Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
184-091
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2V-08A (PTD184-091) OA Exceeded OPL Date:Monday, December 1, 2025 9:11:19 AM Attachments:TIO and Bleed History (5).pdf 2V-08A.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Thursday, October 2, 2025 1:54 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2V-08A (PTD184-091) OA Exceeded OPL Well Name: 2V-08A Facility: CPF2 PTD: 184-091 Well Type: Inj AA Number (if applicable): Internal Waiver (Yes/No if applicable): Type of Issue: OA Exceeded OPL Maximum Pressure (if applicable): 300 Date of Occurrence (if applicable): 10/1/2025 Hi Chris, KRU 2V-08A (PTD 184-091) is a produced water injector that has been shut in since 2012 due OA by conductor communication. The well has a surface casing leak into the conductor and a repair with a welded surface casing patch in 2009 partially repaired the well. Following the repair, the OA has an OPL of 200 psi. The operator reported the OA pressure of 300 psi today 10/1/2025. They bled the OA to 100 psi. No fluid in the conductor or conductor catch drum was observed. CPAI will continue to record the TIO pressures during operator walkdowns and perform bleeds as necessary on the OA. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 AAnnnnuulaarr BBeehhaavviioorrss |TIO Pressures and Injection Rates Well Name 2V-08A Annular Pressures 0 100 200 Date Pressure (PSI)Jul 13 Jul 27 Aug 10 Aug 24 Well is SI Tubing Pressure IA Pressure OA Pressure OOA Pressure Wellhead Temperature 0 50 Date Temperature (F)Jul 13 Jul 27 Aug 10 Aug 24 Injection Rates -1 0 1 DateRateJul 13 Jul 27 Aug 10 Aug 24 Gas Rate (MSCFD)Water Rate (STBD) INJ Date 90 7/5/2025 - 10/2/2025 Last Days AAnnnnuulaarr BBeehhaavviioorrss |Bleed History Date 90 7/5/2025 - 10/2/2025 Last Days Well Name Test Date IA Start Pressure IA End Pressure OA Start Pressure OA End Pressure OOA Pressure OOOA Pressure Well Name 2V-08A File Path (Copy and Place in File Explorer) SURFACE; 33.8-3,668.5— GAS LIFT; 8,045.7- 5.5" INNER CSG; 31.1-8,074.9 PACKER; 8,068.8 PACKOFF; 8,089.6 HANGER; 8,092.1 SEAL ASSY; 8,097.3 SBE; 8,102.8 XO BUSHING; 8,121.5 SEAL ASSY; 8,1 PBR; 8,1 ConocoPhillips Alaska, Inc. 2V-08A, 3/182016 2:03:52 PM Vertical schematic (actual) HANGER; 28.8 =77- bLIUKb I IGK; 6,Zbb.3 SBR; 8,269.3 PACKER; 8,285.1 GAS LIFT; 8,325.0 INJECTION; 8,394.E IPERF; 8,446.0-8,488.0 PATCH; 8,489.0 INJECTION; 8,499.4 LOCATOR; 8,516.2 PACKER; 8,518.0 SBE; 8,520.5 NIPPLE; 8,533.5 SOS; 8,541.1 IPERF; IPERF; 8,628.0-8,678.0 28.8 28.8 0.09 1 HANGER I Vetco Gray 7 1/16" 5M 3 1 514.0 511.0 13.98 1 NIPPLE Camco 2.875" "DS" Nipple 8,097.3 5,598.E 47.88 1 SEAL ASSY I Seal Assembly 80-40 (2' s Tubing Description String Ma... Baker Tie Back Assy 1 5.78 ID (in) 4.410 Top (ftKB) 8,068.81 Set Depth (ft... 8,147.7 I Set Depth (TVt 5,6 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des 8,068.8 5,579.5 48.00 PACKER "HR" ZXP Liner Top Packe 8,089.6 5,593.4 47.91 PACKOFF "RS" Packoff Seal Nipple, 8,092.2 5,595.1 47.90 HANGER "DG" Flex- Lock Liner Har 8,102.8 5,602.2 47.86 SEE Casing Seal Bore 8,121.5 5,614.8 47.81 XO BUSHING Cross over Bushing 8,134.9 j 5,623.81 47.77 1 SEAL ASSY I Seal Assembly w/Locator Tubing Description Stacker Packer 15tring Ma... 1 31/2 ID (in) 2.992 Top (ftKB) 8,137.5 Set Depth (ft... 8,270.0 Set Depth (TVt 5,7 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des 8,137.5 5,625.5 47.76 PBR BAKER 80-40 PBR 8,161.0 5,641.3 47.69 XO Enlarging 3.5"x4.5: 8,171.2 5,648.2 47.66 PACKER BAKER'S-TPRODUCTIO 8,175.3 5,650.9 47.64 XO Enlarging 4.5"x5" 8,176.6 5,651.8 47.64 MILL EXT MILL OUT EXTENSION 8,182.01 5,655.51 47.62 1 XOReducing i5"x4.5" 8,185.1 1 5,657.61 47.61 IXO Reducing 4.5"x3.5 KUP INJ Well Attributes I A Wellbore API/UWI Field Name Wellbore Status r 500292112800 KUPARUK RIVER UNIT INJ 11 Comment H2S (ppm) Date Annotation SSSV: NIPPLE Last WO: Annotation Depth (ftKB) End Date Annotation Last Tag: SLM 8,771.0 3/16/2016 1 Rev Reason: TAG, SET PLUG End De 5/1E Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc. Top (TVD) Top Incl Top (ftKB) (ftKB) (°) Des Corn 8,224.13 1 b,tR53.t5 1 4/.4/ 1 PLUU 2.81" U6-AZ PLULi 8,489.0 5,867.0 44.25 PATCH HES permanent patch across GLM aQ Top of patch set @ 8489' to 8511 `, mir Perforations & Slots Top (TVD) Btm (TVD) Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date 8,446.0 8,488.0 5,836.4 5,866.3 C-4, UNIT B, 9/13/1984 2V-08A nserts ati on Top (TVD) Valve Laic IN Tyr Top (ftKB) (ftKB) Make Model OD (in) Sery Type 1 1 8,045.7 5,564.0 1 CAMCO I KBG-2- I 1 GAS LIFT SOV INT 9 PRODUCTION; SURFACE; 33.8-3,668.5- J GAS LIFT; 8,045.7 5.5" INNER CSG; 31.1 PACKER; PACKOFF; HANGER; 8,092.1 SEAL ASSY; 8,097.3 SBE; 8,102.8 XO BUSHING; 8,121 SEAL ASSY; 8,1 PBR; 8,1 PACKER; B, or;ui . ' . e� WellsAlaska, Inc. �1]nofoPhllllps 2V-08A, 3/182016 2:03:55 PM HANGER; 28. SBR; 8,269.3 PACKER; 8,285.1 GAS LIFT; 8,325.0 INJECTION; 8,394.6 IPERF; 8,446.0-8,488.0 PATCH; 8,489.0� INJECTION; 8,499.4 LOCATOR; 8,516.2 PACKER; 8,518.0 SBE; 8,520.5 NIPPLE; 8,533.5 SOS; 8,541.1 IPERF; 8,586.0-8,612.0 IPERF; 8,628.0-8,678.0 PRODUCTION; 31.2-9,034.E KUP INJ CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2V-08A (PTD 184-091) OA Exceeded DNE Date:Tuesday, December 10, 2024 3:01:38 PM Attachments:AnnComm Surveillance TIO for 2V-08A.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Tuesday, December 10, 2024 2:46 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 2V-08A (PTD 184-091) OA Exceeded DNE Hello Chris, I am emailing a plan forward for KRU 2V-08A (PTD 184-091). CPAI conducted an OA Build Up Rate test and the OA has remained stable and below its pressure limit of 250 psi. The source of the OA repressurisation on 10/17/2024 is still unknown has not represented. CPAI will continue to record the TIO pressures during operator walkdowns and perform bleeds as necessary on the OA. The latest TIO plot, schematic and bleed reports are attached. Please let me know if you have any questions or disagree with the plan. Thank you, Jaime From: Well Integrity Specialist CPF2 Sent: Thursday, October 17, 2024 4:40 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2V-08A (PTD 184-091) OA Exceeded DNE Hi Chris, KRU 2V-08A (PTD 184-091) is a produced water injector that has been shut in since 2012 due OA by conductor communication. The well has a surface casing leak into the conductor and a repair with a welded surface casing patch in 2009 partially repaired the well. Following the repair, the OA has a DNE of 200 psi. The operator reported the OA pressure of 290 psi today 10/17/2024. DHD confirmed the OA pressure was 257 psi. They bled the OA to 40 psi. No fluid in the conductor or conductor catch drum was observed. CPAI intends to monitor the OA pressure for build up and conductor returns. A non witnessed, offline MIT-IA to 2000 psi passed on 6/27/2024. The last 90 days of TIOs and bleed events and the well schematic are attached. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2V-08A 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2V-08A 2024-10-19 257 40 -217 OA CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2V-08A (PTD 184-091) OA Exceeded DNE Date:Monday, October 21, 2024 2:24:47 PM Attachments:AnnComm Surveillance TIO for 2V-08A.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, October 17, 2024 4:40 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2V-08A (PTD 184-091) OA Exceeded DNE Hi Chris, KRU 2V-08A (PTD 184-091) is a produced water injector that has been shut in since 2012 due OA by conductor communication. The well has a surface casing leak into the conductor and a repair with a welded surface casing patch in 2009 partially repaired the well. Following the repair, the OA has a DNE of 200 psi. The operator reported the OA pressure of 290 psi today 10/17/2024. DHD confirmed the OA pressure was 257 psi. They bled the OA to 40 psi. No fluid in the conductor or conductor catch drum was observed. CPAI intends to monitor the OA pressure for build up and conductor returns. A non witnessed, offline MIT-IA to 2000 psi passed on 6/27/2024. The last 90 days of TIOs and bleed events and the well schematic are attached. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2V-08A 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 7 DATE: Tuesday,June 28,2016 P.I.Supervisor ' 'e'f l/ezl/t SUBJECT: Mechanical Integrity Tests t CONOCOPHILLIPS ALASKA INC 2V-08A FROM: Johnnie Hill KUPARUK RIV UNIT 2V-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Jf=-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2V-08A API Well Number 50-029-21128-00-00 Inspector Name: Johnnie Hill Permit Number: 184-091-0 Inspection Date: 6/21/2016 Insp Num: mitJWH160627111529 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2V-08A Type Inj NTVD 5580 " Tubing 12 170 - 173 - 167 PTD 1840910 ' Type Test SPT Test psi 1500 - IA 110 2010 - 1930 - 1925 - Interval 4'RTST P/F P ' OA 45 306 - 275 - 266 • Notes: LTSI 1.0bbls diesel used MS NOV 2 22016 Tuesday,June 28,2016 Page 1 of 1 Image"l~roject Well History File Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ ~' Z_//_ _~ ~ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: o Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: El Other BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY Project Proofing Scanning Preparation x 30 = ~ + c-~ = TOTAL PAGES __ BY: BEVERL'I~INCENT SHERYL MARIA WINDY , IS~ Production Scanning Stage f PAGE COUNT FROM SCANNED FILE: - PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES NO BY: Stage 2 BY; (SCANNING I$ COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAY$CALE OR COLOR IMAGES) ~ROBIN VINCENT SHERYL MARIA WINDY DATE:((~'[~'~ IF NO ;N STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO / /ox RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE; /S/ General Notes or Comments about this file: Quality Checked 12110/02Rev3NOTScanned.wpd MEMORANDUM TO: JimRegg Z~ I~~~iO~ P.I. Supervisor Z FROM: LG ~Cf i ~~~ ~ Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Friday, November 06, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2V-08A KUPARUK RIV iJNIT 2V-08A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J.(7' Comm Well Name: KUPARUK RIV UNIT 2V-08A API Well Number: 50-029-21128-00-00 Inspector Name: LG Insp Num: mitLG091105111730 Permit Number: 184-091-0 Inspection Date: 11/3/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 2V-08A ' -~ Well (Type Inj. ~' ~ TVD P.T.D~ ]sao9lo TypeTest SPT Test psi P INITAL P/F Interval s580 '' IA 500 2020 ~ _ _ ]soo '~ OA loo I zoo ~ Tubing ~ zsoo ~ _zsoo 1960 1960 ~ _ _ zso ~ zao i zsoo zsoo ii __ _ _ ___ Notes• Intiial post RWKO/Injection MIT. Good test but well is still flowing water and slight amount of hydrocarbon's (trace) from OA/Conductor ocasionally. !.,,~ .~qy~~ J t , t ~~ 4r7.{~fi~6iiYi~' ~E~!\ti \g C+ ~~1~ Friday, November O6, 2009 Page 1 of I • • Page 1 of 2 Regg, James B (DOA) ~~ ~ B4- From: Grimaldi, Louis R (DOA) Sent: Sunday, October 18, 2009 6:57 AM To: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Maunder, Thomas E (DOA) Subject: RE: KRU 2V-08A Follow Up Flag: Follow up Flag Status: Red Attachments: KRF 2V-8 Collapsed Casing 01-27-09 LG.jpg; KRF 2V-8 Collapsed Casing b 01-27-09 LG.jpg; KRF 2V-8 Collapsed Casing c 01-27-09 LG.jpg I've seen this well with the conductor stripped off. Pix attached From: Schwartz, Guy L (DOA) Sent: Friday, October 16, 2009 4:04 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay ,,, /~~(~ ~,~~ ~ ~~~ Cc: Maunder, Thomas E (DOA) ~'"~'~ Subject: RE: KRU 2V-08A Jim, This well has a long history of strange OA happenings. It has had multilple cement sgzs in the OA / IA if my memory is correct. Had hydrocarbon flowing up conductor too at one point. Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Regg, James B (DOA) Sent: Friday, October 16, 2009 3:41 PM To: DOA AOGCC Prudhoe Bay Cc: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: KRU 2V-08A MJ Loveland (CPAI) called this afternoon regarding KRU 2V-08A (PTD 1840910). She said they recently put the well on injection to warm it up for Commission-witnessed MIT and it began flowing ground water up the conductor; said analysis of water confirmed it was ground water, and it initially showed hydorcarbons in the C36+ range (contaminated with arctic pack?) but quickly cleaned up to just water. Well was shut in. I understood her to also say the pad/well has some active swamp gas issues so there may be some bubbling going on in the conductor. Annulus is cemented; they believe the path for communication is a microannulus in cement sheath and that it will close up with continued injection as well heats up. Agreed to allow them to put well back on injection (water) and call out inspector for planned MITIA to verify well has internal mechanical integrity, asked for results of MITIA and analysis showing water/gas is not from FOR/reservoir. Don't be surprised if water is leaking up annulus during the MIT. Told her to SI the well immediately and call if there encounter unexpected issues. Jim Regg AOGCC 12/1/2009 • • Page 2 of 2 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 12/1/2009 Attachments to Email dated 10/18/2009 KRU 2V-08A Collapsed Casing PTD 1840910 L~ Regg, James B (DOA) From: Regg, James B (DOA) ,~ ~~~~ ~~~~~~~~~ Sent: Friday, October 16, 2009 3:41 PM ~~. To: DOA AOGCC Prudhoe Bay Cc: Maunder, Thomas E(DOA); Schwartz, Guy L(DOA) Subject: KRU 2V-08A ~ ~~ ~-c~i I MJ Loveland (CPAI) called this afternoon regarding KRU 2V-08A (PTD 1840910). She said they recentiy put the well on injection to warm it up for Commission-witnessed MIT and it began flowing ground water up the conductor; said analysis of water confirmed it was ground water, and it initially showed hydorcarbons in the C36+ range (contaminated with arctic pack?) but quickly cleaned up to just water. Well was shut in. I understood her to also say the pad/well has some active swamp gas issues so there may be some bubbling going on in the conductor. Annulus is cemented; they believe the path for communication is a microannulus in cement sheath and that it will close up with continued injection as well heats up. Agreed to allow them to put well back on injection (water) and call out inspector for planned MITIA to verify well has internal mechanical integrity, asked for results of MITIA and analysis showing water/gas is not from EOR/reservoir. Don't be surprised if water is leaking up annulus during the MIT. Told her to SI the well immediately and call if there encounter unexpected issues. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~~,y!, .:~~~~°,~ ~;n 1 ti; ~0~~ • Page 1 of 1 10/16/2009 2V-08A (184-091) Question Page 1 of 2 Regg, James B (DOA) ~ ~~'d-~~ ~ From: Regg, James B (DOA) ~~t ~~2~ +i~~ Sent: Wednesday, August 26, 2009 1:25 PM To: 'NSK Well Integrity Proj' Cc: Schwartz, Guy L(DOAyNSK Problem Well Supv; Maunder, Thomas E(DOA) Subject: RE: 2V-08A (184-091) Question MJ - Got your voice message this morning; thank you for the reminder about this request. Through the workover and surtace casing weld repair, it appears CPAI has restored mechanicai integrity to the well. Therefore, you do not need an administrative a~proval to inject into this well. The 10-404 is due within 30 days of completing the approved well work; please send 404 ASAP. Not clear why the submittal is being pinned to the restart of injection (compietion of flowiine modifications). Jim Regg AOGCC 333 W.7th Avenue, Suite 100 ~'~~'~^'~^'~~~°y~' ~ a- ~ ~' •~ ~~~~G Anchorage, AK 99501 907-793-1236 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Saturday, August 22, 2009 10:52 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: Schwar~, Guy L(DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: 2V-08A (184-091) Question Jim/Tom, ConocoPhillips completed a workover on water injector 2V-08A (184-091} in May 2009. The follow up 10-404 has not been filed yet as the well has not been brought on line due to flowline modifications. During the workover a 5.5" inner production casing was run and passed an MITIA (State witnessed MITIA will be completed when well is online). The original 7" production casing does not have integrity due to the squeezed perforation holes ~ 600'. The 9 5/8" surface casing leak was repaired earlier in the year with a surface casing weld, however has a limited recommended operating pressure less than 500 psi. The welf lines are nearly complete and before it is placed in service, we need to know if an AA to operate this well in water only service is required. I have attached the a summary of the current condition of the well (which is downloaded from AOGCC website). Please Advise. MJ Loveland Well Integrity Project Supervisor 8/26/2009 2V-08A (184-091) Question ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 «2V-08A 184-091. pdf» Page 2 of 2 8/26/2009 2V-08A (184-091) Question ~ Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Wednesday, August 26, 2009 2:25 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E(DOA); Schwartz, Guy L(DOA) Subject: FW: 2V-08A (184-091) Question Jim, Page 1 of,~ ~ ~ My error, the 10-404 has been submit#ed - it has just not made it to our paper files yet, Regards MJ Laveland Well lntegrity Project Supervisor ConocoPhillips Alaska, lnc. Office (907} 659-7043 Ce11 (907) 943-1687 ~~ ~'~1~,~`~ ! {~tJ~, ;.f "~ ~~1~~~ ., ..u ~rom: Allsup-Drake, Sharon K Sent: Wednesday, August 26, 2009 2:18 PM To: NSK Well Integrity Proj 5ubject: RE: 2V-08A (184-091) Question We filed the 404 far the workover in May on 6/12/2009. I sent a copy to Louise but if you d'+dn't get a copy, 1 can send i# to you. Thank yau, Sharon 263-4612 From: NSK Well Integrity Proj Sent: Wednesday, August 26, 2009 1:45 PM To: Allsup-Drake, Sharon K Subject: FW: 2V-08A (184-091) Question Sharon, Apparent#y we do not need to vvait untii the ~+vel! is online to fifs the pas# rig 4~~F. If it has not been fiied, please do so. Tl~anks MJ 8/26/2009 2V-08A (184-091) Question ~ • From: Regg, James B (DOA) [maiito:jim.regg@alaska.gov] Sent: Wednesday, August 26, 2009 1:25 PM To: NSK Well Integrity Proj Cc: Schwartz, Guy L(DOA); NSK Probiem Weil Supv; Maunder, Thomas E(DOA) Subject: RE: 2V-08A (1$4-091) Question MJ - Got your voice message this morning; thank you for the reminder about this request. Page 2 of ~\ 1 Through the workover and surface casing weld repair, it appears CPA! has res#ored mec~-anica! in#egri#y to the weli. Therefore, you d_o not_need an administrative approv_ai to inject into this we11. The '! 0-404 is due within 30 days of comp{eting the approued weli wark; piease senti ~04 ASAP. IV~t ciear why the submittal is being pinned to the restart of injection (completion of flovvline modifications). Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Saturday, August 22, 2009 10:52 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: Schwariz, Guy L(DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: 2V-08A (184-091) Question Jim/Tom, ConocoPhillips completed a workover on water injector 2V-08A (184-091) in May 2009. The follow up 10-404 has not been filed yet as the well has not been brought on line due to flowline modifications. During the workover a 5.5" inner production casing was run and passed an MITIA (State witnessed MI71A will be completed when well is online). The original 7" production casing does not have integrity due to the squeezed perforation holes ~ 600'. The 9 5/8" surface casing leak was repaired earlier in the year with a surface casing weld, however has a limited recommended operating pressure less than 500 psi. The well lines are nearly complete and before it is placed in service, we need to know if an AA to operate this well in water only service is required. I have attached the a summary of the current condition of the well (which is downloaded from AOGCC website). Please Advise. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. 8/26/2009 • Maunder, Thom~~ E (DQA) From: Maunder, Thomas E {~OA) Sent; MQnday, July Q6, 2Q09 4:12 PM To: 'Gober, Moward' Gc; Aifsup-Drake, Sharon K Subj~ct: RE; 2V=Q8~+(184-091) Page 1 of ~,~ ~ „~~~:#~~~'~J~~ ~~.~~ :~. ~ ~DD~; How~~l, N~ r~~~d ~ s~r~d in ~ r~~i~~ ~~, D~# pt~ir~t ~rw~~ it ~t~~ld ~~pp i~~~ if th~ it~m ~~d th~ d~pt~ ~rould b~ ~g~ r. ~r~ t~t~r~ ~~ ~ E~ ~ ~ ~t~r et b~ " s~y~°: ~~~ ~~: ~'~~ F m: Gober, Haward [mailto:Mrnn-ard.Gober@~or~ocophiliips.com] t; Monday, .luty 06, 2(~f}4 4:09 PM To: aunder, Thvmas E (DOA) Cc: ~f p-~rake, Sharon K Subje~t. E: 2V-0$A (184-091j Tom, The bottom of the ~ is the sea! bor~ a# S3 03' RKB. The tubing is correct and this woult~be the "tubing packer equivalent". W~ have been #a!iowing e 404 format by listing packers and differently if that is what yo wouid like. Would you like a corr point forward? P{ease let me know if you have ar~other questions. Thanks, Howard GQaer Welts Engineer CoraocoPhillip~ Alaska, inc. 9p7-263-4220 O~ce 907-24Q-5515 C~II Howard. Gober@eonacophillips.co~n from; Maunder, Thomas E Sent: Sunday, July R5, 2f}0~ To: Gc~ber~ Howard sub~ectc 2v-osA (184- 1j ~bA) [mailto:tom. 11;45 AM inio this SBE. Thersfore, y~u are (s sspara#ely. We can surely submii the info 404 for this weti or is your request for 404's Heward, I ar'rt r~viewir~g the fl4 for the r'ec~nt worKc-ver performed on this weil. So f~ar as 1 n tefl, the "tubing pack~r equivalent" that tablishes #he bottom of tl~e IA is tt~e seal bore a# ~8100'. 1s ihat ~~t? I a~sc~ t~ave a rsquest, iooking at ~he in rmation 6ne for Packers/SSSV or~ the 404 when ther~ are mu~tipl~ ipment items ~isted it gets 7/6/2QQ9 ~ Maunder, ThQmas E (QQA) From: Gober, Howar,d [Howard.G~ber~c~nocr~phi)lips.cam] Sent: Monday, July 06, 2QQ~ 4:09 PM Tp; Maunder, Thomas E ([34A) Cc; Alfsup-Qr-~ke, Sharon K Subject: R€; 2V-08A {184-091) Tom, • Page 1 of 2 The bott~rn of the fA is the seai bare a# 8'f 03' RKB. The tubing is stabbed into ihis SBE, Th~re€ore, you are correct and this would be the "tubing packer equivalent". We have been foliawing the 404 formai by listing packers and depths separately. We can surely submit #he infa differently if that is what you would like. Wou1d you like a corrected 404 for this welf or is your request for 4(?4's point forward? Please let me know if you have any other questions. Thanks, Howard Gc~ber Wells Engineer Conc~col'hillips Al~ska, ln~. 9Q7-263-422Q C3ffice Fromc Maunder, Thomas E(DOA) [mailko:tom.maunder~a al~ska.gov] Sent: Sunday, July 05, 2009 ~~.:45 AM To: Gober, Moward Subject: 2V-08A (184-U91) Howaed, t am reviewing the 404 for th~ recent vNarkover performed on this well. Sa fiar as t can tell, the "tubing ~acker equiv~i~r~t" th~t e~tablishes the bottom of ~he IA is the seal bore at ~8~OU'. Is that cc>rrect~ i a1~ h~ve a r~quest, lovking at the information fine for~ Packer$/SSSV on the 404 when th~:re ar+~ multiple ~uipmen# items li~ted it gets quite eluttered. Is it pp~s[bte when multiple items are listed to fist the item faflow~d by the de~th- rather than list ~fl the it~ms and then th~ e~epths? Thanks in advanc+~. Tom Maunder, PE AOGCG 7/~/20~9 I~ECEItTEC~ ~ i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 1 ~ 2009 Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ^ Repair Well Q Plug Perforations ~ Stimulate ^ Other ~ Alter Casing ^~ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^~ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, IIIC. Development ^ Exploratory ^ 184-091 /~ 3. Address: Strati ra hic g p ^ Service ~' 6. API Number: ~ ~/G- P. O. Box 100360, Anchora e, Alaska 99510 50-029-21128-00 • 7. KB Elevation (ft): 9. Well Name and Number: / ~y RKB 113' 2V-08A ~ 8. Property Designation: 10. Field/Pool(s): ADL 25655 ~ Kuparuk River Field / Kuparuk River Oil Pool .~ 11. Present Well Condition Summary: Total Depth measured 9050' - feet true vertical 6279' • feet Plugs (measured) Effective Depth measured 8951' feet Junk (measured) true vertical 6204' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 103' 103' SURFACE 3755' 9-5/8" 3868' 2851' PRODUCTION 8921' 7" 9034' 6267' INNER CASING 8041' 5.5" 8075' 5584' Perforation depth: Measured depth: 8446'-8488', 8586'-8612', 8628'-8678' true vertical depth: 5837'-5866', 5937'-5956', 5968'-6005' Tubing (size, grade, and measured depth) 3.5", L-80, 8120' MD. ~ Packers & SSSV (type 8~ measured depth) HR ZXP liner top pkr, SBE, Baker S-3 prod pkr, Camco HRP, Baker FB-1 pkr @ 8069', 8103', 8171', 8285', 8518' Camco'DS' nipple ~ 514' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^ GINJ^ WINJ ^~ ~ WDSPL^ 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: 309-162 Contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Wells Engineer ` Signature Phone: 263-4220 , Date ~ l4~ ~ ~ ~ n All ke 263-4612 Pre a b Form 10-404 Revised 04/2006 '~~~~I~ ~c~~ Q l~~~os ~ R~ ~~G~~~ ~Submit Original Only ~~~~~ ~~ CONDUCTOR, 0-103 TUBING. SOB NIPPLE,514 SURFACE, 34 3.669 Annotation I Depth (flKB) End Date Mnotation I Las~ Motl By Last Tag~ RKB 8 649.0 I 5l2412009 Rev Reason: ADJUST CSG OD/ID ~ Imosbor End Date ~ I I 6/1Z2009 Casing Strin s Casing Dascription String 0... ; String ID ... iop (ftKB) ~ Set Dept~ (t... Set Depth (ND) _. String Wt... Sbing ... String Top ThN CONDUCTOR i6 '~ 15.062 0.0 103.0 103.0 65.00 H-00 Casing Dascription String 0... IString ID ... Top (HKB) Set Dapth (t... Set Depth (ND) ... String YW... String ._ String Top ThM SURFACE 9 5/8 ~~~. 8.525 33J 3,668.5 2]28.4 36.00 J-55 Gasing Dascription String 0... ~,String ID ... Top (ftK6) Set Dapth (t... Set Dapth (ND) ... String Wl... String ._ Stnng Top Thrd PRODUCTION 7 ~ 6.157 312 9,034.6 6,267.5 26.00 JSS Casing Description String 0... I,String ID ... Top (kKB) Set Depth (i... Set Depth (ND) ... String Wt... String ... String Top ThN 5.5" INNER CSG S 12 ! 4.950 31.1 8,074.9 5.583.5 15.50 L80 HYD511 5.5'ir~~v=_? ~~ ~j j„ X,UJ1.1 S,S9S.1 4/.~JO HAN(itH "L7Ci"hleX-LOCKLInErtlanger CSG. 3'~ ~B.OJS ~,_ __ 'ACK[R. B.U69 ~ ~ ~ 8,1~2.8 $,602.2 I 4~.$6 $BE Casing Seal Bore t. .~ ~ 8,1349 5,623.8 47.77 SEAL ASSY I Seal Assembly w/LOCator -- ~ ' ~~ g tription ~ ~ String 0... IString ID ... Top (HKB) Se~ Depth ((... Sel Depth (ND) ... ~.String Wf... Str ~ I I I i SI2Ck2t P2Ck2f I 31l2 2.992 I 8,137.5 I 8,270A 5.715.0 I 9.30 L HANG~~. a osa ` Com Ie Uon De tails '~ ~, ~ i TopDepih~~ ~ SEPLASSY, e 097 \ I ~~ ~ (ND) ~ ToDincl', ' ` SBE 8 103 • .7j ~ 'i To kKB P ( ) (~B) ~ (°) ~~ Item Desai t P ion ~ Commant .. . . __ - ~ 8.137.5 5.625.6 47.76 IPBR I i BAKER80-0OPBR ~~ 6 O ~ I _. I 8.1 12 5,6482 47.66IPA CKER BAKER'S3'PRODUCTIONPACKER seunssr, __l 8.182.0 5,655.5 47.62IX0-Reducing S'x4.5" 4. B.'35 '~ aea.a.~3a ~- ~~~ 8,185.7 5,657.6 47.61IX0-Reducing 4.5"x3.5 3. 8,224.6I 5,684.5 47.651NIPPLE '~ -. CAMCO'DS'NIPPLE 2. 82 e 5710.8~ 4740'OVERSHOT I, _ gqKERPOORBOVOVERSHOTw/5.65'SWALLOW __ 4. _'- __. ___ -_. - , ~ gD s , , T b c'pf on Str g 0... ~String ID .. Top (ftNB) Set Dapth (t... Set Depth (ND) ... String WI... String ... String Top Thr - I UBING O g nai 3 12 2 992 8,267_3 8,541.9 _ 5,9052 I 9.30 J-55 EUEBrd _ _ __- ~ncKeR e ,n " . _ __ , . . - ' Completion Details -- __ Top Depth (ND) ToP Incl Top (kKB) (ryKg) (°) Itam Description Comme~rt ID ~ 8,2673' S,7132~~ 4738~SBR CAMCOOEJ(LowerSectiononly)w/SLICKSTICK 2. ~ 8,285.1 5,7252I 4726 PACKER CAMCO HRP-ISP PACKER 2. 8,432.7 5,827.1 45.30 BLAST JOINT 2. 5,516.2 5,886.5 43.85 LOCATOR LOCATOR 4. Nica~e.e.z25- 8,Si8A 5,887.9 43.83 PACKER BAKER FB-1 PERMANENT PACKER 4. ~ $52Q5~ 5,889JI 43.SO.SBE 3. oveRSNOi._ _ B.P6, ~~_.~, 8,533.SI 5,899.1 4364'~NIPPLE CAMCO'D'NIPPIENOGOw/NIPPLEREDUCER ~ 2. . . ..__' _._. BAKERSNEAROUTSUB I$541 1~ 5 904 6 43 54'~SOS ' 3. seR,fl,2s7 ._.__ . , . . I - -_.. . _-__ _ . ._ . . s etc ~Y~1@f ~fl iu s valv s um fish ) ~~ OI @~~fIC f@tfl@VBb~ Ap(ER.8.285- . ! I , p g , e , p p , . P ~ ___ _ H th i ~ P GASLIFT, 8.325 ~To ftK6 P ( 1 (HKB) (°I Dascri t' ' Comment P ~on RunData ID 8.489 S,Sfi7.0 4425 PA~CH ~HES permanem patch across GLM u~8499' RKB. Top of 5/18/2000 2. indec7ioN. ~~, ~patch set o~ 8489' ~0 8511': min. ID 2375" ~ _ 8.3% ~ . . . .. .. .. P f ti & Sl t er ons ora o s ... __ ___ -- . ~i sno~ ', IPERf. Top (ND) Bim (fVD) Dens 'i B,sa6-8A88 ~ To NKB '. Btrn ftK8 (ftNB , P( 1, ( ) 1 ftKB Zona Data (sh-~ T Comma~A ( 1 YPa I 8,4461 g,qgg 5,836.6 5,866.3 C4, UNI7 B, 9/13/19&4 12.0 IPERF I720 aeg. phasing; S 1l2" Csg Gun ~ 2V-08A I PATCH.8.189 ~ INJECTION. ~ ~.• j MBfIC~f@~ ~Et21~S . . .. __ .. _ _ . . _ _.__._ _- . -. . . . . . B,a99 ",TOpDapth Top ~ . . _ ,_. Port . ._..._ __ _ ~~ ~ , (TVD) Incl OD Valve Lateh Size TRO Run Stn Top(ftK6) (kKB) (°) Make Motlel (~~) Serv Type Type (in) (psi) Run Dale Co ~ocnTOR. . . ~"_ -~ 1 8 045J 5.564.1 48.09~CAMCO KBG2-9 1 GAS LIFT SOV INT 0.000 0.0 5/17/2009 8,516 ~ 2 8,325A 5,7524 46.SSICAMCO KBUG 7 INJ DMY BEK 0.000 0.0 9/32006 ancKeR,e,sia ~ 3 8,394.6 5,800.4 45.97 CAMCO KBUG 7 INJ DMY BEK O.OOOII 0.0 9/3/2006 sae,a,szo _ 4 8,4994 58744 44.06 CAMCO KBUG i INJ Patch 0.0001 0.0 5„8,2000 NIPPLE.8.53a ...J~'. 505.8,5.1 IPERF, 8.586-B,61Y IPERF, Bb28-8,6]B ~-- ~ PRODl1CT10N, " 31 9,035 TD, 9.050 ~ KUP • 2V-08A ConacoPhillips ; ~ ± ... :~,,:.,~.~ i,,. ~ - -- ,.. ___--_...eiicooi~ zG-dan snz~ oo~ ~.r~re~=in . SGii~n~a~ic-Au:u:il TUBING.508 ~ NIPPLE,510 SURFACE. . _ _ 3l 3.669 5.5' HANGER,_ 8.092 SEAL ASSV, 8.09]'~ SBE.8.103 - SEAL ASSY, 8.135 ~ PBR. 8.138 - ~ACKeR,8.t71 NIPPlE.8.2P5- SBR, 8,261 - 'ACKER.8,285- ~- GASLIFT, ._ 8.325 INJECTION, 8,395 IPERF, B.N6-BR88 I.OCATOR, _ _ _ 8,516 ~ACKER.8.516 SBE,8,520 - NIPPLE, 8,5% SOS. 8.541 - IPERF, _ 8,586-8,612 IPERF. 8.628-e,b]8 ~ ~ -- PRODUCTION. 31-9.035 ~ TD.9.050 5/192009 VIEW SCHEMATIC w/Alaska 3/1984 ~ 4.O~IPERF ~90deg.phasing;4" below mandrel Hgr to 2V-08A 2V-08A Well Events Summary DATE SUMMARY ~ • p l?C ~^~ ~ 5/6/09 PRE-RWO MIT- P CASING ( ED ~, FT-LDS 3 LDS WERE SEIZED WITH THE GLAND ~ NUTS, HAVE BEEN FLAGGED AND TAGGED. 5/19/09 PULLED BALL & ROD FROM 8225' RKB. REPLACED SOV WITH INTEGRAL LATCH DV. MIT TBG 2500 PSI, MIT IA 3000 PSi, BOTH PASSED. ATTEMPTED PULL PLUG BODY FROM 8225' RKB. IN PROGRESS. 5/20/09 PULLED RHC PLUG BODY Ca~ 8224' RKB1 BAILED FILL FROM 8470' TO 8495' WLM. IN ~0~~ ~~ PROGRESS. 5/21/09 BAILED FILL AND METAL DEBRIS FROM 8491' TO 8505' WLM. IN PROGRESS. 5/22/09 BAILED FILL OFF PLUG. PULLED PRONG @ 8533' RKB. IN PROGRESS. 5/23/09 BAILED FILL TO PLUG BODY C~l 8533' RKB_ ATTEMPTED PULL PLUG, UNABLE TO ENTER PATC~~ 8499' RKB. IN PROGRESS. 5/24/09 PULLED 2.25" CA-2 PLUG Ca~ 8533' RKB. DRIFTED TBG, TAGGED (a~ 8647' RKB~S' WLM. :MEASURED BHP @ 8632' RKB: 3606 PSI. COMPLETE. L~ Cc~nc~cc~Ph~tlips Time Log & Summary 1NeJNiew We6 ReAOrting Re p o rt Well Name: 2V-08A Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 5/7/2009 4:00:00 PM Rig Release: 5/18/2009 3:30:00 AM 5/07/2009 24 hr Summarv Move Nordic Rig 3 from 1 E Pad to 2V-08A. MIRU, spot aux. equip. Open up well, Set Test plug, ND Master Valve. NU BOPE. Test BOP. 06:00 07:00 1.00 MIRU MOVE OTHR P Load out rig mats to take to f/ 1 E to 2V 07:00 15:30 8.50 MIRU MOVE MOB P Move Nordic Rig 3 f/ 1 E Pad to 2V 15:30 16:00 0.50 MIRU MOVE PRLO P Set "T" mats, spot and level. 16:00 17:00 1.00 COMPZ MOVE PRLO P Acceot Nordic Ria 3 la~ 16:00 hrs Spot and set aux. equipment. Berm u around ceilar. 17:00 18:00 1.00 COMPZ RPCOM NUND P Open well - 450 psi - bled off. ND 7 1/16" Full open valve and install Test 18:00 21:30 3.50 COMPZ RPCOM NUND P NU BOPE 21:30 00:00 2.50 COMPZ RPCOM BOPE P Test BOPE (a~ 250/3,000 psi - 24 Hr BOP Test notice was given to AOGCC @ 20:25 hrs on 5-6-09 and Witness of test was waived by John Criso Ccil 16:00 hrs on 5-7-09. Continue to Test BOPE. PU, MU & RIH w/ 6 1/8 drlg BHA to 403', Tag cmt @ 465', Drill out cmt to 810', Drill out Fast drill lu f/ 810' to 813' - fell free. 00:00 02:30 2.50 COMPZ RPCOM BOPE P Continue to Test BOPE @ 250/3,000 psi. RD Test Equip. Drawdown - 3,000 psi, 1,500 psi after 200 psi - 27 Seconds 3,000 psi - 2 minutes 10 seconds 4 - N2 @ 2,250 psi. 24 Hr BOP Test notice was given to AOGCC @ 20:25 hrs on 5-6-09 and Witness of test was waived by John Cris 16:00 hrs on 5-7-09. 02:30 03:30 1.00 COMPZ RPCOM OTHR P Pull test Plug and Set Wear ring. 03:30 08:00 4.50 COMPZ RPCOM OTHR P Continue to Load Pipe Shed w/ 4 3/4" DC's, Boot baskets, LBS and Jars. Berm u cuttin s box. 08:00 09:00 1.00 0 463 COMPZ RPCOM PULD P MU BHA #1 consistina of 6 1/8" mill tooth bit, 2- boot baskets, bit sub, 4 3/4" bumper sub, fishing jars, on 3 1/2" drillpipe. RIH to 403'. Displaced diesel out and replaced with 9.6 ppa • 09:00 12:00 3.00 463 563 COMPZ RPCOM OTHR P Established parameters. 4 BPM w/160 psi. Up 45K dwn 45K. torque .9K. Tagged up at 465'. Drilled down to 563', circulated clean. SD. 12:00 14:00 2.00 563 563 COMPZ RPCOM OTHR T Drain stack and change out IA valve. 14:00 18:30 4.50 563 703 COMPZ RPCOM OTHR P Established circulation. Continued to drill out cement 63' to 703' w/ 7-10k WOB @ 50 rpm's @.9k Torq, Circ @ 4 bpm @ 160 psi, 45k up wt, 45 dn wt, 45 Rot wt 18:30 22:00 3.50 703 796 COMPZ RPCOM OTHR P Continue to drill out cmt f/ 703' to 796' W/ 7-10k WOB @ 100 rpm's @ 1k tor , Circ. 6 b m 360 si 22:00 22:30 0.50 796 796 COMPZ RPCOM LOT P Attempt to PT to 1,000 psi and_ Broke down Ca~ 470 psi w/ 1/2 bbi um ed - bled down to 250 si. 22:30 00:00 1.50 796 813 COMPZ RPCOM MILL P Drill out f/ 796' to 810' and Tag HES Fast drill lu change rpms f/ 100 to 50 w/ 1.5k torq and,Drill out to 813' w/ 7k WOB - Pluq released 48 up ~ wt, 48 dn wt, 48 Rot wt. 5/09/2009 Chase fast drill remanents to Top of CaC03 plug @ 3,990' +/-, dry drill on plug, POOH, LD drlg assy, PU & RIH w/ 6.151" Drift assy to 900', POOH, LD drift assy. PU & RIH w/ reverse circ. Junk basket, mill 2' and func RCJB. POOH, redress and re run same - mill over to 4,004' 00:00 00:30 0.50 813 833 COMPZ RPCOM OTHR P Continue to Ream down f/ 813' to 833' w/ 1.5k torq @ 50 rpm's, circ 6 bpm @ 360 psi. CBU - Monitor well. 00:30 04:00 3.50 833 3,990 COMPZ RPCOM PULD P RIH f/ 833' U 3 990' PU DP. Ta u 3 990'. 04:00 05:00 1.00 3,990 3,965 COMPZ RPCOM CIRC P Pull up to 3,965' and circ. 1 hole voi. @ 6 bpm @ 1,000 psi ICP and 800 qsi FCP. 05:00 06:30 1.50 3,965 3,991 COMPZ RPCOM MILL P RIH to 3 990' and Drv drill on Pluq remnants to 3,991' @ 60 rpm's w/ 2.5k - 3.5k tor ue. 06:30 08:00 1.50 3,991 3,991 COMPZ RPCOM CIRC P Puil up to 3985', Circulate hole clean. SD monitor well. Static. 08:00 08:30 0.50 3,991 0 COMPZ RPCOM TRIP P POOH standing back drillpipe and DCs. Layed down boot baskets, bit and bit sub. 08:30 10:30 2.00 0 998 COMPZ RPCOM TRIP P MU BHA for drift run Two .1 " Strin Milis, Bumper Sub, oil jars, and 12 - 4-3/4" drill collars to drift 10:30 11:30 1.00 998 0 COMPZ RPCOM TRIP P POOH, standing back drill pipe and drill collars. 11:30 14:00 2.50 0 3,995 COMPZ RPCOM TRIP P MU BHA for scra er run. Reverse junk basket, 7" 26# casing scraper, boot basket, bumper sub, oil jars, and 12 drill coliars. RIH and~~q,q~ 14:00 16:00 2.00 3,995 3,997 COMPZ RPCOM WASH P Dropped ball for reverse basket. Up wt 86K dn wt 65K. ROT 75K Torque 3.0. Dry drill 3 times and kick pump on #o clean up pipe. Made 2' total, bottoms feels very soft. PU and ~circulated bottoms u . 16:00 18:00 2.00 3,997 0 COMPZ RPCOM TRIP P POOH standing back drill pipe and drill collars. LD BHA. 18:00 21:00 3.00 0 3,985 COMPZ RPCOM TRIP P MU and RIH w/ re-dressed Reverse circ. 'unk basket to 3.985'. 86k up wt, 65k dn wt. 21:00 22:30 1.50 3,985 3,985 COMPZ RPCOM CIRC P Displace 9.6 ppg KWF fluid w/ 11.0 ppg KWF @ 6 bpm @ 1,100 psi and obtain slow um rates. 