 5-22 2-9-93 6.3-.-3~- ?~ 1-22-93 75 -.6-10 2-16-93 6-18~ 2-22-93 ~-. ~\t.~ --6-19 2-16-93 77-3300~8_~q 12-19-02 2-15-93 1/,,,~ ,,-9-2 , 2-8-93 9-7-"7 ~'-'~'~ 3-9-93 7'-~ ~"7 -"9-16 3-9-93 9-42--~0--~ 2-20-93 ~-- ]~:~ --9-49 2-6-93 11-1A~ c~.- ] ~7_.2-14-93 11-13/ 3-19-93 [0 1 ...-13-30 2-19-93 13-33'~,~1.- 119b~l. 2-14-92 13-33/ ..... 12-14-92 e~a-0 t--14-5A 3-19-93 /14-28 3-2-93 ,,--x~4.28 3-8-92 * 14-34- ~'5-1~12-10-91 --16-25 2-26-93 16-26-~/Z-c~2-28.93 c/~-/z~, -16-28 2-28-93 ** 16.2 9A-C~2.-/~3.1.93 /C~ ---17-15 11-16-92 /17-16 1-12-93 Leak Detect Run 1, 5" Peri' Record Run 1, 5" Prod Profile Run 1, 5" Prod Profile Run 1, 5" PITS Run 1, 5" Prod Profile Run 1, 5" Perf Record Run 1, 5" Prod Profile Run 1, 5" Peri' Record Run 1, 5" Prod Profile Run 1, 5" Collar Log Run 1, 5" Leak Detection Run 1, 2"&5" Prod Profile Run 1, 5" TMD Run 1,5" Peri' Record Run 1, 5" Perf.Record Run 1, 5" Prod Pro/tle Run 1, 5" Peri' Record Run 1, 5" Prod Profile Run 1, 5" Prod Profile Run 1, 5" Peri' Record Run 1, 5" Prod Profile Run 1, 5" Prod Profile Run 1, 5" Prod Profile Run 1, 5" Iai Profile Run 1, 5" Temperature Log Run 1, 5" Prod Profile Run 1, 5" GR/Collar Run 1, 5" GR/Collar Run 1, 5" Prod Profile Run 1, 5" Tracerscaa Run 1, 5" Tracerscan LOg Run 1, 5" PITS Run 1, 5" Baker IBP/Collar Run 1, 5" Baker IBP/Collar Run 1, 5" TMD Run 1, 5" Prod Profile Run 1, 5" Prod Profile Run 1, 5" Prod Profile Run 1, 5" Prod Profile Run 1, 5" Pert' Record Run 1, 5" Pert' Record Run 1, 5" Please sign and return t~e attached copy as.~receipt of data. flare A Nice Dayl ~ Sonya Wallace ATO-1529 APPROVED_ffff_ Trans# 93049 HIS Camco Camco Camco Camco HIS Camco HLS Camco HIS Camco Camco HLS IlLS HIS Camco HIS Camco Camco IlLS Camco Camco Camco Camco Camco Camco Camco Camco Camco HLS HLS Camco Camco Camco HIS Camco Camco Camco Camco HIS HIS CENTRAL FILES CHEVRON # LUCILLE JOHNSTON EXXON MOBIL PHILLII~ #BPX STATE OF ALASKA The correct APl# for 14-34 is 50-029-21010-00. The coorect well name for this 1o~[ is 16-29A. ARCO Alaska. Inc. P.OJ~x 1OO360 Anchorage. Alaska 99510 RECEIVED DATE: REFERENCE: ARCO CASED HOLE FINALS -11 1-24-93 -11 2-7-93 1-13 2-7-93 Cj.~~1-24A 2-20-93 ~--T"~-_~1-30 1-24-93 2-14 7-27-91 3-9 12-19-92 ~ 5,.~.~.j~L3-24 1-25-93 '3-32 3-32 4-25-92 4-25-92 ~_t~-32 2-19-93 ~3-341 2-19-93 · 4-35 8-16-92 -41 2-22-93 3-2-93 ~9-27 -~ 3-1-92 ~9-27 3-1-92 ~~'~I 2-6-~3 - 2-8-g3 1-1 1-131 3-8-93 1-16 4-14-92 1-18 4-14-92 --X2-4A 2-1 X-93 ~~12-19 2-11-93 5~ 12-29 12-22-92 ~X2-32 X2-~-92 /14-5A 2-20-93 -~14-12 4-24-92 ~~4-~ 4-~4-~ 4-37 4-13-92 4-37 4-13-92 6-21 7-23-92 6-21 7-23-92 6-27 8-23-92 16-30 2-12-93 **,Alaska Oil &A.~,..__Gas Cons. Commission Perf Record '~i~l~" HL8 Perf Record Run 1.5" HLS Perf Record Run l. 5" HIS Perf Record Run 1.5" HIS Pert' Record Run 1.5" HIS TMD Run 1.5" HIS Perf Record Run 1, 5" HIS Perf Record Run 1.5" HIS PGST Computed Results Run 1.5" HIS PSGT Run 1.5" HIS Perf Record Run 1.5" HIS Peri' Record Run 1, 5" HIS TMD Run 1, 5" HIS DSN Run 1.5" HIS TMD Boron Injection Run 1, 5" HIS Perf Record Run 1, 5" HIS Peri' Record Run 1, 5" HIS PSGT Computed Results Run 1.5" HIS PSGT 5 Ft/Min Run 1. 5" HIS PSGT 10 Ft/Mln Run 1, 5" HIS Perf Record Run 1, 5" HIS Perf Record Run 1, 5" HIS PSGT Computed Results Run 1.5" HIS PSGT Run 1, 5" HIS Perf Record Run 1, 5" HIS PSGT Computed Results Run 1.5" HLS PSGT Run 1.5" HIS Perf Record Run 1, 5" HIS Perf Record Run 1, 5" HIS Perf Record Run 1.5" HIS Perf Record Run 1.5" HIS Peri' Record Run 1.5" HIS PS(IT Computed Results Run 1.5" HIS PSGT Run 1, 5" HIS PSGT Computed Results Run 1, 5" HIS PSGT Run 1, 5" HIS PS(IT Computed Results Run 1, 5" HIS PSGT Run 1, 5" HIS Perf Record Run 1.5" HIS Perf Record Run 1.5" HIS Run 1.5" HIS i~.~ 7-21 12-20-92 Perf Record ~ign and return t/he att,ached co, py as receipt of data. RECEIVED BY . . APPROVED Sonya Wallace ATO-1529 Trans# 930 CENTRAL FILES CHEVRON # LUCILLE JOHNSTON EXXON # PHILLIPS # MOBIL # BPX # STATE OF ALASKA * The correct apl# for 3-32 is 50-O29-21141-00. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-15-93 REFERENCE: ARCO CASED HOLE FINALS 12-29-92 Profile Run Inj 1, 5-.2-92 TMD lh_m 1, ~-3 12-13-92 PITS l~_m 1, ~c-~:~-20 12-13-92 Prod Profile Run 1, .~~7-25 12-13-92 Prod Profile Run 1, I~' ~ 1-17-93 Set Baker IBP/CCL l~m 1, ~14.5A 1-7-93 Prod Profile Run 1, 14-11 11-23-92 Gas IJft Run 1, 2'&~' ~-._~_.~ 17-4 12-1292 Temperature Run 1, Please sign and return the attached copy as receipt of data. Have A Nice Day! Sonya Wallace APPROVED__~___ ATO- 1529 Trans# 93032 C~_ taco Camco HL8 Camco Camco Camco C~_mco ~mco # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PHILLIPS PB WELL ~ R&D # BPX # STATE OF ALASKA p,£C£1q£D _ Gommission Alaska Oil ~ Gas Go~s. · ~ncbo(a9e STATE OF ALASKA --~ --' ALASKA"""~L AND GAS CONSERVATION C( MISSION ' REPORT SUNDRY WELL OPIr. RATIONS 1. oPerations performed: Operation shutdown Stimulate ~ Plugging Perforate X. ' ~-~%~'~ I Pull tubing Alter casing Repair well Other X ~--~' 5. Type o~f W. ell . . 6. Datum of elevation(DF or KB) i.~'eve~opmen[~, 73 RKB 2. Name of Operator ARCO Alaska, Inc. Exploratory 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1614' FNL, 1154' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 1241' FNL, 1387' FEL, Sec. 9, T10N, R14E, UM At effective depth At total depth 1002' FNL, 1471' FEL, Sec. 9, T10N, R14E, UM Stratigraphic Service 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-05A 9. Permit number/approval number 92-01 10. APl number 50 - 029-20327-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9380 feet 9238 feet Plugs(measured) PBTD @ 8968' MD (2/20/93) Effective depth: measured 8968 feet true vertical 8881 feet Junk(measured) Casing Length Size Cemented Conductor 124' 20" 300 sx Arcticset Sudace 2663' 13-3/8" 4234 sx Permafrost Production 8559' 9-5/8" 1000 sx Class G Liner 1796' 7" 493 cuft Class G Measured depth True vertical depth 124' 124' 2736' 2736' 8632' 8588' 9380' 9238' Perforation depth: measured 8937-8947' true vertical 8854-8863' Tubing (size, grade, and measured depth) 4-1/2", 12.6~, 13 Cr 80, Tbg @ 8443' MD RECEIVED .41aska Oil & Gas (Jo,~s. L;ommission Anchorage Packers and SSSV (type and measured depth) 7", TIW HBBP 9 Cr Packer @ 8380' MD; 4-1/2", AVA SSSV @ 2196' MD 13. Stimulation or cement squeeze summary intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 1607 6088 8996 -- 1179 6712 2976 -- Tubing Pressure 267 238 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x..&_ Gasm Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _~ '~'- '~ Form 10-404 Rev 06/15/88 965/1 WHS cc: SW, JWP Title Engineering Supervisor SUBMIT IN DUPLICATe, 14-05A DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZES FOR WATER SHUTOFF 6~27~92: A CTU Foamed Cement Squeeze for Water Shutoff was performed as follows: MIRU CTU & PT equipment to 4500 psi. RIH w/CT & fluid packed the wellbore w/250 bbls hot 1% KCl Freshwater, followed by 50 bbls 1% KCl Water w/foaming agent, followed by 100 bbls seawater foamed w/Nitrogen at 1100 scfm, then cement squeezed the perforations at: 8921 - 8932' MD (Z4) 8937 - 8984' MD (Z4) 8972 - 8982' MD (Z4) 8988 - 8994' MD (Z4) Ref Log: BHCS 1/31/92. Pumped 45 bbls of Class 'G' cement (at surface) w/Nitrogen injected, to make 68 bbls of foamed cement (out CT nozzle), to squeeze the perforations. Placed 48 bbls of foamed cement behind pipe at 1200 psi maximum squeeze pressure, but pressure kept breaking back to 1000 psi. Contaminated cement w/biozan & jetted cement from wellbore down to 8700' MD. POOH. Rigged down. 6/29/92: RIH & tagged top of cement at 9079' MD 7/18/92: A CTU Foamed Cement Resqueeze for Water Shutoff was performed as follows: MIRU CTU & PT equipment to 4000 psi. RIH w/CT & loaded the welibore w/374 bbls hot 1% KCl Water & 100 bbls Crude, followed by 100 bbls 1% KCI Water w/foaming agent & 49,500 scl of injected Nitrogen, then resqueezed the perforations (listed above). Pumped 5 bbls of Neat Class 'G' cement, followed by 25 bbls Class 'G' w/aggregate, followed by 50 bbls Neat Class 'G' cement w/Nitrogen injected (made 75 bbls foamed cement), to resqueeze the perforations (above). Placed 88 bbls of cement behind pipe at 500 to 1000 psi squeeze pressure. Attempted to leave the last 17 bbls of cement pumped across the perforations, since it was expected the well would have taken all the cement behind pipe. voidage w/Crude & Diesel down backside. 7/20/92: RIH & tagged top of cement at 8711' MD. 7/26/92: RIH Did not cleanout wellbore. Rigged down. w/underreamer & underreamed cement down to 9021' MD. POOH w/CT while replacing RECEIV D mJaska Oil & Gas Cons. Oommiss~ POOH w/underream~r~cho~.. 8/3/92: Ran Production Profile logs indicating the top squeezed perforation interval was leaking, then returned the well. to production through the leaking squeezed perforations. 2/20/93: Reperforated: 8937 - 8947' MD (Z4) Ref Log: BHCS 1/31/92. Returned the well to production & obtained a valid welltest. Currently the well is under surveillance & a future resqueeze may be performed when justified. ARCO Alaska~ Inc. P.O.Box 100360 Anchorage, ,~!nslra 99510 DATE: 10-2-92 REFERENCE: ARCO CASED HOLE FINALS Pelf Run 1, 5" HIS Perf l~m 1, 5" HLS Pelf Run 1, 5" HIS Pelf Run 1, 5" HIS Collar R,m 1, 5" Hi.q Pelf l~rn 1, 5" HLS Pelf Run 1, 5" HLS Pelf l~m 1, 5" HLS Pelf R,m L 5" HLS Pelf Run L 5" HLS Pelf l~m L 5" HIS Pelf R,m L 5" KLS Pelf Rrm 1, 5" HIS Collar Run 1, 5" ~rLS Pelf Run 1, 5" I:rLS Collar R,m 1, 5" HLS Pelf Run 1, ~' HLS Pelf Run L 5" HLS Pelf R,m 1, 5" HLS Pelf l~m 1, 5" HIS Please sign and return ~-~t~/~7°PY as receipt °f data'~ RECEIVED B~~E~% ///~7/~ Sonya Wallace OC T 0,5 1991! ATO-1529 Nas/ia Oil & Gas Cons. CommJssi.o.n # CENTRAL ~orage # CHEVRON # EXTENSION EXPLORATION # EXXON # MOBIL APPROVED_fi__ Trn_nu# 9221~~'-''''--m- # ~.T.rPs PB WELL ~ # BPX # STATE OF ALASKA The correct well -nme is 1-1B. The correct AP1 # for l-lB is 50-029-21007-01. The correct well -nme iS 6"14~;. The correct APl # for 7-4A is 50-029-20292-01. The correct AP1 # for 14-1 is ~20317.00. The correct AP1 # for 14-5A is 50-0'29-20327-01. The correct AP1 # for 16.31 is 50-02.9-22280-00. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 9-18-92 REFERENCE: ARCO CASED HOY.~'. FINALS Ih,- 1, ~" Rim 1, ~" RLm 1, ~" RLm 1, ~" Run 1, 5" l~m 1, ~" Run 1,5" RLm L 1~' Run 1, fY' Run 1, 5" Please sign ~d return tl!.e attachwI copy u receipt of data. ~n~ W~e 0 5 1992 APPROVED ATO-1529 0G T ~-s~ 9220~-- # PHIL~ PB WELL ~ R&D # BPX # STATE OF ALASKA TEXACO Alaska Oil & Gas Cons. Commission Anchorage # CENTRAL ~ # CHEVRON D&M # EXTENSION ~RATION # EXXON MARATHON # MOBIL * The correct well n~me is 16-29A not 16-29ST. