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Home My WebLink About200-1341 Gluyas, Gavin R (OGC) From:Lau, Jack J (OGC) Sent:Tuesday, March 11, 2025 4:35 PM To:Brodie Wages Cc:Joseph Lastufka; Finn Oestgaard - (C) Subject:RE: D-03A pre-CTD reservoir abandon (Sundry #: 325-041, PTD for D-03B: 225-008) David – After reviewing the CBL dated 28-May-23, I agree the liner is fully cemented. I approve the following changes to the approved procedure: 1) Eliminate CBL 2) Eliminate punches as backside of liner is cemented 3) Attempt to use cement retainer. If unable to use cement retainer, cement job can be done without retainer with a tag of TOC post-cement. Let me know if you have any questions Thanks, Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 OƯice (907) 227-2760 Cell From: Brodie Wages <David.Wages@hilcorp.com> Sent: Friday, March 7, 2025 4:23 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com> Subject: D-03A pre-CTD reservoir abandon (Sundry #: 325-041, PTD for D-03B: 225-008) Hi Jack, After reviewing the approved sundry for the reservoir abandonment of the pre-CTD sidetrack to D-03B, we would like to make some minor changes to the program. The sundry called for a CBL to be run in the 2-7/8” tubing, we were able to find one (attached) run May 2023, would like to eliminate that step The CBL shows very good cement all the way to the top of the 2-7/8” liner, we would like to eliminate punching holes in attempt to establish circulation up the liner backside. 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. 2 Finally, in 2013, service coil has some issues getting into the liner top, we would like to plan for that eventuality with the option to abandon the D-03A reservoir without the cement retainer. The initial attempt will be to use the cement retainer, but if we can’t get it into the liner top, we would then go to the retainerless option. Please let me know your thoughts, we would like to get started on this work March 13th. David Wages Hilcorp – OE – FS2 Cell: 713.380.9836 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. 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By Grace Christianson at 12:57 pm, Jan 29, 2025 325-041 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.01.28 16:05:07 - 09'00' Sean McLaughlin (4311) DSR-1/31/25SFD 2/7/2025WCB 2-4-2025 10-407 *This sundry application approves the work program up through setting of the whipstock. *&: 2/7/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.07 12:51:56 -09'00' RBDMS JSB 021025 To: Alaska Oil & Gas Conservation Commission From:Ryan Ciolkosz Drilling Engineer Date: January 27, 2025 Re:D-03A Sundry Request Sundry approval is requested to set a whipstock and mill a window in the D-03 wellbore as part of the drilling and completion of the proposed D-03B CTD lateral. Proposed plan: See D-03A Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock MIT-T/IA and Caliper. E-line will set a 4-1/2"x5-1/2" whipstock. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2/CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 4-1/2"x5-1/2" whipstock. A dual string (5-1/2"x9- 5/8") 3.80" window + 10' of formation will be milled. The well will kick off drilling in the Kingak and top set in the Shublik. A 3-1/4" protection string will be run to the top of the Shublik. The rig will swap from 2-3/8" to 2" coil and mill out the aluminum shoe with a 2.74" mill. The lateral will land in Ivishak Zone 2 and continue in Zone 2 to TD. The proposed sidetrack will be completed with a 2-3/8" L80 solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in Feb 15th, 2025) x Reference D-03A Permit submitted in concert with this request for full details. 1. Slickline : Run CBL from deviation to TOL @ 9997’ 2. Eline Set 2-7/8” 1 trip cement retainer @ 10,142’ – Confirm with OE TOC behind 2- 7/8” is shallower than set depth. Punch 2-7/8” liner from 10,137’ – 10132’ 3. Coil Stab into retainer & pump 8.0 bbls of Class G cement or equivalent cement and unstab from retainer. Lay in 3.3 bbls of cement while pulling up hole letting cement U-tube in the 2-7/8” & 5-1/2”. Target TOC at 9997’ MD 4 Fullbore WOC and MIT to 1000 psi 5. Slickline Drift for whipstock and Caliper whipstock setting interval 6. E-line : Set 4-1/2" x 5-1/2" Whipstock. Top at 9965' Oriented at 0 deg RHOS 7. Valve Shop : Pre-CTD tree work (install sarber spool, PT swab, leak-tight master) 8. Valve Shop : Bleed wellhead pressures down to zero. 9. Valve Shop : Bleed production, flow and GL lines down to zero and blind flange. 10. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in February 25th, 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,447 psi). 2. Mill 3.80” Window. Perform FIT to 4100 psi equivalent BHP minimum. 3. Drill build section: 4.25" OH, ~50' (18 deg DLS planned) to top of reservoir 4. Run 3-1/2" x 3-1/4" L80 slotted liner with aluminium bullnose shoe 5. Secure well and swap from 2-3/8" to 2" Coil and BOPE rams. Test BOPE 250 psi low and 3,500 psi high. RIH and mill out aluminium shoe 6. Drill build section: 3.25" OH, ~830' (18 deg DLS planned) 7. Drill production lateral: 3.25" OH, ~2225' (12 deg DLS planned). 10-401 PTD rig word is from here down. - WCB 10-403 details are above this line. -WCB 8. Run 2-3/8” L-80 liner 9. Pump primary cement job: 34 bbls, 15.3 ppg Class G, yield 1.33, TOC at TOL. Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : SBHPS, Pressure test liner lap to 1000 psi minimum, set LTP (if necessary). Set live GLVs 3. Service Coil : Post rig perforate (~20’) and RPM. Ryan Ciolkosz CC: Well File Drilling Engineer Joe Lastufka 907-244-4357 Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer Drilling Manager 10/03/24 Monty M Myers By Grace Christianson at 10:45 am, Oct 03, 2024 10-407 SFD 10/4/2024 * BOPE pressure test to 3500 psi. * Variance to 20 AAC 25.112 (i) Alternate plug placement approved with fully cemented liner on upcoming sidetrack and all of the drilling within the BP Oil Pool. DSR-10/10/24MGR16OCT24 RBDMS JSB 020325 To: Alaska Oil & Gas Conservation Commission From:Ryan Ciolkosz Drilling Engineer Date: October 2, 2024 Re:D-03A Sundry Request Sundry approval is requested to set a whipstock and mill a window in the D-03 wellbore as part of the drilling and completion of the proposed D-03B CTD lateral. Proposed plan: See D-03A Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock MIT-T/IA and Caliper. E-line will set a 4-1/2"x5-1/2" whipstock. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2/CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 4-1/2"x5-1/2" whipstock. A dual string (5-1/2"x9- 5/8") 3.80" window + 10' of formation will be milled. The well will kick off drilling in the Kingak and top set in the Shublik. A 3-1/4" protection string will be run to the top of the Shublik. The rig will swap from 2-3/8" to 2" coil and mill out the aluminum shoe with a 2.74" mill. The lateral will land in Ivishak Zone 2 and continue in Zone 2 to TD. The proposed sidetrack will be completed with a 2-3/8" L80 solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Ivishak perfs. This Sundry covers plugging the existing perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in Oct 20th, 2024) x Reference D-03A Permit submitted in concert with this request for full details. 1. Slickline : Drift for whipstock and Caliper whipstock setting interval 2. E-line : Set 4-1/2" x 5-1/2" Whipstock. Top at 9965' Oriented at 0 deg RHOS 3. Valve Shop : Pre-CTD tree work (install sarber spool, PT swab, leak-tight master) 4. Valve Shop : Bleed wellhead pressures down to zero. 5. Valve Shop : Bleed production, flow and GL lines down to zero and blind flange. 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in December 2024) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,447 psi). 2. Mill 3.80” Window. 3. Drill build section: 4.25" OH, ~50' (18 deg DLS planned) to TSAG 4. Run 3-1/2" x 3-1/4" L80 solid liner with aluminium bullnose shoe (swap to VBRs and test prior to running liner) 5. Secure well and swap from 2-3/8" to 2" Coil and BOPE rams. Test BOPE. RIH and mill out aluminum shoe 6. Drill build section: 3.25" OH, ~830' (18 deg DLS planned) 7. Drill production lateral: 3.25" OH, ~2225' (12 deg DLS planned). 8. Run 2-3/8” L-80 liner 9. Pump primary cement job: 24 bbls, 15.3 ppg Class G, TOC at TOL*. Sundry 324-577 ,p y This completion will completely isolate andppg(p abandon the parent Ivishak perfs. PTD 224-129 * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : SBHPS, set LTP* (if necessary). Set live GLVs. 3. Service Coil : Post rig perforate (~20’) and RPM. Ryan Ciolkosz CC: Well File Drilling Engineer Joe Lastufka 907-244-4357 Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer PBU D-03A SFD 10/4/2024 200-134 324-577 SFD 10/4/2024 Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/02/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230416 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPB-15 50029213740000 185121 5/16/2021 READ Caliper Survey MPC-02 50029208660000 182194 4/26/2023 READ Caliper Survey MPE-15 50029225280000 194153 4/17/2023 READ Caliper Survey MPE-15 50029225280000 194153 4/21/2023 READ Caliper Survey MPL-40 50029228550000 198010 4/18/2023 READ Caliper Survey PBU D-03A 50029200570100 200134 5/28/2023 READ MRCBL PBU L-212 50029232520000 205030 4/14/2023 READ Injection Profile PBU S-210 50029236300000 219057 4/17/2023 READ Injection Profile PBU V-212 50029232790000 205150 5/13/2023 READ Injection Profile Please include current contact information if different from above. T37721 T37722 T37723 T37723 T37724 T37725 T37726 T37727 T37728 PBU D-03A 50029200570100 200134 5/28/2023 READ MRCBL Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.12 14:32:41 -08'00' Imagl~ 'roject Well History File Cover! ge 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. ~ ~ - //,~,'~ ¢ Well History File Identifier RESCAN DIGITAL D~A-TA. OVERSIZED (Scannable) [] .,r items: ~ Diskettes, No. 1 [] Maps: Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type [] BY: BEVERLY ROBI~HERYL MARIA WINDY Project Proofing BY: BEVERLY ROBI~SHERYL MARIA WINDY Scanning Preparation Other items scannable by large scanner OVERSIZED (Non-Scannable) [] [] Logs of various kinds Other /s/~ = TOTAL PAGES BY: BEVERLY RO ERyL MARIA WINDY -- Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: d~ ' BY: PAGE COUNT MATCHES NUMBER IN SCANNI;G pvREPARATION'" '-- T .-/~~YES-~-J~s, NO BEVERL O~~INOENT SHERYL MARIA WINDY DA E:~-~-:~ %% Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCJ~ERE FOUND: A~Es ~ ,NO RESCANNEDBY~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or Comments about this file: Is~ Quality'Checked 12/10/02Rev3NOTScanned.wpd • bp BP Exploration (Alaska) Inc. k Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 a -/ March 06, 2011 MAR 1 €Z011 T' -031 : 1 Mr. Tom Maunder iRECEIVEC Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 4 R 9 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB D Pad i' < ' �� ` "k5ssion Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing extemal corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 03/04/11 Corrosion • Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbls ft na gal 0-01 A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 de,0000 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 D -05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 0-10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 D -11 B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 D -12 1800150 50029204430000 NA 1.3 NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 . D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 D -17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -19B 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 D -20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 0-21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 D -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 D -24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 D -27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 0-29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D -31A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 0-33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 OPERABLE: D-03A (PTD #2000) Tubing integrity restored Page 1 of 1 Re James B DOA 99- ( ) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, November 21, 2007 7:15 AM ~~` C~-~3`~ j1 ~~~a 1 To: Regg, James B (DOA); Maunder, Thomas E (DOA) C Subject: OPERABLE: D-03A (PTD #2001340) Tubing integrity restored Jim and Tom, D-03A (PTD #2001340) has been classified as Under Evaluation due to a failing TIFL on 11/08/07. On 11/19/07, slickline set DGLVs in STA # 3 & 4 and fullbore conducted an MIT-IA to 3000 psi. This subsequent MIT-IA on 11/20/07 passed ~- confirming that tubing integrity has been restored. The well has been reclassified as Operable with normal MAASP of 2000/1000 on the IA/OA and may be put on production when convenient. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~~~~~~~ NOV ~ ~ 2007 11 /26/2007 PfJ¿ Ã'.V)t?£ STATE OF ALASKA ('vII ALA. OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS RECEIVED SEP 2 0 2006 Alaska Oil & Gas Cons. Commission 1. Operations Performed: Anchorage o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 200-134 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20057 -01-00 7. KB Elevation (ft): 58.22' 9. Well Name and Number: PBU D-03A 8. Property Designation: 10. Field / Pool(s): ADL 028285 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11355 feet true vertical 9003 feet Plugs (measured) None Effective depth: measured 11292 feet Junk (measured) None true vertical 9006 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 30" 100' 100' Surface 2289' 20" 2289' 2289' Intermediate 4430' 13-3/8" 4430' 4204' 3090 1540 Production 1 0429' 9-5/8" 10429' 8840' Liner 1358' 2-7/8" 9997' - 11355' 8459' - 9003' 13450 13890 2 6 2rfit ~t;ANNG.~ SEP '10";'; Perforation Depth MD (ft): 10820' - 11281' Perforation Depth TVD (ft): 9011' - 9007' 4-1/2", 12.6# x 5-1/2", 17# x 13Cr80 1L-80 10389' Tubing Size (size, grade, and measured depth): 4-1/2" 12 R# Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker 'S-3' packer; 9-5/8" x 4-1/2" Baker 9213' & 10212' packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pulled tubing at -9283'. Cut and pulled 11-3/4" x 10-3/4" x 9-5/8" at -1845'. Cut and pulled 13-3/8" at -1884'. Run 13-3/8" tieback to surface. 1st attempt to cement failed. Perfd 1654'- 1664'. Cement w/327 Bbls LiteCrete (Yield=3.09) (1836 cu It /594 sx). Run 9-5/8" tieback to surface. Cement w/120 Bbls Class 'G' (Yield=1.16) (674 cu It /581 sx). Cut and pulled tubing at 9306'. Run 4-1/2" tubing, overshot at 9308'. 13. Representative Dailv AveraQe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o 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: Contact Doug Cismoski, 564-4303 306-204 Printed Name Terrie Hubble Title Technical Assistant Signature--1ó!lAì 0 th ~Æ.$ 09( ~ Prepared By Name/Number: Phone 564-4628 Date ZQDv-rerrie Hubble, 564-4628 Form 10-404 Revised 04/2006 ORIGINAL RBDMS 8Fl SEP 25 2006 Submit Original Only Digit~l Wellfile . Well Events for SurfaceWell - D-03 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC1 -> D -> D-03 Date Range: 29/May/2006 to 03jJul/2006 Data Source(s): DIMS, AWGRS Events Source Well AWGRS D-03A AWGRS D-03A AWGRS D-03A AWGRS D-03A AWGRS D-03A AWGRS D-03A Date 07/03/2006 07/02/2006 07/01/2006 06/30/2006 06/29/2006 06/28/2006 AWGRS D-03A 06/28/2006 AWGRS D-03A 06/26/2006 AWGRS D-03A 06/18/2006 AWGRS D-03A 06/16/2006 AVVGRS D-03A 06/15/2006 AWGRS D-03A 06/15/2006 AWGRS D-03A AWGRS D-03A AWGRS D-03A AWGRS D-03A 06/14/2006 06/14/2006 06/12/2006 06/11/2006 . Page 1 of 2 Description TIO/OO/OOO = SSV/O/O/O/O. Temp S/I. Pre-Rig Eva!. Removed Hurculite cellar liner. Vacced water out of cellar (85 bbls). Guzzled 4yds gravel out of cellar. TIO/OO/OOO = SSV/O/O/O/O. Temp = SI. Cut out herculite liner (pre-RWO). Vac'd out water from cellar, water flowing back into the cellar. Liner removal put on hold. 6' from top of cellar boards to cellar bottom. T/I/O/OO/OOO = SSV/O+/O+/O+/O+ Temp=S/I Eval for cellar liner (Pre Rig) Well house, scaffolding and flow line have been removed. Cellar is approx. 8' x 14' x 5 1/2 feet deep to what feels like a gravel bottom underneath a herculite liner and is full of water (5'). Any further evaluation may need to be coordinated with a vac truck to keep water evacuated. TIO = SSV/O/O. Temp = SI. Eval cellar for liner, is flow line off? Timber frame rectangular liner measures 13' x 7' 9". Flow line is detached from the well head. Top of conductor is '" 5" below the surface of the cellar water; cellar water is 4' to 4-1/2' deep. TIO = SSV/O/O. Temp = SI. Eval cellar for liner. Water in cellar is 4' to 4-1/2' deep, all of the way around the well; muddy bottom. I-beam cellar box is 12' x 15'. Existing wooden in-lay liner box is 12' 6" x 7' 11". T/I/OA/OOA/OOOA = PPPOT/T Passed PPPOT/IC Failed Pre-Rig Wellhead MIT PPPOT- T: Bled tubing hanger void to "0". Functioned lock down pins, (5) approximately 180 degrees of each other, were unable to move. All five were flagged. The remainder of the pins functioned well.lnstall test pump and test void to 5000 psi for 30 minutes.Test pass. Note: On RWO, after adapter is removed the lock down pin noses will be ground to allow removal of hanger. PPPOT-IC: Bled 9 5/8" casing void to "0". Functioned all lock down pins. All functioned well with no sign of any bent or broken pins. Install test pump and attempt to test void to 3000 psi. Pressure would achieve only 200 psi. Pump plastic packing to energize seal. Attempt to pressure test void again, pressure would not increase beyond 1000 psi and bled immediately to 200 psi. Test Failed. PPPOT-C: Attempt to bleed 13 5/8" casing void. Bleeder screw head broke off due to metal fatigue. Bleeder screw was never opened, No test was attempted due to not being able to bleed void, T/I/0/00/000=SSV/7/0+/0+/0+. Temp=SI. check FL in cellar. (For WIE). Cellar has 29" of water in it. 3 weeks ago I watched the cellar being pumped out, it took 20 minutes to fill back up. T/I/O/OO/OOO= 15/40/40/40/40 Temp=S/1 Bleed WHP's to 0 psi (Pre Cam) All fluid levels close to surface. Bled lAP to 0+ in 1 Hr. All others bled to 0+ in 30 min or less, each. All gas. FWHP=O+/O+/O+IO+/O+ ***NOTE*** OOA and OOOA are under water. T/I/O/OO/OOO= 10/30/0+/60/60. Temp= SI. WHP's (pre-CAM). Integral installed on IA. Poorboy rigged up to IA coming from well 24. T/I/O/OO/OOO = 20/5.5/6/90/100. SI. TBG & IA FL (pre rig circ-out). TBG FL @ 36', IA FL @ 24'. T/I/O/OO/OOO = 50/6/6/90/100. SI. TBG, IA & OA FL (pre rig eirc-out). TBG FL @ Surface, IA FL @ 24', OA FL @ 36'. **Continued from previous days AWGRS*** Circ out T x IA , CMIT T x IA x OA to 1000 psi. FAIL **Established LLR of 1.4 BPM @ 1000 psi** (RWO prep) pump remaning 158 bbls of the 1258 bbls 1 % KCL down TBG, up lA, through jumper line to the flowline on well # 24. U- Tubed 190 bbls DSL to freeze protect TBG & IA. ***CMIT T x IA x OA Pressured up TBG & IA w. 162 bbls DSL (Could not hold pressure to do test) Established LLR of 1.4 BPM @ 1000 psi.) *** Final