22:30 00:00 1.50 3,985 4,004 COMPZ RPCOM MILL P Dro bail and RIH U 3 987' - ta u- Beclin milling @ 50 rpm's w/ 2,500 fUlbs torque circ @ 6 bpm @ 1,200 psi, chase pluq_ to top of RBP (a)_ 4,002' ( 4,007' ORKB Nabors 26E \ (3,997' Nabors 3S RKB in which RBP was set and recorded and begin milling w/ 10k WOB. Mill 5/10/2009 Continue to mill over to 4,005' and RBP let loose, chase to 4,010', POOH and recovered 1.65' of Fast drill plug. MU and RIH w/ BHA #5 to 4,045', engage and POOH w/ RBP. PU and RIH w/ BHA #6 to 4,003', Slip and Cut 84' of drill line. Secure well - Shut down and chan e out Ba lor brake on ri . 00:00 01:30 1.50 4,004 3,983 COMPZ RPCOM MILL P Continue to mill over fast drill w/ RCJB f/ 4,004' U 4,005', PU to reface mill and slacked off to 4,010' (4,015' ORKB) PU to 4,000 and RIH to 4,015' w/ no Rotation and no tag. Pooh to 3,983'. Blow down Top drive. 01:30 04:00 2.50 3,983 0 COMPZ RPCOM TRIP P POOh f/ 3,983' to surface and break down RCJB and recovered 1.65' of HES Fast drill lu . NOTE: Fast drill plug tapped into retrieving neck on RBP and RBP was released when strin was icked u to reface mill shoe. 04:00 06:30 2.50 0 3,603 COMPZ RPCOM TRIP P MU BHA #5 and RIH w/ RBP retreiving tool, X-O, X-O, 7" CSG Scraper, Bit Sub, LBS on 111 jts DP from derrick to 4,045'. 06:30 07:00 0.50 3,603 4,045 COMPZ FISH TRIP P Continue to RIH w/ BHA # 5 t, agged RBP 4045'. PU, indicated we latched onto the RBP, dragging at each casing coliar. Lowered back down and RBP set down on first casina collar and stacked out. 07:00 10:30 3.50 4,045 0 COMPZ FISH TRIP P Close in annular. Pressure test casin would not hold again, est. rate of 320 psi @ 7 SPM or 1/2 BPM. Open annular, POOH standing back drill pipe, laying down BHA and RBP. While pulling out of hole the Baylor Brake locked down. After inspection found large crack in brake housin . 10:30 11:30 1.00 0 414 COMPZ FISH PULD P MU BHA #6 consisting of 10' washpipe shoe, boot basket, scraper, LBS, jars and 12 drill collars. Load replacement Baylor Brake onto ri floor with crane. 11:30 14:30 3.00 414 4,003 COMPZ RPCOM TRIP P RIH with BHA #6 as a kill strinq to +/- 4000' ver slow (not to overheat brakes) and shut down for rig repair Ba lor Brake . 14:30 16:00 1.50 4,003 4,003 COMPZ RPCOM RGRP P Slip and cut drill line. 16:00 00:00 8.00 4,003 4,003 COMPZ RIGMNT RGRP T Rig repairs. Start dismantiing Baylor 5/11 /2009 Continue to Repair Baylor Brake on rig. Continue to RIH w/ BHA #6 C/O to 8,278'. CBU. POOH, lay down BHA #6 and PU & MU StackerPKR ass & RIH to 4,787'. 00:00 06:30 6.50 4,003 4,003 COMPZ RIGMNT RGRP T Ri Re air: Instailing New Baylor Brake ass . Com lete 06:30 10:00 3.50 4,003 8,273 COMPZ RPCOM TRIP P Contin e RI from 4 10:00 1230 2.50 8,273 8,273 COMPZ RPCOM FCO P Established rate of 6 BPM w/1510 psi. Lowered clean out assemblv. ta ed to of OEJ slickstick (a~ 8262' cleaned down to 8273'. Pump high visc sweep and circulated hole clean. No visable signs of trash etc in returns. Small amount of gas circ I t. Shut down pump and monitored well, static. 12:30 17:30 5.00 8,273 0 COMPZ RPCOM TRIP P LD one single and stand back drill pipe coming out of hole. Stand back drill collars and LD BHA. 17:30 18:00 0.50 0 0 COMPZ RPCOM OTHR P Change over floor equipment to TBG. 18:00 20:00 2.00 0 215 COMPZ RPCOM PULD P PJSM PU and MU Stacker Pack r Ass 20:00 2030 0.50 215 215 COMPZ RPCOM OTHR P ange over Floor equipment to DP 20:30 00:00 3.50 215 COMPZ RPCOM TRIP P RIH w/ Stacker Packer Assv on DP to 4 787' MD 83k u wt, 63k dn wt. 5/12/2009 Continue to RIH to 8,271' +/-. Set & Shear out of PBR. POOH locating CSG Leaks. PU and RIH w/ Tension PKR and test remaining upper section of the hole. RU and RIH w/ EX Patch and set. POOH w/ setting tool. PU and MU Com letion Ass and RIH 00:00 01:30 1.50 4,787 7,187 COMPZ RPCOM TRIP P Continue to RIH w/ Stacker Packer Ass f/ 4,787' to 7,187'. Diplacement was over. had slight flow on DP - made decision to circulate surface to surface. 01:30 03:30 2.00 7,187 7,187 COMPZ RPCOM CIRC P Circulate @ 2 bpm @ 370 psi 03:30 05:00 1.50 7,187 8,272 COMPZ RPCOM PULD P Continue to R Stacker Packer Assy f/ 7,187' to 8,272', observe seals slide over Stub w/ 5k dn wt. PU to 8,264' 05:00 05:30 0.50 8,264 8,264 COMPZ RPCOM CIRC P Pump 36 bbls 11 ppg brine w/ 1% by Vol. CRW132 @ 3 bpm @ 440 psi and follow w/ 51 bbls of 11 ppg Brine 3 b m 430 si 05:30 08:00 2.50 8,264 8,270 COMPZ RPCOM PACK P Dro ball and rod and RIH U SL270' (OS depth) w/ Baker S3 PKR @ 8,171' w/ Top of PBR @ 8,137'. Pressure up and set S3 @ 3,700 psi, bleed back to 2,000 psi and Shear out of PBR @ 3,200 psi. Laydown 2 jts DP and Set Retrievamatic @ 8,020' and PT to 2,500 psi. between krs - ood test. 08:00 12:30 4.50 8,020 3,890 COMPZ RPCOM PULD P POOH laying down 128 jts 3 1/2 DP to 3,890'. 12:30 13:30 1.00 3,890 3,890 COMPZ RPCOM PRTS P Up wt = 78K#, down wt = 60K#. Set test packer Ca~ 3890' with 30K# down. Riq up and test below packer to 2500 si / 15 min.- Bleed off and release t 13:30 17:00 3.50 3,890 0 COMPZ RPCOM PULD P Continue POOH laying down 93jts DP and stand back remaining 9 stands. LD Retrievamatic test 17:00 23:30 6.50 0 822 COMPZ RPCOM PRTS P PJSM: PU_and RIH w/ Baker Full bore PKR to 822' and set. Test from 822' to RHC - Plu 8,224' to 0 ~si for 15 minutes - Test Good. POOH to 800' and test to RHC - Piug @ 8,224' to 2,500 psi for 15 minutes - Test Good. POOH to 596' set and test IA to 2,500 si - test failed, POOH to 590', set and test IA to 2,500 psi - Test failed. POOH to 530', set and test IA to 2,500 psi - test failed. Pooh to 401' set and test IA to 2,500 psi - Test failed. POOH to 305' set and test IA to 2,500 psi: good test. Rih to 401' set and test IA to 2,500 psi test failed. 23:30 00:00 0.50 401 401 COMPZ RPCOM OTHR T Call Anc engineer and inform of test results. Bad CSG interval lonqer than pianned for EX Patch. Discuss options and contingency. Pitwatcher stated that we could not account for 15.3 BBLS - Possibly to formation during Pressure testing. No communication through OA valve while testing above 590'. We did see very small amount of fluid rise in conductor, sampled and weighed in @ 8.5 ppg @ 50 degrees w/ 50,000 chlorides - Continued to monitor 3/2009 Continue to discuss options w/ Town engr. Release and RIH w/ DP and DC's f/ derrick - POOH LD same. Pull wear ring. PU and MU 3 1/2 Completion as a contingency plan for kill string to 8,157' CBU POOH to 3,524' and install Baker 7" Storm PKR and RIH to 98' Set and Test for 5 minutes. ND BOP and Gray TBG Head and NU FMC TBG S ooL 00:00 0030 0.50 401 401 COMPZ RPCOM OTHR T Call Anc engineer and inform of test results. Bad CSG interval longer than planned for EX Patch. Discuss o tions and contin enc . 00:30 02:00 1.50 401 1,255 COMPZ RPCOM TRIP T RIH w/ DP and DC's from derrick to 1,255' 02:00 04:00 2.00 1,255 0 COMPZ RPCOM PULD T POOH laying down 12 DC's and 24 'ts 3 1/2 DP. LD Full bore PKR. 04:00 05:00 1.00 0 0 COMPZ RPCOM OTHR T Offload Full bore PKR and Jars. Pull wear ring. Change over to tubing e ui ment. 05:00 14:00 9.00 0 8,157 COMPZ RPCOM PUTB T PJSM, PU and MU 3 1/2 IBT-M Com letion as contingency plan for kill strin and RIH to 8157'. Engage seal assembl and sit down 10K#, no o. 14:00 16:00 2.00 8,157 8,126 COMPZ RPCOM CIRC T CBU @ 5 bpm @ 530 psi retu,~jp~, 1,153 units of gas. Monitor well - static 16:00 18:00 2.00 8,126 3,524 COMPZ RPCOM TRIP T PJSM, POOH w/ 3 1/2 TBG - standin back f/ 8,126' to 3,524' 18:00 18:30 0.50 3,524 3,524 COMPZ RPCOM OTHR T Load Baker orm PKR and 5 1/2" Test Jt in i e shed. 18:30 19:30 1.00 3,524 3,650 COMPZ RPCOM PACK T PU, MU and RIH w/ 7" Baker Storm PKR and Set @ 98' and set w/ TBG tail 3 650'. PT @ 500 psi and hold for 5 minutes. 19:30 23:00 3.50 3,650 3,650 COMPZ RPCOM NUND T ND BOPE and Gray 7 1/16" 5M x 11" 3M TBG Head. Dress stub~The 7" 26# J-55 Stub was in ood condition and never grew. The height of the stub was 5" above the flange) and change out Reducer Bushing to FMC. 23:00 00:00 1.00 3,650 3,650 COMPZ RPCOM NUND T Install and NU FMC 11" 3M x 11" 3M TBG S ool. Pacte f: t 5/14/2009 24 hr Summarv Continue to NU FMC TBG Spool, Test Void to 3,000 psi for 15 min. and BOPE. Set Test plug & Shell test to 250/3,000 psi. Pull Test Plug, Re~ease Storm Packer and Continue to POOH. PU and MU 5" x 7" ZXP LT PKR ass and RIH on DP to 8,137' Locate To of PBR. PU 2' CBU. 00:00 03:00 3.00 3,650 3,650 COMPZ RPCOM NUND T NU FMC 11" 3M TBG Spool, Test Void to 3,000 psi for 15 minutes - Good Test. 03:00 05:30 2.50 3,650 3,650 COMPZ RPCOM NUND T PJSM, NU BOP 05:30 08:30 3.00 3,650 3,650 COMPZ RPCOM BOPE T Set FMC Test Plug and Shell Test to 250/3,000 si - Good, POOH w/ Test Plu 08:30 10:30 2.00 3,650 3,550 COMPZ RPCOM PACK T MU retrieval tool, RIH and pull storm packer to surface and RD. Blow down to drive. 10:30 12:00 1.50 3,550 0 COMPZ RPCOM TRIP T POOH with remaining 3-1/2" tubing, standin back. 12:00 14:30 2.50 0 0 COMPZ RPCOM SVRG T Clean ri floor, arran e i e shed for ZXP run, change out lower seals on seal assembl . 14:30 16:00 1.50 0 85 COMPZ RPCOM PULD T PJSM. MU 85' of Sealbore and ZXP acker assembi 16:00 22:30 6.50 85 8,137 COMPZ RPCOM TRIP T RIH w/ Baker Tie Back assy f/ 85' to 8,135'. Circulated @ .5 bpm @ 60 psi and located Top of PBR @ 8,137'. PU to 8,135' 120k up wt, 85k dn wt 22:30 00:00 1.50 8,137 8,135 COMPZ RPCOM CIRC T Circulate 233 bbls @ 3 bpm @ 350 psi.and swap over to 11 ppg inhibited brine and Pump to 20 bbls and follow w/ 50 bbls 11. KWF. 5/15/2009 Circulate 20 bbl inhibited Brine, followed by 50 bbl KWF, Insert and nogo out, Spaceout, Set Liner Hanger, release off PU and Set down and set ZXP. POOH laying down DP. Set Test piug, Conduct weekly BOP Test. PU and RIH w/ 5-1/2 15.5# Inner Liner to 2,219'. 00:00 00:30 0.50 8,135 8,135 COMPZ RPCOM CIRC T Pump 20 bbls of 11 ppg inhibited brine and follow w/ 50 bbls 11. ppg KWF. 0030 02:00 1.50 8,135 8,149 COMPZ RPCOM PACK T in Is and no 0 out on to of PBR a~8,137' w/ bottom of seals @ 8,149', PU 2' for spaceout. Pressure up to 1,700 psi and set "DG" Flex lock Liner Hanger, slack 60k to insure hanger set, Pull to 140k (20k OSV~ and slack off 60k again. Bring pressure up to 3,200 psi, Bleed off. PU 7' to and insure "HR" Setting tool is released and expose the dog sub. Slack off and set 50k down to set ZXP PKR, PU to same and Rotate @ 18 rpms' w/ 3.5k ft/Ibs free torque and sett back down the same - seen setting action during this process, repeat same 1 more time. cease rotation and POOH siowty w/ first 2 jts to ensure total release of running tool. Blow down Top drive. Top of ZXP Sleeve (c~ 8,069' {which also has a collapse rating of 3,476 psi and Burst rating of 6,957 psi}, of 80-40 Seal ass 8,135' 02:00 10:00 8.00 8,149 0 COMPZ RPCOM PULD T POOH laying down DP and HR Settin Tool. 10:00 16:30 6.50 0 0 COMPZ RPCOM BOPE T Set test plug. Weekly BOPE test 250/3000 psi. Test variables and annular with 3-1/2" and 5-1/2". 24 hr notice given to the AOGCC on 5/14/09 @ 11:45. Test waived by Chuck Scheve on 5/14/05 14:15. 16:30 21:30 5.00 0 0 COMPZ RPCOM OTHR T Continue to Load, Rack and Tally 210 joints of 5-1/2", 15.5#, L-80 511 H dril CSG, driftin to 4.825". 21:30 00:00 2.50 0 2,219 COMPZ RPCOM PUTB T PJSM, PU, MU and RIH w/ 525" OD Tie Back Seal Assy on 52 joints of 5-1/2 ", 15.5# , L-80, 511 Hydril CSG to 2,219'. 60k up wt, 52k dn wt. Continue to RIH w/ 5-1/2 Inner Liner f/ 2,219' to 8,081'. NoGo and Pull out seals. Space out for landing, Spot inhibited Brine in 7" x 5-1/2 annulus and FP w/ 7 bbls diesel, engage seals. Set RBP inside 5-1/2 15.5# CSG. Drain stack and CSG, ND BOP and land Emergency Slips w/ 50k string wt. Cut 5-1/2 CSG, pull stub, and set back BOP. NU TBG Spool. NU BOP. Shell test BOP @ 250/3,000 psi. Pull RBP. MU and RIH w/ 3-1/2 Recom letion. 00:00 06:00 6.00 2,219 8,029 COMPZ RPCOM RNCS T Continue to PU anc~.RIH w/ 5-1/2, 15.5#, L-80 511 Hydril CSG from 2,219' to_ 8~029'~127k up wt, 85k dn wt. Preparing to insert seals in PBR and No Go. 06:00 07:30 1.50 8,029 8,077 COMPZ RPCOM HOSO T RIH and no-go on PBR @ 8077' RKB, sit down 20K#. Rig up to pump down casing. Pressure up casing to 500 psi, PUH 5'. Bleed pressure from 340 psi to 200 psi, PUH another 5' before pressure dropped from130 to 0 psi. PU another 10'. Start pumping 0.5 bpm @ 70 psi, RIH 10' pump pressure starts to increase. Stop pumping bleed off, RIH 10' and no-go at 8077'. PU string weight and 2 extra feet for space out and mark csing for hang off. Puil seals assembl out of PBR. 07:30 10:00 2.50 8,065 8,Q65 COMPZ RPCOM CIRC T Riq_ut~ 'rc late corrosion inhibited Pump 100 bbi of 11 ppg corrosion inhibited brine followed by 180 bbl of un-inhibited brine 3 bpm @ 600 psi, pumping down the 5-1/2" casing taking returns up the 7" x 5-1/2" annulus. 10:00 11:00 1.00 8,065 8,075 COMPZ RPCOM FRZP T PJSM. Rig up LRS to the IA, PT lines. Close annular, pump 7 bbl of diesel down the 7" x 5-1/2" annulus taking returns up the 5-1/2" casin 1bpm @ 200 psi (1:1 returns). Strip 5-1/2" casing down through the closed annular to revious mark for han off. 11:00 12:30 1.50 8,075 8,075 COMPZ RPCOM MPSP T PU and MU Baker 5-1/2" RBP on 3-1/2" tubing. RIH to 60' R~in 5-1/2" casing, pressure up to 2700 psi set and release from RBP. POOH with the 3-1/2" tubing and settin tool. 12:30 1330 1.00 8,075 8,075 COMPZ RPCOM PRTS T RU to pump down the casing. Pressure test on top of the RBP to 1000 si. RD test line. Blow down TD. 13:30 16:00 2.50 8,075 8,075 COMPZ RPCOM NUND T ND BOP from the top of the casing head, lift BOP. 16:00 21:00 5.00 8,075 0 COMPZ RPCOM HOSO T Set new casina sli~s. cut casina above casin head install packoff assembl . NU tubin head. 21:00 00:00 3.00 0 0 COMPZ RPCOM NUND T PJSM, Jack uq riq in order to install new FMC 7 1/16" 5M x 11" 3M TBG Spool and set BOPE due to new CSG head height. NU BOP and Te~,t 5 1/2 " CSG Void to 250/3,000 si and hold for 15 minutes - Good Test. 5/17/2009 24 hr Summarv Continue to NU BOP. Shell test BOP @ 250/3,000 psi. Pull RBP. MU and RIH w/ 3-1/2 Recompletion. Space out and land. PT TBG and IA, shear out SOV. Set BPV, ND BOP NU Tree. Change out 11 ppg KWF w/ inhibited Sea water and FP w/ 68 bbls of diesel. Allow well to swa freeze rotect dieseL 00:00 02:00 2.00 0 0 COMPZ RPCOM NUND T Continue to NU BOPE 02:00 03:00 1.00 0 0 COMPZ RPCOM BOPE T Set test Plug and Shell Test BOP @ 250/3,000 psi. Pull Test Plug. 24 hr notice was given @ 15:30 hrs on 5-16-09 and Witness of Test was waived by Chuck Scheve @ 19:55 hrs on 5-16-09. 03:00 04:30 1.50 0 0 COMPZ RPCOM SVRG T Slip and Cut 84' drili line 04:30 05:00 0.50 0 0 COMPZ RPCOM MPSP T Retrieve Baker RBP 60' POOH 05:00 09:30 4.50 0 8,090 COMPZ RPCOM TRIP P RIH w/ 3 1/2, 9.3#, L-80 IBT-M Completion string to 8,090. Up wt = 87K#, down wt = 63K#. 09:30 10:30 1.00 8,090 8,103 COMPZ RPCOM HOSO P Ru to pump down tubing. RIH and no- o at 8122 RKB sit down 15K#. PUH to 8100', pumping 0.5 bpm @ 60 psi. RIH, start to pressure up at 8105', bleed off pressure, RIH tag up at 8122'. Pressure up to 350 psi and PUH, pressure dropped from 100 psi to 0 si at 8103'. 10:30 11:00 0.50 8,103 8,050 COMPZ RPCOM CIRC P PUH to MU space out pup. Puiling heavy and breaking back. Circulate BU at 5 b m 1000 si. 11:00 12:00 1.00 8,030 8,120 COMPZ RPCOM HOSO P PUH and MU s ace out pup (2' space out), tubing hanger and landing joint. RIH and land tubing han er, RILDS. 12:00 14:00 2.00 8,120 0 COMPZ RPCOM PRTS P PT 3-1/2" tubinq 2500 asi / 15 min, bleed down to 1700 psi. PT 3-1l2" tubin x 5-1/2" casin annulus to 3000 psi / 30 min. Bleed down the casing pressure, then the tubing pressure. Pressure up on the 3-1/2" x 5-1/2" annulus and shear the SOV at 1150 psi. RD um lines and LD landin 'oint. 14:00 15:30 1.50 0 0 COMPZ RPCOM NUND P Set BPV, ND BOPE. 15:30 18:00 2.50 0 0 COMPZ RPCOM NUND P NU tree. test packoff voids 250/5000 psi. Pull BPV, set tree test plug, t_r tree 250/5000 psi. Pull tree test pluq. From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Thursday, May 28, 2009 3:55 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 2V-08A (184-091) Jim/Tom, Following the rig workover on 2V-08A (PTD 184-091), the fluids in the conductor (from the original split and spill that occurred in 1994) swapped with charging ground water and created a 10 gal hydrocarbon/40 gal brine water spill in to the well cellar. The integrity of the well has not been effected. A small conductor cement top off was completed 5/27/09 as a follow up step to the prior completed surface casing repair. The cement top off filled the conductor void and will prohibit any additional water from entering the conductor from below ground. A 10-404 or equivalent report will be filed in the next few days. Please let me know if you have any questions MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 ~,~; 3 >:,y ~ 6/17/2009 2V-08A (PTD 184-091) Revised Plan Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 14, 200910:57 AM To: 'Gober, Howard' Cc: Allsup-Drake, Sharon K; Ennis, J J; Nelson, Erik Q; Packer, Brett B; Nordic 3 Company Man Subject: RE: 2V-08A (PTD 184-091) Revised Plan Howard, I concur that we spoke of the changed plans for 2V-08A. The revised proposal is not dissimilar from other work recently done. No additional paperwork is needed. I will place a copy of this message in the file. Call or message with any questions. Tom Maunder, PE AOGCC From: Gober, Howard [mailto:Howard.Gober@conocophillips.rnm] Sent: Thursday, May 14, 2009 10:51 AM To: Maunder, Thomas E (DOA) Ce: AAsup-Drake, Sharon K; Ennis, ] J; Nelson, Erik Q; Packer, Brett B; Nordic 3 Company Man Subject: 2V-08A (PTD 184-091) Revised Plan Tom, I wanted to document our conversation yesterday regarding 2V-08A (PTD 184-091). Nordic 3 is currently working on the well under Sundry #309-162. Prior to setting the Baker ExPatch expandable casing patch, we pressure tested the casing below and above the patch interval. The 7" casing below 822' RKB tested good to 2500 psi. Above 401' RKB the bleed off rate was too high to pass an MIT. Above 305' RKB we obtained a passing MIT, but the pressure was still bleeding off. We do not have enough expandable patch material to patch from 822' RKB to 300' RKB. Therefore, we have decided to run a 5-1/2" inner casing string. We have already set the S-3 permanent packer as per the original plan. Here is the path forward. • Set storm packer. ND BOP and Gray tubing head: NU FMC casing head (for landing 5-1/2" casing). NU BOP and test packoffs and break to 250/3000 psi. POOH with storm packer. 0) Run tie back assembly to accept the 5-1/2" casing. The assembly will include: a. PBR type seal assembly (this will stab into the PBR above the S-3 packer that was run the other day) b. Seal bore extension (this is where the 3-1/2" tubing will land) c. 5"x7" Flex Lock liner hanger d. ZXP Liner hanger packer with tie back sleeve e. HR setting tool Circulate in a corrosion inhibited brine pill around the tie back assembly. Set hanger and ZXP. POOH. 0) Test BOP. Weekly test will be due, and we will need to test the VBR's for 5-1/2" casing 1) Run 5-1/2" 15.5# L-80 Hyd 511 inner casing string. Circulate corrosion inhibited brine and diesel freeze protect in 5-1/2"x7" annulus. Land in tie back sleeve above the ZXP packer. ND BOP. Install slips and packoff for 5-1/2" casing. Cut off casing. NU FMC Gen 4 tubing head. NU BOP. Pressure test packoff and BOP to 250/3000 psi. 5/14/2009 2V-08A (PTD 184-091) Revised Plan Page 2 of 2 2) RIH with 3-1/2" completion. The 3-1/2" jewelry will be similar to the original procedure sent with the sundry application. The 3-1/2" tubing will sting into the seal bore below the ZXP packer. 3) The remainder of the original procedure will apply except we will pressure test the 3-1/2" x 5-112" inner annulus to 3000 psi. Attached is a Revised Proposed Schematic that shows how the well will be completed. Based on our conversation yesterday we are moving forward with this plan. Please reply if you concur with our plan for continued operations. Please call or a-mail if you have any questions. «2V-08A proposed schematic -Revision i.pdf» Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 OfFce 907-240-5515 Cell Howard.Gober@conocophillips.com 5/14/2009 Well: 2V-08A ~Philli Field: Kuparuk PTD: 184-091 PROPOSED API: 50-029-21128-00 • Lift thds: 3Y" 8rd • BPV: 3" CIW • Tubing = 3-1/2" L-80 IBT-Mod . A: 2.875" DS Nipple @ 500' • B: 5-112" L-80 15.5# Hyd 511 Inner casing string landed at surface • C: Gas lift Mandrel • D: Baker FlexLock Hanger, 7XP Packer and Tie-back slv - 5-1/2" csg landed in tie-back • E: Seal bore extension - tbg is landed here • F: Baker S-3 Packer and PBR • G: 2.813" DS Nipple @ 8230' • H: 4.25" ID Poorboy overshot • I: Camco OEJ slick stick ~ 8267' • J: Camco HRP-I-SP packer 8285' • K: Baker FB-1 Packer ~ 8518' • L: Camco D nipple at 8535' ID = 2.25" (2.75" x 2.25" nipple reducer installed) • M: Re-entry guide at 8543' e Conductor: 16", 62.58 ppf, H-40 at 103' Surface Casino: 96/", 36 ppf, J-55 at 3868' D E F H J K M 8325' 8395' 8499' 5753' KBUG-dummy Existing 5801' KBUG-dummy Existing 5874' KBUG-dummy Existing 600'-602' & 790'-792' 8514-8515' (9/3/84) 8446'-8488' (12 spf, 9/13/84) 8586'-8612' (4 spf, 9/13184) 8628'-8678' (4 spf, 9/13/84) Directional: ~~:s>~~ ~~~ ~~=:~ Max hole angle: 53° at 3900' Production Casino: Angle at top pert: 45° at 8446' 7", 26 ppf, J-55 at 9034' Max doglegs: 5.3°/100' at 700' Fill = 8649' (9/3/06) TD = 9050' Sundry #: 309-162 Last Upda#ed: 14-May-09 Revision #1 Updated by: HBG • p ~ { i Y c• 1 ~.~ ! I ~ ~ ,~ ~ ~ ~ ~ ~` 1 - , ~ ~• i ~~ } SARAH PALIN, GOVERNOR - ~ ~.. ._.r` i.._ _, ,..,. J ~-+y~ -"`a"`-s~ta~~ 0~ ~ ~ ', 333 W. 7th AVENUE, SUITE 100 C01~5ERQA7`IO1~T CU11Z11IISSjUi~T ANCHORAGE, ALASKA 99501-3539 i PHONE (907) 279-1433 Howard Gober 1=Ax (907) 276-7542 Wells Engineer ConocoPhillips Alaska Inc. PO Box 100360 _ ;~,,,~~L `I i~~~~°` ~ ~.~i(`>' Anchorage AK 99510-0360 .,. ~~~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 2V-08A Sundry Number: 309-162 Dear Mr. Gober: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test., contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of May, 2009 Encl. ~.o~+ ~ • STATE OF ALASKA • ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^/ - Repair well ^~ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well Q - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 184-091 ' 3. Address: Stratigraphic ^ Service Q _ 6. AP! Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21128-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y2S ^ NO ~ 2V-08A ` 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25655 ~ RKB 113' - Kuparuk River Field /Kuparuk River Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9050' - 6279' - 8951' 6204' 43s' (cement),s1o', 4000', 8535' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 103' 103' SURFACE 3755' 9-5/8" 3868' 2851' °~ ;~ PRODUCTION 8921' 7" 9034' 6267' OOg :- ~ has ~~~ nch~ra ~- Perforation Depth MD (soo'-so2', 7so'-7s2', Perforation Depth TVD (ft) 594'-596', 769'-771', Tubing Size: Tubing Grade: . Tubing MD (ft): 8446'-8488', 8586'-8612', 8628'-8678' 5837'-5866', 5937'-5956', 5968'-6005' 3.5" J-55 8285'-8542' Packers and SSSV Type: Packers and SSSV MD (ft) Camco HRP-1-SP pkr, Baker'FB-1' pkr @ 8285', 8518' no SSSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: May 8, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ - WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263-4220 Printed Name Howard Gober Title: Wells Engineer D t aJ Signature Phone 263-4220 a e Commission Use Onl Sundry Nu r. Conditions of approval: Notify Commission so that a representative may witness ~ Plug Integrity ~ BOP Test `~ Mechanical Integrity Test ~ Location arance ----` ^ Other: '~ Wv e S ~ ~~ ~ ~°~ ~rG'r+~S ~-nc~~1 ~r~ C`).4 ~ ~CA'l~v~ Subsequent Form Required: "~1~~ ~ ~ ~.,, ~=, /k,~` ~ ~ ~Qa~ APPROVED BY Approved by: E THE COMMISSION Date: Form 10-403 Reviled 02006 / i p ~ { ~ i ~~ H L Submi i ~~~ • ~~ ~anarcoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 1, 2009 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: • ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2V-08A (PTD 184-091). 2V-08A was completed in September of 1984. A workover was performed in 2006 followed by non-rig activities to ensure the Outer Annulus was not allowing fluids to migrate to surface. Two sets of squeeze holes were shot and cement squeezes pumped down the 7" casing. After the squeezes were pumped, a split in the surface casing was welded up so that fluids could not communicate from the OA to the conductor. The purpose of this workover is to set the well up so that it can be returned to injection. The cement will be drilled up in the 7" casing. A FasDrill bridge plug set in the casing will also be drilled up. Then a retrievable bridge plug will be recovered. Anew packer will be run. Next, an expandable casing patch will be run to ensure the squeeze holes in the 7" casing are and will remain isolated. Finally, a new string of 3-1/2" L-80 tubing will be run. If you have any questions or require any further information, please contact me at 263-4220, Sincerely, e~~~%~~~ Howard B. Gober Wells Engineer CPAI Drilling and Wells C_ Kuparuk 2V-O8A General Workover Procedure Pre-riq Work 1. Pressure test casing to 1000 psi. Bleed pressure down to 0 psi. General Workover Procedure 1. MIRU Nordic 3. Note: There is no hanger in the well, but it is isolated with cement and multiple plugs. 2. ND 7-1/16" full opening valve and return to the warehouse. NU 13-5/8" BOP with 2 sets of 3-1 /2" pipe rams. 3. Test BOP including annular to 250/3000 psi. Maximum potential surface pressure is estimated at 1600 psi based on maximum observed SI tubing pressure in September of 2006. Using the last A sand mid pert SBHP of 3484 psi at 8632' RKB and a 0.1 psilft gradient, the MPSP is 2686 psi. 4. Pull test plug. Verify well is dead. 5. Drill out cement from -439' RKB to past the bottom squeeze hole at 792' RKB. Pressure test squeeze holes to 1000 psi. Continue to run in hole and drill up FasDrill bridge plug at 810' RKB. POOH. 6. RIH with bit and scraper to CaCO3 above RBP at 4000' RKB. Dry drill any debris above RBP. POOH. 7. Retrieve RBP at 4000' RKB. 8. Run stack packer completion with poorboy overshot set over the existing OEJ slick stick. Set packer. Shear PBR. POOH. 9. Run drift for Baker ExPatch casing patch. 10. Run Baker ExPatch to cover squeeze holes from 600'-792' RKB. Overall patch length including hangers will be 260'. Set patch. Pressure test casing to 2500 psi. POOH. 11. Run seal assembly, gas lift mandrel, and 3-1/2" L-80 IBT-Mod injection tubing. Load tubing and IA with corrosion inhibited seawater. Space out and land tubing. 12. Pressure test tubing to 2500 psi and IA to 2500 psi. The annulus is only being tested to 2500 psi due to the casing patch. Record casing pressure test on a chart. Shear SOV. 13. Set 2-way check. ND BOPE. NU Tree. Pressure test tree and packoffs to 250/5000 psi. Pull 2- way check. Freeze protect well with 115 bbls diesel to 3300' RKB (2500' TVD). 14. Set BPV. RDMO Nordic 3. Post-Rig Work: 1. Pull ball and rod. 2. Pull SOV and install DV. Pressure test tubing and IA to 2500 psi. 3. Pull RHC body. 4. Pull 2.25" CA-2 plug set at 8535' RKB..~- 5. Tag fill 6. Obtain SBHP 7. Return to injection_ • Well: 2V-08A ~~~~~ Field: Kuparuk PTD: 184-091 PROPOSED API: 50-029-21128-00 Proposed Completion • Lift thds: 3%" 8rd • BPV: 3" CIW • Tubing = 3-1/2" L-80 IBT-Mod • A: 2.875" DS Nipple @ 500' • B: Baker ExPatch casing patch 566'-826' to cover squeeze holes • C: Gas lift Mandrel • D: Baker S-3 Packer and PBR • E: 2.813" DS Nipple @ 8230' • F: 4.25" ID Poorboy overshot Existing 3-1/2" Completion • G: Camco OEJ slick stick 8267' • H: Camco HRP-1-SP packer 8285' • I: Baker FB-1 Packer @ 8518' • J: Camco D nipple at 8535' ID = 2.25" (2.75" x 2.25" nipple reducer installed) • K: Re-entry guide at 8543' B Surface Casing: 95/8', 36 ppf, J-55 at 3868' D Conductor: 16", 62.58 ppf, H-40 at 103' F G H 8325' 8395' 8499' 5753' KBUG-dummy Existing 5801' KBUG-dummy Existing 5874' KBUG-dummy Existing K Perfs Sqz: 600'-602' & 790'-792' Sqz: 8514-8515' (9/3/84) C-4: 8446'-8488' (12 spf, 9/13/84) A-4: 8586'-8612' (4 spf, 9/13/84) A-3: 8628'-8678' (4 spf, 9/13/84) Directional: ~:::':=:_:=:<= {=: `:<~:::~ Max hole angle: 53° at 3900' Production Casing: Angle at top pert: 45° at 8446' 7", 26 ppf, J-55 at 9034' Max doglegs: 5.3°/100' at 700' Fill = 8649' (9/3/06) TD =9050' Last Updated: 1-May-09 Updated by: HBG ~011UCt?~'11~~Ip$ ~ Well Attributes Wellbore APl/UWI IFieltl Nama Well Status ProNlnj Type :Masi::, I r..:. / 500292112800 .KUPARUK RIVER UNIT (INJECTING ,Comment ~H2S Ippm) (Date.Annotation End Date __weu_conig; ~~i!!efn@Sp tAmOU 'z.~' ,I -. _-~ Last TaDONE Dept 619K6) 'E 9/8!2007 Re 1!1/2009 Last WO: 9/14 -.__.. s - naakon v Reason: ADD NOTE coNDUCro i SURFACE 9 518 8.525 0 3 868 2 851.0 36.00 J-55 PRODUCTION 7 6.151 0 9,034 6,267.1 26.00 J-55 csG '- Tubing Strings PUNCHES. 600 ~-~,.. _ String OD String ID Set Depth Set Depth (TVD) String Wt String Tubing Descnption (in) I (in) Top (kKB) (kK8) (f1KB) (Ibsttt) Grade TUBING ' 31/2' 2.9921 8,267 8,542! 5,905 9.30 J-55 CSG -, Other In Ho~l~e hAll Jewelry: Tubing Run 8 Retrievable, Fish, etc.). PUNCHES, 790 ` INDI Top Intl '~ Top (k KB) (ftK8) (°) Description Comment 600 5937 17.70 CSG POST WORKOVER 9/14/2006 CASING PUNCHES 3 3/8' 11 PUNCHES 'HSD PJ, 6 SPF 11/912007 f 26.60 CSG POST WORKOVER 9/14!2006 CASING PUNCHES 3 3/8" 6/ 790 769.1 PLUG,am PUNCHES .HSD PJ, 6 SPF 6/4!2007 -__ - --_. _.. i __.. 810 789.0 31.08 PLUG POST WORKOVER 9/14(2006 7' FASDRILL BRIDGE 6/ PLUG MID ELEMENT set 6!20/2007 suRFACE, __ __ - ..- 4,000 2,930.4 52.08 PLUG POST WORKOVER 9/14/2006 T RETRIEVEABLE BRIDGE 9! 3868 PLUG SET AFTER UPPER PORTION OF OLD '' COMPLETION PULLED 9174/2006 8,285 5 7252 47.27~,PACKER POST WORKOVER 9/1412006 Camco 'HRP-I-SP' 9/ PLUG, 4.aao 8,325 5,752 4 46.8511NJECTION CAMCO/KBUGl1lDMY/BEKf!! Comment: 9/ 8,395 5,800.7 45.96 INJECTION CAMCO/KBUGl1lDMYBEK//! Commen[: 9! 8 4891 5,867.0 44.25 PATCH ~POSI WORKOVER 9!14!2006 Set HES permanent patch 5/ across GLM @8499' RKB. Top of patch set @ 8489' to I ! I i 8511'; min.ID 2.375" 5178/2000 8,499 5874.2 44.071NJECTION CAMCOIKBUG/1/PATCHlBK/li Comment 5/ PACKER, e,zes 8,518 5,887.9 43.83 PACKER POST WORKOVER 9!14/2006 Baker'FB-1' 9/ - 8,535 5,900.2 43.62 NIPPLE POST WORKOVER 9/14/2006 Camco 'D' Nipple NO GO. 9/ ' Set 2.75" x 2.25" "D' profile nipple reducer 5/16/2000 1 ~~ PLUG POST WORKOVER 9/14!2006 TTP set 9/372006 9! 8,535 5900.21 43.62 Iwl=crloN, ~ 8,542 5,905.3 43.53 505 POST WORKOVER 9/14!2006 Baker 9/ 8,325 ,~ 8,543 5,9061 4352 IIL (POST WORKOVER 9/14!2006 9/ Perforations & Slots - _ _ --- - - (sn t I '~ Top (TVD) Btm (TVD) D S INJECTION. Btm (kKB) (ftKB) (kKB) ~ Zo Date (h Type Comn Top (ftK8) a.3ss ~ ~ 5,836.61 5 866.3~C-0, UNIT B '9/13/1984 ~'. 12 0 !IPERF 120 deg. phasing; 5 8 446' 8 488 1 1 ~ 2V-08A I I 8,586 8,612 5,937.3 5,954.2I~A-4, 2V 08A ~~i 9/13/1984 4.0 IPERF 90 deg. phasing; 4' 1 4.OIPERF 90 deg. phasing; 4' 9/13!1984 ~ 8,628 8,678, 5,966.6 6,004.5IA-3, 2V-OSA PERF. _ - , 111 a,a46-a.aaa ', i Notes: General & Safety _ _ _ _ _ _. End Date Annotation 12/212003 NOIE~ WAIVERED WELL: OA x OOA COMMUNICATION 1 9114/2006 NOTE: TOP PORTION OF COMPLETION PULLED - "NOT RERUN" 2/3/2009 NOTE VERTIC SPLIT WELD APPLIED SURFACE CSG RUPTURE FROM 6'4" BELOW MN 137 INJECTION. 8A99 PATCH, 8,689 PACKER, 8.5'8 NIPPLE, 8,535 PLUG, 8,535 SOS, 8,542 TTL, 8.563 IPERF, 8.586-8.612 2V-08A f Date 2/15/2009 0.000 IPERF. 8.628-5,678 PRODUCTION, 9,034 TD. 9.050 Page ~ of ~ ~ Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Wednesday, February 11, 2009 5:13 PM To: Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: 2V-08A (184-091) Tom, All of the photos that ConocoPhiifips submits have copyrights on them. We are not allowed to submit anything with out the copyright unless it has been run by legal first. However, most of the time the copy right mark is not quite so obvious. The failure mechanism in known and was determined last time we excavated (but chose to not patch) the well. It was caused from a combination freeze thaw event that collapsed the surface casing followed by a thermal event that over pressured the weakened casing. The timing for the freeze (collapse) event is unknown -however the over pressure event most likely happened in 1994 when the well was swapped from sea water to produce water the event was documented with a spit! report. Let me know if you'd like to discuss. MJ Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-'1687 ,~ r-- ~} ., ~ > I'] - .,.~. From: NS oblem Well Supv Sent: Wednes February 11, 2009 3:06 PM To: NSK Well Integri roj Subject: FW: 2V-08A (1 91) From: Maunder, Thomas E (DOA) [mailtoaom. r@alaska.gov] Sent: Wednesday, February 11, 2009 1:40 P To: NSK Problem Well Supv Cc: Regg, James B (DOA) Subject: FW: 2V-08A (184-091) MJ and Perry, have just reviewed th 04 regarding the latest repair on our ofd friend 2V-08A. Is th any work underway to determine the failu mechanism? !think we can al! agree this is a strange one. There is other item that concerns the p os. Thanks for including them as noted on the sundry. As with all photos tha PAI submits, these have copyright statement. I understand that the reason for including this statement on ph s is due to some p distribution of photos by internal/other parties not necessarily for sound business reasons. wing 2/12/2009 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, February 11, 2009 1:40 PM To: NSK Problem Well Supv Cc: Regg, James B (DOA) Subject: FW: 2V-08A (184-091) MJ and Perry, have just reviewed the 404 regarding the latest repair on our old friend 2V-08A. Is there any work underway to determine the failure mechanism? I think we can all agree this is a strange one. There is one other item that concerns the photos. Thanks for including them as noted on the sundry. As with all photos that CPAI submits, these have the copyright statement. I understand that the reason for including this statement on photos is due to some past distribution of photos by internal/other parties not necessarily for sound business reasons. Following the initial 25-month-after-completion confidentiality period, AOGCC wells files are placed in the public domain. The 2V-08A file has been in the public domain for over 20 years. In addition to hard copy files, public domain well files are also now accessible over the Internet. Following completion of our internal review, the recently submitted documents for 2V-08A, including the photos, will be added to the public domain files. If there is a matter for discussion here, please call or message. Tom Maunder, PE AOGCC 2/ 11 /2009 ~, ~ ~ ~ • STATE OF ALASKA • ~~.., ~~d~ ALASKA OIL AND GAS CONSERVATION COMMISSION `r~~ ~ '0~; t_ r~ `~,S 6{"~ ~, a REPORT OF SUNDRY WELL OPERATIO ~. ~a~°~E~`~` 1. operations Performed: Abandon ^ Repair Well ^~ ' Plug Perforations ^ Stimulate ^ - Othe~~~'" Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Ina ~~>,.<<a;,~,~4,; ^ Exploratory ^ 184-091 3. Address: Stratigraphic ^ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21128-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 113' 2V-08A a 8. Property Designation: 10. Field/Pool(s): ADL 0025655 ~ ALK 2581 Kuparuk River Field /Kuparuk Oil Pool ' 11. Present Well Condition Summary: ,b~ Z, p.