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-10-92 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS CNTH Run 1 Job~ 92008 Sch CNTD Run I Job~ 92041 Sch CNTD Run I Job~ 92042 Sch CNTD Run 3 Job~ 92081 Sch CNTH Run 1 Job~ 92130 Sch CNTD Run 3 Job# 92010 Sch Please sign and return the attached copy as receipt of data. RECEIVED BY ./~~__ _~_~__ Have A Nice Day! Sonya W_~ll~ce ATO- 1529 RECEIVED JUL 1 ~ 1992 Alaska 011 & Gas Cons. Commission Anchorage. # CENTRAL FILES (CH) CHEVRON D&M D SCHWARTZ (OH/GCT) # EXXON MARATHON MOBIL APPROVED__..//9} Trans# 92145 # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO " ~'"" STATE OF ALASKA -" ALASKA ~,~ AND GAS CONSERVATION CO, ./IISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL,~/¢). GAS [] SUSPEI~ED ABANDONED . SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 92-01 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20327-01 4. Location of well at surface ~.;,~ ....... . 9. Unit or Lease Name 1614'FNL, 1154'FEL, SEC. 09, TION, R14E J ............ "~"~ ~ Prudhoe Bay Unit ~ ~Ji~ ,; 10. Well Number At Total Depth ~--~. Prudhoe Bay Field/Prudhoe Bay Pool 1002'FNL, 1471'FEL, SEC. 09, TION, R14E , 5. Elevation in feet (indicale KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 73' ADL 28312 12. Dale Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J15. Water Depth, if offshore J16. No. of Completions 1/22/92 1/31/92 2/10/92I N/A leet MSLI ONE 17. Tolal Depth (MD+TVD) 18. Plug Back Deplh (MD+TVD 19. Directional Survey J20. Depth where SSSV sel 121. Thickness of Permatrosl 9380' MD/9238' TVD 9335' MD/9199' 7'VD YES [] NO []I 2196'feet MD J 1900' 22. Type Electric or Other Logs Run GR/SP/DIL/BCS 23. CASING, LINER AND CEMENTING RECORD SE'FI'lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.5# Cond. Surface 124' 30" 300 sx Arcticset 13-3/8" 72# N-80 Surface 2736' 17-1/2" 4234 sx pPermafrost 9-5/8" 47# L-80 Surface 8632' 12-1/4" 1000 sx Class "G" 7" 29# 13CR80 7584' 9380' 8-1/2" 493 cuft Class "G" 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 (MDI MD TVD 4-1/2" 8443' 8380' 8921-'8932' 8840'-8850' I spf 8937'8964' 8854'-8878' 4 spf 8972'-8982' 8885'-8893' 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8988'-8994' 8899'-8904' I spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODL.~TION TEST Date First Production IMethod o! Operation (Flowing, gas lift, etc.) 2/10/92 J Gas Lift Date o! Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I~ I iFIow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED MAY - 5 t992 Alaska Oil &. Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ 30. GEOLOGIC MARKERS ~ ,ATION TESTS NAME Include interval tested, pressure data, all lluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 8766' 8706' Shublik 8790' 8727' Top Sadlerochit 8871' 8797' ~ . ,, 31. LIST OF ATTACHMENTS 32. I hereby certify that the loregoing is true and correct to the best o! my knowledge Signed ~/~-~/ TitleAroaOrillinoEncdnoer 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". RECEIVED Form 10-407 MAY - 5 1992 Alaska 0il & Gas Cons. Commission ACTIVITY SUMMARY for WELL 3JECT 4J0132 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : DS 14-5A Page: 1 DRLG RIG : NABORS 2ES WO/COMP RIG: NABORS 2ES 01/21/92 ( 1) TD: 8200 PB: 8200 SUPV:DLW N/U BOPE. MW: 8.4 Seawater MOVE RIG F/ DS ll-3A TO DS 14-5A. RIG ACCEPTED @ 10:00 HRS, 1/20/92. TAKE ON SEAWATER. ATTEMPT TO PULL BPV. R/U LUB. PULL BPV. BLEED PRESSURE. ATTEMPT TO PUMP DN TBG, ANNULUS. R/U ATLAS. RIH W/ JET CUTTER. SET @ 8210'. CUT TBG. POOH. R/D ATLAS. CIRC OUT DIESEL, CRUDE. RECOVER 350 BBLS. OBSERVE WELL. OK. N/D TREE. N/U BOPE. (4J0132) DAILY: $ 44,065 CUM: $ 44,065 EFC: $ 1,664,000 01/22/92 ( 2) TD: 8200 PB: 8200 SUPV:GTG P/U MILL. MW: 9.6 KC1 TEST BOPE. PULL TBG HGR. CBU. POOH W/ 5-1/2" TBG. RIH W/ SECTION MILL. (4J0132) DAILY: $ 37,765 CUM: $ 81,830 EFC: $ 1,664,000 01/23/92 (3) TD: 8200 PB: 8200 SUPV:GTG WORK SERVCO MILL MW: 9.6 KC1 CONTINE TO PU 4-1/2 DP. TAG PACKER AT 8209'_ SPOT PILL. BEGIN CUTTING SECTION. MILLED FROM 7850 - 7883' PUMP SWEEP. MILL. PUMP SWEEP. ROTATE. (4J0132) DAILY: $ 46,943 CUM: $ 128,773 EFC: $ 1,664,000 01/24/92 ( 4) TD: 8200 PB: 8200 SUPV:GTG RIH W/SERVCO K-MILL MW: 9.6 KC1 STUCK AT 7888' REVERSE CIRC. ROTATE. RESUME MILLING. -- PUMP QUICK-SEAL SWEEP. PUMP SWEEP & DRY JOB. POOH. RIH. POOH. RIH W/BHA #2. (4J0132) DAILY: $ 39,332 CUM: $ 168,105 EFC: $ 1,664,000 01/25/92 (5) TD: 8200 PB: 8200 SUPV:GTG (SlP1) OTHER: 24.0 01/26/92 (6) TD: 8209' (8209) SUPV: GG HOLE ANGLE:30 0 OPEN ENDED DP MW: 9.6 KCl CONTINUE TO RIH W/MILL #2. PUMP SWEEPS. MILL TO 7930' PUMP QUICK SEAL. SWEEP EVERY 2 HOURS. PUMP BACK TO BACK SWEEPS & DRY JOB. POOH W/BHA#2. LD BHA#2. RIH. (4J0132) DAILY: $ 122,117 CUM: $ 290,222 EFC: $ 1,664,000 RIH W/BHA #3 MW: 9.6 VIS: 69 RIH. CBU. PUMP 16 BBLS 11 PPG ARCO SPACER, 39 BBL CMT. 4 BBL SPACER, CHASE W/104 BBLS WATER. CIRCULATE. POOH. CIRC. POOH. TEST BOPS. RIH W/BHA#3. (4J0132) DAILY: $ 95,626 CUM: $ 385,848 EFC: $ 1,664,000 (SlP1) DRIL: 17.5 OTHER: 6.5 01/27/92 ( 7) DRILLING AT 8255' MW: 9.7 VIS: 52 TD: 8255' ( 46) CONTINUE RIH 2/BHA#3. DRILL CEMENT TO 7855' SLIDE & SUPV:GG ROTATE. NOTE: DUE TO DATABASE ERROR, CUMM C~ST SHOULD BE HOLE ANGLE:30 0 $419,047. (4J0132) DAILY: $ 33,199 CUM: $ 419,047 EFC: $ 1,664,000 (SlP1) CIRC: 3.0 DRIL: 10.5 SURV: 1.0 TRIP: 9.5 01/28/92 ( 8) DRILLING AT 8569 MW: 9.6 VIS: 48 TD: 8569' ( 314) DRILL TO 8476'. PUMP SWEEP. CBU. POOH. MU BHA. RIH. SUPV:GG HOLE ANGLE:30 0 (4J0132) DAILY: $ 61,163 CUM: $ 480,210 EFC: $ 1,664,000 (SlP1) CIRC: 1.5 DRIL:' 21.0 TRIP: 1.5 01/29/92 ( 9) POOH. MW: 9.7 VIS: 48 .o TD: 8882' ( 313) SUPV:DW HOLE ANGLE:30 0 DRLG 8569'-8882' . CBU. POOH. NOT. DUE TO A DATABASE PROBLEM, THE CUblMULATIVE COST SHOULD BB $534,685. (4J0132) DAILY: $ 54,475 CUM: $ 534,685 EFC: $ 1,664,000 RECEIVED MAY - ,5 1992 Alaska Oil & Gas Cons. Commissior' Anchorage ACTIVITY SUMMARY for WELL _~OJECT 4J0132 Page: 2 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : DS 14-5A DRLG RIG : NABORS 2ES WO/COMP RIG: NABORS 2ES (S1P1) DRIL: 6.5 OLD PROB: 11.5 RIGS: 0.5 TRIP: 5.5 01/30/92 (10) WOrK PIPE WATER ON MUD MW: 9.7 VIS: 45 TD: 9106' ( 224) CONTINUE TO POOH. L/D DYNA DRILL AND MWD. P/U BIT #3 ON SUPV:DW BHA#4 & P/U HWDP. RIH. DRILL TO 9106'. WORK TIGHT HOLE. HOLE ANGLE:30 0 PUMP LCM PILL. SPOTTED PILL. (4J0132) DAILY: $ 52,111 CUM: $ 586,796 EFC: $ 1,664,000 (S1P1) CIRC: 4.0 -DRIL: 6.0 OLD PROB: 10.5 SURV: 0.5 TRIP: 3.0 01/31/92 (11) DROP SURVEY PO~H MW: 9.6 VIS: 49 TD: 9380' ( 274) RIH. SPOTTED LCM PILL. DRILL TO 9127'. L/D 2 JOINTS & SUPV:DW SORT TRIP. CIRCULATE CUT MUD WEIGHT TO 9.5 RIH. DRILLING HOLE ANGLE:30 0 8-1/2 HOLE TO 9380' CIRCULATE. CBU. RIH. WASH & REAM. CBU. DROP SURVEY, ~OOH. (4J0132) DAILY: $ 52,884 CUM: $ 639,680 EFC: $ 1,664,000 (S1P1) CIRC: 4.0 EVAL: 6.0 RIGS: 1.0 TRIP: 13.0 02/01/92 (t2) POOH TO RUN 7" LINER MW: 9.5 VIS: 45 TD: 9380' (- .. 0) CONTINUE TO POOH FOR E-LOGS. CBU. POOH. R/U WIRELINE. SUPV:DW ' R/D ATLAS. L/D BHA #4 & P/U BHA #5. RIH. CBU. POOH. HOLE ANGLE:30 0 PUMP PILL AT SHOE. POOH. (4J0132) DAILY: $ 72,145 CUM: $ 711,825 EFC: $ 1,664,000 02/02/92 (13) TD: 9380 PB: 0 SUPV:DW POOH W/7" LINER MW: 9.5 Seawater POOH. L/D 4-1/2 DP.~ L/D BHA. R/Y CASING CREW. RUN 13CR80 7" LINER. R/D WEATHERFORD. CIRCULATE. RIH W/7" LINER. (4J0132) DAILY: $ 141,568 CUM: $ 853,393 EFC: $ 1,664,000 02/03/92 (14) TD: 9380 PB: 0 SUPV:DW MW: 9.5 Seawater CONTINUE TRYING TO PULL 7" LINER. WORKED LINER TO BOTTOM. PUMPTED 11.5 PPG ARCO SPACER, 400 SX CLASS G CEMENT. SET 9-5/8 X 7" LINER HANGER & PACKER. REVERSE CIRC. POOH. L/D 3-1/2 DP. P/U 3-1.2 DP. RIH. TEST 7" & 9-5/8 TO 3000 - OK. POOH. L/D DP. (4J0132) DAILY: $ 160,865 CUM: $ 1,014,258 EFC: $ 1,664,000 02/04/92 (15) TD: 9380 PB: 9335 SUPV:DW MW: 8.5 Seawater POOH. L/D 4-1/2 DP & 3-1/2 DP. RUN 4-1/2 CHROME COMPLETION STRING. TEST SSSV TO 5000 PSI. (4J0132) DAILy: $ 278,885 CUM: $ 1,293,143 EFC: $ 1,664,000 02/05/92 (16) TD: 9380 PB: 9335 SUPV:LAP RETRIEVING BALL FROM RHC PLUGR MW: 8.5 Seawater FINISHED RUNNING 4-1/2 TUBING. INSTALLED 7-1/16 X 5-1/8 TREE. PUMPED CRUDE TO FREEZE PROTECT. SET PACKER. RIH TO RETRIEVE BALL FROM RHC PLUG CATCHER. (4J0132) DAILY: $ 0 CUM: $ 1,293,143 EFC: $ 1,664,000 02/06/92 (17) TD: 9380 PB: 9335 SUPV:LAP RIG RELEASED. MW: 8.5 Seawater RECOVER PKR SET PLUG. R/D SLICKLINE. TEST PKR. OK. INSTALL BPV. RIG RELEASED @ 09:00 HRS, 2/5/92. (4J0132) DAILY: $ 8,753 CUM: $ 1,301,896 EFC: $ 1,301,896 SF"'-'~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING 14-05A PRUDHOE BAY ALASKA COMPUTATION DATE: 2/ O, ISflV4L 5/92 DATE OF SURVEY: 01/29/92 NWD SURVEY JOB NUMBER: AK-MD-920107 KELLY BUSHING ELEV. = 73.00 OPERATOR: TILLEY FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES DG MN DEGREES DG/IO0 NORTH/SOUTH EAST/WEST VERT, SECT. 7850 7844.00 7771.00 1 45 N 39.50 W .00 48,00N 193.00W 8014 8007,34 7934.34 7 56 N 13.62 W 3,92 60,97N 197.27W 8106 8098.03 8025.03 11 22 N 17,92 W 3,80 75,78N 201.56W 8200 8189.53 8116,53 15 2 N 10,98 W 4.25 96.58N 206.73W 8294 8279.48 8206.48 18 45 N .63 W 5.07 123,68N 209.22W 143,92 157.16 171 .97 192.30 216.52 8388 8367.49 8294.49 22 21 N 2,38 E 3,99 156.65N 208.65W 8484 8455,48 8382.48 24 43 N 1.40 E 2.51 194,96N 207.40W 8578 8540.09 8467.09 26 53 N .38 W 2,44 235.88N 207.06W 8671 8622.55 8549.55 28 13 N 5.50 W 2.92 278.80N 209.31W 8827 8758.86 8685.86 30 6 N 16.55 W 3,65 353.09N 224.00W 244.05 275,73 310.10 347.55 418.15 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 418.15 FEET AT NORTH 32 DEG. 23 MIN. WEST AT MD = 8827 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 327.61 DEG, RECEIVI D MAY - § ltlg _ ~laska O~l & uas 6ons. Commlssio~ Anchorage PRUDHOE BAY 14-05A PRUDHOE BAY ALASKA COMPUTAT"r. Oh! DRILLING DATE: 2/ S~'r-SUN ©RZLLZNG SERVICES A~,iCHORAGE ALASKA PAGE DATE OF SURVEY: 01/29/92 5/92 JOB NUMBER: AF,-ND-920107 KELLY BUSHING ELEV. = 73.00 OPERATOR: TILLEY FT. INTERPOLATED VALUES FOR EVEN !000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL NEASD VERTICAL VERTICAL RECTANGULAR COORDINATES ND-TVD VERTICAL DEPTH OEPTH OEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 7850 78m~,O0 7771.00 48.00 N !93.00 W 6.00 8827 8758.86 8685.86 353.09 N 22A.00 \^1 68.14 62.14 THE CALCULATION PROCEDURES ARE BASED ON 'FHE USE OF MINIMUm4 CURVATURE ~!ETHOD. sp.