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Home My WebLink About204-138By Grace Christianson at 4:27 pm, Oct 29, 2024 10-404 if J-25B drilling not begun in 60 days, otherwise include on P&A 10-407 after J-25B completion isolates J-25A perfs. SFD 10/30/2024 J-25A well status to remain as development-oil until J-25B drilling is complete and the liner is cemented in place to permanently isolate the existing J-25A perforations. J-25A well status will then be changed to Abandoned. J-25A well status to remain as development-oil until J-25B drilling is complete and the liner is cemented in place to permanently isolate the existing J-25A perforations. J-25A well status will then be changed to Abandoned. J-25A well status to remain as development-oil until J-25B drilling is complete and the liner is cemented in place to permanently isolate the existing J-25A perforations. J-25A well status will then be changed to Abandoned. MGR24DEC24 DSR-11/6/24 * Variance request to 20 AAC 25.112 (i) is approved for alternate plug placement with all drilling within the PBU oil pool and abandonment to be completed with fully cemented liner in upcoming sidetrack. SFD J-25A well status to remain as development-oil until J-25B drilling is complete and the liner is cemented in place to permanently isolate the existing J-25A perforations. J-25 well status will then be changed to Abandoned. SFD * BOPE test to 3500 psi. Annular to 2500 psi. MEUIRUMOF Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.26 14:24:21 -09'00'12/26/24 RBDMS JSB 123024 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: October 29, 2024 Re:J-25A Sundry Request Sundry approval is requested to set a whipstock and mill a window in the J-25A wellbore as part of the drilling and completion of the proposed J-25B CTD lateral. Proposed plan: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line will set a 4-1/2"x5-1/2" whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. See J-25B PTD request for complete pre-rig details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or 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 whipstock. A single string 3.80" window + 10' of formation will be milled. The well will kick off drilling in the Ivishak Zone 4 and lands in Ivishak Zone 1. The lateral will continue in Zone 1 to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” L-80 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 Prudhoe Pool 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 December 2024) x Reference J-25A Sundry submitted in concert with this request for full details. 1. Fullbore : MIT-IA and/or MIT-T to 2,500 psi 2. E-Line : Set 4-1/2"x5-1/2" whipstock 3. Service Coil : Mill 3.80" window (if window not possible, mill with rig). Give AOGCC 24hr notice prior to BOPE test. Test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,359 psi. 4. Valve Shop : Bleed production, flow and GL lines down to zero and blind flange. 5. Operations : Remove wellhouse and level pad. Rig Work: 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,359 psi). 2. Mill 3.80” Window (if not done pre-rig). 3. Drill build section: 4.25" OH, ~638' (18 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2,676' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2” x 3-1/4” x 2-7/8” L-80 solid liner. 6. Pump primary cement job: 47 bbls, 15.3 ppg Class G, TOC at TOL*. 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Sundry covers plugging the existing perforations via the liner cement job or liner top packer PTD 224-134 Sundry 324-618 Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : SBHPS, set LTP* (if necessary). Set live GLVs. 3. Service Coil : RPM and Post rig perforate (~200’). 4. Testing : Portable test separator flowback. The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: x A min EMW of 8.4 ppg KCL. KCl will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. x The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil’s departure. x Additionally, all BHA’s will be lubricated and there is no plan to “open hole” a BHA. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3. x Fluids >1% hydrocarbons or flammables must go to Pad 3. x Fluids >15% solids by volume must go to GNI. Hole Size: x The window and 10’ of formation will be drilled with a 3.80” OD mill. Well Control: x BOP diagram is attached. x AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. x Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. x BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. x BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. x 10 AAC 25.036 c.4.C requires that a BOPE assembly must include “a firewall to shield accumulators and primary controls”. A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: x J-Pad is not an H2S pad. The last H2S reading on J-25A: 10 ppm on 3/5/2022. x Max H2S recorded on J-Pad: 36 ppm on J-07 (8/17/2020). Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,239 psi at 8,800 TVD. (7.1 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,359 psi (from estimated reservoir pressure). x A min EMW of 8.4 ppg for this well will provide 645 psi over-balance to the reservoir. Trevor Hyatt CC: Well File Drilling Engineer Joe Lastufka 907-223-3087 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 3-1/8" Pipe / Slip 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 neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee CDR2 or CDR3 BOP and Well Tree Height Hydril 7 1/16" Annular Blind/Shear 2" or 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2" or 2-3/8" Pipe/Slips 2-3/8" or 3.0" or 3-1/8" Pipe / Slip Blind/Shear 2" or 2-3/8" Pipe/Slips 2" or 2-3/8" Pipe/Slips 1" or 1-1/4" Pipe/Slips 2-3/8" x3-1/2" VBRs 2-3/8" or 3.0" or 3-1/8" Pipe / Slip CDR2 Maximum Tree Height with 6 ram BOP: 163" Current Well Tree Height: 167.5" CDR3 Maximum Tree Height with 6 ram BOP: 172" Rig Floor Cellar Top/Ground Level Top of Tree (top swab flange) Well: J-25B 6 ram BOP height based off two triples. 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 J-25A well status to remain as development-oil until J-25B drilling is complete and the liner is cemented in place to permanently isolate the existing J-25A perforations. J-25A well status will then be changed to Abandoned. SFD SFD 10/30/2024 324-618 SFD 10/30/2024 PBU J-25A 204-138 J-25A well status to remain as development-oil until J-25B drilling is complete and the liner is cemented in place to permanently isolate the existing J-25A perforations. J-25 well status will then be changed to Abandoned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y Samantha Carlisle at 9:55 am, Jan 28, 2022 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV $&7,9,7<'$7(6800$5< :(//6,21$55,9$/'62127,),(' 6(71257+(5162/87,216&,%30,'(/(0(17$7 3(5)25$7( 86,1*+6&/2$'(':*5*(2 &+$5*(6*DV5DWHG63)GHJ3KDVHG 35(3(5)7%*35(6685(32673(5)7%*35(6685( &255(/$7('726/%0(025<3352)'$7('129 'DLO\5HSRUWRI:HOO2SHUDWLRQV 3%8-$ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS _ L-71". o %.a T 3� 3�0 JUL 17 2919 1. Operations Performed � Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operetio�.g rt�ut lOiJ ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Set CIBP 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 15. Permit to Drill Number. 204-138 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 1 6. API Number. 50-029-21741-01-00 7. Property Designation (Lease Number): ADL 028281 = 8. Weil Name and Number: P13U J -25A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 10310 feet Plugs measured 9840, 10100 feet true vertical 9048 feet Junk measured None feet Effective Depth. measured 9840 feet Packer measured 8219 feet true vertical 9060 feet Pecker true vertical 8206 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 39-119 39-119 Surface 2647 13-3/8" 39-2686 39-2686 5380/6390 2670/2820 Intermediate 8543 9-518" 37-8580 37-8528 6870 4760 Production Liner 1477 3-1/2" x 3-3/16" x 2-7/8' 8829-10306 8715-9048 13450 13890 Perforation Depth: Measured depth: 9410-10270 feet True vertical depth: 9067-9049 feet Tubing (size, grace, measured and true vertical depth) 5-1/2" 17# L-80 35-8340 35-8319 Packers and SSSV (type, measured and 5-1/2" TIW HB -BP Packer 8219 8206 true vertical depth) No SSSV Installed 12. Stimulation orcement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 392 39919 191 0 1061 Subsequent to operation: No Test Available 400 920 14. Attachments: tmyuirea ver 20 n 25 070 25 071. a 252837 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Stechauner, Bernhard Contact Name: Stechauner, Bernhard Authorized Title: FS2 Lead P Contact Email: Bernhard.Stechauner�bo.com Authorized Signature: Date: 7//6/t-9 Contact Phone: +1 907 564 4594 Farm 10-404 Revised 04/2017 /1 AgMIE/jUL 1 91019 Submit Original Only Daily Report of Well Operations PBU J -25A ACTIVITVhATF C i innMeoV 6/27/2019 CTU#8 1.75" CT. Job Scope: Depth Log / Set CIBP MIRU