~ Total Depth measured ~9A8'~gt~~o / feet true vertical ~ G 27f feet Plugs (measured) 4000' - RBP, 810' Fastdrill BP Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 103' 16" 103' 103' SURFACE 3755' 9-5/8" 3868' 272$' PRODUCTION 8921' 7" 9034' 6267` Perforation depth: Measured depth: 8446-$488, 85$6-8612', $628-867$' true vertical depth: 5837-586ca, 5967-5956, 5968-6005 Tubing (size, grade, and measured depth) 3_1/2" , J-55, 8267-8542' MIr3. Packers &SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP' ; BAKi~R 'FB-1' pkr= 8285' ; $518` no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N!A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 18. Well Status after proposed work: C^ Ga~ WAG^ GINJ ^ WINJ Q ~ WDSPL ^ 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: 308-241 contact M.J. LovelandJPerry Klein Printed Name M.J. Lov,~land /"~ ~ Title Well Integrity Projects ~ Signature ,~n ~ ~ ~~~f~~~~ Phone 659-7043 659-7043 Date 2/6/2009 ,~, ~ D ~,. io • og "ors Form 10-qr~4 Revised 04/20(~"4~ ~ ~ ~` E ~ ~ ~~ ~ ,~-~,^~ Submit Ofjgjnal n - /O~ F ~~" I \ /T, ~iy~~/ • 2V-08A • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/16/09 Finish with excavation and install shoring box, P-gravel, egress. Build scaffolding tomorrow. 01/21/OS Pur a nitro en while cuttin two 18 x 18 inch windows under the Tanko To .Cut one 18 x 18 inch window and a 18 x 28 inch window @ the collar. Kakivik to inspect the SC this p.m. 01 /25/09 01 /28/09 02/01/0' Nitrogen purge for cutting and removal of Tanko head and conductor. Cleaned area of Surface Casing leak for inspection and took photo records of damage.Notify stateman (Lou Grimaldi) to witness damage to SC - he asked if we would call again before we repair. AOGCC State man (Lou Grimaldi) witnessed SC damage with Jon Arend and Perry Klein. He also took pictures w/approval by Perry. ~ Nitrogen purge and firewatch for surface casing repair weld.Welded a vertical weld 24" in length on dams ed area of surface casin .Weld starts 6' 4" below mandrel han er and ends 9'1" below. Had KAM mag tested the welded area for further damage,none noted.T/I/O = SI/O/O. 02/02/09 02/04/09 MIT-OA.Initial T/I/O = SI/0/O.Pressured up 250 psi,small leak observed 3' below vertical repair weld.Upon closer inspection there appears to be a hairline stress crack in area of pitting. Welders to return to repair suface casing. surface casing.Made a second vertical repair weld 2'- 11" in Iength.Seal welded plug Ca~13'- 4".First days weld starts ~a 6'- 4" and ends @ 9'- 1" below top of mandrel.Second days wel starts @ 10'- 8" and ends @ 13'- 7"-below top of mandrel.Kakivik mag tested weld ready for MIT-OA. MIT- OA.Installed VR plug on OA. Pressured to 350 psi,no leaks observed,T/I/O = SI/0/350. 15 min. T/I/0 = SI/0/295. Repressured to 365 psi,no leaks observed,T/t/O = SI/0/365. 15 min. - _- --- - T/I/0 = SI/0/305. Re ressured to 355 si no leaks observed T/I/O = SI/0/355. 15 min. T/I/0 = SI/0/315. Repressured to 350 psi,no leaks observed,T/I/O = SI/0/350. 30 min. T/I/0 = SI/0/300.Repressured to 360 psi,no leaks observed,T/I/O = SI/0/360. 30 min. T/I/0 = SI/0/315. Bled to 0 psi. Denso wrapped surface casing. Final T/I/O = SI/0/0. No Increase in conductor fluid level indicating no further SC leaks. 02/05/09 Weld 13' 3" of new conductor in place. Conductor is 16" 65# H-40 with rupture groove. • 2V-08A • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary • ~p = ~=~~: i= ~ . ~~u . ~. ~~ t ©ConocoPhillips Alaska, Inc. " ~ This photo is copyrighted by ~-; ConocoPhillips Alaska, Inc. and cannot ~ be released or published without express written consent of ConocoPhillips Alaska r, 1 a+ - - • ' `° `_ ,. _rs.,a„ +~„x .~, ~. -,~~~~ ~# r• i ~~ ,. f., ,~ . k ~ ' r ~ ~~ '; r _ ~, n 1~ ~ ~~~; II ! ,, ~~~ ~x . :a ~, :~ . _ r g~,t ;. aG , t' ;,~. - -~ ail 4 ti~~ sk ~:~~s +. ~ t .~~_ .. ~91'~~,~ _ _ a - ~ r ., "~ sr ~~' ~ ~+ t.a §'' ~ r~~ s~ _~ y ~ n~ t r~ ~~ ~ ~4 1 i t Y~'° } 1 ~ n i .; ~. .~ . i 2~. "~' ~; "~ .~. '. Sf~ gi w` q`L~.., ~`~~ k ";, a . ~° y~ ~ , ~~.~~ ~~„ 4~ ~ = ~~ ~~ :r a~. ,e~ ~,~ ~. ~' z ., ° S .~ ~ ' ~. ~ ~:~ , , `5~1 j ~ ' x ~ ' k i~ •: ~ .. ~ ~ .,. a='; " A til ~w ~ ~ ' ` '~ ` ~'r ~~ y~i w~ t " C fg - ~ t ~. ~. tk.. _ ~ M "~ ~I~.r :`~~'~~f + ~ ~ ~. Ma 4 ~ F ~ a rt t~ ~'~ X ~ ~ ~ ~.ra ~ iF+,~ _ ,~ f ' ice` r ~ ~ ~ f' ' E • .~ 'h- q. ~ 7 s~ a ~;. , k' ;4 :' s _ ~£ ~_- ~ ; ~:~'~ 7`; ~' I Page 1 of 1 U Regg, James B (DOA) From: Grimaldi, Louis R (DOA) 1<w?;~.,(. 21~---0°Q Sent: Wednesday, January 28, 2009 4:45 AM 2.t~~,`~~ ~ i ~ f Q,~ 4 ~Q~ ~ To: Regg, James B (DOA) ~~`~ Cc: Maunder, Thomas E (DOA) Subject: KRU 2V-8 collapsed casing pix Attachments: KRF 2V-8 Collapsed Casing 01-27-09 LG.jpg; KRF 2V-8 Collapsed Casing b 01-27-09 LG.jpg; KRF 2V-8 Collapsed Casing c 01-27-09 LG.jpg Jim/Tom, I stopped by CPAI's KRU 2V-8 yesterday to look at the collapsed surface casing. Pretty impressive but seen it before, it will be interesting to see how they P&A this well when it's time comes. One interesting thing I noticed is that as expected the casing folded at the weakest spot, the seam. The interesting part is that directly below the split there is moderate corrosion pits on the seam but nowhere else. Maybe a poor annealing process? I don't think it would have made any difference to whether the casing would have collapsed, just it caught my eye. I know the pix don't show the pit's but I will try to get back out there before they weld it up to get a better shot of it. Lou ~~11 ~' r~ ~~~• 1 /28/2009 KRU 2V-08 (CPAI) Collapsed Surface Casing Photos by AOGCC Inspector Lou Grimaldi (rl) t ~, Q- ~`l ~ 1 /27/2009 l , .;_ ` ~ ` ~' ~. . ~= r ~~_. ~-~ Y~ b r~..~ ~~„~ ~ o ., ~~w~ ~ , ~ , <~~ ;- -; f, , , ._ n - ~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS V. 4. AUO { 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other '' -^ Alter Casing ^ Pull Tubing ~ r Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown0 ~ -ete^-~-r~~'(~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^ Exploratory ^ 184-091 / ~ 3. Address: Stratigraphic ^ Service ~ i 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21128-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 113' ~ 2V-08A - 8. Property Designation: 10. Field/Pool(s): ADL 25655 ~ Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 905Q' • feet true vertical 6279' , feet Plugs (measured) 810', 4000', 8535' Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 103' 103' SURFACE 3755' 9-5/8" 3868' 2851' PRODUCTION 8921' 7" 9034' 6267' Perforation depth: Measured depth: 600'-602', 790'-792', 8446'-8488', 8586:8612', 8628'-8678' - ~ - - ~~ AUC ~ ~ 2008 true vertical depth: 594'-596', 769'-771', 5837'-5866', 5937'-5956', 5968'-6005' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 8267' - 8542' MD. Packers &SSSV (type 8 measured depth) pkr= CAMCO'HRP-I-SP' ; BAKER'FB-1' pkr- 8285' ; 8518' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) cmt sqz: 790'-792' MD with 150 bbls AS1 cmt, 450 psi final pump pressure and Treatment descriptions including volumes used and final presst cmt sqz: 600'-602' MD with 47 bbls AS 1 cmt 230 psi final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ Q WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: 306-301 contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Wells Group Engineer Signature Phone: 263-4220 Date ~~l ~~~ Pre aced b Karon Allsu Drake 263-4612 7 ' s.,> ~a,~, ~ n Form 10-404 Revised 04/200 ~ ~ ~ ~ ~.i ~ C~ ~ ~~~ ~ ~oDQ Submit Original Only r • Cono~oPhiilips Time Log & Summary ttielNiew Vteb R-~prYirrg Report Well Name: 2V-08A Rig Name: NABOBS 3S Job Type: RECOMPLETION Rig Accept: 9/10!200611:00:00 AM Rig Release: 9/14/2006 12:00:00 AM -- - - - - --- ___--- Time Logs Date From To Dur S. G`epth E. Depth Phase Code Subcode T Comment _ - -__- __ 9/09/2006 24 hr Summary RD Nabors 3S at 2C-16. Begin move to 2V-08A. 00:00 02:00 2.00 MIRU MOVE RURD P Nabors 3S - LD Kelly, swivel, and rathole. 02:00 05:00 3.00 MIRU MOVE RURD P Scope down & lower derrick. 05:00 10:00 5.00 MIRU MOVE RURD P Move pit module & pipe shed away from rig carrier. Move rig carrier off well. PU ri mats and herculite liner. 10:00 12:00 2.00 MIRU MOVE RURD P Move camp, shop, & generator skid to 2V Pad. Start moving rig to 2V Pad. Pits & pipe shed at 2V, rig about 1/2 mile from 2V Pad at midni ht. 9/10/2006 Move Nabors 3S rig over well, RU, raised derrick. Accept rig @ 1100 hrs. Pull BPV to ensure well is dead. Install BPV. ND tree. NU 7-1/16" FO valve, DSA, BOPE. 00:00 11:00 11.00 MIRU MOVE RURD Spot rig over well. 11:00 11:00 0.00 Acre t Nabors 3S ri at 1100 hrs. 11:00 13:00 2.00 WELCTL KLWL P Pull BPV. Well is dead. Install BPV. 13:00 15:00 2.00 WELCTI NUND P Bleed down SSSV control line and start to ND tree. 15:00 15:00 0.00 WELCTL BOPE P John Spaulding, AOGCC, called and waived the BOP test. He asked that the results be sent to him when finished. 15:00 17:00 2.00 WELCTL NUND P ND tree. Tubing hanger threads OK. Set test dart. 17:00 18:00 1.00 WELCTL NUND P NU 7-1/16", 5 Ksi, full opening valve & DSA. 18:00 00:00 6.00 WELCTL NUND P NU 13-5/8", 5 Ksi BOP stack. Hook up hydraulic lines. NU choke & kill lines. 9/11 /2006 Test BOPs. Witnessing of test waived by John Spaulding, AOGCC Field Inspector. Pull tubing hanger to floor and circulate 11.0# brine surface to surface. POH stand back tubing, spool up SSSV control line. LD SSSV. Recovered 29 clamps, original tubing tally indicates 36 were ran. Missing 7 clamps. Continue POH, stand back 64 stands 4038' tubin .Continue POH, LD tubin .195 'oints out at midni ht. 00:00 02:00 2.00 COMPZ WELCTL BOPE P NU BOPE. 02:00 03:00 1.00 COMPZ WELCTI BOPE P Function test BOP. Fill stack. PJSM on testin ROPE. f~age 1 ~sf ~ • l Time Logs J Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:00 08:00 5.00 COMPZ WELCTL BOPE P Test BOPE: VBRs & Blind/Shears to 250 psi/3000 psi; Annular to 250 psi/2500 psi; Choke Manifold valves, Choke and Kill lines and valves, floor safety valves to 250 psi/3000 psi; Accumulator capacity test, rebuilt 200 psi in 30 seconds, full pressure in 2 min. 30 sec., OK. Will test Kelly if picked up. Witnessing of test waived by John Spaulding, AOGCC Field Inspector. Sent results to AOGCC. 08:00 09:00 1.00 COMPZ WELCTt EORP P Have DHD crew vac out conductor fluid from 9' to 23'. 09:00 10:00 1.00 COMPZ RPCOM OTHR P Pull dart and BPV. Observed no flow. 10:00 11:30 1.50 COMPZ RPCOM PULD P MU landing joint and screw into tubing hanger. Back out lock-down screws. Pull free at 105K up weight. After ullin free, u wei ht of 65K. 11:30 13:30 2.00 COMPZ RPCOM CIRC P Circulate 11.0# brine surface to surface. 13:30 15:30 2.00 COMPZ RPCOM PULD P Pull 3-1/2" com letion with SSSV control line. Stand back tubing and strap same. LD SSSV. Recovered 29 SS control line clamps. Old tubing detail indicates 36 clamps used. Missing 7 clamps. There was one clamp every otherjoint, so it may be possible that original tubing detail a e was incorrect. 15:30 18:00 2.50 COMPZ RPCOM PULD P POH stand back 3-1/2" tubing, SLM. 18:00 18:30 0.50 COMPZ RIGMNT SVRG P Service rig. 18:30 21:00 2.50 COMPZ RPCOM PULD P Continue POH, stand back 64 stands 3-1/2" tubin ,SLM. 21:00 00:00 3.00 COMPZ RPCOM PULD P Continue POH, LD tubing, SLM. Total of 195 'oints out at midni ht. 9/12/2006 Finish POH LD tubing. Recovered full string thru OEJ Barrel (Chem Cut only penetrated -1/2 of joint). PU & MU BHA #1: 6" Mill, 7" Scraper, etc. RIH to 4064'. CBU, 4 BPM, 3330 psi. POH LD BHA. RIH w/ Baker "wireline set" RBP and h draulic settin tool. 1 stand left to run at midni ht. 00:00 02:30 2.50 COMPZ RPCOM PULD P Finish POH LD 3-1/2" tubing. Recovered full string thru OEJ Barrel, Chemical Cut in middle of joint between GLM and OEJ penetrated pipe for only about 1/2 of circumference. 02:30 04:00 1.50 COMPZ RPCOM PULD P Finish strapping tubing. Clear floor. 04:00 07:00 3.00 COMPZ RPCOM RURD P Bring in Baker tools, strap & tally same. PU & MU BHA #1: 6"Junk Mill + 2 boot baskets + 7" Casing Scraper + BS + Bumper Sub + Jars + 4 SDC + XO. 07:00 10:30 3.50 COMPZ RPCOM TRIP P RIH w/drift BHA on 3.5" tubing to 4064'MD, had to change single joint on stand number 42 bad thread . Pacfe 2 caf 4 r~ ~~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment _ _____ 10:30 12:00 1.50 COMPZ RPCOM WOEL T Troubleshoot mud pump, found gravel in pump #1 valve seats and sump, removed debris, possibly came from clean vac truck. 12:00 13:00 1.00 COMPZ RPCOM CIRC P Circulate bottoms up 13:00 16:00 3.00 COMPZ RPCOM TRIP P POOH standing back tubing 16:00 17:30 1.50 COMPZ RPCOM PULD P On surface with BHA, nothing in boot baskets, lay down mill BHA. Clear & clean u floor. 17:30 19:00 1.50 COMPZ RPCOM PULD P Make u RBP BHA. 5.968" Baker WLSRBP/Baker setting tool/Crossover to 3.5" tubin . 19:00 20:00 1.00 COMPZ RPCOM TRIP P RIH with Baker RBP on tubing from derrick. 20:00 22:30 2.50 COMPZ RIGMNT RGRP T Replace 4-way air valve for drawworks hi-drum clutch. 22:30 00:00 1.50 COMPZ RPCOM TRIP P RIH with Baker WLS-RBP with hydraulic setting tool on tubing from derrick. 62 stands in hole at midni ht. PU 15' u . 9/13/2006 RIH. Set Baker WLS-RBP @ 4000' MD, test to 1500 psi. POH LD setting tools. MU M/S &RIH open ended to 3948'. Circ once around, 11.0 ppg brine. Spot 15 Bbl pill w/ 12 sacks CaCO on top of RBP @ 4000'. POH LD tubing. Close 7-1/16" FO Valve & test valve, casing, & RBP to 1500 psi, 15 min., OK. ND BOPE. NU 7" Otis Union & Ca ,test to 1500 si, OK. Released Ri 2400 hrs. Pre to move to 1C-01. 00:00 01:00 1.00 COMPZ RPCOM TRIP P RIH with Baker "wireline set" RBP and hydraulic setting tool on tubing from derrick. MU TIW valve, head pin and circulating lines. Drop 1-7/16" settin ball and let fall. 01:00 02:00 1.00 COMPZ RPCOM DHEO P Set RBP on depth, top @ 4000' MD (Nabors 3S RT - 21.25' RT too LDS). Pressure up in stages, 1500 psi, 2000 psi, 2500 psi and set RBP. Pressure up and sheared shear stud and released setting tool at 3300 psi. PU 2' & verify tool released from RBP. Test RBP & 7" casing to 1500 si for 20 minutes, OK. 02:00 05:30 3.50 COMPZ RPCOM TRIP P PJSM. LD 15' pup joint. POH, stand back tubin . 05:30 06:00 0.50 COMPZ RPCOM PULD P LD Baker setting tools. 06:00 06:30 0.50 COMPZ RPCOM PULD P PU & MU muleshoe. Prepare to RIH o en ended. 06:30 09:00 2.50 0 3,950 COMPZ RPCOM TRIP P RIH open ended to 3948'. 09:00 10:00 1.00 3,950 COMPZ RPCOM CIRC P Circulate once around, 4 BPM, 200 psi. _Mix and pump 15 Bbl visosified ill with 12 s k s of ill above Baker RBP 4000'M D. 10:00 12:00 2.00 3,950 0 COMPZ RPCOM TRIP P POOH laying down 3.5" tubing 12:00 15:00 3.00 0 COMPZ RPCOM RURD P On surface with tubing, lay down make-up equipment, mule shoe, clear and clean ri floor. Pane 3 of d Time Low __ Date From To Dur S. De th E D~th Phase Code Subcode T Comment T 15:00 ____ 17:00 _ 2.00 COMPZ ___ RPCOM DHEO P Close 7 1/16" valve. Rig-up lines to test 7-1/16" valve, 7" casing, & RBP to 1500 PSI, 15 minutes, good test. charted Drain stack. 17:00 22:00 5.00 COMPZ RPCOM NUND P Slowdown lines. ND BOPE. Set stack back on drilling spool on skid & MU. Lay stack over on skid. ND DSA. 22:00 00:00 2.00 COMPZ RPCOM NUND P NU 7-1/16" flange with 7" Otis Union & Cap. Test same to 1500 psi, OK. Bleed off test. Secure well. 7-1/16" full opening valve left in closed osition. Release Ri . _ ~ P~x€~~ ~~ t ~ 2V-08A Well Events Summary . DATE SUMMARY 8/31/06 POT-T- PASSED, PPPOT-T -PASSED, POT-IC -PASSED, PPPOT-IC -PASSED, LDS FUNCTION TEST -PASSED 9/2/06 VAC OUT CONDUCTOR 9/3/06 TAG FILL ~ 8649' RKB. ESTIMATE 29' OF FILL. OBTAIN SBHP'S OF 3284 PSI (111 DEG F) @ 8632' RKB AND GRADIENT OF 3241 PSI (111 DEG F) @ 8495' RKB. REPLACED CV'S @ 8235' & 8395' RKB W/ DV'S, SET 2.25" CA-2 BLANKING PLUG Cad 8535' RKB, PT TBG TO 2000# GOOD TEST. DUMP A COUPLE LOADS OF CALCIUM CARBONATE ON PLUG Ca) 8535' RKB. PULLED 1.5" DV @ 8227' RKB. CIRCULATE 290 BBLS OF 9.6 BRINE DOWN TBG TAKING RETURNS UP IA. BLEED TBG & IA TO 0 PSI AND HOLDING. 9/5/06 LOAD OA WITH 12# BRINE 9/5/06 CHEMICAL CUT TUBING. 2-5/8" CHEMICAL CUTTER & STRING SHOT. STRING SHOT INTERVAL: 8240'-8252'. 2-5/8" CHEMICAL CUT AT 8251' IN MIDDLE OF FIRST FULL JOINT ABOVE OEJ. DID NOT TAG TD. 9/7/06 VAC OUT CONDUCTOR FLUID TO 26' 9!9/06 RD Nabors 3S at 2C-16. Begin move to 2V-08A. 9/10/06 Move Nabors 3S rig over well, RU, raised derrick. Accept rig @ 1100 hrs. Pull BPV to ensure well is dead. Install BPV. ND tree. NU 7-1/16" FO valve, DSA, BOPE. 9/11/06 Test BOPS. Witnessing of test waived by John Spaulding, AOGCC Field Inspector. Pull tubing hanger to floor and circulate 11.0# brine surface to surface. POH stand back tubing, spool up SSSV control line. LD SSSV. Recovered 29 clamps, original tubing tally indicates 36 were ran. Missing 7 clamps. Continue POH, stand back 64 stands (4038') tubing. Continue POH, LD tubing. 195 joints out at midnight. 9/11/06 EVACUATE CONDUCTOR FLUID FROM 9' DOWN TO 23'. 9/12/06 Finish POH LD tubing. Recovered full string thru OEJ Barrel (Chem Cut only penetrated ~1/2 of joint). PU & MU BHA #1: 6" Mill, 7" Scraper, etc. RIH to 4064'. CBU, 4 BPM, 3330 psi. POH LD BHA. RIH w/ Baker "wireline set" RBP and hydraulic setting tool. 1 stand left to run at midnight. 9/13/06 RIH. Set Baker WLS-RBP @ 4000' MD, test to 1500 psi. POH LD setting tools. MU M/S &RIH open ended to 3948'. Circ once around, 11.0 ppg brine. Spot 15 Bbl pill w/ 12 sacks CaCO on top of RBP @ 4000'. POH LD tubing. Close 7-1/16" FO Valve & test valve, casing, &RBP to 1500 psi, 15 min., OK. ND BOPE. NU 7" Otis Union & Cap, test to 1500 psi, OK. Released Rig @ 2400 hrs. (Prep to move to 1C- 01. ) 9/15/06 VAC OUT CONDUCTOR FLUIDS, SAMPLED CONDUCTOR & OA GAS & CONDUCTOR FLUIDS FOR LAB ANALYSIS 9/18/06 UNABLE TO PERFORM USIT CEMENT BOND LOG . MISSING VALVE HANDLE FOR 7-1/16" FMC VALVE. JOB POSTPONED. 9/21/06 U$IT__LO,GGED IN 7 INCH_CASING. FOUND POOR CEMENT OVER ENTIRE LOGGING INTERVAL. ALSO OBSERVED HIGHLY CORRODED ZONE FROM 690 - 700 FT. LOGGED FROM RBP TO SURFACE (0 - 4000 FT). 9/23/06 VAC OUT CONDUCTOR 24' 9/27/06 VAC OUT CONDUCTOR STARTED @ 6' FINAL DEPTH IS 26' T/I/0= SI/O/O 10/5/06 Vac out conductor from 4'10" to 26', unable to vac OA. 10/10/06 VAC OUT CONDUCTOR 10/12/06 Bridge Plug Rental 10/14/06 RAN LEAK DETCTION LOG USING TECWEL NOISE TOOL: LOGGED FROM CIBP AT 3996' TO SURFACE. NO FLUID OR GAS WAS OBSERVED COMING FROM THE CONDUCTOR DOWNSPOUT WHILE LOGGING, LOGGED FOR BASELINE PASS -WILL RE-LOG IF LEAK REOCCURS. RESULT FROM PDS PENDING. 2V-08A Well Events Summary 11/5/06 RAN A TECWELL LDL. LOG UP PASS AT 15 FPM TO CHECK FOR~AK. NO LEAK FOUND. LOGGED UP PASS AND STATION READINGS OVER AREA OF INTEREST AT 700'. NO LEAK WAS FOUND. WELL FLOWED UP CONDUCTOR x SURFACE CASING ANNULUS IN TWO BURSTS. NOT CONSISTANTLY. WHISPING GAS DURING ENTIRE OPERATION. 5 HOURS AFTER START FIRST FLOW (OVERFLOWING ~3 GALLON BUCKET).- SECOND FLOW ROUGHLY 7 HOURS LATER AND FILLED 4" IN 55 GALLON DRUM 12/31/06 RAN 6.125" RING ON JUNK BASKET TO 3961' SLM,NOTHING RECOVERED.RAN PDS MTT & CALIPER FROM 3961' SLM TO SURFACE.WHISPER OF GAS FROM CONDUCTOR X SURFACE CASING ANNULUS, ABOUT 6" OF FLUID FLOWED INTO 55 GAL DRUM.KEPT OA BELOW 4 PSI DURING ENTIRE JOB. 3/3/07 LOGGED TECWEL'WAF' LEAK DETECT LOG FROM 3994' TO SURFACE. RESULTS PENDING TECWEL INTERPRETATION. POSSIBLE LEAK ANOMALY AT 1685' -----.. WELL ACTIVELY DRIPPING FROM CONDUCTOR DOWNSPOUT THROUGHOUT LOG. 5/15/07 RUN EMIT/PMIT FOR CORROSION ANALYSIS FROM 3984- 1000'. EMIT FAILED AT 1000': 9 5/8" CASING SHOE AT 3672', NOT 3868' AS WELLBORE SCHEMATIC INDICATES. NOTE: SURFACE CONDUCTOR DRAIN PIPE IS FROZEN AND NOT DRAINING. 5/21/07 DRIFT TBG w/ 5.95" GAUGE RING TO 3965' SLM. JOB COMPLETE. 6/1/07 LOGGED EMIT/PMIT FROM 1510' TO SURF AT 900 FPM NO SIGNIFICANT INTERNAL METAL LOSS DETECTED WITH PMIT EMIT DATA TO BE EVALUATED BY DEVELOPMENT TEAM 6/4/07 PERFORATE 7" 26# PRODUCTION CASING FROM 790-792' CORRELATED TO USIT LOG DATED 21-SEP-2006. PERFORATE WITH 3 3/8" HSD GUNS LOADED 6 SPF WITH 3406 POWERJET CHARGES. RETURNS TO CONDUCTOR DOWNSPOUT INCREASED SIGNIFICANTLY AFTER PERFORATING. RIGGED LRS TO PRODUCTION CASING VIA PUMP IN SUB AND PUMPED 10 BBLS AT 0.75 BBL/MINUTE (125-PSI). TOOK APPROXIMATELY 10 BBLS TO CONDUCTOR DOWN SPOUT AND VAC TRUCK. 6/20/07 SET HALIBURTON 71N LW FAS DRILL BRIDGE PLUG MID ELEMENT AT 810' 7/16/07 ULTRA SONIC CORROSION IMAGING TOOL (UCI AND USI RUN IN SEPARATE RUNS FOR CORROSION) FOUND HOLE IN CASING FROM 691'-697'. GEMCO TYPE CENTRALIZERS RUN ON SONDE IN ADDITION TO INTEGRAL SONDE CENTRALIZERS AND STILL HAD SOME ECCENTRALIZATION ISSUES- AFFECTING SOME OF THE PIPE THICKNESS DATA. INTERNAL RADIUS DATA LOOKS GOOD. 7/21/07_ Pumped two 75 BBL stages of AS1 into 9 5/8" Casing via perforations at 790- Z~?'~nn 9.6 PPG Brine was circulated prior to cement stage. 85 BBLS 9.6 PPG brine returns cleaned up <1-1. First 75 BBL stage AS1 pumped at 5 BPM 450 PSI for 25 BBLS. Rate lowered to 3 BPM 300 PSI for 25 BBLS. 1 BPM 150 PSI for 25 BBLS. At 68 BBLS away weak cement water to surface via 9 5/8" down spout @ .2 RPM,_ r~a~, Called for second truck of 75 BBLS cement. Pumped second stage at 5 BPM 450 PSI. initial pump start up took 825 PSI to open communication to shoe. During second stage no returns to surface. Second stage included 200# fiber for plug off effect. (witnessed no change). 7" freeze protected with 25 BBLS diesel. Pad operator notified for special walk around /drum inspection for fluid content until DHD performs PT on 7". Will need to drift & tag in preparation of cement log program for isolation assurance. 7/26/07 Prod Csg PT Failed, LLR = 5.5 gpm, no increase in drip rate to conductor catch drum, all fluids pumped appear to have gone downhole 2V-08A Well Events Summary 9/8/07 DRIFT TO 300' W/ 6.125 JU~ASKET, WORK TO 619' SLM (TIGHT S~S)- BASKET MT @ SURFACE. RBIH W/ 2.55 GR AND TAGGED @ 619' SLM; UNABLE TO GET DEEPER. RECOVERED SAMPLE OF CEMENT. JOB COMPLETE. 9/28/07 RAN 6"JUNK BASKET GR AND ISOLATION SCANNER. TAGGED PTBD AT 630' WITH JUNK BASKET RUN. FOUND HIGH QUALITY AS1 CEMENT IN 7 x 9 5/8" ANNULUS TO SURFACE. 11/9/07 PERFORATED FROM 600'-602' WITH 3-3/8" HSD POWERJET GUN. PUMPED 15 BBL DIESEL DOWN TUBING WITH LITTLE RED. DID NOT GET ANY RETURNS AT SURFACE THROUGHOUT JOB. 11/16/07 Pumped 47 bbls of AS1 Cement into perfs @ 600' leaving Top of Cement @ 500' in an attempt to stop Conductor leak. Conductor was not leaking when we started pumping but started leaking during the displacement. Left vac truck to monitor well. 1/19/08 MITPC -PASSED 2/12/08 Standby for rig up. Restart in A.M. 2/13!08 RIH with CTU to 60 ft, pumped total of 57 bbls hot h2o before conductor had steady flow to catch drum. Flow from Conductor x surface casing annulus appears to be temperature related and does not appear to be coming from any downhole producing intervals. Surface casing annulus appears to have good isolation from previous cement squeezes. RIH to tag of 439 CTMD, freeze protected well with diesel. 4/9/08 PRE RWO IC-POT & PPPOT (PASSED ) r KRU 2V-08A (~~ Cc~rt4Gt~Phi~~ips Alas3ca, (nc. ', 2V-08A CSG PUNCHES (soo-sot, OD:7.000) CSG PUNCHES (7so-7sz, OD:7.000) SUR. CASING (0-3~. OD:9.625, wr.3s.ao) OLD TUBING (azs7-s5az, OD:3.500, ID:2.992) PKR (8285-8286, OD:6.151) Perf (e446-a4e8) PATCH (8489-8511, OD:3.500) PKR (8518-8519, OD:6.151) PLUG (8535-8536, OD:2.250) SOS (8542-8543, OD:3.500) Perf (8586-8612) HYI: DUUpL I ILtSW VVell I e: IIVJ Hn le aJ I J: 4D Oe QI 8440 SSSV Type: NONE Orig 9/13/1984 Angle @ TD: 42 deg @ 9050 Com letion: Annular Fluid: Last W/O: 9/14/20D6 Rev Reason: CSG PUNCHES Reference Lo Ref Lo Date: Last U date: 11/10/2007 Last Ta : 619' SLM TD: 9050 ftK6 Last Ta Date: 9/8/2007 Max Hole Angle: 53 deg n 3900 - Gasin Sarin -ALL STRINGS Descri lion Size To Bottom ND Wt Grade Thread CONDUCTOR 16.000 0 103 103 65.00 H-40 SUR. CASING 9.625 0 3668 2728 36.00 J-55 PROD. CASING 7.000 0 9034 6267 26.00 J-55 Tubin Strin - T UBING OLD COMPLETIQN~_ Size _ To Bottom TVD tM Grade Thread 3.500 ----- 8267 8542 5905 9.30 J-55 EUE 8rd Perforations Summary Interval TVD Zone Status Ft SPF Date T Commem 8446 - 8488 • 5837 - 5866 C-4,UNIT 42 12 9/13/19B4 IPERF 120 deg. phasing; 51/2" - B Cs Gun 8586 - 8612 , 5937 - 5956 A-4 26 4 9/13/1984 IPERF 90 deg. phasing; 4"Csg Gun 8628 - 8678 5968 - 6005 A-3 50 4 9/13/1984 IPERF 90 deg. phasing; 4" Csg - ~ Gun - - 1rt'ection MandrelsNalves ~ - - '~ St MD __ TVD .._ Man Mfr Man Type _ V Mfr V Type V OD Latch T Port - TRO Date Run VN Cmnt 2 8325 5753 Camco KBUG DMY 1.0 BEK 0.000 0 9/3/2006 3 8395 5801 Camco KBUG DMY 1.0 BEK 0.000 0 9/3/2006 4 8499 5874 Camco KBUG PATCH 1.0 BK 0.000 0 5/18/2000 Other ~plu~s, equip., etc. -OLD COMPLETION (POST WORKOVER 9114/2Q06) 790 769 CSG PUNCHES CASING PUNCHES 3 3/8" HSD PJ, 6 SPF 6/4/2007 0.000 810 787 PLUG 7" FASDRILL BRIDGE PLUG MID ELEMENT set 6/20/2007 0.000 4000 2930 PLUG 7" RETRIEVEABLE BRIDGE PLUG SET AFTER UPPER PORTION OF OLD COMPLETION PULLED 9/14/2006 0.000 8285 5725 PKR Camco'HRP-I-SP' 2.937 8489 5867 PATCH Set HES permanent patch across GLM @8499' RKB. Top of patch set @ 8489' to 8511'; min. ID 2.375" 5/18/2000 2.375 8518 5888 PKR Baker'FB-1' 4.000 8535 5900 PLUG TTP set 9/3/2006 0.000 8535 5900 NIP Camco'D' Nipple NO GO. Set 2.75" x 2.25" "D" profile nipple reducer 5/16/2000 2.250 8542 5905 SOS Baker 2.992 8543 5906 TTL 2.992 3eneral No€es ~ x Perf (8628-8678) • ~: ~~ ~~~ ; Ia~~ ~ ~ ~ ~f~~ I~~~ ~~ ~ ~ i ', ~ ;~ ~ ~ 1 `., ~ a t ~~ OIL ~ lftll7 COrTSERQATIOI~T COMI~IISSI01~ MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~i Re: Kuparuk River Field, Kuparuk River Oil Pool, 2V-08A Sundry Number: 308-241 ~`Y" ~~ JU~ ~. ~ 2dU~ Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Corrunission to witness any required test, contact the Commission's petroleum field inspector at (90~ 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. . 7~ DATED thisl~ day of July, 2008 Sincerely, ~~ Darnel T. Seamount, Jr. Chair Encl. • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 7, 2008 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~/~~~. ~~~ ~ ~ Z~0 ,~Oil~ ~~~ ,- ~ .. i_~ ,. .. ~iJi Enclosed, please find a request for Sundry Approval to reattempt a repair of the surface casing leak on we112V-08A (PTD 184-091). Please call me or Perry Klein at 659-7043 if you have any questions. Sincerely, ~ 6- ~,. MJ L eland Well Integrity Projects Supervisor Attachments ~. 4 0. ~~:~ ,i STATE OF ALASKA ~A ~U ~t ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~,~~ ~' Q 9 j~.~~t~ ~ ~ APPLICATION FOR SUNDRY APPROVAL ~ ~'~~ ~~ ~~ ~r1. 20 AAC 25.280 ~ ^ -; 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well /^ ~ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ patch SC 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 184-091 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21128-00 '~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y2S ^ NO Q 2V-08A ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 0025655 ' ALK 2581 RKB 113' , Kuparuk River Field /Kuparuk Oil Pool , 12. PR ESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9050' 6279' 4000' - RBP, 810' Fastdrill BP Casing Length Size MD TVD Burst Collapse CONDUCTOR 103' 16" 103' 103' SURFACE 3755' 9-5/8" 3868' 2728' PRODUCTION 8921' 7" 9034' 6267' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8446-8488, 8586-8612', 8628-8678' 5837-5866, 5967-5956, 5968-6005 3-1 /2" J-55 8267-8542' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= CAMCO'HRP-1-SP' ; BAKER'FB-1' pkr= 8285' ; 8518' no SSSV no SSSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service^ • 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: September 1, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and Corr t to the best of my knowledge. Contact: Perry Klein/ MJ Loveland Printed Name MJ Lov n Title: Well Integrity Project Supervisor Signature ,~~~''~ "'~ ~..-~, Phone 659-7043 Date ~'~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness .30 ~ , 4. Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ t_ ,, ~n ~ ~~Q~ 2~t:CCa.VCf.~~ :T ~~-~~l'i ' ~tQ QQ~ C__ Other: '~~~ ~Cvv"~~~~G~°CO°t~ ©~ ~Cj MG S . e ~ Subsequent Form Required: ` , ~ "1 ~, ORIGINAL ' c APPROVED BY ~®' ~ ~ Approved by: COMMISSIONER THE COMMISSION Date: ~h Form 10-403,$Cevisedl 06/2006 a ~,~~e~ra~ us ~° JvL ) 5t LUUg u i D licate ConocoPhillips Alaska, Inc. • Kuparuk Well 2V-08A (PTD 1840910) Sundry Notice 10-403 Request 7-Jul-08 Purpose: The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to repair a known surface casing leak that is 8 feet below grade. History (if needed): The leak is a known 2' long split and is located approximately 8-feet below the surface casing annular valve, or approximately 5-foot below the top of the conductor. The actual split is only about 2' long however the extent of the surface casing deformation is the entire joint of surface casing. The damage was originally excavated but not repaired in 2006 because full working pressure could not be achieved. The purpose of the repeat attempt is to contain the leak and achieve a working pressure greater than 200 psi. The conductor casing will require partial removal to expose the damaged surface casing and a 26' excavation around the wellhead will be necessary to provide adequate workroom Proposed Plan: 1. Remove well house, floor boards and cellar box as needed for access 2. A 26' deep excavation around wellhead is needed to provide workroom. 3. Drill and Tap the conductor in several locations. Install nitrogen purge fittings in conductor penetrations. Several locations may be used to ensure adequate purge gas flow inside the casing. 4. Cut and remove Tanko head from conductor. 5. Cut and remove approximately 22-25' of the 16" conductor. ,~ 6. Clean surface casing for visual inspection. 7. Notify AOGGC for inspection opportunity 8. Visually inspect the 9 5/8" surface casing for additional damage, penetrations and areas of concern with Mechanical Engineer (x7258). Perform UT in wedding band areas and magnet flux or UT test any other areas of concern. Prepare welding repair plan as per Mechanical Engineer's direction (sleeve /patch or other). 9. Repair casing, QA/QC. Cover with corrosion protection materials. 10. Install new conductor casing and back-fill void area with cement and corrosion inhibitor 11. File 10-404. KRU 2V-08A ConocoPhillips A laska, Inc. 2V-08A API: 500292112800 Well Type: INJ Angle @ TS: 45 de 8446 SSSV Type: __ NONE Orig 9/13/1984 Angle @ TD: 42 deg @ 9050 CsG PUNCHES Com letion: (soo~o2, Annular Fluid: Last W/O: 9/14/2006 Rev Reason: CSG PUNCHES oD:7.oo0) Reference Lo : Ref Lo Date: g Last U date: 11/10/2007 - Last Tag: 619' SLM - - - - TD: 9050 ftK6 csG r Last Ta Date: 9/8/2007 Max Hole An le: 53 de 3900 PUNCHES Casin String - ALL STRINGS pso-7s2, _ _ _ ottom l TVD Wt Grade Thread Descrl lion Size Top B oD:7.oo0) _ _ CONDUCTOR 16.000 0 103 103 65.00 H-40 SUR. CASING ______ 9.625 __ 0 3668 2728 36.00 J-55 _ _ __ _ PROD. CASING 7.000 0 9034 6267 26.00 J-55 Tubin Stri~_-TUBING (OLD COMPLETION - --- Size Top_ Bottom TVD Wt Grade Thread ____ 8267 8542 I 5905 9.30 J-55 EUE 8rd 3.500 suR. _ Perforations Summa CASING (03668, -- -- Interval_ _ TV_ D_ _ Zone _ Status Ft SP_F Date_ __ Type Comment oD:s.sz5, 8446 - 8488 5837 - 5866 C-4,UNIT 42 12 9/13/1984 IPERF 120 deg. phasing; 5 1/2" wc3s.oo) g Cs Gun 8586 - 8612 5937 - 5956 A-4 26 4 9/13/1984 IPERF 90 deg. phasing; 4" Csg Gun 8628 - 8678 5968 - 6005 A-3 50 4 9/13/1984 IPERF 90 deg. phasing; 4" Csg Gun In action MandrelsNalves OLD TUBING St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv (82678542, Cm nt oD:3.5o0, 2 8325 5753 Camco KBUG DMY 1.0 BEK 0.000 0 9/3/2006 IDZSSZ> 3 8395 ' 5801 Camco KBUG DMY 1.0 BEK 0.000 0 9/3/2006 _ 4 8499 5874 Camco KBUG PATCH 1.0 BK ----- 0.000 0 5/18/2000 PKR ( (POST WORKOVER 9/14/2006) ui etc Othe lu e ) -OLD CO {ETION lazes-azfis OD:6.151) p g p., r q . _ s,_ _ _ Depth TVD Type Description ID 600 594 CSG CASING PUNCHES 3 3/8" HSD PJ, 6 SPF 11/9/2007 0.000 PUNCHES 790 769 CSG CASING PUNCHES 3 3/8" HSD PJ, 6 SPF 6/4/2007 0.000 PUNCHES 810 787 PLUG 7" FASDRILL BRIDGE PLUG MID ELEMENT set 6/20/2007 0.000 4000 2930 PLUG 7" RETRIEVEABLE BRIDGE PLUG SET AFTER UPPER PORTION OF 0.000 OLD COMPLETION PULLED 9/14/2006 8285 5725 PKR Camco'HRP-I-SP' 2.937 8489 5867 PATCH Set HES permanent patch across GLM @8499' RKB. Top of patch set @ 2.375 8489' to 8511'; min. ID 2.375" 5/18/2000 Perf 8518 5888 PKR Baker'FB-1' 4.000 (eaas~4ee) 8535 5900 PLUG TTP set 9/3/2006 0.000 8535 5900 NIP Camco'D' Nipple NO GO. Set 2.75" x 2.25" "D" profile nipple reducer 2.250 5/16/2000 ; _ 8542 _ 5905 SOS Baker ; 2.992 _ 8543 5906 TTL 2.992 General Notes Date ~ Note 12/2/2003 NOTE: WAIVERED WELL: OA x OOA COMMUNICATION PATCH 9/14/2006' NOTE: TOP PORTION OF COMPLETION PULLED - "NOT RERUN" (8489511, OD:3.500) PKR (8518$519, OD:6.151) PLUG 8535$536 ( , OD:2.250) SOS _ (8542-8543, OD:3.500) Perf (8586-8612) Perf (8628678) ~1Ci~~~~~a~~~r1- Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~ o~ ;~,~~~~ N0~ ~ 2007 Log Description ._, ._ ''"d"ate N0.4445 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD 10!15/07 2N-343 (REDOy 11745232 MEM INJECTION PROFILE ` = C - '~ 08108107 1 1 B-14 11837493 PRODUCTION PROFILE ~ - 08/27/07 1 1A-18 11839651 PRODUCTION PROFILE (~- 08/30/07 1 1Y-18 11837499 PRODUCTION PROFILE C' 08/30/07 1 1G-14 11839652 INJECTION PROFILE ~ ~ ~j- ~( 08131107 1 1A-01 NIA USIT - 08131/07 1 1Y-04 11839653 INJECTION PROFILE f~ ~ 09101/07 1 1Y-32 11839655 PRODUCTION PROFILE ~ - 09/02/07 1 2T-TAB-01 11839656 INJECTION PROFILE C - 09103/07 1 2K-25 11846439 INJECTION PROFILE U = j 09/06/07 1 2K-18 11846440 INJECTION PROFILE / -~ 09/07/07 1 18-18 11846441 PRODUCTION PROFILE < - 09108107 1 2T-20 11846442 PRODUCTION PROFILE ~' fj - 09/09/07 1 2N-310 11850433 SONIC SCANNER 7b"~ -(~ t5 09/16/07 1 2N-310 11850433 SONIC SCANNER-FMI ~ - C~`-~ 09/16/07 1 1J-176 11846443 US{T "~ -p 09/17107 1 1E-29 NIA UCI ~ -1 09/19/07 1 3F-21 11837503 RST/ WFL - 09/20/07 1 26-10 11839661 INJECTION PROFILE L - 09/22/07 1 1G-05 11837506 INJECTION PROFILE v ~C 09123107 1 2H-13 11839662 INJECTION PROFIL ~ - 09/23107 1 1B-05 11837508 INJECTION PROFILE .LL 09/24/07 1 3H-08 11839663 PRODUCTION PROFILE (~ 09124107 1 1Y-31 11839664 PRODUCTION PROFILE ~ ~i - 09125107 1 1G-06 11839665 INJECTION PROFILE 09/26/07 1 2Z-01A 11837512 USIT - / ( 09/27/07 1 2V-08A 11837511 ISOLATION SCANNER ~~ - 09/28/07 1 1G-11 11837513 PRODUCTION PROFILE - 09/29/07 1 1Y-22 11837515 PRODUCTION PROFILE 6 09/30/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • 07/23/07 Scblumbel'gel' NO. 4336 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ,JUL 2 5 Z007 Oil B! . Cons. GomrniS1Jiol1... 2 '7 2.007 /\ndloŒg~¡ scANÞìED JUL Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 U J:C- I "ffÁ1-o~ / Field: Kuparuk - ,. ..-::..~!';"~"..,,._'~.-. Well Job# Log Description Date BL Color CD \1:J 2M-20 11629044 PRODUCTION PROFILE 07/11/07 1 3M-20 11665456 INJECTION PROFILE 07/13/07 1 2M-27 11665457 INJECTION PROFILE 07/14/07 1 1 R-20 11632727 LDL 07/12/07 1 2M-17 11632731 INJECTION PROFILE 07/14/07 1 3M-27 11632732 LDL 07/15/07 1 1R-15 11632734 INJECTION PROFILE 07/17/07 1 2L-327 11665460 TEMPERATURE SURVEY 07/17/07 1 2V-08A 11665459 USIT 07/16/07 1 2Z-16 11665458 SCMT 07/15/07 1 2N-343 11665463 INJECTION PROFILE 07/20/07 1 1L-07 11632735 INJECTION PROFILE 07/20/07 1 1A-09 11632736 INJECTION PROFILE 07/21/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . 06/08/07 Schlullbepger NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ], 120m (~ié\l'j.con~,.G{)m~NED JUN 142007 U ...LŒ. 1~L.f -cf1/ Kuparuk ~v Field: Well Job # Date Color CD Log Description BL .', .