-~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 PRUDHOE BAY DRILLING 14-05A PRUDHOE BAY ALASKA COMPUTATION DATE: 2/ 5 /92 DATE OF SURVEY: 01/29/92 JOB NUMBER: AK-ND-920107 KELLY BUSHING ELEV. = 73,00 FT. OPERATOR: TILLEY INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA NEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST ND-TVD VERTICAL DIFFERENCE CORRECTION 7850 7844.00 777!.00 48.00 N 193.00 W 6.00 7879 7873.00 780'0,00 49,00 N 193.60 W 6.02 .02 7979 7973.00 7900.00 56,75 N 196.19 W 6.38 .35 8080 8073.00 8000.00 71,22 N 200.13 W 7.52 1.14 8182 8173.00 8100.00 92,37 N 205.87 W 9.92 2.40 S287 8273.00 8200,00 121.52 N 209.18 W 14.17 4.25 8393 8373.00 8300.00 !58.92 N 208.55 W 20.96 6.79 8503 8473,00 8400,00 203.03 N 207.20 W 30.29 9.33 86t4 8573.00 8500.00 252,75 N 207.50 W 41.99 11.70 8728 8673.00 860.0.00 305,95 N 212.95 W 55.41 13,42 8827 8758.86 8685.86 353,09 N 224.00 W 68.14 12.72 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEARES¥ 20 FOOT ND (FROH RADIUS OF CURVATURE) POINTS ORIGINAL PRUDHOE BAY DRILLING DS14-05~'A RE ¢EIVED MAY - 5 1992 Oil & Gas Cons. Anchorage GREAT LAND DIRECTIONAL DRILLING, INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY PRUDHOE BAY DRILLING COMPANY DS 14-05ST WELL NAME PRUDHOE BAY LOCATION AL192D5 MWD 02/04/92 JOB NUMBER BOB MAGOS TYPE SURVEY DIRECTIONAL SUPERVISOR NAME TITLE SIGNATURE 7850.0 FT. 9380.0 FT. DEPTH INTERVAL DATE SURVEY TAKEN FROM TO 01/24/92 01/31/92 FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. t I } } I i } ! I ! I ) ! I ! ! ......... 1 ! ) REAT LAND DIRECTIONAL DRILLING, INC. lient .... : 'ield ..... : 'ell ...... : ection at: :ngineer..: PRUDHOE BAY DRILLING PRUDHOE BAY DRILL SITE 14 DS 14-05 SIDE TRACK N,11.40,W BOB MAGOS MEAS INCLN DEPTH ANGLE Computation...: Survey Date...: RKB Elevation.: Reference ..... : Magnetic Dcln.: RECORD OF SURVEY (Calculated from a tie-in station at 7850 MD) 02/04/92 VERTICAL-DEPTHS BKB SUB-SEA MINIMUM CURVATURE 01/31/92 73.00 ft 30.07 E 7850 1.75 7844.0 7771.0 8014 8.00 8007.3 7934.3 8106 11.40 8098.0 8025.0 8200 15.00 8189.5 8116.5 8294 18.70 8279.5 8206.5 SECTION DIRECTION RELATIVE-COORDINATES DISTNCE BEARING FROM-WELL-HEAD .84.6' N 39.50 W" 98.2 N 13.60 W 113.7 N 17.90 W 135.1 N 11.00 W 162.1 N 0.60 W 47.0 N 195.0 W 60.0 N 199.3 W 74.9 N 203.6 W 95.7 N 208.8 W 122.7 N 211.2 W CLOSURE DISTNCE BEARING DL /lOO 200.6 N 76.45 W <TIE 208.1 N 73.23 W 3.95 216.9 N 69.80 W 3.78 229.7 N 65.37 W 4.17 244.3 N 59.84 W 5.06 8388 22.40 8367.5 8294.5 8483 24.70 8454.6 8381.6 8578 26.90 8540.1 8467.1 8671 28.20 8622.6 8549.6 8765 29.00 8705.1 8632.1 194.3 N 2.40 E 231.2 N 1.40 E 271.7 N 0.60 W 314.2 N 5.50 W 359.1 N 12.40 W 155.7 N 210.6 W 193.6 N 209.4 W 235.0 N 209.1 W 277.9 N 211.5 W 322.3 N 218.5 W 261.9 N 53.53 W 4.09 285.2 N 47.24 W 2.46 314.6 N 41.67 W 2.49 349.2 N 37.27 W 2.81 389.4 N 34.14 W 3.61 8826 30.10 8758.2 8685.2 389.2 N 13.60 W 9325 30.00 9190.4 9117.4 636.1 N 24.00 W 9380 30.00 9238.0 9165.0 662.9 N 25.20 W 351.6 N 225.3 W 587.3 N 305.5 W 612.3 N 316.9 W 417.6 N 32.65 W 2.05 662.0 N 27.48 W 1.04 689.5 N 27.37 W 1.09 Survey Codes: I/SINGLE SHOT 3/MWD 8/TIE-IN J/PROJECTED DS1405ST B1.24) ) } } ! } ! ) ! ! 1 } ! ! ! ! ] .... ! ) ,S 14-05 SIDE TRACK Page 2 02/04/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL (Calculated from a tie-in station at 7850 MD) IUBSEA MEAS INCLN IEPTH DEPTH ANGLE TVD BKB 8000 8081 10.46 8073 8100 8183 14.35 8173 8200 8287 18.43 8273 8300 8394 22.54 8373 8400 8503 25.17 8473 8500 8615 27.42 8573 8600 8728 28.69 8673 8700 8843 30.10 8773 8800 8959 30.07 8873 8900 9074 30.05 8973 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 8 8 N 16.71 W 70.32 N 202.11 W 10 2 N 12.25 W 91.47 N 207.94 W 14 4 N 1.35 W 120.57 N 211.24 W 21 7 N 2.34 E 157.98 N 210.55 W 30 9 N 0.97 E 202.20 N 209.23 W 42 '12 N 2.55 ,W 251.85 N 209.61 W 55 13 N 9.71 W 304.96 N 215.09 W 70 15 N 13.96 W 359.92 N 227.31 W 86 16 N 16.37 W 415.82 N 242.46 W 101 16 N 18.77 W 470.95 N 259.91 W 9000 9190 30.03 9073 9100 9305 30.00 9173 117 16 N 21.18 W 525.16 N 279.62 W 132 15 N 23.59 W 578.34 N 301.52 W ~S 14-05 SIDE TRACK Page 3 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 02/04/92 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DL/ DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 100 8000 7.47 7993 7920 96 N 15.81 W 58 N 199 W 207 N 73.72 W 3.9 9000 30.07 8909 8836 476 N 17.23 W 436 N 248 W 501 N 29.70 W 1.0 PRUDHOE BAY DRILLZN6 #arker Identification HD A) TIE-IN 7850 47 N B) 'iD 9380 6].E N E/W 3].7 ~ DS 14-05 SIDE TRACK PLAN VIEW CLOSURE. · 68§ ft at N 27.37 W DECLINATION.' 30.07 E SCALE · ! inch = 100 feet DRANN · 02/t0/92 Great Land Directional Drilling ............................... : ................................... ] ...............................i ......................... ; ........................................................ I ...................................................... g ........................ ~ ............................................................................................... .............................................................................. ! ................................... ~ .................................. ~ .............................. : ....................... ~ ................................................................ i ~ _..~ .................................................................... I ........... : T'~ ............................................... I ............ - r'-'% .......................~ ......................................... I ......... ~ , ~ .......: .................................. I .......... .............. ~' ............................... I ...... , . ~ SIDE~A~ .... ~ ............................ r .............. ~ ' ' ~ :.--"--: -i-=--: L.__. ........................ 4 ............... I ........ ~ ................. h .... ; ........ : .............. I ' ~ ............. i ............... -I iO 600 ' 550 500 45O 400 350 3OO E.-.50 200 t50 lO0 50 0 5O <- WEST · EAST -> ~ PRUBHOE BAY DRZLLZN6 DS 14-05 SIDE TRACK VERTICAL SECTION VIEH Section at: N tt.40 W TVO Scale · 1 inch = 300 feet Oep Scale · t inch = 300 feet . , ---~ .......... ' ........ ~ Drawn .... · 02/10/92 : } T Marker Iden[lflca~lon &) TIE-IN BI TO MD BKB SECTN INCLN 7850 7844 85 t.75 9380 9238 663 30..00 ;.. 0 t50 300 450 600 -- Section De arture l~.alO ICJ 9~ 0~J:4(15S7 ~..~B 8:3~. ~J~ ZJ 750 900 tO50 // ARCO Alaska, Inc. P. O2~ox 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS ?~'/ 14-2 3-3-92 PITS ?~-f~- 14-3 2-10-92 Leak Detect 72~? 14-4 2-11-92 Prod Prof ~z~-/ }14-5A 2-29-92 Prod Prof * ~14-5A 3-17-92 PITS ? ~,~14-6 2-13-92 Jewelry ~ *~*~16-9A 3-12-92 PITS /~ ~ 16-9A 2-24-92 Jewelry ~/-~ ~ 16-13 3-16-92 Prod Prof ~'-~I/16-15 2-25-92 Prod Prof ~£~t/~ 16-21 2-24-92 Prod Prof ~ ~-/ 16-22 3-8-92 PITS ~/- ;~/17-8 2-26-92 InJ Profile ~?/ 18-16 2-20-92 PITS Rim 1, 5" Camco Run 1, 5" Camco R-n 1, 5" Camco R-n 1, 5" Camco R._n 1, 5" Camco Rnn 1, 5" ~CO Run 1, 5" Camco R-_n 1, 5" Cai:nco R.- 1, 5" Camco Rl~n 1, 5" Camco R-n 1, 5" Camco Rl~n 1, 5" Camco R11~i 1, 5" Camco R.n 1, 5" Caxnco Please sign and return the RECEIVED BY ~ Have A Nice Day! Sonya Wallace ATO-1529 attached copy as receipt of data. ~ ~ C E IV APR 5 0 ~992 Alaska Oil/& (hs Cons. APPROVED~~f___~nch°':ag~ Trans# 92080 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALAS~ TEXACO The correct well name for this log is 14-5~ The correct well name for this log is 16-9A. ARCO Ahsk~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-6-92 REFERENCE: ARCO CASED HOLE FINAL~ ?~ ?? t4'7 2-7-92 USIT-Cement 4-7 ~/ 2-7-92 USIT-Corrosion 5-6 ~/ 2-11-92 Collar-Perf 9-44 ~ 2-12-92 Collar-Perf ~'~ ** 11-3A J 2-9-92 CNL $~ ~ 13-25 ~ 2-22-92 CCL (Peri) t ' 14-5A ~ 2-9-92 CNL ffz~t 14-5A ~ 2-10-92 Collar-l~i~ ~//~ 18-14 ~ 2-20-92 Dual Burst TDTP Color Color Run R~n Run Run Run 2, 5' 2, 5' 1.5" I, 5" 1, 5" 1, 5" 1, 5' 1, 5" 1, 5' Please sign and return the attached copy as receipt of data. Have A Nice Day~ Sonya W-Il. ce ATO-1529 Sch Sch Atlas Attas Sch Atlas Sch Atlas Sch # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL #PHILLIPS PB WELL FILES R&D #BPX # STATE OF ALAS~ TEXACO ** The correct APl# for 11-3A is 50-029-20666-01. RECEIVED MAR 12 1992 Alaska Oil & Gas Cons. Commission Anchorage P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-6-92 REFERENCE: ARCO DIRECTIONAL DATA '~/"'/Y';'a".:~W~ 4-79T 2/8-X7/92 MWD Directional Survey 1 l-lL, q 1/24-~1/99 MWD Directional Survey ~> ~/ X4-SA X/24*3X/92 MWD Directional Survey Job#AL292D6 GLDDI Job~AL 12911)47 GLDDI Job#AL192D5 GLDDI Please sign and return the attached .co~py u receipt of data. RECEIVED BY Have A Nice Day! Sonya Wallace ATO-1529 CENTRAL FILES CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON MOBIL PHILLIPS # PB WELL FLS (2 COPIES] R&D # BPX # STATE OF ALASKA TEXACO RECEIVED MAR 1 2 1992 Alaska 011 & Oas Cons. Commission Anchorage ARCO Aluka, Inc. P.O.Bo~' 100360 Anchorage, Alaska 99510 DATE: 2-21-92 REFERENCE: ARCO M&GNETIC TAPE(S) WITH LISTINGS / * 2,M 1/8-13/93 ? MWD:~~ Runs 10-18 Job~853 ** ~ 11/9-13,/91/ MWD Rmm 1~ Job/~1112~ 14-5A 1-31-93 / DIFL/AC Teleco 8perry Atlas Atlas Please atgn and return the attached copy u receipt of dat~ RECEIVED BY Have A Nice Day[ Sonya Walhce ATO- 1529 CE~ ]m.Z,S (C~ CHE~ON D'&M # DEDE SCHWa, RTZ (OH/GCT) # ~ON -~ ~~ON MO~ # p~z.rps PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO * The corrected API# for 2-34 is 50-029-22234. ** The corrected API# for 2-35 is 50-029-22222. RECEIVED FEB 2 5 1992 Alaska 0ti i Gas Cons. Commission Anchorage ARCO Alask~ Inc. P.O.Box 100,360 Anchorage, Alaska 99510 DATE: 2-21-92 REFERENCE: ARCO OPEN HOLE FINALS (.14-5A 2-3-93 SSTVD Run 1, l"&2" Atlas 2-3-92 BHCA-GR Run 1. :~'&5" Atlas 2-3-92 DIFL-GR Run 1.2"&5" Aths 2-3-92 CNL-GR Run 1, 2"&5" Atlas 1-31-92 SSTVD Run 1, 1'&2" Atlas 1-31-93 BHCA-GR Run 1, 2"&5" Atlas 1-31-92 DIFL, GR Run 1, 2"&5" Atlas Please sign and return the attached copy as receipt: of data. RECEIVED BY.. /~~~_/~-~ Sonya Wallace APPROVED ATO- 1529 Trans# 9203~/' # CENTRAL'FILE8 # CHEVRON #D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLI3~ # PB WELL ~ R&D #BPX # STATE OF ALASKA #TEXACO RECEIVED FEB 2 5 1992 Anchomg~ ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 22, 1992 Mike Zanghi Area Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well Name: DS 14-5A ARCO Alaska, Inc. Permit No. 92-01 Sur. Loc. 1614'FNL, l154'FEL, Sec. 09, T10N, R14E UM Btmnhole Loc. 969'FNL, 1471'FEL, Sec. 09, T10N, R14E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope Pager at 659-3607. Sincerely,r---~-~c--~-~ ~man Alaska Oil~and'Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA JIL AND GAS CONSERVATION CL. .,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redril117111b. Type of well. Exploratory l-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] SingleZone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 73'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchorac~e. Alaska 99519-6612 ADL 28312 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(see 20 ^^c 25.o2s) 1614' FNL, 1154' FEL, SEC. 09, TION, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1216' FNL, 1422' FEL, SEC. 09, TION, R14E DS 14-5A U-6300610 At total depth ,9. Approximate spud date Amount 969' FNL, 1471' FEL, SEC. 09, TION, R14E January 18, 1992 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(uDandmVD) p rop~l~y~ line 28313 @ 4288' feet DS 14-36 @8800'/2000' feet 2560 9384Y9229feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAc 25.035 (e)(2)) Kickoff depth z45o'feet Maximum hole angle 31 o Maximum surface 3330psig At total depth (TVD) 118. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7-5/8" 29. 7# L-80 SFJP 700' 7600' 7594' 8300' 8284' 408 cuft Class "G" 8-1/2" 7" 29# 13Cr-8~ Fox 1084' 8300' 8284' 9384' 9229' 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~ [~ I~, [~ ! V Present well condition summary Total depth: measured 9443'feet Plugs (measured) JAN 1 7 t992 true vertical 9435'feet Effective depth: measured 9318'feet Junk (measured) Alaska 0il & Gas Cons. true vertical feet ~,~h0rage Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 124' 20" 300 sx 124' 124' Surface 2663' 13-3/8" 423 sx Permafrost 2736' 2736' Intermediate 8559' 9-5/8" 1000 sx 8632' 8625' Production Liner 1112' 7" 325 sx 9433' 9425' Perforation depth' measured 8850'-8910', 8912'-8940', 8951'-8989', 8998'-9009' true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l'~l Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby cert~y t~at the foregoing is true and correct to the best of my knowledge Signed'!//~(c,,[',~ ,~/~ Title AreaDrilling Engineer Date/-'(7,J'~'~' ~--~ ") Commission Use Only Permit Number IAl~umber ~ IApproval date JSee cover letter ~..~ ---D / J50-~,~ ~ --~) .~ ,~ ? ..-. O/ I //~-.,~ - ~ ~ If°r other requirements Conditions of approval Samples required [] Yes I~ No Mud log required []Yes rl~ No Hydrogen sulfide measures ~ No Direction~.i survey requ~recl ~Yes [] Required w~re f~r B(~/ [~"2.~1; 1-13M; ~SM; []1OM; []15M~/- Other: ~ ~ ~ "~._ ~ ..... e~.~.~~_ ~.~~ ...... Commissioner by order of Approv Ins commission Date./-/....~.... Form 10-401 R, Submit ~ icate PROPOSED~DRILLING AND COMPLETION._..PRQ. GRAM WELL 14-5A [9-10-14] OBJECTIVE: A redrill is requested to replace the existing 14-5 wellbore that is shut-in due to a high watercut. The objectives of the 14-5 sidetrack are to plug and abandon the original perforations, pull the 5-1/2" 17# L-80 PC tubing, section mill a 80' window in the 9-5/8" casing, lay a cement plug across the section, kickoff and drill a new 8-1/2" hole to a target 330' NNW from the original wellbore, run open hole logs, run and cement a 7-5/8" 29.7# 13CR x 7" 29# 13CR liner, recomplete with 4-1/2" 13CR tubing, and pedorate the pay zone. CURRENT STATUS: The DS 14-5 well is currently shut-in due to a high watercut (33 BOPD, 98% WC, 3000 GOR). The well is believed to be located in a highly fractured area near a dissipating fault. These fractures are thought to be linked together and in communication with the aquifier. Previous cement squeezes have been unsuccessful shutting off the communication problem. The DS 14-5 well was spudded 1/16/79 with the Parker #176 rig. Surface casing (13- 3/8") was set at 2736' MD/TVD. Intermediate casing (9-5/8") was set and cemented at 8632' MD / 8625' TVD. A 7" production liner was set at 9433' MD / 9435' TVD. The well was completed with 5-1/2" tubing and brought on line in May, 1979 at 8800 BOPD at 11% WC. PROPOSED PRE-RIG PROGRAM: (Operation to be Approved Under Sundry Notice) Rig up coiled tubing unit. Cement squeeze all existing perforations and leave at least 100' of cement above the upper perforation at 8850'. RU slickline unit. RIH and confirm cement top. RIH with jet cutter and cut 5-1/2" tubing just above the PBR. Circulate well over to seawater and freeze protect well to 2000'. Set 5-1/2" BPV. A waiver for state regulation 20 ACC 25.105(h)(2) is requested for the placement of a liner top cement. As discussed in the 12/17/91 meeting between the AOGCC and BP/ARCO, the kick-off plug will serve a dual purpose as kick-off and liner top plug. The kick-off plug is to be set 7600' - 8030' MD and will be only 301' feet from the existing 7" liner top at 8331' MD. / CfflVED JAN 1 7' '~992 Alaska Oil & Gas Cons. Commission Anchorage PROPOSED~.DRILLING AND COMPLETION...PROGRAM WELL 14-5A [9-10-14] PROPOSED DRILLING PROGRAM: (Operations to be Approved Under Drilling Permit) The milling/drilling fluid program will consist of a 9.5 - 9.8 ppg water based mud in the 8- 1/2" hole. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3330 psi based upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. The plan consists of pulling the 5-1/2" tubing and milling an 80' section in the 9-5/8" casing from 7850'- 7930'. A cement kick-off plug will be set in the 9-5/8" casing across the window area from 7600'- 8030'. An 8-1/2" hole will be directionally drilled to TD. A 7 x 7-5/8" liner will be run from TD to 250' inside the 9-5/8" casing kickoff point and cemented with Class G cement. The liner will be cleaned out to the 7" landing collar. The mud will be changed over to filtered and inhibited seawater completion fluid. The 9-5/8" casing and 7" liner and lap will be tested to 3000 psi. A 4-1/2" 13CR tubing completion will be run with the production packer in the 7" liner, A subsurface safety valve with dual control lines will be located about 100' below the base of permafrost. The well will be freeze protected with diesel. The production packer will be set and tested. A production tree will be installed and tested. The well will be perforated through tubing after the rig leaves. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. I ECEIVED JAN 7 7 OiJ & ~as Cons. Comrnissio~ Ancherage PRELIMINARY WELL PLAN Well' 14-5A [9-10-14] PBU APl No.' 50-029-20327-00 LOCATION: Surface: Target: BHL: 1614' FNL, 1154' FEL, Sec. 9, T10N, R14E 1216' FNL, 1422' FEL, Sec. 9, T10N, R14E 969' FNL, 1471' FEL, Sec. 9, T10N, R14E ESTIMATED START: 18 January, 1992 OPR. DAYS TO COMPLETE' CONTRACTOR: 15 (5 days prep & mill, 5 days drill, 5 days complete) Nabors 2ES MAX ANGLE / SECTION COURSE / KOP / BUILD RATE' 31° / N11.35°E / 7850 / 4° Item TVDss MD(BKB) Mud Wt. 30" CONDUCTOR 73' 13-3/8" SHOE 2679' KOP 7771' TOP SAG RIVER SANDSTONE 8638' CURRENT GCC 8730' TOP SADLEROCHIT 8730' TARGET 873O' TOTAL DEPTH 9156' 73' N/A 2736' N/A 7850' 9.5 8782' 9.8 8889' 9.8 8889' 9.8 8889' 9.8 9384' 9.8 LOGGING PROGRAM: Ooen Hole - Record all logs on magnetic tape where applicable. 8-1/2" Hole: Resisitivity/CNL/Sonic/GR/SP ! ECEIVED MUD WEIGHT CALCULATIONS: Mud Wt. (8-1/2" Hole): 9.8 ppg. Pore Press. Sag River: Pore Press. Sadlerochit: 3584 psi. 3622 psi. OB Sag River: OB Top Sadlerochit: Current GCC: 818 psi. 827 psi. 8730' TVD ss Top Sag River Top Sadlerochit 8638' TVD ss 8730' TVD ss LINER DETAILS' CASING 7-5/8" 29.7# L-80 SFJP 7" 29# 13CR-80 FOX A combination 7-5/8" x 7" liner is planned' DEPTH BURST 7600'-8300' MD (7594'-8284' TVD) 8300'-g384' MD 6890 psi 8160 psi (8284'-9229' TVD) COLLAPSE 4790 psi 7030 psi TENSILF 490 klbs 676 klbs CEMENT CALCULATIONS: 7"x 7-5/8" LINER; Measured Depth: Depths: Basis: Total Cement Vol: 7600' (Hanger) - 9384' (Shoe) 7" (8300'-9384') and 7-5/8" (7600' - 8300') 1.35 X Ann. vol. (9384' to 7850') + 150 cu ft for lap & excess 408 cu ft or 352 sxs of Class G blend @ 1.16 Cu ft/Sk TUBING DETAILS' 4-1/2" 12.6# 13CR-80 Fox RECEIVED Alaska Oil & Gas Cons. Oom~tss'tot~ Anchorage 14-5A MUD PROGRAM DEPTH DENSITY PV YP INT 10 MIN FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) TYPE 7850' 9.5 10 10 5 7 8 0 5 Water to to to to to to to to to Base 9384' 9.8 16 15 10 15 5 0 7 Mud RECEIVED JAN 1 7 t992. AJaska 0il & Gas Cons. Commission Anchorage GREAT LAND DIRECTIONAL DRILLING, INC. Corporate Office 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING Well ......... : DS 14-05A Field ........ : PRUDHOE BAY DRILL SITE 14 Computation..: MINIMUM CURVATURE LOCATIONS LEGAL DESCRIPTION Surface ...... : 1614 SNL 1154 WEL S09 T10N R14E UM Tie-in ....... : 1566 SNL 1347 WEL $09 T10N R14E UM Target ....... : 1216 SNL 1422 WEL S09 T10N R14E UM BHL .......... : 969 SNL 1471 WEL S09 T10N R14E UM Prepared ...... : 01/15/92 Section at .... : N,11.35,W KB elevation..: 73.00 ft X ASP ZONE 4 Y 675327.78 5938728.35 675133.80 5938771.91 675050.00 5939120.00 674994.69 5939366.14 PROPOSED WELL PROFILE · STATION MEAS INCLN IDENTIFICATION DEPTH ANGLE VERT-DEPTHS SECT BKB SUB-S DIST TIE-IN 7850 1.75 7844 7771 7900 3.63 7894 7821 8000 7.57 7993 7920 KINGYAK 8037 9.05 8030 7957 8100 11.55 8092 8019 END BUILD & TURN SAG RIVER SHUBLIK TOP SADLEROCHIT TARGET TSAD ZONE 3 8200 15.54 8189 8116 8300 19.54 8284 8211 8400 23.54 8377 8304 8500 27.53 8468 8395 8578 30.63 8535 8462 8782 30.63 8711 8638 8810 30.63 8735 8662 8889 30.63 8803 8730 8889 30.63 8803 8730 9144 30.63 9023 8950 9168 30.63 9043 8970 9234 30.63 9100 9027 9384 30.63 9229 9156 HOT OWC TD DIRECTION REL-COORDINATES DL/ BEARING FROM-WELLHEAD 100 85 N 39.52 W 48 N 193 W <TIE 87 N 23.68 W 50 N 194 W 4.0 97 N 16.41 W 59 N 197 W 4.0 102 N 15.56 W 64 N 199 W 4.0 114 N 14.12 W 75 N 201 W 4.0 137 N 13.00 W 98 N 207 W 4.0 167 N 12.32 W 128 N 214 W 4.0 204 N 11.87 W 163 N 221 W 4.0 247 N 11.54 W 206 N 230 W 4.0 285 N 11.35 W 243 N 237 W 4.0 389 N 11.35 W 345 N 258 W 0.0 403 N 11.35 W 359 N 261 W 0.0 443 N 11.35 W 398 N 269 W 0.0 443 N 11.35 W 398 N 269 W 0.0 573 N 11.35 W 526 N 294 W 0.0 585 N 11.35 W 537 N 297 W 0.0 619 N 11.35 W 570 N 303 W 0.0 695 N 11.35 W 645 N 318 W 0.0 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ~~0 E B A Y D R I L~~ Marker Identification MD BKB 8ECTN INGLN A) TIE-IN 7850 7844 85 i.75 B) END BUILD ~ TURN 8578 8535 885 30.63 C) TARGET 8889 8803 443 30.§3 O) TO 9384 9289 695 30,63 DS i4-05A VERTICAL SECTION VIEW Section at: TVD Scale.: Dep Scale.: Dra~n ..... : t~.35 ~ inch = 200 feet ~nch = 200 reef 01/~5/92 AVERAGE ANGLE 30.83 DEGREES ORIGINAL WELL o~ ii§O lBO0 0 ~00 800 300 400 500 800 700 800 900 lO00 Section Departure OE BAY DRZ NG Marker Identification Al TIE-IN 8] END RUILO ~ TURN O) TARGET 0) TO MO N/S E/M 7850 48 N i§3 M A 8578 243 N 237 M 8809 398 N 889 M 9384 845 N 3iR M DS 14-05A PLAN VIEN CLOSURE ..... : 720 ft at N 26.25 W DECLINATION.: 30.00 E SCALE ....... : i inch = i50 feet DRAWN ....... : 01/15/§2 Great Land Directional D~Jllin~ TARGET iSQ ~T RADIUS ORIGINAL NE~ S_-~ ........................................ 585 450 375 300 225 i50 75 0 75 lSD 225 300 375 450 585 <- NEST: EAST -> NABORS RIG NO. 2E$ MID SOLIDS C.ONTROL EQUIPMENT 2 - Continental Emsco Fl000 Mud Pumps 1 - Derrick FIoLine Cleaner Shale Shaker 1 - Mud Cleaner 1 - DRECOGas Buster 1 - Pioneer Sidewinder Mud Hopper 1 - 5 HP Flash Mixer Agitator 3 - Abcor 10 H P Agitators 1 - 50 bbl. Trip Tank 1 - Recording frilling fluid pit level indicator with both visual and audio warning devices at driller's console. 