WHP's=300/0/0/100/140 T/I/0=400/100/180/100/140 Circ out T x IA , CMIT T x IA to 3500 psi., MIT x OA to 1000 psi. (RWO prep) Pumped 5 bbls neat meth followed by 1100 bbls of 1% KCL down TBG, up lA, through jumper line to the flowline on well # 24. ***Continued on 6-15-06 WSR*** Circ-Out---Did Not Pump-nHardline and Casasco not rigged up yet T/I/0/00/000=200/590/590/80/80. Temp=SI. WHP's & FL's for E-line. (Chem cut). TBG FL @ 1974' (74 bbl). IA FL @ 102' (3 bbl). OA FL @ 96' (6 bbl). TP has increased 70 psi in 2 days. lAP has increased 100 psi in 2 days. OAP has increased 100 psi in 2 days. OOAP has decreased 20 psi in 2 days. OOOAP has decreased 20 psi in 2 days. ***NOTE*** FO and E- Line have been working on the well and bleeding WHP's so the pressure increased and decreased do not accurately represent what the well is doing. Cellar has been Vac'ed out partially but the OOOA valve still can not be seen due to the cellar liner and water. SHOT STRING SHOT FROM 9272' - 9284', TUBING PUNCHER SHOT FROM 9265' - 9267'.T/ II hUp:/ / digi talwellfile. bpweb. bp.comIW ellEvents/Home/Default.aspx 9/20/2006 Digital Wellfile AWGRS D-03A 06/10/2006 AWGRS D-03A 06/08/2006 AWGRS D-03A 06/02/2006 AWGRS D-03A 05/30/2006 AWGRS D-03A 05/30/2006 AW~ßS D-03A OS/29/2006 AWGRS D-03A OS/29/2006 Page 2 of 2 . . o = 150/ 500/ 450 PRIOR TO SHOOTING TUBING PUNCHER. T/ 1/ 0 = 730/ 1200/ 1250. SET PLUG AT 9299'. SET HALIBURTON 4.37" FAS-DRILL PLUG AT 9299' MID-ELEMENT DEPTH. TUBING PUNCHER #2 SHOT FROM 9258'-9260'. CHEMICAL CUT TUBING AT 9283'. Job complete... T/I/0/00/000=130/490/490/100/100 Temp=SI Eval cellar for water and overall depth. Cellar has 3' 2" of water. The overall depth is 3'10". T/I/0/00/000=sSV/490/490/100/100. Temp=SI. FL's,Eval for Bleed WHP's to 0 psi, Eval for liner, pre-CAM, RWO). TBG FL @78' (3 bbl). IA FL @ 96' «3 bbl). OA is @ 90' (6 bbl). OOA is @ Surface. OOOA is @ 240' (42 bbl). Cellar was being pumped out when I arrived, 20 minutes later the cellar was full of water again. OOA & OOOA gauges are both remote gauges plumbed with 3/8 stainless tubing. The OOOA tubing fitting on the casing valve seems to be leaking, bubbles can be seen directly above the connection. Cellar is full of water and the fitting can not be reached from the cellar boards. Cellar has a liner in it already but liner has holes in it. LOG SCMT TO DETERMINE TOP OF CEMENT IN THE 9-5/8" X 5.5" ANNULUS FROM A PACKER SQUEEZE. NO SIGNIFICANT CEMENT ABOVE GLM#2. TOP OF CEMENT IN IA AT 9416' ELM. FREE PIPE AT 9414' ELM Post Job T/I/O = 100/500/450 ***JOB COMPLETE / WELL LEFT SHUT IN*** ***W5R continues from OS/29/06*** T/I/O/OO/OOO=- 2075/500/460/100/140. ASSIST SLICKLINE; PT TBG plug [failed] Final WHP= 200/500/460/100/120. ***CONT FROM 5-29-06*** SET 3" LTTP @ 9990' sLM W/ 2 1/2 INTERNAL G FN & 4" EXTERNAL G FN FOR COIL(5000# shear disc). LRS PRESSURE UP TO 500 PSI, PRESSURE KEPT FALLING OFF, ATTEMPTED TEST A FEW TIMES W/ NO SUCCESS. ATTEMPTED FOR 2 HRS TO PULL LTTP, NO SUCCESS. DECIDED TO TAP CORE DOWN AGAIN ON SEAT AND LEAVE IT. HAVE BEEN GmING GAS BACK WHEN BLEEDING OFF. LRS PUMPED 250 BBLS KCL AND APPROX. 80 BBLS DIESEL TOTAL ***GIVE WELL BACK TO DSO. LEFT SI*** T/I/O/OO/OOO =- 2075/500/460/100/140. Assist Slickline. Pumped 6 bbls meoh, 220 bbls 1% kcl, 89 bbls diesel down the Tbg. Pump another 50 bbls of diesel to pressure up on TTP (not holding) ***WSR continues on 05/30/06*** ***WELL 5/1 ON ARRIVAL*** (pre rwo) DRIFTED W/ 4.50" CENT TO LINER TOP @ 9987' SLM. RAN CALIPER FROM LINER TO SURFACE. SET 3" LTTP @ 9993' SLM (run 2 1/2 gs to set & pull. 4" gs fn on outside for coil if needed). UNABLE TO ACHIEVE 500 PSI ON LTTP, PULLED LTTP CURRENTLY ATTEMPTING TO LTTP AGAIN ***CONT ON 5-30-06*** http://digitalwellfile . bpweb. bp.comIW ellEvents/Home/Default.aspx 9/20/2006 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 D-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 7/23/2006 16:30 - 17:30 17:30 - 18:30 18:30 - 20:00 20:00 - 20:30 20:30 - 22:00 22:00 - 00:00 7/24/2006 00:00 - 00:30 00:30 - 03:00 03:00 - 04:00 04:00 - 04:30 04:30 - 05:30 05:30 - 06:30 06:30 - 08:00 08:00 - 08:30 08:30 - 10:30 10:30 - 14:00 14:00 - 18:00 18:00 - 19:00 19:00 - 20:00 7/25/2006 20:00 - 21 :00 21 :00 - 22:30 22:30 - 00:00 00:00 - 02:00 02:00 - 08:30 1.00 MOB P 1,00 MOB P 1.50 MOB P 0.50 WHSUR P 1.50 KILL N 2.00 KILL P 0.50 KILL P 2.50 KILL P 1.00 KILL P 0.50 KILL P 1.00 WHSUR P 1.00 BOPSU P 1.50 4.00 BOPSU 1.00 BOPSU 1.50 BOPSU 1.50 BOPSU 2.00 BOPSU 6.50 BOPSU PRE PRE PRE DECOMP WAIT DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Finish RID of Cellar. Pull Forward off Well D-14a and Travel Down Pad to D-03. Back Rig Up to Well D-03. Spot Rig. Level and Shim Rig. Lay Secondary Containment and Spot Slop Tank. RlU Double Annulus Valve. RlU Circulating Manifold and Hoses to IA and Tree Cap. Spot #2 Mud Pump, and #4 Generator Module. Accept Rig at 20:00 hrs 7/23/06. P/U BPV Lubricator. Verify Pressure on IA and OA = Zero psi on both. Pull BPV. Approximately 10 psi on tubing. UD BPV Lubricator. Bleed Down Tubing Pressure to Bleed Tank. Wait on all Seawater to Arrive on Location Take on SW and Test Lines to 2500 psi. Found Leak on Stem Packing on Master Valve of tree. Call Out VECO Valve Crew. Pressure Test All Circulating Equipment to Valve on top of Tree. VECO Valve Crew on location and C/O Master Valve Packing Stem. Pressure Test Clrc Hoses, Manifold, and Tree to Master Valve to 1000 psi. Circulate Out Diesel Freeze Protect. Circulate down IA first and take Diesel Out of Tubing. Swap to Tubing and Pump 40 bbl Hi Visc Sweep and Chase with 750 bbls of 120 deg Seawater. Pump Rate 10 bpm @ 750psi. Monitor Well for 15 mins and B/D and RID all Lines. Well on Vac, RlU and Pump Down Tbg. Est 108 bbl 1 hr Loss Rate. RID Lines and Set TWC and Test to 1000 psi. Wait on Orders. Decided to Set Plug in SSSV. Call Out DSM for Lubricator to Pull TWC. Wait on DSM to pull TWCwl Lubricator PIU DSM Lubricator and Pull TWC. Tubing on Vac Wait on Slickline to arrive on Location. Slickline on location. PJSM. Rig Up Extension to tree, Pump In Sub, BOP's and Lubricator. Slickline Brush SSSV, Set Plug in SSSV at 1938' and Set Prong. PT to 1000 psi from Above. RID SLickline. Install Two Way Check, Tested TWC to 1,000 psi From Above. Good Test. NID Tree and Adapter Flange. Check IJ4S XlO (Make up) Function Test L.D.S. Nipple Up Spacer Spool and BOPE Continue to Nipple Up Spacer Spool and BOPE. Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by John Crisp. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- Annular Preventer, Choke HCR, Kill HCR, Upper IBOP. Test #2-Manual Choke, Manual Kill, Lower IBOP. Test #3- Choke Valves 1, 12, 13, 14 Test #4- Choke Valves 9-11 and Blinds. Test #5- Choke Valves 5-8-10, TIW Valve Test #6-Choke Valves 4-6-7,and Dart Valve Printed: 8/28/2006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 D-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 Test #7- Choke Valve 2. Test #8- Choke Valve 3 Test #9- 5-112" Test Joint in VBR's Test #10- 7" Test Joint in VBR's Accumulater Test- 2,950 psi Starting Pressure, 1,800 psi After Actuation, First 200 psi in 13 seconds, Full Pressure in 1 Minute 10 Seconds. 5 Nitrogen Bottles at 2,250 psi. 08:30 - 10:30 2.00 BOPSU DECOMP 4-1/2" x 7" VBR's did not test with 7" Test Joint. Pull rams and replace. 10:30 - 11 :30 1.00 BOPSU DECOMP Test new VBRs with 5-1/2" and 7" Test Joints to 250 psi Low and 3500 psi High. 11 :30 - 14:00 2.50 BOPSU WAIT DECOMP Wait on Veco Valve Crew 14:00 - 14:30 0.50 BOPSU DECOMP RlU Veco Lubricator and Pull TWC. 14:30 - 15:30 1.00 DHB DECOMP PJSM with SWS Slickline and Rig Crew. Rig Up SLickline. Shooting Nipple, Pump In Sub, Valve, BOP and Lubricator. 15:30 -18:30 3.00 DHB N WAIT DECOMP Riser Extension from Shooting nipple had a valve with plug that hit inside the bowl when made up tight against the pipe rams. Had to locate suitable replacement for extension and bring to location. 18:30 - 20:00 1.50 DHB P DECOMP RIH Retrieve Prong, Second Run Retrieved Plug @ 1,931' In SSSV. 20:00 - 21 :00 1.00 DHB P DECOMP RID Wire Line Crew. 21 :00 - 22:00 1.00 PULL P DECOMP Reverse Circulate 244 bbls at 10 bpm, w/1 ,260 psi. RID B/D Surface Equipment. 22:00 - 00:00 2.00 PULL P DECOMP M/U XO to Hanger, B.O.L.D.S. Attempt to Pull Hanger to Rig Floor 7/26/2006 00:00 - 02:00 2.00 PULL P DECOMP Attempt to Pull Tubing Hanger to Rig Floor. Pull Hanger Free w/280,OOO# Up Weight. 02:00 - 05:30 3.50 PULL P DECOMP Pull Hanger Free, Unable to Pull to Rig Floor. Worked Pipe Maximun Pull 300,000# Up Weight, Indication of Incomplete Chemical Cut at 9,283'. 05:30 - 07:30 2.00 PULL P DECOMP UD 1 JT Drill Pipe w/lJ4S Tubing XC, Clear Tools flRig Floor In Preparation For SWS to Rig Up. 07:30 - 11 :30 4.00 PULL N DPRB DECOMP N/D Flow Line and Bell Nipple. RlU 13 5/8"x 7" Otis Quick Connect Shooting Flange to Annular Preventer. 11 :30 - 15:30 4.00 PULL N WAIT DECOMP Waiting On SWS Crew to Arrive Remove Riser Flange, Install Shooting Flange To Hydril 15:30 - 20:00 4.50 PULL N DPRB DECOMP PJSM wI SWS E-line Crew, RlU E-Line Sheaves and Full Pressure Control Equipment .Tested Surface Equipment to 2,000 psi. 20:00 - 23:00 3.00 PULL N DPRB DECOMP PJSM with E-line Crew and Rig Crew on Cutting Tubing, RIH wlCCL and Jet Cutter, Cut at 9,290' 23:00 - 00:00 1.00 PULL N DPRB DECOMP RID E-Line and Pressure Control Equipment. 7/27/2006 00:00 - 01 :00 1.00 PULL N DPRB DECOMP N/D Shooting Flange, N/U Circulating Spool and Riser 01 :00 - 01 :30 0.50 PULL N DPRB DECOMP Make Up jt DP and XO to IJ4S, M/U to tbg Hanger. 01 :30 - 02:00 0.50 PULL N DPRB DECOMP BOLDS, Pull Hanger to Rig Floor, 280,000# Up Weight to Pull out of Hanger, 260,000# String Weight. 02:00 - 03:30 1.50 PULL P DECOMP CBU 12 bpm @480 psi with 60 bph Loss Rate, RlU to UD Tubing. Approx 40 bbls of Diesel Back to Surface. 03:30 - 04:00 0.50 PULL P DECOMP UD DP, IJ4S and Tubing Hanger, Changed Out Elevators, Printed: 8/28/2006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 D-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 7/27/2006 04:00 - 08:30 4.50 PULL P DECOMP PJSM with Control Line Spooler and Rig Crew On UD 7" Tubing with Control Lines. UD 7" Tubing. 08:30 - 09:00 0.50 PULL P DECOMP Change Elevators and Tong Dies to 5.5". 09:00 - 09:30 0.50 PULL P DECOMP UD SSSV, and Control Line Spooling Equipment. 09:30 - 11 :30 2.00 PULL P DECOMP UD 5.5" Tubing to 6,244'. 11 :30 - 12:30 1.00 PULL P DECOMP Attempt to Pull Tubing, Worked Stuck Pipe, Cut Joint at 6,246', First GLM at 52' below Rotary Table. 12:30 - 14:30 2.00 PULL P DECOMP PJSM on Operation Change, RIU and Pumped Safe Lube Pill at 5 bpm with 180 psi,Through Kill Line. Suspect Collapsed Casing Close to Surface Ordered out Swedging Tools f/Baker. 14:30 - 15:00 0.50 PULL P DECOMP Continue to Work Stuck Pipe 15:00 - 16:30 1.50 PULL P DECOMP P/U BHA #1, Swedge, Jars, Bumper Sub, 1 Drill Collar. 16:30 - 21 :00 4.50 PULL P DECOMP Free Stuck Pipe, and Work Tight Spots with Swedge, Pump Additional 10 bbls Safe Lube Pill. 21 :00 - 22:00 1.00 PULL P DECOMP Change Out Jars, Pick Up Another Drill Collar. Inspect Top Drive and Derrick. 22:00 - 22:30 0.50 PULL P DECOMP Continue to Work Swedge Hole Conditions Improving. 140,000# Working String Weight, Max Pull 260,000# 22:30 - 00:00 1.50 PULL P DECOMP UD 5.5" TBG f/6,244' to 5,826'. 7/28/2006 00:00 - 00:30 0.50 PULL P DECOMP Service Rig and Derrick Inspection. 00:30 - 07:30 7.00 PULL P DECOMP Pull 5.5" TBG. Tubing Pulled Tight on First GLM out of Hole, Worked pipe and Maximum Overpull was 50,000# Over String Weight of 105,000#. Pulled Tight On Second GLM out of Hole, Worked Pipe to Maximum of 30,000# over String Weight of 80,000#. 07:30 - 08:00 0.50 PULL P DECOMP Lay Down Cut Jt, Length=26.97' 08:00 - 08:30 0.50 PULL P DECOMP Clear Tubing Tools flRig Floor. 08:30 - 09:30 1.00 PULL P DECOMP Clear and Clean Rig Floor. 09:30 - 10:00 0.50 PULL P DECOMP Install Wear Ring, RILDs 10:00 - 10:30 0.50 PULL P DECOMP Rig Service 10:30 - 11 :00 0.50 PULL P DECOMP Prepare to Pick Up BHA, Bring Tools to Rig Floor. 11 :00 - 12:00 1.00 CLEAN P CLEAN P/U BHA #3, 8" Casing Swedge w/ 6 3/4" Drill Collars. 12:00 - 13:00 1.00 CLEAN P CLEAN RIH Swedged Tight Spot at 52' in on BHA #3. 13:00 - 14:00 1.00 CLEAN P CLEAN UD BHA #3, P/U BHA #4, BHA Consists of Bull Nose, XO, String Mill, LBS, Fishing Jars, XO, 9-6.25" Drill Collars, XO. BHA=309.2' 14:00 - 14:30 0.50 CLEAN P CLEAN RIH w/MiII Tag up at 35' in. Up Weight=45,000#, Down Weight=45,000#, Rotating Weight-45,000#. 14:30 - 15:00 0.50 CLEAN P CLEAN Establish Circulation, Pump 5 BPM 30 psi, WOO 15:00 - 21 :30 6.50 CLEAN P CLEAN Mill Tight Spots fl 35' to 73' Pumping at 5 bpm, 85 rpm, 5-8,000 ft-Ibs Torque. Fell Through at 83', Back Reamed to 30', RIH no Rotation with 12-20,000# Down Weight. Took Weight to 74' Weight dropped off to 5,000# to 85'. 21 :30 - 22:00 0.50 CLEAN P CLEAN POOH Stand Back Milling Assembly. 22:00 - 23:00 1.00 CLEAN P CLEAN C/O Saver Sub to 5". 23:00 - 23:30 0.50 CLEAN P CLEAN Clear and Clean Rig Floor. 23:30 - 00:00 0.50 CLEAN P CLEAN RIU and Test TiW and Dart Valves for 5" Drill Pipe String. 250 Low, 3,500 High Test. 7/29/2006 00:00 - 00:30 0.50 CLEAN P CLEAN Service Rig. 00:30 - 01 :00 0.50 CLEAN P CLEAN Test Dart Valve for 5" Drill String. 250 Low 3,500 High Test. 01 :00 - 03:00 2.00 CLEAN P CLEAN P/U M/U BHA Work Through Tight Spot. f/34' to 73' Reamed area. 03:00 - 09:00 6.00 CLEAN P CLEAN P/U 5" Drill Pipe From Pipe Shed 1x1. Tight Spot at 1,939' Printed: 8/28/2006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 D-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 7/29/2006 03:00 - 09:00 6.00 CLEAN P CLEAN Reamed Through with80 rpmat 3,000 ft-Ibs Torque, With5 bpm and 230 psi, Continue to RIH to 5,154'. 09:00 - 10:30 1.50 CLEAN P CLEAN Load Strap and Tally 150 jts of 5" DP in Pipe Shed. 10:30 - 15:00 4.50 CLEAN P CLEAN PIU 5" Drill Pipe From Pipe Shed 1x1 and RIH to 9,242'. 15:00 - 16:30 1.50 CLEAN P CLEAN Pump Hi-Vis Sweep @ 8 bpm 390 psi. Losses 48 bph. 16:30 - 17:00 0.50 CLEAN P CLEAN PIU 2 jts DP and Tag Stump at 9,290' 17:00 - 18:30 1.50 CLEAN P CLEAN Slip and Cut Drilling Line and Service Rig. 18:30 - 22:00 3.50 CLEAN P CLEAN Back Out and Blow Down Top Drive, POOH 22:00 - 22:30 0.50 CLEAN P CLEAN Working Milling Assembly Through Tight Spot. After Pulling Mill to rig Floor Unable To go Back Through Tight Stop. Able to get Back Through with Rotation. 22:30 - 23:30 1.00 CLEAN P CLEAN Added Second Watermelon Mill to Tighten up Assembly. UD 1 Drill Collar. 23:30 - 00:00 0.50 CLEAN P CLEAN Started Milling at 34' to 74'. 7/30/2006 00:00 - 02:00 2.00 CLEAN P CLEAN Continue to Mill Between 34'and 75' With Double 8.5" Watermelon Mills. With 60 rpms, 7,000 ft-Ibs Torque, 3,000# wob, 5 bpm at 40 psi. Still Unable to Work Mills Through Tight Spot Taking 20,000# Down Weight to get through. 02:00 - 02:30 0.50 CLEAN P CLEAN UD String Mills P/U 8.125" Swedge. 02:30 - 03:00 0.50 CLEAN P CLEAN Ran Swedge Through Tight Spot No Problems. POH UD Swedge. 03:00 - 03:30 0.50 CLEAN P CLEAN P/U 9 5/8" RTTS. 03:30 - 06:30 3.00 CLEAN P CLEAN RIH With 9 5/8" RTTS. No Problem going Through Tight Spot at 34' to 75'. RIH to 2,200' for Pressure Test. Attempted to Set RTTS at 2,200'. Unable to Set RTTS RIH wrrhree Stand DP to 2,640' Good Set. 06:30 - 07:00 0.50 CASE P DECOMP Attempted to Test Below RTTS unable to obtain 3,500 psi Test. Tested Above The RTTS to Surface to 1,000 psi Good Test, This Test Had Commuication To The 95/8" x 13 3/8" Annulus Through 9 5/8" CSG Between 34' and 75' Thus Testing the 13 3/8" CSG Shoe. 07:00 - 09:00 2.00 CASE P DECOMP RIH to 6,000' Set RTTS. 09:00 - 09:30 0.50 CASE P DECOMP Test Below The RTTS, NO Test. 09:30 - 11 :00 1.50 CASE P DECOMP RIH to 9,140' Set RTTS. 11 :00 - 12:00 1.00 CASE P DECOMP Test Below RTTS, NO Test, Tested Above the RTTS to Surface Good 1,000 psi Test for 30 minutes. 12:00 - 15:30 3.50 CASE P DECOMP POOH f/9,140'. 15:30 - 16:30 1.00 CASE P DECOMP Stand back Drill Collars, UD RTTS. 16:30 - 17:30 1.00 DHB P DECOMP P/U RBP and 3 Stand of Drill Collars. 17:30 - 21:30 4.00 DHB P DECOMP RIH w/RBP to 9,240' and Set RBP. 21:30 - 22:00 0.50 DHB P DECOMP Set Top of RBP @ 9,234' Bottom of RBP at 9,243' Set with 15,000# Down Weight. 22:00 - 22:30 0.50 DHB P DECOMP Test Above RBP to 1,000 psi for 30 minutes. Good Test. 22:30 - 00:00 1.50 CLEAN P DECOMP Blow Down Top Drive and Kill Line. POOH f/9,240' to 8,040'. 7/31/2006 00:00 - 03:00 3.00 CLEAN P DECOMP Continue to POOH f/8,040' with RBP Running Tool. 03:00 - 04:00 1.00 CLEAN P DECOMP P/U RBP #2. 04:00 - 09:30 5.50 DHB P DECOMP RIH w/RBP #2 to 9,200'. 09:30 - 10:00 0.50 DHB P DECOMP Set RBP #2 @ 9,204'. Test to 1,000 psi. 10:00 - 14:00 4.00 DHB P DECOMP POOH. Stand Back Collars, UD RBP Running Tool. 14:00 - 16:30 2.50 EV AL P DECOMP RIU SWS E-line and Test Pack Off and Connections @ 1,000 psi f/5 minutes. 16:30 - 00:00 7.50 EVAL P DECOMP RIH wlUSIT Logging Tools, Logging Up From 9,085' to Surface. Printed: 8/28/2006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 0-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 8/112006 00:00 - 01 :00 1.00 EVAL P DECOMP RIH wlUSIT Logging Tools, Logging Up From 9,085' to Surface for Usit and Corrosion 01 :00 - 03:00 2.00 EVAL P DECOMP Repeat of Corrosion in Hi-Res Mode. 03:00 - 05:00 2.00 EVAL P DECOMP Repeat Pass of US IT. POOH. 05:00 - 06:30 1.50 EVAL P DECOMP RID US IT Tools, RlU String Shot. 06:30 - 08:30 2.00 EVAL P DECOMP RIH wlString Shot Calibrate, Review Logs for Shot Point. Shot at 1,875' POOH wI Wireline 08:30 - 10:00 1.50 EVAL P DECOMP RID Wire Line Equipment. 10:00 - 11 :00 1.00 EVAL P DECOMP P/U and RIH w/RTTS to 1,880'. 11 :00 - 12:00 1.00 EVAL P DECOMP Set and Test Below RTTS to 3,500 psi Held for 30 minutes. 12:00 - 12:30 0.50 EV AL P DECOMP Release RTTS RID Blow Down Top Drive. 12:30 - 13:00 0.50 EV AL P DECOMP POOH 10 stands, 13:00 - 14:00 1.00 EVAL P DECOMP RIH w/RTTS to 1,965' Set RTTS. 14:00 - 15:00 1.00 EVAL P DECOMP Test 9 5/8" Casing Below PBR f/1 ,965' t/9,200, to 3,500 psi for 50 minutes. 15:00 - 15:30 0.50 EVAL P DECOMP Release RTTS RID Blow Down Top Drive. 15:30 - 16:00 0.50 EVAL P DECOMP POOH f/1 ,965' , UD RTTS. 16:00 - 18:30 2.50 EVAL P DECOMP RIH w/RBP Set at 2,600' Top of RBP at 2,595' Bottom of RBP at 2,604'. 18:30 - 19:00 0.50 EVAL P DECOMP Test RBP to 1,000 psi for 10 minutes. 19:00 - 20:00 1.00 EVAL P DECOMP POOH UD RBP Running Tool 20:00 - 20:30 0.50 EV AL P DECOMP Pull Wear Bushing. 20:30 - 22:00 1.50 EVAL P DECOMP RlU and Set Joint of 81/8" Wash Pipe in Slips and Dump 2,200 Ibs of River Sand on Top of RBP. 22:00 - 22:30 0.50 BOPSU DECOMP RlU BOP Test Assembly. 22:30 - 00:00 1.50 BOPSU DECOMP Test BOPE, Choke Manifold, Floor Valves and Top Drive to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test Held for 5 Minutes. AOGCC Witness of Test Waived by Chuck Scheve. Test Witnessed by Doyon Toolpusher and BP WSL. 8/2/2006 00:00 - 02:00 2.00 BOPSU P DECOMP Test BOPE, Choke Manifold, Floor Valves and Top Drive to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test Held for 5 Minutes. AOGCC Witness of Test Waived by Chuck Scheve. Test Witnessed by Doyon Toolpusher and BP WSL. No Failures. 02:00 - 03:00 1.00 BOPSU DECOMP RID Test Assembly, Install Wear Bushing. 