-...,.'!,................. . 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROF/LDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1C-125 N/A MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RST/ WFL 05/04/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1 1E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT OS/25/07 1 2V-08A 11629013 PMIT 05/15/07 1 1J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1H-07 11665436 SBHP SURVEY OS/20/07 1 2F-11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1 B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE OS/22/07 1 1H-22 11637339 INJECTION PROFILE 05/16/07 1 1Y -11 11632708 INJECTION PROFILE OS/23/07 1 1G-03 11637336 INJECTION PROFILE 05/14/07 1 1A-23 11665443 MEM PRODUCTION PROFILE OS/29/07 1 1 F -08 11665435 SBHP SURVEY OS/20/07 1 1J-170 11632709 INJECTION PROFILE OS/24/07 1 1D-109 N/A INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY OS/28/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . . WELL LOG TRANSMITTAL i~~=j·¡ ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-51 02 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) EDE Disk 2V - OBA Leak Detect - WAF 04Mar-07 ~c~ APR 0 3 2007 .:r(! l~¿( -60., ( qt JL( :)91 .iI'!:t~ Signed: ~1 dli l . X. '''---/ Date : CJl r)~.-h IA p t1t~l1 iA (Lp 1/1 Print Name: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: V\J'W'J\J.MEMOR'fLOG.COM D:\Master _Copy _00_ PDSANC-2OxxIZ _ W ordlDislributionlTransrnittal_ Sheets\Transrnit_ Original.doc . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1J 2) 3J 4J 5J 6J 1 BL / EDE Disk 2V - OBA Caliper Report 31-Dec-D6 5CANNED JAN 0 8 2007 UI~ I <¡£.{- OC¡ I i::i- 1~{3IÒ 7) Signed: (~.t~- ~-0 r 75+'1/10 Mo. 1,1 ¡Ii /,("'" 111 Print Name: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: .,.C\L_::>''''''~.;·!''::':~·''_:;·':·:': WEBSITE:'" _" ...,',. .. 0\00 ..PDSANC-2006\Z, Word\Disinbution\Tf1l!1Smittal, Sheetsífransmit, Origmal.doc I I I I I I I I I I I I I I I I I I I Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: Pipe3Desc.: Pipe3 Use: . . Memory Magnetic Thickness Tool and Caliper Log Results Summary ConocoPhillips Alaska, Inc. December 31,2006 6141 1 7" 261b J-55 Production Casing 9.625" 36 Ib J-55 Surface Casing 16" 65 lb. H-40 Conductor Pipe Well: 2V-08A Field: Kuparuk State: Alaska API No.: 50-029-21128-00 Top Log Intvl.: Surface Bot. Log Intvl.: 3,960 Ft. (MD) Top Log Intvl.: Surface Bot. Log Intvl.: 3,868 Ft. (MD) Top Log Intvl.: Surface Bot. Log Intvl.: 103 Ft. (MD) Inspection Type: Assess Corrosive Damage (Metal Loss) to Production Casing. COMMENTS: This Caliper/MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first log of this well with the 40-Arm Multi-finger Caliper (MFC) and 12 Arm Magnetic Thickness Tool (MTT). The caliper records the features of the internal surface of the 7" production casing in this well and the Magnetic Thickness Tool responds to the total thickness of metal of the 7",9.625" casing and 16" conductor pipe within the logged interval. The entire tubing string was logged with both tools, but the MTT recorded useable data only up to the bottom of the 9.625" surface casing (3,640') - therefore MTT results are only provided for this interval (3,640' - 3,960'}- In this log, the MTT was calibrated down hole (3,800'), where the readings are assumed to represent undamaged tubing and casing. The total amount of metal sUffoundinq the MTT in the interval (surface- 3.640') exceeded the amount under which the tool can operate fJrofJerlv. Therefore. no interfJretable data is recorded in this interval. INTERPRETATION OF CALIPER LOG RESULTS FOR 7" PRODUCTION CASING: The 7" production casing interval logged appears to be in good condition with respect to corrosive damage. No significant wall penetrations, areas of cross-sectional waif loss, or 1.0. restrictions are recorded in the 7" production casing interval logged. A slight bend is recorded in joint 1 at -12'. No significant 1.0. restriction is recorded at 12'. The distribution of maximum - recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS (Caliper): No significant wall penetrations (> 10%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS (CaIiPe~ECEIVED No significant areas of cross-sectional wall loss (> 4%) are recorded. JAN 0 9 Z007 MAXIMUM RECORDED ID RESTRICTIONS (Caliper): ProActive Diagnostic Services, Ire Phone: or 565·9085 Fax: PruÔhc)e 8a\/ Fiejd Office Phone: Alaska Oit & Gas ConS. commisSIon Anchorage No significant 1.0. restrictions are recorded. P<O, Box 1369{ 659-2307 Fax: u:t:C- I i5~( -OO¡ I 1;t l'f31D I I . . I I INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval between 3,640' - 3,960'. The recordings indicate 3% and 4% circumferential metal loss in the interval between (3,747' - 3,779') and (3,899' - 3,933'), respectively. However, the apparent metal loss in these intervals is probably a result of the casing manufacturing process and not an actual meta/loss due to corrosion. The percentages are noted in this report for future reference. I I The total amount of metal surrounding the MTT in the interval (surface- 3,640') exceeded the amount under which the tool can operate properly. Therefore, no interpretable data is recorded in this interval. I I I I I I I I I Field Engineer: D. Cain Analyst: M Tahtouh & J. Burton Witness: C. Kenedey 7"7497" I I I I I I I I I I I I I I I I I I I - Well: Field: Company: Country: 2V-OBA Kuparuk ConocoPhillips Alaska, Inc. USA Tubing: Nom.OD 7 ins Weight 26.5 f Grade & Thread J-55 Penetration and Metal loss ('Yo wail) penetration body metal loss body 150 100 50 o o to 1% 10 to 20 to 40 to over 20% 40% 85% B5% 1 to 10% pene. loss o o Damage Configuration ( body ) 10 o isolated general line ring hole / pass pitting corrosion corrosion corrosion ible hole total = 2) o o PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal sl: December 31, 2006 MFC UW 40 No. 210357 2.75 40 M. Tahtouh Norn.ID 6.276 ins Nom. Upset 7ins Upper len. 6.0 ins Lower len. 6.0 ins Damage Profile ('Yo wall) penetration body o 1 metal loss body 50 100 101 \ \ \ \ \ 51 Bottom of Survey = 103 Analysis Overview page 2 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal ID.: 7. in 26.5 ppf J-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: 2V-08A Kuparuk ConocoPhìllips Alaska, Inc. USA December 31, 2006 Joint Jt. Depth 1\'1) Pen. Pen \¡¡etal Min. Damag e Profile No. (Ft.) Body !.D. Commenls (% wall) (Ii) (Ins.) (Ins.) 0 50 100 1 0 0 0.02 6 4 6.20 SIÌlzht Bend Middle Bodv. 2 27 0 0.01 ;: 1 6.26 3 67 0 0.01 3 I 6.26 4 106 0 0.01 4 1 6.25 5 144 0 0.01 4 ¡ 6.26 6 184 0 0.01 1 6.25 7 224 0 0.01 I 6.25 8 263 () 0.01 I 6.24 9 300 0 0.01 I 6.25 10 338 0 0.02 I 6.27 11 378 0 0.01 ;: 6.26 12 416 () 0.01 -; 6.27 13 455 () 0.01 I 6.26 14 494 0 0.01 I 6.26 15 533 I 0.01 I 6.25 16 573 I 0.01 I 6.25 17 613 I 0.01 I 6.25 18 653 I 0.01 I 6.25 19 689 () 0.01 3 I 6.25 20 729 0 0.01 3 I 6.25 21 769 0 0.01 3 1 6.26 22 807 U 0.01 3 I 6.25 23 847 U 0.01 I 6.26 24 886 0 0.01 I 6.26 25 923 0 0.01 I 6.27 26 961 0 0.02 I 6.13 Lt. Denosils. 27 1001 0 0.01 1 6.26 I 28 1039 0 0.01 3 I 6.26 29 1079 0 0.01 I 6.26 30 1115 0 0.01 I 6.26 31 1155 0 0.01 I 6.25 32 1193 () 0.01 I 6.26 33 1231 0 0.01 I 6.25 34 1268 0 0.01 2 I 6.26 35 1305 0 0.01 4 I 6.27 36 1342 0 0.02 4 I 6.26 37 1382 0 0.01 t 6.26 38 1420 0 0.01 t 6.24 I 39 1457 0 0.01 I 6.24 40 1496 0 0.01 t 6.24 41 1536 0 0.01 I 6.25 42 1576 0 0.01 ¡ 6.25 I 43 1615 0 0.01 I 6.26 44 1655 0 0.01 3 I 6.25 45 1695 0 0.01 I 6.26 46 1733 0 0.01 ¡ 6.26 47 1770 0 0.01 1 6.24 48 1807 0 0.01 1 6.26 49 1847 U 0.01 1 6.25 50 1886 0 0.01 ¡ 6.24 Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I - PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaIID.: 7. in 26.5 ppf J-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: 2V-08A Kuparuk ConocoPhíllips Alaska, Inc. USA December 31, 2006 Joint Jt. Depth Pen. F~ i [vlelal Min. Damage Profìle No. (Ft.) Body 1.0. Comments (%wall) ( (Ins.) (Ins.) 0 50 100 51 1922 0.02 4 1 6.25 52 1960 0.01 ¡ 1 6.24 53 2000 í 0.03 ( 1 6.24 Shallow Ditting. 54 2035 I 0.01 í 6.25 55 2075 í) 0.01 1 6.25 56 2114 I) 0.02 1 6.26 57 2154 0 0.01 1 6.25 58 2194 ) 0.04 I] ¡ 6.26 Shallow nittim!. 59 2232 0.02 6 ~¡ 6.26 60 2271 ( 0.ü1 ( 6.26 ( 61 2309 0 0.01 ¡ 6.24 62 2349 D 0.01 ¡ 6.26 63 2387 0 0.01 '1 6.26 64 2423 0 0.02 I 6.25 65 2461 0 0.01 ¡ 6.25 66 2499 0 0.01 1 6.25 67 2537 í 0.01 I 6.25 68 2576 ( 0.01 3 I 6.24 69 2616 0.01 4 1 6.25 70 2656 0 0.ü1 j 6.25 71 2694 () 0.ü1 1 6.24 72 2734 í 0.01 i 1 6.25 73 2773 ) 0.01 1 6.25 74 2813 0 0.01 1 6.25 75 2852 0 0.01 ( 6.25 ( 76 2889 F 0.01 4 I 6.25 77 2927 I 0.01 I 6.25 78 2966 Ö 0.01 I 6.24 79 3006 í) 0.ü1 ¡ 6.23 ( 80 3045 I 0.01 I 6.25 81 3083 í) 0.01 ( 6.25 ( 82 3119 (I 0.01 1 6.25 83 3159 (I 0.02 ,I I 6.25 84 3199 0 0.01 I 6.23 85 3238 0 0.01 1 6.25 86 3278 0 0.01 I 6.25 87 3317 I 0.01 I 6.25 88 3357 0 0.01 ¡ 6.24 89 3397 () 0.01 1 6.24 90 3436 () 0.ü1 ¡ 6.25 91 3476 ( 0.01 I 6.25 I 92 3516 ( 0.01 3 ( 6.25 93 3554 ( 0.01 4 1 6.24 94 3591 () 0.01 4 I 6.21 95 3631 () 0.ü1 1 6.24 96 3670 O· 0.01 ¡ 6.25 97 3709 í 0.ü1 i 6.25 98 3746 ( 0.ü1 I 6.24 I 99 3782 ( 0.01 I 6.25 100 3822 ( 0.01 4 6.23 Body Metal Loss Body Page 2 I I Pipe: Body Wall: Upset Wall: NominaIID.: I I Joint Jt. Depth No. (Ft.) I 101 3861 102 3898 103 3935 I I I I I I I I I I I I I I . PDS REPORT JOINT TABULATION SHEET 7. in 26.5 ppf J-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: Min. 1.0. (Ins.) 6.24 6.23 6.22 Page 3 2V-08A Kuparuk ConocoPhillips Alaska, Inc. USA December 31,2006 Comments Damage Profile (%wall) o 50 100 Body Metal Loss Body I I I I I I I I I I I I I I I I I I I ~ ~'-s. PnoAcrlvE DIAqNO!iTic SER"¡CE5. INC. Database File: Dataset Pathname: Presentation Format: Dataset Creation: Charted by: Magnetic Thickness (10HZ Log) d: \warrior\data \2v-08eL 3\2v -08. db 2v-08.1 24SCAL -1 Tue Jan 0210:00:042007 by Calc Sondex Warrior VTO Depth in Feet scaled 1225 3680 ..I--r- - 7" Casing I Jt 96 3690 -50 Delta Metal Thickness (%) 50 o Line Speed (ft/min) -200 ~ .. -Bottom of 9.625"-- ~ I .--;¡... ---.: ---- m III 7" Collar j __1. _! '- I--r...: "-i"-'IJ -- J'II.. 7" Colla ~ 7/ ~. . ---J- .-1-.- -f--...- r---h ~--_...... 1 I 1·-... 7" L )11ê!i ...- "J J ... -. I_"'-'{ II I r ( (" Collar - 2.4 -6.4 MTTP01 (red) MTTP12 (red) 12.4 3.6 3640 FImiF=~ ~ - 0- ~ -- = $€-. ~~ "- t=bE~ 3650 7" Casing Ji 95 3660 ..... .- - - - vVIV t £ L 1....-1 I-....t--.. - '-- f'- r--- ;:WI :':il E - - - - -. - - - -.. 3700 '--...,. jf1U .-- ,..-- 3720 1:1 J 7" Casing Ji 97 1---.... --. 3730 1---. - 3740 3750 ~.. ---- 3760 ...-' --- 7" Casing Jt 98 Ë 3770 3780 I-- I ( .. ..-- t--- I--- ~ ~ --. - .-...-... - - - ..-.... -- I ¡--.j....- j-- - - _.~,._...- - .- -- - .- ~I - -r-' - I-- - 1---- 1-- é- I ~ - ~ {I ,. , " Ii (; I Ii I { I fu ,r '" 'w I 1 / ! '--- -,. --' I _____.,_ _"WO' I I I I -,.-.----- I ....- I I I ~""'( I I I ~'--~1 I t= -.., r----· ~ -,- -.r- - I - -.- f--- I~-n 7" Collar 1 -r-- u ,-~..._"-- -:-~ { Collar-I-- -- }--- ,.---- --~ --- 7" Collar .._ J - ---t+--- ..... =F: ...End of La ;I-- I_- I 1 I _.~- I ~ --.--¡--.- -50 Delta Metal Thickness ('Yo) 50 o Line Speed (ftlmin) ,200 I I I , 3790 asing Jt 99 3800 w ~ ..- 3810 w.m___ - 4& '% " t ' $'1 - ~_.. ,. . , 3820 ~ ~ - -. t- 3830 7" Casing -~ Jt 100 If 3840 -~-~- 3850 "'$: - II - 3860 -..~ f- l--. I---' -, 3870 - - 7" Casing Jt 101 - --f--~ -- 3880 , -.. ~ - - .-- r....- 3890 L::"' 3900 r---' f--. f--- ~ i I 3910 t 7" Casing 1- Jt. 102 I~ I-- 3920 I-- ..... 0., - 3930 ~ - .--- 3940 7" Casing Jt. 103 -!T I 3950 1: ¡ I ~ I I, I fI 2.4 6.4 ---- - - ¡---- ¡---- - - - 1--- 1--- i-- -.- -- - ~._- I-- r-- ~- - ---- - - ~ - 'it 1 - " -- t -.- - 1.- ~- _..m.___ - -- -" - ~._- _. -. 1< - ~ t-- 'ì. ¡-...- ..- .- ~ - - .- - - - -- - --- à - - -... ¡w. -~ ~ MTTP01 (rad) MTTP12 (rad) - ., -...-- ...---- - 12.4 3.6 I I .- -. a KRU 2Va08A 'r ., I I API: 500292112800 Well Type: INJ S: 8446 SUR. CASING SSSV Type: NONE Orla Completion: 9/13/1984 0: 9050 (0-3868, I Annular Fluid: Last W 10 9/14/2006 n: W OVER, NO OD9.625, COMPLETION Wt36.00) ~ Ref Loa Date: Last Update: 9/25/2006 Last 8644 TO: 9050 ftKB Last 4/9/20~~ Max Hole Anale: 53 dea IfìJ 3900 Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 D 103 103 65.00 H-40 SUR CASING 9.625 0 3868 2851 3600 J-55 PROD. CASING 7.000 0 9034 6267 26.00 J-55 I "UJlf!a~"""";" ]()rn"f'f"Iftlll £;;"nf"\I\!\ ow TUBING Size I Top I Bottom I TVD I Wt I Grade I Thread (8267-8542, 3.500 I 8267 I 8542 I 5905 I 9.30 I J-55 I EUE 8rd 00:3.500, 102992) Interval TVD Zone Status Ft SPF Date Type Comment 8446 - 8488 5837 - 5866 C-4,UNIT B 42 12 9/13/1984 IPERF 120 deg phasing; 5 1/2" Csg Gun PKR ~2 5937 - 5956 A-4 26 4 9/13/1984 IPERF 90 dea. phaslna' 4" CSQ Gun (8285-8286, 8678 596f! - ROŒi A-3 50 4 9/13/191\4 IPERF 190 den. nh~~;nn' OD6.151) St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt 2 8325 5753 Cameo KBUG DMY 1.0 BEK 0000 0 9/3/2006 3 8395 5801 Cameo KBUG DMY 1D BEK 0000 0 9/3/2 4 8499 5874 Cameo KBUG PA' :H 1.0 BK 0000 0 <aQUin..at :.l~l"n 1::, !"It' Depth TVD Tvpe Description ID 4000 2930 PLUG 7" RETRIEVEABLE BRIDGE PLUG SET AFTER UPPER PORTION OF OLD 0000 COMPLET ION PULLED 9/14/2006 8285 5725 PKR Cameo 'HRP-1-SP' 2.937 8489 5867 PATCH Set HES permanent patch across GLM @8499' RKB. Top of patch set @ 8489' to 2.375 8511' min. 102.375" 5/18/2000 8518 5888 PKR Baker 'FB-1' 4.000 8535 5900 PLUG TT P set 913/2006 0000 Perf 8535 5900 NIP Cameo '0' NiPPle NO GO. Set 2.75" x 225" "0" profile nipple reducer 5/16/2000 2250 (8446-8488) - 8542 5905 SOS Baker 2.992 --- 8543 )90R TTL 2992 NotèS"' -. - Date Note 12/2/2003 WAIVERED WELL OA x OOA COMMUNICATION 9/14/2006 TOP PORTION OF COMPLETION PULLED - _. PATCH (8489-8511, 00:3.500) PKR (8518-8519, 006.151) PLUG (8535-8536, 002.250) SOS (8542-8543, OD3500) Perf - - (8586-8612) --- f--- - I---- -- --- - -- - = -- Perf - - (8628-8678) -. --- - -- - I--- '- t= I I I I I I I I I I I I I I I I I -. . . WELL LOG TRANSMITTAL 1'1" ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hale/Mechanical Logs and lor Tubing Inspection(Caliper / MTT1 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AI< 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) 1 EDE 2V - OBA Leak Detect - WLD 05-Nov-D6 p,''''''v"'' "Ir~ Ik \:\~Nt:,J ,:",,pf"%. ". \' ,: L).:I C-- I t"{ -oL) I /LldgLj Print Name: f!.~ t~ í/'5IrH ¡(,.o ~IA kR- 1/1 fìR \,! v Signed: D~ on,& Gas Cams, /1.nchcfaiJe PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E..MAIL: ?DSj:\ì\JCr+:,JRAG-=(!Q)iVH=¡\j1C:¡,;(~{LD;3_COjv1 WEBSITE : ~¡ï.Fj\jlj'J.MEMOR'1LOG.':;OM D:\OO _ PDSANC-2006\Z _ W ord\DistributionlTransmittat Sheets\ Transmit_ Original.doc I I I I I I I I I I I I I I I I I I I . . TecWelm cIrls \~--" Final Job Report BP Alaska Prudhoe Bay 11-24A Well Leak Detector (WLD) AUTHORIZATION Name Position Signature Date Prepared By Joel Johns Sales and Marketing 9-15-06 Manager Approved By T odeif Torgersen Customer Care Mgr, 9-18-06 RECEIVED DEC 0 8 2006 ~ 011 & Gas Cons. Commission Anchorage 103 -9D'-( -1/.: ILld~L( I I . . Final Job Report Manufacturer: TeçWeIAS Document no. : IN-WlD200609-146 ~ ,lr3s Revision 0 1 General Information I I I . Well is production well on gas lift. Currently shut in due to pressure build up in IA and failed MITIA 8-20-06, . Tubing is reportedly in communication with inner annulus with a calculated leak rate of. 46 to .37 GPM @ 3000 psi (8-20-06). 2 Objectives The objectives of the operation were: · Identify the location reported TxIA communication. I 3 Results I I I I I I · Prior to logging operations, a WRP was set and the tubing tested to 3000 psi. · The tubing wing valve was reported leaking upon onset of logging operations. · A leak was established by pumping down the IA and attempting to maintain pressure between 2800 and 3000 psi during logging operations. · The leak rate established at the above pressures was approximately 0.36 gallons per minute. · Eight leak signatures were located at the depth shown on the chart below. · The shape and amplitude of these leak signatures are consistent with those typically seen with casing leaks. The passing MIT on the tubing would tend to support their analysis as casing leaks. · The casing tally and a CBL have in an effort to correlate the slick line depths with the casing depths. It was found that the position of most of the leaks is consistent with casing joint locations, The following chart shows the SL leak depths and corresponding tool joint depths as correlated from the casing tally and CBL. It can be seen from the chart trend that the leak points very likely line up with casing joints. I Leak MD of joint (Casing SL MD joint SL # SL Leak Depth Talley) Correction Req'd (7/14/86 CBL) Correction Req'd 1 4054 4031,08 -22.92 4034 -20 2 5572 5583,9 -11,9 5586 -14 3 5866 5876.73 -10,73 5879 -13 4 6516 6524.74 -8.74 6527 -11 5 6638 6647.53 -9.53 6650 -12 6 6680 6689.35 -9,35 6692 -12 7 6720 6729,92 -9,92 6732 -12 8 6848 6855.46 -7.46 6858 -10 I I I I I · There were some minor, albeit inconclusive, temperature fluctuations on leaks 1-4. In order to fully confIrm the direction of the leaks further diagnosis could be performed. A logging pass with the tubing and casingjumpered and pressurized would confmn the locations of the casing leaks. A logging pass with the tubing pressurized and no pressure on the annulus would further confmn the integrity of the tubing, · Page 2 of 11 8-28-06 I Final Job Report I Manufacturer: TecWel AS Document no. : IN-WLD200609-146 Revision 0 I 4 Appen.dices 4.1 Log - Leak Point #1 @ 4054' MD I I I I I I I I I I I I I I I Page 3 of 11 8-28-06 I Final Job Report Manufacturer: TecWeI AS Document no. : IN-WLD200609-146 Revision 0 4.2 Log - Leak Point #2 @ 5572' MD I I I I I I I I I I I I Page 4 of 11 8-28-06 I 2000 o 30 CCl Line (fUmin) TEMP -200 -100 230 AlDA AlOB AlOC TEM P (degF) 50000 50000 50000 129 1 I I Final Job Report Manufacturer: TecWel AS Document no. : IN-WLD200609-146 Revision 0 I 4.3 Log - Leak Point #3 @ 5866' MD I I I I I I I I I I I I I I I I Differential Temperaturè 5900 leaks ALDA ALOB ALOC 119 -3 Page 5 of 11 8-28-06 4.4 Log - Leak Points #4 @6516' MD, #5 @ 6638' MD, #6 @ 6680' MD & #7 @ 6720' MD. I I I I I I I I I I I I I I I I I I I Final Report Manufacturer: TecWeI AS Document no. : IN-WLD200609-146 - Revision 0 Page 6 of 11 8-28-06 I I I I I I I I I I I I I I I I I I I - Final Job Report Manufacturer: TecWe! AS Document no. ' IN-WLD200609-146 Revision 0 4.5 Log - Leak Point #8 @ 6848' MD. f , :<:;r""" (} -3 Page 7 of 11 Possibfe Leak Differential Temperature ALDC Temperature (degF) Differential T¡¡¡m¡:HU¡;¡tyre 8-28-06 I . Final Job Report Manufacturer: TecWeI AS Document no, : IN-VVLD200609-146 I 4.2 Completion Schematic I tr:Œ·.. -I-IM.- aN , 1JoIot:a:r. IIISt NO :Þi'P :,r.¡a (¡Till': ~1'" r"'M1~ I ,..r.11,m:- ra nr, . pit I:lr, - ror-- ~Þ"'- p¡ur NJ- 1' Jj.. I 1...._wr(:'IQ T)<# LoM ID- 1.1':...,- H 2'~!' I Minm1U1Ti ID" 3}2S' @ 81{)6' 41.'2' OnSXN NIPPLE I ~r.:o r œ:r:IHC I-a-, D- (,1M'" I ~:·,d\"(:'IQ...... toM c.-r,MI" I I -!-liI'" 11IGI I'>'" 1:'<",. "'1:\1' qw ID-:."....... ;S;'i" I I r:.ITLOO ÞW:-;.,:.co,clOO.,..,· M 11'60.; Þ"at"T Ta'1V".... .T, oA fo.1our ".... r:.MBII>I'\'hb"J.....ca fir ....~ " :q fo.1010· fo.1ol.'i fo.1ol.'· fo.1ol:fl fo.1o:.... fo.1o:.... ~...."'. ?2f(, :e.x~. :r..;-m ¡o,j ".?".."11 ,r.,j1' '\. ,r.,.""., :fI."/i!iI·~I(! 411.. I ~.7.(l" ;- .t.-:.xr 1', :p.~~.{(' t~ o o œ,n.,«, IId4.\1i\ (! I. i'NtII œ,I\'oM (tt.~ /llii'Ntll ......~ ......~ I ."r-:.'r( + :...:''ö- t. ~·~"'...tr ,. :~.À·~· t. o o o o :r:.(t ... I . I!mmI Jris Revision 0 11-24A ~A.I"CT"f !ooòO'ID,' ...Ior C.-II: TBG..& r C..-I ..... .211'!' +-1&7" QNCO ~ 1J:.,J"'i:'5'jiJ' Eo. :.t.IT 'ß>;";'iLOClmOl.T I~M, . t' >: "'IXI M:¡.. ?, ~ Dlr r~ " 0001./'M ~-- - ! .. fû'!t¡ tlU! './'(, ~ Dlr r~ ( M.I')'of! , + fiTI\', t¿;}1' .l'T ~ Dlr r~ (! M'>:)'of! , :'i T:~ TMI µ ~ Dlr r~ !'! M>:)'of! , to 1'tß! T.I'tI) >.\ ~ Dlr rot: " M>:)'of! , ~11' ~ )~ ~ Dlr "I( ( M2)'of! , (I íIUì ffiII'¡ j') ....... Dlr 1'1; ÍI .....OCiWl M.(('(:'IQ ...OI.T W'tCQN (¡X~~J' ..(,,"j)(( 1-~~--"lj I UlI!,f ~I,.ronD¡I>S',D-,''''I·'·1 I :aee'l H:-:o -I-1.71J(r::....DL"jn;r. D- :.':;1- I :a.t I'.rom:o 1>1" ID -:¡ (¡I."- ~·---~'"i :a7IJE!' ~I'.rom :0........ D- :¡T./:S" I ~ 1St H+-leT TUJI'Ð TÞI. '^"-I:M I ;fJ'12' HI1M:>TTtOQGC:on.¡,~ I 1"1:" II'r :- u-.r;. »II t:,..;:4M.\ I\'TII'fr( CoOlllG>T7 R'U]i>ocD...... '-I~ YoUL 11,,/'.1,,10 R:RoIT M lío.....x...-. ..F1I>.. !itHI.'!:o-JII\.I':.·( 1 ...0::.... TII"'!':III: .l'lrr...LoI. Ir.... I'D. 0.> 11: OI.OtAT ~T''i '*'- cOlI ¡J u:r1Olol 0'11: r.r'D"r OllMïOf, [4"1:¡11.1( I=D'I":',; I . I ,,:.IW'.lIJ' (I"''' CR"·£crø·,';~ i'i y~ I ".. _ __ i ~ OOoI.1'o'(W', 1t1.J';'c (&',(.0 !It._ .i',~1 fIPI..I'..'ß'. ',ç.( 'i 00 I I I II' CIp.ar_" ,.....t;¡: Page 8 of 11 8-28-06 I . . I Final Job Report Manufacturer: TecWeI AS Document no, : IN-WlD200609-146 I:m'ZlD ,Iris Revision 0 4.3 Event Log I mmm 1.... WEll $. ,,-Oi~»"<'-; .; t ... ~ ~Di.......~ìl[~I" Evønt Log I I Customer: BP Exploration(Alaska}, Inc. Field: Prudhoe Well: 11-24 Date fltlll ...... ....... I 10-Sep-06 04:00:00 04:15:00 05:25:00 07:11 :30 07:20:00 07:30:00 08:05:00 09:55:00 11:30:00 Depart for Location Arrive Location Verified leak @ _36 GPM Connect Battery Make up Lubricator PT LUB RIH to above Plug, Set in "XN" @ 8706 Prong found @ 8680' SLM logging out Looks like the Wing is still leaking (per AWGRS) will watch pressure on "S" riser I I I 17:15:00 in Lubricator I I I I I I I I I Page 9 of 11 8-28-06 I I . . I Final Job Report Manufacturer: TecVVeI AS Document no, : IN-WLD2006 09-146 ~Jr3s. Revision 0 4.4 Pressure Log I I Il'mD :."... w,,, s... ~.~ PreSSll'B LOU ¿ ~ P,"",'", "'~rio:."'''""" Customer: BP Explondion(Alaska), Inc. Field: Prudhoe well: 11-24 IIatII r_ .. -- -- WIT -. 22-Jul-06 5:40 0 3000 60 Just press'd up to verify leak 5:55 100 2800 60 .72 GPM leak 6:10 100 2700 60 .36 GPM leak 6:25 100 2600 60 .36 GPM leak 6:30 0 850 0 Bled oil to RIH 9:25 140 3000 100 Pressurized to 3000 9:40 140 2860 100 .49 GPM Leak Rate 9:55 t40 2780 100 .285 GPM Leak Rate 10:10 140 2680 100 .36 GPM leak 10:25 140 2600 100 .285 GPM Leak Rate 10AO 140 2520 100 .285 GPM Leak Rate 10:43 120 3000 100 Repressurized to 3000 10:58 100 2900 100 .36 GPM leak 11:13 100 2800 100 .36 GPM leak 11:28 100 2700 100 .36 GPM leak 11:43 100 2600 100 .36 GPM leak 11:58 100 2500 100 .36 GPM leak 12:01 tOo 3000 100 Repressurized to 3000 12:16 100 2900 100 .36 GPM leak 12:31 100 2800 100 .36 GPM leak 12:46 100 2700 100 .36 GPM leak 13:01 100 2600 100 .36 GPM leak 13:16 100 2520 100 .285 GPM Leak Rate 13:18 100 3000 100 Repressurized to 3000 13:33 100 2900 100 .36 GPM leak 13:48 100 2800 100 .36 GPM leak 14:03 100 2700 100 .36 GPM leak 14:18 100 2600 100 .36 GPM leak 14:33 60 2540 100 .214 GPMLeak 14:35 60 3000 100 Repressurized to 3000 14:50 60 2900 100 .36 GPM leak 15:05 60 2800 100 .36 GPM leak 15:20 60 2740 tOO .214 GPM Leak 15:35 60 2640 100 .36 GPM leak 15:50 60 2570 100 .251 GPM Leak 15:53 60 3000 100 Repressurized to 3000 16:08 60 2900 100 .36 GPM leak 16:23 60 2820 100 .28 GPM Leak 16:38 60 2760 100 0.214 16:53 60 2660 100 .36 GPM 17:08 60 2580 100 .28 GPM Leak 17:15 Done Logging I I I I I I I I I I I I I I Page 10 of 11 8-28-06 I I . I Final Job Report Manufacturer: TecWeI AS Document no, : IN-WLD200609-146 I 4.5 Tool Schematic I "':11~JI C{f~1 <I:. SLOG 17 s.: ·5.,,<i<;.l-e~. 17=2 I I s.....,_ 14,::'! I I I I I TEI.I;> ,; ;:" ~I I (:[:1 :; 1; I I ",.c... ':'.C6 ( ~: ( D-:, (' rt"· e ¡;: ,',I n;, ·...LDO I "A":J,.r Ç^I"':~ f.¡:,r ¡': It' ..UTTFt.I:> (; (t: U\,'TCURR ( Co: I I I I :::':r~m:b: II o n... ,,'... , r..,,,, ,,,..:1'11 r III"Ì .·...;'tl CD Revision 0 [}:;',,:I-=bJfI :4J:= ,S':U,I(" I:-~.:" C:.:-"-nÛ':t t ,}4- -:'(2=-i,_~JìIH '-:'f~~i'Jt. Atr~;'_',Jhi 1J''''~ XUI,.~-.~\t S:-,Ot).) 8.:1: L n~ (:1I,1-';;~)Ìlt:'"~ .~. ~: t' - :;,: ;;,/;'1'. "I,'! >.~ :'.ù . ImmIJds L,~:th ;)I),'m ", it:,:_ ) 1) , i'~ !X 1 g~ 115 "5 -::(J (I ~J".ï , 50 !}I,; :;t4..U):'" I(J~..~., :",ó,:rì II.. i<rl,".~,. .I'"'' ,I io7 r ) ,~: 1;:;(1 rt ·:£1;,..1"" ¡ÙM;!d. _".., 11,1' c.ç :¡ IF 3.'1,-X I :1(OD1 t.PL t.i;:ltw. !!.ït\:; ',' _UT·CI"~ í21':~"'''', 1.1t .......i U'¡II'~" . ::-;4 ',' :~lr, (:,t.frJl' 'J4~ <~~.! 19~': t;v:.;, 4 iI.r__f .,~,_ ,h""~ ~.''¡¡I ,'.,> THP I))J 121:;;:; Ie> D~'.:¡ "i!" t..''''t,H: ~> 'I,_I,".·'!,,-':.I !-tft~,to..~; :CL,IJ) 11 J::.Q3D9. C..m111':c[dl ",r ." q,....... :c:t.rr4c~:-4Ï1 .:r: ~ 1~-1 ~C;ì_ "":',.f'\'; ~,...,;hli;.:H" '.11-: 'J,;:'. ....., '"'ì~~.-;, :1"¡J ~ ~~': T ...'t.-',LJ lUj"n:~h ,,-:¡,~..-:¡;:::~;,,¡¡;~.;-~ 3UL,XOXGX,! Elíl FltI!; f,,"t'~"'''''''"_I'.:I._ ',_,:t",_',d:1 17 !If; n A;. ";";'J Ih 175 ¡II Page 11 of 11 1!;(J 1':;" 1 G!'I ;'! ,:a: ~~::; H!'I ,ae," ;:: .. t 12,~fj II;J!;I I CL 1 (:9 I.EC I '.!L I (;9 !:IX ~-- .... t I C9 12 :G i r,... j ;:.(. ;¡ ;:1' ) J[I 1 .:;!'I ! "-C 8-28-06 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 r, ~: t: oj: 1) 2) 3) 4) 5) 6) 7) 1 BL / EDE Disk 2V - 08 Leak Detect - WLD 140ct-06 Print Name: {' JL alA (;5.{-¡ lAP /V[,o.J/1/A V?)AA Signed: u J-C- 1'7s1.../-091 tt ,L/8':JO PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATlONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E..MAIL: ;"'J;5A:·,j:;;:~jO?y!:,GEa·D¡11E::J10R-'/L0i3.-:>~)¡~;¡ WEBSITE: <'i\i]\P4'i.;vìE:iJG:F:'.'YLDG.';~¡V¡ 0:\00_ PDSA1'1C-2006\Z _ W ordlDistributionlTransmlttal. SheetsITransnut,Onginal.doc 10/13/06 Seh_bergep OCT 1 () 2006 ;~!Ba Oil & (~as Gum~. Cqlffl~~W7 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth §ÇA~I~i.~!I). ~'~J\1.....~J '1$.. <'ì 2finrc e:Ji ..1,·1,....., ~ 4 ·VljU Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 U.T Q IÝJ~/- Cf7 ( Field: Kuparuk Well CD Job# Log Description Date BL Color 1J-127 11404957 PROD PROFILE W/DEFT 09/14/06 1 2W-10 11404958 INJECTION PROFILE 09/15/06 1 2W-14 11404960 INJECTION PROFILE 09/17/06 1 2U-01 11404964 PROD PROFILE W/DEFT 09/20/06 1 2A-19A 11415618 PROD PROFILE W/DEFT 09/03/06 1 1E-04 11421627 INJECTION PROFILE 09/13/06 1 2W-02 11296718 INJECTION PROFILE 09/14/06 1 3H-10B 11296723 PATCH/STATIC SURVEY 09/19/06 1 2T-39 11296724 PROD PROFILE W/DEFT 09/20/06 1 1 L-04 11415626 SBHP SURVEY 09/24/06 1 2V-04 11415628 INJECTION PROFILE 09/26/06 1 1A-17 11415622 PROD PROFILE W/DEFT 09/21/06 1 1 L-06 11415625 SBHP SURVEY 09/24/06 1 1 F-07 11415629 LDL 09/27/06 1 2F-06 11434750 FLOWING BHP SURVEY 10/03/06 1 2A-17 11434751 PROD PROFILE W/DEFT 10/04/06 1 2P-447 11404966 INJECTION PROFILE 10/06/06 1 2V-08A 11216327 USIT 09/21/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Re: 2V-08A (PTD 184-091) . . MJ, Your request is appropriate given the wo k in progress. Tom Maunder, PE AOGCC NSK Well Integrity Proj wrote, On 10/3 0066:25 AM: Tom, Injection well 2V-08A (PTD 184-091) h d the tubing pulled and casing plugs set mid September during the first steps of several in the r pair plan approved in Sundry # 306-301. Since the tubing has been removed and the reservoir is isolated with a casing plug the TIIIO data has very little value. Therefore ConocoPhillips req est approval to remove 2V-08A PTD (184-091) from the monthly failed MIT report beginning wit the October report. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 9 ,,'.~ l' ".".- 1 of! 10/3/20068:29 AM RJ:::: 1 V -U~A Subject: RE: 2V -08A From: "Gober, Howard" <Howard.Gober@conocophillips.com> Date: Fri, 08 Sep 2006 17:12:38 -0800 To: Thomas Maunder <tom _ maunder@admin.state.ak:.us> Thanks Tom. I appreciate your help. I promise that requesting a quick turn around like this will NOT be the norm. Thanks, \'6~-a<\\ SCANNED SEP 1 3 2006 Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell !i~~~9.:Eª-=-º-?þ~~~~~.?g_~~~.Ebl-} 1 :h.£~_~om -----Original Message----- From: Thomas Maunder [mailto:tom Sent: Friday, September 08, 2006 To: Gober, Howard Subject: 2V-08A maunder@admin.state.ak.us] 5:08 PM Howard, I have reviewed your sundry application and forward up front for approval. On that basis, you have "verbal" approval to proceed. Tom Maunder, PE AOGCC 1 of I 9/12/2006 9: 12 AM '~-- ~- '""""-" ".~-, ., -"-'-) -.....:...Î í :::-_J 0". ""- , -="'-"' '." '_:..:.' . J -_.,~-, .;':.1 _-=-_~~ .__~- .=~ FRANK H. MURKOWSKI, GOVERNOR ~. A.,ASKA. ORAND GAS CONSERVATION COltDlISSION 333 W. rH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 \%4-0q Re: Kuparuk River Field, Kuparuk Oil Pool, 2V-08A Sundry Number: 306-301 SCANNED SEP 132005 Dear Mr. Gober: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, J ". N Chairm DATED this <t day of September, 2006 Encl. 7Ióf-6.. .J;,.. RECEIVED STATE OF ALASKA --' c;., ß" ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 0 6 2006 APPLICATION FOR SUNDRY APPROVAlIaska Oil & Gas Cons. Commission 20 MC 25.280 Anchoraoe o - Time Extension 0 Re-enter Suspended Well 0 1. Type of Request: o o o Pull Tubing Abandon Suspend Alter casing Repair well Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: "" Y .J o o o Operational Shutdown Perforate o o Perforate New Pool o o o Stimulate Plug Perforations 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory D Service 0 P. O. Box 100360, Anchorage, Alaska 99510 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes D 9. Property Designation: Kuparuk River Unit AO ~ l~'S-> ~'î.1.oC. 12. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 9050' 6279' 8644' Casing Length Size CONDUCTOR 80' 16" SUR. CASING 3755' 9-5/8" PROD. CASING 8921' 7" Perforation Depth MD (ft): 8446'-8488',8586'-8612',8628'-8678' pkr= CAMCO 'HRP-1-SP'; BAKER 'FB-1' Otis FMX TR 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch 0 15. Estimated Date for September 15, 2006 Date: Signature Waiver Other D 5. Permit to Drill Number: 184-091 6. API Number: 50-029-21128-00 ' 8. Well Name and Number: No 0 - 2V-08A 10. KB Elevation (ft): 11. Field/Pool(s): RKB 113' Kuparuk River Field / Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): MD TVD 103' 103' 3868' 2851' 9034' 6267' Tubing Size: 3-1/2" Contact: Title: Phone 263-4220 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Perforation Depth TVD (ft): 5837'-5866', 5937'-5956', 5968'-6005' Packers and SSSV MD (ft) pkr= 8285'; 8518' SSSV= 1943' 14. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D Commencing Operations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Howard Gober -'~ Plug Integrity D BOP Test '~ Location Clearance D Mechanical Integrity Test D Other: ~()O 0 ~.~, ßOY~S ~ "-."> ~\~.-eJ Approved by: Form 10-403 Revised 06/2006 Subsequent Form Required: '-\ \) ~ Burst Collapse Tubing Grade: J-55 Tubing MD (ft): 8542' Service 0 . Plugged D WINJ 0 Abandoned D WDSPL 0 Howard Gober Wells Engineer Date q/~/Oú:> Sundry Number: ertø '-, 'xJ l R:ßrD[Y0 1 g () b ~~ D~:~!/~~~ nM~/lIÐ'ßTONER L11 APPROVED BY THE COMMISSION ~...I!!:I!!!!P" -" RECEIVED Sfp 0 G Alaska 0:' 2006 " & Ga sCans. C . Anchorage Dn7rn;ssion ConocJ'Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 5, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2V-08A (PTD 184-091). 2V-08A was completed in September of 1984. A surface casing repair was attempted in July of 2005, but the repair could not be completed due to deformed and split casing. It was reported to the AOGCC that small amounts of fluid were leaking to a catch drum via the conductor downspout which was installed 8/24/05. Since the suspected source of the fluid is the West Sak or Ugnu sand, the outer annulus needs to be isolated from these formations. The purpose of the proposed workover will be to prep the well for a cement squeeze on the outer annulus. The tubing will be removed and a 7" retrievable bridge plug will be set below the surface casing shoe. The wellbore will be loaded with fluid of sufficient density to balance reservoir pressure. After the rig leaves location, coiled tubing will be used to squeeze cement into the outer annulus. Prior to the squeeze work, we will excavate the surface casing and patch the known split with a low pressure patch. A separate Application for Sundry Approval will be submitted when we are ready to do a workover in order to put the well back on injection. If you have any questions or require any further information, please contact me at 263-4220. Sincerely, ~ Howard B. Gober Wells Engineer CPAI Drilling and Wells - "~ Kuparuk 2V-08A General Workover Procedure Pre-riQ Work DHD: 1. POT and PPPOT tubing and 7" casing packoffs. Function test lock down screws. Slickline: 2. Tag fill. Obtain SBHP at 8632' RKB and gradient stop at 8495' RKB. 3. Pull CV's in mandrels at 8325' RKB and 8395' RKB and replace with DV's. 4. Set tubing tail plug in 2.25' D nipple at 8535' RKB. Pressure test tubing to 2000 psi and bleed down tubing pressure to 0 psi to ensure plug is holding. Dump bail 5' calcium carbonate on top of plug. 5. If plug does not hold pressure, pull plug. Set WRP at +/-8308' RKB. Pressure test tubing to 2000 psi and bleed down tubing pressure to 0 psi to ensure plug is holding. Dump bail 5' calcium carbonate on top of plug. 6. Pull DV at 8227' RKB and leave an open pocket. 7. Load well with 9.6 ppg brine. E-Line: 8. Shoot string shot and chemical cut 3-1/2" J-55 tubing at 8251' RKB in the middle of the first full joint above the Camco OEJ. DHD: 9. Load OA with 12.0 ppg brine. Valve Shop: 10. Set 3" Gray BPV within 24 hrs of MIRU. General Workover Procedure 1. MIRU Nabors 3S. 2. NO Tree, MU Gray test dart, NU 7-1/16" 5K full open valve. NU 13-5/8" 5K BOPE. MASP=1250 psi based on maximum observed shut-in tubing pressure in June of 2006. 3. Test the BOPE to 250/3000 psi (annular to 250/2500 psi). 4. Pull test dart. Pull BPV. 5. Load hole with kill weight fluid using pre-rig shut-in bottom hole pressure. Fluid density will be calculated planning for 9.6 ppg brine to 3300' MD (2500' TVD) at end of workover. 6. Pull tbg to chemical cut. Stand back 4000' tubing. Lay down remainder. 7. RIH and set retrievable bridge plug at +/- 4000' RKB. Test casing to 2500 psi. 8. Pull up to 3300' RKB laying down tubing. ·~v'"'~~ Co.-~'\~ 50 ~~ Q ~~JJ ~?J1f "-' 9. Circulate 9.6 ppg brine into the well for freeze protection. 10. POOH laying down tubing. 11. Close 7-1/16" valve. ND BOPE. NU Tree cap. Pressure test 7" valve and tree cap to 2500 psi. Note: Hanger will not be set in wellhead. Full access to the 7" casing will be required to perform the outer annulus casing squeeze. 12. RDMO Nabors 3S. Post-Riq Work: Slickline: 1. Tag retrievable bridge plug. Dump bail sand on top. E-Line: 2. Run USIT log. DHD: 3. Excavate down -10'. 4. Remove conductor. Patch known split in surface casing. 5. Pressure test patch to -50psi. E-Line: 6. Perforate 7" casing. 7. Pump down 7" casing to ensure squeeze holes are open. 8. Set cement retainer above squeeze holes. CTU: 9. Circulate cement through cement retainer into 7" x 9-5/8" outer annulus. E-Line: 10. Run USIT log to verify cement quality. 11. Monitor OA for flow. 12'_7~11 i " ¡ \ ì ¡ í ! ¡ i I I , 4'···.~" I I , f J'-Ok" ~ t 1'-1 W' t 1 J'-·or t ---'---- ~-_._._"---.-._-------- ~-- ,~ 2-1/16"#5000 / HCR VALVE (;), (----'-) ~ I ) ]" #f)OOC II r I JICR VAL V[ -~ ~ _ _ BLIND RAMS ".~Q_ J I' 3-1/8~ CHOKE y ~ ~ ~ I I ~ '1 5 DO ~~...,.,_. I. I '.. "''''._~~~ J. ¡. 0 S·,·,-,,· ... _._.,..PIPE."..RAMS,,-,. "...... ....... GA FE VAL'VE tL-- r- I'..L.......,.......