1 - Drilling fluid flow sensor with readout at driller's console RECEIVED ,JAN 1 7 !,992 Alaska Oil & Gas Cons. Comrnissior~ Anchorage C OMPAR'i'MENT CAP~ C. JT'Y I CAPAC,FrY ~ EA.ICT1ON ?ANK i ,co :) PIM. TANK ::) 11,4J~C'T10H TANK 245 /'~ BRINE TANK~ ~4~2~ BB~ SEPARATOR ~ E~f"-Jg'~ LI~E Itl et.rt"t'E~Y VA~.V~ I~1 ~JCT~N VALVE IL-.' - -- Il--- I~l'X3 SYSTE~ FLOWS'~'EET 5,00.0 PSI BO' '-"STAOK ANNULAR PREVENTER 7 PIPE RAMS 6 BLIND RAMS DRILLING SPOOL PIPE RAMS 3 TUglNG HEAD 2 1. 13-3/8' CASING HEAD :2. 5000 PS1 TUBING HEAD 3.13-5q~ - 5000 PSI PIPE 4. 5000 I~1 DRILLING SPOOL 5. 13-5/~' · 5000 P~i BLIND 13-5/8" . ,5000 PSI PIPE F~M~ 7, 13-5r8' . 5000 PSI ACCUMULATOR CAPACITY TES~ 1. CHECK ANO FILL AGCUMLX.ATOR RESERVOIR TO F~OPER LEVEL WrTH HYDRALIJC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI D(3WNSTlqEAM OF THE REGULATOR. 3. OB.SERVE TIME, THF_.N GLO.SE ALL UNITS SIMULTANEOUSLY AND RECORO THE TIIIv~ AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WTTH CH. ARGING PUI~P OFF, 4, RECQt=ID ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONO,~J CLOSING TIlV~ AND 1200 PSI REMAINING PRES.SURE. BOP STACK TEST_ 1. FILL BOP STACK ANO MANIFCLD WITH ARCTIC DIESEL IN WINTER OR SEAWATER DURING SUMMER MONTHS. 2. CHECK THAT ALL ~WN SCREWS ARE FULLY RETRACTED. PREDETE,=iMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELI.HEAD, RUN IN LOCK~.DOWN SCREWS IN HEAD, 3, CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD, 4, TEST ALL COMPONENTS TO 250 PSi AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 2500 PSi AND HOLD FOR 10 MINUTES. Bt ~_n TO ZERO PSI. 6, ~ AIk,I4ULA,~ PREV~ AND CLOSE TOP SET OF PIPE 7, INCR~ PRES.SURE TO 5000 PSI AND HOLD FOR 10 MINUTES. B, CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRES,SURE TO ZF. RO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZEFIO PSI DOWNSTR~ BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKCN=F RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAM~ AND TESTTO 500(I PEA FOR 10 MINUTES. BLEED TO ZERO PSI, 10. OPEN BLIND RANIS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION, 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCI~S AND INSIE~ BOP TO 5000 PS1 WITH KOOMEY PUMP 13, RECORD TEST INFORMATION ON Bt.O~2~)IJTPREVENTF_RTEST FORM. AND SENO TO DRILLING SUPERVISOR. 14, PF_RFORM CONI=LETE ~ TEST ONCE A WEEK AND FUNCTIONALLY OPF. FIATE ROPE DAILY FOR DRE.LING OPERATIONS, FOR COMPLETIC,'q, WOFIKOVEFI OPEY:IATION~, PERFORM COMPLETE BOP TEST EVERY DAYS AND FUNCTION TEST EOP WF_EKLY. RECEIVED JAN 1 ? t~92 Alaska 0il & Gas Cons. Commission DAM 1 1/20/89 BOP SCH (FOR: NAB 2ES) ITEM (1) Fee _ (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** [2 thrum8];' ' ' 3. 4. (3) ['9 thru z- [10 & 13] [14 thru 22] z,¢.. [23 thru 28] (5) BOPE (6) Other Company (6) Addl Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~ber appropriate .......................................... Does well have a unique name & nc~nber ................................ ,~ ? Lease & Well ~ ~z.. YES NO Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. ./ REMARKS [29 thru ~1] 30, 31, Is a diverter system required ......................................... ~ Is drilling fluid program schematic & list of equipment adequate ..... /7~ ,, Are necessary diagrams & descriptions of ~~-~--~'BOPE attached .... ~, Does BOPE have sufficient pressure rating -- test to~o.o.psig ..... ~ .. Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... ~ FOR EXPLORATORY & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. ,, If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. 0 IZ ~"~0 geology: eng]neer ing~, . DW~ MTM ,~1/ LCS rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT oN/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' Well History File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi ,, No special *effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER , ****************************** * ............................ ....... SCHLUMBERGER * ****************************** Oil & ':'"' COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S 14-05A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292032701 REFERENCE NO : 97528 MICROFILMED LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: * * * * REEL HEADER ** * * SERVICE NAME : EDIT DATE : 97/12/14 ORIGIN : FLIC REEL NAME : 97528 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC, PRUDHOE BAY, DS 14-05A, API #50-029-20327-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/12/14 ORIGIN : FLIC TAPE NAME : 97528 CONTINUATION # : 1 PREVIOUS TAPE : CO~ff4ENT : ARCO ALASKA INC, PRUDHOE BAY, DS 14-05A, API #50-029-20327-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D. S 14-05A API NUMBER: 500292032701 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 12-DEC-97 JOB NUMBER: 97528 LOGGING ENGINEER: J. PAWLUK OPERATOR WITNESS: M. REYNOLDS SURFACE LOCATION SECTION: 9 TOWNSHIP: 1 ON RANGE: 14E FNL: 1614 FSL : FEL: 1154 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 72. O0 DERRICK FLOOR: 71. O0 GROUND LEVEL: 44. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT)WEIGHT (LB/FT) 1ST STRING 8.500 7. 000 9380.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 31 -JAN- 92 LOGGING COMPANY: ATLAS BASELINE DEPTH .............. 88888.0 8940.0 8937.5 8921.5 8921.0 8906.0 8892.5 8892.0 8890.0 8887.5 8880.5 8875.5 8875.0 8872.0 8870.5 8868.5 8868 0 8865 5 8860 0 8858 0 8855 5 8852 5 8851.0 8850.5 8845.5 8839.0 8838.5 8830.0 8825.0 8818.0 8817.0 8814.5 8809.0 8808.5 8796.5 8796.0 8792.0 8789.0 8786.0 8784.5 8779.5 8773.0 8770.5 8769.5 8768.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88884.5 88886.0 8934.0 8919.0 8892.0 8880.5 8874.0 8871.5 8868.0 8858.0 8853.5 8849.5 8837.5 8831.0 8818.0 8811.0 8797.0 8794.0 8790.0 8786.5 8779.5 8775.0 8770.5 8938.0 8933.5 8919.5 8904.5 8892.0 8889.0 8887.0 8874.0 8871.5 8868.0 8866.5 8860.5 8855.5 8853.5 8849.5 8844.5 8837.5 8831.0 8824.5 8821.0 8818.0 8811.0 8797.0 8790.0 8785.5 8770.5 8768.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 8764.5 8765.5 8765.5 8761.5 8762.0 8761.0 8762.0 8757.5 8755.5 8755.5 8753.0 8752.0 8755.0 8745.0 8744.5 8742.0 8744.5 8738.0 8739.5 8734.0 8735.5 8735.5 8728.0 8731.5 8725.0 8726.0 8722.0 8725.5 8715.5 8718.0 8715.0 8718.0 8706.0 8708.0 8705.5 8707.5 8701.5 8699.5 8701.0 8701.0 100.0 98.0 100.0 REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTG DATA AQUIRED ON ARCOALASKA'S WELL DS 14-05A. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN PASS #1 GRCH TO THE BCS GAM~A RAY, ALSO PASS #1 NPHI TO THE BCS GAPff~A RAY, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8955.0 8694.0 CNTG 8960.0 8694.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. REMARKS: THIS FILE CONTAINS CNTG PASS #1. PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA THERE ARE NO PASS TO ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1088209 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTD PU-S 1088209 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTD 1088209 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTD 1088209 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTD CPS 1088209 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTD CPS 1088209 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTD CPS 1088209 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CNTC CNTD CPS 1088209 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTD GAPI 1088209 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTD LB 1088209 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTD V 1088209 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1088209 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9000.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD -999.250 CCL.CNTD -999.250 GR.BCS DEPT. 8690.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD -999.250 CCL. CNTD -999.250 GR.BCS -999.250 -999.250 26.060 -999.250 -999.250 103.745 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-i997 11:01 PAGE: FILE SUMPL~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8955.0 8690.0 CNTG 8960.0 8690.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 8954.5 8945.5 8940.0 8937.5 8935.5 8931.0 8930.5 8922.0 8921.0 8907.5 8905.5 8899.0 8896.0 8895.5 8893.0 8888.0 8886.0 8875.5 8875.0 8872.5 8870.5 8868.5 8865.5 8860.0 8858.0 8852.5 8851.0 8847.5 8838.5 8836.0 8830.5 8830.0 8825.0 8824.0 8817.0 8815.0 8811.0 8806.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTG 88884.5 88885.5 8952.0 8942.0 8936.5 8938.0 8933.5 8932.0 8928.0 8928.0 8919.0 8919.5 8906.0 8904.0 8898.5 8895.5 8894.5 8892.5 8887.5 8885.5 8874.0 8874.0 8871.5 8871.0 8868.0 8866.5 8859.5 8860.5 8858.0 8853.0 8849.5 8849.5 8846.5 8837.5 8835.5 8831.0 8831.0 8824.5 8824.5 8818.0 8818.0 8813.0 8807.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: 8796.5 8794.5 8793.5 8789.5 8787.5 8784.5 8779.5 8776.5 8776.0 8774.0 8770.0 8768.0 8765.0 8761.5 8758.0 8753.0 8748.5 8745.5 8741.0 8736.5 8735.0 8734 5 8732 0 8727 0 8725 5 8722 0 8721 5 8715 0 8712.0 8704.0 8702.5 8700.0 100.0 $ 8797.5 8795.5 8790.5 8784.5 8777.5 8775.5 8770.5 8765.5 8762.0 8755.5 8748.5 8740.5 8735.5 8734.0 8726.0 8721.0 8711.5 8795.0 8790.5 8787.5 8778.5 8776.0 8768.5 8757.5 8755.0 8749.0 8739.0 8736.0 8728.5 8725.0 8715.0 8704.5 8702.0 8700.0 8701.0 100.0 101.0 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NPHI PASS #2 TO NPHI PASS #1, CARRYINGALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1088209 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTD PU-S 1088209 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTD 1088209 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTD 1088209 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTD CPS 1088209 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTD CPS 1088209 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTD CPS 1088209 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTD CPS 1088209 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTD GAPI 1088209 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTD LB 1088209 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTD V 1088209 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 8957.500 NPHI.CNTD 26.295 NRAT. CNTD 2.905 CRAT. CNTD NCNT. CNTD 2344.523 FCNT. CNTD 786.979 CFTC. CNTD 782.284 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 2987.000 CCL.CNTD 0.009 2.845 2258.354 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O . 5000 FILE SUFmL~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8955.0 8690.0 CNTG 8960.0 8690.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 8950.5 8946.0 8939.5 8937.0 8935.0 8930.5 8927.5 8924.5 8921.5 8920.