03:00 - 04:00 1.00 CLEAN DECOMP P/U Muleshoe and RIH to 2,450' 04:00 - 11 :00 7.00 CLEAN DECOMP Circulate 140 Degree Seawater to Heat 13 3/8" x 9 5/8" Annulus. 11 :00 - 12:30 1 .50 CLEAN P DECOMP POOH from 2,450' 12:30 - 13:00 0.50 CLEAN P DECOMP Pull Wear Bushing. 13:00 - 15:00 2.00 WHSUR P DECOMP N/D BOPE and RemoveTubing Spool. 15:00 - 15:30 0.50 WHSUR P DECOMP Secure 9 5/8" Emergency Slips Together Ensure Recovery When Pulling 9 5/8" Casing. 15:30 - 20:30 5.00 WHSUR P DECOMP NIU Spacer Spools, BOPE, Bell Nipple and Hole Fill Line. 20:30 - 21 :30 1.00 WHSUR P DECOMP RIH with 3 Stands of DC's, P/U 9 5/8" RTTS and Set Below Wellhead at 32'. 21 :30 - 22:30 1.00 WHSUR P DECOMP Test BOPE and Wellhead Connections Against Annular Preventer to 250 psi Low Pressure and 3,500 psi High Pressure. Hold Each Test for 5 Minutes. Good Test. 22:30 - 00:00 1.50 WHSUR P DECOMP Release and Lay Down RTTS, Stand Back DC's. Clear Rig Floor. 8/3/2006 00:00 - 00:30 0.50 CLEAN P DECOMP M/U 8 1/4" Multistring Cutter Assembly. 00:30 - 01 :00 0.50 CLEAN P DECOMP RIH with Multistring Cutter and 4" DP to 2,000' Printed: 8/28/2006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 D-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 8/3/2006 01 :00 - 02:30 1.50 CLEAN P DECOMP Displace Well to Heated 9.8 ppg Brine. 2.5 bpm at 130 psi. 02:30 - 03:30 1.00 CLEAN P DECOMP POOH and Locate 103/4" x 9 5/8" XO at 1,845', Establish Parameters, SPR, 20 spm at 84 psi, 30 spm at 130 psi. Up Weight 90,000#, Down Weight 90,000#, Rotating Weight 90,000#. P/U to 1,781' and Cut 103/4" Casing in Middle of the Second Joint Above 9 5/8" XO. 80 rpm at 4,000 ftllbs Torque, 5 bpm at 800 psi Pump Pressure. 03:30 - 05:00 1.50 CLEAN P DECOMP Monitor Well, Gas Back to Surface. Shut Well In. 90 psi SICP. o psi SIDP. 90 psi on 133/8" x 9 5/8" Annulus. CBU Through Choke at 3 bpm. Shut Pumps Down, 0 psi on SIDP and SICP, No Flow at Shakers. Open Well Up. Gas Breaking Out at Surface, No Flow. 05:00 - 07:00 2.00 CLEAN P DECOMP Monitor Well. No Flow, Gas Breaking Out at Surface. 07:00 - 09:00 2.00 CLEAN P DECOMP POOH with 8 1/4" Multistring Cutter. 09:00 - 11 :00 2.00 BOPSU P DECOMP MIU RTTS and Set Below Wellhead. MIU Test Assembly and Test Annular Preventer to 250 psi Low Pressure and 3,500 psi High Pressure. Hold Each Test for 5 Minutes. Good Test. 11 :00 - 12:00 1.00 CLEAN P DECOMP UD RTTS, UD 8 1/4" Multistring Cutter Assembly 12:00 - 12:30 0.50 CLEAN P DECOMP Clear Rig Floor. 12:30 - 13:30 1.00 CLEAN P DECOMP RIH with Mule Shoe and RTTS. RTTS at 130', Mule Shoe at 1,765'. 13:30 - 16:00 2.50 CLEAN P DECOMP Pump DP Volume Plus 5 bbls of 120 Degree Diesel. Set RTTS. Pump 90 bbls of 120 Degree Diesel up 9 5/8" x 13 3/8" Annulus at 2 bpm at 400 psi. 16:00 - 17:00 1.00 CLEAN P DECOMP Let Heated Diesel Soak Into Artic Pack. 17:00 - 19:00 2.00 CLEAN P DECOMP Pump 120 bbls of 120 Degree 9.8 ppg Brine at 8 - 10 bpm with 2,300 psi Pump Pressure. Pump 68 bbls of 120 Degree Diesel Followed by 120 bbl Safe Surf Pill and 100 bbls of 120 Degree 9.8 ppg Brine. 8 - 9 bpm at 2,000 psi Pump Pressure. 19:00 - 20:00 1.00 CLEAN P DECOMP POOH with RTTS, UD RTTS, UD Muleshoe. 20:00 - 20:30 0.50 CLEAN P DECOMP RIU Handling Equipment for 11 3/4" x 9 518" Thermo Case II. 20:30 - 22:00 1.50 CLEAN P DECOMP M/U Spear Assembly, Engage Casing and Back Out Lock Down Screws. 22:00 - 22:30 0.50 CLEAN P DECOMP Pull Casing to Rig Floor. Came Free at 350,000#. Upweight190,000# with 30,000 - 60,000# Drag. 22:30 - 23:00 0.50 CLEAN P DECOMP Remove 9 5/8" Emergency Slips. 23:00 - 00:00 1.00 CLEAN P DECOMP Release from Spear. Break Out and UD 9 5/8" Thermo Case II Cut Pup. 8/4/2006 00:00 - 00:30 0.50 CLEAN P DECOMP UD Spear Assembly 00:30 - 01 :30 1.00 CLEAN P DECOMP Service Rig, Top Drive Inspection. 01 :30 - 03:00 1.50 CLEAN P DECOMP Wait on Thermo Case II Pup to be Recut, to Use as a Lift Nubin for Pulling Thermo Case II Pipe. 03:00 - 12:00 9.00 CLEAN P DECOMP UD 3 Joints of 11 3/4" x 9 5/8" Thermo Case II Pipe and XO. Joints Were Collasped and Joint #1 was Split. Thermo Case II Casing Connections Broke at 22,000 ftllbs of Torque. UD 10 3/4" Seal Lock Casing. Recovered 3 Joints of Thermo Case II, 38 Joints of 10 3/4" and 21.78' Cut Joint of 10 3/4" Csg. Average Break Out Torque was 35,000 ftllbs. 12:00 - 13:00 1.00 CLEAN P DECOMP Clear and Clean Rig Floor. 13:00 - 14:00 1.00 CLEAN P DECOMP RIH with 5" Muleshoe to 1,780' 14:00 - 15:30 1.50 CLEAN P DECOMP Circulate Around 20 bbl Hi -Vis Sweep Followed by 20 bbl Hi -Vis Sweep Followed by Clean 9.8 ppg Brine. 7 bpm at 100 psi. Printed: 8/28/2006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-03 0-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 8/412006 15:30 - 16:00 0.50 CLEAN P DECOMP POOH with Muleshoe. 16:00 - 17:30 1.50 EVAL P DECOMP RlU SWS Wireline Unit, Shooting Nipple and Pack-off. 17:30 - 21:00 3.50 EVAL P DECOMP Run USIT Log, Tool Failure on First Run. RIH to 1,765' and Log Up and Evaluate Corrosion and Look for Cement. 21 :00·23:30 2.50 EV AL P DECOMP Evaluate Log and RID SWS Equipment. 23:30 . 00:00 0.50 CLEAN P DECOMP Gather BHA # 10. 8/5/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP P/U BHA #10. Bull Nose, XO, Spear w/ 9.90" Grapple, Spear Extension, Stop Sub, Bumper Sub, Fishing Jars, XO, 3 x 6 1/4" DC's, XO, Intensifier. BHA Length = 140.43 01 :00 - 01 :30 0,50 CLEAN P DECOMP RIH with BHA #10 to 1,750'. 01 :30 - 02:30 1.00 CLEAN P DECOMP Cut and Slip 75' of Drilling Line. 02:30 - 03:30 1.00 CLEAN P DECOMP Establish Parameters, Up Weight 77,000#, Down Weight 80,000#, Rotating Weight 81 ,000#. Spear Into Top of 103/4" Stub at 1 ,781 '. P/U Seal Assembly Came Loose at 85,000# 03:30 - 04:30 1.00 CLEAN P DECOMP CBU, 10 bpm and 280 psi. Monitor Well. 04:30 - 06:30 2.00 CLEAN P DECOMP POOH with Seal Assembly. 06:30 - 07:00 0.50 CLEAN P DECOMP UD Spear Assembly. 07:00 - 09:30 2.50 CLEAN P DECOMP UD 10 3/4" Cut Jt 19.25' Long, 1 jt of 10 3/4" Csg, 2 Jts 9 5/8" Csg and Seal Assembly. 09:30 - 10:30 1.00 CLEAN P DECOMP Clear and Clean Rig Floor. 10:30 - 12:30 2.00 CLEAN P DECOMP M/U BHA #11, 6 5/8" Bull Nose, 11 3/4" Multistring Cutter, XC, 9 x 61/4" Drill Collars, XO. Total BHA Lenght = 287.78' 12:30 - 14:00 1.50 CLEAN P DECOMP RIH to 1,897', Establish Parameters, Up Weight 88,000#, 92,000#, Rotating Weight 90,000#, 80 rpm with 2000 - 3,000 ftllbs of Torque. Tag PBR at 1,929' 14:00 - 15:00 1.00 CLEAN P DECOMP Space Out and Cut 13 3/8" Casing at 1,884', 80 rpm 5,000 - 6,000 ftllbs of Rotqry Torque. 7.5 bpm with 700 psi Pump Pressure. 15:00 - 16:00 1.00 CLEAN P DECOMP Break Circulation up 133/8" x 20" Annulus, 8 bpm with 870 psi. Pump 31 bbls of 9.8ppg Brine with 8.4ppg Water Retums. 16:00 - 17:00 1.00 CLEAN P DECOMP POOH with BHA #11. 17:00 - 17:30 0.50 CLEAN P DECOMP UD Multistring Cutter Assembly. 17:30 - 18:00 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 18:00 - 19:00 1.00 CLEAN P DECOMP M/U Muleshoe and RIH to 1,865' 19:00 - 00:00 5.00 CLEAN P DECOMP Circulate 13 3/8" x 20" Annulus, Pumped 189 bbls of 9.8ppg Brine. 50 bbls of 8.4ppg Water Returns, Followed by Gas, Returns Coming Back to Cellar. Shut Down Circulation. Discuss Options With Anchorage. Circulate 133/8" x 20" Annulus. Stage Up from 1 bpm at 60 psi to 14 bpm at 400 psi. 8/6/2006 00:00 - 03:00 3.00 CLEAN P DECOMP Circulate 133/8" x 20" Annulus. From 1 bpm at 60 psi to 14 bpm at 400 psi. Taking Returns in Tiger Tank and in Cellar. Total of 410 bbls Pumped. Shut Down and Monitor Well. Fluid Seeping Around Surface Pipe. Wait on Trucks for More 9.8ppg Brine and Haul Off Fluid. 03:00 - 04:00 1.00 CLEAN P DECOMP Circulate 133/8" x 20" Annulus, Pump 325 bbls of 9.8 Brine from 2 bpm at 60 psi Staging Up to 12 bpm at 300 psi. All Returns Into Cellar. 04:00 - 06:30 2.50 CLEAN P DECOMP Monitor Well, Returns Still Coming Into Cellar. 06:30 - 07:30 1.00 CLEAN P DECOMP Pump 40 bbl Safe Surf-O Pill, 10 bpm at 180 psi 07:30 - 09:00 1.50 CLEAN P DECOMP Monitor Well, Fluid still Coming into Cellar. 09:00 - 10:00 1.00 CLEAN P DECOMP POOH with Muleshoe from 1,865'. 10:00 - 16:00 6.00 BOPSU P DECOMP Clean Drip Pan and NID BOPE, Casing Spool and DSA. 16:00 - 18:00 2.00 WHSUR P DECOMP Prep Wellhead and Emergency Slips. Top Bolts on Emergency Printed: 8/28/2006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 D-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 2.00 WHSUR P Slips Broken Except One. 3.00 BOPSU P N/U 20" Diverter Spool, 20" Annular and Riser. 1.50 CLEAN P Break Out and UD Baker Fishing Tools. 1.50 CLEAN P M/U Mule Shoe and RIH with 5" DP Killstring to 1,922' in Preparation for Suspending Operation. 8/7/2006 00:00 - 08:30 8.50 CLEAN C DECOMP Secure Well, Clear Rig Floor, Send Off All Rental Equipment and Tools, Band Onto Pallets. Clean Rig. Flush and Drain Mud Pumps. Clean Pits. 08:30 - 09:30 1.00 CLEAN C DECOMP POOH Laying Down 5" DP. 09:30 - 17:00 7.50 CLEAN C DECOMP RIH with 5" DP from Derrick and POH Laying Down 5" DP. 17:00 - 17:30 0.50 CLEAN C DECOMP Standback 6 1/4" Drill Collars. 17:30 - 18:30 1.00 CLEAN P DECOMP M/U Spear Assembly for 13 3/8" Casing. 18:30 - 19:00 0.50 CLEAN P DECOMP Engage Top of 133/8" Casing at 29' 19:00 - 19:30 0.50 CLEAN P DECOMP NID Divertor Spool and Lift to Facilitate Removal of Emergency Slips. 19:30 - 20:30 1.00 CLEAN P DECOMP POOH with 133/8" Casing. 175,000# Up Weight, Maximum Pull 275,00#. Pulled 26' Before Emergency Slips Rode Up on First Casing Collar. Remove 13 3/8" Emergency Slips, All Slip Parts Recovered. 20:30 - 21 :30 1.00 CLEAN P DECOMP NIU Divertor Spool. 21 :30 - 22:30 1.00 CLEAN P DECOMP Pull 13 3/8" Casing to Rig Floor and Release and UD Spear Assembly. 22:30 - 00:00 1.50 CLEAN P DECOMP POOH Laying Down 13 318" Casing. Joints Breaking Out with 60,000 - 65,000 ftllbs of Torque. 8/8/2006 00:00 - 16:00 16.00 CLEAN P DECOMP POOH Laying Down 133/8" Casing. Recovered 47 Joints of 13 3/8" Casing, 13 3/8" Upper Cut Joint That was Set in Emergency Slips was 26.28' Long and 13 3/8" Lower Cut Joint That was Cut Down Hole was 9.70' Long. Pipe was in Good Condition with no Collapses and No Holes Seen. Unable to Break Out One Joint, Had to Be Cut with Wach's Cutter. Bottom Cut Joint Was Rough with One Half Jagged and Flared Out. 16:00 - 17:00 1.00 CLEAN P DECOMP RID Casing Equipment, Clear and Clean Rig Floor. 17:00 - 18:30 1.50 CLEAN P DECOMP PIU BHA #13, 171/2" Tapered Mill, XO, XO, Fishing Jar, XO, 9 x 6 1/4" Drill Collars, XO, Intensifer. BHA Lenght = 313.91' 18:30 - 20:00 1.50 CLEAN P DECOMP RIH to 1,884'. Milled Tight Spots from 530' to 533' and 1,230' to 1,255'. Milled Through Quickly. 0-2,000# WOM, 2,000 - 3,500 ftllbs Torque at 35rpm. 20:00 - 21 :00 1.00 CLEAN P DECOMP POOH to 314'. No Signs of Tight Spots. 21 :00 - 22:00 1.00 CLEAN P DECOMP UD 17 1/2" Tapered Mill Assembly. 22:00 - 00:00 2.00 CLEAN P DECOMP M/U BHA #14. 171/4" Drag Shoe, 1 x 16" TSWP Washpipe, Drive Sub, XO, XO, Fishing Jar, XO, 9 x 6 1/4" Drill Collars, XO, Intensifier. Total BHA Lenght = 348.11' 8/9/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP RIH with Drag Shoe and Washpipe to 1,864' 01 :00 - 02:00 1.00 CLEAN P DECOMP Establish Parameters, Up Weight 92,000#, Down Weight 95,000#, Rotating Weight 95,000#, 3,000 ftllbs Torque at 35 rpms. 150 psi at 6 bpm, Wash Over 133/8" Casing Stub from 1,884' to 1 ,904'. Loss Rate 90 bph at 6 bpm. 02:00 - 05:00 3.00 CLEAN P DECOMP Artic Pack Returns Coming Into Cellar and Up Riser, Gas Breaking Out of Artic Pack. Circulate Out From .5 bpm to 6 BPM. Appx. 150 bbls of Artic Pack Back to Surface. Circulate Till 9.8 Brine Back to Surface. Loss Rate 90 bph at 6 bpm at 80 psi. Monitor Well. Printed: 8/28/2006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 D-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 8/9/2006 05:00 - 06:00 1.00 CLEAN P DECOMP POOH with DP and Stand Back in Derrick. 06:00 - 07:45 1.75 CLEAN P DECOMP Arctic Pack coming out of DC's. Stab with Circ Head. No Pressure Seen at surface and No FLow up Back Side. Circulate Well, Returns to Slop Tank and Cellar. 07:45 - 08:30 0.75 CLEAN P DECOMP Clean Rig, Monitor Well, and Wait on Orders. 08:30 - 13:00 4.50 CLEAN P DECOMP Wait on Flow Back Tank and Hardline from DSM. Continue to Monitor Well and Clean Rig. 13:00 - 14:30 1.50 CLEAN P DECOMP PT Hard Une to 500 psi. B/O and UD BHA #14, Wash Over BHA. 14:30 - 15:30 1.00 CLEAN P DECOMP P/U and M/U BHA#15, Dress Off BHA for 13-3/8" Stub. BHA = 17" OD x 13.375" ID Dressing Shoe, 1 x 16" Washpipe, Drive Sub, XO, XO, Fishing Jar, XO, 9 x 6 1/4" Drill Collars, XO, Intensifier. Total BHA Lenght = 346.53' 15:30 - 16:30 1.00 CLEAN P DECOMP RIH Slowly with Dress Off BHA. Monitor Well for Arctic Pack and Gas as RIH to 1850'. 16:30 - 17:00 0.50 CLEAN P DECOMP Establish Paramters. Up Wt = 90,000 Ibs, Down Wt = 93,000 Ibs, Rot Wt = 94,000 Ibs with 40 rpm's and 3,000 ft-Ibs torque. Dress Off 13-3/8" Stub at 1884' as per Baker Recommendations. First Foot of Stub Required work to Dress Off, After First Foot Pipe Clean and in Good Shape. Swallowed 6 ft of Stub. Took 35 bbls initially to get fluid returns. A good volume of Arctic Pack seen with circulation initially, as well as gas. 17:00 - 18:00 1.00 CLEAN P DECOMP Continue to Circulate Well with 9.8 ppg brine. Lossing 2 bpm while on the active system while pumping 3.5 bpm at 60 psi. Returns over Shakers =9.8 ppg. Fluid coming into cellar at - 2.0 bpm. Returns to Cellar = 8.4 ppg. Pumped 280 bbls of 9.8 ppg and collected over 200 bbls from Cellar while pumping. 18:00 - 19:30 1.50 CLEAN P DECOMP Shut Down Pumps. Monitor Well and Flow in Cellar. Fluids in Wellbore dropping immediately at a rate of about 2 ft per min. Cellar continue to flow but at slower rate. Consult Town. 19:30 - 21 :00 1.50 CLEAN P DECOMP POOH From 1,884' to 334'. Stage Out, Circulating Every 5 Stands. 21 :00 - 23:00 2.00 CLEAN P DECOMP UD 13 3/8" Dressing BHA. 23:00 - 00:00 1.00 CLEAN P DECOMP Clear and Clean Rig Floor. 8/10/2006 00:00 - 02:30 2.50 BOPSU P DECOMP Clean and Nipple Down 20" Annular and Diverter Spool. Remove From Cellar. 02:30 - 04:00 1.50 BOPSU P DECOMP Nipple Up 20" Tin Horn Riser. Install Nipples and Valves in Outlets. 04:00 - 06:00 2.00 CASE P TIEB1 Rig Up to Run 13 3/8" Casing. 06:00 - 09:30 3.50 CASE P TIEB1 PJSM on Running Casing. M/U Baker 13-3/8" Casing Patch, HES Baffle Collar, 10' Casing Pup Joint, and HES ES Cementer. Baker Lock All Connections and M/U to the Base of Triangle. Average Torque 11,000 ft-Ibs. 09:30 - 14:00 4.50 CASE P TIEB1 M/U and RIH with 45 Joints 13-3/8" 68# L-80 BTC Casing. Average Make Up Torque = 11,000 ft-Ibs. Ridged Body Free Floating Centrilizers installed on Joints #2 - #36, #40, #44. 14:00 - 15:00 1.00 CASE P TIEB1 M/U Joint #45 and Take Parameters. Up Wt = 153,000 Ibs, Down Wt = 160,000 Ibs. M/U Pup Joints and Circulating Head to Joint #45. S/O and Tag 13-3/8" Casing Stub at 1886.5 ft. Continue to S/O and Swallow Casing Stub 4' with Patch, required 50,000 Ibs Down Wt to Completely Swallow Stub. Patch Went Over Stub Smoothly. P/U and Pull Test Patch with Printed: 8/28/2006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 D-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 8/10/2006 14:00 - 15:00 1.00 CASE P TIEB1 150,000 psi Over String Wt. Patch Held Good. 15:00 - 16:00 1.00 CASE P TIEB1 Pressure Test Casing to 1950 psi for 30 minutes. Test was Good. Bleed Down Pressure. Load Closing Plug in HES Cement Head. 16:00 - 17:00 1.00 CEMT P TIEB1 B/O and UD Circulating Head. Drop Bomb for ES Cementer. M/U Cementing Head to Casing. RlU Cement Line and Pressure Test. Pressure Up on Casing to Shear Up ES Cementer. Required 2550 psi to Shear Cementer. Break Circulation and Pump through ES Cementer. Pump 50 bbls at 4 bpm and 320 psi. Returns seen to shakers with 19 bbls pumped. 17:00 - 17:30 0.50 CEMT P TIEB1 PJSM with Rig Crew and Dowell on Pumping Cement for Casing. 17:30 - 18:00 0.50 CEMT P TIEB1 Prime Up and Pressre Test Lines to 4500 psi. Begin Pumping 11.2 ppg Lite Crete Cmt with 1-1/2#/bbl Sem Net and 1/2#/bbl Cello Flake. At 20 bbls away, Cmt Pump Down due to C-Pump Failure on Unit. Down for 10 mins. 18:00 - 19:00 1.00 CEMT P TIEB1 Come Back on line with cement pumping at 5.0 bpm. Pressure continue to steadily increase to 3,000 psi at 1.3 bpm. Discontinue Mixing LCM Into the Cement, Continue to Try and Get Cement to Move Pumping at.7 bpm at 4,300 psi. 19:00 - 21:00 2.00 CEMT N TIEB1 Bleed Off Pressure and Flush Out Lines, Switch Over to Rig and Attempt to Circulate Out Cement. Pressure Up to 3,500 psi and Bleed Off to Try and Break Cement Free. 21 :00 - 00:00 3.00 CEMT N TIEB1 RID Cement Head and Attempt to Break Out Top 133/8" Casing Pup Joint. Would Not Break Out. Clear Rig Floor and Clean Out Surface Lines. Consult With Anchorage. Consult with Dave Kraft (Cameron Town), Recover 133/8" Emergency Slips Previously Removed from Well. Inspect Slips for Possible Re-use as Pack-Off. Check Through Old Wellhead Inventory at Cold Storage for Pack Off Assembly. 8/11/2006 00:00 - 01 :30 1.50 CEMT N TIEB1 Locate Assembly to Pack-Off 13 318" x 20" and Compare with 13 3/8" Emergency Slips. 01:30 -10:00 8.50 CEMT N TIEB1 Send Cameron to Rest, Formulate Plan of Operation. Wait on Orders. 10:00 - 11 :00 1.00 REMCM N TIEB1 M/U Wach's Cutter on Rig Floor and Cut 13-3/8" Casing -1.5 ft above floor. Found Cement in pipe below Cut and 10 gallons of cement found above cut. Cement was not firm and still in a semi liquid state. 11 :00 - 12:00 1.00 REMCM N TIEB1 CIO Bails and Lay Down Cut Joint. 12:00 - 13:30 1.50 REMCM N TIEB1 Evaluate where to cut Casing below Rig Floor. Unable to get cut just below. Unable to make cut at height for wellhead due to Tin Horn would not pull up high enough. Decide to Cut Just above bottom of flow riser. Clean Out Casing Down Past Cut Joint. Found Cement to just below Rig Floor and then only water down to top of Tin Horn. 13:30 - 15:00 1.50 REMCM N TIEB1 Pull Bushings and Pull Riser. Make Cut on 13-3/8" casing with Wach's Cutter Just above top of Tin Horn. Pull and Lay down Cut Joint. 15:00 - 18:30 3.50 REMCM N TIEB1 N/D Tin Horn and Pull Up above Uni Head. Install Pack Off in 13-3/8" x 20" Annulus. NIU Tin Horn and Install Flow Riser. 18:30 - 19:00 0.50 REMCM N TIEB1 Wash Up and UD Spider Elevators, Install Short Bails and 5" Pipe Elevators. Printed: 812812006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 D-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 8/11/2006 19:00 - 19:30 0.50 REMCM N TIEB1 M/U Muleshoe and RIH, Tag Cement at 192', POOH LID Muleshoe. 19:30 - 20:30 1.00 REMCM N TIEB1 M/U 121/4" Bit, Fishing Jars and 1 Stand of 6 1/4" Drill Collars and RIH to 192'. 20:30 - 00:00 3.50 REMCM N TIEB1 Drill Out Cement in 133/8" Casing from 192' to 489'.5,000# WOB, 5.5bpm with 120 psi Pump Pressure, 60 rpm with 2,000-3,000 ft/lbs of Torque. Cement Has Been Firm with No Stringers. ROP 100 - 150 fph. 8/12/2006 00:00 - 06:00 6.00 REMCM N TIEB1 Drill Out Cement in 13 3/8" Casing from 489" to 1,058'. 5,000# WOB, 5.5bpm with 120 psi Pump Pressure, 60 rpm with 2,000-3,000 ft/lbs of Torque. Cement Has Been Firm with No Stringers. ROP 100 -150 fph. Out of Firm Cement at 1,058'. 06:00 - 06:30 0.50 REMCM N TIEB1 Circulate around 20 bbl High Vise Sweep. 