__.L·1 .. " -'J"x2" DSA NABORS ALASKA RIG 35 13-51S·BLOW-OUT PREVENTOR 2 RAM STACK CONFIGURATION --- -- i' KILL UNE GATE VALVE 1 j 5/B" 5000# VIP i-iYDRiL, TYPE nGKI! r 3 5/8" 5000# WP LATCHED TOP BY 13 5/8" FLANGfD BOTTOM AN,'~'ULÞR BOP 54 1/2" LENGTli HYDNlL 13-5/8" 5k PSI HYDRAULIC RAM SiNGLE GATE FUWGED CONNECTION 36 1/ 4fJ LENGTH 13-5/8" 5000# API FLANGED MUD Ct~OSS HYDRIL rJ-·5/8" 5k PSI HYDI?AUUC r?AM SiNGLE GATE FLANGED CONNEC1ïON .36 1/4 fJ LfNGTI--l ( ~.~~.~,~_~.¡rr__1 ...M:Dan....... =~ç"==~~' .. .__'- ...._.. _ fOlU..2Ü'1 \1b1.~~..1f ('Q 1wMl~ Nl/lYJlfi ~S,l'A lfKiJS \iIìI 1"'..'/$' IMW··(xIf ~Mf{1(1I .2 /I;W s:r,lt;1( m.l'"I\.1'I.dI¡IW~ :~M.œ'!·.1 ~.¡,. !v~ Status of 2 V -08A sundry --- '~ Subject: Status of 2V -08A sundry From: "Allsup-Drake, Sharon K" <Sharon.K.Allsup-Drake@conocophillips.com> Date: Thu, 07 Sep 2006 15:02:25 -0800 To: jody _ colombie@admin.state.ak.us Jody - can you tell me the status of 2V-08A sundry? We will be moving the rig to this well tomorrow and need the sundry soon. Thanks, Sharon office phone: 263-4612 fax: 265-6224 I of I 9/8/20068:41 AM - '---- From: NSK Problem Well Supv <n1617@conocophil1ips.conl> Date: Mon, 12 lun 2006 12:58:29 -0800 T.o:Thomas Maunder <toffijUaunder@admin.state.ak:.us>, James Regg· <jim,"""""regg@admin.state.ak.us> CC:NSK Well Integrity Proj <N1878@conocophillips.com>, NSK Problem Well Supv <n1617@conocophillips.com> Tom,& Jim 2V-08a (PTO 184-091) is leaking small amounts of fluid to a catch drum via the conductor downspout which was installed 08/24/05. Initially it was assumed that shallow gas from decaying organic matter was entering the conductor causing it to occasionally product fluid to the catch drum. The well was SII 10103/05 in an attempt to refreeze the thaw bulb around the well bore and minimize biological activity. 2V-08a has continued to leak fluid to the catch drum since being shut in. Samples of the conductor fluid analyzed by Gas Chromatograph have a fingerprint similar to West Sak crude. The well is suspect of leaking formation fluid up the OA via an open shoe or some deep leak in the surface casing whereas the fluid exits the split casing to the OOA and is expelled to the conductor catch drum. On 06/11/06 the OA was loaded with 12.0 ppg viscosified solids free brine. The well is being observed daily by day and night operators. The T/I/O is 125010/1. Tubing and IA pressures have been stable since being shut in. No MITIA is planed at this point. Immediate plans are to monitor and retreat as necessary with weighted brine to prevent production of fluid to the conductor catch drum. A work over plan is being developed. Sincerely, Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 ~~~\~ o\>~'" ~-.j\;j,\\~~ c..ù\-~ ?0 \ \ '\ l \.~w~'-.JCLr- dc.\¡"'D-~ ~ s.ò\~c:..<:>~QJ~ùM~ ho...S ~~(¡~~ ~<-,~ç-cù~ ~'~ I",~\~~V'-.~ \fé~~'\'-~~C~\~I( a-'J \<:> i'^QD<.: ~~~t--\'-\~V\ r "'-.) « "> c.~",c o.t I..:) 'J "'-0 ) ~co\--~'-Lk"'H) ~~I;'tG.\t,\ JCü<Ytvl ~/'~L~ I of 1 kJ\c, \f'-~ ~\,ê 9/8/2006 8:54 AM c~_ -' KRU 2V-08A API: 500292112800 SSSV Type: TRDP Well Type: INJ Orig 9/13/1984 Completion: Last W/O: Ref Log Date: TD: 9050 ftKB Angle @ TS: 45 deg @ 8446 Angle @ TD: 42 deg @ 9050 sssv (1943-1944, 00:3.5(0) Annular Fluid: Reference Log: Last Tag: 8644 Last Date: 4/9/2005 Casing Description CONDUCTOR SUR. CASING PROD. CASING Tubing Size 3.500 0 Perforations Summary Interval TVD 8446 - 8488 5837 - 5866 Rev Reason: PULL PLUG Last Update: 8/29/2005 Max Gas Lift 3ndrelIDummy Val\Æ! 1 (8227-8228, 00:5.780) Size 16.000 9.625 TVD 103 2851 Wt Grade 65.00 H-40 36.00 J-55 SBR (8267-8268, 00:3.5(0) Zone Status Ft SPF Date Type Comment C-4,UNIT 42 12 9/13/1984 IPERF 120 deg. phasing; 5 1/2" B Csg Gun A-4 26 4 9/13/1984 IPERF 90 deg. phasing; 4" Csg Gun A-3 50 4 9/13/1984 IPERF 90 deg. phasing; 4" Csg Gun PKR (8285-8286, 00:6.151) 8586 - 8612 5937 - 5956 8628 - 8678 5968 - 6005 Gas Lift MandrelsNalves St MD TVD Man Man Type Mfr 1 8227 5686 Otis Injection St MD TVD Injection MandrelNal\Æ! 2 (8325-8326, V Mfr V Type DMY V OD Latch Port TRO Date Run Vlv Cmnt RO-5 LBX 1.5 Man Type V Mfr V OD Latch Man Mfr Cameo Camco Type DPHFCV DPHFCV PATCH Vlv Cmnt Injection MandrelNalve 3 (8395-8396, 2 8325 3 8395 4 8499 Other Depth 1943 8267 8285 8489 KBUG KBUG 1.0 1.0 1.0 BEK BEK BK 0.000 0.000 0.000 o o o Perf (8446-8488) TUBING (0-8542, 00:3.500, 10:2.992) Description Otis 'FMX TR' (LOCKED OUT 4/23/89) Cameo 'OEJ-1 0' Camco 'HRP-1-SP' Set HES permanent patch across GLM @8499' RKB. Top of patch set @ 8489' to 8511'; min. ID 2.375" 5/18/2000 Baker 'FB-1' Camco 'D' Nipple NO GO. Set 2.75" x 2.25" "D" profile nipple reducer 5/16/2000 Baker 2.813 2.937 2.937 2.375 SBR PKR PATCH 8518 5888 8535 5900 8542 5905 PATCH 8543 5906 (8489-8511, 00:3.5(0) PKR NIP 4.000 2.250 SOS TTL 2.992 Note WAIVERED WELL: OA x OOA COMMUNICATION PKR (8518-8519, 00:6.151) NIP (8535-8536, 00:3.5(0) 11'>-.11 SOS (8542-8543, 00:3.5(0) /~:,r,:4::.;i>:it +~*;f;~;W/;' Perf (8586-8612) - ---.- Perf (8628-8678) 10/07/05 Schlumberger NO. 3492 Schlumberger -DCS 2525 Gambell Street, Suite 400 5CANNEC NOV {) 2 2005 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 AUn: Helen Warman A TTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~ Well Job# Log Description Date BL Color CD 3M-07 11015737 INJECTION PROFILE 09/26/05 1 1 E-18 11015745 GLS SURVEY 10/02/05 1 1 Q-22 11015744 PRODUCTION PROFILE 10/01/05 1 1G-08A 11072911 PRODUCTION PROFILE 10/01/05 1 1G-10A 11072910 PRODUCTION PROFILE 09/30/05 1 2C-04 11072907 INJECTION PROFILE 09/27/05 1 2D-05 11072909 INJECTION PROFILE 09/29/05 1 2P-429 11056695 INJECTION PROFILE 09/18/05 1 2N-306 11056696 INJECTION PROFILE 09/19/05 1 1 D-122 11015730 INJECTION PROFILE 09/06/05 1 1 C-111 11015732 INJECTION PROFILE 09/22/05 1 1 D-114 11015728 INJECTION PROFILE 09/04/05 1 2V -08A 11072913 INJECTION PROFILE 10/03/05 1 3M-01 (REDO) 11015736 INJECTION PROFILE 09/25/05 1 31-04 10092325 PRODUCTION PROFILE 10/02/05 1 1 E-1 05 11015726 TEMPERATURE SURVEY 09/02/05 1 _.r SIGNED: lL.l riU DATE: / 7 (\)~ Akt r- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. f 8 '-f-- ~ffl f=': (." Jul 18 05 06:03p Kuparuk Environmental [9071 659-7712 p.2 • r_SP_Discharge Printed: 07/17/200 Page: l ~~~' "`~ J~ ~~~~~~ ConocoPhillips Alaska, tnc. Final Agency Report LOCATION OF DISCHARGE; CPF2 ADDITIONAL LOCATION INFO. DS-2V - Well ar8A TIME OBSERVED: 8:00:00 AM 0I/16/1995 CortiocoPhittips .clukt Ina ~~~~ Y ~'~~ REPORTED BY: BARB BYRNE u J~- " • TO: ADEC: ADEC ADNR: ADEC . _~ '~i' NSB: Ralph Davis Other; AOGCC ~'~'~~ Rf:SPONSIBLE GROUP: ARCO ALASKA INC. TYPE AND A'~IOU;~1'1°: 200.0 Total Ga[lon(s) 0.0 Gallon(s) Unto Tundra, covering 0.0 area { (~ (-„{ ~ ®~ 0.0 Gallon(s) into Water, covering 0.0 az•ea v 0.0 Gallon(s) Inside Secondary Containment U.0 Gallon(s) Into Building 100 % CRUDE CAUSE OF DISCHARGE: CORROSION/EROSION l/16/95-Communication between 9-5/8" surface casine and l6" conductor ~~ pipe, which is mast likely the result of drill pipe wear on the 9-5/$" ~~ ~~ 5 `ice b~ ~j'~ casing. Converting the welt from a seawater (60 degreeF} to produced water (140 degreeF} injector, increased the temperature and expanded the ~~ thaw bulb around the welt bore, resulting in fluid and gas seepage from the 16" casing. 6!8!05-Additional contamination was encountered while repairing a surface casing leak. ADEC; ADNR, NSB and AOGCC were notified. Further investigation revealed that the surface casing had pressure damage, extending down at least 30' from the surface. ENVIRONMENTAL DA1viAGE: ~ ~~ n~ ~V~`O ~ C ~-V 1` V`7CeS~lV~~p`VtCCJ ®~t(~~ CLEANUP ACTIONS: 1/I6/9~-The crude aad°eil cellar gravel was vacuumed out of the cellar to a depth of approximately 2 feet. Area in cellar steam cleaned. Following cleanup activity, an impermeable pit Iincr was installed in the cellar to collect any future liquid seepage or drips. 6!8/OS-As a result of the discovery on 6/8/0, well cellar was removed and hole around well excavated to 25' deep to conduct futrther diagnostics. Backhoe and Supersuckers removed 258 cy of contaminated gravel and [30 bhls of freshwater from 7/4-7110/05. Fluids were recycled and gravel was sent to GBcI in Prudhoe. Sampling was conducted 7/10-7/l 1/O5. Results show that the area is clean. CLEANUP VERIFICATION: VISUAL ~~ ~ _ ` ~~ v~J~ \\\ CCCJJJ AMOUNT OF SPILL RECOVERED: l00% PREVENTIVE ACTION: Repaired canductor casing with welded patch, installed 3' circulating nipple below- Tanko-Head on the conductor, and received approval from AOGCC to operate well in water injection service. DISPOSAL/RECYCLE LOCATION: DS-4 (GRIND & INJECT) Liquids went to CPF-i water recycle facility. Re: 2V-08A (PTD 184-091 / Sundry 305-121) ( ( Subject: Re: 2V-08A (PTD 184-091 / Sundry 305-121) From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 14 Jul2005 12:29:18 -0800 To: NSK Problem Well Supv <nI617@conocophillips.com> CC: "Mooney, M" <M.Mooney@conocophillips.com>, NSK Well Integrity Proj <NI878@conocophillips.com> MJ/Marie, We received the 404 and photos documenting the unsuccessful attempt to repair the surface casing. Your proposal to operate the well in water only service with 2 competent barriers is acceptable. With the tubing and production casing intact, a failure of either will not result in any release from the well. At this time, I do not believe it is necessary to submit a sundry for the operation of this well. Increasing the MIT frequency and pursuing a workover are good ideas. The only additional requirement that we feel is appropriate is to add this well to the monthly monitoring list. That will help keep it "in front" of all of us. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: "c.--- U.\\.\~"'~¡::¡, PlJ~ oj ¿1 ZOD5 ;::, ne~,"p'..,I_..) L- Tom, This is an update on the well status of 2V-08A (PTD 184-091/ Sundry 305-121). As you may recall this well has a surface casing x conductor leak. We originally located the leak about 7' below the OA valve and had planed to excavate, remove the conductor, weld a patch on the surface casing, repair the conductor, then normal the well back up. During the process of the above repair plan we discovered that the leak was not from corrosion but from a pressure event. The surface casing was egg shaped with a 20" split. At first we thought it could be fixed and excavated an additional +/- 15 feet down from the original 1 0' hole (total excavation depth -25'). Upon inspecting the surface casing at the bottom of the excavation we noted that it was still egg shaped and the hoop stress had been mortally compromised for at least another 15' and possibly the entire joint of surface casing. Safety concerns prohibited excavating any deeper. At that point plans to repair the surface casing were aborted. The conductor was repaired and included the addition of a 3" circulation nipple to enable conductor access and monitoring. In the near term it is ConocoPhillips intention to pursue approval to normal up 2V-08A and resume operations limited exclusively to water injection. The well has two formal barriers with passing MIT's on the tubing and the production casing. The well would be placed on an accelerated bi annual MIT schedule. It is also ConocoPhillips intention to aggressively pursue a rig workover for this well. The 10-404 report of Sundry Operations was filed today summarizing the repair attempt. Please advise if any additional approval is required from the AOGCC for continue operation of 2V-08A as a water injector only with 2 competent barriers, but with out competent surface casing. I look forward to hearing from you. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 lof2 ~"- W ~ï~;\.fc 7/14/2005 12:42 PM Conoc;Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 12,2005 RECEIVED JUL 1 4 2005 Alaska Oil & Gas Cons po '. . v mm,ss,on Anchorage Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 2V -08A (PTD # 184-091). The Sundry reports the attempted surface casing repair. Please call Marie McConnell or me at 659-7224 if you have any questions. Sincerely, ~~ MJ Loveland Problem Well Supervisor SC,ANNEU JUL 1/1 2005 Attachments Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 113' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: ( ~ RECEIVED JUL 1 4 2005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Alaskat£lil & Ü8~ns. Cornllli~sior Time Extensi~C~age Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Ope rat. ShutdownD Re-enter Suspended Well o Plug Perforations 0 Perforate New Pool D Stimulate D Waiver D Perforate 0 4. Current Well Status: Development D Stratigraphic D Exploratory D o 5. Permit to Drill Number: 184-091 6. API Number: 50-029-21128-00 Service 9. Well Name and Number: 2V-08A 10. Field/Pool(s): Kuparuk Oil Pool measured 9050' feet true vertical 6279' feet measured feet true vertical 6276' feet Length Size MD 103' 16" 103' 3755' 9-5/8" 3868' 8921' 7" 9034' Plugs (measured) Junk (measured) TVD Burst Collapse 103' 2851' 6267' Measured depth: 8446-8488, 8586-8612, 8628-8678' true vertical depth: 5837-5866, 5937-5956, 5968-6005' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 8542' MD. RBDMS 8Ft JUl 1 4 2005 Packers & sssv (type & measured depth) pkr= CAMCO 'HRP-1-SP'; BAKER 'FB-1' pkr= 8285'; 8518' SSSV= SSSV SSSV= 1943' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinç¡ Pressure Tubinç¡ Pressure Prior to well operation NA Subsequent to operation NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAG 0 GINJD WINJ D WDSPLD 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 ·30..Ç'-/~ I Contact Marie Mcconnell/M~J Loveland@659-7224 Printed Name MJ Love~nd / Title Signature~ '/ ~ A.. Phone Form 1 ~ Revised 0412004 0 R \ G \ N A L Problem Wells Supervisor 907 -659-7224 Date /;¿ :TV/.. Ó\S- Submit Original Only " It ( 2V -OSA DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 6/6/200S Secured well with plug in SSSV profile @ 1943' and PT'd to 2500 psi 6/S/200S excavated approximately 10' down in cellar to expose conductor 6/11/2005 Cut initial 2' x 2' window in 16" conductor casing exposing damaged surface casing and pressure split. The initial window was cut 8' below the OA annular valve 6/19/2005 State Inspector Lou Grimaldi witnessed the damaged surface casing and took pictures if the damage 7/7/2005 Excavated an additional 12' in depth (20-25' total depth) and cut away additional conductor to evaluate surface casing damage. It appears the pressure damage on the surface casing extends down at least 30' from surface. Due to the depth of the damage and hazards associated with further excavation, the 9 5/8 surface casing repair was aborted. 7/11/2005 Repaired conductor casing with welded patch, installed 3' circulating nipple below Tanko- Head on the conductor, pulled Shoring box out of pit and prepared for gravel back fill. I Excavation will be back filled after ADEC approval :::.,... ~ ~T ~ ~~ ~N } n • ~ ~ ' ` ~ ` ~ ~\ • .' i ~ ~ ~•' • r~r` _ ~ L f ~ fi i s ~ s ~ ._ r~ ~~ - ~ ~ 4x:A~ i f ~, e , ~.; ~ b'~i ,~ a, :,~ '7S. r°t ~ :a , Damaged surface casing after removing ;~ coductor casin . g The pressure ridge in the Surface casing extends well beyond the safe capabilities of repairing from surface with a welded patch. ,,,T~~- ==~. ~.. ~ ~ ~~. ~ ~ ~ ~t • ~' .:. w a~ ,• ~ ~s _ . ._ ~~~ ~ ~~ . •,~. _ Y ~~~ Re: [Fwd: RE: 2V -08A Surface Casing Repair PTD 1840910] (' Subject: Re: [Fwd: RE: 2V-08A Surface Casing Repair PTD 1840910] From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 20 Jun 2005 14:36:08 -0800 To: James Regg <jim_regg@admin.state.ak.us> I see what you mean on trying to see anything regarding collapse in the photos. Contrast is poor. Might have helped if the "lines" (where any bends are) had been highlighted with chalk One thing in the discussion is we are talking about the OOA (conductor x surface casing annulus). It is not designed to contain any pressure. I'll add comments according to your numbers. 1. I agree. If internal pressure had been the culprit here, the failure would likely have resembled A-22. Such failure presumes that gas is the charged fluid. Might it be different if liquid is involved?? One thing I experienced once upon a time was bridging off while doing a cement job and having the head "fail" on an XO. We had 3000 psi on the head when it let go and the result was collapsed pipe a ways down the well. Such mechanism doesn't seem to be plausible here. 2. This is a 19B4 vintage well. There is precious little information regarding whether or not cement was gotten to surface. I joined ARCO in late 19B4 and cement to surface was something I worked on for a long time. Regardless of circulating cement from the primary job, a lot of company men did top jobs to assure the best quality cement in the conductor. The goal of my work was to establish volumes and excesses that would get cement to surface on the primary job. Sometimes it worked, sometimes it didn't. I think that attention to getting cement to surface was greater, but a lot of it all depended on the company man. We could have the Inspectors look into the cellars, but all that will probably do is maybe determine if it might be possible to even "sound" for t,he cement in the OOA. Having them get a feeling if that would be possible would give us a clue on how hard the operators might "push back" if we want a determination of the TOC in OOAs. CPAI has done a series of "top offs" on a number of their Alpine wells and some in Kuparuk as well. I seem to remember Jerry saying that they are trying to follow the rigs to check on TOCs and top them off "soon". 3. Right off hand I don't know of other wells. I may have some information in my files. I will check. It is probably likely that there are similarly failed wells out there. 4. The "tankco head" is a debris barrier covering the OOA. It was not designed to contain pressure. You are correct that this well appears to be one they want to return to service. If they do the "sleeve" fix, that should restore the primary integrity they desire, depending on if there are other failure points in the casing they don't know about. What they are finding seems to be getting them beyond the scope of what they originally went in to fix. Tom James Regg wrote: Spoke with Lou about KRU 2V-OBA this morning; he saw what was described below; said CPA has good photos of collapse but was reluctant to send to Commission because they are concerned photos will end up in our electronic well files. I had not picked up on collapse from photos Chuck had sent; re-looking at them you can see the collapsed pipe adjacent to crack in 9-5/B". What they have found in 2V-OBA presents serveral interesting issues and questions. 1) I tend to agree with the freeze-back theory as reason for failure (absent any other study work that might shed some light on metallurgy) . 2) No cement to surface is an obvious area of concern; should we have North Slope operators verify TOC in OA for all wells? We could also direct inspectors to visually check for cement in OA when they enter a wellhouse [could we direct operator to do top jobs or grout those annuli where cannot confirm cement top near surface?] 3) There are numerous wells on the North Slope with fluids in the cellar; some of the arguments used by well integrity personnel in the past to explain seem to be bogus after PBU H-11 and KRU 2V-OBA failures; are there other wells with similar freezeback failures that need to be addressed? 4) The tanko head on the OA is something I had not thought about in the past; based on its inability to hold pressure, does that invalidate the OA as a barrier? The well is obviously an important one to their injection campaign (doubt they would be pursuing this otherwise); curious why they would not just redrill or decomplete/recomplete instead of putting a band-aid on the wounded well. Any approvals to continue operating this well should err on the side of caution if granted at all; ongoing surveillance must be rigorous if the well is allowed to operate after a lof3 ~\"-~ ~~\\E;' k2~ 7/14/2005 12:41 PM Re: [Fwd: RE: 2V -08A Surface Casing Repair PTD 1840910] (' (" band-aid repair. Jim -------- Original Message -------- Subject: RE: 2V-08A Surface Casing Repair PTD 1840910 Date: Sun, 19 Jun 2005 22:24:31 -0800 From: 'NSK Problem Well Supv <n161 7@conoc~:ehi~J::,~,E~",:,_~.E.!!1,?:. To: Thomas Maunder <tom maunder@admin.state.ak.us>, NSK Well Integrity proj 5~_"l,,ª-,7_,?_~,s:__?-!:!:?,s:gpþ_~,,~,~,,?':p,!?.:..~.9_~?.. CC: jim regg@admin.state.ak.us, NSK Problem Well Supv <n1617@conocophillips.com> Tom, More details have been observed regarding the 2V-08 SC leak. The 9-5/8" surface casing did not bulge and split in a smile shape as typical of burst pipe. The casing appears smashed as if it collapsed from an external force. The surface casing is formed around the 7" injection casing on the south side and an approximately 10' long smashed section is present on the north side. The smashed section is in the shape of a Vee that looks as if the side of the pipe was pinched in a 10' long vice. The tip of the Vee is 1.75" away from touching the conductor wall. The SC leak was a split at the tip of the Vee where the metal was severely stressed. A cross-section of the surface casing at the damaged location would be teardrop shaped. The south side that is still round, is elliptical in shape and is 2.25" from the conductor wall. If the SC is centered in the conductor, the OOA clearance is 2.81". The east and west sides are pushed in away from the conductor wall 4" and 2.875" respectively. There is no corrosion damage on the outside of the surface casing. The pipe is in new condition and the very slight impression of the rig's slips can be seen on the surface casing just under the top collar when the pup was made up on the rig floor. Looking into the split at the 7" casing and the inside of the 9-5/8"casing, there is no indication of corrosion on the inside of the surface casing. AOGCC inspector Lou Gramaldi witnessed the damage on 6-19-05. The collapse rating of the 9-5/8" casing is 2020 psi. I'm still puzzled at how this casing could have collapsed. The conductor is designed to burst before the surface casing collapses. Conductor burst rating is 1640 psi. The conductor is in new condition with no signs of bulging from internal pressure. The conductor top is a tanko head that shouldn't hold more than 20 - 40 psi. The surface casing metallurgy may have been flawed and failed at a much lower pressure. The only theory I have so far is a possible ice event in the conductor annulus that collapsed the OA when the well was SI and cold with a vacuum on the OA. At this time, there no plans to cut out a section of this pipe to send away for failure analysis, it would be interesting and is something that will be considered. Our mechanical engineer reviewed the damage on 6-16-05. Due to the flattened shape of the casing, if the split was repaired with a fill weld, the internal pressure would no longer be exerted as hoop stress, but as a flat plate force. Pressure ratings for flat plate vessels indicate the casing would only hold somewhere between 80 to 200 psi as estimated from a few vessel rating calculation methods. At this time, plans to seal weld the split have been cancelled as it would likely split shortly after repaired by this method. The crack has propagated in both directions from the split and would need to be ground out at each end prior to a fill weld repair, this is likely to require additional excavation to remove the bottom end of the crack. An alternative repair plan has been discussed. The flattened section appears to stop about 81 below the split. TOC in the conductor appears to be about 14' below the split and the pipe appears to be in fairly good condition at the cement top. It appears that with an additional 10' of excavation, the flattened section of surface casing could be removed and a sleeve patch installed. The sleeve patch would return the surface casing to the original pressure rating. The surface casing may be slightly elliptical just below the flattened section, but as long as it is curved and not flat in this section, the internal forces would act in hoop stress and a sleeve repair would be successful. A boroscope will be ran in the conductor annulus this week to futher investigate the condition of the surface casing. At this point, visual observations by lowering a flashlight on a rope into the conductor. An additional 10' of excavation is not a trivial issue and is being discussed. The repair may need to wait a while for the ground to thaw out & dry up before additional excavation is possible. Materials to shore the sides of the excavation pit may also be needed. The OA was arctic packed. If the SC leak is successfully repaired, the OA will be filled with diesel during the MITOA. Please let me know if you have any questions, Marie McConnell Problem Well Supervisor .~\,,~'d~~'<:- JHþ~05 12:41 PM 20f3 Re: [Fwd: RE: 2V -08A Surface Casing Repair PTD 1840910] { 659-7224 -----Original Message---~- *From:* Thomas Maunder [mailto:tom maunder@admin.state.ak.us] *Sent:* W~dnesday, June;)5, 2005 10:21 AM *To:* NSK Well Integrity proj *Cc: * .t~,~_~,~,9,9~~9.:9.!.!!~,!?-_:,_?.,~,9.:!:,~.,:_,~~.,,:_~,~.; NSK Problem Well Supv *Subject:* Re: 2V-08A Surface Casing Repair PTD 1840910 Jerry, MJ or Marie, With regard to the area around the split, is there any plan to do any "thickness measurements" or other inspections to investigate the properties of the surface pipe?? Base on Jerry's message, it does not appear that any of the surface casing will be cut away that a metal sample would be secured. I have to do some research on this well. Was the well arctic packed?? What fluid is intended to be left in the OA?? With the repair only planned to be tested to 500 psi, that establishes an operating threshold of about half of your "WOG". As we have discussed previously, WOG may not strictly apply since this is an injection well. Is it possible to install some sort of alarm on the OA since the pressure threshold is much lower than "normal" wells. Tom Maunder, PE AOGCC NSK Well Integrity proj wrote: Tom: As per our conversation about the surface casing repair on 2V-08A, when we cut and removed the conductor we found a split in the surface casing instead of corrosion. As per Sundry approval #305-121, CPA was given approval to repair this well. Although the mechanism for the failure is different than what we expected, the repair will be slightly different than detailed in the Sundry request. The split in the 9-5/8" casing is only 18" long, the widest gap approximately 1/4". There is pipe deformity that extends approximately 20-feet below the split (and out of site) that presumably continues down to the next tool joint. There is no possible way to repair this casing to original strength in these conditions. However, we can seal weld the split so that there in no longer communication into the conductor. This should prevent any future spills around the wellhead from OA fluids. Our welders are looking at the situation now and making a plan for welding the split. They are approaching the repair as if the finished product should support up to 500 psi. We can test the repair with nitrogen to see if there are any remaining leak areas. When the surface casing is repaired the conductor window will be replaced, and the pit will be back-filled with gravel. Since this is an injector with two good barriers (tubing and production casing), we plan on putting this well back in service on water injection only. Providing the pressure test passes OK, the OA will be limited to very little pressure (100 psi, for example). The main goal of this repair was to stop the leak of hydrocarbons around the wellhead, and well feel confident we can still achieve that with this proposed fix. Please let MJ Loveland or Marie McConnell know if you concur with our change in repair plans. Referring to the discussion submitted on the Sundry Application, there are only a few changes from what we are proposing in this email. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 30f3 ~ ~,,~"d~,~,~c,; 7/14/2005 12:41 PM '~~ ~4 x ~ ~^ ~ ~~y .N~ yi~~- iy ` :~Mr ~~ ~+ + . it i ~~ .. it_ ~_ , '~~ , •' ~..`, ~ .~ r G ~~~ ~ .a V ' ' .. :el- -. ~ _ ~ psi ~} ~ e `` w r' !'i _ ~ ~j "et.,~'~ ~" wmryy n ~~_ .gip Jet ,~ ;~ •• _ t-~_t "`. ,a~,a ~.' r ~,~~ - ~ ~,~, ems, ti Y ~pv~~`t"~~• ~.~``y •r F~ .~ ~ , ~~ j. ,~„f~ ' ~ - .. ~ i~,y;~.A '~..' '- ~ .alb`s w ''`. 4 °r ~ ~ ~~' ~` PP ~T ~ ~h` mss, P ~ ,\:l 1. c ~ Z ~ ~, ~ ~~~ ~ '~€:af ;., r} ~ ... a ..~ `~~xr~ -. ~p \s .t ~ I ~ ~~'4r ;gip-„ ~. : i ~ 'F' _'.. to 'p „ ~ • -~_ ~I ~ ;v ~ .~ a r ~:X n ~.... 7 . ,,p3. fy ~ ~ ~~ ~~ ~ S ` \ ~~ yy ' r . ~~~ " V' { `~., - 1 ~~• . t) • ~- ~:~lt~ .) ') 2V -08A Surface Casing Repair PTD 1840910 Subject: 2V-08A Surface Casing Repair PTD 1840910 From: NSK Well Integrity Proj <N1878@coÌ1ocophillips~com> Date: Tue, 14 Jun 2005 10:24:50 -0800 To: t0111_maunder@admin.state.ak.us CC: jim_regg@admin.state.ak.us, NSK Problem Well Supv <n1617@conocophillips.com>, NSK Well Integrity Proj <NI878@conocophillips.com> Tom: As per our conversation about the surface casing repair on 2V-08A, when we cut and removed the conductor we found a split in the surface casing instead of corrosion. As per Sundry approval #305-121, CPA was given approval to repair this well. Although the mechanism for the failure is different than what we expected, the repair will be slightly different than detailed in the Sundry request. The split in the 9-5/8" casing is only 18" long, the widest gap approximately 1/4". There is pipe deformity that extends approximately 20-feet below the split (and out of site) that presumably continues down to the next tool joint. There is no possible way to repair this casing to original strength in these conditions. However, we can seal weld the split so that there in no longer communication into the conductor. This should prevent any future spills around the wellhead from OA fluids. Our welders are looking at the situation now and making a plan for welding the split. They are approaching the repair as if the finished product should support up to 500 psi. We can test the repair with nitrogen to see if there are any remaining leak areas. When the surface casing is repaired the conductor window will be replaced, and the pit will be back-filled with gravel. Since this is an injector with two good barriers (tubing and production casing), we plan on putting this well back in service on water injection only. Providing the pressure test passes OK, the OA will be limited to very little pressure (100 psi, for example). The main goal of this repair was to stop the leak of hydrocarbons around the wellhead, and well feel confident we can still achieve that with this proposed fix. Please let MJ Loveland or Marie McConnell know if you concur with our change in repair plans. Referring to the discussion submitted on the Sundry Application, there are only a few changes from what we are proposing in this email. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7043 $tANNEP OCT 3 1 2005 2V -08A Spill Report During Excavation ) ¡ ) Subject: 2V -08A Spill Report During Excavation From: NSK Well Integrity Proj <NI878@conocophillips.com> Date: Thu, 09 Jun 2005 08:31 :38 -0800 To: tom _ maunder@admin.state.ak. us, chuck _ scheve@admin.state.ak. us CC: NS Well Integrity Proj <NSKWellIntegrityProj@conocophillips.com> Tom and Chuck: As Chuck already knows, yesterday we began the excavation for the surface casing repair on 2V-08A. When we got to the bottom of the cellar we found significant contamination, the residue from an old spill. We reported this as if it was new, through our Environmental Group to the agencies. However, after doing some research they found this spill had been reported in 1995. The original spill was estimated at 200 gallons and the final cleanup was to be done during field closeout. Now that we have uncovered it, an attempt will be made to finish the cleanup and close out the spill report. The original spill report reported the spill from the conductor into the cellar through a hole in the surface casing. They hypothesized the cause was from wear on the casing during Drilling Ops. My expectation is that we will determine the cause is now from casing corrosion--we will be able to confirm that on Saturday. Chuck: Should you desire to see the exposed casing, we should have the conductor removed by Saturday afternoon. It will be open for a day or two before we get the patch installed. Call if you have any questions. Jerry Dethlefs Problem Well Supervisor 659-7043 -----Original Message----- From: NSK Env Proj Sent: Thursday, June 09, 2005 6: 18 AM To: CPF2 Prod Supv; NS Env Coord; NS HSE Supv Cc: NSK Problem Well Supv; NSK HSE Admin Assist; CPF2 Fac Engr Subject: RE: 2V-8 Spill Question Glynn, I looked into the database and found the spill you referenced. It was a 200 gallon crude spill which was reported to the agencies. Cause was "communication between 9-5/8" surface casing and 16" conductor pipe, which is most likely the result of drill pipe wear on the 9-5/8" casing." On the cleanup description it said, "The need for future action will be determined at field abandonment." I think we are seeing residual contamination from the 200 gallon spill, plus some continuing seepage. I will talk to Tom DeRuyter at ADEC today about recording this in their database as a continuation of the 2V spill on 1/16/95. Hopefully we can use this opportunity to file a final spill report on the 2V spill (assuming we are able to get the majority of contamination), since it was never closed out. Leigh Leigh McDaniel and Jeff Smith Senior Field Environmental Coordinator - Kuparuk (907) 659-7242 Phone (907) 659-7712 Fax Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 1of2 6/9/2005 9:36 AM Re: 2V -08A Spill Report During Excavation ( i{ Subject: Re: 2V -08A Spill Report During Excavation From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 09 Jun 2005 09:36:06 -0800 .... To: NSK Well Integrity Proj <NI878@conocophillips.com> Thanks Jerry. Never know what you might dig up. I'll have to take a look at the well file. 2V-08 and 2V-08A has an interesting history from what I remember reading previously. Tom NSK Well Integrity Proj wrote: Tom and Chuck: As Chuck already knows, yesterday we began the excavation for the surface casing repair on 2V-08A. When we got to the bottom of the cellar we found significant contamination, the residue from an old spill. We reported this as if it was new, through our Environmental Group to the agencies. However, after doing some research they found this spill had been reported in 1995. The original spill was estimated at 200 gallons and the final cleanup was to be done during field closeout. Now that we have uncovered it, an attempt will be made to finish the cleanup and close out the spill report. The original spill report reported the spill from the conductor into the cellar through a hole in the surface casing. They hypothesized the cause was from wear on the casing during Drilling Ops. My expectation is that we will determine the cause is now from casing corrosion--we will be able to confirm that on Saturday. Chuck: Should you desire to see the exposed casing, we should have the conductor removed by Saturday afternoon. It will be open for a day or two before we get the patch installed. Call if you have any questions. Jerry Dethlefs Problem Well Supervisor 659-7043 -----Original Message----- From: NSK Env Proj Sent: Thursdav, June 09( 2005 6: 18 AM To: CPF2 Prod Supv; NS Env Coord; NS HSE Supv Cc: NSK Problem Well Supv; NSK HSE Admin Assist; CPF2 Fac Engr Subject: RE: 2V-8 Spill Question Glynn, I looked into the database and found the spill you referenced. It was a 200 gallon crude spill which was reported to the agencies. Cause was "communication between 9-5/8" surface casing and 16" conductor pipe, which is most likely the result of drill pipe wear on the 9-5/8" casing." Or) the cleanup description it said, "The need for future action will be determined at field abandonment." I think we are seeing residual contamination from the 200 gallon spill, plus some continuing seepage. I will talk to Tom DeRuyter at ADEC today about recording this in their database as a continuation of the 2V spill on 1/16/95. Hopefully we can use this opportunity to file a final spill report on the 2V spill (assuming we are able to get the majority of contamination), since it was never closed out. ' Leigh Leigh McDaniel and Jeff Smith Senior Field Environmental Coordinator - Kuparuk (907) 659-7242 Phone Af~(\"Q~~ì\.