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GR CH CNTG 88884.0 88886.0 8942.0 8936.5 8931.5 8925.5 8922.5 8919.0 8948.5 8934.0 8928.0 8919.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: 10 8907.0 8906.0 8905.0 8904.0 8904.0 8898.5 8898.0 8896.0 8895.5 8892.5 8892.0 8887.5 8887.5 8885.5 8885.5 8885.0 8884.5 8880.5 8880.5 8880.0 8878.5 8875.5 8874.0 8874.5 8874.0 8872.0 8871.5 8870.0 8871.0 8868.0 8868.0 8865.0 8866.5 8860.0 8860.0 8859.5 8860.5 8857.5 8858.0 8858.0 8852.5 8853.5 8852.0 8854.0 8850.5 8849.5 8849.5 8847.5 8847.0 8845.0 8844.0 8838.0 8837.0 8836.0 8835.5 8830.0 8831.0 8828.5 8829.5 8825.5 8824.5 8823.5 8825.0 8820.5 8822.0 8816.5 8818.0 8814.0 8817.5 8811.0 8813.5 8808.5 8811.5 8808.0 8810.5 8805.5 8807.5 8801.5 8802.5 8800.5 8801.5 8795.0 8795.5 8793.5 8795.5 8789.5 8790.5 8789.0 8790.5 8784.5 8784.5 8785.5 8780.0 8779.5 8779.5 8779.0 8774.0 8775.5 8771.0 8772.0 8769.5 8770.5 8767.0 8768.0 8764.0 8766.0 8761.0 8762.0 8756.0 8756.5 8755.0 8755.0 8751.0 8751.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: 11 8749.0 8749.0 8748.0 8749.0 8742.5 8744.5 8737.5 8739.0 8732.0 8734.0 8726.5 8728.5 8725.0 8726.0 8716.5 8718.5 8713.5 8715.0 8710.0 8709.5 8707.5 8706.0 8703.5 8702.0 8703.0 8704.0 8700.0 8699.5 100.0 98.5 99.5 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO NPHI PASS #3 TO NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: 12 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) FT 1088209 O0 000 O0 0 3 1 1 4 68 0000000000 DEPT NPHI CNTD PU-S 1088209 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTD 1088209 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTD 1088209 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTD CPS 1088209 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTD CPS 1088209 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTD CPS 1088209 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTD CPS 1088209 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTD GAPI 1088209 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTD LB 1088209 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTD V 1088209 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 8958.000 NPHI.CNTD 26.706 NRAT. CNTD 3.095 CRAT. CNTD NCNT. CNTD 2340.656 FCNT. CNTD 836.775 CFTC. CNTD 820.402 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 2991.000 CCL.CNTD -0.011 DEPT. 8688.500 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD 91.897 TENS. CNTD -999.250 CCL.CNTD -999.250 2.868 2256.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: 13 FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, CNTG $ REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, &3 OF THE CNTG TOOL. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1088209 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1088209 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1088209 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1088209 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1088209 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: 14 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) FCNT CNAV CPS 1088209 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1088209 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1088209 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 1088209 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTD LB 1088209 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 8958.000 NPHI.CNAV -999.250 NRAT. CNAV -999.250 CRAT. CNAV NCNT. CNAV -999.250 FClFT. CNAV -999.250 CFTC. CNAV -999.250 CNTC. CNAV GRCH. CNTD -999.250 TENS.CNTD 2946.000 DEPT. 8692.000 NPHI.CNAV -999.250 NRAT. CNAV -999.250 CRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV -999.250 CNTC. CNAV GRCH. CNTD 92.913 TENS.CNTD -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MA3fREC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001 CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: 15 FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTG 8992.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) '. DEPTH CONTROL USED (YES/NO): STOP DEPTH 8693.0 21-SEP-97 8C0-609 1029 21-SEP-97 8973.0 8963.0 8700.0 8960.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAlV~WzA RAY CNTG COMPENSATED NUETRON $ TOOL NUMBER SGT-L CNT-G BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 9380.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PUMPED IN CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EP I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 7000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: 16 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: TIED INTO AWS BHCS DATED 1/31/92. PUMPED 261 BBLS CRUDE AND 10 BBLS DIESEL GOC APPEARS TO BE AT 8900' LOGGED ON SANDSTONE MATRIX THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1088209 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1088209 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1088209 O0 000 O0 0 5 1 1 4 68 0000000000 TArRA PS1 1088209 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PS1 CPS 1088209 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1088209 O0 000 O0 0 $ 1 1 4 68 0000000000 CNTC PS1 CPS 1088209 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1088209 O0 000 O0 0 $ 1 1 4 68 0000000000 GR PS1 GAPI 1088209 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1088209 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: 17 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CCL PS1 V 1088209 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 8993.000 NPHI.PS1 17.624 RTNR.PS1 2.375 TNRA.PS1 RCNT.PS1 2367.365 RCFT. PS1 981.884 CNTC. PS1 2285.267 CFTC. PSI GR.PS1 27.689 TENS.PSi 2204.000 CCL.PS1 0.033 DEPT. 8692.500 NPHI.PS1 42.603 RTNR.PS1 3.545 TNRA.PS1 RCNT. PS1 1673.699 RCFT. PS1 439.156 CNTC. PS1 1597.720 CFTC. PSI GR.PSl 93.296 TENS.PSI 2928.000 CCL.PS1 -999.250 2.325 1004.460 3.740 448.141 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SU~VARY VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: 18 CNTG 8974.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 8685.0 21-SEP-97 8C0-609 1029 21-SEP-97 8973.0 8963.0 8700.0 8960.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTG COMPENSATED NUETRON $ TOOL NUMBER ........... SGT-L CNT-G BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) '. LOGGERS CASING DEPTH (FT) : 8.500 9380.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : PUMPED IN CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: 19 REMARKS: TIED INTO AWS BHCS DATED 1/31/92. PUMPED 261 BBLS CRUDE AND 10 BBLS DIESEL GOC APPEARS TO BE AT 8900' LOGGED ON SANDSTONE MATRIX THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1088209 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1088209 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1088209 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1088209 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PS2 CPS 1088209 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1088209 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1088209 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1088209 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1088209 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1088209 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1088209 O0 000 O0 0 6 1 1 4 68 0000000000 · LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: 2O ** DATA ** DEPT. 8974.500 NPHI.PS2 RCNT. PS2 2349.072 RCFT. PS2 GR.PS2 32.977 TENS.PS2 DEPT. 8684.500 NPHI.PS2 RCNT. PS2 1630.789 RCFT. PS2 GR.PS2 91.092 TENS.PS2 22.864 RTNR.PS2 851.281 CNTC.PS2 2324.000 CCL.PS2 47.187 RTNR.PS2 391.746 CNTC. PS2 2963.000 CCL.PS2 2.714 TNRA.PS2 2267.608 CFTC. PS2 0.009 3.744 TNRA.PS2 1540.946 CFTC. PS2 -999.250 2.657 870.854 3.991 401.239 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE · 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O . 5000 FILE SUmmARY VENDOR TOOL CODE START DEPTH CNTG 8978.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : STOP DEPTH .......... 8688.0 21-SEP-97 8C0-609 1029 21-SEP-97 8973.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: 21 TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTG COMPENSATED NUETRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 8963.0 8700.0 8960.0 1800.0 TOOL NUMBER ........... SGT-L CNT-G 8.500 9380.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PUMPED IN CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS)'. 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: TIED INTO AWS BHCS DATED 1/31/92. PUMPED 261 BBLS CRUDE AND 10 BBLS DIESEL GOC APPEARS TO BE AT 8900' LOGGED ON SANDSTONE MATRIX THIS FILE CONTAINS THE RAW DATA FOR PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: 22 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1088209 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1088209 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1088209 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1088209 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 1088209 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1088209 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1088209 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1088209 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1088209 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1088209 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1088209 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 8978.500 NPHI.PS3 20.520 RTNR.PS3 2.571 TNRA. PS3 RCNT. PS3 2239.475 RCFT. PS3 857.801 CNTC. PS3 2161.811 CFTC. PS3 GR.PS3 44.303 TENS.PS3 2393.000 CCL.PS3 -0.011 DEPT. 8687.000 NPHI.PS3 43.151 RTNR.PS3 3.733 TNRA.PS3 RCNT. PS3 1626.910 RCFT. PS3 395.936 CNTC.PS3 1564.153 CFTC. PS3 GR.PS3 88.690 TENS. PS3 2903.000 CCL.PS3 -999.250 2.517 877.524 3.770 421.353 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 11:01 PAGE: 23 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/12/14 ORIGIN : FLIC TAPE NAME : 97528 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, PRUDHOE BAY, DS 14-05A, API #50-029-20327-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/12/14 ORIGIN : FLIC REEL NAME : 97528 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC, PRUDHOE BAY, DS 14-05A, API #50-029-20327-01 eOeJotpu¥ uo!sfltumo3 'suo3 se9 ~ 1!0 mlSeiV ~66l £ l -IFIP CI]AI]D]U , * , * ****************************** 00'0 0'o 000'0 C~S/~q) ,L~DI~ (&J) H~d~O (NI) ~ZIS (~I) ~ZI~ 00'~ O0~'tL no ~L O6 ~-~'t iOL~COE6gO0§'~SO:~['t~ MOHOf'iad'ONl VMM~i"V OD~V : iLN~OD : 3dY& 9ilOIh:]~d l : # : ~ NOi&¥'ftNI&NOD Olqa : NIDIaO $ $ O'gOI O'gOI O'OoI S'EL98 S'[L98 S'[L98 S'89L8 O'LgL8 0'06L8 0°88L8 O'L6L8 S'S188 ~'8f88 0'1~8 0'8~88 ~'/~88 ~:°8988 §'L988 O'~LSa ~'PL88 0'9L88 ()'g968 0'g968 0 g968 ~'0868 0'6868 ~'6868 0'0668 0'6t06 0'6~[06 ~'~§06 0'~06 0'68888 ~'L8888 # $ H£d3q $ 0'9~98 O°OEE6 H£ND 0'9~98 0'I'[[6 HD~D "saI'[~ a%~do~ u~ S~d q~a zo~ sa^~t'~ pOdd'I"[~ pue PO~tqs £0:[i IS Tape V'erification bistinq ~h.lt,~mber~er Alaska, Com?)utiD~ Center TYPE REPR 7 65 !.! 