06:30 - 08:00 1.50 REMCM N TIEB1 Continue in hole to Drill Out Cement. Wash Down from 1058' to ES Cementer at 1872 ft. No Cement Seen in Casing 08:00 - 12:30 4.50 REMCM N TIEB1 Circulate 20 bbl High Vise Sweep. Continue to Circulate Hole Clean while waiting on clean 9.8 ppg brine to arrive. Pump at 10 bpm and 360 psi. 12:30 - 14:00 1.50 REMCM N TIEB1 Circulate 20 bbl High Vise Sweep and Chase with Clean 9.8 ppg brine. Pump at 8 bpm and 230 psi. 14:00 - 15:00 1.00 REMCM N TIEB1 POOH w/2 Stands of DP. PIU HES 13-3/8" RTTS. RIH w/1 Stand of DP. Set RTTS. 15:00 - 16:00 1.00 REMCM N TIEB1 Attempt to Establish Circulation Through ES Cementer and Up 13-3/8" x 20" Annulus. Pressure Up to 1500 psi with 7 bbls and shut down pump. Pressure Slowly decreasing. Pressure Up to 1900 psi wI an additional 3 bbls and shut down pump. Shut-in valves to pumps and monitor pressure. Pressure Slowly decreasing. Loosing - 900psi in five minutes. Elect to Perf Casing. 16:00 - 17:30 1.50 REMCM N TIEB1 Release RTTS and POOH. LID RTTS. POOH and Stand Back DP. 17:30 - 18:00 0.50 REMCM N TIEB1 LID 12 1/4" Clean Out Assembly. 18:00 - 18:30 0.50 REMCM N TIEB1 M/U BHA #17, Bit, Csg. Scraper, Float Sub, XO, Fishing Jars, XO, 3 x Drill Collars, XO. Total BHA Lenght = 117.02' 18:30 - 19:30 1.00 REMCM N TIEB1 RIH with Scraper Assembly to 1,870' 19:30 - 20:30 1.00 REMCM N TIEB1 Circulate 20 bbl High-Vis Sweep Around at 10 bpm with 370 psi. 20:30 - 21 :30 1.00 REMCM N TIEB1 POOH from 1,870', Stand Back DP. 21 :30 - 22:00 0.50 REMCM N TIEB1 LID 133/8" Scraper Assembly. 22:00 - 00:00 2.00 REMCM N TIEB1 Spot Schlumberger Wireline Unit, PJSM, R/U Wireline Equipment. P/U 4 1/2" 10 Ft Gun, Random Phase, 5 SPF, Big Hole Charges. RIH with Perf Gun. 8/13/2006 00:00 - 00:30 0.50 REMCM N TIEB1 Fire Gun, Perf from 1,654 to 1,664'. Fluid Level in 133/8" Csg Dropped to 50'. 00:30 - 01 :30 1.00 REMCM N TIEB1 M/U Muleshoe and RIH with 3 Stands of 6 1/4" DC's, P/U HES 133/8" RTTS and 1 Stand of 5" DP. Set RTTS at 99' 01 :30 - 03:30 2.00 REMCM N TIEB1 Establish Circulation Through Perf's. Circulate Bottoms Up. Pump Rates 2 bpm at 50 psi, 3 bpm at 60 psi, 4 bpm at 60 psi, 5 bpm at 70 psi, 6 bpm at 110 psi, 7 bpm at 120 psi. 9.8ppg Brine Returns to Shakers and 275 bbls 8.4ppg Water Returns in Cellar. 03:30 - 05:00 1.50 REMCM N TIEB1 Release RTTS, Monitor Well, LID RTTS and Stand Back DC's. Clear Rig Floor. Printed: 8/28/2006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 D-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 8/13/2006 05:00 - 06:30 1.50 REMCM N TIEB1 NID Tin Horn Riser and Lift for Pulling 13 3/8" x 20" Pack-Off. 06:30 - 08:30 2.00 REMCM N TIEB1 NIU Tin Horn and Riser. 08:30 - 11 :00 2.50 REMCM N TIEB1 M/U HES Cast Iron EZSV-B and RIH on DP to 1580'. 11 :00 - 11 :30 0.50 REMCM N TIEB1 M/U Top Drive and Break Circulation at 3.0 bpm at 0 psi for 20 bbls. Set HES Cast Iron EZSVat 1580' 11 :30 - 12:30 1.00 REMCM N TIEB1 R/U Circ Head to DP and Break Circulation Through EZSV and up 13-3/8" by 20" annulus at 5.0 bpm and 230 psi with 45 bbls. 12:30 - 13:00 0.50 REMCM N TIEB1 PJSM wI Rig Crew, Dowell, and Vac Truck Drivers. 13:00 - 15:30 2.50 REMCM N TIEB1 Pressure Test Cement lines to 4500 psi and pump 50 bbls of 10.0 ppg Mud Push, 375 bbls of 11.2 ppg LiteCrete Cement wi 1-1/2# ppb Cem Net and 1/4 # I bbl Cello Flake. Pumped job at an average of 4.5 bpm and 160 psi. Returns to Rig Pits at 2.5 bpm, with only - 130 bbls back to pits when cement at surface. 100 bbls pulled out of cellar during the job. Mud Push at surface with 280 bbls of Cement pumped and 338 bbls total pumped. Cement at surface with 358 bbls of cement pumped and 408 total bbls pumped. Pumped a total of 375 bbls of cement with 39 bbls in returns. CIP at 15:09 hrs. Shut-in and Monitor Well, Cement not falling out and staying level. 15:30 - 16:30 1.00 REMCM N TIEB1 Displace Drill Pipe with 22 bbls of 9.8 ppg and Pull Out of EZSV. BIO and UD Cement Hose and Circ Head. CIO Bails. POOH and UD one Joint. Load Foam Ball. M/U Top Drive. Pump Foam Ball Out of Drill String with 28 bbls. PUH 90 feet and Circulate 40 bbl High Visc Sweep and Chase out of hole. A small amount of cement and LCM seen in returns. 16:30 - 17:30 1.00 REMCM N TIEB1 POOH with DP and UD HES EZSV Stinger. 17:30 - 18:00 0.50 REMCM N TIEB1 Flush and Pull Riser, Center Up 133/8" Casing Inside of 20". 18:00 - 00:00 6.00 REMCM N TIEB1 Wait on Cement. Clear and Clean Rig Floor, Perform Work Orders and Maintenance. UCA 0 psi at 22:00 hrs. 8/14/2006 00:00 - 14:00 14.00 REMCM P TIEB1 Wait on Cement. Perform Rig Work Orders and Maintenance. UCA at 00:00 hrs = 0 psi, UCA at 03:00 hrs = 35 psi. UCA at 05:30=230 psi. UCA at 07:45 hrs = 425 psi. 14:00 - 15:00 1.00 WHSUR P TIEB1 NIU Wachs 20" casing cutter. Cut Casing - 6 inches below grade level. Top of Cement 3.625 ft below top of 20" Casing. 15:00 - 16:00 1.00 WHSUR P TIEB1 Make Second Cut on 20" above and Split 20" Piece to remove. 16:00 - 17:30 1.50 WHSUR P TIEB1 Make Cut on 13-3/8" Casing with Wachs Cutter. Pull and UD 13-3/8" Casing Cut Joint. UD 20" Tin Horn. 17:30 - 18:00 0.50 WHSUR P TIEB1 Prep 133/8" Casing for Wellhead. 18:00 - 22:00 4.00 WHSUR P TIEB1 Stab New Wellhead, Preheat and Weld as per Cameron Procedures. 22:00 - 00:00 2.00 WHSUR P TIEB1 Reheat and Wrap Wellhead With Insulation. 8/15/2006 00:00 - 05:00 5.00 WHSUR P T1EB1 Waiting on Wellhead Welding to Cool as per Cameron Procedure. 05:00 - 06:00 1.00 WHSUR P TIEB1 Test Wellhead with Nitrogen. Attempt to test to 1000psi. Unable to build pressure up to 500 psi or maintian pressure on wellhead. Inside welds leaking. Need to re-weld. 06:00 - 07:00 1.00 WHSUR P TIEB1 Wait 0111 GBR Welders to arrive on location. 07:00 - 08:00 1.00 WHSUR P TIEB1 Rig Up!Welders, Sniff Area, and Fill Out Permits. 08:00 - 18:30 10.50 WHSUR P TIEB1 Re-weld wellhead to repear leaking area. Wrap wellhead with insulation to let cool as per Cameron Procedures. 18:30 - 19:30 1.00 WHSUR P TIEB1 Re-test wellhead with Nitrogen to 1100 psi. Pressure bled off to 800 psi in 3 min. 19:30 - 21 :00 1.50 WHSUR P TIEB1 Re-weld wellhead to repair leak. Small repair with minimal Printed: 8/28/2006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-03 0-03 WORKOVER DOYON DRILLING INC. DOYON 16 8/16/2006 1.50 WHSUR P 3.00 BOPSU P 2.00 BOPSU 4.50 BOPSU 06:30 - 09:00 2.50 DRILL 09:00 - 12:30 3.50 DRILL 12:30 - 14:00 1.50 DRILL 14:00 - 21 :00 7.00 DRILL 21 :00 - 00:00 3.00 DRILL 8/17/2006 00:00 - 03:00 3.00 DRILL 03:00 - 03:30 0.50 DRILL 03:30 - 05:00 1.50 DRILL 05:00 - 05:30 0.50 CASE 05:30 - 06:00 0.50 DRILL 06:00 - 08:00 2.00 CASE 08:00 - 11 :00 3.00 CASE 11 :00 - 12:30 1.50 CASE 12:30 - 13:30 1.00 CASE 13:30 - 15:00 1.50 CASE 15:00 - 15:30 0.50 CASE TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 welding. Allow to cool and retest to 1100 psi for 30 min. RIU and NU BOPE. Continue NU BOPE. Test BOPE to 250 psi Low and 3500 psi High. Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by John Crisp. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- Hydrill, HCR Choke, HCR, Kill, Upper IBOP, TIW Valve Test #2- Manual Choke, Manual Kill, Lower IBOP, Dart Valve Test#3-ChokeValves 1, 12, 13,14, Test #4- Lower Pipe Rams 41/2" x 7" Test #5- Choke Valves 9, 11, Blind Rams Test #6- Choke Valves 5, 8, 10, Test #7- Choke Valves 4, 6, 7 Test #8- Choke Valve 2, Test #9- Choke Valve 3 Accumulator Test- 2,950 psi Starting Pressure, 1,900 psi After Actuation, First 200 psi in 17 seconds, Full Pressure in 1 Minute 09 Seconds. 5 Nitrogen Bottles at 2,200 psi. PU 121/4" bit and clean out BHA, RIH. Tag CMT at 1500', wash to CMT retainer @ 1574'. Drill on CMT retainer @ 1574' wI 6-9.5 BPM 130-310 psi. WOB 15-30K, TO 2-10K, 80 RPM. RU and test CSG to 3000 psi for 15 minutes. RD testing equipment. Drilled through CMT retainer. Continue drilling at 80 RPM, wI 5-10K TO, 8 BPM wi 240 psi, and 30K WOB Wash from 1575' to 1584 where the bit took weight. Continue drilling on CMT @ 80 RPM, w/5-10K TO, @ 8 BPM wI 240 psi, and 20-30 WOB. Continue drilling through CMT from 1584' to 1638' @ 80 RPM, w/5-10K TO, @ 8 BPM wi 250 psi, 20-30K WOB. Service Rig Continue drilling and washing through CMT from 1638' to 1871'. Tag bomb. Tag bomb on ES Cementer and stacked 40K to close sleeve. Attempted 3 times, On Third Time noticed 5,000# Decrease on Weight Indicator, No Noticible Pipe Movement on Rig Floor. RU to test CSG. Attempt to Test Casing. Decision Made to Drill Out ES Cementer and Clean out to PBR. Drill out ES Cementer from 1872' to 1876' at 50 RPM, 2.5-6 BPM wI 100-180 psi and 30K WOB. PU single and wash from 1876' to the top of the PBR @ 1927'. Pumped a 20 bbl HiVis Sweep at 12 BPM wI 480 psi at 60 RPM. POOH and UD BHA. Clean out full Boot Baskets. PU and RIH wi polish mill assembly to 1919'. PU single and wash to 1928' at 80 RPM wI 9 BPM at 320 psi and 2-3K TO. Continue to wash and ream throught the PBR to Printed: 8/28/2006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 0-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 8/17/2006 15:00 - 15:30 0.50 CASE TIEB1 1941'. 15:30 - 16:00 0.50 CASE TIEB1 Pump a 20 bbl HiVis sweep at 12 BPM wI 400 psi which brought an increase of rubber to surface. 16:00 - 18:00 2.00 CASE TIEB1 POOH and UD BHA. Boot baskets were full of CMT and a small amount of metal. 18:00 - 20:30 2.50 CASE TIEB1 Pull wear ring, CIO pipe rams to 9 5/8", set test plug, and RU to test BOPE. 20:30 - 22:00 1.50 CASE TIEB1 Test pipe rams to 250 psi Low and 3500 psi High test. CIO bad seal in test plug. RD testing equipment. Witnessed by Tour Pusher and Well Site Leader. 22:00 - 00:00 2.00 CASE TIEB1 RU to PU and RIH w/9 5/8",40 PPF L-80, TC-II CSG. 8/18/2006 00:00 - 06:00 6.00 CASE TIEB1 Continue RIH w/9 5/8",40 #, L-80, TC-II CSG to 1652'. 06:00 - 09:30 3.50 CASE TIEB1 Continue RIH w/9 5/8" CSG and land @ 1943' inside the PBR. No problems, no fill. 09:30 - 10:30 1.00 CASE TIEB1 RU and test 9 5/8" CSG to 2000 psi, held for 30 minutes. 10:30 - 11 :00 0.50 CASE TIEB1 Pressure up on CSG to 2800 psi to shear ES Cementer. Continue circulating 50 bbls brine to establish circulation at 4.5 BPM wI 270 psi. 11 :00 - 13:30 2.50 CASE TIEB1 Pressure Test Cement lines to 4500 psi and pump 20 bbls of 13.0 ppg Mud Push, 120 bbls of 15.8 ppg Class G CMT wI .3% BWOC Dispersant, .05 GPS Accelerator, .4 GPS Antifoam, 2 GPS GASBLOK. The last 10 bbls of CMT was treated with 1.5 PPB Cem Net. Pumped job at an average of 4.5 bpm and 230 psi. Full returns to rig pits. Displaced CMT wI rig @ 6.3 BPM. 5 bbls of CMT returned to surface and Treated with D-110. Bumped plug wI 1550 stks and 750 psi. Pressured up to 2000 psi and held for 5 minutes before bleeding off to 0 psi. CIP at 01 :00 hrs. Shut-in and Monitor Well. 13:30 - 14:30 1.00 CASE TIEB1 ND BOPE and set McEvoy 9 5/8" slips as per Cameron Rep. Set slips wI 110K. 14:30 - 16:00 1.50 CASE TIEB1 RU and cut 9 5/8" CSG w/Wachs Cutter. 16:00 - 16:30 0.50 CASE TIEB1 ND 4' spacer spool and remove from wellhead. 16:30 - 18:00 1.50 CASE TIEB1 NU TBG Spool and spacer spool. 18:00 - 20:00 2.00 CASE TIEB1 Test Packoff to 2400 psi. Test witnessed by Well Site Leader. 20:00 - 22:30 2.50 CASE TIEB1 NU BOPE and CIO varriable pipe rams to 3.5" x 6". 22:30 - 00:00 1.50 CASE TIEB1 RU and test pipe rams with 5" and 4" DP, 4" dart valve and TIW valve. Test witnessed by Tour Pusher and Drill Site Leader. 8/19/2006 00:00 - 01 :30 1.50 CASE TIEB1 Continue Testing BOPE wI 5" and 4" test jt. Test varriable pipe rams, 4" TIW valve, and 4" Dart valve. Test witnessed by Tour Pusher and Well Site Leader. 01 :30 - 02:00 0.50 CASE TIEB1 Install wear ring. 02:00 - 03:00 1.00 CASE TIEB1 While WOC, PU and break out 133/8" Spear Assy. PU and clean out Boot Baskets on Clean Out Assy. 03:00 - 04:00 1.00 CASE TIEB1 Continue WOC. Schlumberger confirmed 1000 psi compressive strength @ 03:40 hrs. 04:00 - 05:30 1.50 CASE TIEB1 PU Drill out assembly and RIH. Tag CMT @ 1880". 05:30 - 07:30 2.00 DRILL TIEB1 Start washing to sand @ 75 RPM wI 10 BPM @ 200 psi. Tag and drilled out ES Cementer @ 1893'. Pumped 20 bbl HiVis sweep at 12 BPM. 07:30 - 09:00 1.50 CASE TIEB1 RU and test 9 5/8" CSG to 3500 psi for 30 minutes. Witnessed by Well Site Leader. 09:00 - 10:30 1.50 DRILL TIEB1 Continue to RIH and tag Baffle plate @ 1919' and drill out 10 Printed: 8/28/2006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 D-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 8/19/2006 09:00 - 10:30 1.50 DRILL TIEB1 BPM wI 500 psi @ 75 RPM. CBU 10:30 - 13:30 3.00 DRILL TIEB1 Continue RIH to top of sand @ 2507'. Ream and wash through sand and junk 2514'. CBU. Continue washing and reaming through junk to 2566' at 60 RPM wI 3-6K TQ, and 90 psi @ 2.5 BPM. 13:30 - 15:00 1.50 DRILL TIEB1 CBU and pump 20 bbl HiVis sweep. Displace well to 8.6 ppg seawater at 15.5 BPM wI 800 psi. 15:00 - 16:00 1.00 DRILL TIEB1 POOH 16:00 - 18:30 2.50 DRILL TIEB1 MU Reverse Jet Basket BHA and RIH to 2566' 18:30 - 19:00 0.50 DRILL TIEB1 Wash down from 2566' to 2580' 19:00 - 21:00 2.00 DRILL TIEB1 POOH and service Reverse Jet Basket of large peice of rubber element and small pieces of metal. 21 :00 - 22:00 1.00 DRILL TIEB1 RIH for 2nd Reverse Jet Basket run. Tag sand @ 2580' and wash to 2583'. 22:00 - 00:00 2.00 DRILL TIEB1 POOH wI Reverse Jet Basket. Retreive small amounts of metal. UD Baker fishing tools. 8/20/2006 00:00 - 02:00 2.00 FISH TIEB1 MU RBP retrieving tool. RIH and tag sand @ 2568'. 02:00 - 03:00 1.00 FISH TIEB1 Wash down while reverse circulating @ 5 BPM. Tag top of RBP @ 2595'. 03:00 - 05:00 2.00 DHB TIEB1 Attempt to release RBP. After several attempts to release RBP, RBP released with 90K overpull. 05:00 - 05:30 0.50 FISH TIEB1 CBU @ 6 bpm, 120 psi. 05:30 - 08:30 3.00 DHB TIEB1 POOH laying down 5" drillpipe and RBP. RBP was missing one rubber element. 08:30 - 09:00 0.50 DRILL TIEB1 Clear and Clean rig floor. 09:00 - 09:30 0.50 DRILL TIEB1 Drain BOPE and look for missing rubber element. 09:30 - 11 :00 1.50 DRILL TIEB1 RU topdrive for 4" drill pipe. 11 :00 - 12:00 1.00 FISH TIEB1 PU RBP retrieving tool. 12:00 - 12:30 0.50 DRILL TIEB1 Service rig top drive, draworks, and skate. 12:30 - 20:30 8.00 DRILL TIEB1 PU 4" drillpipe and RIH tag RBP @ 9208'. Up wt 170K, Down wt 130K. 20:30 - 00:00 3.50 DHB TIEB1 Latch onto RBP and attempt to relax PKR. Made several attempt to relax PKR by overpulling in 10-15K increments. The PKR was allowed 10-15 minutes to relax before increasing the overpull. 8/21/2006 00:00 - 00:30 0.50 DHB P TIEB1 Continue working to release RBP. Parameters are 170K up wt, 130K down wt. Slack off from 245K to 170K and hold while circulating 2 BPM w/110 psi. Pull up to 200K, hold to relax rubbers, bleed down to 195K. Allow RBP elements to relax and RBP pulled free. Max overpull 70K. 00:30 - 02:00 1.50 DRILL P TIEB1 PJSM covering the hazards of fluid lose and possibilty of a kick while releasing the RBP. Monitor Well and CBU at 6 bpm and 820 psi with No Losses or Gains. 02:00 - 03:00 1.00 DRILL P TIEB1 POOH 7 stands and well out of balance. RU and circulate 1.5 drillpipe volumes @ 6 BPM w/1 040 psi. Monitor well dead. No losses or gains. 03:00 - 08:00 5.00 DRILL P TIEB1 Continue to POOH. UD RBP #2. Missing Rubber Element. 08:00 - 10:30 2.50 DRILL P TIEB1 P/U 2 Jts From Pipe Shed, RIH to Retrive RBP #1. 10:30 - 11 :30 1.00 DRILL P TIEB1 PJSM Slip and Cut Drilling Line. 11 :30 - 12:00 0.50 DRILL P TIEB1 Service and Lubricate Rig 12:00 - 16:00 4.00 DHB P TIEB1 Continue RIH from 4800' to 9208'. Obtain Parameters 175,000# Up Weight, 135,000# Down Weight, Slide over RBP . Latch up and Pulled Up With 10,000# Overpull. RBP Printed: 8/2812006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 D-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 8/21/2006 12:00 - 16:00 4.00 DHB P TIEB1 Unlatched. Slide Over RBP Latched, Pulled 15,000# Over, Let Weight Bleed Off, Pulled Up 20,000# , Let Weight Bleed Off, Pulled Up 45,000# Let Weight Bleed Off, Pulled Up 50,000#, Let Weight Bleed Off. Pulled Up 60,000# Let Weight Bleed Off. Pulled Max of 75,000# Over Neutral Weight. Let Packer Element Relax. 16:00 - 17:00 1.00 DRILL P TIEB1 Circulate Bottom Up At 50 spm at 580 psi. Monitor well dead wI no losses or gains. 17:00 - 22:00 5.00 FISH P TIEB1 POOH w/ RBP #1. 22:00 - 22:30 0.50 FISH P TIEB1 Clear and clean up rig floor. 22:30 - 00:00 1.50 FISH P TIEB1 PU and MU Wash Pipe and Wash Over BHA assemby. 8/22/2006 00:00 - 01 :00 1.00 FISH P TIEB1 Continue building Wash Over BHA. 01 :00 - 05:30 4.50 FISH P TIEB1 RIH w/ Wash Pipe to TBG Stump @ 9,288'. Pumped 20 bbl Dry Job, Drillpipe Overflowing. 05:30 - 06:30 1.00 FISH P TIEB1 Washed Over Stump @ 5 bpm 520 psi. ( Tagged Junk @ 9,280',9,289', Wash Pipe Lenght 95' Washed Over 94' From 9,288' to 9,384'. 06:30 - 09:00 2.50 FISH P TIEB1 Pumped 20 bbl Hi-Vis Sweep. 9 bpm at 1900 psi. 09:00 - 10:00 1.00 FISH P TIEB1 Pulled off Bottom, Pulling Tight Worked Pipe 50,000# to 60,000# Overpull. 5.5 bpm, 520 psi. Packed Off, Worked Pipe Free Regained Circulation. 10:00 - 13:30 3.50 FISH P TIEB1 POOH f/9,384' 13:30 - 15:00 1.50 FISH P TIEB1 POOH wI Wash Over BHA. UD Same. Recovered Control Line Clamp and Pin. 15:00 - 16:00 1.00 FISH P TIEB1 MIU Out Side Tubing Cutter Assembly, Out Side Cutter 1Joint of Wash Pipe, Drive Sub, Pump Out Sub, Cross Over Sub, 9 Drill Collars, XO BHA Length=322.09'. 16:00 - 19:30 3.50 FISH P TIEB1 RIH V2,622' Pumped 15 bbl Dry Job. Due to Pipe Running Over While RIH. Continued in Hole. 19:30 - 21 :00 1.50 FISH P TIEB1 Obtain Parameters, Locate Tubing Collar, Cut Tubing at 9,306'. 21 :00 - 22:30 1.50 FISH P TIEB1 Dropped Dart Pumped @ 2.5 bpm at 70 psi. Opened Pump Out Sub @1100 psi. CBU @ 13 bpm, 3200 psi. Monitor Well 22:30 - 00:00 1.50 FISH P TIEB1 POOH 8/23/2006 00:00 - 02:30 2.50 FISH P TIEB1 Continue to POOH fl 9,306' 02:30 - 04:00 1.50 FISH P TIEB1 UD Outside Cutter Assembly, Recovered Cut Joint Lenght 17.84'. Cut Joint Full of Metal Shavings, Pieces of Clamp Rubber, and One Piece of Alumnium 4" Long 3" Wide and 1" Thick. Outside Cut is in Good Condition. HES Fasdrill Recovered. After Cut Was Made Experienced Losses of 105 bph for First Hour Tapering Off to 72 bph. 04:00 - 04:30 0.50 FISH P TIEB1 Clear and Clean Rig Floor. 04:30 - 06:00 1.50 FISH P TIEB1 M/U Dress off Assembly and 3 Stand of 6 1/4" DC. 06:00 - 07:30 1.50 FISH P TIEB1 RIH w/27 Stands Drill Pipe to 2,892'. 07:30 - 08:00 0.50 FISH P TIEB1 RlU Pump 15 bbl Dry Job. RID Blow Down. 08:00 - 10:00 2.00 FISH P TIEB1 Continue to RIH f/2,892' to Top of TBG Stub @ 9,306'. 10:00 - 11 :00 1.00 FISH P TIEB1 Obtain Parameters ( P/U 205,000#, SIO 140,000#, RT 168,000#) Tagged Stub @ 9,306' Swallowed 8', Dress off OD wl8.5" x 5.5" Shoe. Dress Top Of TBG Stub w/Dressing Mill. Pumping at 5bpm and 560 psi, 8,000 to 10,000 ft-Ibs Torque. 11 :00 - 12:00 1.00 FISH P TIEB1 Blow Down Top Drive RlU to UD Drill Pipe. 12:00 - 13:30 1.50 FISH P TIEB1 PJSM and Lay Down Drill Pipe. 13:30 - 14:00 0.50 FISH P TIEB1 Service Rig. 14:00 - 15:00 1.00 FISH P TIEB1 Continue to UD DIP. Printed: 8/28/2006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 D-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 8/23/2006 15:00 - 16:00 1.00 FISH P TIEB1 M/U Storm RTTS and Set at 101' Test to 1,000 psi. 16:00 - 17:00 1.00 FISH P TIEB1 Pull Wear Ring Set Test Plug RlU to Test BOPE. 17:00 - 21 :30 4.50 FISH P TlEB1 Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Chuck Sheve. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1-Hydril, HCR Choke, HCR Kill, TIW. Test #2- Choke Manual, Kill Manual, Dart Valve. Test #3- Choke Valves 1, 12, 13, 14. Test #4- Variable Rams 3.5"x 6". Test #5- Blinds, Choke Valves 9, 11. Test #6- Choke Valves 5, 8, 10, Upper IBOP. Test #7- Choke Valves 4, 6, 7, Lower IBOP Test #8- Choke Valve 2 Test #9- Choke Valve 3 Accumulater Test- 3,000 psi Starting Pressure, 1,900 psi After Actuation, First 200 psi in 16 seconds, Full Pressure in 1 Minute 10 Seconds. 5 Nitrogen Bottles at 2,200 psi. 21 :30 - 22:00 0.50 FISH TIEB1 RID Test Equipment BID Ulnes Pull Test Plug, Set Wear Ring. 22:00 - 23:00 1.00 FISH TIEB1 RIH Retrieve RTTS At 101', POOH UD RTTS. 23:00 - 00:00 1.00 FISH TIEB1 UD Drill Pipe t/6,540'. 8/24/2006 00:00 - 05:00 5.00 RUNCO RUNCMP POOH UD 4" HT-38 DIP. 05:00 - 07:00 2.00 RUNCO RUNCMP UD 9 Drill Collars and Dress Off Mill Assembly. Milled Showed Signs of Good Dress Off Job and Tagging No-Go. 07:00 - 08:00 1.00 RUNCO RUNCMP Clear and Clean Rig Floor. Cleared Floor of Excess Tools. 08:00 - 08:30 0.50 RUNCO RUNCMP Pull and UD Wear Ring. 08:30 - 10:00 1.50 RUNCO RUNCMP RlU to Run 4.5",12.6#, 13 CR-80, JFE Bear Completion. 10:00 - 00:00 14.00 RUNCO RUNCMP Run 4.5" 12.6#, 13CR-80, JFE Bear Tubing. Using Jet Lube Seal Guard Pipe Dope. Average M/U Torque 4,400 ft/lbs For Yam Top Assembly on Bottom Hole Jewelry. Average Make Up Torque For JFE Bear Tubing is 4,500 ft-Ibs. 205 jts of 4.5", 12.6#, 13Cr80, JFE Bear Tbg, 1 Unique 9.625" x 5.5" Overshot, 1- 4.5" X Nipple wI RHC, 1 jt Yam Top Tubing, Baker 9.625" x 4.5" S-3 9Cr Pkr, X Nipple, 3 GLM's , 3 jts Yam Top Tubing, 1 GLM, DCR Shear Valve in top Station, and 1 X Nipple at 2100'. 8/25/2006 00:00 - 02:30 2.50 RUNCO RUNCMP Continue to Run 4.5" 12.6#, 13CR-80, JFE Bear. Using Jet Lube Seal Guard Pipe Dope. Average M/U Torque 4,400 ft/lbs For Yam Top Assembly on Bottom Hole Components. Average Make Up Torque For JFE Bear Tubing is 4,500 ft-Ibs. 223 jts of 4.5", 12.6#, 13Cr80, JFE Bear Tbg, 1 Unique 9.625" x 5.5" Overshot, 1- 4.5" X Nipple wI RHC, 1jt Yam Top TBG, Baker 9.625" x 4.5" S-3 9Cr Pkr, X Nipple, 3 GLM's, 3 jts Yam Top TBG, 1 GLM, DCR Shear Valve in top Station, and 1 X Nipple at 2100'. 02:30 - 03:30 1.00 RUNCO P RUNCMP RID Tbg Compensator and Sling, M/U Clrc Head Pin to Jt 225. M/U Jt 225 to String. Circ 20 bbls Down Tbg, 3bpm at 110 psi. Establish Parameters. PIU Wt = 135,000 Ibs, SID Wt = 115,000 Ibs. Pump at 3 bpm, 110 psi. SIO on Tbg String, tag top of Tubing Stub and slide over at 9306', Pressure Increased Printed: 8/28/2006 10:42:53 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-03 D-03 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/22/2006 Rig Release: 8/25/2006 Rig Number: Spud Date: 4/19/1970 End: 8/25/2006 03:30 - 04:30 to 190 psi, SID another 4 ft to 9310' and Shear Pins wI 7500 Ibs at 9310', Continue to SID another 4 ft and begin taking wt. Stack Out 15,000 Ibs at 9314'. P/U and repeat to confirm depths of Stacking Out. RUNCMP RID Circ Head Pin and Hose. POOH and UD Jt #225 and #224. Picked up Double Pin XO 3.07, 5.79 Space Out Pup, 1jt Vam Top TBG 42.29, Hanger 3.24, Unique Overshot Spaced Out 3.41' above No-Go. Pumping 140 bbls of Clean 140 Deg Sea Water, At 3 bpm with 115 psi. Followed by 500 bbls of 140 deg Corrosion Inhibited Sea Water. Rig Down Blow Down Circulating Lines. M/U Landing Jt Land Hanger, RILDS, Break Circulation @ 2 bpm, with 80 psi. RID Circulating Head, Drop Ball and Rod, RlU Circulating Head. Set and Test 9 5/8"x 4.5" S-3 Packer. Test Tubing and Casing Annulus to 3,500 psi for 30 mins. GOOD Test. Shear DCR Valve, Pump Throught DCR Valve Down TBG and Down Annulus Blow Down, Rig Down lines and Circulating Equipment. Set and Test Two Way Check, Test to 1,000 psi. Nipple Down BOPE, Open and Clean Out Ram Doors. Change Out Lock Down Screws On Tubing Spool. Five Lock Down Screws Where Damaged. Discussed Situation With Mark Kerschion Cameron Repesentitive. Nipple Up Adapter Flange and Production Tree. Test Adapter Flange to 5,000#. After the Test, it Was Noticed That the Block Valve Was Obstructed. Voiding Test, Service Rep Called Out For More Parts. Carried on With Rig Operations Tested Production Tree to 5,000 psi for 30 minutes. Good Test. RlU Drill Site Maintenance and Pull Two Way Check With Lubricator. RID DSM. Re-Tested Adapter Flange to 5,000 psi for 30 minutes. PJSM With Little Reds Crew and Rig Crews. Rig Up Little Red, Test lines to 1,000 psi. Pumped 140 of Diesel Down Annulus at 2 bpm with 625 psi. U-Tube Well. Rig Released at 12:008/25/2006 04:30 - 08:30 RUNCMP 08:30 - 09:00 0.50 RUNCMP 09:00 - 10:00 1.00 RUNCMP 10:00 - 12:00 2.00 RUNCMP 12:00 - 12:30 0.50 RUNCMP 12:30 - 13:00 RUNCMP 13:00 - 13:30 RUNCMP 13:30 - 15:30 RUNCMP 15:30 - 17:00 RUNCMP 17:00 - 18:30 1.50 RUNCMP 18:30 - 19:30 1.00 RUNCMP 19:30 - 20:30 1.00 RUNCMP 20:30 - 21 :00 0.50 RUNCMP 21 :00 - 21 :30 0.50 RUNCMP 21 :30 - 23:00 1.50 RUNCMP 23:00 - 00:00 RUNCMP Printed: 8/28/2006 10:42:53 AM TREE = 6"CrN . D-03A SAFETY Na ORlG WELLBORE & PERFS P&A'd W/CMT. .. W8..LI'iEAD = MCEVOY PKR SQZ - 100, THERE'S CMT BEHIND TBG. ACTUATOR = OTIS FROM DRLG - DRA FT ESTIMATED TOC IS 10,000' ***(SEE NOTE BELOW)*** KB. 8..EV = 58.22' BF. 8..EV = 38.10' I Surface -lTOP of Cement of 13-3/8" Casing I KOP= 2900' Surface -TOp of Cement of 9-518" Casing I Max Angle = 94 @ 11270' Datum MD = 10451' I 1883' H 13-3/8" x 20" ECP I Datum TVD = 8800' SS I 1876' -i9-S/8" Foe I .. 13-3/8" CSG, 68#, L-80, ID = 12.4 1- 1890' · I 2114' -14-1/2" HES X NIP, ID" 3.813" I 9-5'8' ~ 4:Jf, L-EQ D=8æ51- 1943 . .. 1986' -9-5/8" FOC I 9-5/8" CSG, 47#, N-80, ID = ???? 1991' 1--- 1991' -i 10-3/4" BAASH ROSS PA TCH, ID = ??? I 13-3/8" CSG, 72#, N-80, ID = ??? 1994' fl I JI~~ 1994' -i 13-3/8" BAASH ROSS PATCH, ID = ??? I 120" CSG, 133#/94#, K-55IH-40, ID =? I j 2379' 2379' -f 10-3/4" X 9-5/8" XO, ID =??? , ~ GAS LIFT MANDR8..S 1:13-3/8" CSG, 68/61#, K-55 1-1 4430' -.J ST MD TVD DEV TYÆ VLV LATCH PORT DATE r-- 4 3360 3330 25 SLB OMY RK 0 08/25/06 SEALLOCK, ID = 12.415"/12.515" J 3 6196 5422 38 SLB DMY RK 0 08/25/06 2 7729 6515 38 SLB DMY RK 0 08/25/06 · 1_____ 1 9022 7600 29 SLB DCK RKP 0 08/25/06 ~ :x: ~ 9183 H4-1/2" HES X NIP, 10 = 3.813" I · I~ 9213' 1-19-5/8" x 4-1/2" BAKER 8-3 PKR I TOPOF 2-7/8" LNR I I , ~ It--.... ~ 9244 -\4-1/2" HES X NIP, 10 = 3.813" I 9997' ~ I r -f UNIQUE MACHINE OVERSHOT I 9308' I I ~ 9997' -\BAKER DEROYMENT SLV, 10- 3.00" 15-1/2" TBG, 17#, L-80 BTRS, 10188' 10078' -i 5-1/2" OTIS XA SLIDING SL V, 10 = 4.562" I .0232 bpf, ID = 4.892" I 10188' H BTM PBR TBG SEAL ASSY I SAFETY NOTES: IA X OA COMM. OPERATING LIMITS: 10212' H 9-5/8" X 4-1/2" BOT PKR, ID - 3.958" I MAX lAP = 2200 PSI; MAX OAP = 2200 PSI; MAX OOAP = 500 PSI. WELL HAS 4 WELLHEAD VLVS. I 1-\4-1/2" OTIS X NIP (B8-tlND LNR} 10 = 3.813" I BTM 2 ACCESS THE 13-3/8" X 20" ANNULUS (16" ~ 10308' CIRC STRING REMOVED DURING 1974 RWO) (01/11/04 WAlVER)*** ~ I H4-1/2" OTIS XN NIP (BB-IIND LNR) 10 = 3.725" I 10347' ~ 14-1/2" TBG. 12.6#, L-80, .0152 bpf, ID = 3.958'" I H 4-1/2" BOT MULESHOE (WLEG) I 10389' I '\ 10389' ~ I 10386' 1-\ 8..MD TI LOGGED 03/26/98 ÆRFORA TION SUMMARY REF LOG: SWS-BHCS ON 05/31/70 ) ANGLEATTOPÆRF: 89@ 10820 I MILL OUT WINDOW 10429' - 10434' I Note: Refer to Production DB for historical perf data ) ~ SIZE SPF INTERV AL Opn/Sqz DATE 2" 4 10820 - 10885 0 09/15/00 2" 4 10915-11281 0 09/15/00 PBTD H 11292' I 19-5/8" CSG, 47#, N-80, SEALLOCK, ID = 8.681" I 10797' I f-' 12-7/8" LNR, 6.16#, L-BO STL, .00579 bpf, 10 = 2.372 I 11355' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNrr 06/08/70 ORIGINAL COMPLETION 04/02/03 BJMlTLH CORRECTIONS WELL: D-03A 01/01/77 RWO (16" eSG PULLED) 09/17103 CMO/TLP DATUM MD, LOCATION ÆRMrr No: "2001340 08/01/77 RWO 02/22104 JLJITLP GL V C/O API No: 50-029-20057-01 09/19/82 RWO 08/28/06 JUvVPAG ORLG DRAFT CORRECTIONS SEC23, T11N, R13E, 1909.8' FNL & 1067.08' F8.. 09/17/00 eTD HORlZ SIDETRK (D-03A) 05/02/01 CH/TLP CORRECTIONS BP Exploration (Alaska) Sehlumberger RECEIVED. '1ílr¡:' '~fA,.,,,,,},..\r-:;fJ T\ 'Jh .; ¿i LJ".] ~\aJ^."t.'4¡:.,¡,.,~-'''' 11'·.J ~L ... J~UG 1 0 2006 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 NO. 3907 Alaska Oata & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth Alaska Oil & Gas Cons. CommissiOfl Anchorage r-'\¡"l '\ - /'0 L( d~ ,",. Field: Prudhoe Bay Well Job# Loa DescriDtion Date BL Color CD 02-166 11209601 McMP .~- 04/25/06 1 16-21 11221558 reM 04/03/06 1 16-01 1105228 INJECTION PROFILE 07/21/05 1 16-01 10980601 INJECTION PROFILE 08/15/05 1 D.S 11-08 11223100 INJECTION PROFILE 02/27/06 1 0.5. 02-26C 11223117 LOL 05/16/06 1 09-09 11211484 PROD PROFILE W/DEFT 04/28/06 1 18-33A 11258719 LOL 06/08/06 1 X-07 A 11217272 USIT 08/05/06 1 D-03A 11243918 SCMT 06/02106 1 D-03A 11217271 USIT 08/04/06 1 Z-19 11217273 USIT 08/06/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 08/08/06 . . Dí- ....; v L...U ~b~~~ AUG 0 8 2006 Schlumberger ,jJø.ska Oif & Gas Cons. Co~ NO. 3883 Anchorage i__)('Ý\ ~_(7)é.1 {"...,.,,,l"",J'-.,...· .'_ Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth EO', ~\ÛC ~: ,}; 7.tlÜ'J SC1\NN' 1,/ h v·¿ Field: Prudhoe Bay Well Job# Loa DescriDtion Date BL Color CD NK-43 11211388 IPROD . WIDcFT 04102106 1 NK-22A 10568415 IPROD .~ .~~ W/DEFT 02726703 1 L4-12 N/A WFULDL 05/09/06 1 L2-21A 10670034 MEM PROD PROFILE 09/20104 1 13-06A 11217266 INJECTION PROFILE 07112/06 1 01-17B 11209602 MEM PROD PROFILE 04/27106 1 09-08 11296705 INJECTION PROFILE 07121/06 1 09-19 11296704 INJECTION PROFILE 07/20/06 1 09-25 11296703 INJECTION PROFILE 07/19/06 1 04-09 11211398 INJECTION PROFILE 04128/06 1 04-10 11211380 INJECTION PROFILE 03/23106 1 17-21 11223104 PROD PROFILE WIDEFT 03122/06 1 18-03B 11057071 SBHP 12102105 1 X-15A 11212877 US IT 07118/06 1 J-01 B 11511430 USIT 07/24106 1 15-12A 11221595 US IT 07/25/06 1 Z-14B 11217268 USIT 07129106 1 5-400 10987564 CH EDIT PDC-GR OF USIT 01/26/06 1 D-03A 11217269 USIT 07131106 1 05-28A 11217267 USIT 07/28/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 08/01/06 . . D-03A Procedure e wo.. 1~4 e Subject: D-03A Procedure From: "Cismoski, Doug A" <CismosDA@BP.com> Date: Wed, 02 Aug 2006 11 :23:30 -0800 To: winton_aubert@admin.state.ak.us Winton - . As we discussed on the phone, I've taken the original scope of work that was attached to the Sundry application and have added detail regarding where our mechanical barriers and secondary well control equipment status. 1. MIRU. NO tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut at 9283'. (DONE) 2. Pull and LD 7" x 5-Y2" tubing string to the cut. (DONE) 3. Set two (2) RBP's at 9204' and 9240' above the tubing stub at 9283'. (DONE) 4. Run US IT to determine top of cement in the 9-5/8" x 13-3/8" annulus. (DONE - TOC @ 1910') 5. Set third RBP at 2600' (DONE) 6. Cut and Recover 9-5/8" Thermocase II and 10-3/4" casing just above TOC (The cemented shoe in the 10-3/4" x 13-3/8" annulus passed a PT to 1000 psi). 7. Run US IT to determine top of cement in the 13-3/8" x 20" annulus. 8. Remove stack and install 20" diverter lined to flowback tanks 9. Recover 13-3/8" casing just above TOC. 10. Run and cement 13-3/8" casing to surface. 11. Run and cement 9-5/8" casing to surface. 12. Run 4-Y2" 13Cr80 stacker packer completion with Baker S-3 packer. Position packer at -9215' MD. 13. Displace the IA to packer fluid and set the packer. 14. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 15. Set BPV. ND BOPE. NU and test tree. RDMO. If you have any questions, I can be reached at 564-4303 (0) or 240-8041 (cell). Doug Cismoski (~t'" À.'I\_I>.I¡:;;r, f\ 1 ! G" i~ l ') n f1 ii U·W;'~i':"_k~' {ì.V "JJ :.: (,..'-"'\.,.'.,1 1 of 1 8/2/2006 12:50 PM e ~1f~1fŒ (ID~ L%~L%~æ1Ã\ e AI1ASIiA OIL AND GAS CONSERVATION COMMISSION / Doug Cismoski Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 -""' dv 0 't) \ -:3 4" Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-03A Sundry Number: 306-204 Dear Cismoski: " , .,' 1i"'''' "11'1 -< . Znf\f'J' :Cu"'j>!li/'l,:.KI...f); :.LJ·\J I ¿;Y:. vv 'i:.-1!Vu-\Ü \i~~f.-~~Þ' ~ ~ ....... 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, DATED thisß day of June, 2006 Encl. /fl,' \11~ V ALASKA I ::~;i~1:E~~~~:)~:!'SSION R~~:"o~ ~ APPLICATION FOR SUNDRY APPRQVAb¡¡ & Gas Cons. CQrtI11ission 20 MC 25.280 Anchorage 1. Type of Request: 0 Abandon 181 Repair Well (" o Plug Perforations o Stimulate o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension o Re-Enter Suspended W 2. Operator Name: 4. Well Class Before Work: / 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development 0 Exploratory 200-134 / 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20057-01-00 /' 7. KB Elevation (ft): 58.22' 9. Well Name and Number: PBU D-03A ./ 8. Property Designation: 10. Field / Pool(s): ADL 028285 Prudhoe Bay Field / Prudhoe Bay Pool 111;: ..... ,Y. 0' _,il ··i····. ii. < '.. 'i;;!:'i .;; .. '.' < .",,'" .,.;:i..··,'.· Total Depth MD (ft): Total Depth TVD (ft):1 Effective Depth MD (ft): Effective Depth TVD (ft) Plugs (measured): Junk (measured): 11355 9003 11292 9006 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 30" 10~ 100' Surface 2289' 20" 2289'../ 2289' Intermediate 4430' 13-3/8" '4ff30' 4204' 3090 1540 Production 10429' 11-3/4" x 10-3/4" x 9-5/8" 1 0429' 8840' Liner 1358' 2-7/8" 9997' - 11355' 8459' - 9003' 13450 13890 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 10820'-11281' 9011'-9007' 5-1/2", 17# x 4-1/2", 12.6# L-80 10389' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker packer I Packers and SSSV MD (ft): 10212' 12. Attachments: 13. Well Class after proposed work: 181 Description Summary of Proposal 0 BOP Sketch o Exploratory 181 Development 0 Service o Detailed Operations Program 14. Estimated Date for Junh ,2006 15. Well Status after proposed work: .-/ Commencing Operations: 181 Oil o Gas o Plugged o Abandoned 16. Verbal Approval: ~: o WAG OGINJ OWINJ o WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Doug Cismoski, 564-4303 Printed Name Doug Cismoski Title Drilling Engineer Sicmature A-h.ü..¿, ~..:.- ~< Date c<ø/~(, Prepared By Name/Number: Phone 564-4303 Terrie Hubble, 564-4628 - ¿:7 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: æ(, .. öJ,Otf o Plug Integrity ~OP Test o Mechanical Integrity Test o Location Clearance Other: T e <;. t- BOPE to ~S-OO f~ · RBDMS 8Fl JUN 1 3 2006 Subsequent Form Required: 10 - ~D YJd ([ J. ~ COMMISSIONER APPROVED BY 6-/3,fJ6 Approved By: THE COMMISSION Date Form 10-403 Revised Q7/2OO5 'l¡6 ~V '- Submit In Duplicate OR!:d~J ..oAL e e D-03A Rig Workover Scope of Work: Pull 7" x 5-%" completion, recover Thermocase and 9-5/8" production casing to top of cement, recover 13-3/8" casing to top of cement, run and cement 13-3/8" casing to surface, run and cement 9-5/8" sing to surface, and run 4- W" 13Cr80 stacker packer completion. MASP: 2 psi Well Ty . ,producer Estimate Start Date: June 21, 2006 Pre-ria [ reD wor : S 1 Drift thru 5-%" tubing for chem cutter. Run PDS caliper survey for 5-1/2" tubing. Set L TTP in liner top at 9997' MD. DONE 5/30/06 ,/ E 2 Run SCMT to determine top of cement from the packer squeeze. Pressure up tubing to 500 psi while runninQ SCMT. Done E 3 Set HES 5-%" FasDrill at 9299' MD, in the 7th full joint above GLM #2, 5' above the pin end. Chem cut 5-%" tubing 15' above the FasDril1. Reference tubing tally dated 09/18/1982. F 4 Circulate wellbore to clean 1 % KCI through chemical cut. FP w/ diesel. CMIT TxlA to 3500 psi. MITOA to 2000 psi Bleed WHP's to 0 psi. 0 5 Check the tubing and IC Casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage. PPPOT T & IC. Note: Well has confirmed TxlA communication. 0 6 Set a BPV in the tubing hanger. 0 7 RHINO line cellar. Remove the wellhouse & flow line. Level the pad as needed for the rig. k Proposed Procedure // 1. MIRU. NO tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater throUgh the cut. 2. Pull and LD 7" x 5- W" tubing string to the cut. 3. Run USIT to determine top of cement in the 9-5/8" x 13-3/8" annulus. 4. Recover 9-5/8" casing just above TOC. /' 5. Run USIT to determine top of cement in the 13-3/8" x 20" annulus. 6. Recover 13-3/8" casing just above TOC. 7. Run and cement 13-3/8" casing to surface. 8. Run and cement 9-5/8" casing to surface. 9. Run 4- W' 13Cr80 stacker packer completion with Baker S-3 packer. Position packer at -9215' MD. 10. Displace the IA to packer fluid and set the packer. / 11. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 12. Set BPV. NO BOPE. NU and test tree. RDMO. TREE = 6" CrN e SAFETYNOa ORlGWELLBORE& PERFS P&A'dW/CMT. WELLHEAI:> = MCEVOY D-03A PKR SQZ - /00, THERE'S CMT BetlND TBG. ACTUATOR - OTIS ESTIMATED TOC IS 10,000' ***(SEE NOTE BELOW)*** KB. ELEV = 58,22' BF. ELEV = 38.10' ~ Y 44' H 11-3/4" X 9-5/8" THERMOCASE II I KOP= 2900' Max Angle = 94 @ 11270' 1834' -i 10-3/4" X 9-5/8" XO, ID = ?17? I Datum MD = 10451' 1868' -i 7" x 5-1/2" XO, ID = 4.892" I Datum lVD = 8800' SS / .~ 1876' -i 9-5/8" Foe I / 110-3/4" CSG, 55,5#, N-80, ID =?17 1 1834' r 1931' -i 5-1/2" OTIS 'ROY' SSSV NIP, ID = 4.562" I 19-5/8" CSG, 47#, N-80, ID = ???? I .~ . 1986' -i 9-5/8" Foe I 1991' t-- r---.. D' I 1991' -i 10-3/4" BAASH ROSS PATCH, ID =17? I 113-3/8" CSG, 72#, N-80, ID =?17 I 19~ r- l- I J I -~ 1994' -i 13-3/8" BAASH ROSS PATCH, ID =17? I 120" CSG, 133#/94#, K-55/H-40, ID =? I /~79'J ~ ~ 2379' -i 10-3/4" X 9-5/8" XO, ID =17? 1 \,/ µ ~ GAS LIFT MANDRELS 13-3/8" CSG, 68/61#, K-55 4430' ST MD lVD DEV TYÆ VLV LATCH PORT DATE SEALLOCK, ID = 12.415"/12.515" U 10 3099 3038 18 OTIS DOME RM 16/64 09/21/00 9 4857 4468 45 OTIS DMY RA - 01/30/00 8 6781 5811 46 OTIS DOME RA 16/64 09/21/00 Minimum ID = 2,372" @ 10006' 7 7932 6656 37 OTIS DMY RA - 01 /30/00 PIN ID OF 2-7/8" LINER 6 8518 7114 31 OTIS DMY RA - 01 /30/00 5 8674 7230 29 OTIS DOME RM 16/64 02/22/04 4 9081 7620 29 OTIS DMY RA - 01/30/00 ~ ~ 3 9243 7750 28 OTIS DMY RA - 01/30/00 ITOPOF 2-7/8" LNR 1 9997' I 2 9571 8041 28 OTIS DMY RA 01/30/00 I I - 1 9727 8226 28 OTIS S/O RA 24/64 09/21/00 I I ~ 9997' I-iBAKER DEPLOYMENT SLV, ID=3,OO" 1 1~-1/2" TBG, 17#, L-80 BTRS, 10188' 10078' H5-1/2" OTIS XA SLIDING SLV, ID = 4.562" I ,0232 bpf, ID = 4.892" 10188' H BTM PBR TBG SEAL ASSY 1 SAFETY NOTES: IA X OA COMM. OPERATING LIMITS: I 10212' l-i 9-5/8" X 4-1/2" BOT PKR, ID = 3.958" I MAX lAP = 2200 PSI; MAX OAP = 2200 PSI; MAX ~ OOAP = 500 PSI. WELL HAS 4 WELLHEAD VLVS. ~ I 10308' H4-1/2" OTIS X NIP (BEHIND LNR) ID = 3.813" I BTM 2 ACCESS THE 13-3/S" X 20" ANNULUS (16" CIRC STRING REMOVED DURING 1974 RWO) ~ (01/11/04 WAlVER)*** I 10347' H4-1/2" OTIS XN NIP (BEHIND LNR) ID = 3.725" I ) 14-1/2" TBG, 12,6#, L-80, ,0152 bpf, ID = 3,958"1 10389' I I 10389' H 4-1/2" BOT MULES HOE (WLEG) I I 10386' H ELMD TT LOGGED 03/26/98 I PERFORATION SUMMARY REF LOG: SWS-BHCS ON 05/31/70 ANGLE AT TOP PERF: 89 @ 10820 I MIL LOUT WINDOW 10429' - 10434' 1/ Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10820 - 10885 0 09/15/00 2" 4 10915 - 11281 0 09/15/00 PBTD H 11292' 1 19-5/8" CSG, 47#, N-80, SEALLOCK, ID = 8.681" 1 10797' I I_l 12-7/8" LNR, 6,16#, L-80 STL, .00579 bpf, ID = 2.372 I 11355' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 06/08/70 ORIGINAL COM PLETION 04/02/03 BJIINTLH CORRECTIONS WELL: D-03A 01/01/77 RWO (16" CSG PULLED) 09/17/03 CMOITLP DATUM MD, LOCATION PERMIT No: 2001340 08/01/77 RWO 02/22/04 JLJ/TLP GL V ClO API No: 50-029-20057-01 09/19/82 RWO SEC 23, T11 N, R13E, 1909.8' FNL & 1067.08' FEL 09/17/00 CTD HORlZ SIDETRK (D-03A) 05/02/01 CH/TLP CORRECTIONS BP Exploration (Alaska) 1876' -i 9-5/8" FOC I -2100 -i4-1/2" HES X NIP, ID = 3.813" -i 9-5/8" FOC I -i 10-3/4" BAASH ROSS PATCH, ID = ??? I -i 13-3/8" BAASH ROSS PATCH, ID = ??? I -i 10-3/4" X 9-5/8" XO, ID =??? I GAS LIFT MANDRELS ST MD ìVO DEV TYPE VLV LATCH PORT DATE 4 3 2 1 TREE = 6" CrN WELLHEAO = MCEVOY ACTUA TOR = OTIS KB. ELEV = 58.22' BF. ELEV = 38.10' KOP = 2900' Max Angle = 94 @ 11270' DatumMD= 10451' Datum ìVD = 8800' SS 19-5/8" CSG, 40#, L-80, ID = 113-3/8" CSG, 68#, L-80, ID = 19-5/8" CSG, 47#, N-80, ID = ???? 