CTU. MU & RIH w/ HES GR/CCL BHA w/ 2.25" DJN. ***In Progress*** CTU#8 1.75" CT. Job Scope: Depth Log / Set COP Continue to RIH w/ HES logging Tools. Tag shallow at 9654'. Log from Tag depth up to 9200'. Flagged pipe at 9600'. Received good data( +12' Correction). MU & RIH w/ Baker 2.23" Venturi/Burnshoe Milling BHA. Correct depth at flag. Tag obstruction at 9670'. Venturithru with little motorwork. Venturi down to 10080'. Venturi backup hole above perfs to 9300'. Drydrift to 10000' clean. Paint Flag at 9800'. Pooh. Recover < 1/4 cup of formation debris. Rih w/ Baker CIBP. Correct depth at flag. Set top of CIBP at 9840'. Pooh. Freeze Protect Tbg w/58 bbls 50/50 Methanol. Rig down CTU. 6/28/2019 ***Job Complete*** WaLFBAD= MCLa/OY ACTUATOR= OTIS K8. ELEV = 77.14' BF. ELEV = 38-89' KOP= 8000' Max Angle = 96' @ 9513' DatunMD= 9048' DatunTVD= 8800'SS Minimum ID = 2.377" @ 8829' 3-3/16" X 2-7/8" LNR XO 5 -1/2 -TBG. 17#, L-80, .0232 bpf, D=4.892" TOPOF 5-72" LNR 9-5/8" CSG.47#. L-80. D=8.681' I J -25A L12' LN; 8.81#, L-80, .0087 bpf, D = 2.990' 888 PERFORATION SUMMARY 5-12' MECHANICAL WHPSTOO( (08/7/4) 8917 REFLOO: ????? ON XX )O( w/ 3 RA TAGS ANGLEAT TOP PF3iF:95-@9410' Note: Refer to Pladuction DB for historical pert data —8912 5-12" LNR, 17#, L-80, .0232 bpf, D=4.892' w SAFETY NOTES: GAS LFT MANDRELS ST MD PERFORATION SUMMARY I DEV I TYPE REFLOO: ????? ON XX )O( LATCHTO ANGLEAT TOP PF3iF:95-@9410' Note: Refer to Pladuction DB for historical pert data SIZE SPF INTERVAL OpNSrg DATE OTB 2' 6 9410-9510 O 08/14/04 5 2- 6 9560-9810 O 08/14/04 SO 2- 6 9860 -10D60 C 08/14/04 6628 2- 6 10160- 10270 C 08/14/04 RM w SAFETY NOTES: GAS LFT MANDRELS ST MD I ND I DEV I TYPE VLV LATCHTO 07/14/19 TFA/,JD SETBKR CBP(0628/19) DATE 6 3006 3005 5 OTB DOME RM08/08417 BP Exploration (Alaska) 11/08/13 CJS/RIC SET C13P(11/7/13) 5 5193 5191 0 OTB SO PAA08/08/07 4 6628 6825 2 0719 DMY RM 3 7520 7517 4 OTB DMY RM 2 7866 7881 8 OTB DMY RM 1 8041 8034 11 OTB DMY PAA 9-518"x 5-1/2" TIW HBBP PKR, D = 4.75" w/SBRSEALASSV 8880 B.A5TTLOGG®1227/95 I 8829 I NO GO D=2.39' IV _ 113=30(r 8861' —1312' HES X MI-LOUr WINDOW (J -25A) 8910'-8919' F—SMW--1—3-3/16" X 2-7/B' XO. D = 2.377' D=2.80' .LED WFr C13P(11/06/13) 10236'CTM P l3 1027, 18' LNR 6.16#, L-80, .0058 bpf, D = 2.441' 2-7/8" BKR C13P(11/7/13) PRUDHOE BAY UNIT WBL: .L25A PERMITNo:2041380 AR No: 50-029-21741-01 SEC9, T11N, R73F, 799' FNL 8 1881' FIi DATE REV BY COMMENTS DATE REV BY COMAAF34P5 0823187 Alld2 INTAL COM PLETION 07/14/19 TFA/,JD SETBKR CBP(0628/19) OSM4104 JDP#/T CTD SIDETRACK IJ -26A) 07/14/19 TFA/JI) WFr CBP MILL A FISH (11/061131 03/31/05 WRR/rLH GLV C/O (09/08!04) 07/14/19 DDJMD ADDED BF 8 MLLOU! WIDOW 05/17/06 RCT/PJC GLV C/O 06/08/07 CJNPAG GLV C/O BP Exploration (Alaska) 11/08/13 CJS/RIC SET C13P(11/7/13) STATE OF ALASKA RECEIVED - AL A OIL AND GAS CONSERVATION COMM )N REPORT OF SUNDRY WELL OPERATIONS DEC 10 2013 1.Operations Abandon U Repair Well Plug Perforations U Perforate U Other Li fOGC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extensions Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development 1151 Exploratory ❑ 204-138-0 . 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-21741-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028281. PBU J-25A• 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL • 11.Present Well Condition Summary: Total Depth measured 10306 feet Plugs measured 10100 feet true vertical 9048.44 feet Junk measured None feet Effective Depth measured 10100 feet Packer measured See Attachment feet true vertical 9052.4 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 37-117 37-117 0 0 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 8545 9-5/8"47#L-80 35-8580 35-8527.76 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9410-9510 feet 9560-9810 feet 9860-10060 feet 10160-10270 feet True Vertical depth 9066.68-9061.06 feet 9057.38-9059.93 feet 9058.74-9055.13 feet 9049.81 -9049.09 feet Tubing(size,grade,measured and true vertical depth) 5-1/2"17#L-80 35-8340 35-8318.98 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED Treatment descriptions including volumes used and final pressure: SCANNED "/4 j r i:'14 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 431 25541 392 0 1209 Subsequent to operation: 494 25934 196 0 1231 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ig • Gas U WDSPIU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC•❑ 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: N/A Contact Garry Catron Email Garry.CatronCa)_BP.Com Printed Name Garry Catron Title PDC PE Signature itict.44 1 Ca - Phone 564-4424 Date 12/9/2013 vt-r' /Or RB!M` DEC I "' 20 Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028281 SW Name Type MD TVD Depscription J-25A PACKER 8219 8129.32 5-1/2"TIW HB-BP Packer J-25A PACKER 8829 8638.02 5-1/2" Eclipse Packer m 00 • 0 co CD Or- N CO (0 CO N V �r O SO 000 M• � CO C3) CO MCO • COQ M 4 4 co N 0) 0) CO • O Nt I,- O O O Cr) • CO CO I"- 00 O v- CO CO • CO Co CO N V' CO 00 I- N- 0 0 Co 0 CO CO CO CO O CA CO CO N N CO co CA N- d) O) O 4 O co M Lo 4 (D r M to co CO Nr CY) CO M 0c,-)O 000 CO CD CO N E N M CO O 0 CO N ' O O M co to CO CO V' CA 00 Nr O to r O CO co 000DO CIO CO (NI NoO VCU co 2 N N co co co co CO CO M co 0 M CO C 0 Q a owl ico U J J 0)J U J M N• C CO U inUNCV � Fw °�° NMMN N• ,A M _ co co co M N N U) LC) CD LO C 000 IN O a O N M Clf LO MCAO NCO 00 0 J Z 0 WW rnD (-) WQUC� V W W Z W W W Q Q. m Q Z_ Z Z Z W J D D D UJJJJd (/) U) (/) F- O U) o N C 2 O�1 § Q-2 m -0 -0 0 -0 -O 0 0 c 1 N V +--� C C _ C O O a _ .0 U 2 _ a7 M - Q C C O C �O `- O N a C) a)U Q m O O C C L ° E (6 - O O O O = O n• o ° 4 4 D .a Ca 5R •. a • j o Jc L - ° ° a � ° °-o RI o U o a Y (a E• a) Q U 0 0 a 0 O C) = O 0) _ O C C 0)- -0 ' CC oW Y Y -ti 4- N ° `a •• ° a o CD m E o E o N o °)a) 00 ° J c� o- o°) °c) -°a 0 `n a, 2 C 0,-) CD ° 3 E o E @�'- 0 o Q o -° Q 0 000 v o o_ a) U (o C� c CL a) m = ca a a ° � � m � (n ca Qua OM a) cca aQO _� aQo � � c m m = H 3a) (nv 0 m U 0 3 0° mrna m m rn ¢ ,_ E ° U U � CO orn CIS oU � aa)) � JD _ = Uaga) Ua © 6Yn 1 0 0 a2a E o- D o a) ° 3D oU all oU 3D ; rno.j O a) c L ° o c C _zo C ct fx Q o Y C cn m ° I..L = 0 .0 2 -4- L c I LL O 1 LL 0R-: ,---.,,,2- - ° 0 0- riN cam _ co ° CL . Q U OQ amp d � VY O a � VY O2 � C RS a) a) N = IY Q O CO O p J oo a) `t C y C _:- ) 't c cM -0 CD N N O 0 w V) N O = M C -- Ti a) ° w = N a) ° - d7 a) 0- o o �' `� ° J m° o o °) rn °) a) o u°)i = E o v°)i = E L C O — C C — °ice 3 - Q O C . . Q-o C 3 C � 0 �n L C 0 U) L m '- - CO 3 3 a ' = 0 3 C 0 0 ° E Y Y a_ o co - QCQ 0co p= O4 0a C - ''-) - ° � �m — ° � �mma0 N L = O - 1 J L • a] 0 -cp L a L L U) L CO co 0 0 oa) 2a) U) � cz LoQ o.. o 0- c 0LC a) ,- o 0 a) - oU Q7 p .L —3 a) (n a) . . O _ Q C I (0 0) w -0 0) 4- 0) 7 O J - a) _ . a a) a N ° - co 0 • °)O C •0 0 o >, 0 o ca >, (U s 4, O < o � ac`r) a) Q o_ 3L0U c = =O 'O)aU. •° 0 - a O ° Na0Q o (Ni (rj N EO C3 c ° C) E a - ° N ° O (o .. N 3 ca U (n N 3 U cn C O Q _ _ co Ce M ((0 U © O (� CO ) °)N O co J - . ~ •C O M i Q n M ct I O ) 0 C V) a) fl- C I = L a) >+ II - II c 0 N 3 0) CO` " c• 3 ti a E - II c c ii c c .C) > - > - HQ 1 0 o 06) 07 > .- vm � o • > 3 0 0 > - 3 0 ° E n5 RS H C H cv 0) Q _ 1_ c� cn a) U Q- a) Cn H 4 0 0 0)* H 4. 0 -0 °) U 0 U a) ° °)_Q= N U • -a - ((i) U a) °)a in U a) rn a o w (o (� = Q C m_ (n _ H a) I- ~ rn -I oa ornI = g ' co = H N „ .Qm C 0 2 U E m 3 E o ° - U E N c = c U Eon E U 0 O Eo 6 E U - 03 U) 0 a U a) - (� N C 6) a .� O C .� O Co E M M C -= c � J � vipM C 0 O L0)) C% CM C 3 ~ U -0,.., M C 3 ~ UN °-Ca *k -, *k .- a) 0_ - *k - -c (n co U - *k - .r a) •- a) H - H 0 3O Eo ( rn ooH o .(� o a) a' CO off o0 o U? H •E' CO o u°) 01EO 0 UUCna °-. 30) U � UUcn <- 5Ua � 000M U . : UUM o .E E 3 ,- M M co co co ;7= O O O O O t N N N N N r = , r r r r I / Gd / \ o \ \ \ a t • \ k c:1 2 ® � / ƒ H co m 2 E k % / \ / / / Og 2 E 2 \ g / 2 i \ E / ac ƒ 8 2 2 $ 2 \ 6 / ° / GE> 0 / & CO G ■ \ ® \ § ƒ / \ \ ƒ \ 3 G y § § \CL \ R O 2 ' c \ = E CD o f O ° o f — O _ c -o . — 0 \ = m = 2'o I = • co -• 4z, 2 \ / ) w 7 4 \ w o -0 c ® / ° 3 + e 0 U) ' . / t 9 f \ $ I / O 5 - o Q . / E - oi . /_ . CD ® » .@ / \ / \ £ / 2 % E / m r t k A - •�� ¥ = = a = - e I- \ \ U/ \ / / 2 g ® ® e co » 0 ; R � ƒ \ - EcLH w - o a) 7 / E T.0 0 0 » _ ¥ o R \ n o \ § g E \ ° o / § 7 ° # / 7 2_TD 2 Co : � n \ _ - c D ? < Ro - F- oI - c.) 042 E o m I O 0 = : m n \ 3 CO / TREE= CAMERON WS_LHEAD= MCEVOY J -25A SAl ,VOTES: ACTUATOR= OT1S KB.ELEV= 77.14' BF.ELEV= 39.24' KOP= 8000' Max Angle= 96 @ 9513 ® 2109' I—5-1/2"CAMCO SSSV LAND.NP,D=4.562' Datum MD= 9048' Datum ND= 8800'SS 13-3/8'CSG,72#,L-80,D=12.347" —1 2686' GAS LIFT MANDRaS ST MD ND DEV TYFE VLV LATCH PORT DATE 6 3006 3005 5 OTIS DOME RM 16 06/08/07 5 5193 5191 0 OTIS SO RM 20 06/08/07 4 6628 6625 2 OTIS DMY RM 0 9-5/8"CSG,47#,L-80,NSCC X BTRS —I 4337' 3 7520 7517 4 OTIS DMY RM 0 2 7886 7881 8 OTIS DM' RM 0 1 8041 8034 11 OTIS DMY RM 0 Minimum ID =2.377" @ 