66 13 66 14 65 15 66 16 66 6 0 6 0,5 FT 0 PT 0 ** SET TYPE - CHAN ** ''''' ' ' 'NAIF ~, .... '~'i~ ' ~ ~ ~ ~ 7. '''''''''' .... ;~....R V ;:~,! CE AP1 A ID [1R~. ER ~ t, OG TY DEPT FT ~4(')989 O0 0 NDHI C~TH PU-$ 440989 O0 0 NRaT CNTH 440989 O0 0 C~AT CMTH 440989 O0 0 NC~T CNTH CPS 440989 O0 0 FCNT CNTH CPS 440989 OD 0 CNTC CNTH CPS 440989 O0 0 CFTC C?~TH CPS 440989 O0 0 GRCH CNTH GAPI 440989 O0 0 9:ENS CNTH LB 440989 O0 0 PE CLASS MO O0 OO O O0 O0 0 O0 O0 0 O0 O0 0 O0 O0 0 O0 O0 0 O0 O0 0 O0 O0 0 O0 O0 0 O0 O0 0 FiLE NtI,~B Nb,aB .IZE RE R $ 0 NUmB S.l. ~P ELEM CODE (HEX) 1 1 1 4 68 OOOO000000 i 1 ! 4 68 0000000000 1 1 I 4 68 0000000000 1 1 I 4 68 0000000000 1 1 1 4 68 O000OO0000 I 1 I 4 68 0000000000 1 1 1 4 68 0000000000 1 1 1 4 68 0000000000 1 1 I 4 68 0000000000 1 1 1 4 68 0000000000 mmmmmmmmmMmmmmmmm.mmmmmmmmmmmmmmmmmmmmmmmmm ** DATA ** DEPT. 9320 (')0~ i'~PHI.CN.H 'NCNT.CHTH 2353.965 wCNT,CNTH (;RCH. C~'~TH -9q9.250 '?EN&.CNTH DEPq'. gO00. 000 i'dPHI. CNTH qCHT.CNTH 2265.175 FCNT.CNTH GDC~. C'~TH ~.7.131 TENS.CNTH 22.148 783.2O] 2695.000 20.706 837.000 2612.1.0g 60,619 240.313 2490.0O0 MR AT. CNTH Cf',: 'TC. CN T H 2.663 2274.933 CRAT.CNT!i CFTC. CNTH NRAT,CNTH 2.718 CRAT.CNTH CNTC.CNTH 2281.607 CFTC.CNTH 6.000 1.141.~45 NRAT.CNTH CNTC.CNTH CRAT,CNTH CFTC.CNTH 2 bib 869:444 2,529 9!8,891 4.728 261.620 ~'06~6 O*OI~b I O'OggO 0'I696 0'96~6 S'OO~6 ~'60~6 H.£d3~ [~OUD 3AafiD fl~d L /LOI~6 : LOV~O0 : ~OIS~A DlqA : 3Oia~2~ L /LO/gO : /0~100 : NOIS~3A OlqJ **** a~qi'vaj, 2qlA **** fO:Et g66['riqP'L "lDdN [ ~H~ H~ND ~H~ ,JO ~d $ §'66 ~'IL98 ~'0698 0 '[gL8 S' f,,E L 8 9"99L8 0 '~6L8 0'8£88 !L988 ~688 g 616B S'['668 '00"[6 ' g 'i: $ 6 0'00[ ~'0998 O'[OL8 o'~gL8 ~'99L8 ~'§6L8 0 · g 688 O'~Eb8 ~'6g06 0'§~06 0'L906 O'§L06 $ 0 "OOI §'OS9B 0"8S98 0'~L98 0:'[698 0 $'99L8 O~LgL8 S S6L8 0:~'88 S L~88 ~:L988 0 0'§868 ~: L906 § ~L06 0: '[ 0 ": 6 ,IS Tane Verif!cation !...,isti. nq :chl, Umber,.~er alas~.a Como,~ting Center 7-J{.i!~- 1992 13:03 PAGE: ~ 6~ 0,5 9 65 F? 1! 66 25 ~2 6~ 13 66 0 14 65 FT I5 66 6~ 16 66 ! 0 66 ~ TYPE ,, ¢!tAN ** 8E~¥ API A.PI API ~tbE N NUk IZE REPR , ORDER ~ LOG TYPE CLASS ~OD N[,I~'.~ SAMP ELE~ COD~ (fl~X) [:ED? FT 440909 O0 ()00 O0 0 ~ 1 1 4 68 0000000000 NPHI CNTH PU-$ 4409B9 O0 000 00 0 2 {. I 4 68 0000000000 NRAT CNTN 440989 OO 000 O0 0 2 1 i 4 68 0000000000 C~AT CNTH 440989 00 000 00 O 2 I I 4 68 0000000000 NCNT CNTH CP5 440989 00 000 00 O 2 I. 1 4 68 0000000000 FCN? CNTH CPS 44098q 00 000 00 O 2 1 1 4 68 0000000000 GRCH CNT~ GAPT 440980 00 o00 00 0 2 I 1 4 6~ 0000000000 C~TC CNTH CPS 4~0989 0!) 000 00 0 2 1 I 4 68 0000000000 CFTC C~TH CPS 440989 00 go0 00 0 2 ! 1 4 68 O000000000 T~NS CNTH [,,B ~409~9 O0 000 O0 0 2 1 1 4 68 0000000000 DFPT, 9]~0.O0(i iqPH!.CNT}~ 22.~43 N~AT.CNTH 2.798 CRAT.CNTH NC.~iT CNTH 2268.992 FCN~. "~ . - . CNTH 809..454 GRCH.CNT~ -999.250 CNTC.CNTH CFTC. C~,JTH 889.765 TEhS.C~TH 2715.000 1') F t~'r oOOn. O0o ,"~mHI. C~iTH 20.377 NRAT CNTH 2.737 CRAT.CNTH NCNT.CNTH 2269.938 wCNT.C~;TH 839.406 GRCH,CNTH 27.467 CNTC.CNTH CFTC.C~,~T~ 911 156 TCNS L i'~ 2622 063 DEPT. 9567.500 WDH'[.CmTH 47.039 MRAT.CNTH 4.455 CRAT.CNTH NC:'~. Ch!T~ 1203.907 wCNT.CN~~ 3C2.764 GRCH.C~TH -999.250 CNTC.C~TH CCT~.CN3'H 3o3.~93 r F;rqs. c~,;T~ 2495.r)00 2.656 2247.275 2.508 2302,250 3 983 1205:875 ** EN!) OF DATA ** IS Ta~e Verification Listins chlumberqer Alaska Compotfng Cent. er 7-JUL-!992 13:03 . 140~5 9140.5 9!..!..2'5 o69.n 9059 5 9o52~5 9o51 .o 9oi9.$ 8965 5 ~964,5 8935 5 8935,0 8920,0 89z0.0 8892,5 a892.0 8875,a ~8~4 5 88.49.5 8824.0 881.7.0 a816.5 88OO,0 8796,0 8767,5 8767,0 8767,0 87~, 0 ~721,0 869!,0 867!,0 8670,0 8657'5 100,0 99,0 S 9!43,5 9112.5 9059,5 8984,5 $869,0 8824,0 8819,0 8799,5 8766,5 8~90,5 8657,0 99,5 %...'~!Ia W'lS~; CO!'~TAI}'~!S. THE TH!61D PASS OF THE CNTH.. THE D. ~DTH ADjUST~E~gTS S~'.IOWN ~BOVE REFLECT PASS 3 ~RCH TO PASS 1 GRCH AND PASS 3 NPHI TO PASS 1. NPHI, LIS FORMAT DATA PAGE~ DATA FOR,'~.Am SPECIFICAT!Ol'~ RECORD ** ** SET TYP~] - 64E6 ** 6fi ~ 66 0 3 73 40 4 66 5 66 6 73 7 65 8 68 0,5 0~'666- 0~E'666- 816'~g~ 809'~ EI8'06~ 619'Z 0g~'666- HIND'9!43 NiND'D£ND ~L£'SL H£ND'HD~D 0q['660- H£ND'iND HJ~ND'£~D 0~'666- H~ND'i~N 0~'666- H£r~D'IHd N£ND'D£ND LLg'6g HIND'tIDeD Oqg'N~8 N&ND'&ND HiND°i~D L~L'~ HZND'Z~HN [l. 6°t~ H£ND'I'Hd HiND'DtND 0~g'666' HJ:NO' HD~]D §gI 'g.qU E~LND' i:ND HIND' J,~D ~/L'E HIND'iV'~N Lg~'E~. l~ 00 ~ ' 9 ~. ~ ~ ' N O00'O00b ' £O~;jd 00000010000 89 ~ '[ E 0 O0 000 0 ~ ~ ~ E 0 00 000 0 0000000000 89 0000000000 89 ~ ~ ~ ~ 0 O0 OuO 0 0000000000 89 ~ t I E 0 O0 o00 o 0000000000 89 ~ l[ I E 0 00 000 0 0000000000 89 ~ i [ ~ 0 o0 000 0 0000000000 89 ~ l ~ [ 0 uO 000 0 0000000000 89 ~ ~ '[ [ o oo 0oo 0 0000000000 89 ~ I t [ 0 O0 oOU 0 0000000000 89 ~ I [ [ 0 O0 000 0 ~ OuO'O~E6 '&daq 0 ~860~ Id~9 H£ND 0 6860~ 9dD H~ND iNDA 0 6860~ ~dD [q£NO £NDN 0 6860~ H~ND ~VdO 0 6860~9 HAND iVaN 0 6860~ &.4 id3(] # ~J~tda mmmmmmmmmmmmmm~m mm~ m' m mmmmmmmmmmmmmmmmmmmmmmmm, ~ mm t 99 9 ~9 99 ~ ~A S9 ~ 0 99 [ ~mmm I ,i mi ij uI :3D~d £O:El g66 f~'qflP-L ~ 99 0 99 EO:E~ g66 i'qfiP-'L Tape Verification Listi, no ;chlumberoer AlasKa Computin~ Center 7-'J!JL-1992 PAGE: 12 *~ SET N E S E R ¥ U ~ [ T I, D ''';;'''''''''''''DE.. ~'~ FT N'~AW CNAV C~AT CaAV NCNT C~'~V CPS FCN~ C~ V CPS C~TC C ~.~ ~.v CPS CFTC CNAV CPS G~C~ CNAV GAP! TYPE - CHh .... S VICE ORDER # L 44098,9 00 440989 00 440989 0O 440989 00 44(t989 00 440q89 O0 440989 00 '~40989 00 440989 00 ** OaT& ** DF. PT. 9320.000 NP NCNT,C'NAV 2326.(}45 FC GPCH.CN'~V ~,,t15 TEl D~;PT. 90o0. ()o0 HP ~4C~T. Ca AV 226.~.502 FC G~CH. C~,l~ v 27.956 ~E OFP?. ~647.000 ',lP NC~iT.CNAV 1.117.633 MC (ii'CH. C~4 AV 7o.139 0 FT 68 ! -:--- .... ,-,--------,,......-.,........,................... P APl P APl FI NJ,~B UMB $IZ REPR PROCESS Od TY,,.L CbASS MOD MdMB 8AMP ELES CODE (HEX) 000 00 0 4 1 1 4 68 0000000000 000 O0 0 4 I I 4 68 0000000000 000 O0 0 4 ~ 1 4 68 0000000000 000 O0 0 ~ 1, 1 4 68 0000000000 000 O0 0 4 1 ! 4 68 0000000000 000 00 0 4 ~. !, 4 68 0000000000 OOO O0 0 a 1 1 4 68 0000000000 000 O0 0 4 1 ! 4 68 0000000000 000 00 0 HI,CMAV 22.384 ~:F~AT,CNAV 2 735 CRAT.CNAV biT.CN~V 814.846 CNTC.CNAV 2270~780 CFTC.CNAV NS.CNAV 2721.916 HI CNAV 21 016 NF'AT,CNAV 2.7.t0 CP. AT,CNAV NT:C~:AV n33~135 CNTC.CNAV 2282.037 CFTC.CNAV N'S. C~:AV 2631 .898 HI.CNAV 55.482 bIPAT.CNAV 4 972 CRAT.CNAV NT.CN~V 244.569 CNTC.C~AV 11.36~557 CFTC.CNAV N,9.CNAV 2499.750 2 630 888:415 2.548 917,361 4 446 266:247 tis Tame Verification bistlnq ;chlumberqer Alaska Computlnq Center 7-JUL-1992 13:03 **** FILE TRAI!SER **** FILE MANE : EDIT .004 SERVICE : FLIC VFRSION : O01A07 DATE : 92/07/ 7 ~aX REC SIZE : !.02{ FILM TYPE : LO hAST FILE : **** FILE HEADER **** SERVICE : FLIC VERSION : O01A07 DAT~ : 92/07/ 7 MA× REC SIZE : 1024 FILE TYPE bAST FI[,~ CURVES Curves and ioq ~eamer 8ata ~'or each Dass in separate ~iles: raw background pass .In last ~lle P~S$ NLI~BER: 1 D~PTH INCREMENT: -.5000 YENDDR TOOL COD~ START DEPTH [.,~(; HEADER DATA STOP ~EPTH 8645.0 DATE LOGGED: TD ORILLE~ (FT): ~0 I,,OGGER(FT): TOP LO~ INTERVAL ~OT'¥O~ LOG INTERVAL bO~GING SPEED [FPHR) TOO[, ST~.[NG (TOP TO CNTH T~LEiqETRY CARTRIDGE CNTH G~M~A RAY CNTH Cg~PENSAT~D NEUTRO~ CNTH TELE~iErR¥ MODULE $ O9-FEB-92 CP ~034 09-FEB-92 9380.0 9323,0 7400,0 9320,0 TCC [~ 420 SGC SA 59 CNC HA 'TC~ 278 ,IS Ta~e Verification Listtnq ;chlUmberqer Alaska Computinq Center 7-JUL-!992 13:03 PAGE: BOREHOLE A~D CA$Ib!G DhTA DRILLERS C~SING DEPTH LOGGERS CASIN~ DEPT~ ~ORE[{OLE CONDITIONS FL[.iID TYPE: Phi,liD DENSITY (LB/G): CiR,.ACE 'I .... ,~DERATIIRE ([)MAW), FL!lID SALINITY FL!,tiD LEVEL CFT): ~aT~ CUTS (PCT): GAS/OIL RATIO: CMO~E 5!~UTRON T©Ob TOOL TYPE (EPiTHERMA[, OR THERMAL): M~RIX: ~TRI× HOLM CORRECTION 2.65 COUNT R~TE LFt~'~ SCALE (CPS): 0 ~E~ARKS: F~.R CO[lET RATE HIG.[.~ SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEaR COUNT R~TE HIGH SCALE (CPS): Tt.Er~ li'~TQ BHCS DATED 31-JAN-9~. 4 0 0 0 0 10000 ND mER~O~ATI;]M..q EXIST IM TEE W~;LL.... SIDETRACKED F¢O~ WE;bi, 14-5, hOGGED THREE PASSES ~T ]0 MPPm. ~P=O PS! ~H?= 1.0 DEG. F PASS NO, 2 WAS LOGGED UP *[3 SHORT JOINT aT 8575' A ,JEW~TLE~Y LOG P~SS ~'AS aLe ' ...... .,O ~ADE FRflM 8600' TO GL~ ~5. LIS F'D~T DAT.& 12,~50 7e 5 o SEAWATER/CRUDE 208,0 .BbUEL!NE COUNT RATE NOR~4ALIZATIO~$ IN OIL ZONE TOP Ni3RgAblZING WINDOW (FT): BASE NORt~ALIZ!NG ~J!NOOW (FT): .,:I$ Tare Verification Listinq ;chlumberc;er Alaska Computina Center 7"d t![.~- ! 9¢}2 1 PAGE: TYPE -64EB ** . ~E: ~EP~ CODE VALLiE 0 66 0 73 44 5 66 ~ 73 ~ 6~ 0,5 9 65 FT 11 66 23 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 ~ ** SET TYPE NA~E S~R UNIT ID ORDE DFPT FT 4409 NPHI PS1. ~'I'NP PSI T~!P~ RCFT PS1. CNTC PS1 CFTC PS1 GP TENS CCh CHAN ** APl A,. I APl FIbE ~$ N!JM~ SIZE RE ROcE$ ~ ~ bOG TYPE CLASS NOD NUMB 8A~P ELEN CODE (BEX) 89 00 000 00 0 5 1 1 4 ~8 0000000000 pti 440989 00 000 00 0 5 ~ I 4 68 0000000000 4409~9 00 000 O0 0 5 l 1 4 68 0000000000 440989 00 000 O0 0 5 ! 1 4 68 0000000000 CPS 4409~9 O0 000 O0 0 5 1 1 4 68 0000000000 CPS 4409~9 00 900 O0 0 5 I 1 4 68 0000000000 CPS 44agoq 00 000 00 0 5 1 1 4 68 0000000000 CPS 44a989 O0 000 bO 0 5 1 1 4 68 0000000000 GAP,I 440989 00 000 00 0 5 1 1 4 68 O00000000O l,B 440989 OO 000 00 0 5 1 1 4 6~ 0000000000 'V 440989 O0 000 O0 0 5 I. I 4 68 0000000000 15 * * D A T & * * DF, PT aP.PSI D EI::T. GP, PS 1 9336.0(}0 !~PHI.P$1 10.772 RTNe. PS1 2 631 TNRA.PS1 20q5.295 RCF'To P,S 1 7~.~25 C~]TC.PS! 20~,~729 CFTC.PSi 34,875 TgNS,PS1 2160,000 CCL,PS1 -0,004 9(;t)0.()00 ~PHI,PS1 2!.002 RTNR.PS1 2.74~ TNRA.PSI ~47.596 ~CFT.PS1 a28.!95 CNTC.?S! 2~8~.949 CFTC.PS1 ~7.594 TEaa.~$1 26~5.000 CCh. PS1 0.009 2.468 857.400 2 548 917~193 ON O'OOSI 0'0~£6 0'99q8 L /LOll6 : DIq2 : 2DiA~2~ ~gOI : 3ZI~ D2a L ~LO/E6 : LO~IO0 : ***, aaqiva$ aqlJ **** 9t 099'i9~ :3DYd 090'0- lSd'qOD O00'06Pg ISd'aNi~ fO:C[ [66'[-qOP-L I~d'IHdN 000'~98 '~d~d :,iS Tape verification L, isti~q :,chlumber(~er A!asKa Computinq Center 7-JUb-t992 13:0] PAGE: 17 TOO!~ STRING (TOP TO ,6OTTO') VENDOR TOOL CODE TOO[, TYPE CNTH CNT~ CNTM CNTH CNTM $ CO?4PENSATED NEOTROF~ TELE~ETRY MODUhE ~OREHOLE AND CASING DATA []PEN HOLE .[SIT SIZE (IN): DRIbI..~ERS CASI~'G DEPT..;-! (FT): BOREHOLE FLUID TYPE: FLUID DENSITY SURFACE TE~aPERATURE (DEGF): SOT,rO~ HOLE T~HPERAT~IRE (DgGF): Fbi,liD SALINITY (PP~): FLUID LEVEL (FT): FLUID RATE'. AT WELLHEAD WATER CUTS (PC'ri CHOKE (DEL): CAL YA 1592 TCC 8 42O SGC Sa 59 c~c ~!a 332 TC~ 27R 55?0 SEAWATER/CRUDE 208.0 NEUTRON TOOL TOOb TYP~'~ (EPITNE~MAb OR THERMAL): ~aATR!X: SANDSTONE ~ATR. IX DENSITY~ 2.65 HOL'E CORRECTIO~'~ (IN): 8LUELINE COd[,)T ~ATE NORMALIZATION IN ~IL ZONE TOP NOP~AbIZIi,~G WINDOW BASE ~O~M~I..,IZIf~G ~4!'IDUW BLUELI~,{E CO'(It, iT kATE SCALES SET BY FIELD ENGINEER FaP CO!