~' 7/14/2005 12:34 PM lof2 MIT KRU 2V -08 10-12-03 .xIs <' { Subject: MIT KRU 2V-08 10-12-03.xls From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Wed, 29 Oct 2003.13:20:20 -0900 To: bob _ fleckenstein@admin.state.ak.us, j im _regg@admin.state.ak.us, tom _ maunder@admin.state.ak.us CC: n1617 <nI617@conocophillips.com> Torn, Jim, Bob, Attached are MIT IA and MIT T results for 2V-08. The tests were completed during diagnostics for a potential surface casing problem that originated from a "swamp gas" report. Both MIT's passed good and there is no sign of TxIA or IAxOA communication. We are submitted the MIT data to restart the 4 year clock on 2V-08 Please let me know if you have any questions MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 (See attached file: MIT KRU 2V-08 10-12-03.xls) KRU 2V-08 Content-Type: application/msexcel Content-Encoding: base64 1 of 1 Q\\t--.\t'ð ~r ~t \(Q Je.1"tilt4/2005 12:36 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test it Email to:Tom_Maunder@admin.state.ak.usandBob_Fleckenstein@admin.state.ak.us OPERA TOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk I KRUI 2V 10/12/03 D.SAUVAGEAU Packer Depth Well 2V-08A Type Inj N TV.D. 5725 P.TD. 1840910 Type Test P Test psi 1500 Notes: MIT IA for Diagnostics - TTP in well during test Tubing Casing OA Pretest Initial 15 Min. 30 Min. 1900 1900 1900 1900 Interval 1400 2500 2420 2380 P/F o 0 0 0 o P Well 2V-08A Type Inj N T.V.D. 5725 Tubing 1950 3000 2950 2900 Interval 0 P .TD. 1840910 Type Test P Test psi 1500 Casing 1400 1400 1400 1400 P/F P Notes: MIT -Tubing completed for diagnostics wI TTP OA 0 0 0 0 Well Type Inj TV.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj TV.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.TD. Type Test Test psi 1500 Casing P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey 0= Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover o = Other (describe in notes) \X"\~~~ ~~~\lQ MIT Report Form Revised: 05/19/02 MIT KRU 2V-0810-12-03.xls 7/14/2005 Æ..~ ) ) J 8'1-o? I ,~ _.~ (ð' ^ """"'~"':1 """~ 1(' 1~'~ ¡),"'1i, ,,,,. ! '~ \\ c¡".., ,r' , '1-" 'l.liW·'I"i'~ I, ,:\ \; " ¡: i }~\ "~ '!I ! a='1 ,~ 'w' .,,"\ I! i iU~'~ i i t ii' f ¡ 'I' ;1: ,11i"'''1, I: ! ~, ,: :' ,I \~ ,: U·w \~ \ W ~ ,!,J'-r", "':,\ "',r~,ír,, ':::I , I I I \ !, fur, ji¡ iU' ;r"'-I n I I ' , \~ I,~ '-'''<\ 'I"'" !Ì ,1 1\, :,' ~,' l.1il "¡ li û\ II i. 'ni'!'1 l ,: ,\j ;_~ l0\J \ \'- ,\,' 'n)) "---- FRANK H. MURKOWSK/, GOVERNOR AlfA~HA OIL AND GAS CONSERVATION COltDlISSION 333 W. yTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska SCANNED MAY 262005 Re: Kuparuk 2V -08A Sundry Number: 305-121 Dear Mr. Dethlefs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day fa~~~~~,s 0 holiday or weekend. A person may not appeal a Commission decision to Supror ~urt unless rehearing has been requested. . ' ./ nere¥y,.I -- Chairman DATED thisØay of May, 2005 Encl. Kuparuk surface csg "dig and weld" repairs ) ) ",¡a.. Súbject: Kuparuk surface csg "dig and weld" repairs From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 11 May 2005 15:05:42 -0800 To: AOGCC North Slope Office <aogcc-prudhoe_bay@admin.state.ak.us> f L""' 0 q \ tCb4 All, Just a heads up. I am processing 3 sundries for "dig and weld" repairs for surface casing leaks at Kuparuk. The wells are 2V-08A, 3F-17 and 3F-18. The sundry for 3F-18 says "immediately" but I have not been able to get any idea how soon that would be. The proposed repairs are similar to the 5 or so other wells they have worked on previously. Tomorrow, I will have Bren scan one of the procedures and will get it emailed out. The witness requirement I recommend is when the conductor has been cut away and the leak "exposed". Witness of other activities is at your discretion. I have required photos for documentation. Call or message with any questions or comments. Tom ~") ~O*-<:¿~ C-? Þ>..~ ~S ~~<è ~'D()~~ S- 'êJ-\-~~ s '\ ~\ \ 0.-'- ~ 'Ð '-ö ~ ~Ù C_C_ <1':.. <s 'S. ~ \. ~ . l ~~Ç: Sk"--~ c:....~~~c:s.-';,CC \-0 ~~~\~!M.. W<2U~ 0..> \Ltv---S, ~\~ ":>\0\!-'-..~~~ ~ ~~\-'\r--..~ ..n oÄ- -\-~ ~\ \ "> \<È- F\1C-"'ð ~\+-\........\-\,\ ";> ~~~cJ £; ~.~ N-O...f'-\ ~ \<=- O-,Q:: O~ ~S- 4~ I of 1 5/1112005 3:05 PM ) ) y ConocoPhillips Alaska ,0" \ aUt \-u P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 R' 1'""" /. '~'",~I '~F . \' :'_:¡"'1.""~"" May 8, 2005 AI i\ ì( . ~ '_',J [)¡ 0 ç:,I' 1l!§.4¡ · Ji J.' ~ Œ!& Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AI< 99501 Dear Mr. Maunder: Enclosed please find three 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. wells 2V-08A, 3F-17 and 3F-18. The approval requests regard repairs for surface casing leaks. Also enclosed is a, 10-404 Report of Sundry Operations for well 3F- 09 for an attempt to repair a surface casing leak with sealant. Please call MJ Loveland or Marie McConnell at 659-7224 or me at 659-7043 if you have any questions. Sincerely, ;1--1c~ Jerry Dethlefs Problem Well Supervisor Attachments ) :~ ,':!)- /2 -0 S ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Type of Request: APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 Abandon o o o Suspend 0 o o Stimulate Re-enter Suspended Well o 5. Permit to Drill N~ber: 184-091 V 6. API Number: 50-029-21128-00 9. Well Name and Number: 2V -08A Perforate 0 o Repair well Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 113' 8. Property Designation: Kuparuk River Unit 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 9050' 6279' Casing Length Pull Tubing 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory 0 Service 0 10. Field/Pool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): RECEIVEOf MAY 11 2005 /¡, Alastut Oil &, Gß$ Con!. Commission Waiver AncQagê'nnular Disp. 0 Time Extension 0 Other 0 Junk (measured): CONDUCTOR 103' SUR. CASING 3755' PROD. CASING 8921' Size MD TVD Burst Collapse 16" 103' 103 9-5/8" 3868' 2851 7" 9034' 6267 Perforation Depth MD (ft): 8446-8488,8586-8612,8628-8678' Packers and SSSV Type: pkr= CAMCO 'HRP-1-SP'; BAKER 'FB-1' SSSV= SSSV Perforation Depth TVD (ft): 5837-5866, 5937-5956, 5968-6005' Packers and SSSV MD (ft) pkr= 8285'; 8518' SSSV= 1943' Tubing Size: 3-1 /2" 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Printed Name J~ Deth~f:,,- f\ Signature ~ '-- '~ - \ Uommission Use Only June 1,2005 Date: 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Contact: Title: Phone 659-7043 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: ~o~,~ ì 1:...,,~ \_ _ \ t C\ " '" ~~~ \<ê.c.~, ~ÚS~~<Ln ct'( ~C~~Ù . Tubing Grade: J-55 Tubing MD (ft): 85421 Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Loveland/McConnell 659-7224 Problem Well Supervisor Date ~7?As- Sundry Number: 3ð~/~1 ~ \<--.C- \-.::Ieo, "~å ~ -\0 ~C CSI ~ ~'" .\0-\\0 ~ 0 ~ ~ F ~ COM~s~,~L N A L~~~~~~~~~'ON Date:.s;ý c£ INSTRUCTIONS ON REVERSE RBDMS BFL MN: 1 6 7!JOObmit in Duplicate '- Form 1 0-403 ~~003 ) ) ~' ' ConocoPhillips Alaska, Inc. Kuparuk We1l2V-08A (PTD 1840910) SUNDRY NOTICE 10-403 APPROVAL REQUEST May 7, 2005 This application for Sundry approval for Kuparuk well 2V -08A is for the repair of a surface casing leak. The well is an injector, completed in September 1984. The first record of a problem on this well is dated January 11, 1994, with a report of a leak around the wellhead. A leak in the threads of the casinghead was suspected and pressure was kept bled off the OA. On September 28,2003, a recurrence of the leak was determined to be from up the conductor through an apparent leak in the surface casing. On October 6,2003, diagnostics were performed to locate and quantify the leak. A leak rate of 7 gpm was established at 50 psi and at a depth of approximately 7-feet below the OA annular valve. With approval, repair of the surface casing will require the following general steps: 1. Notify AOGCC Field Inspector of repair operation so they may witness the event. 2. Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze protection cap. 3. Remove the floor grate and equipment from around the wellhead. 4. Install nitrogen purge equipment for the OA and conductor so that hot work may be conducted in a safe manner. 5. Cut away the conductor casing and remove cement around surface casing for inspection. Approximately the top 8-feet of conductor will be removed to provide access to the surface casIng. 6. CP AI Mechanical Engineers will determine appropriate patch and/or repair to return the casing to operational integrity. 7. QA/QC the repair and MIT-OA for a final integrity check. 8. Install anti-corrosion coating as specified by CP AI Corrosion Engineer. 9. Replace the conductor and fill the void with cement to seal out water and oxygen. 10, Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well to production. 12. File 10-404 with the AOGCC post repair. NSK Problem Well Supervisor 05/07/05 SSSV (1943-1944, 00:3.500) Gas Lift mdrel/Oummy Valve 1 (8227-8228, 00:5.780) SBR (8267-8268, 00:3.500) PKR (8285-8286, 00:6.151) Injection mdrel/Oummy Valve 2 (8325-8326, 00:5.313) Injection mdrel/Oummy Valve 3 (8395-8396, 00:5.313) Perf (8446-8488) TUBING (0-8542, 00:3.500, 10:2.992) PATCH (8489-8511, 00:3.500) PKR (8518-8519, 00:6.151) NIP (8535-8536, 00:3.500) SOS (8542-8543, 00:3.500) Perf (8586-8612) Perf (8628-8678) ) ConocoPhUlips,Alaska,ln&. 2V':'08A l~ ~,:::;, ,_.d.'t (¡(~ IIIIIÎII. =i ---- ~ ;-'-,.,'.",w··1 it II-~ . - 2 8325 5753 3 8395 5801 4 8499 5874 1. w/WI Pkg Other'(pIÜgs,·eQI.j p.,·'.étc.) .., JEWELRY Depth TVD Type 1943 1627 SSSV 8267 5713 SBR 8285 5725 PKR 8489 5867 PATCH 8542 5905 8543 5906 General Notes Date I Note 12/2/2003 WAIVERED WELL: OA x OOA COMMUNICATION API: 500292112800 SSSV Type: TRDP Annular Fluid: Reference Log: Last Tag: 8661 Last Tag Date: 4/26/2000 Casing String - ALL STRINGS Description CONDUCTOR SUR. CASING PROD. CASING Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 8446 - 8488 5837 - 5866 8586 - 8612 5937 - 5956 8628 - 8678 5968 - 6005 I Gas Lift MandrelsNalves St MD TVD Man Mfr 1 8227 5686 Otis Injection·'.MàridÎ'~lsl\fåhiés St MD TVD Man Mfr Camco Camco Camco 8518 8535 PKR NIP 5888 5900 ,.--- "---- SOS TTL ) KRU 2V-08A Well Type: INJ Orig 9/13/1984 Completion: Last W/O: Ref Log Date: TD: 9050 ftKB Max Hole Angle: 53 deg @ 3900 Angle @ TS: 45 deg @ 8446 Angle @ TD: 42 deg @ 9050 Rev Reason: WAIVERED WELL Last Update: 3/1/2004 Size Top Bottom 16.000 0 103 9.625 0 3868 7.000 0 9034 Bottom TVD Wt 8542 5905 9.30 TVD 103 2851 6267 Grade H-40 J-55 J-55 Thread Wt 65.00 36.00 26.00 Grade J-55 Thread EUE 8rd Zone Status Ft SPF Date Type C-4,UNIT 42 12 9/13/1984 IPERF B A-4 26 4 9/13/1984 IPERF A-3 50 4 9/13/1984 IPERF Comment 120 deg. phasing; 5 1/2" Csg Gun 90 deg. phasing; 4" Csg Gun 90 deg. phasing; 4" Csg Gun Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.5 RO-5 0.000 0 11/14/1989 V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BK 0.000 0 4/27/2000 (1 ) DMY 1.0 BK 0.000 0 3/19/1985 PATCH 1.0 BK 0.000 0 5/18/2000 LBX Man Type V Mfr KBUG KBUG KBUG Description Otis 'FMX TR' (LOCKED OUT 4/23/89) Camco 'OEJ-1 0' Camco 'HRP-1-SP' Set HES permanent patch across GLM @8499' RKB. Top of patch set @ 8489' to 8511'; min. ID 2.375" 5/18/2000 Baker 'FB-1' Cameo 'D' Nipple NO GO. Set 2.75" x 2.25" "D" profile nipple reducer 5/16/2000 Baker ID 2.813 2.937 2.937 2.375 4.000 2.250 2.992 2.992 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test K(1'! 1(13~ Emall to.Tom_Maunder@admlnstateakus;Bob_Fleckenstein@admin.stateak.us; and Jim_Rebg@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: KRU 2V DATE: 06/28/04 OPERATOR REP: Sauvageau 1 Arend - APC AOGCC REP: Waived Packer Depth Pretest Initial 15 Min. 30 Min. Well 2V-01 Type Inj S TV.D. 5778 Tubing 1500 1500 1500 1500 Interval 4 P.T.D.1831580 Type Test P Test psi 1500 Casing 1150 2200 2200 2200 P/F P Notes: Well 2V-02 Type Inj S TV.D. 5705 Tubing 2150 2150 2150 2150 Interval 4 P.T.D. 1831610 Type Test P Test psi 1500 Casing 1150 2700 2660 2640 P/F P Notes: Well 2V-03 Type Inj S TV.D. 5689 Tubing 1150 1150 1150 1150 Interval 4 P.T.D. 1831640 Type Test P Test psi 1500 Casing 850 1920 1900 1900 P/F P Notes: Well 2V-04 Type Inj S T.V.D. 5538 Tubing 950 950 950 950 Interval 4 P.T.D. 1831650 Type Test P Test psi 1500 Casing 150 1900 1890 1880 P/F P Notes: Well 2V-05 Type Inj S TV.D. 5672 Tubing 2300 2300 2300 2300 Interval 4 P .T.D. 1831760 Type Test P Test psi 1500 Casing 950 1750 1720 1710 P/F P Notes: Well 2V-06 Type Inj G TV.D. 5636 Tubing 2550 2550 2550 2550 Interval 4 P.T.D. 1831790 Type Test P Test psi 1500 Casing 900 1700 1690 1690 P/F P Notes: Well 2V-07 Type Inj S TV.D. 5692 Tubing 2500 2550 2550 2550 Interval 4 P.T.D. 1831800 Type Test P Test psi 1500 Casing 900 1750 1720 1710 P/F P Notes: Well 2V-08A Type Inj S TV.D. 5725 Tubing 2450 2450 2450 2450 Interval 4 P.T.D. 1840910 Type Test P Test psi 1500 Casing 1550 2980 2900 2880 P/F P Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workol/er 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 2V 06-28-04.xls 7/13/2004 1\.1IT KR1I2V-08 10-12-03.xls \ S ~ -()'-\ \ Subject: l\HT KRU 2V -08 10- I 2-03.xls From: NSK Problem Wel1 Supv <n 16 I 7@'conocophillips.com> Date: 'Ned, 29 Oct 2003 13:20:20 -0900 To: bob - fleckenstein@'admin.state.ak. us. jinl_regg@)admin.state.ak.us, tom- maunder@.'admin.state.ak.us CC: n 1617 <n 1617@,'conocophil1ips.com> Tom, Jim, Bob, Attached are MIT IA and MIT T results for 2V-08. The tests were completed durlng diagnostics for a potential surface casing problem that originated from a "swamp gas" report. Both MITis passed good and there is no sign of TxIA or IAxOA communication. We are submitted the MIT data to restart the 4 year clock on 2V-OS Please let me know if you have any questions MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 (See attached file: MIT KRU 2V-OS lO-12-03.xls) i ! Content- T,'pe: application/msexcel i ,l\'IT KRU 2V-08 lO-12-03.xls . b 61 i Content-Encoding: ase.... I of I 7/20/200-43:12 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.usandBob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk I KRUI 2V 10/12/03 D.SAUVAGEAU Packer Depth Well 2V-08A Type Inj N T.V.D. 5725 Tubing P.T.D. 1840910 Type Test P Test psi 1500 Casing Notes: MIT IA for Diagnostics - TTP in well during test OA Pretest Initial 15 Min. 30 Min. 1900 1900 1900 1900 Interval 0 1400 2500 2420 2380 P/F P 0 0 0 0 Well 2V-08A Type Inj N T.V.D. 5725 Tubing 1950 3000 2950 2900 Interval 0 P.T.D. 1840910 Type Test P Test psi 1500 Casing 1400 1400 1400 1400 P/F P Notes: MIT -Tubing completed for diagnostics wI TTP OA 0 0 0 0 Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Vanance T est during Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 2V-0810-12-03.xls 7/20/2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_ RKB 113 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__x Kuparuk Unit 4. Location of well at surface 8. Well number 1884' FSL, 112' FWL, Sec. 8, T11 N, R9E, UM (asp's 508699, 5966591) 2V-08Ai At top of productive interval 9. Permit number / approval number 1436' FSL, 1284' FWL, Sec. 17, T11 N, R9E, UM (asp's 509899, 5960865) 184-091 At effective depth 10. APl number 50-029-21128 At total depth 11. Field / Pool 1029' FSL, 1346' FWL, Sec. 17, T11 N, R9E, UM (asp's 509963, 5960458) Kuparuk Oil Pool 12. Present well condition summary Totaldepth: measured 9050 feet Plugs (measured) Tagged PBTD (4/26/00) @ 8661' MD. true vertical 6279 feet Effective depth: measured 8661 feet Junk (measured) true vertical. 5992 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 110' 16" 220 Sx Cold Set II 110' 110' SURF CASING 3755' 9-5/8" 800 Sx CS III & 500 Sx 3868' 2728' CS II PROD CASING 8921' 7" 550 Sx G & 250 Sx CS I 9034' 6267' RECEIVED Perforation depth: measured 8446 - 8488'; 8586 - 8612'; 8628 - 8678' ? ZOO1 true vertical 5837 - 5866'; 5937 - 5956'; 5968 - 6005' Alaska Oil & Gas Cons. Commission Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55, Tubing @ 8542' MD. Anchorage Packers & SSSV (type & measured depth) Camco 'H RP-1-SP' Packer @ 8285' MD; Baker 'FB-I' Packer @ 8518' MD. MCX linj Valve, Set on "X" Lock 8/26/99 @ 1943' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut In - - Subsequent to operation 3500 3800 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil__ Gas __ Suspended _ Service ~.(WAG)~ ,.. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ .~f. ~.~/~,~. Title: Dattrep~ed b,~y j~e~265.6471 ~;~.' Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICAT~~ 2V-08Ai TUBING PATCH INSTALLATION DESCRIPTION OF WORK COMPLETED 4/26/00: RIH & tagged PBTD at 8661' MD. 5/2/00: Performed a Leak Detection Log and found leak at GLM #4 at 8497' MD. 5/18/00: RIH & set 3.5" (2.375" ID) HES Tubing Patch over GLM #4 at 8489 - 8511' (seal to seal). POOH. RD. 5/21/00: Pressure tested the Tubing Patch to 2900 psi for 20 minutes. Tested good. Placed the well on gas injection & obtained a valid injection rate. ARCO Alaska, I! · Post Office Box ,u0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 15, 1995 Mr. David Johnston AOGCC 3001 Porcupine Dr. Anchorage, AK 99501-3192 Re: Re-Submittal of Sundry Notices 2C-07 and 2V-08A Dear Mr. Johnston, Enclosed is the re-submittal of Sundry Noticies 2C-07 and 2V-08A per my conversation with Blair Wondzell on June 14, 1995. Sincerely, T. Wellman Beluga / Kuparuk Staff Manager :jls CC: J. Walker NSK 14 Zuspan / Erickson NSK 69 RECEIVED JUN 1 5 1995 kl~sk~ Oil & Gas Cons. Commission Anchom? ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AH,3B 0003 C '--;;~'~'x STATE OF ALASKA ~' ALA~,A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon w Suspend w Alter casing __ Repair well Change approved program __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Operation Shutdown __ Re-enter suspended well __ _ Plugging_ Time extension _ Stimulatem Pull tubing __ Variance ~ Perforate __ Other 6. Datum elevation (DF or KB) RKB 113 7. Unit or Property name Kuparuk River Unit 4. Location of well at surface 1884' FSL, 112' FWL, Sec. 8, T11N, R9E, UM At top of productive interval 1436' FSL, 1284' FWL, Sec. 17, T11N, R9E, UM At effective depth 1095' FSL, 1338' FWL, Sec. 17, T11N, R9E, UM At total depth 1029' FSLr 1346' FWLr Sec. 17~ T11Nr R9E~ UM 12. Present well condition summary Total Depth: measured 9 0 5 0 feet true vertical 6277 feet 8. Well number 2V-08A 9. Permit number 84-91 10. APl number S0-029-21 1 28 11. Field/Pool Kuparuk River Field/Pool Effective depth: measured 8951 feet true vertical 6204 feet Plugs (measured) None feet Junk (measured) None ORIGIk, AL Casing Length Size Structural Conductor 1 I 0' I 6" Surface 3 6 2 9' 9 - 5 / 8" Intermediate Production 8999' 7" Liner Perforation depth: measured 8446'-8488', true vertical 5837'-5866', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 8542' Cemented Measured depth True vertical depth 220 Sx CS II 1 1 0' 110' 800 Sx CS III 3 6 6 8' 2728' & 500 Sx CS II 550 Sx Class G 9 0 3 4' 6267' & 250 Sx CS I 8586'-8612', 8628'-8678' 5937'-5956', 5968'-6005' RECEIVED JUN 1 5 1995 0il & Gas Cons. Commission Packers and SSSV (type and measured depth) Anch0ra;e Pkr' Camco HRP-1SP @ 8285', Baker FB-1 @ 8518'; SSSV: Otis FMX-TR w/MCX Inj Valve ~ 1943' 13. Attachments Description summary of proposal ~X Detailed operation program _ BOP sketch_ Continue to inject. 7" production casing demonstrated integrity on 1/21/95 so continued injection is not considered to be UIC significant. 14. Estimated date for commencing operation '~ 5/95. onooing I 16. If proposal was verbally approved Name of approver Date approved Service Water Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 15. Status of well clas~ifi~at~*on as: Oil __ Gas Suspended Signed "~,/~,~-~,~,,,_ Title Beluga/Kuparuk Staff Mgr FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so rePresentative may witness Plug integrity ~ BOP Test _ Location clearance ~ Mechanical Integrity Test Subsequent form require 10- -- Approved Copy Returned dr~g,nal Signed By Approved by order of the Commission 0avid W. Johnston c0rnmissio~er ' D'~te Date IApproval No. ! 9_~"--//~ Form 10-403 Rev 06/15/88 SUBMIT Ih TR'IpLI~_,ATE 7 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston,~~~'''' DATE: Chairman ~ ~U: Blair Wondzell, //,~.~/~,~..- FILE NO: P. i. Supervisor FROM: John Spaulding, '.,y',4~. SUBJECT: Petroleum Inspector January 20, 1995 GB9LASCD.doc Casing Leak ARCO / KRU / 2V-8a Kuparuk River Unit Thursday January 20, 1994: I inspected the apparent casing leak 'at ARCO/' KRU well 2V-8a. Well 2V-8a is a produced water injector that is injecting at pressure range of 1600 psi to 2200 psi with temperatures of 125 deg. F. Prior to mid December of 1994 the well was a water alternating gas (WAG) well, pressure ranges of 2600 psi to 3300 psi and temperatures of 80-90 deg. F. The wellhead has an apparent leak of gas and hydrocarbons in the starting head area at the bottom of the christmas tree. The amount of gas and hydrocarbons leaking appears to be small (15-20 gal. / day). In order to find which formation the hydrocarbons are coming from, Arco has sent samples to Piano Texas to have analyzed. Having the hydrocarbons analyzed will aid Arco in the type of workover program for this well. Jack Walker. Arco drill site supervisor informed me that well 2V-8 was originally spudded approximately 8' from 2V-8a. Well 2V-8 was abandoned due to hole problems, apparently from lost circulation and problems with cementing the casing. January 24, 1995 the well was shut in and allowed to cool down and the release of hydrocarbons ceased. Arco is still in the process of diagnosing the wells problems. ARCO Alaska, Inc Post Office ~ , ,d0360 Ancnorage,~A'laska 99510-0360 Telephone 907 276 1215 Da'~E: 09 -12- 85 TkANSI~IITTAL NO: 5349 RJJTURN TO: ARCO ALASKA, INC. KUPARUK t)PERATIL~N~ ENGINEERING RECORDS CLERK ATO-1115B P.O. t~OX 100360 ANCHORAGE, AK 9951. U TRANSMITTED HEREWITH ARE THE FOLLOWING I'±'E[dS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. '~lA-4-- STATIC I~OTTOMHOLE PRESSURE REPOF, T 1/20/~5 "~2G-7-~- STATIC BOTTOI.iHOLE PRESSURE REPORT 1/23/85 ----2V-SA-~ STATIC BOTTOMHOLE PRESSURE REPORT 1/24/85 --2Z-4 ~" STATIC BOTTOI, i[IOLE PRESSURE REPORT 1/19/85 :/~'Z~"~ Pt~,ESSU~iE IIUILDUP REPORT 1/21/85 - / PRESSURE BUILDUP REPORT 1/24/85 STATIC BOT~'OI~4HOLE PRESSURE REPORT 1/24/85 ' RECEIPT ACKNOWLEDGED: BPAE ii. CURRIER CHEVkON D & H D~ILLING L. JOMNSTON M~DIL . NSK CLEiiK DISTRIBUTION: W. PASHER EXXON. PHILLIPS OIL J. iiA~3i-]IvlELL* DATE: SOHIO UNION K.TULIN/VAULT ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieidCompany ARCO Alaska, Inc," Post Oflice ~;ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 05-2 9-$ 5 TRANSMITTAL NO: 5199 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-!llSB P.O. BOX 100360 A~'~HORAGE, AK 99510 Tlb\NSMITTED tIEREWITII ARE TIlE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. KUPARUK ~ELL PRESSURE REPORT ENVELOPE DATA: (ONE COPY OF EACH) 2A-4 04-22-85 2A-7 04-23-85 2F-6 03-21-85 2G-8 03-21-85 2G-12 03-23-85 2H-13 04-26-85 21i-14 04-28-85 2H-15 04-29-85 2U-1 04-11-85 2U-2 04-11-85 2U-3 04-11-85 2U-4 04 -11-85 2U-5 05-02-85 2U-6 05-03-85 2U-7 05-04-85 2U-8 05-04-85 2U-13 03-09-85 2U-14 03-21-85 2U-!5 03-20-85 2U-!6 03-15-85 2V-2 03-23-85 2V-SA 03-17-85 2V-SA 01-24-85 2W-4 04-13-85 2X-1 04-14-85 2X 3 -8 · - 04-13 5 2X-13 03-30-85 STATIC-'C' SAND STATIC-'A' & 'C' SAND STATIC-PBU-'A' SAND PBU-'A' SAND STATIC-PBU-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND PBU-'A' SAND PBU-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND ST%"~¥C-'A' SAND STATIC-'A' SAND STATIC STATIC-'A' & 'C' ~TATIC-'A ' &'C ' STATIC- 'A ~ TAT iC - ' C STATIC- ' C S TAT IC - ' A .~. lC- A .~.~ IC- A S~TIC-'A & C' PBU-'A' SAND SAND SAND '&'C' SAND ' SAND ' SAND '&'C ' SAND ' SAND '&'C ' SAND SAND >ECEIPT ACKNOWLEDGED: DRILLING L. JOHNSTON MOB I L * NSK CLERK DISTRIBUTION: W. PASfIER E XY. ON PHILLIPS OIL* J. RATH[,:ELL* DATF~i~.sk~ Oil & ~s t;cns, t;ur;~mtssion STATE OF ALASKA* SO]~iO* UNION* K. TULiN/VAULT ARCO Alaska, Inc. Post Office Be? 360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports 2D-15 2V-SA 1£-24 2X-14 2G-14 DS 6-5 2G-15 for the fo 11 owing we 11 s: If you have any questions, Sincerely, Gruber Associate Engineer JG/tw GRUg/L01 Enclosures please call me at 263-4944. RECEIVED AY2 1 85 Alaska Oil & Gas Cons. Commission Anct~orage ARCO Alaska, inc. is a Subsidiary of AUanllcRIchfieldCompany ~--~'~,, STATE OF ALASKA -.-'"' ALASKA ,-tND GAS CONSERVATION C¢. ,~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , 2. Nam~ of Operator 7. Permit Number ARCO Alaska~ Inc. 8~'91 3. Address 8. APl NUmber P. 0. Box 100360~ Anchorage, AK 99510 ' 50- ' 029-21128 4. Location of well at surface 9. Unit or Lease Name 1884' FSL, 112' FWL, Sec.8, T11N, RgE~ UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1436' FSL, 1284' FWL, Sec.17, T11N, RgE, UN 2V-8A At Total Depth 11. Field and Pool 1029' FSL, 13~6' FWL, Sec.17, T11N, RgE, UN Kuparuk River Field , , 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 113' RKB ADL 25655, ALK 2581 , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 1!5. Water Depth, if offshore 16. No. of Completions 07/13/84 07/23/84 09/13/84 N/A feet MSL 1 17. T0taI'Depth{MD+TVD) 18. Plug Back Depth (MD+'rVD) 19. DirectionalSurvey I~O. Depth where SSSV ,et I~.Thic~ne,'ofPermafrost 9050'MD,6277'TVD 8951 'MD,6204'TVD YES E~X NO [] 1943 feet MD 1500m (approx) 22. Type Electric or Other LOgs Run D IL/SFL/GR/SP, FDC/CNL, Cal~ BHCS/GR, CBL/VDL/GR/CCL~ Gyro, Tamp. Log 23. CASING, LINER AND CEMENTING RECORD , , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED ..... 16" 62.5# H-40 Surf 110' 2b," 220 sX Cold Set: II .... 9-5/8" 36.0# '" J-55 Surf 3668' 12-1/4" 800 sx CS III & 500 sx CS II 7" 26.0# J-55 Surf 9034' 8-1/2" 550 sx Class (; & 250 s; C$ I 24. Perforations open to Production ('MD+TVD 'of'.ToP and Bottom and 25. TUBING RECORD ..... interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8628' - 8678' w/4 spf, 90° phasing 3-1/2" 8542' 8285' & 8518' 8586' - 8612' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,, 8~,66' - 8488' w/12 spf, 120° phasing ...DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8446' - 8466' 8514' - 8515' 200 sx Class G See attached Adde ~dum. da~.~d a/l~/Rr~_ · 27. N/~' PRODUCTION TEST .......... Date First Production I MethOd of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ FlowTubing Casing Pressure CALCULATED =~ OIL-BBL GAS-MCF WATER'BBL OIL GRAVITY-APl (Corr) Press. 24-HOUR RATE 28. CORE DATA , ,, Brief description o~ lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None P. ECE: V[D Alaska 0il & Gas Cons. commission Ancll0r~03 Form 10-407 GRU6/WC36 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. . GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. .. Top Upper Sand 8445' 5834' Base Upper Sand 8480' 5858' Top Lower Sand 8569' 5923' N/A Base Lower Sand 8742' 6050' 31. LIST OF ATTACHMENTS Addend.m 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~) ~t~~ ~/~'~.~t._,,/ Title ^ .... ,.~-~ ~-,..,, .... Date .~-/-~- Signed ~ ~ ~ ~, ,.,v ~,, ,~ ,..~,., ~, ,~,, ,~.,~, 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,s5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this fOrm and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. !~i~'~:i ~-.i~: ii: ~';~ ,::~.)!'~ :; ~.-~J<:.:~!. i;;,:'.~ _:.'.,!.L' "~i ~', '~;!.~~ ADDENDU. M WELL: 3/28/85 3/29/85 2V-8A Frac well in 8 stages w/300 bbls gelled diesel, 800# 100 mesh & 16,500# 20/40 mesh. RU WL, TIH, found top of sand @ 8684'. Rn Temp log f/8684'-8200', POH, RD. Drill-i~-~Su~r~ntendent ARco. Alaska, Inc. Post Office t ~0360 Anc.horage, Alaska 99510-0360 Telephone' 907 276 1215 .. ~ ~... ;'],? ., T I. J ]: £ 'T F.: F'~ N,% i'! J: T T,'::~ l_ ~ · . · ", ,.:':... :;/' n T :!: ,S' · -, r,.... -.' i;' ,"? ~" T ,?' 2. '" :... '"' i.... ._."'" '~', ]: 2 [::'" i [:::~., D']" :[ £ ":' "" "" i '":; .':':' T ]: ,:T. .:.. :.. .... ,. "~ m ... ' .r'... 'F '" ,;.; :.. '~ 4'. ,../ ..... .'"..' · ."2. F" .... 6 ~ [) T .'I: ,",.: ~ .ri'. .~ -'.- / m,..',i:/I..!T.; /I;' .~:. ~ "- , ...! '..'~ ..;. i~ .' ~ ~ ,~....' i,~ , , ,..- x n.'!'..i.,:..:' .,,-....,m ..... ~ ...:. ... '::'"' .i !.".: ,."':'7 '" "' .... : .... .~ ,.'.' .... ,%.-.'Z-, ~' ~"r I.:? ... ,..- ~ ,....'-, ,:,.n .... ?.-' ,.'iT T ,? '-, r _. -' ,:,,, E)'T' T ~.- 2U-- i. 5-~ !]TI S '" ;"'"' '-'" ~qT ]:,? .-;. ". 4'_ _, ":",: · ~-' ' '~'~' T ? ~;, v -' (~: ;..., T'., ,..- · ");; .... ,-.; ..'. X' "~ T 'T ~ ~:...'.: :., r.'~ ,~.' .,.,,... ~,:.. t, ... , .... ;",!.I...i-.-:' j r',-~-'r ','7 '..-'~ ....~ ;..: '. .;. ~..* .:.:-."' '::.; ..... ; ,.'::"- ..... ;-'. T I ,.> '"' '" - .... ?~ ."; -~" .!..',.'.' ' -'-. - nT]'S 2 X .... ; ......... 2 X--- .i ~x .,--~ ~ -.,- ;, .::, ... ! .!. t..· ..... ..;. F{i I ,..'..:,:::', .... ~ ,. .... ; .... .... , -' ... [.,, ~ r.:.'[,~I ~'3 .... '2?---E:S . !,:HF' -' --',"'~ :"; I{': I-.I f..' i (:;'T' I C 0 2 "' 2: ,' ... _ '" ' (') 3-" '2 7 '-' ?, :'5 F' F.: IT F' F [) F: F' R,q C ,..! (::I !:'. o, ,, ~, ,.':, .... ,:. ,' :'" ::D...' F' "T', 't"~ ! !!~'I N G F' 0 I:;: F' F;: r::~ [': C.'",-';2'--2 ,-' ~"~'~' ' .... ,:::. .... ~'1!',' I"[ ~S, 3-.. ~ ?-95 ' F:'~.,'I...I - ,3 3 -.. :..:'. ~ -- ~"~ ~,~!IF:CE W~'~TEF..' H~.:.:~,..I 03 .... i 6..--.::,'"'=.; RL/N GI..V ' ,:. . . ¢, 7,- -' -' ';'~'..- .,.. , ; .... ~:...;- l.:.'.Uh! r...-..1-.V' ,.:. ,?-.,, ~ ....'.:, ~ o='. ~' T:, ~ ...... "' ;:.' ..:' ~ .2"' I 0S.-.25--..°.,=.;.F ~.:,!.-~ F 0~:-.-''> '~'--~='. 'F' t'! "" .... · ,.: .~...~ ,:_,_:. 03-t/'' '"'~ OFEr~ ' C. ~ . ;.., .... o.., ' '~ ' ""~.'-'~ND/,~'F(:;TIC [;I-IF'( IN]:T:[PiL ~ · ,,~..~' ~ ,,.. , ·. ..... , , ~, ~ -.- i;-;""n'='':...,. F' F:E F' . FOR 'C. ' ."-':.' i;:, N ~::, ,.' ~' '"' 'F,"a T .T. C, B I:.I ~:-"' C, .!'-. .... f 7 -:. :g .5,S.' T ;..t.i T I C h H F'/' C ' ,? ;-'.'i N I) [)N L Y G3- i '" ~'~ · , "'"" · :., - ?_;.F' F: E F' r..- 0 F:: I.. R ;.., C OS-'2/",- ""~ _. ,:-.,/i,,UN ....c:,., F:'t ll...~ ~'.,",,' ' .... ' '; '~.'; l ....... ~... ~3--i D - :'--l: "-'_.., F' '~.:.-,' ~ ~.. c:, 2 -- '" "" '"":'"' F:' ~.:' ~ t . . 4.: 7 -' C.' ..? .'..' ;.. t:'., '.'T ._ ';, ~.."~ ._ ~ m ~ F' '" ,,'-.~! ?j .... ;.., ............... ;. ..... ~. [...'. F: ,$71.; F: v E Y O ~ -- "" E:..' .... ~"'"'- '· ;~.~T; r.:,r~l~ ....... .:::, ~ ~.'t.'i ' ,?F'~, -~.... , ,.., .... ... ... ARCO Alaska, !nc.is a Subsidiary of AtlanlicRichfieldCompany 0. ..,nA~;'~=,::..: _ Oil & Gas Cons· , "~ ,- t, I ~ ~ .. ,'. ,.:. · ~'" ~" ~ I. 1' C: t~F. · ,~ , ..... t,. r, U N 19 ~'~ '~ '1 'l , ~ · i ,'~" ~ STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION C~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL r~ OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, 14. Location of Well SURFACE LOCATION' 112' T11N, RgE, UM ALASKA 99510 FWL, 1888' FSL, Sec. 8, 7. Permit No. 84-91 8. APl Number 50- 029-21128 9. Unit or Lease Name KUPARUK RIVER UN I T 5. Elevation in feet (indicate KB, DF, etc.) 78' (RKB)114' 12. Lease Designation and Serial No. L25655 ALK 2581 10. Well Number 2V-8A 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER O I L Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Conversion of wells on D.S. 2A provided adequate injection capacity and made it unnecessary.to convert D.S. 2V-8A to an injector. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ - Tit~e OPERAT IONS COORD ! NATOR The space below for Commission use Conditions of Approval, if any: Approved by_ By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 __ ~1 ''(~,lk~lll~t [~rte'~ in ARCO Alaska, Post Offic Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/17/85 Transmittal No: 4981 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. ~' 100360 --~orage, AK 99510 · . ~ /T~z~nsmitted herewith are the following items. Please acknowledge receipt '"and return one signed copy of this transmittal. OTIS PBU SURVEYS 2w-8-A' 1/08/85 1B-7 .... 12/14/84 2F-12 1/06/85 2F-5~ 1/02/85 2W-§ J~. 1/07/85 W-6 '~' 1/07/85 , w-7--' 1/07/85 i lA-1~' 12/31/84 1A-1 ~.~ 12/15/84 lA-1 12/23/84 G-5 ..... 12/25/84 2F-3~ -12/31/84 2V-8A~-- 12/16/84 2B-10 ' 12/17/84 1Y-9-~ 12/20/84 2F-2 ~ 12/29./84 2F-15~' 1/05/85 2F-14- 1/04/85 2F-9 '~ 1/02/85 2~-8~ 1/01/85 API 02 9-21228 '029-2D616 029-21097 029-21073 029-21220' 029-05900 -- 029-20908 02 9-211.9.8. 029-21084 029-20935 02 9-2 029-23 063 02 9-21048 029-23 090 029-21077 CAMCO PBU SURVEYS 1E-12 -"' 12/14, 16/84 /cat Receipt Acknowledged: B. Currier DISTRIBUTION Drilling W. Pasher Date:~daska 0il ~< ~s Co,~ cn,,mis~cs Anchora~ State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. 3. Rat~mell Well Files ARCO Alaska. Inc. it a subsidiary of AtlantlcRichfieldComDart¥ ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 18, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupin'e Drive Anchorage, AK 99501 Commi ssi on Dear Mr. Chatterton- Attached is our notice of intention to convert Kuparuk well 2V-8A. If you have any questions, please call me at 263-4253. Field Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RF_-CF.. IVED AN 1 8 lg85 Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ STATE OF ALASKA ALASKA (~- AND GAS CONSERVATION CO,vIMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-91 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21128 OTHER [] 4. Location of Well SURFACE LOCATION' T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) _ 78' (RKB~ll4' 12. 112' FWL, 1888' FSL, Sec. 8, 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2V-8A 11. Field and Pool KUPARUK RIVER 6. Lease Designation and Serial No. KU P A R U K R I V E R ADL25655 Al K 25R1 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data FIELD OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other . )~]] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that Kuparuk well 2V-8A be converted from a producer to a gas injection well. The well has produced from both the "A" and "C" sands. For injection however, the "A" sand will be blanked off and injection will be in the "C" sand only. ANTICIPATED START DATE- January 21, 1985. ECEIVED 1985 ~S GOrrlmissJorl 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed __ Title OPERATIONS C00RDINATOR The space below for Commission use Date 1/18/85 Conditions of Approval, if any: Approved by Approved CoF7 Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO AlaSka, Post Office ~'ox ,00360 Anchorage, Alaska 99510 TelephOne 907 276 1215 January 2, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2V-8A Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L33 Enclosures RECEIVED JAN 0 9 1985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~/---,,~ STATE OF ALASKA --,~. "' ALASK, ~ .