1 113-3/8" CSG, 72#, N-80, ID = ??? I 120" CSG, 133#/94#, K-55/H-40, ID = ? D-~A Proposed RWc!t 13-3/8" CSG, 68/61#, K-55 SEALLOCK, ID = 12.415"/12,515" 1 TOP OF 2-7/8" LNR 1 9997' 5-1/2" TBG, 17#, L-80 BTRS, .0232 bpf, ID = 4,892" 10188' -iTOP of Cement of 13-3/8" Casing I -iTOp of Cement of 9-5/8" Casing I 1986' 1991' 1994' 2379' -i4-1/2" HES X NIP, ID = 3,813" -i 9-5/8" x 4-1/2" BAKER S-3 A<R -i4-1/2" HES X NIP, ID = 3.813" -i UNIQUE MACHINE OVERSHOT -iBAKER DEPLOYMENT SLV, ID= 3,00" -i5-1/2" OTIS XA SLIDING SLV, ID = 4.562" -i BTM PBR TBG SEAL ASSY I l-i 9-5/8" X 4-1/2" BOT A<R, ID = 3.958" 1 I /"' 10308' H4-1/2" OTIS X NIP (BEHIND LNR) 10 = 3.813" 10347' H4-1/2" OTIS XN NIP (BEHIND LNR) ID = 3.725" 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958"1 10389' H 4-1/2" BOT MULESHOE (WLEG) 10386' H ELMD TT LOGGED 03/26/98 I PERFORATION SUMMARY REF LOG: SWS-BHCS ON 05/31/70 ANGLEATTOP PERF: 89 @ 10820 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10820 - 10885 0 09/15/00 2" 4 10915 - 11281 0 09/15/00 19-5/8" CSG, 47#, N-80, SEALLOCK, ID = 8.681" 12-7/8" LNR, 6.16#, L-80 STL, .00579 bpf, ID = 2.372 DATE 06/08/70 01/01/77 08/01/77 09/19/82 09/17/00 05/02/01 REV BY CHlTLP COMMENTS ORIGINAL COM PLETION RWO (16" eSG PULLED) RWO RWO CTD HORlZ SIDETRK (D-03A) CORRECTIONS DATE 04/02/03 09/17/03 02/22/04 REV BY COMMENTS BJMlTLH CORRECTIONS CMOITLP OA TUM MD, LOCATION JLJITLP GL V C/O I MILLOlfTWINOOW 10429' - 10434' PRUDHOE BA Y UNIT WELL: D-03A PERMIT No: 2001340 API No: 50-029-20057-01 SEC 23, T11 N, R13E, 1909.8' FNL & 1067,08' FEL BP Exploration (Alaska) 7/18/2005 10:58 AM 1 of 1 SCl~N~\JEt~ . II J 2.~: 2005 Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 Email: NSUADWWellIntegrityEngineer@bp.com Please call if you have any questions. Hello Winton & Jim. The waiver has been canceled and well D-03 has been classified as a Trouble well. D-03 has Thermocasing and the required test pressure to maintain the IAxOA communication waiver is greater than the rated collapse of the outer Thermocasing shell. Anders, Joe L wrote: Jim Regg AOGCC In the past you have given status (e.g., well secured and options for repairs are being evaluated). To make sure our records are clear, it may be preferable to state that BP has canceled its internal waiver and give the well status. That will avoid someone not as familiar with the process as you and us that this is not an AOGCC waiver Joe - Thanks for the notice that the BP internal waiver has been canceled. I believe the well is PBU D-03A, PTD 2001340. -----Original Message----- From: J ame s Regg [!n.9.:.~J..t.:g...:..1.~.~_!.:.~.9..9..~.~:.9.~.~..~...:....ê...t...9.:.t...~...:...9.:.~...:..~::!:.ê..] Sent: Wed 7/13/2005 9:45 AM To: Anders, Joe L Cc: Subject: Re: D-03: Cancel Waiver Will do, thanks for the note back. Joe ') Subject: RE: D-03: Cancel Waiver From: "Anders, Joe L" <anders22@BP.com> Date: Wed, 13 Jul2005 11 :09:04 -0800 To: James Regg <jim_regg@admin.state.ak.us> CC: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Engel, Harry R" <EngeIHR@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "Dube, Anna T" <Anna~Dube@BP.com>, "Mielke,Robert L." <robert.mielke@BP.com>,. "Reeves, Donald F" <ReevesDf@BP.com> Pr:bÆ,zoo -( 34 ) RE: D-03: Cancel Waiver ') \ ) ~~~II MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ I nserts\M icrofi I m _ Marker.doc 09/16~03 Schlumberger NO. 2959 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD D-03A ~.~LI~'D~ I~ . 23404 MCNL 06/26/03 W-34A ~ ,(~__,~.~r 23347 MCNL 05/22/03 F-10B ~,~ ~~ 23401 MCNL 06112103 F-26B ~-~( ~ 23399 MCNL 06/23/03 D.S. 7-30A-~~~ 23420 MCNL 08/08/03 W-16A ~~ :}~ 23426 MCNL 07/19/03 Pl-18A ~~~ ~ 23276 RST 04/04/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd.. ~.,~,,~,,,~___~ ~,~'~' ~'~ ' Anchorage, Alaska 99508 Date Delivered: SEP 20 2003 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'I-rN: Beth 07/22/03 Schlumberger NO. 2916 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATI'N: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Color Well Job # Log Description Date Blueline Prints CD Z-39 c',~~' PROD LOG W/DEFT 07119103 D.S. 2.14 '~.c~O~L'~ ~,~ RST GRAVEL PACK 07117103 ~ ~ ~*~ LDL 071~ 6103 N-~Ja '~q~ ~ ~ SBHP SURVEY 07/~6103 D.S. 15-08B ~ ~ ~-~ RST G~VEL PACK 07/14/03 ' ~[ I ~ ( ~ PROD PROFILE W/DEFT 06109/03 D,S. 5-04A ~ ~0%~ MEM PROD PROFILE 06/14103 D-13A ~~1 MDB PROD PROFILE 06123103 D.S. 5-02A ~O~ ~ M ~' MEM PROD PROFILE 06/10/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'FTN: Beth Permit to Drill 2001340 MD 11355 J TVD DATA SUBMITTAL COMPLIANCE REPORT 315/2003 Well Name/No. PRUDHOE BAY UNIT D-03A Operator BP EXPLORATION (ALASKA) INC 9003 - Completion Dat 9/16/2000 ~ Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-20057-01-00 UIC N REQUIRED INFORMATION Mud Log N.._9 Sample N__~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval OH I Start Stop CH ED D Ver LIS Verification 10680 11329 Open (data taken from Logs Portion of Master Well Data Maint) Received 5/9/2002 12/6/2002 Dataset Number Comments 10800 ~// 11408~' Digital Well Logging Data / ED C Cn See Notes Well Cores/Samples Information: Name Start Interval Stop 10380 11355 Open Sent Received Dataset Number Comments Rate of Penetration, Dual Gamma Ray ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Analysis _ Y ! N ~ R ~.r.~.iv~.d ? Daily History Received? ~ N Formation Tops i~ N Comments: Compliance Reviewed By: Date: To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 04, 2002 MWD Formation Evaluation Logs · D-03& AK-MW-00181 D-03A: Digital Log Images 50-029-20057-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~ ~p_~ RECEIVED DEC 0 6 2002 WELL LOG TRANSMITFAL To: State of Alaska April 29, 2002 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs D-03A, AK-MW-00181 1 LDWG formatted Disc with verification listing. API#: 50-029,20057-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: J'nn Cadvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED 2002 AlaskaOil & Oas Cons. Commissio~ An~orage K~' STATE OF ALASKA ALAS OIL AND GAS CONSERVATION ,JMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Operation Shutdown [] Stimulate [] Plugging [] Pull Tubing [] Alter Casing [] Repair Well [] Other 5. Type of well:. . IX] Developmen[ [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 1910' SNL, 1067' WEL, SEC. 23, T11N, R13E, UM At top of productive interval 1983' NSL, 3234' WEL, SEC. 14, T11N, R13E, UM At effective depth (n/a) At total depth 2662' NSL, 2765' WEL, SEC. 14;' T11N, R13E, UM [] Perforate Acid 6. Datum Elevation (DF or KB) KBE = 58.22' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number D-03A 9. Permit Number / Approval No. 200-134 10. APl Number 50- 029-20057-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 11355' feet 9003' feet 11292' feet 9006' feet Length Size Plugs (measured) Junk (measured) KOP (window) 10429'- 10434', 9-5/8" CSG abandoned from 10429' to 10797'. Cemented MD TVD Structural Conductor 100' 30" 250 sx concrete Surface 2289' 20" 4800 sx Permafrost Intermediate 4430' 13-3/8" 2000 sx Class 'G' Production 10429' ~1-3/4-1o-3/4-9-5/8 3830 sx Class 'G' Liner Sidetrack. Liner 1358' 2-7/8" 74 sx Class 'G' 122' 122' 2311' 2311' 4441' 4441' 10451' 8858' 9997'-11355' 8459'-9003' Perforation depth: measured Open Perfs 10820' - 10885', 10915' - 11281' true vertical Open Perfs 9011' - 9009', 9009' - 9007'. Tubing (size, grade, and measured depth) 7"x 5-1/2" XO @ 1868', 5-1/2" 17#, L-80 tubing to 10212' with 4-1/2" tailpipe @ 10389'. Packers and SSSV (type and measured depth) 9-5/8" PKR (BOT) @ 10212', 5-1/2" Otis SSSVLN @ 1931' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure RECEIVED ,.:ji',,t 05 2001 Aj~,ska 0ii & ~,as Co~s, C~mrnission Anchorage 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed scott LaVo~e _~~t ~______~ ~ Title Technical Assistant Prepared By Name/Number: De Wayne ~chno~,f'5~4_.-~~ Submit In Duplicate'~ Form 10-404 Rev. 06/15/88 ORIGINAL D-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS O4/11 ~2OO 1 04/23/2001 05/04/2001 ACID: PRE ACID TIFL ACID: ACID PICKLE ACID: ZONE 2 ACID JOB SUMMARY 04/11/01 TIFL PASSED, PRE-ACID [Ann Comm, TIFL] 04/23/01 PUMP 12 BBLS METH/H20, 24 BBLS 50/50 DIESEL/XYLENE, 24 BBLS 12/10 DAD ACID FOLLOWED BY 196 BBLS DEAD CRUDE AVE RT--4 BPM AVE PSI=1100 PSI. WELL POP TO FLOW PICKLE OUT. WILL PUMP ACID TREATMENT 4/26/01. 05/04/01 ACIDIZED ZONE 2 PERFS WITH 75 BBLS OF 7.9% HCL USING 2 EA. WAX BEAD DIVERTER STAGES. MAX TREATING PRESSURE WAS 2125 PSI, AVG TREATING PRESSURE WAS 1082 PSI AT 4.75 BPM. LEFT WELL S/I FOR 6 HR SOAK TO DISSOLVE WAX. PCC TO POP @ 2030 HRS. WELL FP'D W/5 BBLS MET. Fluids Pumped BBLS. Description 12 DIESEL 27 METHANOL 669 2% KCL WATER 12 XYLENE 24 12/10 DAD ACID 196 CRUDE 75 7.9% HCL ACID 1015 TOTAL MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, ~-~ Commissioner i~ ~ ~'t . Tom Maunder, P. I. Supervisor ~(.~h..O ~,. DATE: April 20, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit D Pad Friday, April 2.0, 20.0!: I traveled to BPXs D Pad and witnessed the semi annual safety valve system *testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 20 wells and 40 components with 1 failure. The surface safety valve on well D,06 had a slow leak when pressure tested. This valve was serviced and the retest.witnessed 'on thiS date. Merv Liddlow performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and ali equipment appeared to be in fair conditions. Summary: I witnessed the semi annual SVS testing at BPXs D-Pad. PBU D Pad, 20 wells, 40 components, I failure 2.5% failure rate 25 wellhouse inspections Attachment: SVS PBU D Pad 4-20-01 CS X, Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS PBU D Pad 4-20-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Chuck Scheve Submitt~ By: Chuck Scheve Field/Unit/Pad: Prudhoe/PBU / D Pad Separator psi: LPS 154 Date: 4/19 & 4~20 HPS 660 Well Pemit Separ Set ~ T~t T~t T~t Date ~, WA~,'~ ~mJ, Number Number , PSI , PSI Tdp , Code Code Code Passed G~ or ~C~ D-01A 1970780 154 125 125 P P OIL D-03A 2~1340 154 125 125, P P OIL , ~ , D-04A 1871250 D-05 1700060 660 550 450 P ' P' ' OIL D-06A 1970430 660 550 600 P 4 OIL D'-07A 1931570~ 660 550 525 P P ' 4/20/0'1 ' 'oiL D-08 1790360 D-09A 1990850 ~60 550 525 e P ' ' OIL D-10 1790530 ~ 660 550 ~25 P P ' OiL , ~,~ , , D-11A 1951830 660 550 525 P P OIL , , , , D-12 1800150 660 550 530 P P OiL 2ooo8 o ' ' ' D-14A 1961530 , , D-15A .1972120 , , ~ , , , D-16 1811710 660 550 5~ P P OIL , ~ , ,, ,, , , , , , , , D- 17A 1960460 . ,, ~ , , ~ D-18 1811880 D-20 1820440: 154 125 ' '120 P' P ' ' OIL D-21 1820~20 154 125 125~ P P ~' oIL D-22A 1972~0 ~ , , , D-23A 1961880 660 550 525 P P OIL D-24 1852990 D-25A 2~0240 154 125 ' ' '100 P P ' OIL ~ , D-26A 1970870 660 550 525 P P OIL D-27 ' 1860330 660 " 550 ~50 P P OIL D-28A' '1952130 ' 660 550 550 P P OIL D-29 1852530 154 125 110 P P "OIL D-30 1960260 D-31A '1960950 660 550 '550 P e ' OIL D-33 196036'0 '660~ 550 S50 P P OIL , ,, ~ , , , ~ RJF 1/16/01 Page 1 of 2 SVS PBU D Pad 4-20-01 CS Wen Number Wells: Permit Number 2O , Remarks: Separ Set L/P Test Date on, WAG, ~NJ, PSI PSI Trip Code Passed CAS or CYCLE 40 Failures: 1 Failur~ Rate: 2.50% [2]90 Day Components: ...... .. The mxrface safety,valye on well D-6, .had sl.0w leak, ~ pre~.testexL V~ve was ~V~c~ ~,~~ ~,~y,' ................. __~ RJF 1/16/01 Page 2 of 2 SVS PBU D Pad 4-20-01 CS STATE OF ALASKA ALASKa.~f ,L AND GAS CONSERVATION COM~' SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. 'Name of Operator .7. Permit Number BP Exploration (Alaska) Inc. 200-134 3. Address ?~'CXT, A~ 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~, 50- 029-20057-01 4. Location of well at surface ~ ...... : ~: ,~r ·. ~ 9. Unit or Lease Name 1910' SNL, 1067' WEL, SEC. 23, T11 N, R13E, UM '~ Prudhoe Bay Unit At top of productive interval ; //'.'~.,,_.) ~.~ 1983' NSL, 3234' WEL, SEC. 14, T11 N, R13E, UM ' --~',.,-,-.~'-.--~'-~- · At total depth ,.~ -.. 10. Well Number 2662' NSL, 2765' WEL, SEC. 14, T11 N, R13E, UM /~) ..... D-03A 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 58.22' ADL 028285 12. Date SpuddedD/12/2000 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'9/14/2000 9/16/2000 115' Water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) 1 18. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set1 21. Thickness of Permafrost 11355 9003 FTI 11293 9006 FTI [] Yes [] NoI (Nipple) 1931' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run GR / HOP 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 30" Stove Pipe Surface 100' 36" 250 sx Concrete 20" 133 / 94 / 65# K-55 / H-40 Surface 2289' 26" 4800 sx Permafrost 13-3/8" 68 / 61 / 72# K-55 / N-80 Surface 4430' 17-1/2" 2000 sx Class 'G' 9-5/8" x 56# / 47# N-80 Surface 10429' 12-1/4" 3830 sx Class 'G' (x 10-3/4. x 11-3/4") 2-7/8" 6.16# L-80 9997' 11355' 3-3/4" 74 sx Class 'G' "' - ' 24. Perforations op. en to, Production (MD+TVD of Top and 25. TUBING RECORD' Bottom and imervai, size and number) S~zE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 5-1/2", 17#, L-80 10212' 10212' MD TVD MD TVD 4-1/2" Tailpipe 10389' 10820' - 10885' 9011' - 9009' 10915' - 11281' 9009' - 9007' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 0J IGIN/ L 2000' Freeze Protect with 34 Bbls of MoOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) September 24, 2000 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOO I Flow Tubing Casing Pressure CALCULATED OIL'BBL GAS-MCF WATER'BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests ,, Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Zone 2C 10374 8792' 25N 10467' 8871' 23N 10529' 8915' 22N 10560' 8935' 21N 10640' 8975' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble .~/~.,~f ~ Title TechnicalAssistant Date D-03A 200-134 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 BP EXPLORATION Page 1 of 5 Operations Summa Report Legal Well Name: D-03 Common Well Name: D-03 Spud Date: 4/19/1970 Event Name: REENTER+COMPLETE Start: 9/10/2000 End: 9/16/2000 Contractor Name: NORDIC C^LIST^ Rig Release: 9/16/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: Date From- To HOurs Activity code :Phase Description of Operations 9/10/2000 00:00 - 08:00 8.00 RIGU PROD1 Park DS/N #1 on D Pad. Raise derrick. General RU 08:00 - 10:30 2.50 RIGU PROD1 Spot rig over tree. Remove tree cap. NU BOPE. Spot slop tank, berm and RU hardline 10:30 - 12:30 2.00 RIGU PROD1 Pull CT to floor and stab. Install CTC. PT @ 32K 12:30 - 13:00 0.50 RIGU PROD1 Fin NU BOPE. Accept rig for operations @ 1100 hrs 9/10/00 13:00- 18:00 5.00 BOPSUF; PROD1 Begin DOPE test. Witness waived by AOGCC Fill CT w/FVV. Pump dart. Landed at 58.2 bbls. PT CTC, inner reel valve @ 3500 psi 18:00 - 18:30 0.50 BOPSUF PROD1 Safety/prespud mtg 18:30 - 19:30 1.00 STWHIP PROD1 Chk well for press. Bleed off residual. Slight leak thru wing. 19:30 - 20:00 0.50 S'I'WHIP PROD1 MU milling BHA #1 (cement/junk mill, straight motor). 20:00 - 22:00 2.00 STWHIP PROD1 RIH. Tag with motor work 10194'. Correct depth to 10186'. 22:00 - 00:00 2.00 STVVHIP PROD1 Mill cement 70 - 100 FPH to 10219'. Two stalls here, then smooth milling 50 - 80 FPH to 10300'. 9/11/2000 00:00 - 01:15 1.25 STWHIP PROD1 Mill cement f/10300' (2.7/1300) at 80 - 100 FPH with stalls at 10312', 10326', 10349'. Last one XN? Stall 10359'. Mill to 10370'. 01:15 - 03:00 1.75 STWHIP PROD1 POOH. 03:00 - 03:15 0.25 STVVHIP PROD1 SB inj. LD Milling BHA #1. 03:15 - 05:00 1.75 S'I'WHIP PROD1 MU milling BHA #2 (HC D331GEB, 1.37 deg motor, MWD package). Change pack-off. 05:00 - 06:45 1.75 STWHIP PROD1 RIH. 06:45 - 08:10 1.42' STWHIP PROD1 Tag at 10220' CTD. PUH 38K. Log/ream down from 10215' 2.4/2260 08:10 - 08:30 0.33 STVVHIP PROD1 Subtract 16', RIH reaming. IA 495 08:30 - 08:45 0.25 S'I'WHIP PROD1 Tag at 10372'. PUH 47k. Orient to Iow side 08:45 - 09:20 0.58 STWHIP PROD1 Mill cement from 10372' 2.5/2460/165R 09:20 - 10:00 0.67 STWHIP PROD1 Begin Iow side ramp at 10391' 2.6/2750/177L and drill to 10414' 10:00 - 10:20 0.33 STWHIP PROD1 Orient to high side 2.6/2100 10:20 - 12:20 2.00 STVVHIP PROD1 Ream 10100-300' while circ out tailpipe gas thru buster 12:20 - 13:00 0.67 STWHIP PROD1 Begin milling high side ramp from 10414' 2.6/2750/8R and drll to 10426'. Back on MM w/gassy returns 13:00 - 13:20 0.33 S'I'WHIP PROD1 Ream 10350-426'. PUH 47.3K 2.6/2660 13:20 - 14:10 0.83 STWHIP PROD1 Begin tie-in from 10240'. All gas is out. Losing 5 bph. Load CT with 35 bbl Fie Pro pill. Add 2.0' so TD is 10428'. RIH 14:10 - 16:40 2.50 STWHIPi PROD1 POOH @ 80% chasing cmt fines to surface. Receive AOGCC Permit to Drill approval 16:40 - 17:30 0.83 S'I'WHIP PROD1 OOH. Change out mill and motor for 3.80" one-step mill and 2.57 deg motor 17:30 - 19:30 2.00 S'I'WHIP PROD1 RIH w/BHA #3. Correct depth at flag (-21.5'). RIH to 10350'. 19:30 - 20:00 0.50 S'I'WHIP PROD1 Orient to high left. RIH at min rate. Tag 10419.5'. Pull off bottom and check TF = 26L RIH at 2.0/1600 and tag 10419'. PUH to tie-in. Log tie-in at 10229' GR spike. Add 9.5'. 20:00 - 23:20 3.33 STVVHIP PROD1 RIH 2.0/1700. Bring pumps to 2.6/2550, RIH 17.5k down, tag 10428.0'. Flag pipe, PU 1', and start time drilling at 20:20 hrs. 2.6/2550/15L. 23:20 - 00:00 0.67 STWHIP PROD1 Back to 10428'. Continue time drilling with TF steady at 9L Swap well over to Fie-Pro. 9/12/2000 00:00 - 03:30 3.50 S'I'WHIP PROD1 Continue time milling per RP. Lost charge at 10430.3'. Pick-off bottom. Finish time milling at 10431'. Final 2.6/3500/9L. 03:30 - 05:00 1.50 STWHIP PROD1 Increase WeB. Acted like it wanted to run on us. Back off and establish pattern. Free spin: 2.6/3300/4L. Milling: 2.6/3800/26Lwith 4k WeB. Significant metal over shakers. Two stalls at 10433.5'. 