~,,~T aaT~; bu;~ SCALE (CPS): o FAR COI/NT RATE HIG}.{ SCALE (CPS): 4000 S~EAR COUNT RATE bOW SCALE (CPS): 0 ~JEAR COUNT RATE HIGH SCAI.,E CCPS): 1o000 TfIf~L STA~-~DOFV (IN): ~E~ARKS: TIED INTO [4NCS DATED 31-JA~-92. ~-~ PERFORATI(1N~; EXIST IN THE WELL,.,, 8IIDETR~CKED FROM :4EI.,L ~.4-5. bOGGED THREE PASSES AT 30 dHP:O PS! WHY: 10 DEG. F P~SS UO. 2 ~AS [,OGGED UP TO SHORT jOINT AT 8575' A jKt,~EbERY L[3G PASS ;qaS ~L50 ~ADE FRF]~ 8000' T(')~[,~ ,5. # LIS Ft']P:'~AT DATA .,I.S TaD. e Veriitcstion ListIDq ;c.hlumberqer Al.~aska Computinq Cent. er 7-JUl,-1992 i3.'.03 PA.G~: ** BATA Fr]~'MIT SPECIFICATION RECORD ** ** MET TYPE - 64EB ** TYPE ~ ODE V 1 66 0 2 66 0 3 73 44 4 66 t 5 66 6 73 7 65 8 68 0,5 9 65 ~? 11 66 23 ~2 6~ 13 66 0 14 65 FT 15 66 68 1.6 66 1 0 66 1 ''X~['' ......... ;'~ .... '''' ......... X';"'''''~ ..... ' '''''''''''''''''"''''''''''''' N.. SERV [INI. .... RVIC.;E ~' APl API P API bE Nit~B... NUMB sIZE REPR PROCESS VT 44008q 00 000 00 0 6 ! 1 t 68 0000000000 DEPT NDHT PS2 PU 44098q O0 000 O0 0 6 1 1 4 68 O000000OO0 RTiq~ PS2 440~9 00 000 00 0 6 1 1 4 68 0000000000 TNRA PS2 440989 O0 000 O0 0 6 I. 1 4 68 0000000000 RCNT P~2 CPS 440989 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 44098q 00 000 00 0 6 1 1 4 68 0000000000 C~TC PS2 CPS 440989 0o 000 O0 0 6 ! I 4 68 00000000O0 CWTC PS2 CPS 440980 00 0o0 00 0 6 ] 1 4 68 0000000000 G~ PS2 (.;AP! 440999 00 000 00 0 6 ! 1 4 68 0000000000 T~NS PS2 ' ' ** DATA ** D,t,.,EPT ¢~33H. ... .5(}0 .... 14 PI4 I . PS2 22 .929 RTl'JR . PS2. 2.R36 TNRA . P,S2 R ..NT:PS2 2115,595 RCF'T. PS2 737.939 C~JTC, PS2 2!02.907 CFTC, PS2 GR,PS2 42.256 TE~!S,D$2 2175.000 CC[:,PS2 -0.00] [)~FT. 9000.00() NPHI,PS2 PCNT,D$2 2261.357 RCF'T.PS2 GR.D$2 27,57~ TE"q · . . . _ 1¥ ~ . 20,b05 RTNR,PS2 R31.408 CNTC,P$2 2635.000 CCh,PS2 2.848 TNRA,PS2 2294.348 CFTC.PS2 -0.066 2,660 802.701 2 522 921:978 H&dSO dO£D 9gO[ : MZIS D38 X~ L /LO/~6 : ~ LOttO0 : NOi~MA LO{}' ~iqM : M~VN MqiA **** MMOYMH MqI~ **** 2qlA $S~q LOVIO0 : ~OIS~A 900' %I03 ; SwVN >qiA ~86 6IO'O' gS:d'O~Sj §LB'§OgT g~d'qDO O00'fi6fg 6T buT~sTq UOT~OT;'j~aA aae~ Si~ 0000t 000%' :(~dD) 3~D~ HDIH 3iV~ 2, NFIOD 8~A :(£~) i~OqNl¢. DNiZIqV~80N 2"3lYti 2~NOZ qlO N'[ NOI£~ZI'IVHSON [tiV8 iNiiOD 3Niq2RrI~ 0'808 O'S~SL OS~'~'[ 8~9~fiN qO0~ :XI~iV~ qoo& NO~ii2~ :(NI) ~Zi9 tI~ 3qOH N3dO aO£VJfiq 8¥qqo~ O~ EO:Ei ~66i'qflP-/ 0~9'8~8 000°0 £gd"'lDD O00"gg'[g ~gd"SN~Z gLE"g[ [Rd"aD ESd°~SN& L~9"g E~d"~N~a ~00 U~ Egd"IHd~ 000"6[t6 &d~d ......0000;;~'~00 89 ~ i ..........[ 7='=""'0 ...... ' O0 000 ....... O; ............ 6860~ ~ ......... ~d 0000000000 89 ~ t I L 0 O0 000 0000000000 89 ~ I t ~ 0 O0 OOO 0000000000 89 ~ I t L 0 O0 000 0000000000 89 ~ t l L 0 O0 000 0000000000 89 ~ t I £ 0 O0 000 0000000000 89 ~ I i £ 0 O0 000 0000000000 89 ~ I I L 0 O0 000 0000000000 89 ~ I I L 0 O0 000 0000000000 80 ~ ~ '[ L 0 O0 000 0000000000 89 ~ I i L 0 O0 000 SS3DOHd adaU 3ZIW ~O~ ~ 3"Ii~ ld~ Id~ IdV oo 686o~ 9dO E9d O0 68b0~ MdO [~d O0 6860~ 9~D £~d O0 6860~P ~gd O0 6860~ fid [gd iHdN O0 6860~ £~ I 89 0 9g 9~ 99 89 ~'~ §9 6 [0:£l' ~66 i-qDP-L 0t0'0- tO:Ei aalua5 ~u'[~adaoD e~se'[~ Copyright 1987, 1988, 1989, 1990, 1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved,t PROGRAM--. TAPESCAN REVISION: 2.58 Start of execution: Tue 4 FEB 92 2:04p Tape Subfile 1 is type: LIS ~ ~ 92/ 2/ 4 O1 **** TAPE HEADER **** 921 21 4 O1 RECEIVED FEEl 2 5 1992 Alaska 0il & Gas Cons. Commis$to~ Anchorage Tape Sub file: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes MICROFILMED Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL : ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 14-5A 500292032701 ARCO ALASKA INC. ATLAS WIRELINE SERVICES 5-FEB-92 RUN1 77040 BRAD ESARY WESTER/BACAK RUN2 RUN3 9 10 14 1514 1154 72. O0 71. O0 44.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9. 625 7855.0 CIRCULATION STOPPED ~ 09: 30 31-JAN-92. TOOL SET DOWN SOLID AT 9119 '. DRILLING REPORTED STICKY HOLE FROM 8800 ' TO 9100 ' AND POSSIBLE KEY SEAT FROM 8850' 8875'. "*~ ON LOG DENOTES CYCLE SKIPS, WHICH ARE AT: 8190', 8190', 8397',8622', 8720', 8835' - 8860', 8888' AND AT 9077'. $ **** FILE HEADER **** FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; depth shifted and clipped curves; all runs merged; no case hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE BCS 0.5000 START DEPTH 7847.0 STOP DEPTH 9081.0 DIL 784 7.0 GR 7847.0 $ BASELINE CURVE FOR SHIFTS: 9107.0 9076.0 GR FROM BCS CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 7770.0 7770.0 8918.2 8919.5 8991.0 8989.5 9130.0 9130.0 $ MERGED DATA SOURCE PBU TOOL CODE RUN NO. PASS NO. MERGE TOP BCS 1 2 784 7.0 DIL 1 2 784 7.0 GR 1 2 784 7.0 $ REMARKS: CN : ARCO ALASKA INC. WN : 14-5A FN : PRUDHOE BAY COUN : N. SLOPE STAT : ALASKA MERGE BASE 9091.0 9107.0 9076.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: FEET 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 DT BCS 68 1 2 GR BCS 68 1 3 ILD DIL 68 1 4 ILM DIL 68 1 5 LL8 DIL 68 1 6 MTEM BCS 68 1 7 SP BCS 68 1 8 TEND BCS 68 1 9 TENS BCS 68 1 US/F 4 GAPI 4 OHMM 4 OHMM 4 OHMM 4 DEGF 4 MV 4 LBS 4 LBS 4 4 20 789 90 0 4 20 789 90 0 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 20 789 90 0 4 20 789 90 0 4 20 789 90 0 4 20 789 90 0 * DATA RECORD (TYPE# O) 1006 BYTES * Total Data Records: 103 Tape File Start Depth = 9130.000000 Tape File End Depth = 7847.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet 36 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 25671 datums Tape Subfile: 2 186 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes 9~ seqXq 900r :qqhue~ paooe~ seqXq ~9 :qqhue[ paooe~ · ''sp~ooe~ 6~ ~ :er~$qn~ edu~ s~n~ep 9ZZ 89 :epoD deH :~J~ns ~u~pooep epoo uo~e~ueseJdeJ ~ee~ = s~u~ q~deG er~ ed~ 00000£'0 = ~u~o~ds rono~ or~ O00000'OZZZ = q~doG pu~ o[~ O00000'ZPSZ = qqdoc qJ~qS ~[~ od~ 06 68Z O~ ~ 06 68Z O~ 9 06 68Z O~ ~ 06 68Z O~ 9 ~ S~ ~ 89 SD~ EN~ 9 P S~ ~ 89 SD~ CN~ ~ 9 ~D~G ~ 89 SD~ W~W ~ ~ IdVD r 89 SD~ HDHD r pow SrD dX~ d,{~ q$~ue7 ezr.$ IdV IdV IdV IdV s$r. ui] se~du~S epoD too. r, eu~N : senJnD 9 .r,~X :(ri ~$dep ~WV~rX H~d HJ~G ~NO (~9 #~dX~) GHOD~H .r, VWHO~r VXSVfI¥ : ~dO~IS 'N : N~OD XV~ ~OHGBHd : N~ Vg-Pr : 'DNI VMSVfrV OOHV : ND r :H~WDN ~I~ Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 2 0.5000 VENDOR TOOL CODE START DEPTH DIFL 784 7.0 AC 784 7.0 GR 7789.0 $ LOG HEADER DATA DATE LOGGED: SOF~ARE VERSION: TIME CIRCULATION ENDED: TIMELOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 9107.0 9091.0 9076.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP PCM GR AC DIFL $ CABLE HEAD TENSION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMA RAY ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: 31-JAN-92 WSYS 256 REV GO02 VER 2 930 31-JAN-92 1606 31-JAN-92 9380.0 9113.0 7789.0 9110.0 1800.0 TOOL NUMBER 3974 3967 2806 3506 1309 1609 1503 8.500 7855.0 7847.0 XCD/SEAWATER 9.60 49.0 8.5 1.0 171.0 0.220 0.100 0.200 0.000 70.0 171.0 70.0 0.0 MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: CN WN FN COUN STAT : ARCO ALASKA INC. : 14-5A : PRUDHOE BAY : N. SLOPE : ALASKA 0.310 70.0 0.000 0.0 0.00 0.000 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: FEET 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 AC BCS 68 1 2 ACQ BCS 68 1 3 CFOC DIL 68 1 4 CHT BCS 68 1 5 CILD DIL 68 1 6 CILM DIL 68 1 7 GR BCS 68 1 8 RFOC DIL 68 1 9 RILD DIL 68 1 10 RILM DIL 68 1 11 SP BCS 68 1 12 SPD BCS 68 1 13 TEMP BCS 68 1 14 TTEN BCS 68 1 US/F DIM MMHO LBS MMHO MMHO GAPI OHMM OHMM OHMM FT/M DEGF LBS 4 4 20 789 90 0 4 4 20 789 90 0 4 4 50 746 76 1 4 4 20 789 90 0 4 4 50 746 76 1 4 4 50 746 76 1 4 4 20 789 90 0 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 20 789 90 0 4 4 20 789 90 0 4 4 20 789 90 0 4 4 20 789 90 0 * DATA RECORD (TYPE# O) 966 BYTES * Total Data Records: 341 Tape File Start Depth = 9130.000000 Tape File End Depth = 7770.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 107287 datums Tape Subfile: 4 417 records... Minimum record length: 62 bytes Maximum record length: 966 bytes 56 MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: CN WN FN COUN STAT : ARCO ALASKA INC. : 14-5A : PRUDHOE BAY : N. SLOPE : ALASKA 0.310 70.0 0.000 0.0 0.00 0.000 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: FEET 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 AC BCS 68 1 2 ACQ BCS 68 1 3 CFOC DIL 68 1 4 CHT BCS 68 1 5 CILD DIL 68 1 6 CILM DIL 68 1 7 GR BCS 68 1 8 RFOC DIL 68 1 9 RILD DIL 68 1 10 RILM DIL 68 1 11 SP BCS 68 1 12 SPD BCS 68 1 13 TEMP BCS 68 1 14 TTEN BCS 68 1 US/F DIM MMHO LBS MMHO MMHO GAPI OHMM OHMM OHMM FT/M DEGF LBS 4 4 20 789 90 0 4 4 20 789 90 0 4 4 50 746 76 1 4 4 20 789 90 0 4 4 50 746 76 1 4 4 50 746 76 1 4 4 20 789 90 0 4 4 50 74 6 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 20 789 90 0 4 4 20 789 90 0 4 4 20 789 90 0 4 4 20 789 90 0 * DATA RECORD (TYPE# O) 966 BYTES * Total Data Records: 341 Tape File Start Depth = 9130.000000 Tape File End Depth = 7770.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet * *** FILE TRAILER * * ** LIS representation code decoding summary: Rep Code: 68 107287 datums Tape Subfile: 4 417 records... Minimum record length: 62 bytes Maximum record length: 966 bytes 56 RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY Tape Sub file 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 1 0.5000 ~ VENDOR TOOL CODE START DEPTH STOP DEPTH DIFL 8826.0 9106.0 AC 8790.0 9084.0 GR 87720.0 9076.0 $ LOG HEADER DATA DATE LOGGED: SOF~WARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP PCM GR AC DIFL $ CABLE HEAD TENSION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMA RAY ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH : FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 31-JAN-92 WSYS 256 REV G002 VER 2 930 31-JAN-92 1536 31-JAN-92 9380.0 9113.0 7789.0 9110.0 1800.0 TOOL NUMBER 3974 3967 2806 3506 1309 1609 1503 8.500 7855.0 7847.0 XCD/SEAWATER 9.60 49.0 8.5 1.0 171.0 0.220 0.100 0.200 0.000 0.310 0.000 70.0 171.0 70.0 0.0 70.0 0.0 9~ pow srD dX.T. dX.T. qq~Sue~ ez.rs' Ic~V IdV IdV Id-V s$~ufl send. es epoD ~oo~ e~eN :senJnD Pr ~ :GI q~dep ed~ ~WVHW H~d HJ~G ~NO (~9 #~dA~) GHOD~VWHO~ · 0'0 000'0 00'0 VXEV~f : ~dO~IS 'N : XV~ ~OHCflHd : Vg-~r : · DNI VXSV~V ODHV : NflOD N~ ND : S>IHVWEH : (NI) ~WOGNV. T.E ~00~ Tape Subfile 6 is type: LIS ** * * TAPE TRAILER * ** * 92/ 2/ 4 O1 **** REEL TRAILER **** 92/ 2/ 4 O1 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 4 FEB 92 2:05p Elapsed execution time = 33.72 seconds. SYSTEM RETURN CODE = 0