8829' � I I I 8154' 1-15-1/2" __I 5-1/2"OTIS XA SLD SLV,D=4.562' I 3-3/16" X 2-7/8" LNR XO 2% 8219' I_9-5/8'x 5-1/2'T?W HBBP PKR,D=4.75' w/SBR SEAL ASSY 8292' I—5-1/2"OTIS X NP 13=4.562' 5-1/2'TBG,17#,L-80,.0232 bpf,D=4.892" —J 8336' 8336' —15-1/2"SEAL ASSY W/O SEALS I TOP OF 5-1/2"LNR H 8340' I 8336' }—ELMD TT LOGGED 12/27/95 9-5/8"CSG,47#,L-80,D=8.681' —I 8580' IJ ► 8829' I—5-12"ECLIPSE LNR TOP PKR w/BKR SEAL ASSY,NO GOD=2.39" 8841' I—I 3.70"BKR DEPLOY SLV,D= I 8861' I—3.1/2'HES X NP,D=2.813" I 3-1/2'LNR,8.81#,L-80,.0087 bpf,D=2.990" H 8893' I-- { 8893' I—3-12'X 3-3/16'XO,D=2.786" 5-12"MECHANICAL WI ISTOCK(08/7/4) —I 8912' 1\ ii w/3 RA TAGS MLLOUT WINDOW(J-25A) 5-1/2"LNR,17#,L-80,.0232 bpf,D=4.892" —I —8912 I 9406' 3-3/16'X 2-7/8'XO,D=2.377" 5-1/2"CUP(08/06/04) --I 8960' /- PERFORATION SUMMARY REF LOG: ', ?ON XX/XX/XX ANGLE AT TOP PERF:95°@ 9410' 10100' F-2-7/8"MP(11/07/13) Note:Refer to Rod uction DB for historical pert data SIZE SFF NTERVAL Opn/Sqz DATE 2" 6 9410-9510 0 08/14/04 3-3/16"LNR,6.2#,L-80 TC1, 9406' 2" 6 9560-9810 0 08/14/04 .0076 bpf,D=2.80' k* 2" 6 9860-10060 0 08/14/04 2' 6 10160-10270 C 08/14/04 PBTD —i 10272' ,. 2-7/8"LNR,6.16#,L-80,.0058 bpf,D=2.441' —I 10306' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/23/87 AUDI 2 IMTIAL COMPLETION VVELL: J-25A 08/14/04 JDM/TLH CTD SIDETRACK(J-25A) PERMIT hb: 2041380 03/31/05 VVRWILH GLV C/O(09/08/04) API No: 50-029-21741-01 05/17/06 RCT/PJC GLV C/O SEC 9,T11 N,R13E,799'FNL&1881'FEL 06/08/07 CJWPAG GLV C/O 11/08/13 CJS/PJC SET CBP(11/7/13) BP Exploration(Alaska) • • .:, ~~_ ~~ ~ . -~ __ MICROFILMED 03/01 /2008 DD NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CWrPgs_InsertslMicrofilm_Marker.doc 11/15/07 SChlgmberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Lnn nP9Crl n+lnn NO. 4498 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Pt. Mac. Milne Pt. nn4n RI Rnlnr cn MPS-37 11594513 OH LDWG EDIT ~ (a 06/26/07 6 2 1 J-25A 11767130 MCNL tx. p-p 06/18/07 1 OWDW-SW 11483588 _ RST v -~,_ ~1~ - ~j'~ ~ 11/17/06 1 1 OWDW-NW 11626127 RST (,~(0 10109/07 1 1 OWDW-SE 11225967 RST G ~ 04/19/06 1 1 M-12A 11216184 MCNL (~ - , ( ~ 04/04107 1 1 P1-09 11773114 RST ~ L nj 04/24/07 1 1 OWDW-SE 11855823 RST.V a~ pZj ~ ~ / 10128/07 1 1 r~~r+ac ra~.nivvvv~cuuc KcVCIr•' 1 6T Albrvlrvla ArvU Kt 1 UKIVII~_la.aJlVt I;VYY tAl:Fi I V: BP Exploration (Alaska) Inc. j _~ ~~ ~ x~ ~! Petrotechnical Data Center LR2-1 ,, ,~_.~,,, ' ! - 900 E. Benson Blvd. Anchorage, Alaska 99508 t Date Delivered: ~~'f~ a~.taii~9Ei47~i(1i¢i Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • .7 ScblumblPger RECEIVED NO. 4324 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth JUL 0 3 Z007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Oil & Gas Coos. CommIssion Anchorage Field: Prudhoe Bay C CD Well Job# Loa Description Date BL olor H-13 11676950 GAS ENTRY SURVEY 06/20/07 1 C-41 11801077 LDL 06/19/07 1 A-30A 11661159 MEM PROD PROFILE 06/23/07 1 W-21A 11661140 MEM PROD PROFILE 04/21/07 1 E-21B 11661157 MEM PROD PROFILE 06/19/07 1 M-23 11626107 PRODUCTION PROFILE 06/23/07 1 01-21 11824330 PRODUCTION PROFILE 06/22/07 1 J-25A 11767130 MEM PROD PROFILE 06/18/07 1 Z-08A 11630483 GLS/PROD LOG 06/22/07 1 M-34 11824330 PRODUCTION PROFILE 06/22/07 1 02-30B 11594512 LDL 06/23/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 S-38 11801078 LDL 06/20/07 1 H-37A 11594506 PPROFIIPROF (REVISED) 06/05/07 1 N-15 11637129 PROD PROFILE (REVISED) 06/13107 1 Z-13A 11649962 MEM PROD PROF (REVISED) 04/21/07 1 P2-15A 11594511 SCMT 06/15/07 1 12-05 11676951 USIT (CEMENT) 06/24107 1 12-05 11676951 USIT (CORROSION) 06/24/07 1 B-15 11626097 US IT 06/14/07 1 G-24A 11628750 SCMT 02105/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SCANNED JUL 05 2007 Date Delivered: [)ó« - I~~ Received by: 06/29/07 . . J>~ DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Permit to Drill 2041380 Well Name/No. PRUDHOE BAY UNIT J-25A Operator BP EXPLORATION (ALASKA) INC ..Çw;L q~~'1 A~ No. 50-029-21741-01-00 MD 10306.-/ TVD 9048........-' Completion Date 8/15/2004 Completion Status 1-01l Current Status 1-01l UIC N - - - ------~~--~~.- REQUIRED INFORMATION Directional ~ ---~~ Mud log No Samples No --~._~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset !~Med/Frmt Number fF!D 0 Asc I Rpt SGRC Combined GR & EWR, MGR / eel / CNl (data taken from logs Portion of Master Well Data Maint . rEfJ 0 ~ l.CJ Rpt fD C ..;Ff' ..' S ~g .:¡:f-- l.d C lis I L~~._~~ Name Directional Survey Directional Survey Induction/Resistivity LIS Verification Log Log Scale Media Run No Interval Start Stop 8908 10306 8908 10306 8706 10258 8706 10258 8267 10195 OH/ CH -~-~ Received Comments -- 9/14/2004 IIFR 9/14/2004 IIFR 1 0/29/2004 1 0/29/2004 11/29/2004 12791 12791 12866 Gamma Ray 12866 Gamma Ray Blu 8267 10195 11/29/2004 MCNL/MEMORY DCCL/CNl MCNL/MEMORY DCCL/CNl ROP DGR EWR plus Graphics 13506 Induction/Resistivity 8932 10310 Open 2/22/2006 -~-_.~ ~~- Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments . ADDITIONAL INFORMATION Well Cored? YW Daily History Received? Ç1r ~ Chips Received? Y / ''I Formation Tops Analysis Received? ~ --- ---- --~ Comments: Permitto Drill 2041380 MD 10306 TVD 9048 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Well Name/No. PRUDHOE BAY UNIT J-25A Operator BP EXPLORATION (ALASKA) INC ~;'" D'te 811512004 Completion Status 1-01L Current Status Date: API No. 50-029-21741-01-00 1-0IL)~ ~~ ~ . . J-)'iA (PID #2041380) Classified as Problem Well ~ . All, Well J-25A (PTD #2041380) has been found to have sustained casing pressure on the IA. The TIO's on 05/11/06 were 2040/2040/0 when the well failed a TIFL on pressure build-up. LÇ , c@f>\ % M.J~-P ZL1 .1°Ce The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. WIE: Eval for GLV c/o 3. SL: GL V c/o 4. DHD: Re-TIFL 5Ã- 5C!...-f 2.€'.L¡o ~ / UT. j -D. r~""l-I ff€-'.35l~~ Ò K per . . Cð tV1 'Z- A well bore schematic has been included for reference. «J-25A.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, }lnna (j)u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: J-25A.pdf Content-Type: application/octet-stream Content-Encoding: base64 I of I gD£{ -13 Õ 5/19/2006 3: 15 PM ,J '.. TREE =: CAMERON WELLHEAD =: MCEVOY _.~~ n~n~~.<~.~^ ACTUA TOR =: OTIS .n.,... on._.~"_ __.~n_""'_"'~ KB. ELEV =: 77.14' SF. ELEV = 39.24' KO~p~;~n «.........".. ß'"..~..^nh 80001 _M > , ~ Max Angle =: 96 @ 9513' ··DatumMD;;-~-··········9048' DatûmWD == '-H8800;"äs~ . J-25A ~OTES: . 2109' H 5-1/2" CAMCO SSSV LAND. NIP, ID =: 4.562" I 113-3/8" CSG, 72#, L-80, 10 =: 12.347" H 2686' ~ - L 19-5/8" CSG, 47#, L-80, NSCC X BTRS H 4337' , I Minimum ID = 2,39" @ 8829' 5-1/2" SEAL ASSY NO GO ~ GAS LIFT MANOR8..S ST MO TVD DEV TYÆ VLV LATCH 6 3006 2928 5 OTIS DOME RM 5 5193 5114 0 OTIS SO RM 4 6628 6548 2 OTIS DMY RM 3 7520 7440 4 OTIS OMY RM 2 7886 7804 8 OTIS OMY RM 1 8041 7957 11 OTIS OMY RM ffiRT DA TE 16 09/08/04 20 09/08/04 o o o o / I I 8154' H 5-1/2" OTIS XA SLIDING SLEEVE, ID =: 4.562" gj Ìg 8219' 8219' H SBR SEAL ASSY I H9-5/8" x 5-112" TfIN HBBP PKR, ID =: 4.75" I 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" H 8336' ~ '- ITOPOF 5-1/2" LNR H 8340' 19-5/8" CSG, 47#, L-80, ID =: 8.681" H 8580' 1- ~ 8292' H 5-1/2" OTIS X NIP, ID =: 4.562" I 8336' H5-1/2" SEAL ASSY W/O SEALS I 8336' H ELMO IT LOGGED 12/27/95 I 13-1/2" LNR, 8.81#, L-80, .0087 bpf, ID =: 2.990" H ÆRFORA TION SUMMARY REF LOG: ????? ON XXIXXlXX ANGLE AT TOP ÆRF: 95° @ 9410' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9410 - 9510 0 08/14/04 2" 6 9560 - 9810 0 08/14/04 2" 6 9860 - 10060 0 08/14/04 2" 6 10160 - 10270 0 08/14/04 I 5-1íZ" LNR, 17#. L-80, 10 =: 4.892" H 9532' 5-1/2" SLTDLNR, 17#, L-80, 10 = 4.89Z" Ii 11659' OA TE REV BY COMMENTS 08/23/87 ORIGINAL COMPLETION 08/14/04 JDMITLH CTD SIDETRACK (J-25A) 03/31/05 WRRfTLH GLV C/O (09/08/04) 8893' f_~ ~I : 8841' 8861' 8893' 8829' 1-15-1/Z" ECLIPSE LNR TOP PKR I w IBKR SEAL ASSY, NO GO 10 = 2.39" H 3.50" BKR OER..OY SL V, 10 =: 3.00" I H 3-1/Z" HES X NIP, 10 = 2.813" I H 3-1/2" X 3-3/16" XO, 10 = 2.786" I 8912' I-MECHANICAL WHIPSTOCK w/3 RA TAGS (08/07/04) 8960' - CIBP (08/06/04) I H 3-3/16" X 2-7/8" XO, 10 =: 2.440" I ~ ~I I .J ;g¡ . 13-3/16" LNR, 6.2#, L-80, .0076 bpf, 10 =: 2.80" l-i I PBTD H 10272' 12-7/8" LNR, 6.16#, L-80. .0058 bpf, 10 = 2.441" H 10306' DA TE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: J-25A ÆRMIT No: 2041380 API No: 50-029-21741-01 SEC9, T11N. R13E BP Exploration (Alaska) . . WELL LOG TRANSMITTAL J-D4 - I 32) To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17,2006 /o~ RE: MWD Formation Evaluation Logs J-25A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 J-25A: LAS Data & Digital Log Images: 50-029-21741-01 1 CD Rom ~ ð-19-fr/OIo Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . ?d{..r:$O W-05A 'ftr~L3-02 Jot'J..2.1fi OWDW-SW OWDW-SW 2/)'f..(),!;? P1-07 A ~ rn J-25A 20'1"/0" C-25B 1...E>t(..()( I S-14A 7Øf.Of 0 E-39A ;20'1. ('l. 