05:00 - 07:30 2.50 S'I'WHIP PROD1 Continue milling to 10441'. Free spin 2.5/3100/12R. Milling 2.5/3600 reactive to 9L-38L. 3k VVOB. Ream thru window, clean. IA 750 07:30 - 08:05 0.58 STWHIP PROD1 PUH 40.5k. Begin tie-in, no corr. Flag at 10135.0' EOP Printed: 9/1912000 4:13:00 PM BP EXPLORATION Page 2 of 5 Operations Summa Report Legal Well Name: D-03 Common Well Name: D-03 Spud Date: 4/19/1970 Event Name: REENTER+COMPLETE Start: 9/10/2000 End: 9/16/2000 Contractor Name: NORDIC CALIST^ Rig Release: 9/16/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: Date From -TO Hours ActiVi~ COde Phase ~ DescriptiOn of Operati°nS · : !9/12/2000 08:05 - 09:45 1.67 STWHIP PROD1 POOH for dressing mill 09:45 - 10:55 1.17 STWHIP PROD1 OOH. LD 2 its. Change mill and motor. Change MWD probe, NRJ 10:55 - 12:40 1.75 S'I'WHIP PROD1 RIH w/BHA ~ (2.29 deg motor and 3.78" tapered mill) 12:40 - 12:50 0.17 S'I'WHIP : PROD1 Tie-in to flag, -20'. Begin tie-in at 10250' 2.5/3250/97R. Add 7.0' ,12:50 - 13:30 0.67 STWHIP I PROD1 Orient to high side. RIH dry to 10429'. Repeat. Same tag. PUH to check/adjust TF. Tag same. Try rolling pumps 2' from TD. No luck. Ease into it with pumps. Several stalls, then est steady milling pattern 0.7 FPM 2.5/3000/9L. 13:30 - 14:20 0.83 S'I'WHIP PROD1 Check tool face. RIH. Time drill. Run through window. Tag TD at 1 O439' CTD. 14:20 - 15:45 1.42 STWHIP PROD1 Dress window w/tapered mill at various tool faces from 9L to 19R. All runs were clean 15:45 - 16:00 0.25 S'I'WHIP PROD1 PUH 38k. Tie-in from 10250' 2.4/2940/69R Add 1.0', flag at 10100' ~ FOP. TD is at 10440' corrected. 16:00 - 17:30 1.50 STWHIP PROD1 POOH for drilling assy 17:30 - 18:30 1.00 DRILL PROD1 OOH. LD motor and mill. MU drilling BHA #5 (M-09 bit and 1.75 deg motor). 18:30 - 20:20 1.83 DRILL PROD1 RIH. Correct depth (-19') at flag. 20:20 - 20:45 0.42 DRILL PROD1 Log tie-in down with bit at 10250'. Add 6'. RIH to 10400' 20:45 - 21:20 0.58 DRILL PROD1 Orient around to high side. Only getting 10 deg per click. 21:20 - 21:40 0.33 DRILL PROD1 RIH at minimum wt with 10L TL. Clean to tag at 10440'. Bring up pumps. TF 30L. 2 stalls at 10439'. Then mill to 10440'. Get a coulpe of clicks. 21:40 - 22:10 0.50 DRILL PROD1 Drill 2.5/3100/10R. Drill to 10455.5 ft CTD. 22:10- 22:45 0.58 DRILL PROD1 Drill 2.6/3300/20R. Stall @ 10472 ft CTD. 22:45 - 23:00 0.25 DRILL PROD1 Continue drilling 2.6/3200/12R. Stall at @10476 ft CTD. Continue drilling 2.6/3250/40R to 10478 ft CTD. Stall out. 23:00 - 23:25 0.42 DRILL PROD1 Looks like tool was clicking when stalling out. Orienting 10 deg/click. PUH. Oriented toll 2.6/3100/10L. 23:25 - 23:45 0.33 DRILL PROD1 Re-start drilling at 10478 ft CTD. 2.6/3200/12R. Stall at 10479.5 ft CTD. Drill 2.6/3200/18R. Stall 10480.7 ft CTD. 23:45 - 00:00 0.25 DRILL PROD1 Drill 2.6/3120/29R 9/13/2000 00:00 - 00:25 0.42 DRILL PROD1 Drill to 10485.5 ftm CTD 2.6/3160/18R. 10497 ft CTD. PUH. 39 K#s . Drill 2.6/3200/72L @10502.5 ft CTD. 00:25 - 01:40 1.25 DRILL PROD1 PUH to 10480 ft CTD. RIH. Tool face went from 23R to 74L in the last eight feet (10494' -10502)t. Working out spot to smooth it. 01:40 - 02:20 0.67 DRILL PROD1 Made a couple of clicks. Drill 2.6/3200/22L .Drill to 10515 ft CTD. 02:20 - 02:35 0.25 DRILL PROD1 Orienting.' Drill 2.5/3100/18R. Stall @ 10524 ft CTD. PUH 39K#s. 02:35 - 02:55 0.33 DRILL PROD1 Drill 2.5/3100/23R. Drill to 10535 ft. Made a click. 2.7/3200/35R 02:55 - 03:20 0.42 DRILL PROD1 Drill 2.6/3300/35R. Made a click to get into the highside. 2.6/3250/40R. 03:20 - 03:30 0.17 DRILL PROD1 Drill 2.6/3200/29R. Stall at 10565.5 ft. 03:30 - 03:45 0.25 DRILL PROD1 Drill 2.6/3280/29R. Stall at 10570.5 ft. Continue drilling 2.6/3200/35R 03:45 - 04:05 0.33 DRILL PROD1 Made a click @ 10573.5 ft. 2.6/3200/35R 04:05 - 04:35 0.50 DRILL PROD1 Drill 2.4/3050/52R. Drill to 10600 ft. 04:35 - 04:45 0.17 DRILL PROD1 Wiper trip to 10450 ft. PUH at 40K#s 04:45 -'05:00 0.25 DRILL PROD1 Re-start Drilling 2.4/3170/52R 05:00 - 05:20 0.33 DRILL PROD1 Continue drilling @10613 ft. 2.5/3180/40R. Drill to 10639 ft. 05:20 - 06:00 0.67 DRILL PROD1 Orienting tool 06:00 - 08:45 2.75 DRILL PROD1 Drill ahead for angle to 10769' - 2.7/2.7/3400/12R. Now planning to land well at +/- 8950 TVD with 87 deg angle. 08:45 - 09:45 1.00 DRILL PROD1 Cent drilling ahead to 10798'. 09:45 - 10:15 0.50 DRILL PROD1 Short trip to window - tight spot at 10527 & work thru same. RIH to Printed: 9/19/2000 4:13:00 PM BP EXPLORATION page3 of 5 Operations Summa Report Legal Well Name: D-03 Common Well Name: D-03 Spud Date: 4/19/1970 Event Name: REENTER+COMPLETE Start: 9/10/2000 End: 9/16/2000 Contractor Name: NORDIC CALIST^ Rig Release: 9/16/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: : : Date From_T° Hours Activi~COde: Phase DesCription of oPerations 9/13/2000 09:45 - 10:15 0.50: DRILL PROD1 bottom and make correction - (+5.2)'. 10:15 - 10:30 0.25 DRILL PROD1 Drill ahead to 10821' - hit 14N shale at 8951' 'rVD. 10:30 - 11:00 0.50 DRILL PROD1 Orient around for build to get out of shale. Orienter giving erratic response making good orientation difficult. 11:00 - 12:45 1.75 DRILL ORNT PROD1 POH to change orienter. 12:45 - 14:15 1.50 DRILL ORNT PROD1 OOH. Stand back injector. Change bit and orienter and MWD probe. MU injector head. 14:15 - 16:15 2.00 DRILL ORNT PROD1 RIH with bit #2 to 10240'. Shallow hole test MWD - OK. 16:15 - 16:45 0.50 DRILL ORNT PROD1 Log tie in to orig GR at 10229' - (Correction -14.5'). 16:45 - 17:00 0.25 DRILL ORNT PROD1 Cent RIH - orientation looks good to go thru window. Cut pump rate and go thru window - OK. RIH to bottom. 17:00 - 18:00 1.00 DRILL PROD1 i Drill to 10890' - appear to be back in sand and possibly Z2. 18:00 - 18:45 0.75 DRILL PROD1 ~Circ up sample for geologist looking for HOT. Sample shows we are about 3' above the HOT. 18:45 - 20:20 1.58 DRILL PROD1 Re-start drilling 2.4/3400/119R. Drill to 10919' with 93 deg. 20:20 - 20:55 0.58 DRILL PROD1 Orienting. 2.5/3050/29R. Tried to drop angle. 20:55 - 21:03 0.13 DRILL PROD1 Drill to 10923'. 21:03 - 21:17 0.23 DRILL PROD1 Orienting tool. 21:17 - 22:10 0.88 DRILL PROD1 Drilling to 10930'. 2.4/3000/46R. Drop angle to 88 deg. Made one click. Re-start drilling 2.4/3180/63R. Drill to 10960'. 22:10 - 22:55 0.75 DRILL PROD1 Drilling ahead to 11,030'. 2.5/3300/85R. Stall out. 22:55 - 23:10 0.25 DRILL PROD1 Continue drilling. 2.5/3500/85R. Drill to 11050'. Found tight spot between 10780'- 10790'. Had an overpull of 45K#s. 23:10 - 23:45 0.58 DRILL PROD1 Wipert trip to 10450 ft. P/U weight 37K at 10650'. 23:45 - 00:00 0.25 DRILL PROD1 Back on bottom. Orienting tool. 9/14/2000 00:00- 00:15 0.25 DRILL PROD1 Continue orienting. 2.5/3100/100L 00:15 - 00:45 0.50 DRILL PROD1 Drilling ahead. 2.6/3350/89L. Drill to 11099'. 00:45 - 01:05 0.33 DRILL PROD1 Problems getting survey - bit vibration interfering with survey data on bottom. Can only get survey data off bottom. 01:05 - 01:20 0.25 DRILL PROD1 Drilling ahead. 2.5/3500/84L Drill to 11125'. 01:20 - 02:50 1.50 DRILL PROD1 Orienting tool. Re-start drilling 2.5/3400/84L. Drill to 11183'. 02:50 - 03:30 0.67 DRILL PROD1 Made some clicks. Erratic tool face readings. Drill 2.6/3300/106L. Drill to 11199'. 2.5/3100L 03:30 - 04:20 0.83 DRILL PROD1 Wiper trip to 10460'. P/U 40K#s. While running in found tight spot at 1O780'. 04:20 - 06:45 2.42 DRILL PROD1 Drilling ahead. 2.5/3350/89L. Drill to 11239'. Made some clicks. 2.6/3500/35R. 06:45 - 07:00 0.25 DRILL PROD1 Got survey showing 94 deg incl. Get clicks to drop angle. Est TD at +/- 11350' - end of polygon. 07:00 - 07:30 0.50 DRILL PROD1 Drill ahead 2.5/2.5 bpm. 3400 psi. 147R TF. ReP = 90 FPH. TD well at 11350' MD. 07:30 - 08:00 0.50 DRILL PROD1 POH to 10200' - hole condition good. 08:00 - 08:45 0.75 DRILL PROD1 Tie in to GR marker at 10229' (Depth correction + 4.5'). Flag pipe at 1 O200' FOP. 08:45 - 09:15 0.50 DRILL PROD1 RIH to bottom. No problem going thru window. Correct TD to 11355'. 09:15 - 11:30 2.25 DRILL PROD1 POH for 2 7/8" liner. Minor pull at 10650'. Came thru window OK. Flag pipe at 8200' FOP. 11:30 - 12:00 0.50 DRILL PROD1 Stand back injector. LD BHA. 12:00 - 12:30 0.50 CASE PROD1 RU to run 2 7/8" liner. 12:30 - 13:00 0.50 CASE PROD1 Safety meeting and Hazard identification prior to running liner. 13:00 - 15:00 2.00 CASE PROD1 Run 45 jts of 2 7/8" 6.16# L-80 STL liner. Fill pipe half way in. 15:00 - 16:00 1.00 CASE PROD1 MU Deployment sleeve and CTLRT. PU injector and MU coil connector. Pull & pressure test - OK. Printed: 9/19/2000 4:13:00 PM BP EXPLORATION Page 4 of 5 Operations Summar Report Legal Well Name: D-03 Common Well Name: D-03 Spud Date: 4/19/1970 Event Name: REENTER+COMPLETE Start: 9/10/2000 End: 9/16/2000 Contractor Name: NORDIC CALISTA Rig Release: 9/16/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: Date FromLTo HOurS ACtivi~ COde phase i: iDeScriPti°n°fOPerationSl :: 9/14/2000 16:00 - 18:00 2.00 CASE PROD1 RIH with liner on CT. Correct to flag at 8200' EOP. (Correction -20.9'). Wt check at window - 44K up 20K down. Tag bottom at 11348' and correct depth to 11355' - (Corr'n +7').' 18:00 - 18:30 0.50 CASE PROD1 Load 5/8" ball in reel manifold and pump to CT. Displace downhole at 2.4 bpm @ 2600 psi. Ball on seat at 48 bbl away. Pressure up to 3900 3si and shear ball seat to release from liner. PU and confirm released - OK. 18:30 - 22:00 3.50 CEMT PROD1 Displace well to 2% KCl brine - 3.2bpm @ 2800 psi. Batch up cement and bring up to weight at 21:50 hrs. 22:00 - 22:15 0.25 CEMT PROD1 Safety meeting prior to pumping cement. 22:15 - 23:00 0.75 CEMT PROD1 Test cement lines to 2500 psi. Switch valves to cement line. Pump 15 bbl Class G slurry to coil. Install dart in reel manifold. Pump dart to coil. SD and verify dart away - OK. Displace cement 2.7 bpm in 2.7 bpm out. Slow down to 2 bpm at 56 bbl. 23:00 - 23:15 0.25 CEMT PROD1 See liner wiper plug shear at 59 bbl away at 3400 psi. Increase rate to '2.6 bpm with full returns. Bump plug at 66.1 bbl away with 3000 psi. Bleed off pressure to verify floats holding - OK. Pressure up to 1000 psi and unsting from deployment sleeve. 23:15 - 00:00 0.75 CEMT PROD1 Circulate at liner top. POH 9/15/2000 00:00 - 01:00 1.00 CEMT PROD1 Continue POH. CCH. Stack back injector. LD BHA 01:00 - 04:00 3.00 CEMT PROD1 P/U new BHA P/U 44 jts 1 1/4" CSH worstring. Stack in injector. 04:00 - 05:20 1.33 CEMT PROD1 RIH to 9000'. Confirm with Dowell lab cement strength is 2150 psi @ 05:00 hours. 05:20 - 06:00 0.67 CEMT PROD1 Wash down inside liner and tag latch collar at 11309'. Correct depth to 11292' (-17'). 06:00 - 06:30 0.50 PERF PROD1 Circulate in 18 bbl of 150k LSRV perf pill and spot in liner. 06:30 - 07:15 0.75 CEMT PROD1 POH with BHA laying in pill. POH to 9980'. 07:15 - 08:00 0.75 CEMT PROD1 Pressure test liner and lap cement to 2200 psi w/550 psi on IA. Hold pressure for 30 min - lost 100 psi. Test OK. 08:00 - 09:30 1.50 CEMT PROD1 POH. Stand back injector. 09:30 - 11:00 1.50 CEMT PROD1 LD 10 jts 1 1/4" CSH & rack back remainder. LD motor and mill. 11:00 - 14:30 3.50 PERF PROD1 Wait on Schlumberger perforating guns to arrive on location. 14:30 - 15:00 0.50 PERF PROD1 Put perf guns in pipe shed and RU to run same. 15:00 - 15:15 0.25 PERF PROD1 PJSM prior to picking up perf guns. 15:15 - 16:00 0.75 PERF PROD1 MU 22 2" perforating guns. 16:00 - 17:00 1.00 PERF PROD1 RIH with 17 stands 1 1/4" CSH workstring. PU injector and MU coil connector. 17:00 - 18:45 1.75 PERF PROD1 RIH with perf guns. Tag latch collar at 11309' and correct depth back to 11292'. Space out for bottom shot at 11281'. 18:45 - 19:30 0.75 PERF PROD1 Pump 10 bbl perf pill. Load firing ball in reel manifold and pump same to coil. Displace ball to firing head 2.3 bpm 2600 psi. Ball on seat at 56.6 bbl away. Fire guns at 3300 psi. Pull off botto immediately. 19:30 - 21:40 2.17 PERF PROD1 POH with perf guns filling across top of hole. CCH, 21:40 - 23:30 1.83 PERF PROD1 Lay down 1 1/4" pipe. 23:30 - 00:00 0.50 PERF PROD1 Continue laying down BH^ Printed: 9/19/2000 4:13:00 PM 1. Type of Request: STATE OF ALASKA ALASK(: IL AND GAS CONSERVATION COMf' ~SION ~PPMCATION FOR SUNDRY APPROVAL' [] Abandon [] Suspend [] Plugging [] Time Extension r'! Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate [] Other Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 1910' SNL, 1067' WEL, SEC. 23, T11N, R13E, UM At top of productive interval 1282' NSL, 3028' WEL, SEC. 14, T11N, R13E, UM At effective depth 1895' NSL, 3223' WEL, SEC. 14, T11N, R13E, UM At total depth 2168' NSL, 3249' WEL, SEC. 14, T11N, R13E, UM D 15. Type of well: lie Development I-! Exploratory [] Stratigraphio [] Service JPLICATE 6. Datum Elevation (DF or KB) KBE = 56.19' ' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number D-03 9. Permit Number 170-005 10. APl Number 50- 029-20057-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10802 feet true vertical 9177 feet Effective depth: measured 10190 feet true vertical 8631 feet Casing Length Structural Conductor 100' Surface 2289' Intermediate 4430' Production 10797' Liner Plugs (measured) Junk(measured) Packer Squeeze from 10000' - 10230', followed by Abandonment Plug, TOC at 10190' (07/00) Chemical Cutter lost in hole (03/87) Size Cemented 30" 250 sx Concrete 20" 4800 sx Permafrost 13-3/8" 2000 sx Class 'G' 11-3/4' X 10-3/4' X 9-5/8' 3830 SX Class 'G' MD 1-VD 100' 100' 2289' 2289' 4430' 4-204' 10797' 9173' Perforation depth: measured true vertical 10417' - 10620' (Ten Intervals) 8830'- 9010' (Ten Intervals) Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 10212' with 4-1/2" tailpipe to 10389, Packers and SSSV (type and measured depth) 9-5/8" BOT packer at 10212'; 5-1/2" SSSV LN at 1931' : 13. Attachments I~' Description Summary of Proposal 14. Estimated date for commencing operation September 11,2000 16. If proposal was verbally approved Name of approver Date Approved~ Contact Engineer Name/Number: Ted Stagg, 564-4694 [] Detailed Operations Program 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service [] BOP Sketch Prepared By Name/Number: Terrie Hubble, 564-4628 17. I certify that ~g is true and correct to the best of my knowledge Title CT Drilling Engineer Plug integrity __ BOP Test Mechanical Integrity Test __ Approved by order of the Commission Location clearance Subsequent form required 10- Approval NO..~ ~2 ~ Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate I DA~ I CHECK NO. H 172643 9e/°4/°° I I ipo172&43 VEN[X)R AL/] ~RA~ I A I 1 U D^*rE ~NVO~CE / CnEO~ ~E~ OE~R,~ G~ O,~T ~ )~0200 ~:KOBO200H 100. O0 100. O0 HAN~Zl4G ~NST: TERR :E X46~ 'F:iFI$'I"~ATIOI~3~C,;BAN K:::~F AsHlAND CLEVELAND, OHIO .... .... ::::!: :"~6-g80 .' i':" ;:'":. . ~AY "" l, ? 8C=,t, 3," "-Oh ;i, aO3,°.q5'-' OOSt, h BP EXPLORATION page 5 of 5i Operations Summa Report Legal Well Name: D-03 Common Well Name: D-03 Spud Date: 4/19/1970 Event Name: REENTER+COMPLETE Start: 9/10/2000 End: 9/16/2000 Contractor Name: NORDIC CALISTA Rig Release: 9/16/2000 Group: Rig Name: NORDIC 1 Rig Number: :Date From ~ TO' Hours ActiVity:i Code Phase ~ DeSCription of0perati°ns~ 9/16/2000 00:00 - 01:30 1.50 PERF PROD1 Guns on surface. All shots fired. 01:30 - 01:45 0.25 PERF PROD1 P/U CT nozzle to freeze protect. 01:45 - 02:15 0.50 PERF PROD1 RIH/nozzle to displace 2000 ft to methanol. Pumped 34 bbls. @3BPM/2170 psi. POH 02:15 - 03:00 0.75 PERF PROD1 OOH. Lay Down BHA.Close wab valve. 03:00 - 04:00 1.00 DEMOB PROD1 Displace coil to nitrogen. 04:00- 06:00 2.00 DEMOB PROD1 Rigging down. Clean pits. 06:00 - 08:00 2.00 DEMOB PROD1 Remove BOP stack. Install and test tree cap. RELEASE RIG FROM D-03A AT 08:00 HRS ON 09/16/2000. Total time on well was 5 days 21 hours. Printed: 9/19/2000 4:13:00 PM North Slope Alaska Alaska State Plane 4 PBU_ WOAD Pad D-O3A Surveyed: 14 September, 2000 SURVEY REPORT 2 October, 2000 Your Reft API-500292005701 Surface Coordinates: 5959091.00 N, 654092.00 E (70° 17' 42.5303" N, 148° 45' 08.0961" W) Kelly Bushing: 58.22ft above Mean Sea Level A HA~AI~UI~TON ~,OIV~ANY Survey Re f: s vy 10485 Sperry-Sun Drilling Services Survey Report for D-O3A Your Ref: APi-500292005701 Surveyed: 14 September,~2000 North Slope Alaska Measured Depth ([1) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 10400,00 28.720 353.600 8756.70 8814.92 10414.00 28.540 353.615 8768.99 8827.21 10452.78 36.830 356.685 8801.60 8859.82 10487.78 42.290 359,565 8828.58 8886,80 10510.78 46.410 358.555 8845,02 8903.24 10540.98 51.060 357.855 8864.93 8923.15 10581.98 58.100 3.305 8888,69 8946.91 10611.38 60.640 6.465 8903.67 8961.89 10647.78 65.940 14.385 8920.05 8978.27 10674.78 71.020 17.365 8929.95 8988.17 10717,58 77.430 18.065 8941.58 8999.80 10748.98 81.650 22.285 8947.28 9005.50 10779.58 85.960 20.005 8950,58 9008.80 10830.18 89,380 32.305 8952,65 9010.87 10861.18 92.810 37.405 8952.06 9010.28 10903.38 89,820 45.495 8951,09 9009.31 10936,58 89.650 52.175 8951.24 9009.46 10973.18 90.970 60.435 8951.04 9009.26 11028,58 91.320 69,575 8949,93 9008.15 11062.58 91.320 73,445 8949.15 9007.37 11093,38 91.930 62.365 8948.27 9006,49 11125.58 91.930 58,675 8947.19 9005.41 11181,78 86.920 46.015 8947.75 9005.97 11219.18 86.660 34.595 8949.86 9008.08 11270.18 94.390 40,925 8949,39 9007.61 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (~) (~) (~) (~) 3906,29 N 2171.78W 5962951,95 N 651840.59 E 3912.96 N 2172.53W 5962958.60 N 651839.71 E 3933.81N 2174,24W 5962979,41N 651837.57 E 3956,08 N 2174.93W 5963001.66 N 651836.42 E 3972.15 N 2175.20W 5963017,72 N 651835.82 E 3994.83 N 2175.92W 5963040.38 N 651834.64 E 4028.20 N 2175.51W 5963073.75 N 651834,37 E 4053,40 N 2173.35W 5963098.99 N 651836.01 E 4085.32 N 2167.42W 5963131.03 N 651841.28 E 4109.46 N 2160.54W 5963155.31N 651847.66 E 4148.68 N 2148.01W 5963194.77 N 651859.39 E 4177.64 N 2137.38W 5963223.95 N 651869.44 E 4206.01N 2126.39W 5963252.53 N 651879,83 E 4251.29 N 2104,15W 5963298.26 N 651901.14 E 4276.72 N 2086.44W 5963324,04 N 651918.32 E 4308.31N 2058.54W 5963356.20 N 651945.57 E 4330.15 N 2033,56W 5963378.55 N 651970.09 E 4350.43 N 2003.14W 5963399.45 N 652000.10 E 4373,81N 1952.99W 5963423.86 N 652049,75 E 4384.59 N 1920,76W 5963435.29 N 652081.76 E 4396.15 N 1892.28W 5963447,44 N 652110.00 E 4411.99 N 1864.27W 5963463.84 N 652137.68 E 4446.24 N 1819,88W 5963498.99 N 652181.35 E 4474.87 N 1795.76W 5963527.91N 652204.88 E 4514.93 N 1764,57W 5963568.81N 652235.24 E Dogleg Rate (°/lOOft) 1.287 21.794 16.453 18.174 15.495 20,292 12.655 24.273 21.432 15.059 18,847 15.913 25.208 19.822 20.431 20.127 22,854 16.507 11.379 36.014 11.453 24.219 30.495 19.584 Alaska State Plane 4 PBU_WOA D Pad Vertical Section (ft) Comment 2077.39 2082.55 2099.06 2117.30 2130.60 2149.18 2177.31 2199.58 2229.53 2253.49 2293.16 2323.23 2352.97 2403.04 2434.00 2475.72 2507.68 2541.32 2588.36 2615.03 2640.31 2668.91 2721.88 2758.88 2809.65 Tie-on Survey Window Point MWD Magnetic Continued... 2 October, 2000.23:40 - 2 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for D-O3A Your Ref: API-500292005701 Surveyed: 14 September, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (tt) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 11320.78 92.200 49.535 8946.47 9004.69 4550.47 N 1728.74W 11355.00 92.200 49.535 8945.16 9003.38 4572.66 N 1702.73W 5963605.07 N 652270.33 E 5963627.79 N 652295.88 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Dogleg Rate (°ll00ft) 17.529 0.000 Alaska State Plane 4 PBU_WOA D Pad Vertical Section (ft) Comment 2859.01 2891.83 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 33.230° (True). Based upon Minimum Curvature type calculations, at. a Measured Depth of 11355.00ft., The Bottom Hole Displacement is 4879.40ft., in the Direction of 339.576° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings COmment (ft) (ft) (ft) (ft) 10400.00 8814.92 3906.29 N 2171.78 W Tie-on Survey 10414.00 8827.21 3912.96 N 2172.53 W Window Point 1 ! 