~NDGASCONSERVATION, j~, ,'ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-91 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21128 4. Location of well at surface 9. Unit or Lease Name 1884' FSL, 112' FWL, Sec.8, TllN, RgE, UM Kuparuk River Unit At Top Producing Interval LOCATIONS! 10. Well Number 1436' FSL, 1284' FWL, Sec.17, TllN, RgE, UM VERIFIED ! 2V-SA At Total Depth Surf. f ] 11. Field and Pool 1029' FSL, 1346' FWL, Sec.17, T11N, RgE, UM B.H._~.,- I Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ' ~ Kuparuk River 0i 1 Pool 113' RKBI ADL 25655, ALK 2581 12. Date Spudded07/13/84 13' Date T'D' Reac'hed07/23/84 14' Date C°mp" Susp' °r Aband' 115' water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns09/13/84 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9050'MD,6277'TVD 8951 'MD,6204'TVD YES [~ NO []I 1943 feet MD 1500' (approx) 22. Type EleCtric or Other Logs Run D IL/SFL/GR/SP, FDC/CNL, Cal, BHCS/GR~ CBL/VDL/GR/CCL, G),ro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE . TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 220 -~x Cold -~"-t II 9-5/8" 36.0# J-55 Surf 3668' 12-1/4" 800 sx CS III & 500 sx CS II 7" 26.0# J-55 Surf 9034' 8-1/2" 550 sx Class G & :250 s~ CS I 24. Perforations open to Production (MD+TV.D of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8628' - 8678' ' w/4 spf, 90° phasing 3-1/2" 8542' R2R~' ~ R~IR' 8586' - 8612' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8466' - 8488' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8446' - 8466' 8514' - 8515' 200 sx Class G 27. N/A PRODUCTION TEST Date First Production I Method of Operation (FlOwing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow 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. None RF_CEIVED ,JAN 0 9 ]985 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 GRU3/WC28 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8445' 5834' Base Upper Sand 8480' 5858' Top Lower Sand 8569' 5923' N/A Base Lower Sand 8742' 6050' 31. LIST OF ATTACHMENTS Well History.. Workover Well History; GvroscoDic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (_.~,/'f3~,,~}(.~,; .~ ~.! !L,,' / ..t..' ~/L- Title Assec,.' ~te Eng,.' ?.eer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Auth. or W.O...n~ AFE 702676 Nabors 26-E ~ Slope Borough Alaska ell no. #25655 / 2V-SA l Title Drill, Complete & Perforate Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and'd'e'pth as of 8:0~ e,m, ID~, 7/13/84 Complete record for each day reported IHour 0200 Hrs. IARCO W.I. · 56 24% IPrlor etatus If a W.O, 7/13/84 7/14/84 thru 7/16/84 7/17/84 7/18/84 7/19/84 16" @ 110' 200' (96'), PUMWD Wt. 9.1, PV 12, YP 58, PH 9.5, WL 16.2, Sol 6 Accept rig @ 10:00, 7/12/84. NU diverter sys. Spud well @ 0200 hfs, 7/13/84. Drl 1~¼" hole to 200'. 16" @ 110' 3680' (3480'), Prep to' rn 9-5/8" Wt. 9.7, PV 24, YP 20, PH 8.5, WL 10, Sol 14 Drl, DD & surv 12¼" hole to 3680', 20 std short trip, C&C, POOH, LD BHA. 263', 3-1/2°,'S14E, 262.97 TVD, 1.92, 1.91N, .23E 657', 21.5°, S14.5E, 646.96 TVD, 83.96, 81.41N, 20.90E 1112', 38.6°, S12.5E, 1039.03 TVD, 311.91, 304.51S, 67.67E 2506', 50.6°, S12.5E, 1995.60 TVD, 1323.00, 1288.48S, 302.30E 3630', 51.7°, Sll.5E, 2695.83 TVD, 2202.08, 2148.53S, 484.29E 9-5/8" @ 3668' 3680' (0'), NU BOPE Wt. 10.0, PV 16, YP 8, PH 9.5, WLNC, Sol 14 RU & rn 93 its, 9-5/8", 36#, HF-ERW J-55 BTC csg w/FC @ 3586', FS @ 3667'. cmt w/800 sx CS III @ 12.2 ppg, followed w/500 sx CS II @-:!5,Q..PPg:, DisPl using rig pmp. Bump plug. CIP @ 1630 hrs, 7/: i:~:iva~ter, NU BOPE. -5/8!~;i~3 .6~.!:~:~::7~' 3885~::(~7:~}:;!! ~[a v/~avi-Drl ~. 8.9, ?V 11, ¥~ 7, ?~ 10.5, ~ 25, Sol 4 ~st BO~; O[. ~[H, tag ~C @ 3582', tst esg to 1500 psi. DO ~C, F$ + 10' new hole. Condue~ leak-off tst to 12.5 ppg EI~. Dr1 & surv 8½" hole to 3885'. 3739', 51.5°, S13[, 2763.54 ~V]::), 2287.50 VS, 2232.015, 502.41[ 9-5/8" @ 3668' 6417' (2532'), Drlg Wt. 9.1+, PV 10, YP 7, PH 10, WL 10, Sol 4 Drl & surv 8½" hole to 6417'. 3912', 53.7°, Sl0.5E, 2868.61TVD, 2424.94VS, 2366.56S, 530.40E 4380', 49.4°, S13.5E, 3165.81TVD, 2786.11VS, 2718.72S, 610.91E 5008', 50.3°, S14.5E, 3571.36 TVD, 3265.27VS, 3184.46S, 724.89E 6108'; 49 9°,'S12.5E, 4276.63 TVD, 4109 18VS, 4007.80S; 91 1985 The above is correct Alaska Oil & Gas Cons. Commission r'..~ui~ulage Date Title 7/20/84 J Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing coring, or peHorating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores, Work performed by Produc ng Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string la set, Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IState Alaska North Slope Borough Alaska Field ILease or Unit IWell no. Kuparuk River I ADL #25655 I 2V-8A 7/20/84 7/21/84 thru 7/23/84 7/24/84 Date and depth as of 8:00 a.m. Complete record for each day while drilling or workover in progress 9-5/8" @ 3668' 8290' (1873'), Prep to POOH Wt. 9.1+, PV 8, YP 6, PH 10, WL 12.4, Sol 5 Drl & surv 8½" hole to 8290'. 6421', 49.7°, Sll.5E, 4478.65 TVD, 4348.25 VS, 4241.64S, 960.42E 7080', 49.0°, Sll.5E, 4906.50 TVD, 4849.47 VS, 4731.92S, 1064.63E 7402', 50.1°, Sll.5E, 5115.41TVD, 5094.50 VS, 4972.03S, 1113.48E 7832', 48.8°, S12.5E, 5397.92 TVD, 5418.65 VS, 5289.27S, 1180.12E 8142', 47.9°, S14.5E, 5607.26 TVD, 5653.91VS, 5518.14S, 1235.06E 9-5/8" @ 3668' 9050' (760'), Rn 8½" OHL Wt. 10.3, PV 15, YP 7, PH 10, WL 5.8, Sol 8 Circ& wt up to 10.2+ ppg, POH, rite f/6594'-6499'. Drl & surv f/8289'-9050', 14 std short trip, C&C f/logs. RU & log DIL/SFL/GR/SP f/9049'-3673', FDC/CNL f/9049'-8225', CAL f/9049'-7425', BHC/GR f/9049'-8225'. 8493', 44.3°, S9.5E, 5847.18 TVD, 5903.22 VS, 5762.00S, 1286.90E 8815', 42.7°, S9.5E, 6080.98 TVD, 6124.71VS, 5980.61S, 1323.48E 8990', 42.1°, S6.5E, 6209.98 TVD, 6242.47 VS, 6097.46S, 1339.90E 9050', 42.1°, S6.5E, 6254.50 TVD, 6282.53 VS, 6137.43S, 1344.46E 9-5/8" @ 3668' 9050' (0'), RIH w/7" csg Wt. 10.3, PV 15, YP 7, PH 10, WL 6, Sol 8 Log BHC f/9049'-8225'. RIH w/bit, tag fill @ 9024', wsh &rm to 9050', C&C, POOH. RU to rn 7". The above is correct see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate [ Title 8/07/84 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Inetmactions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Rel3ert" should be submitted also when operations are..suN3~ended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representatt've-,teat data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish Lease or Unit Title IAccounting State cost center code Alaska Field Alaska North Slope Borough Kuparuk River ADL #25655 Well no. 2V-8A Auth. or W.O. no. AFE 702676 Drill· Complete & Perforate Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Spudded Date Date and depth as of 8:00 a.m. Complete record for each day reported 7/25/84 7/13/84 Iotal number of wells (active or inactive) on this, cst center prior to plugging and I bandonment of this well our I Prlor status if a W.O. 0200 Hrs. I Old TD Released rig 2000 Hrs. 7" @ 9034' 8951' PBTD, (0'), RR 10.3 ppg NaCl/NaBr Rn 232 its, 7" 26# J-55 HF-ERW csg w/FS @ 9034' FC @ 8951' · · · Cmt w/550 sx Cl "G" w/3% KC1, .7% D-19, .7% D-31 & 1% D-6. C.~P @ 1103 hrs, 7/24/84. ND BOPE. Instl & tst packoff to 3000 psi. Arctic Pak w/250 sx CS I. RR @ 2000 hrs, 7/24/84. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data NewTD 9050I (7/23/84) Cate 7/24/84 PB Depth Kind of rig Type completi~ (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands RECEIVED 0 9 3985 Alus~'a 0111 & ~,~-~s Cons. Commission" ' 895 Rotary Well no. Date Reservoir Producing .Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P'. ' C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct IOate 8/07/84 ITM Drilling Superintendent ~011 ami-Ga~ Company Well History - Initial Report - Dally Prelim and lubmlt the "lldtlll RM~II" on the flint Wednesday efts, a well is spudded or workover operations ere started. Dally wo~ prior tO Sledding ~hould be summarized on the form giving Inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 702676 ICounty, pari~h or borough North Slope Borough [Laa~e ADL t/25655 or Unit ITitle Comp 1 e t io~1 State Alaska IWell no. 2V-SA Roll' n t/4 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate IH°ur Completion 9/01/84 Date and depth as of 8:00 a.m. 9/o[/84 thru 9/04/84 9105184 9/06/84 The above is correct 9/07/84 thru 9/10/84 Signature ~ For form preparation II~d d~atribuflon, see Procedures Manure, Section 10, Drilling, Pages 86 and 87. Complete record for each day reported 2300 Hrs. ^.co w.,. 56.24% IPr or status If a W.O. 7" @ 8937' 10.3 Cont pkr, 9035' PBTD, Tst'g DP string @ 8320' NaCl/NaBr tst'g DP every 1200', POOH, LD R-3 pkr. tst ea std DP, lk'g f/leak. RIH w/7" Champ IDate 9/Zb/84 I Title 7" @ 9035' 8937' PBTD, Perf'g 10.3 NaC1/NaBr Cont tst'g DP f/leak; no leak found, POOH, LD Champ pkr. TIH w/stinger, sting into cmt retnr @ 8336'. M&P 200 sx C1 "G" cmt w/.5% CFR-2, .3% Haled-24 & 5% KC1. Displ cmt w/45 bbls, 10.3 ppg brine. Sqz cmt thru perfs w/final sqz @ 1/4 BPM w/3000 psi. Sqz cmt in place @ 0730 hrs, 9/7/84. Rev circ to cln DP, POOH, LD stinger. RU to rn 3½" DP, RIH, tag retnr @ 8337', DO retnr & cmt, drl EZSV retnr @ 8337', drl cmt f/8341'-8536', circ hole cln. TsC sqz cmt & csg to 1500 psi; OK. Wsh & RIH f/8536'-8594', POH. RIH w/3½" DP to 8937', rev circ hole cln, POOH, LD DP. RU Schl, rn CBL/VDL/GR/CCL f/8950'-7980'. RU perf guns, RIH, perf w/4", 4 SPF/90° phasing, f/8658'-8678', 8638'-8658', 8628'-8638', 8602'-8612'. RECEIVED JAN 0 9 ]g85 AI~-~.- ~.. . .... Dna ull & Gas ~P99 ~';~!$a~u. Drilling SupeaSnCendefi~ ..... 7" @ 9034' 8937' PBTD, RIH, tst'g DP 10.3 NaCl/NaBr Fin rev circ hole cln, POOH, LD boot bskts & bit. RIH w/retnr, set @ 8336' DPM. Sting into retnr, est IR into perfs @ 8514'-8515' @ 3 BPM/2500 psi, rat's on ann. Press up on back side, press inc'd on DP. Unsting f/retnr, press up on top of retnr @ 2500 psi; OK. Sting back into recnr, pmp dn DP, rat's on ann. POOH, lk'g w/wshout in DP. LD setting tl & ~tinger. RIH w/Bkr R-3 pkr, tst'g DP every 1200'. 8937' PBTD, Circ 10.3 NaCl/NaBr Accept ri~. @ 2300 hrs, 9/1/84. ND tree, NU & tst BOPE. RU & rn GR/JB to 8700'. RIH w/4" csg gun, perf 8514'-8515' @ 4 SPF. RIH w/EZSV, set same @ 8500'. RIH w/EZSV stinger, tag top of retnr @ 8489' DPM, unable to sting into retnr. PU BHA, RIH, tag retnr @ 8489' DPM, drl up retnr, psh retnr to 8937' DPM, rev circ. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold, "Final Rel~ort" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. t Accounting cost center code District County or Parish State Alaska North Slope Borough Alaska Field Lease or Unit 1 Well no. Kuparuk River ADL #25655 I 2V-8A Auth, or W.O. no. T tie AFE 702676 Completion Roll'n #4 Operator 1A.R.Co. W.I. ARCO Alaska, Inc. t 56.24% Spudded or W.O. begun I Date Complet ion J 9 / 01 / 84 Date and depth as of 8:00 a.m. 9/11/84 9/12/84 9/13/84 Complete record for each day reported Iotal number of wells (active or inactive) on this i ost center prior to plugging and I bandonment of this well I our I Prior status if a W,O, I 2300 Hrs. 7" @ 9035' 8937' PBTD, RIH w/3½" compl string 10.3 NaC1/NaBr Perf 8602'-8612', 8596'-8606', 8606'-8612', 8586'-8596' @ 4 SPF/90° phasing. Perf 8466'-8488', 8446'-8466' w/5", 12 SPF/120° phasing. RIH w/6.109" gage ring/JB/CCL f/8946'-surf, POH. RIH w/FB-1 pkr, set @ 8518' WLM. RIH w/3½", 9.3#, J-55 EUE 8RD AB MOD compl string. 7" @ 9035' 8937' PBTD, MIRU slickln unit 10.3 NaC1/NaBr Cont RIH, PU 264 jts, 3½", 9.3#, J-55 EUE 8RD AB MOD tbg, space out & ind. ND BOPE, NU & tst tree; OK. Prep to MIRU slickln unit to set std'g vlv in "D" nipple to displ well. 7" @ 9035' 8937' PBTD, RR Crude NU lub & tst to 2500 psi. 8535', tst tbg to 1000 psi. followed by 288 bbls crude. @ 0400 hfs, 9/13/84. RIH, set std'g vlv in "D" nipple @ Displ well w/30 bbls diesel, RIH, fsh st'd vlv. Set BPV. RR Old TD New TD 9050' (7/23/84) ReleaseQ rig 0400 Hrs. Date 9/13/84 Ps 0epth 8937 ' K nd of r g Rotary Classifications (oil, gas, etc.) Oil Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk River Potential test data Well no, Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature .~_~~~ I Date JTitle For form preparati .... d ~is~rib~ion, see Procedures Manual, Section 10, Drilling. Pages 86 and 87. Drilling Superintendent S UB-$ URFA CE DIRECTIONAL SURVEY ~-~ UIDANCE r~ ONTINUOUS ~'-~ OOL Company Well Name Field/Location ATLANTIC RICHFIELD COMPANY 2V-8A KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 69417 Locjfled By: LESNIE Date 1-AUG-84 Computed BI/: R. KRUt~ELL GC1' r)~R~CTIONAL SdRVEI At~CU AI,AS~A Ii,C, ~V-~A KUPARUK rtOR'lH Sb{lFE, ALASKA SORYEt' DATE: 1 AUGUST 1984 KN(;xNEER: L~SNI~ ~ETiinos OF COMPuTATIDN TOOL LOCATION: TA~GFNTIAb- averaqeu aevlation and azimuth I,~T~RPDLATIuN: I.,INEA~ ! - . VErTICAl, SkCTION: Hf]RIZOi~TAI, DISTAt~CE PROJ~C£ED ONTf} AN AZIMUTH UF $OU'fH 1! DE:~ 40 MIN EAST GC? D1R~R~IDNAL CIJ6TU~kR ARCO ALASKA IRC, 2V-~A KUPARUK NORi'H 8DOP}:~, ALA$1',,A M~THOD$ O~= CO,qPUTATIOi~ TUO~ DOCAXIUN; TANG~i~TIAh- ~veraged oevl~tzon ~n~ dzlmutD INTgRPObATION; LINNAR ARCO AbA~KA 1NC, 2V-SA KUPARUK hOkTH SbOPE, AbASKA TRUK SUB-SEA COURS~ MEASURED VEHTICAL VERTICAb DEVIATION AZiMUT~ DEPTH DEPTti D~PTH DEG MIN DEG MIt~ 0 O0 O.O0 -113,00 0 0 100 O0 100'00 '13.00 200 O0 200,00 ~7 O0 0 300 O0 299,91 186 91 4 18 400 OU 399,22 2~6 22 8 29 500 00 497.44 3~4 44 13 2? 600 00 593.72 4~0,72 17 4~ 700 O0 687 54 514.54 23 0 800 O0 777:97 604,g7 26 59 900 O0 ~65,97 752.97 29 39 1000 O0 950,91 8&7,91 34 17 1]00 O0 1031,1~ 918,12 38 23 1200 O0 1108,99 995,59 40 6 1300 O0 1183,03 1070,03 43 59 1400 O0 1253,16 l140,1b 46 15 500 O0 1321,25 l~08,Yb 47 34 600 O0 1389,34 1276,34 46 18 1700 O0 1458.02 1345,6240 11 1800 O0 15~8,10 1415.10 45 59 1900 O0 1597,13 14u4,13 40 47 2000 O0 lb6b,13 1552,13 47 26 2~00 O0 1732,39 16~,39 47 5~ 2200 O0 179B,~.3 1685,83 48 40 2300 O0 1864.59 1751,59 49 5 2400 O0 19~9,';0 1816,70 49 39 2500 O0 199t 06 18~1.00 50 11 2600 O0 2057192 19%4.92 50 20 2700 O0 2121.b7 200H'57 50 40 2800 O0 ~184.67 2071.67 51 5 2900 O0 2247,03 2134,03 51 3000.00 230~,02 2195,82 51 51 3100,00 237U,39 22~7,39 52 9 3200.00 2432.1B 2319,18 51 3300 O0 2494,t5 23dl,75 5.[ 3 3400'00. 2557.81 2444,81 50 36 3500 O0 2621,3.3 250~.33 50 36 3600 O0 2084,b2 2571,52 51 4 3700 OD 2747,10 2634,10 51 25 3800 OO 280~,b9 2695 69 52 35 3900 Ob 2~68.~0 2765~00 53 23 COMPUTA'rION DATE: 4 bEPTEMDEA PAGE 1 DATE OF SURVEY: 1AUGU$~ 1984 KELLY BUSHING EbEVATION~ 113,00 F~ · ~NGINEERI bE~NIE iNT~hPULA'PED Vat, UE~ Fha EVEN 100 FEE~ OF' MLA~UEE~ DEPTH VC:R'£ICA6 OOGLEG RECTANGU6AR COORDINATES HURI~, D~PARTUR~ 6ECTION S~V~RIT~ NORTH/SOUTH EAST/W~ST D18~,!. A~IHU~H' ' FEET DEG/IO0 FEET F~:ET F~ET DEG MIN N O 0 E 0,00 0,00 O,O0 N O,OO E N 71 23 W -0,19 0,i5 0,14 N 0,26 W 0 S 11 25 W 0,11 1,26 0,25 S O.b3 W 0 S 13 57 E 3.64 b 90 3,76 S 0.16 W 3 S 17 51 E 15,17 3~40 14,81S 3,29 E 15 S 14 47 E 33,74 5,37 32,b9 S 8,bO E 33 S 1.~ 8 E . 00,64 3,91 58,79 S 1.5,10 E 60 S 12 31E 95,13 0,15 92,35 S 23,14 E 9~ S 9 36 E 137,77 3 22 134.25 S 31,11 E 137 S 8 b3 E 185,18 3:24 181,12 S 38,b1 E 185 S 9 28 E 237.85 4 94 S 10 4 F 297 49 2:29 S 9 57 E 360169 2.57 $ 9 5 E 427,3B 4,12 $ 11 48 E 498,60 3'71 S 14 5 E 571,80 0,58 S ~3 36 E 644,98 1.17 S 13 44 ~ 717,0b O.13 S 14 0 E 788,93 0.50 S 14 0 E 861,23 0.99 13 59 g 934.50 1.3 55 E 1008,44 13 35 E 1083,13 13 11 E 1158,45 12 59 E 1234.32 12 54 E 1310,B4 12 42 E 13~7,7~ 12 22 E 1464,90 12 In E 1542,4U 12 0 E 1620.6b S 11 32 ~ 1699,27 S 11 ZB E 1778.07 S 11 21 E 1856.70 S 1i 3 E 1934,70 S lO 38 E 2012,31 S lO 11 E 20~9.50 S 9 59 E 2166,98 S 9 50 E 22~4.g~ S 9 ~ E 2323,66 $ 9 37 F 2403.~2 0,48 0,74 0,54 0,68 0,09 0,40 0,'19 0,62 0,67 0.17 1,25 0.39 0,57 0.81 1,28 0,35 291,99 S 57,04 g '297.51 S 11 3 E 354,21S 6U.30 E 360'74 $ 10 54 E 42~,01S 79,44 E 427,46 $ 10 42 E 490.24 $ 91.55 E 498,72 S 10 34 E 561,47 S 108,54 E 571,86 S 10 56 E 632 54 S 12b,20 E 045,01 S 11 lb E 702,b2 S 143,22 E 717,U6 a 11 7?2,43 $ 160,49 E 788 93 ~ 11 44 E ~42,64 $ 17~,00 E 861:23 ~ 11 55 E 913,'/8 S 195,72 E 934,bl S 12 b E 98b,59 S 213,00 g 1008,47 6 12 13 E 1058,18 S 231,37 E 1083.18 S 12 20 E 1131,48 S 24U,80 E 1158,51 S 12 24 E 120b,39 S 26b.01 E 1234.39 6 12 26 E 1279,99 S 283,14 E 1310.93 135~,02 S 300 25 E 1387,89 1430,32 S 316193 E 1465,01 S 12 29 / ~bOU,lo S 333~54 E 1§42,~9 lbB2,51 S 350,07 E 1620,76 lbbg,4~ 6 360.09 r 1699.38 S 12 26 E 1'i30,70 S 3BI.bO E 177~.17 6 12 23 E 1~13,7b S 397,38 E 1856,79 S 12 21E lb90,2~ S 412,55 E 193~,78 S 12 18 E 19b0.~7 S 427,33 E 2012,37 ~ 12 15 E 2042.45 S 441,17 E ~089,~5 S 12 11 6 2195.b9 S 4~,14 E224~,9b S 12 2 ~ 2273,2] S 481,55 E 2323,67 ~ 11 57 E ARCO AbASKA INC, 2V-BA KUPAEUK NOETH SLOPE~ ALAbKA DATE UF SUkVEXt 1 AUGUST 1.984 K~LBY BUSHING EbEVATION~ 11~OO iNTEAPULAT~,D VA[,UM~ FOR mVEN 1uO F~FI' oF M~AMURED UE~TH TRUE SUH-~A CflOR~F] M~A~URED VERTICAL V~R~TCA~ DEVIATION AZIMUTi~ DEPTH DEPTH D~PTU OEO NIN DES Nih 4100:00 2991 ~2 2~:u~ 49 5~ 4200,00 3055~7 2943,87 49 14 4300,00 3122,23 3009.23 49 8 45 00.00 3253.20 3~40~20 49 6 4600,00 3318,46 3205.45 49 14 4700,00 3383.55 3270 55 49 ~0 4800,00 3448 32 3335:,2 '49 44 00,00 3512:79 3399.79 49 58 49 5000,00 5100,00 5200,00 5300,00 5400,00 5500,00 5600,00 5700,00 5800.00 5900,00 3577.08 34o4.08 50 3 :3041,27 3528,27 50 3 3705,3~ 3592,38 50 11 3769,23 3656,23 50 27 3832,98 3719,98 50 0 3897,96 3784,96 49 1~ 3963,06 3850.06 49 29 4027'93 3914,93 49 35 4092' 71 3979.71 49 43 4157,25 4044.25 49 56 b000 Ob 4221,~4 4108.54 49 55 6100 O0 4285,07 4173,07 49 41 6~00 O0 4~50,87 4237,87 49 29 6300 00 441~,04 4303,04 49 14 6400 00 4481,~8 4368,1~ 49 27 6500 O0 4545,13 4433,13 49 33 6600 O0 4611,07 4495.07 49 22 6700:00 4~76,~6 4563.36 49 11 6800,00 4741.~9 4628,59 49 30 6900,00 4807,08 4694.08 48 52 7000 OU 4872,~6 4'159,85 48 ~8 7100 Ou 493~,59 4825,59 48 5] 7200 O0 5004,25 4H91,25 49 4 7300 O0 5069,bl 4956,61 49 27 7400 O0 5134,%0 502~,40 49 44 7500 O0 519~.~5 5006.]5 48 47 7600:00 5265,68 5152'68 48 16 7700,00 5332,4~ 5219.43 48 4 800,00 5398,88 5285,88 48 25 ~900,00 5465,19 5352.19 48 26 VERTICAL DOGLEG AECTANG~ibAK COURDINATEM t~URIZ, D~PARTUEE SECTION S~VgRIT~ NORTH/~OOTH ~AMT/WES~ D~MT, A~IMUTH FE~;T I)EC;/IO0 FEET FEFT FEET DgG SiN $ lu 27 E 24~3.21 S 11 39 E 2551.12 $ !1 56 E 26]7,07 S !1 5~ E 2712,75 $ 12 ~ E 27~8,36 S 12 19 E 28~3.90 S 12 31 F 2939°67 S 12 44 E 3015,58 S 12 42 M 3091.75 S 12 40 E 3158.19 1 ~9 0,15 o,bl U,lO 0,55 0,36 0,14 0,49 2430,55 S 50~,~5 E 2~83 2507,0] $ 523,57 g 2561 2581,34 $ 539 26 E 2537 2555,~9 S 554:92 E 2712 2729,33 $ 570,70 E 2788 2~03,15 586,76 E 2863 2~77,15 $ b03,00 ~ 2939 2951,23 S 61~,53 E 3015 3025,54 S 535,42 E 309! 3~00,~3 $ 653,19 E 3168 S 12 40 E 3244.7~ S 12 42 E 3321.45 S 12 44 E 3398.17 S 12 a3 F 3475.13 $ 12 4 g 3552,17 S 10 28 E 3628,17 S 10 32 E 3704.06 $ 10 45 F 37~0,15 S 10 49 ~ 3856.31 S ~0 5~ E 39]2.69 u 20 0:03 0,21 0,33 2,38 0,24 0,30 0,40 0,33 O,bO 3174,05 $ 570,02 E 3244,78 5 11 55 E 3249,06 $ 58b'85 E 3J21,46 S 11 55 E 332~,52 S 7o3'75' E 3398,19' ~ 11 57 E 3399,59 S 720.72 E 3475,~5 5 11 58 E ~474,7~ S 737,5~ E 3552,~9 $ 11 58 E 3624,04 $ 765,82 E 3704,07 S 11 55 E ]o98,84 S 779,85 E 3780,15 5 11 54 E 3773,06 S 794,14 E 3855,32 5 11 53 E 3~48,~7 S 808,56 E 3932,69 S 11 51 g S 11 I F: 4009,28 $ 11 2 E 4085,65 S 11 I E 4161.82 S t0 58 E 4237,65 S 10 b~ F 43i3.52 $ 10 56 E 4389,55 S 10 ~1 E ~455,58 S 10 40 E 4541,32 S 10 37 E 4617.10 $ 10 27 E 4692,65 0,55 0,46 0,20 0,71 0,57 0,42 0.24 0 28 0,22 3923,~b S ~2~ 19 E 4009,28 8 11 50 E 3998,84 S 837:81 E 4085,66 & 11 49 E 4073,60 S 852,J8 g 4161,82 S 11 49 E. 414~,04 S 856,U9 E 4237,05 S 11 48 E 4222,34 $ ~1,24 E 4315,52 & 11 47 E 297,22 S 895,58 E 4389,55 S 11 46 E 13'11,~ S 910.02 E 4465,59 S 11 45" 4445,29 S 924,16 E 4541,32 ~ 11 44 ~ ff 4520,79 S 938,14 E 4~17,10 $ 11 43 E 4595,0~ $ 951,99 E 4~92.56 $ il 42 E 10 31 r 4757,95 lO 35 g 4843,29 10 39 E 4918,70 1.0 ~(} E 4994,37 lO 43 E 5070,53 !O 27 K 5146,54 10 33 E 5221,3'1 lO 45 E 5295,81 lO bB E 5370,53 11 17 E 5445.37 0,18 u b4 0:33 0.51 0,46 l.b6 O,b3 0,51 0,31 0.59 4669.14 S 965.09 E 4767,9~ 6 11 41 g 4743,22 S 979.51 4~17,35 $ 993,44 E 4918,71 4891,7.{ S 1007,44 P: 4994,39 5 11 38 E 49~0 38 S 1021,59 E 5070,55 ~ 11 37 E 50411X9 $ lO]b,b5 ~ 514o.57 ~ 11 3~ E 5114,91 $ 1049.16 E 5221,40 S 11 35 E 51eS"u~ $ 1062.95 E 5295,~5 ~ 11 34 E b~34~9, S lu91.50 E 5445.42 ~ 11 3 E ARCO 2V-SA KLIPRRU~ D~TE UF SURVEY= [ AUGUST 1984 KEL~ BuS~I~G EbEVA'fION= 113~00 F~ ENGINEER: 6E6NIE IN1;E~PULATED VADuE~ ~O~ EVEN 100 F~E'f UF M~AbU~EO DEPTh TRUE SUB-SEA CObRSW HEA6UAED VERTICAL V£H'IICAb DEVIATION AZIMUTH DEPTH DEPT~ D~PTH DEG ~1~ DEG I~IN VERTICAL DtJ(;LEG HEC'TANGtJLAI~ C[IORDINA'fEa HORI~, DEPAR'~URE SECTION SEVERITY NU~TH/5OUTH EAST/WES~ I) IS~, AZIMU~,H F'E~T DE(;/lOO FEEl' FEET FEET DEG 8000.00 5531.77 5418.77 48 17 8100,00 5598.44 54~5.44 47 52 20 0,00 5005.?9 5552,79 47 34 ]00.00 5733.00 5620,60 47 iO . oo oo O0 O0 6018.94 5905,94 42 57 8800 00 6092.15 5979.15 42 41 8900 00 6165,90 0052'90 42 17 S 11 24 E 5519.99 $ 11 37 E 5594.52 'S 11 46 E 5668.43 S 11 bBE 57%1,93 $ 11 2~ E 5814.84 S 10 13 E 5885 48 S 9 51 E 5953~97 S 9 47 E 0021.94 S 8 42 E b090.00 S ~ J8 E 6157,35 0.93 O,71 2.71 1,55 0.46 1.65 5408,07 $ llOb.lb E 5520 03 ~ 11 33 E 5481,10 S 5555,47 S llJb.O3 E 5068 5025,40 S 1151,16 E 5741 5090.75 $ llbo,Og f 5~14 576~ ~8 $ 1179,24 E 5885 5833~57 $ 1191.16 E 5954 $ 1202.79 E 6022 97 &.Il 33 g 89 $ 11 34 E S 11 32 O1 1 31 ~,, 5900,07 5967.87 5 1213.93 E 6090 29 E 6034,~0 $ 1222.89 E 6157,46 & 11 27 E 9000,00 623V,V4 9050,00 627b,95 6126,94 42 14 blb3,95 42 14 S O 31E 0224,29 $ b jl E o257,75 O.OO u,uO 6101,59 $ 12]0.54 E 6224,44 ~ 11 24 E b134,99 $ 1214.3~ E 6257,93 5 11 22 E CO~POThT&O~ DhTE: 4 SEPTE~DER PAG~ 4 2V-8A KUPARU~ NORTH SLOPL, DATE uF SURVEY: I AUGUST 1984 KELbY BUSHING EhE~ATION: 113,00 ~NGINE~R: 4E~NAE INTEi4POLATED VAI,,oE5 r'D~ ~VEN 1000 FE~T OF MEASURED DEPT TRUE MEASIJEED VERTICAL VERTICAb DEVIATION AZiMOT~ DEPTH DEPTH DLPTH PEG V~RTICAL DOGhEG SECTION SEV~RIT] FEET DEG/IO0 ~ECTANGt{LAR COORDINATE5 HORI~, DEPARTURE F'EE~ K~E~ FEET DEG MAN 0 O0 1000!00 2000 OU 3000.~0 4o00.0 sooo:§o 6000 0 ooo:§o 8000 o 9000,00 0.00 -113,00 0 0 950.9! 8~7,91 34 ~7 1065.13 1557,13 47 8 2308.82 2195,82 51 5! 2929.15 2B16,15 52 5 3577,0B 3464,08 50 ] 422t.54 4108.54 49 55 4872,B6 4759,8~ ~ 48 48 5531,77 541~,77 48 17 6239,94 ~126,96 42 {4 N O 0 fl 0.00 S 9 28 E 237.85 S 13 59 E 934,50 S 11 32 E A699.27 S ~U 27 E 2483,21 S 12 40 F 3244,78 S 11 I E 400g,28 S 10 31E 4~67,95 $ 11 ~4 E 6519,99 $ b 31 E ~224,29 0.00 4,94 O,4B 1,89 0,20 0,55 0,18 0,26 0,00 o.oo N 0.o0 2]J,lb $ 47.08 E 913,7~ S 195,72 E 934~51 S 12 5 1059'48 S 366,09 E 1699,38 ~:12 20 E 243o,55 $ bOb,b5 E 2483,21 3174,85 $ 670,02 E 3923,u6 S 823 19 g 4009,28 1 50 4669,14 S 965~9 f 4';67~96 54o8,07 $ 110~ 16 E 55~0.03 8 ~! 3~ E 6~01.59 $ 1230:64 E 6224,44 ~ ~! 24' E 9050.00 6270,95 0163.95 42 14 S O jl E o257.76 0,00 6134,99 S 1234,36 E 6257,93 ~ 11 22 E ARCO AbASKA LNC. 2V-SA NORTH 5LOPE, ADAbKA T,UK $UB-$~A COORSE MEASURED VERTICAL VERTICAb DEVIATION AZIMUT~i DEPTH bEPT~ D~:PTH DEG MIN bEG ~h 0 O0 13~o0' 113,o0 213,00 313 13 413 94 516 03 620 28 727 02 839 54 C()MPOTATiON DATE: 4 fiKPT~UER PAGE 5 DATE OF 8ORVE~: 1 AUGUST 1984 KELLY BUSHING EbEVATiON~ 113,00 F~ INTEkPULATED VAI..UE~ rOM ~VEN 100 F~ET OF $U~-SLA DEPTH V~R'rICAb DG(;bEG 'RECTANGUbAA COORDINATE5 MOMI[, DEPARTUEE SECTION $~V~RAT~ NOHTH/~OUTH EAST/WEST DIST,~ AZIMUTH FERT DEG/IO0 FEEY F~K~ FEET DEG M~N 0.00 -113,00 0 0 13,00 -t00.00 0 13 133.00 0,00 0 18 100.00 0 51 200,00 5 5 ]00,00 8 58 400,00 14 Il 500,00 18 4 600,00 24 23 700,0U 28 8 N U 0 E 0.00 0.00 0.00 S 65 35 E 0,00 0,00 0,00 ~} 74 16 W '0.22 0.27 0,16 S b 25 W 0.28 1,bO 0.42 $ 15 26 K 4,72 5,90 4,80 $ J'! 46 E 17,27 3,85 15,82 S 14 30 E 37,56 4.30 35.39 S 14 2 E 66,93 4,96 6~,90 S ~1 35 E 106,34 8.36 S 9 10 E 156,08 2,39 152,32 213,00 31.3,00 413,00 513,00 01~,00 713 ~0 813~ 0 S 9 16 E 213,1b 4,79 S 9 45 E 283,27 3,~5 S 9 54 E 364,37 Z,99 $ 9 15 F: 457,~4 3'22 5 14 4 E 562,77 0'38 S 13 36 E 609.62 S 1~ b9 E 7'13,33 0'49 S 1~ O E ~78.18 0,61 $ 15 58 E 9~6.9B 0,43 S 13 29 E 1099,~b 0,72 954,73 913,00 BOO OO 31 58 1076,9b 1013,00 qO0:0O ]7 ~7 1205,74 1113,00 1000,00 40 13 1342,2b ]213,00 1100,00 45 25 1487'76 131J,00 1200,o0 47 38 t~ 17 1413,00 1)00,00 40 8 28 1513,00 1400.00 45 1923 23 1613,00 1500.00 40 ~II 07 1713.00 l~O0,O0 47 49 47 1813,00 1700,00 48 46 S 15 ] F 1214.70 S lZ 52 E 1333,60 S 12 23 E i454.45 S 12 14 E 1577,79 S 11 32 E 1704.58 S 11 23 E 1832.5~ S 11 2 E 1957 25 S lo 12 E 2079~36 S 9 53 F: 2202.3b S 9 43 E 2329,28 2374,24 1913,00 1800,00 49 20 2529,61 2013.00 1900,00 50 16 686,48 2113,00 2000,O0 50 36 845.27 2213,00 2100,00 51 24 3006 7b 2313,00 2200,00 51 53 3169 15 2413.00 2300.00 51 40 329 01 2513,88 ~00 O0 50 5q 486 87 2613, 00:00 50 54 3645 43 2713,00 260o.00 51 16 3807 08 2~13,U0 2700,00 52 40 S lO 6 E 2402.33 S 11 54 F 2585.99 $ 11 57 f: 2702.10 S 12 16 E 2817.53 8 12 50 E 2933,34 S 12 ~3 E 3050.!5 ~ 12 40 ~ 31bH.4b $ 12 ~1 ~ 3~87.69 S 12 44 E 3~07.30 $ 12 32 E 3528.17 3973 60 2913.00 2800.00 52 26 4132 61 3ulJ.O0 2900.o0 49 28 4285 90 3113,00 3000.00 49 10 4438 63 3213.oo 310o,00 4~ 5~ 4591 65 3313,00 3200,00 49 12 4745 42 3413.00 3300.00 49 36 4900.33 3513,0o 3400,00 49 b8 5055,.97 3b13 . OU 3500, O0 50 5 b211,89 3713.00 3bOO,00 50 11 5368,77 3013,00 3700,00 50 21 O,b4 0,20 O,SN O,b7 0,b6 0,94 O,lq 0,40 0,55 1,42 1.72 0,69 0,50 0,29 O,bl 0.14 O,bO 0.14 0,24 0,94 208,'15 2'17.97 u,00 k: 0,00 N 0 0 E 0,00 E O,O0 · N i90 0 E 0,33 W 0,37 N 64 26 0,65 w 0,7.8 '..$:::§7 2 W 0.12 E 4.80 S' 1 23 E 5 93 E 17'27 ~::'~: 3 E 9:46 ~ 37,60' S:14 3~ ~ ) lb b4 E 67,00 43,04 E 213,15 ~ 11 38 E 5~,~0 E 283.29 6 l~ 6 E 35'I,~4 $ b8,94 E 364,~2 S 10 54 E 449,45 S 84,07 E 457,24 S 10 35 E 552,70 $ iOb,]4 E 562,84 ~ 10 5~ ~ bS~ 91S 131.97 E 669,04 fi 11 21E 75'1~29 $ 150,71 E 773,33 S 11 4$ E B59,09 S 1M2oll E 878.18 S 11 58 g 964,75 $ 20~,42 ~ 98~.0! ~ 12 ~1 ~ 1073.07 $ 235.15 E 1099,31 ~ 12 21E 118b,28 $ 261,59 E 1214,78 1302,18 S 28B 22 1420,11S 314:59 E 1454.56 5 12 29 E 1540.60 S 341 06 E 1577,90 S 12 2~ E IO~4,bB S 367~15 E 1'10~,69 ~ 12 2b E 1790,08 ~ 392,~1 1~12,42 S 41,6.87 E 1957,32 20~2,46 ~ 4~9,37 2153,62 S 460,85 E 2202,~B 227~,7'! $ 482,50 E 2329.29 2410.00 S b04,92 E 2462.33 5 11 49 E 2531~3'1 $ b2U,o7 E 2585.99 S 11 47 E 2044,9b $ 552 71E 2702.10 $ 11 48 E 2757,84 S 5'16~88 E 2817.b3 6 11 48 E 2870,98 S bO1 02 E 2933,34 fi 11 50 E 29~4,Nb $ 527~25 E 305U,15 ~ ~1 52 E 31~U 3~ $ ~5~,25 E 315~'45 ~ 11 5] E ~J~3,42 S 705,76 E 3407.31 ~ 11 57 E ~451.3~ s 7]2.37 E 3578,~8 ~ 11 58 ~ COMPUTATION DA'~E: PAGE ARCO AbA~KA INC, 2V-SA NORT~ $I, UPg, AbAbKA DATE OF 8URYEI: 1 AUGUST 1984 KEI,h¥ BOSHIi~G EbEVATION; 113,0o INT'EAPOLATED VA[,UE6 b'O~< bV~;N 100 FEET OF ~UB-~EA DEPTH TRUE SUB-SBA CBUR6E N~A~URED VENTZCAb VgR%ICAb DEVIATION AZimUTH DEPTH DE~T~ D~Pi"H DEG MIN p~ ~Ih VmR'l'ICAb DO(;bEG RECTANGUbA~ COUROINATE8 HOEI~, DEPARTURE ~ECTION SEV~RfT¥ NORTH/SOUTH EA~I"/WES~ D15~',. A[IMUTH * FE~T O~O/lOO F~ET FEEl' FEET DEG ~IN 552] 08 3913.00 BBO0,O0 49 2! 5676 95 4013,00 3900,00 49 35 5831 40. 4113,00 4000,00 49 46 5986 72 4213 O0 4100.00 49 58 6141 60 4313~00 4200,00 49 30 OO 4300,00 49 14 6295 34 441~, . 6448,9~ 4513,00 4400,00 49 29 6602,96 4013,00 4500,00 49 21 6756,08 4713,00 4600,00 49 14 6909,00 4813.00 4700.00 48 52 S 10 29 E 3645.67 S lO 40 E 3702,59 S 10 50 g 3880.28 S ll 1E 3999.11 $ 11 I ~ 4117,]7 S 10 59 E 4234 13 S 10 bi E 4350~73 $ lO bl E 4407,83 S lO 37 E 458,3,77 S 10 27 E 4699,44 0.16 0.48 0,17 0.~1 0,29 O,b8 0,34 0,25 0,34 0.18 3~bb,ol S 755,17 E 3645,69 $"11 57 E 3'7w'7.21 $ 7~8,64 E 3a80,29 $ 11 52 E 4029,9'1S 843:~8 E 4117.37 ~ .. -. E 4144,58 S 866,21E 4234,13 ~i11 48 42~9~09 S 8B8,25 ~ 4350,73 $ 11 46 437~,09 $ 910,44 E 45 ~ 4~,02 S 9~2'00 E 4683,77 ' S 11 43 ~ 4001,75 $ 953,22 ~ 4699,44 S 11 42 ~ 7061 O0 4913,00 4800.00 4~ 58 7213~36 5013,00 4900,00 49 5 5000,00 49 39 5100,00 7366 7520 7670 7821 7971 812] 8269 8415 92 5113,00 63 5213,00 48 34 95 5313,00 5200,00 48 3 9 5413,00 5"{00.00 48 24 0 5513,~0 5400.00 48 1{ 67 5613,00 5500,00 47 45 72 5713.00 5600 O0 47 4 69 5813,00 5700:00 45 3l I0 34 £ ~813.87 10 39 E 4928,80 10 42 E 5045,]1 t0 20 E 5162,02 10 42 E 5274.21 11 3 E 5386.46 11 ~0 E 5498.94 11 38 E bblO 57 !.1 53 E 5719:7j I1 15 E 5826,07 0,50 0,29 0.23 0,04 0.39 0'43 0,32 0,12 2.45 4714,29 $ 974,10 E 4813.88 S 11 40 E 4~27.27 S 995,3! E 4928,81 $ 11 39 E 4941,~0 $ 1016.89 E 5045 34 6 11 37 g 5056.62 $ 103~,44 E 5162 05 S 11 36 E 5166,85 $ 1058,93 E 5274 25 $ 11 34 E 5277,~1 S 10~0,06 E 5356 50 ~ 11 ~4 g 5387.4~ S 11o2,01 g 5498 99 S i1 33 g 6490,81 $ 11W4.31 ~: 5610.~2 ~ 11 ~J E bOO3 09 S 1146.57 g 5719'78 ~ 11 33 ~ 5707:7'/ S 1160.31 E 5826,11 6 11 34 8555 44 591J.uo 5800.00 43 7 8691 88 6013,00 5900.00 42 65 8828 33 6113'00 0000,00 42 33 8963 61 6213,00 0100,00 42 14 9050 O0 6276,9~ 6103,96 42 14 S ~ 58 E 5923.66 S 9 48 E b016,41 $ ~ 4 E b109,14 $ o 31E b199.93 S o 31 E ~26'7.76 1.15 0,59 1,b0 0,00 O.O0 5{~03.77 S 1185.95 E 5923,70 ,5 11 32 E 5096,22 $ 12Ol ~5 f 6016 48 6 11 31 E 5986,84 S 1210:73 E 6109~23 ~ 11 29 E 6077,29 S 1227.76 E 6200.07 ~ 11 25 } 613~,99 S 1234,36 F 6257,93 ~ 11 22 E ARCO AbASKA 1NCo NORTh ~I, UP~, A~A~KA IN'I'.F.,RPULATED VAI,U~:5 ~'D~ CHUSEN HuRIZ[}N,5 MARKFR MgASUR~D DgPTH TVl) B~LOW Kt~ FROM K~ RgB 113.uo 113,00 TOP UPPER 8A,~[) 8445 O0 5833,62 BAfiE tIPPER SAND R48O:UO 5858,4U TOP bOWER fiAND 8569.00 5922,90 PB~D 8951.00 ~203o~b TO~'A~ DEPTH ~P~ILI,~R) ~050,OO b276.gb SUB-S~A 512U,o2 574b,4N 5809.90 6090,06 6163.95 PAG~ 7 K~LLY BUS~]NG E6EVATION; 113,00 F3' SurFACE 6OCATION O~76IN=fiEC" ~TWp. llh RG£, 9E RECTANGUb~R NURTH/$OUTH 0,1~ N 0,33 5752:5 5812,89 592~,9t 5 61 g 0134,99 ~',,"~ I'I l I l iii iI;] i[; [:l i 2V-SA KUPARIIK NOETh ;SLOPE, AI~AiSKA TOP UPPER ~AND BASE UPPER ~AND TOP LOWFR 5AN[) BA~E bOWER SAND TOTAb DEPTH (OAILL~R) COi~PUTATICIN I~ATE; 4 5EPT~M~E~ PAGE DATE OF SURVEY{ 1 AUGUST 1984 KELLY BUSHING F~bEVATION{ 113,00 F2 ~NGINEER~ LESNIE MEASURED DgP'£H TVD RELUW K~ FRU~ KB SUB-S~A 844b,0¢) b83].t>2 5720.b2 8~RO.OO 5858,48 5745,4B 8742,00 6049,~6 5936,b6 905~,U0 o276,9b 6~b3,95 5728 21 5752 485 5812 9 5928 29 g 55 E f~3, E m -?'"~i']i ! ii il)Dll: [;l{ ~:~UHBE~ER' KUPARLIK NORTH SLOPE:, RLASKA TVkl PLOT FROI'I P_.~CT DATA JOB REFERENCE 6941 '7 ......... !,tELL' 2V-3A '~- ' ' -SUP, F^CE LOCAT?-".. ' '.-~-~ ___ ;- i-'...":"' 112' F'WL & FSL -.. .. ~'"'~RIZONTAL PROJECTION -4000 -2CIDO 0 20(~ :W~L$,- -2V-8A SURFACE LOCATION: ' FWL & 1885' FSL I VERTICAL PROJECTION Pt~:NJ[CTION ~ V~RTIa:I. PI.i:IN[ ~F I:t~II~UTH 168 Suggesc~ form to be inserted in each "ACtive" well folder to d~.eck for timoly cc'~liance with our' rc<julations. Ouerato'r~, %9~11 ~an~ ~nd Numker .. Reports 'and Materials to be received by:./~-Z~ -Fy Date Required Date Received Remarks · , · Ccmpletion Report Yes . Well, History, . , Yes · .. _Samples · Core Chips '' ' . Core Description /~~' ' .....~'~ Registered Survey Plat ~e~. ?-'/~-~'9 .~/J~ .~' _ · · .-'~ · Inclination Survey /~/~ · Drill Stun Test Reports /~/~,~~ Logs Run,' Yes .. ARCO Alaska, Inc. r---, Post Office r'-- Anchorage, ,.,..~SKa 99510 Telephone 907 277 5637 Date: 11/27/84 Transmittal No: 4868 RETURN TO: ARCO ALASKA, INC. ~ ATTN: Records Clerk ATO-1115B P.O.. Box 100360 Anchorage, AK 99510 ~/Transmitted herewith, are the followinE items. Please acknowledge receipt and return one signed copy of this transmittal; CBL's/Schlumberger/FINALS · "Variable Density" "GCT/JB/GA" 9/19/84 " " " 9/31/84 ti tl ti It oo Acoustic "VDL/Signature/GR" /cat Receipt Acknowledged: Runl "GCT" 10/07/84 " "GCT" 10/07/84 " "GCT/JB / GA" 9 / 31/84 " "GCT/JB/Ring 9/17/84 " "GA/JB/GCT" 9/19/84 " " 9/!7/84 " "GCT" 7/21/84' " "GCT" 9/21/84 " "GCT/GA/JB" '9/14/84 " " 9/15/84 " · "GCT/JC" 10/12/84 " " lO/15/84 " " 10/12/84 " " ". lO/13/84 " " "GCT/JB/GA" 10/22/84 " " " 10/22/84 " " "JB/GA" 8/19/84 " " " 8/20/84 Run 3 " 9/21/84 Run 1 " "GCT/JB" 10/14/84 Run 1 " " lO/14/84 " " " lO/O5/84 " " "GCT" 10/05/84 " " "Perf 4"~ 9/10/84 Run 2 5 i/2"/PPS/JB" 11/o5/84 B. Currier BPAE Chevron Run 1 DISTRIBUTION · Drilling W. Pasher GeologY~.~ G. Phillips Mobil Phillips Oil 6597 - 8292 '/~B-3/~ 7000 - 8460 ~/2B-!6/ 4950- 7004 '~2B-13v~ 5750,- 8408 ¢2B-14 5700- 7970 'J2B-15/ 5348 - 6824 ~2B-2 7250 - 9182 --2B-4 5055 - 6487 ~B-i¢ 6200 - 7866 ~2D-5~ 6800 - 8954 --2D-6 505~ - 6650 ~2D~7~. 5597 8084 --'2D-'8-/ 5650 - 7951 --2G-9~ 58ao - 8524 49~o - 6765 .~ 2G-10~ 5730 - 7950 5790 - 7814 -- 2G-13~ 5989 - 8624 '~--2G-14~ 865O - 9334 8650 - 9562 ~.~lF-6~ 5692 - 6742 ~lY-5~, 5150 - 7252 4500 - 6550 ~lL-2~' 68oo - 75~8 dL-4~ 7000 8210 --1~3~ 7961 - 8941 6100 - 6992 ~-1E-24 ~ ~a t:e '62"'AK' Sohio Union D & M NSK Ops. J. Rathmell Well Files ARCO Alaska. Inc._.,.,----,,, O'". ~ *:. · -. :..;,'~c:-,c 9.~,7 :'=7 5[37 Transmi'ttal No: 4765 Return To: · . ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B Q/T~a P.O. Box 100360 Anchorage, AK 99510 nsmitted herewith are the following items. Please acknowledge receipt w and return one signed copy of this transmittal. CBL' s FINALS / Schlumberger 2V-8A "Variable Density'' "GCT" 2G-1 /~ " " " 8/01/84 Run 1 8/27/84 " 7400 - 8909 5151 - 7991 8/27/84 " 8/27/84 '" 4275 - 6536 5950 - 8526 8/27/84 " 5070 - 7650 7/31/84 " 6500- 7830 7/30/84 " 7/30/84 " 6100 - 7720 7200 - 8732 2H-15 ~"' " " " · 2H-16 /'' " " " · · 2D-11 -'~ " " " 2D-9 j " " " / 11 I1 I!' 2D-12 ' 2D-lO -~ " " " Receipt Acknowledged: B. Adams F:G. Baker P. Baxter BPAE Chevron 7/30/84 " 7/30/84 " 8/25/84 " 8/25/84 " 8~25/84 " 8/25/84 " 6100 - 7422 DISTRIBUTION D&M W.V. Pasher G. Phillips Drilling ~ Phillips Oil Geology Mobil J.J. Rathme 11 NSK Operations R &D 7000- 8410. 5900- 7588 6700- 7768 - 8486 6900 6~~ 485O - Date: Alasl(a Oil & ~as Cons. Commission ~Anchpmge C. ~. State of Alaska Sohio Union Well Files ARCO Alaska, Inc. ' Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 '277 5637 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchora§e, AK 99510 Date: 9J12/84 Transmittal No: 4721 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. TAPES/Schlumberger GCT #69416 Run 1 GCT #69417 " 7/31/84 54 · - 7754 8/01/84 33.5 - 8910 OH LIS #69467 " OH LIS #69467 " 8/17/84 3227 - 8640 RFT 20-3 / Receipt Acknowledged: Date: B. Adams F.G. Baker P. Baxter BPAE Chevron DISTRIBUTION D & M Dzilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R&D ~C. R. smith State of Alaska Sohio Union Well Files ARCO Alaska, Inc.~ Anchorage. Alaska 99510 Te!,:.phon( 9C, 7-277 5637 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 9J12/84 Transmittal No: 4721 Transmitted herewith are the following items. Please acknowledge receipt and re:urn one signed copy of this transmittal. TAPES/Schlumberger ~"GCT #69416 Run 1 -7/31/84 54 - 7754 2H-13 /GcT #69417 " 8/01/84 33.5 - 8910 .-2V-8A j~ LIS #69467 " /OH'LIS #69467 " LIS #69325 , . LIS #69325 " " 8/17/84 Run 2 6/25/84 3227 - 8640 2G-3 EFT " DITD/SGTE/LDT " //- CNL/EPT/p~/ ":"~Z~'~ . Receipt Acknowledged: DISTRIBUTION B. Adams SEP 1 1984 Alaska 0il & Gas Cons, Commission, Anchorage E W.V. Pasher Anchora:?,~ C. R. Smith F.G. Baker P. Baxter BPAE Chevron Dzilling Geology Mobil NSK Operations G. Phillips Phillips Oil J.J. Rathmell R & D State of Alaska Sohio Union Well Files ARCO Alaska~:. ~ P:',:' O"!"~ Ec,~ 360 Anchorapc-. Alaska 99510 Te!cphon(. 