'ð 07 -32B t!jlf.Cltr Q-05A Fto-ø( DS 09-41 Well . Job # 10715426 10708048 10563038 10672360 10621778 10715419 10715434 10884020 10728394 10861926 10715356 10563111 CH EDIT (PDC-GR) RST-SIGMA RST -SIGMA RST -BORAX US IT (PDC) MCNL MCNL MCNL MCNL MCNL MCNL RST-SIGMA Log Description Date 09/02/04 02/05/04 03/30/03 03/27/04 04/20/04 08/13/04 10/11/04 09/18/04 03/28/04 08/03/04 10/26/03 10/12/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: (t}<ifl- Blueline 11/23/04 NO. 3277 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 AnChorage'.AK 9950}-£838.. ~ ATT~ -Ü"t<-) R~bY Û · . . ~/) rJ./;3ff WELL LOG TRANSMI'ITAL To: State of Alaska Alaska Oil and Gas Conservation Comrr_. Attn.: Helen Wannan 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Fonnation Evaluation Logs: J-25A, 1 LDWG fonnatted Disc with verification listing. API#: 50-029-21741-01 October 28, 2004 AK-MW-3220865 1/)vlQI I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date/r;J1 BP Exploration (Alaska) Inc. Petro- Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 tI~ · STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: a Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 800' SNL, 1881' WEL, SEC. 09, T11N, R13E, UM Top of Productive Horizon: 578' SNL, 1190' WEL, SEC. 09, T11 N, R13E, UM Total Depth: 134' NSL, 812' WEL, SEC. 04, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 642472 y- 5970533 Zone- ASP4 TPI: x- 643158 y- 5970769 Zone- ASP4 Total Depth: x- 643520 y- 5971488 Zone- ASP4 18. Directional Survey a Yes 0 No 21. Logs Run: SGRC Combined GR & EWR, One Other 5. Date Comp., Susp., or Aband. 8/15/2004 6. Date Spudded 8/912004 7. Date T.D. Reached 8/12/2004 8. KB Elevation (ft): 77.1' 9. Plug Back Depth (MD+ TVD) 10272 + 9049 10. Total Depth (MD+TVD) 10306 + 9048 11. Depth where SSSV set (Nipple) 2109' MD 19. Water depth, if offshore N/A MSL CASING SIZE 20" 13-3/8" 9-518" 5-1/2" MGR I CCL I CNL CASING, LINER AND CEMENTING RECORD $:friNG·Deffl"HMD SETI'1NGÐEPTH'IVCI .BOTTOM Top 8ØtroM 110' Surface 110' 2684' Surface 2684' 8580' Surface 8528' 8912' 8319' 8768' 10306' 8723' 9048' 22. Conductor 72# 47# 17# 8.81# /6.2# /6.16# L-80 I S-95 NSCC I L-80 L-80 L-80 Surface Surface Surface 8340' 8841' 3-1/2" x 3-3/16" x 2-7/8" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 6 spf MD TVD MD TVD 9410' - 9510' 9067' - 9061' 9560' - 9810' 9057' - 9060' 9860' - 10060' 9059' - 9055' 10160' - 10270' 9050' - 9049' 26. Date First Production: September 15, 2004 Date of Test Hours Tested 9/18/2004 4 Flow Tubing Casing Pressure Press. 276 1,530 27. PRODUCTION FOR TEST PERIOD ... CALCULATED ...... 24-HoUR RATE""'" None f3nl'\¡"'¡kl:.t~ ~D01'\fQ" ~t. .~ 'JJ g¡) ~i!i. SfP ~. e, 1I'!!tr"l' Form 10-407 Revised 12/2003 Revised: 09/21104, Put on Production 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-138 13. API Number 50- 029-21741-01-00 14. Well Name and Number: PBU J-25A 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028281 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED 8 cu yds Concrete 17-1/2" 3250 cu ft PF 'E', 465 cu ft PF 12-1/4" 1750 cu ft Class 'G' 8-112" 465 cu ft Class 'G' 4-1/8" x 3-3/4" 90 CU ft Class 'G' 24. SIZE 5-1/2", 17#, L-80 DEPTH SET (MD) 8336 PACKER SET (MD) 8219' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with MeOH W~9? WATER-BeL 2,388 ORIG'l~AL CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-OIL RATIO 95° 4,888 OIL GRAVITY-API (CORR) 37.6 Alaska Oìl & Gas ComL Commission Anchorage (gf PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing t1,¡dJ OIL-¢oi P' GA;9fá- OIL-BeL GAs-McF 2,446 11,956 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". R E C E IVE 0 SEP 2 1 2004 28. . e GEOLOGIC MARKERS 29. e FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 25N 9037' 8867' None 24N 9083' 8910' 8964' 22N 9142' 21N 9158' 8977' Zone 1 B 9254' 9034' RECEIVED SEP 2 1 2004 Ataska Oil & Gas Cons. Commission Anchorage 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~~ ~_ Title Technical Assistant Date 09· ~{-oc¡ PBU J-25A 204-138 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mary Endacott, 564-4388 Permit No. I 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ALASKAeL AND ~Ä~T~g~S~L::~ON COMrlSION RECEIVED WELL COMPLETION OR REcOMPLETION REPORT AND LOG SEP 1 52004 Alaska Oil & Gas COjjS. Commission 1b. Well Class: Anchorage 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 2Q4.138 13. API Number 50- 029-21741-01-00 14. Well Name and Number: 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20MC 25.105 20MC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 800' SNL, 1881' WEL, SEC. 09, T11N, R13E, UM Top of Productive Horizon: 578' SNL, 1190' WEL, SEC. 09, T11 N, R13E, UM Total Depth: 134' NSL, 812' WEL, SEC. 04, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 642472 y- 5970533 Zone- ASP4 TPI: x- 643158 y- 5970769 Zone- ASP4 Total Depth: x- 643520 y- 5971488 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: SGRC Combined GR & EWR, One Other 5. Date Comp., Susp., or Aband. 