355.00 9003.38 4572.66 N 1702.73 W Projected Survey Continued... 2 October, 2000 - 23:40 - 3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for D-O3A Your Ref: API.500292005701 Surveyed: 14 September, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA D Pad Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 10414.00 8827.21 To Measured Depth (ft) 10414.00 11355.00 Vertical Depth (ft) 8827.21 9003.38 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro MWD Magnetic DrillQuest 1.05.05 2 October, 2000 - 23:40 - 4 - ALASi~A OIL AND GAS CONSERVATION COPl~IISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit D-03A BP Exploration (Alaska), Inc. Permit No: 200-134 Sur Loc: 1910' SNL, 1067' WEL, Sec 23, T1 IN, R13E, UM Btmhole Loc. 2602' NSL, 2802' WEL, Sec 14, T1 IN, RI3E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law. from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE C0~IISSION DATED this /rt/cT"Z day of September, 2000 l jr/Enclosures cc: Department of Fish & Gmne, Habitat Section w/o encl. ' Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK/~-- ,L AND GAS CONSERVATION COMIC-- .~ION PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [][] Re-EntryDdll [][] DeepenReddll lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 56.19' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028285 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 2O AAC 25.025) 1910' SNL, 1067' WEL, SEC. 23, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1282' NSL, 3028' WEL, SEC. 14, T11N, R13E, UM D-03A Number 2S100302630-277 At total depth 9. Approximate spud date 2602' NSL, 2802' WEL, SEC. 14, T11N, R13E, UM 09/11/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028284, 2477' MDI No Close Approach 2560 11323' MD / 8949' TVD ~16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10430' Maximum Hole Angle 90 ° Maximum surface 2244 psig, At total depth (TVD) 8800' / 3300 psig 18. Casing Program ' '- Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin,q Wei,qht Grade Couplin,q Lenqth MD TVD MD TVD (include stare data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 10000' 8403' 11323' 8949' 103 sx Class 'G' 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10802 feet Plugs (measured) Packer Squeeze from 10000' - 10230', followed by true vertical 9177 feet Abandonment Plug, TOC at 10190' (07/00) Effective depth: measured 10190 feet Junk (measured) Chemical Cutter lost in hole (03/87) true vertical 8631 feet Casing Length Size Cemented MD TVD Structural Conductor 100' 30" 250 sx Concrete 100' 100' Surface 2289' 20" 4800 sx Permafrost 2289' 2289' Intermediate 4430' 13-3/8" 2000 sx Class 'G' 4430' 4204' Production 10797' 11-3/4. x10-3/4, x9-5/8. 3830 sx ~.C~.~s~.'~ .... ~ ......... ~ ~ Liner ~ ,~ ~' ~ ~ ~ ~ ~--~ ~'~" 10797' 9173' 0,?0 0RIGINAL Perforation depth: measured 10417'- 10620' (Ten Intervals) ~ '"'..,."¥d ~i true vertical 8830' - 9010' (Ten Intervals) 120. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements "~ontact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the forego, ing is true and correct to the best of my knowledge / ~ Signed TedStagg ~'~2~ ~ Title CT Drilling Engineer Date Permit Number _._. / APl Number ApDrovalpate See cover letter ~ ---/',,~ 50- 029-20057-01Ot/ II/OO for other requirements Conditions of Approval: Samples Required [] Yes.ri.i~ No Mud Log Required [] Yes ,~ No Hydrogen Sulfide Measures J~Yes [] No Directional Survey Required I~'Yes [] No Required Working Pressure for DOPE [] 2K [] 3K 'J~K [] 5K [] 10K [] 15K [] 3.5K psi for CTU Other:'7/ S eNED orUer of .Approved By D Taylor R~rn~,,,n, Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX D-03a Sidetrack Summary of Operations: D-03 is currently shut in with the liner and tubing tail filled with cement. D-03a will kick off from a cement whipstock for a Zone 2 sidetrack. Mill window, Drill and Complete sidetrack: Planned for Sept. 11, 2000. Drilling coil will be used to mill a window from existing cement in the 9 5/8" casing then drill and complete the directional hole as per attached plan. The sidetrack will be completed with a cemented liner. Top of 2 7/8" liner to be approx. 10,000' MD (8403'ss) with top of liner cement approx. 10,230'MD (8608'ss). This will leave top of liner cement approx. 200 ft above the window. Approx. 2'1 bbls cement will be used for this liner cement job. Mud Program: · Milling to be done with 2% KCI and FIo-Pro sweeps. · Drilling to be done with 8.7 ppg FIo-Pro. Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.16#, L-80, ST-L cemented liner will be run from TD to approx. 10,000' MD. Top of liner cement will be at approx. 10,230' MD. Cement volume will be approx. 21 bbls. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray log will be run over all of the open hole section. · Real time Resistivity will be run while drilling. Hazards One small fault will be croSsed near the heal of the sidetrack but lost circulation is not expected. Res. pressure is normal. The highest H2S measured to date on D Pad is 10 ppm. Reservoir Pressure Res. press, is estimated to be 3300 psi at 8800ss. Max. surface pressure with gas (0.12 psi/fi) to surface is 2244 psi. TREE: 6" CIW WELLHEAD: McEVOY ACTUATOR: OTIS 7" 26#/It, L-80, IJ4S TBG O-03 13-3/8", 68/61#/ft, K-55, SEALLOCK 14430' I~ KOP: 2400' MAX ANGLE: 49°/5200' FOC 5-1/2", 17#/It, L-80, AB/BTRS TUBING TUBING ID: 4.892" CAPACITY: .0232 BBL/FT Cement Behind Tubing - Packer Sqz (7/07/00) Est. TOC- 10,000' TOC in Tubing @ 10,190' Tubing Above This Depth Milled Out to 4.55" ID PERFORATION SUMMARY REF LOG: SWS - BHCS - 5-31-70 . 3/8" 7/8" 10,417- 10,450' 10,454 - 10,464' 10,470- 10,512' 10,521 - 10,536' 10,550- 10,590' 10,590' - 10,620 SQZD 4/17/87 SQZD 3/17/98 ABAND 7/19/00 KB. BF. ELEV = 38.10' ~ 7"x 5 1/2" X-OVER 1 868' 1/2" SSSV LANDING NIPPLE 1 931' OTIS )(4.562" ID) GAS LIFT MANDRELS OTIS W/RA LATCH) N~ MDIBKBt TVDss 0 3099' 3038' 9 4857' 4468' 8 6781' 5811' 7 7932' 6656' 6 8518' 7114' 5 8674' 7230' 4 9081' 7620' 3 9243' 7750' 2 9571' 8041' I 9727' 8226' SL OT,S (4.562" ,D) I 10,078' I 10,188'I BOT PBR TBG SEAL ASSY 9-5/8" PACKER I 2' ( EOT ) (3.958"1D) 0~21 4 1/2", 12.6#/ft, L-80 TAILPIPE 4 1/2" "X" NIPPLE (OTIS) (3.813" ID) 41/2" "XN"NIPPLE I 10347 (OTIS) (3.725" ID) --7------' 4 1/2" TBG TAIL I 10,389' (BOT MULESHOE) (ELMD)I 10,386' PBTD ] 10,692' J 9-5/8", 47#~t, I 10,797' N-80, SEALLOCK DATE 6-8-70 9-19-82 1/30/95 REV. BY PPA 3/15/95 M B W 3/25/98 ~HONG 7/7/00 Pfaff J FISH: 8' x I 1/8" OD CHEMICAL CUTTER LOST ON 3-15-87. TOP IS BELOW 10,648' WLM. COMMENTS INIT'L COMPLETION LAST RWO Corrections to perf depths Revised Add Perf C e~rn~.e," top..I,u, ~g^ ............... PRUDHOE BAY UNIT WELL: D-03 (23-14-11-13) APl NO: 50-029-200S7 SEC 23;TN 11N;RGE13E BP Exploration (Alaska) TREE: 6" CIW WELLHEAD: McEVOY ACTUATOR: OTIS 7" 26#/ft, L-80, IJ4S TBG D-03aProposed Completion KB. ELEV = 58.22' BF. ELEV = 38.10' -- 7" x 5 1/2" X-OVER 5 1/2" SSSV LANDING NIPPLE ( OTIS )(4.562" ID) 1868' 1931' 13-3/8", 68/61 #/ft, K-55, SEALLOCK J 4430' I KOP: 2400' MAX ANGLE: 490/5200' FOC 5-1/2", 17#/ft, L-80, AB/BTRS TUBING TUBING ID: 4.892" CAPACITY: .0232 BBL/FT Top of D-03a 2 7/8" liner to be approx. 10,000 ft. Cement Behind Tubing - Packer Sqz (7/07/00) Est. TOC - 10,000' TOC in Tubing @ 10,190' Tubing Above This Depth Milled Out to 4.55" ID D-03a to kick off from cement whipstock @ approx. 10430'. Existing perfs are currently abandoned. GAS LIFT MANDRELS (OTIS W/RA LATCH) N-~ MD(BKB) TVDss 10 3099' 3038' 9 4857' 4468' 8 6781' 5811' 7 7932' 6656' 6 8518' 7114' 5 8674' 7230' 4 9081' 7620' 3 9243' 7750' 2 9571' 8041' 1 9727' 8226' SL OTIS ( 4.562" ID) I 10,078' I BOT PBR TBG SEAL ASSY 10,188'1 9-5/8" PACKER ( BOT ) (3.958"1D) 4 1/2", 12.6#/ft, L-80 TAILPIPE 4 1/2 .... X" NIPPLE (OTIS) (3.813" ID) 4 1/2 .... XN" NIPPLE (OTIS) (3.725" ID) 4 1/2" TBG TAIL (BOT MULESHOE) (ELMD) 10,212'I 10,308' I 10,347' I 10,389' I 10,386' I PERFORATION SUMMARY REF LOG: SWS - BHCS - 5-31-70 ~ 7/~" / 4 I " 141 " /4 I " /~ I INTERVAL OPEN/SQZ'D 10,417 - 10,450' 10,454 - 10,464' 10,470 - 10,512' 10,521 - 10,536' 10,550 - 10,590' 10,590' - 10,620 SQZD 4/17/87 II II II II II II SQZD 3/17/98 ABAND 7/19/00 PBTD 9-5/8", 47#/ff, N-80, SEALLOCK ! 10,692' J I 10,797' I FISH' D-03a 3.75" open hole with 2 7/8" cemented liner 8'X 1 1/8" OD CHEMICAL CUTTER LOST ON 3-15-87. TOP IS BELOW 10,648' W LM. -3,000 D-03 8,948 -2,500 -2,000 X distance from Sfc Loc - 1,500 5,000 4,500 4,000 3,500 -1,000 JWell Name D-03 J CLOSURE JDistance 4,837 ft Az 338 de~l NEW HOLE E/W (X) N/S Of) Kick Off -2,253 3,875 TD -1,831 4,477 State Plane 652,261 5,963,568 Surface Loc 654,092 5,959,091 DLS de~l/100 Tool Face Len~lth Curve I ' 6 0 K0 Curve 2 22 10 268 Curve 3 22 90 210 Curve 4 22 80 39 Curve 5 22 90 99 Curve 6 22 -90 249 895 Drawn: 8/30/2000 6:51 Plan Name: Case 102 D-03 Vertical Section 8400 8450 8500 8550 8600 8650 8700 8750 8800 8850 8900 8950 9000 9050 9100 500 Path Distance (Feet) 1,000 1,500 I I 2,000 Angle @ K.O.= 28 deg MD:10430 Tot Drld:893 ft 11323 TD Marker Depths ~)ri~l Wellbore TZ3 I 8.6681ftTVD 8,884J 8,884Jfi. TVD TSAD J 8,487Jfi. TVD JKick Otf J 8,783JftTVD 10,430Jft MD JDeprtr @KO 4,497 fi' J MD KO Pt 10,430J MD New Hole 893J I Total MD 11,323J TVD TD 8,949J Curve 1 Curve 2 Curve 3 Curve 4 Curve 5 DLS de~l/100 6 22 22 22 22 Tool Face 10 90 80 90 Len~lth 30 268 210 39 99 249 Curve 6 22 -90 895 Drawn: 8/30/2000 6:51 Plan Name: Case 102 2 3/8" CT ~ Pack-Off Lubricator-~ D-03a CT Drilling & Completion BOP 12" 36" 22.5" 71/16" _ ~ Pipe/Slip ~ ~ 2 3/8" 7 1/16" Pipe '~~ 2 3/8" SWAB OR MASTER VALVE I COMPANY i cu ss ADMINISTRATION DATE WELL NAME-~ ' ~5/~ PROGRAM: exp ~ ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and.number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... dev v/ redrll ~ wellbore seg ann. disposal para req ~ v/ serv N · N ?DATE GEOLOGY 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~~ 13sig. ~),//~.~_~---"~ ON/OFF SHORE 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~ N 28. Work will occur without operation shutdown ........... ~ N 29. Is presence of H2S gas probable ................. y (~) 30. Permit can be issued w/o hydrogen sulfide measures ..... Y~.._) '¥ 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ........... '. _: [/3 ""'Y N 33. Seabed condition survey (if off-shore) ......... ~ r~ y N 34. Contact name/phone for weekly progress reports [e~,proratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UICIAnnular COMMISSION: Commentsllnstrucfions: ]§ I§ c:\msoffiCe\wordian\diana\checklist (rev. 02117/00) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify'finding information, information of this nature is accumulated at the end of the file under APPENDIXl o. No special'effort has been made to chronologically organize this category of information. o o- ldq Sperry-Sun 2rillLng Services LiS Scan Unili:v SRevislon: 2 $ LisLib $Revislon: 4 $ Tue Apr 23 09:C. 4:~6 2002 Reel Header Service name ............. LiSTPE Date ..................... 02/04/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/04/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS w~z~ NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA D-03A 500292005701 BP Exploration (Alaska), Inc. Sperry Sun 23-APR-02 MWD RUN 1 MWD RUN 2 MWD RUN 4 JOB NUMBER: AK-MW-00181 AK-MW-00181 AK-MW-00181 LOGGING ENGINEER: S. LATZ S. LATZ S. LATZ OPERATOR WITNESS: SEVCIK/MCMUL SEVCIK/MCMUL MCMULLEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 5 AK-MW-00181 B. JAHN JUNCA/MASKEL 23 liN 13E 1910 1067 58.22 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) tST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE MW2 RUNS i - 5 ARE ~._n~.iONAL WiTH NATURAL GAMMA. PROBE ~NGP' U?i ~iNG A S~_N.~_~._~.~ DETECTOR. Gk~2v~ kAY tSGRD> OBTAINED DURING ~WD RUN 40C FROM iC674' MD, 8930' SSTV? ~.~ !0794' MD, 8952' SSTVD iS REALTIME DATA DUE TO LOST RECORDED DATA. 4. NO FOOTAGE DRILLED ON MWD RUN 300 AND IS NOT PRESENTED. 5. DEPTH SHIFTING / CORRECTION WAIVED PER THE EMAIL FROM D. SCNORR OF 10/09/01. MWD CONSIDERED PDC. THIS WELL KICKS OFF FROM D-03 AT 10414' MD, 8769' SSTVD. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1 - 5 REPRESENT WELL D-03A WITH API# 50-029-20057-01. THIS WELL REACHED A TOTAL DEPTH OF 11355' MD, 8945' SSTVD. SGRD = SMOOTHED GAMMA RAY SROP = SMOOTHED RATE OF PENETRATION $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/23 ~x~Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10380.0 11329.5 ROP 10414.0 11355.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 10380.0 10428.0 2 10429.0 10440.5 4 10441.0 10824.0 5 10824.5 11355.0 # Data Forma5 Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin EQUIVALENT UNSHIFTED DEPTH MERGED MAIN PASS. $ Max frames Der record ............. Undefined Absent value ...................... -999 Deptk Unl~s ....................... Datum Speciflca~icn Block sub-~ype...C Name Service Order Units Size Nsam ReD Code Offset Channel - DEPT F! 4 i 68 0 1 ROP MWD F?/H 4 ! 68 4 2 GR MWD APi 4 ! 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10380 11355 10867.5 1951 ROP MWD FT/H 0.78 392.68 100.004 1883 GR MWD APi 13.96 182.93 30.5116 1900 First Reading For Entire File .......... 10380 Last Reading For Entire File ........... 11355 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 First Reading 10380 10414 10380 Last Reading 11355 11355 11329.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD · Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10380.0 10402.0 ROP 10414.0 10428.0 $ LOG HEADER DATA DATE LOGGED: ll-SEP-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: 3.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10428.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE 002 BOREHCLE AND CASING DATA OPEN HOLE BiT SiZE DRILLER'S CASING DEPTH 5OREHSLE CONDITIONS MUi TYPE: MU2 DENSITY {LB/G]: MU2 ViSCOSiTY MUD PH: MU2 CHLORIDES PPM): FLUID LOSS (C3 : RESiSTiVITY (OHMM) AT TEMPERATURE (DEGF} MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 3.800 Sea Water 8.30 .0 12.0 10000 .0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 192.3 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 10380 10428 10404 97 ROP MWD010 FT/H 15.87 57.24 27.6538 29 GR MWD010 API 13.96 29.94 24.4704 45 First Reading For Entire File .......... 10380 Last Reading For Entire File ........... 10428 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/23 Maximum, Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 10380 10414 10380 Last Reading 10428 10428 10402 Physical EOF File Header SerVice name ............. STSLIB.003 Service Sub Level Name... Version Number ........... l.C.O Date of Generation ....... 02/04/23 .Ma.~:imum Pk?sical Record..6553_~ File Ty~e ................ LO Prevlsus F~ie Name ....... STSLIB.002 Co~e n~ Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMF~RY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10402.5 10415.0 ROP 10428.5 10440.5 $ LOG HEADER DATA DATE LOGGED: 12-SEP-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: 3.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10441.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 30.0 MAXIMUM ANGLE: 30.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE 002 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.800 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: FLO PRO MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S): 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) ~JD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 138.0- MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth UniTs ....................... Datum Speclflra%lcn 51ock sub-zype...C Name Servzce 3rder Units Size Nsam Rep Code Offse~ Channel DEPT FT 4 ! 68 C ROP MWDC£~ FT/H 4 _ 66 4 2 GR .MW2S2~ AP1 4 _ 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10402.5 10440.5 10421.5 77 ROP MWD020 FT/H 0.78 20.7 3.9088 25 GR MWD020 AP! 25.55 28.61 26.725 26 First Reading For Entire File .......... 10402.5 Last Reading For Entire File ........... 10440.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 First Reading 10402.5 10428.5 10402.5 Last Reading 10440.5 10440.5 10415 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 · RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10415.5 ROP 10441.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER {FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING {TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE STOP DEPTH 10794.5 10824.0 NGP $ NATURAL GAMMA PROBE 13-SEP-00 Insite 4.05.2 3.3 Memory 10824.0 36.8 86.0 TOOL NUMBER O33 BOREHOLE AND CASING DATA OPEN HOLE EiT SiZE (iN): DRILLER'S 2ASiNG DEPTH 3.80C BOREHCLE CONZ!TiONS MUD TYPE: FLC PRC MUD DENSiYY (LB/G]': 8.75 MUD ViSCOSiTY (S): .0 MUD PH: 9.0 MUD CHLORIDES iPPM): 24000 FLUID LOSS (C3): 5.2 RESiSTiViTY (OHMM) AT TEMPERATURE (DEGFi MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size NsamRep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 .0 141.? .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 10415.5 10824 10619.8 818 ROP MWD040 FT/H 0.95 255.36 76.4986 767 GR MWD040 API 16.77 146.75 33.8353 759 First Reading For Entire File .......... 10415.5 Last Reading For Entire File ........... 10824 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 First Reading 10415.5 10441 10415.5 Last Reading 10824 10824 10794.5 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/23 5:a>:im~T. Ph',-sz_-al Record.. E5535 File Type ................ LC Frevlcus File Narco ....... STSLZ~.004 Comment Recorh FiLE HEADER FILE NUMBER: 5 RAW MWD Curves and ici keader data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMEN/: .500C FILE SUM~RY VENDOR TOOL C2DE START DEPTH STOP DEPTH GR 10795.0 11329.5 ROP 10824.5 11355.0 $ LOG HEADER DATA DATE LOGGED: 14-SEP-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: 3.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11355.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (PT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.7 MAXIMUM ANGLE: 94.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE 002 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.800 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: FLO PRO MUD DENSITY (LB/G): 8.75 MUD VISCOSITY (S): .0 MUD PH: 9.0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 5.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 154.3 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0. NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specifisation Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacin~ ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service 3rder Units Size Nsam Kep Code Cffse~ Ckanne2 DEFT FT 4 ~ 65 ' ' RCF ~DCS~ FT/H 4 _ 65 4 ~ GR !,~D~53 APi 4 ' 68 ~ 3 Name Service Uni5 Min Max Mean Nsam DEPT ~ 10795 11355 11075 1121 ROP MWD05C FT/H 2.39 392.68 121.218 1062 GR MWD050 APi 17.22 182.93 28.5 1070 First Reading For Entire File .......... 10795 Last Reading For Entire File ........... 11355 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 First Las5 Reading Reading 10795 11355 10824.5 11355 10795 11329.5 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/04/23 origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/04/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File