907 277 5637 Return To: ARCO ALASKA, Inc. ATTN: Records'Clerk ATO-1115B P.O. Box 100360 / Anchorage, AK 99510 Transmitted herewith are the following items. and return one signed copy of this transmittal. Date: ~/12/84 Transmittal No: 4721 Please acknowledge receipt TAPES/Schlumberger ~GCT #69416 Run 1 7/31/84 54 - 7754 C-CT #69_417 " 8/01/84 33.5 - 8910 ~ LIS #69467 " 8/17/84 3227 - 8640 OH LIS #69467' " H LIS #69325 2s Run 2 6/25/84 11 II ,, / RFT DDBHC/GR DITD/SGTE/LDT " CNL/EPT/P CD/LS S / OR~ Receipt Acknowledged: B.'Adams F.G. Baker P. Baxter BPAE Chevron Date: DISTRIBUTION D&M Drilling Geology Mobil NSK Operations W.¥. Pasher G. Phillips Phillips Oil J.J. Rathmell R&D C. R. Smith State ~pf. ~Easka Sohio Union Well Files ARCO Alaska, In~/'--~'~ Post Office vox ,00360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 31, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - 2V Pad Wells 1-8, 8A Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU1/L20 Enclosure If RECEIVED SEP 1 4 I984 Naska Oil & Gas Cons. Comrn/~sjo~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany PHASE I- WELLS I thru 8 ~p~.,1_.~.,-,,,~..~..,../,....,.~o ,, ,~ ~ I'~'.-~,'.._ 5276-s- .~,r~-,,~ ~ Gas Cons. Com~ i -g&~'~"_,,,_ _.. ,.~,~ ~ / Anchorage LOCATED IN PROTRACTED SECTIONS 7 I~ 8 TOWNSHIP liN., RANGE 9 E.,UMIATMER. NOTE; BASIS OF LOCATION IS MONUMENT =52-1 ~ 2X 30bTH;BASIS OF ELEVATION IS TBM 8:5-45-25 AS SET BY LHD a ASSOC. DRI~-'"~ITE 8-V CONDUCTORS AS-uUILT LOCATIONS REV. I; CHANGE WELL NUMBERING PER NSK DRILLING, REMOVE PROPOSED LOCATION 1,2,11 ~ 12. REMOVE NOTE RE= ORIGINAL LOCATIONS 7 I~ 8; SHOW AS' BUILT LOCATIONS FOR CONDUCTORS 5 I~ 6. REV. ~; ADD CONDUCTOR 8.A. Y: 5,966,598.45 X= 508,4~. 1.8 I 168' FEL LAT. 70° 19' I 1.8641" LONG. 149055' 54.215" 189:5' FSL 2- Y= 5,966, 718'.54 LAT. 70° 19' 15.0452'' 'X'- 508,421.75 LONG. 149° 55'54.21 $'' 167' FEL 201:~' FSL Y: 5,966,838.52, LAT. 70° i 9' 14 2254" X= 508,4Pl.94 LONG. 149°55'54 ~Z04" 166' FEL 2133' FSL 4 Y:5,966,958.61 · LAT. 70°19'15.4065'' X: 508,421.81 LONG. 149° 55'54.205" 166' FEL 225:5' FSL Y :5,966,958.46 LAT. 70° 19' 15.4020" X'- 508,701 .94 LONG. 149°55'46.0:~8'' 114' FWL 225:$'FSL" 6 Y=5, 966,838.50 LAT. 70° 19'14 . ~221" X: 508,701.92 LONG. 149°55'46.033" 114' FWL 213~' FSL Y:5,966,718.55 LAT. 70° 19' 13.0420" X= 508,701.89 LONG. 149° 55'46.0:57" .* II 3' FWL 201:5' FSL (= 5,966,598.58 LAT. 70° 19'11.862~" '~SiO : 508,701.86 LONG. 149°55'46.042'' 112:' FWL 1895' FSL -- 8A Y=5,966,590.19 LAT. 70°19'11.7798'' X: 508,701.89 LONG. 149°55'46.042" 112' FWL 1884' FSL 2-V~ RVEY- .- E~ 8 9 M.'A T MER. "'- I MH-E I HEREBY CERTIFY THAT' I AM PROPERLY '. REGISTERED AND LICENSED TO PRACTICE · LAND-SURVEYING IN THE STATE OF ~LASKA AND THAT THIS PLAT REPRESENTS A SURVEY · MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF OCT. 20~ 198:5. CONDUCTORS 5 ~ 6 SURVEYED NOV. 5 ,198:5; 8.A SURVEYED JULY 11,1984.. ... ~. ~. ARCO Alaska, Inc. Kuperuk Project North Slope Drililng ' AS-BUILT CONDUCTOR /' :ii LOCATIONS 1BSSO~g date' NOV.,, ,985 ,c, le: I"-' 400 drawn by: E.W. dwg. no.: 9.05.2: ~., ,,,, Nm,m rev. ARCO Alaska, t~'~ A,ncho;age. Ata:.k8 99510 Telephone 907 277 56,37 Date: 8/22/84 Transmittal No: 4702 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 /~n'~smitted herewith are the following items. Please acknowledge receipt v and return one signed copy of this transmittal. OH FINALS/Schlumberger 2V-8A 2"/5" DI-SFL " 5" BHC Sonic/GR " " 2"/5" FDC-CNL/GR "Raw" " 2"/5" " " " "Poro" " " 2" BHCS " " CPL/Cyberlook " Run 1 8/23/84 3672 - 9042 8/23/84 8225 - 9040 8/23/84 8225 - 9022 8/23/84 8225 - 9022 7/23/84 8225 - 9040 7/22/84 8225 - 9000 /cat Receipt Acknowledged: DISTRIBUTION B.-Adams . F.G. Baker P. Baxter BPAE D&M Drtll~ng / Mobil W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell C. R. Smith State of Alaska Sohio Union Chevron NSK Operations R&D Well Files KUPARUK ENGINEERING Transmit'tal ~/ ~~ Type of Tape Date Tape Number ~//~ t ,/8¢ (~ ¢ ~ ap DISTRIBUTION -- State of AK ~. ,/~-~'/ Gaoiogy/C. Smith *~ Return to: ARCO A~S~,:':",INC P.O. Box 100360 ~nchorage, ~K 99510 ~~' Photocopy Please note: Blueline, Sepia, OH LIS ARCO Alaska, Inc. PoSt Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 20, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2G-1 2H-13 2D-10 2V-SA 2G-7 2H-14 2D-11 2B-4 2G-8 2H-15 2D-12 Thank you. Sincerely, J. B. Kewin Area Drilling Engineer JBK: ih L01 06/28/84 Enclosures RECEIVED AUG 2 7 1984 Alaska Oil & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary ol AtlanticRichfieldCompany '~' ALASKA MONTHLY REPORT O OPERATIONS 1. Drilling well Workover operation [] 2. Name of operator 7. Pe~4t_l~ ARCO Alaska, Inc. 3. Address 8. APl N0rp_l~.21128 P. O. Box 100360, Anchorage, AK 99510 50- 9. U~~kN~ver Unit 112' FWL,1888' FSL, Sec. 8, TllN, R9E, UM 4. Location of Well at. surface 5. Elevation in feet (indicate KB, DF, etc.) Pad 78, RKB 114 6. Lease Desiqnation and Serial ADL 25655 ALK N~581 10. W~N~A 11. F~ld and P~ol ~uparu~ River Field Kuparuk River Oil Pool July 84 FortheMonthof ,19~ 12. Depth at end of month, footage drilledI fish!ng jobs, directional drillirlq D_roblems, spud d~bm~arks Spud well @ 0200 hrs 07/13/84. Drld 12-1/~-" hole to . Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 9050'TD as of 07/23/84. Ran logs. Ran, cmtd & tstd 7" csg. Performed Arctic pak. Secured well & released rig @ 2000 hrs 07/24/84. 13. Casing or liner rgn and quantities of cement, results of pressure tests 9-5/8" 36# J-55 HF ERW BTC csg w/shoe @ 3667'. Cmtd w/ 800 sxs'Cold Set III & 500 sxs Cold Set II. 7" 26# J-55 HF ERW BTC csg w/shoe @ 9034' cmtd w/550 sxs Class "G". 14. Coring resume and brief description N/A 15. Logs run and depth where run D~/S~/G~/SP f/9049'to 3673'. ~DC/C~L f/9049'-8225'. CAL f/9049' ~o 7425' ~CS/6~ f/9049'-8225' 1 6. DST data, perforating data, shows of H2S, miscellaneous data N/A AUG 2 ? 1984 Alaska 0/1 & Gas Co~s. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ///~/,~~j~~/,~.,. Area Drilling Engineer ¢ /~. SIGNE~, .............. ~-v - -- )~- TITLE DATE _~ _ C~ NOTE--Report on this f,9~ is req~ed f~r~each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservati~ Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 I-JILL/MR175 Submit in duplicate M EMORAN'UUM TO: THRU FROM: State of Alaska ALASKA. OIL_~ GAS CONSERVATION COMMISSION , c. v_~,/ Chai~ F~LENO: D.31.32 Co~issioner Petroleum Inspector TELEPHONE NO: SUBJECT: Witness BOPE Test on ARCO' s 2V-8A, Sec. 8, TllN,RgE,UM, Permit No. 84-91. ~esday,_ July 17, 1984: The BOPE test began at 12:30 pm and was COncluded at 2:00 pm. As the attached BOPE test report shows, there was one failure. In s~ary, I witnessed the BOPE test on ARCO's 2V-8A. Attachment 02.00IA(Rev. 10/79) STATE OF ALA$~O\ ALASKA O,T-'~, -CAS CONSERVATION CfMMISSION "-~',. B., .E. Inspection Rcport .Inspector Operator Date Representative Location: Sec ~ T///V/R, ~M L) Drilling Contractor ·)//);/Z~'¢''~'f~ Location, General__ ', '~-~ Ceneral Housekeeping Rsserve pit. Rig -, BOPS Stack "" '~'"'. /mnular Preventer Blind Rams. Choke Line. Valves H.C.R. Valve Kill I2.ne Valves Check Valve, : ~Casing .Set Rig ~Representative- ~~~ ~ ACCUMULATOR SYSTEM .. Full Charge Pressure PreSsure After Closure ps'i9 psig Pump incr. clos. pres.· 200 psig_-- min~o sec. Full Charge Pressure Attained: ._ ~ minW¢'sec- Controls: Master g¢ .~% Remote~¢ %_B~inds_ s~.~tch cover Kelly and Floor Safety Valves · Upper Kelly. / .Test Pressure ~z; Test Pressure ! Test Pres sure ~r Kelly - Ball Type '~. Test Pressure Inside BOP. / Test Pressure Choke Manifold ~ ~Test Pressure ~o. valves /J No. flanges ~D Adjustable Chokk~ % t~fdrauically operated choke / Test Time' /:.~7.~.hrs. Test Results: Failures, / _days and Repair or. Replacement of failed equipment to he made within Inspector/Cc~ssion c~, fice notified. Remarks: ..... , , / Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector. · M EMORAN oUM State of Alaska TO: C. ~~~t~to~ : DATE: July 18. 1984 ~RU: Lonnie C. Smith<~'~ Commissioner FROM: Bobby Petroleum Ins~ee~tor FILE NO: D. 3I. 33 TELEPHONE NO: SUBJECT: Inspect diverter on ARCO' s 2V-8A, Sec. 8, TllN,R9E,UM, Permit No. 84-91. Thursday, July 12, 1984~ I inspected the diverter system on ARCO's 2V-'8-A thi~S'""date~ a~d all components met the API RP-53 and the AOGCC regulations for diverter systems. In summary, I inspected the dtverter system on ARCO's 2V-8A. J~e 22, i984 Mr. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 ~chorage, Alaska 99510-0360 Kuparuk ~ver Unit 2V-dA ARCO-~as~, Inc. Pemtt No. 84-91 Sur. Loc. 112' ~, 1888' FSL, 'Sec. 8, TllN, RgE, UM. Btmhole Loc. 1381' ~, 1022' FSL, Sec. 17, TllN, RgE, UM. Dear Mr. Kewin ~ Enclosed is the approved application for permit to drill the above referenced well. If 'coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). if available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you ma)- be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 amd the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Envi~°nmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. Jeffrey B. K~win Kuparuk River Unit 2V-SA · _2_ June 22, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment ~nstallation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. in the event of suspension or abandonment, please give this office adeq~te advance notification so that we may have a witness present. Ver~_ trUly yo~s, Chairman of Alaska Oil and Gas Conservation Commission Ic Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of En-~ironmental Conservation w/o encl. ARCO Alaska, Inc.~ Post Office · .100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 19, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2V-8A Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2V-8A, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on June 23, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Silly, - -' x. ~Xrea Drifting Engineer JBK/JG7/L94 :tw Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ ALASKA O,- AND GAS CONSERVATION COi,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC L~ SINGLE ZONE ~[}( MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. RECEIVED 3. Address P. 0. BOx 100360, Anchorage, Alaska 99510 JUNE 4. Location of well at surface 112' FWL, 1888' FSL, Sec.8, T11N, RgE, UN At top of proposed producing interval 1290' FWL, 1464' FSL, Sec. 17, TllN, RgE, UN At total depth 1381' FWL, 1022' FSL, Sec. 17, TllN, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 114', PAD 78' 6. Lease designation and serial no. ADL 25655 ALK 2581 9. Unit or lease name Kuparuk F~ll~lllll~lt& G~ C0118. 10. Well number 2V-8A 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance COmpany Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 1022 feet 2V-8 well 5' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 9124' MD, 6229' TVD feet 2467± 06/23/84 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2731 psig@ 80OF Surface KICK OFF POINT 300 feet. MAXIMUM HOLE ANGLE 52 oI (see 20 AAC 25.035 (c) (2) $136 psig@ RI~Ik ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole Casing 24" 16" 12'1/4" 9-5/8" '8-1/2" 7" ,,. 22. Describe proposec~ Weight 65.5# 36.0# 26.0# program: CASING AND LINER Grade I Coupling! H-40 HFIERW BTC1 J-55 Length MD TOP TVD 80' 36' I 36' 3471 ' 9091 ' 35' 35' I I I 33' ~ 33' MD BOTTOM TVD 116' I 116' '3506' I 2724' I 9124' I 6229' I I (include stage data) ± 200 cf 1040 sx Permafrost E & 250 sx Permafrost C 325 sx Class G neat ARCO Alaska, Inc., proposes to drill a KuParuk River Field development well to approximately 9124' MD (6229' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2731 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uneemented annuli through the permafrost interval. 2V-7 will be 125' away from 2V-8A at the surface. A closer wellbore is the plugged and abandoned 2V-8.____~well, 5' away at the surface, with a kickoff point at 500' and TD at 3167'MD. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any (see attached sheet) · 23. I hereby cert,,i,f'C~at the foregoing is true and correct to the best of my knowledge // SIGNED (/ /~-~ , TITLE Area Drilling Engineer The space f n use ~" CONDITIONS OF APPROVAL DATE ,lsslon Samples required Mud log required Directional Survey required APl number ~]YES ~NO [~YES ,~NO XYES []NO 50- ~);~q- ~-~/,/EdO Permit number SEE COVER LETTER FOR OTHER REQUIREMENTS Form 10-401 Approval date ,COMMISSIONER DATE June 22, 1984 by order of the Commission Submit in triplicate Permit ~o Dri]l 2V-SA fnterrupt~ons fn the disposal process. The weTT wfTT be completed by the workover rfg using 3-1/2% 9.2~/fts J'55s BTC tubfng. Selected intervals wfll be Perforated wfthfn the Kuparuk formation and reported on subsequent reports. A subsurface safety valve wf11 be fnstalled and tested upon conc]usfon of the job. RECEIVED JUN2OLq 4 Alaska 011 & Gas Cons. Commission Anchorage -~T '-~ -"~-~"~ "+~"+ ....... + *~' ~ .... ~ ......... ~ ................ ~ ........... . . . : z : . : = : : ~ : : ; .. : ..... ~ ~ .... ~ ~ , ~A~ ~A~~ ~U~.~ T~-- ~,.d~-~ ~ - ~ .... . ..... ~ .... . ......... ~ ......~'..~ ..... ~ .~~; ~ . ; . ~ -~_; ......... , ................ ~ .............. .~ - ~ ' ' ~ ,,m ,;,~,,, ~ur~ ~.~,~ ~r.~e ~~ . ; . . : . . ;::: :: :::: :'::: :-: ~.::. ::: :_.L:: ::::::::::::::::::::::::::::::: :-.:..::: :.; :.: ::_..:::; ::::::::.L::_::.:::::::;'~:~.' :.::: :?:': ':.: ~ :;'.:~-:: .......... :.~: :~;.~.::::- -:::~,.,~;~ :... ;::~:::..~,. : :.:. .. ~.. :~:. . ~ ........ ,..~ ........... ~ ..... :.,~.~.. ...... .._: ....... ~ ............. ~.F.:; .... , ...................... .~2:: :::: :: l~ff~Off--,'J~~~r-":":'-:':'-:--.'-':-~-': .... :'-'~':--:":": ..... ::'-:"':'[:'7~ :':'-:'"? :-:':":-,":-:'-':-: :.:: :: ~::: ' .[~% .... : ::;' :::::-:: :.-:;:: ::: ~-:;-;t~;.::--:~ :-:::-=============================== ~-::. , ~ _ ~ i i ~ ~ . ~" ~ ~ ~ _ . i I . I . . L ~ I II ~ J ~ - . I I ] I ~ ~ ~ e II I ~ ~ ~ I . . : : : ~ . __ ..... - .__ t :':'::::::::: :;::: :' :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :':REC:E VE:E : :: i :~:_ ::: ::::: :: :-/2---:-:::--)2:2:~5L;~:/::::-~/:~::;: :::::::::::::::::::::::: ::::-:--: :-::::.::: ~,-,::- ,'%, t .................... ~ "'~' Y- ..... ~':", ', .... ;-' :~' ; .... ~laS~ 011 & Gas ~onS 'CorlmiSelon ......... :.,.::-- ~~":~Tt:-:-T~~~-:.~a~;4~~+ ..... ~- ..~:~ ' ~ .-- .... ~ ........... ~ ~.~.~ ~.. ~[ tS -'-T~; ~~~ ~~ ' '~ __.~.- ~,~:~ ................ ~ .......~ ' ~ .............. ~ ......... , ..... ~ .............................. . _ . : :: :::.':3;.' .......... ;"L'~:_;~: ......... ~:: ......... T.~:. ............. ~: ............ ~:'~::_': ' ' ~0 ..... ~ . ~ i , , ....... :~ nnn: ........................................ . I - ........ ~ ~ ' -/': .... ~' · '~.l. ...... . ~j . .... . ~ .............. , , , ~ , , ~ ...... l t ' '. .- t ..................... ~ ........ ~ .......... . . l ~. .~-~ ..... . .... ~ .... ; .......... . ''~ : I ............... ~_~., ........ ~__, ..... ~ ..... ,...-~..; ..... ~ .... "" ::::-:JUN20.~i~' ~". I ..... ~ ~ ................................ + ............ . . . ANNULA~ PREYENTE~ PIPE 6 DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" , 5000 psi' pipe rams 8. 13-5/8" - 5000 psi blind rams g. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST '1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL 'UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PS! RiEMAINING PRESSURE. )3-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARC?IL DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND ~./)kL¥]~S U1)S'i~q]~Ji~v[ 01~ CwrIOI<]~S. DON~T TEST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PS[ AND HOLD'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 ~. ~~'PRESSURE mWNSTREAM OB CHOK~ ISOLATION V_B, LV]~S~ TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOt'rOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR lO MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. RECEIVED JUN2 01.984 Alaska 011 & Gas Cons. Comml#ion Anchorage 7 6. Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 16" X 20" 2000 psi double studded adapter. ' 4. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. im Maintenance & Operation 1. Upon initial installation close annular preventer and verify 6hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor RECEIVED JUN 2 0 1984 ~1 & ~ms Cons. Cemm~ CHECK LIST FOR NEW WELL PERMITS Company /~/~'~2~/ /-//~-~K~ ~--/Y~ Lease & Well No. ITEM APPROVE DATE YES NO , (1) Fee ~ ~-Z/-~f- 1. Is the permit fee attached .......................................... . -- REMARKS (2) Loc ~j~A~ &-z/-Md (2 thru 8) (3) Admin /~ ~ (9 thru 11) (10 and 11) (12 thru 20) (5) #t/J (21 thru 24) (6) Add: ,/7/j"/?t ~-f)'['~l 2. Is well to be.located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is well bore ~7~ ~~7~ .............. 7. Is operator the only affected party ................... 8. Can permit be approved before ten-day wait .......................... e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Does operator have a bond in force .................................. z~ Is a conservation order needed ...................................... /W~C Is administrative approval needed ................................... /w~ Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ........ Will cement tie in surface and intermediate or production strings ..1 Will cement cover all known productive horizons .................... Will surface casing protect fresh water zones .................... . Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required .................................... ' a~tached ;7d;~ Are necessary diagrams of diverter and BOP'equipment ... Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (Feb.78) .................. __ .IV~7-' 5 u2~MI ZT!D 0 H 0 Geology: Engin~, ing: rev: 12/08/83 6. CKLT INITIAL'' GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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 APPENDIX. No special*effort has been made to chronologically organize this category of information. his ThPE VERIFIChTION LIST!NG ~mmmmm~mmmmmmmmmmmmmm~ TAPE V~RIFICATIDN I, IS~IN~ WP 010,HO~ VERIFICATION PAGE ~ RE~I, t;EADER ERVTCK NAME :EDIT I~TE ,'84/0q/ 4 RTGTN ; DN'flNIIATI~N ~ ;01 REVIOU5 REEl,, 3~MENTI; :SCHLUMBERGER NELl, SERVICE~ PROPRIETARY FIELD TAPE * TAPE HEADER ERVICM NA~E :EDIT ATE :~4/09/ 4 RIGIN :6941 RMVIOI]~ TAPE D~MENT& :SCHLUMBERGER WELL SERVICES PROPRIETARY FIELD TAPE EOF , FILE HEADER ** II,E NAM~ :EDTT .001 MRV!CE NAME ~TE : ~×IMU~ !,ENGTH : 1024, ILE TYP~ : RMVTOIlS FILE , INFOR.ATION RECORDS ** NEM CONTENTS N : ~RCO AI,ASKA INC, N t 2V-LA N : KUPARUK ANG: 9E ECl': n Ul~t N. SLOPE T~: ALASKA . COMMENTS ** UNIT TYPE CATE SIZE CODE 000 000 000 000 000 000 000 000 000 000 OlO 065 000 OO6 065 OOU OOB 065 000 002 065 000 003 065 000 001 O65 000 008 065 000 006 065 000 004 065 VP 010.HO? VERIFICATION bio. ING PAGE 2 ************************************************************************************ 6CHI',UMBER~[~R , ALASKA COMPUTING CENTER * *********************************************************************************** DMpANY :~..ARC~ ALASKA INC. ELLI~LD DUNTY = NORTH SLOPE BOROUGH TATE = ALASKA ASING = 9.625" m 3668 FT, AS1NG = 7 0" ~ 9034 FT *******************~********************************************************** VP 010.~]O2 VERIFICATION LISTING PAGE * CYRU CONTINUOUS TOOb (~CT) * DEFINITIONS~ , * HhAZ= AZIMUTH , * DEVI: DEVIATIUN , * gOEP: GyRO DEPTH · * VOMP: TRUE VERTICAb DEPTH * * MSDR= NORTH OR SOUTH DEPARTURE , * EWDH= EAST OR WEST DEPARTURE * * DGL : DOG bEG (CURVATURE OF THE WEbb) * * * , $ , · , , $ $ , $ , $ , , , , , · , , · , , · · , · $ , $ · YP olo. Mo~, VERIFICATION LISTING PAGE DATA FORMAT RECORD ** NTRY BI,,OCKS TYPE SIZE 4 8 4 9 4 0 1 ATUM SPFCIFICATION RbOC NEM SERVICE 6FRVICE; UN iD OROER ~ CPT FT DEP CCT FT DMP CCT FT LAZ CCT DEE EVI GC? DEG SDR OCT FT WDR GCT FT GL GCT FT EPT EPT £PT EPT EVI gPT EPT EPT 33 5000 GDEP 100,0000 CDEP 200 0000 0:4~1! 300.O000 GDEP 3.62q7 400,0000 GDEP 7.9977 500.0000 GDEP 12.4251 600,0000 GDEP 16.q360 700.0000 GDFP 21.5602 800 O000 26:0329 qO0.O000 GDEP AP1 bOG TYPE REPR COD~ 66 73 65 66 APl API FiLE CLASS MOD NO. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0000 VDEP g:ooo 81.1000 VDEP 0,1072 E~DR 1.80,5999 VDE[' -0,0574 EMDR 287,9999 VDEP -2,9402 EWDR ~u5 ~9~ vD~v 1~:8777 ~83 4998 VDEP 29:1~43 58~.~997 VDEP -53,3752 EWDR ~75,4996 VDEP 83.2'850 EWDR 770 1 9q'l -121~110o B54,4996 VD~P ENTRY 255 6O ,lin 0 SIZE PROCESS SAMPL£ 4 0 1 4 0 1 4 0 ! 4 0 4 0 1 4 0 4 0 1 4 0 1' 33,0000 HI, AZ 0,0000 DGb 81.0995 HbAZ -0.1792 DGL 1.80.5979 NbAZ -0,5791 DGL 287,9448 HLAZ -0.3505 DGL 385.2685 HbAZ 2.6636 DGL 481.3571 HbAZ 7.5482 DGL 575.8755 UGAZ 13,7412 DC;I, 664,8721 HI, AZ 21.0754 DGL 751.31~7 HLAZ 28,8462 DGI, 826,1797 HLAZ REPR CODE 68 68 6n 68 68 68 b~ 68 290,4059 0,0000 289 7280 0:6056 197,6196 0,962b 167.7422 5,5b13 16],0591 ,5076 165,0081 5,4478 105,9217 4,5052 166,9842 5.7168 ~69,9299 3,4976 171.0048 VP 010.}{02 VERIFICATION LISTING iooo oooo EVI 37,4466 N~DR -271: EPT 1200,0000 GDEP i158, EPT 1]O0,OOnO GDEP 1275, EVl 42.gb05 ~SDR -403, EPT 1400,0000 GDEP 1369. fYI 45,9269 WSDR -468, EPT 1500 0000 GDEP 1463, EVI 47:4464 NSDR -535, EPT 1600 0000 GDEP 1557, EVI 47:1146 ,MDR -602. EPT 1700 0000 GDEP !~74 EVI ' 45,8425 "SDR '750. EVI 46.4237 "SOR -816' ooo.oooo 19s4 EPT 2100,0000 GDEP ~070 EPT 2200 0000 GDEP 2163 EVI 48:476! NSDR -1031: EPT 2300,0000 GDEP 2255, EVI 4~,9401 NSDR -1098, EPT 2400. 0000 Gl)EP 2371. EvI 49.4788 NSDR -1184. EPT 2500.0000 GOEP 2464 gVI b0.0085 MSDR -1253: EP~' 2600.0000 GD~P 2556. EvI 50.3322 NSDR -1322. EPT 2700.0000 GDEP 2672, 3150 199~ 4028 5996 1050 799b 2848 8994 6~82 5994 744~ 3994 2272 1992 ~968 4993 7430 3992 4034 2991 0626 7993 5206 4990 3428 0991 ~803 5991 8691 3989 1775 0991 1357 5991 4197 2988 E~DE VDEP E~DR VD~P E~D~ VD~P EWDR VDFP EWDR VDEP EWDR VDEP E~DR VD~P EWDR VDEP E~DR VDEP EhDR VDEP EWDR VDMP EWDR VDEP E~D~ VDEP EWD~ VDEP EWDR VDEP EWDR VDEP EWDR VDF[' EWDR VDEP 35,2260 926.9~32 44,45J0 1004o029! 53,4185 1076.9026 63.6873 1165.557~ 76,7814 1232 0884 87:3186 1296.6008 101,9675 1359 98O7 118:7901 1440,9700 138.8438 1506.1238 154.9930 1571.2217 171,3702 163~,5042 187.7015 1712 6179 208:3176 1774.4333 224,8365 1835,4487 ~4~,~170 1911,1621 261,1044 1971.0442 276.9828 2030.~429 292.8397 2103,9937 DGI., HbAZ ,ri. GL DGL HbAZ DGb HbAZ D(;b HbAZ DGL HI.,AZ DGb HLAZ DGL DGL ~L~Z DGL HLAZ DGL HI,AZ DGL HbAZ DGL HI, AZ RbAZ DGL H b A Z DG[, ~[,AZ HLAZ PAGE 2,21!0 ~70.6167 5,6274 170,3813 3,5056 169,6565 2.2833 170 6342 4:6454 109,7354' 3,8443 166 1245 2~2433 1988 166,2837 0,6187 lb6 0118 0~5005 166,0024 0,2887 166,0166 0,7990 166,0321 0°42O4 166,3001 0.9154 166,6548 0,2906 106,9327 0,6247 167,0750 0,4727 lb7.1669 0,3443 167,5674 VP 010.I.t02 VEPlFiCATION bIGTING EVI 50.5515 MSDR EPT 2800,0000 GDEP EVi 50.9153 MSDR EPT 2900 0000 GDFP EVI 51:5796 M~DR EPT 3000 OOnO GDEP gVl 51~8473 MSDR EPT 3100.O000 GDEP EPT 3200.0000 GDEP EVI 51'6381 NSDR EPT 3300 0000 GDEP EVI 51:1186 ~!8DR EPT 3400,0000 ~DFP EVI 50,9493 NSDR EPT 3500 0000 ~D~P gvI 50:57~2 NSDR EPT 3600 0000 CDEP EVI 50~8654 MSDR EPT 3700 0000 GDEP EVI 51:327b M6DR EPT 3800 0000 ~DEP EV1 52~1595 NSDR EPT 3q00.0000 GDEP EVI 53.P7~b N~DR EPT 4000.0000 CDEP EVI 52.5308 M6DR EPT 4100.0000 GDFP EVI 51.2483 MSDR EPT 4200.0000 GDEP EV1 4q.3380 N~DR EPT 4~00.0000 ~DEP EVI 49.?i09 MSO[{ EPT 4400.0000 GD~P EV! 49,1389 NMDR EPT 4500.0000 GDEP -1409.4080 2763.0986 -14.78,0908 2876 99~5 -1564:8684 2968.0986 -1634,9084 3059,~988 -1705.2371 31 3984 3264,7988 -i863,3982 3356.~9S7 -1933,1545 3470.4985 -2020,0242 -2088.61 ' 3673.1982 -2174,9805 3763.~98~ -2~44,5723 3~75.8979 -2332,94~4 3965.9980 -2404.0806 4055 9980 -2473:7192 4168.4980 -2557.9795 4258.3984 -2624.5'835 436~,1982 -2706,5542 4457,7979 EWDR VDEP EWDR VDEP EWDR VDEP ~WDR VDEP EWOR VDEP EWDR VDEP EWDh VDEP EWDR VDEP EWDR VD~P ~WOR VDEP EWDR VDEP EWDR VDEP EWDR VD~P EWDR VDEP EWDR VDEP EWDR VD~P EWOR VD~[' EWDR VOEP 312,3397 2161 4399 2~3~;7549 346,3023 2~89,1099 36~,0555 2345 3691 375:4162 2415.6250 393,2727 2472,64~6 407.2818 2530.1060 420.9159 2602.5977 437,1252 2659.7134 449'4069 730 3540 2464:5660 786 ~944 2476:6283 2854,4224 491.72~7 2908.3647 503,8528 2963.8691 516,8665 3031,3301 53 .3094 3095,0439 548,40~8 3167.5283 565,8203 3~25.5767 PAGE 0.3665 7,t418 160, 951 167,8839 0,6650 168,3500 0,4~79 168,4958 0,1412 1.68 ~152 168,8378 0,2862 168,9835 '0,5306 169 7557 0:2872 ~69,9292 ~70,~546 0,2834 170,2146 1,3218 170,3931 0,6575 170,0051 1,9076 168 8805 2:2347 lb8,0256 0,0451 168,0641 0.42~0 167,9362 0,0983 167.6955 VP OIO.H02 VERIFICATION 49,0591 NSDR EPT 4600 0000 GDEP EPT 4700,0000' GDEP EVI 4q,a. 195 NSDR EPT 4800,0000 GDEP EVI 49,6154 NSDR EPT 4900.0000 GDEP EVI 49.9121 MSDR 5o2o1 , EPT 5100.0000 GDEP gVi 50,0~55 N6DR EPT 5200 0000 GDEP gVI 50~1581 NSDR EPT 5300,0000 ~DEP EVI 50.39~9 MSDR EPT .5400,0000 GDEP £VI 50.3203 NSDR E.PT 5500,0000 gVi 49,2944 EPT 5600,0000 ~OEP EVI 49.3598 NSDR EPT 5700,0000 GDEP EVI 40,5977 HSDR EPT 5800.0000 GOEP EV1 49,62]9 MSDR EPT 5qO0,O000 GDEP EVI 49,8448 NSDR EPT bO00,O000 GOFP EVl 49.9909 MSDR EPT 6100,0000 GDEP EV1 49,8367 NSDH EPT ~200.0000 GDFP EV! 49.5664 NMDR EPT 6300.9000 GDEP blSTING '2771, 4568 '2853: 4661, '2922, 4753, '299~, 4869, '3077, 496~, '3~46, 5055, -3216, 5169 -3301~ 5260. '3370, 5374. '3455; 5465, '3524, 5557, '3591" 5671. '3677, 5762 '3745: 5875. '3830, 5965, -3898, 6055, '3965, 6~67. '4049. 6257. 9790 5977 957O 0977 4028 99~0 3296 8984 6514 5977 8770 4980 3779 6982 8086 9980 2695 7979 8701 9971 0562 0977 9990 0977 2026 ~97! 5972 997! 649~ 8975 2187 6973 6479 9971 7104 7969 EwD~ VDEP EWDR VDEP EWDR VDEP EWDR VDEP VDEP EWDR VDEP EWD~ VDEP EWDR VDEP E~DR VDEP EWDR VDEP EWDR EWDR VDEP VDEP EWDR VDEP EWDR VDEP VOEP EWDR VDEP VDEP 579.9580 3~97 9341 597:8621 3358,2559 613,~183 3418 5630 628:6896 3493.~155 648.~438 3553,0688 663,7185 3612.6987 679,3506 3685.9932 698,6188 3744.38~3 714,094~ 3816,8447 733,3834 3875,7822 747,30~6 3935,1523 759,8750 4009,2075 775,7567 4068 4238 788:7754 414~,7900 805,0800 4199,6201 818,1997 4257,45~1 831,3~33 4330.0908 847.7251 4388,4941 DG[, HbAZ DGL HLAZ DGL HL, AZ DG[, Hr, AZ DGI.., }11, A Z DG L HI,AZ DC;I, HLAZ DGL HI,AZ DGL HLAZ DGL HLAZ DC.;L HLAZ DGb H b A Z DGL Hi, AZ DGL HLAZ D C; I, HbAZ DGL HI, AZ DGI, _H ~, A Z DGL HbAZ PAGE 0,4594 167 6 167,3069 0,2648 167,2643 0,1789 167,3394 0,0744 167,~992 O, 064 167 3144 0:1451 0,4970 167 2715 0:2779 {67,4949 1,'1686 169,3910 0,9248 169 5058 0:06~2 169 3391 0~4833 ~69 82 0,393 168,9979 0,2965 168,97~1 0,4864 168,9805 0,6143 lb8,9693 .VP ~EVI !EPT 'EPT 'EPT 'EVI 'EPT .EVI .EPT ,EVl 'EPT ~EV1 'EPT 'EPT ~iVI ~EPT 'EVI ~EPT ~EVI ~EPT ~EVI EPT VERIFICATION LISTING 49.2943 NSDR -4116,6641 6400 0000 GDEP 6370.0977 49:3894 NSDR -4200.2373 6500.0000 ~OFP 6459 8975 49,5264 NSDR -4267~2627 6600,0000 GDEP 6572,3975 49.4678 NSDR -4351.3057 6700 0000 GDEP 6661.2969 49~1889 MSDR -4417,5176 0800 0000 GOEP 6771.9980 49:3309 NSDR -4499'8662 6900 0000 GOEP 6860.5967 48[8824 N6D~ -4565,9111 7000 nO00 GDEP 6971.1963 48:8671 NMDR -4647,8281 7100..0000 GDEP 7059.6973 48,9719 NSDR -4713,3291 7200 0000 CDEP 7170.2979 48:9891 NSDR -4795.2998 7]00.0000 GOEP 7258.8965 49,1'/85 NSDR -4861,1143 7400,0000 GDFP 7369 0967 49.6561 NSDR -4943:4297 7500,0000 COEP 7477 8975 49,16RB NISDR -5024:9033 7600 0000 C, DEP 7564.8965 48: 3977 NSDR -5089 , 1250 7700.0000 GDEP 7673.6973 4R,ObI3 NSDR -5168.8662 7800,0000 GO~P 7760.7969 48.4707 NMDR -5232,6787 7~00,0000 ~DEP 7869.7969 48,5166 NSDR -5317,7129 8000 OOO0 GDEP 7962 2959 48; 1944 ~,$DR -5380:4824 8100.o000 GDEP 8057,1963 EWDR VDEP EWDR VDEP EWDR VDEP EWDR VDEP EWDR VDEP EWDR VDEP E~DR VDKP EWDR VDEP VDEP EWDR VDEP EWDR VDEP EWDR VDEP EWDR VDEP EWDH VDEP EWDH VDEP EWDR VDEP EWDR VDEP EWDR VDEP 860,7766 4461,7393 076,9623 4520;1045 889,8138 4593,~045 906,0560 4651 0615 918~7141 4723 3994 934~2213 4781,1465 946,5939 49 .7371 4912,1494 973,9222 4984 7930 989:2944 5042.8018 1001.6792 5114,4063 1017,1997 5184.8486 1032,6023 5242 3447 .1044:3784 5314,8408 1059,3096 5372,8633 1071,4583 5445.1924 1087.0759 5506,6748 1100.6179 5569.8369 Iii, AZ DG[, HbAZ DGL DGL HLAZ DGL HLAZ DG[, HLAZ DGL Hb~Z DGL HI, AZ DGL HLAZ DGL HI, AZ DGL HbAZ DGL HbAZ Hr, AZ DGL HbAZ DGL HI,AZ DGL HI, AZ, PAGE 0,0458 169,1276 0.2228 169,~303 '0, 101 169,0610 0,7583 ,, 351 !69,~859 1, 305 169,4755 0,6586 169,5047 0,2812 169,4197 0.5047 169 3342 0:4264 1.69,3594 0,1817 169 2842 0~2083 169,4171 1,8966 109,5942 0,6054 16~,2939 ..3828 lb9,1385 0,4158 168,7705 0,3342 168 6803 0:4768 168.4249 ,'ir,,-.-- VP 010,~0~ VISR][FIC/~TiDN LISTING ATE :¢~/09/ g ONTINIIATiON ~ :01 E×T R~EI, NAME : OM~ENT$ :SC~{LI~M~ERGER WELl, SERVICE~ PROPR!~;TARY FIELD TAPE ********** EOF ********** EOF ********** PAGE 10 YP OIO,HO~ VERIFICATION L~$TING ~ EVI 48°2330 NSDR EPT 8700,0000 GDEP EVI 47.5481 MfDR EPT 8300,0000 GDEP EVI 47,0708 qSDR EPT 8400 0000 GDEP EVI 46~7998 NSDR EPT 8500,0000 GDEP EVI 4~.4840 M~DR EPT 8600 0000 GDEP EVI 42~9729 MSDR EPT 8700 0000 GDEP EVI 42~600 M~DR EPT 8800,0000 GDEP EVI 42.9655 NSDR EPT 8900,0000 GDEP EVI 42.4569 NSDR ~p~ 891o oo~o ou~ '5449,9033 '553 , 8267,3965 '5602,0234 8360,3965 '5668.6846 '5750 420 8569,3965 '5813,1621 8662,3965 '5875,4658 8755 4 1 8~8~ 8905 - EWDR VDEp EWDR VDEP EWDR VDEP EWDR VDEP EWDR VDEP EWDR VDEP EWDR VDEP EWDR VDEP EWDR VDEP EWDR 1114,6687 DGL 5648,3740 HbAZ 1132.1565 D(;L 5711~4238 HbAZ 1146,2207 DGL 5774,7236 abAZ 1160,3047 DG[, 5855.9697 HLAZ 1176,3296 DG[, 5923,1924 HLAZ 1187,5967 DGL 5991,3838 HLAZ 1198,4197 DGL 6059,5254 HbAZ 1~09.1357 DGL 6157.4766' ~LAZ 1221'9875 DGL 6169,6768 HLAZ 1~23,'2854 DGb * FILE TRAIt, E;~ I[,E NAME :EDIT .001 ERVICF NA~E ATE : AXIMUM LENGTH : 102a II, E TYPE EXT FILE NA~E EOF * TAPE ?aAII, ER EPVICF NAME :EDIT ATE :R4/09/ 4 RIG1N ;6941 APE; NAaF ; ONTINUATION ~ ;01 EXT R~PE NAME O~NFNT$ :SCHL~;MBERGER WELL SERVICES PROPRIETARY FIELD TAPE EPVICE NAME ;EDIT PAGE 0.3726 168,2956 0.4898 168,~133 O, 338 168,2390 1,4908 169,7015 2,0176 21 170,1438 0,3985 170,5910 0,7642 173,~108 3, 049 1.73 745 VERIFICATIOM LISTING ~N ~ ,~ASKA INC ,L~v- ~ RANG) ?OWNI COUN{ N,$bOP~ CT~Y~ USA 000 000 0~6 065 000 000 005 065 000 000 OOB 065 000 000 002 065 000 000 004 065 000 000 002 065 000 000 008 065 000 000 006 065 000 000 004 065 PAOi PA 7O 4 ' P 2 4 ~R ~T PS3 4 R PS3 R F'DN "ALI FDN 3 O 0 4 ~HOB FDN ~ 0 0 4 DRNO FDN G/C3 42 44 0 0 0 4 NRAT FDN 42 42 1 0 0 4 RNRA FDN 42 0 0 0 0 NPHI FDN PO 42 68 2 0 0 4 ~C~b rO~ CPS 42 34 92 0 0 4 I 68 1 68 ! 68 ! 68 1 68 ! 68 1 68 ) 9 D -~ -999 9 -9' -,9~ ,D DEPT SP SRAT ~CNb DEPT SP GR FCNL 94~q375 ' o og -36 5000 9~ 2500 62 4375 CALI 2 8340 RNRA 895 0000 8500 0000 SFLU -23 1719 91 3t25 Ga 79 5000 9 9512 710 5000 94 0000, DT !06 6875 GR 9 4 DRHO 56 ! D 9~ 6250 DT 3'281: RHOB 3 ~520 NPHI 9~,5000 GR "]867 DRHO 34,9609 NCNb 27.8594 IL, D 18.8125 Ih~ ,5625 DT 93,6875 GR 9,2187 RHOB 2,2500 DRHO 2,9707 NPH! 30.5176 NCNb : 0313 lbD 6,1016 7 5000 DT -999'2500 77,0625 DT 92,2500 GR 10'4297 "HOB 2'4141 DR"O 3320 NPHI 30,~105 NCNL 4 95 92 0000 0 022O 2000 0000 19 5625 61 8437 58 9687 0 O0O5 2660 0000 6,1914 -999.2500 71,8750 0,0229 2368,0000 PAG~ 2 t63 I ,M ,D ?CNb 426 0000 DEPT 7~.0o SP 26 GR -?99 NRAT 3 F'CNL 524 2500 9375 cC'~Li 5820 RNRA 000 SP DT GR PCNb 7800 0000 SFLU -33 R750 GR -999 2500 GR 100 4375 CALi 3 3379 RNRA 569 0000 SP DT GR NRAT 7700 0000 SFLU -26 8125 OR -999 2500 GR 100 1875 CALI 3 2070 RNRA D 1 5 100 -q99 6875 4375 DT 2500 DT 2 34 PHOB 207 NPHI 3 7285 TLD I00 1875 DT -999 2500 DT 1~ 5000 RHOB 5020 NPHI ,,, 3, 99 I ,M 2598 NCNb 4,6758 IbM '999,2500 GR 4238 DRHO 36,$234 NCNb 4 -999 -999 01!7 :IbM 2500 OR 2500 GR ~4355 DRHU 031 NCNb 5957 25OO O63 1844 6oo0 4 7344 -999 -999 ~500 50O 0 O034 2118 0000 3 9980 -999 2500 -999 2500 0 0244 1984 00o0 )EPT ~P ~R~T ~T ~RAT YCNL DEPT SP ~T 7~00 0000 SFI.,~ 15 2109 GR -99~ 2500 GR 3 3750 RN~A 568 5000 7000 0000 SFbU -29 9219 GR -999 2500 GR 113 7500 CALl 3 6387 RNRA 426 5000 0900,0000 SFLU '26,~813 GR '999, 500 GR 8~,4629 '8125 DT -999,2500 DT It ,4453 RHOB 3,6855 NPHI 3 8125 XbD 113 7500 DT -999 2500 DT 14 1250 ~HOB 4 3320 NPHI 3 2832 ILD -999, 500 DT 3,71009 II.,l~ -999;250 OR '999,2500 GR 37~:3398 DRHO 2559 NCNb 3 7617 IbM -999 2500 GR -999 2500 GR 2 3809 DRHO 40 7715 NCNb 3 2676 '999, GR 3,6152 -999,2500 -999,2500 0000 -999 -999 2500 0 0151 1848 0000 3,2793 :999,2500 999,2500 )EPT 5P ~RAT ?CNL ~)EPT 5P URAT ~CNL SP ~CNL OEPT 6400:0000 :SFLU. ::~: .:::: :3 3242i ::Z;bD ~12 T -999: 11] 6250 CALl 1~ 2305 RNRA 616 5000 b300 -11 -999 102 626 O0 2500 7500 CALI 4316 RNRA 0000 2 4727 IbD 102 7500 DT -999 2500 DT I0 2109 RHOB 6289 ~PHI 6200 0000 SFLU -10 81~5 GR -999 2500 GR 94 4375 CALl 3 3809 RNRA 648 5000 2 9277 I5D 94 437~ DT -999 250 DT lO 2422 RHOB 3 9707 ~PHI 6100,0000 SFLU 2,7500 IbD 3 3398 . I~ GR .3496 DRHO ,4004 NCNb -99g 5605 Ib~4 2500 GR -999 250O GR 2 3027 DRHO 39 3555 NCNL 3 0137 Ib~ -999 2500 GR -999 2500 OR 2 3359 DRHO 38 3789 NCNb 2,8242 Ib~ '999 0 2284 2 5000 -999 2500 -999 2500 0 0015 2272 0000 2 9785 -999 2500 -999 2500 0 0146 2576 0000 2,7891 RHO~, 0 DEPT T FCNL OEPT SP OT GR NRAT FCNL DEPT SP DT NRAT FCNL -9' ~,~500 ~T -99.9 4336' ~NRA 4,0586 NPHI 38,8672 NCNb 2346 0000 5600 -15 -999 103 619 ~R ~750 CALf 3477 RNRA SO00 2:,8437 I.hO .103,3750 DT 999~2500 DT 1~.4922 RHOB 18789 NPHI 5500 -20 '999 98 3 558 000 SFLO 344 GR 75 CALl ~906 RNgA 0000 2 98 -099 tO 3 .375 DT 2500 DT 5547 RHOB 7656 2,9082 ILN '999,2500 GR -999,2500 CR 2,2500 DRHO 38,0859 NCNb 2 -999 -999 -0 2102 8008 2500 0000 5400 0000 SFLU -22}~87b UR -999 2500 GR t14 750 CALl 3 ~31 RNRA ~46 5 O0 2 9844 ILO 114 3750 DT -999 2500 DT !~ 1797 RHOB 4863 NPH! 3,1875 Ib~ -99~,2500 GR ,2500 ~R 2.2598 DRHO 35.8184 NCNb 3 0254 -999 1500 -999 500 0 0024 2254 0000 2 ,D 2 3 NPH~ T . CNL DEPT SP GR NRAT OEPT SP DT FCNb DEPT SP DT GR 4844 ~PH! 33,,2520 NCNb 4800 0000 SFLU -19 ]906 ~ -999 2500 0000 CALl 7363 RNRA 567 0000 2 8:418 9~ 0000 DT -999 2500 1~ 3359 RHOB 5996 ~PHI ~ 3223IBM -ggg 2500 GR -999 2500 OR 4~ 2676 DRHO 8965 NCNb 4700 o000 SFLU -22 1094 OR -999 2500 OR 103 1250 CALl 3 6895 RN~A 451 7500 3 0156 ILD 103 1250 D? -q9~ 2500 DT 9687 R I HOB 4 2070 NPHI 3 0996 IbM -999 2500 GR 05 DRHO 43 2129 NCNb 4600,0000 SFLU '23,2344 GR '999,2500 GR $2,1875 CALI 4.7539 lbo 8~.1875 DT -99 .2500 DT 10.6641 RHOB 5,1562 IbM -999.~00 GR '999. O0 (IR 2.1797 DRHD -999 0 2023 0000 -999 o' ,oo,o 2042,0000 2 9629 -999 2500 -999 2500 0 0205 lq01 0000 4,9609 -999.2500 -999.2500 0.0259 )EP'T rCNb NRAT ~C14L GR NRAT rCNL DEPT SP GR FCNL DEPT -999 4200 00:00. SFL~ !': ! i:':,:ii:!::~i:~'5 0:6:64 79 -999: 624 0000 t:b:D -999 8! 3 520 0 599b 0000 I RNRA 4000 0000 -25 7031 -999 2500 65 8750 3 5625 537 0000 SFLU ~R GR CALl RNRA 3900 '27 -999 99 3 476 000 SFLO 187 GR 2500 GR 1875 CALI 8516 RNRA 0000 3~00 0000 SFLU 25:9375 GR 6 8! -999 13 4 0 D~ 9 NPHI 5,8555 .965 8750 DT 99 2500 DT 1~ 3047 RHOB 8906 NPHI 6 99 -999 14 3 5 2500 DT 1484 RHOB 9199 NPHI 5,160~ IbD 74,250 DT d NCNb 1794 0000 -999 -999 2187 DRHO 0 0 61 1 .,s'o?8.::: .C/Nb : 21,74 40, -9' H:O 0 4 NCNb 2236 6.8047 IbN -999,2500 GE -999;2500 GR 2.~914 DRHO 38.8184 NCNb .9959 ,7500 .2500 -999.2500 0,0303 2090.0000 , 8437 IbM -99 ,2500 GR -q99,2500 GR 2,2402 DRHO 44,6777 NCNb 5 -999 -999 0 1866 250 500 g500 32'/ 0000 6,1406 Ib~ '999,2500 GR ;TING )00 3 ,.~ 4 5 NPH gEXT : Mi;`` · EOF ~* TAP~ TRAILER ** ~ERVICE NAME :EDIT )ATE 3RIGIN 000~ E 9382 ~ONTINUATION ~ 101 ~EXT TAPE NAME ~OMMENTS :LIBRARY TAPE ** REEL TRAILER *~ SERVICE NAME :FDIT DATE 184/07/28 OR~GIN : REEL NAME :REEL ID CONTINUATION # :01 NEXT R~EL NAME ~ COMMENTS ~LI~RRRY TAPE EOF **********