8/15/2004 6. Date Spudded 8/9/2004 7. Date T.D. Reached 8/12/2004 8. KB Elevation (ft): 77.1' 9. Plug Back Depth (MD+ TVD) 10272 + 9049 10. Total Depth (MD+TVD) 10306 + 9048 11. Depth where SSSV set (Nipple) 2109' MD 19. Water depth, if offshore NIA MSL CASING SIZE 20" 13-3/8" 9-518" 5-1/2" MGR / CCL / CNL CASING, LINER AND CEMENTING RECORD $!:'rTII\!GDEPTHMD Setrll\!$DËP'l'HTVD HOLË BOTTOM lOP BOTTOM SIZE 110' Surface 110' 2684' Surface 2684' 8580' Surface 8528' 8912' 8319' 8768' 10306' 8723' 9048' 22. FT. Conductor 72# 47# 17# 8.81# 16.2# 16.16# L-80 I S-95 NSCC I L-80 L-80 L-80 Surface Surface Surface 8340' 8841' 3-112" x 3-3116" x 2-718" 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 2" Gun Diameter, 6 spf MD TVD MD TVD 9410'-9510' 9067'-9061' 9560' - 9810' 9057' - 9060' 9860' - 10060' 9059' - 9055' 10160' - 10270' 9050' - 9049' 26. Date First Production: Not on Production Yet Date of Test Hours Tested PRODUCTION FOR TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Press. 24-HoUR RATE PBU J-25A 15. Field I Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028281 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED 8 cu yds Concrete 17-1/2" 3250 cu ft PF 'E', 465 cu ft PF 12-1/4" 1750 cu ft Class 'G' 8-1/2" 465 cu ft Class 'G' 4-118" x 3-314" 90 cu ft Class 'G' 24. SIZE 5-1/2", 17#, L-80 DEPTH INTERVAL (MD) 2200' DEPTH SET (MD) 8336 PACKER SET (MD) 8219' AMOUNT & KIND OF MATERIAL USED Freeze Protect with MeOH PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A OIL-BsL GAs-McF WATER-BsL OIL-BsL GAs-McF WATER-BsL CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ~~7Q<;r{ ,~_ t Form 10-407'"Rëvišêã'1'2~003 ORIGI~d^L i . i¡\Jì~ CONTINUED ON REVERSE SIDE ~~';ûS StP1~ , ()J G 28. e GEOLOGIC MARKERS 29. e FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 25N 9037' 8867' None 24N 9083' 8910' 22N 9142' 8964' 21N 9158' 8977' Zone 1 B 9254' 9034' RECE".lJ:: SEP 1 5 200<í Alaska Oìl & G . as Cans Anchorage' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble /'fÔ.!tJ\i..t. ~ Title Technical Assistant Date 09 -I S ~ <-r PBU J-25A 204-138 . Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mary Endacott, 564-4388 Permit No. I 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 OR\G\NAl Submit Original Only e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-25 J-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/4/2004 Rig Release: 8/15/2004 Rig Number: N1 Spud Date: 7/24/1987 End: 8/15/2004 8/4/2004 19:00 - 23:00 4.00 MOB P PRE Rig Released from 07-32B @ 19:008/4/2004. PJSM. Back rig off OS 7-32. Clean location and hold post well pad inspection w/ pad operator. Hold pre rig move meeting wI security and tool service. 23:00 - 00:00 1.00 MOB P PRE Move rig from OS 7 to J Pad. 8/5/2004 00:00 - 05:15 5.25 MOB P PRE Continue moving rig from OS 7 to J pad. 05: 15 - 06:30 1.25 RIGU P PRE Arrive J-pad & spot rig adjacent to J-25. Lay rig mats in front of J-25 due to tree height. 06:30 - 09:00 2.50 RIGU N WAIT PRE W. O. rig trucks/loads to be delivered to J-25. Nabors 2ES move to DS#07 is delaying trucks. Meanwhile remove J-25A tree cap & prep tree. Install cellar berm. Dismantle injector control line & remove gooseneck/packoff. 09:00 - 09:15 0.25 RIGU P PRE PJSM with Peak crew on CT reel & injector swap. 09:15 -11:30 2.25 RIGU P PRE P/U & lower reel to Peak double drop trailer. Replace reel drive plates. Shim up reel stand. P/U replacement reel into reel house & align drive pins & bushing. Meanwhile setback injector on catwalk for swapping out. R/U & UD windwalls. 11 :30 - 16:00 4.50 RIGU P PRE P/U & lower injector to Peak double drop trailer. P/U replacement injector & set on catwalk. Move injector to rig floor. Raise back windwalls. 16:00 - 16:15 0.25 MOB P PRE PJSM. Review procedure, hazards & mitigation for backing rig over well. 16:15 - 17:00 0.75 MOB P PRE Back rig over well & set down. 17:00 - 19:30 2.50 BOPSUF P PRE N/U BOPE. Spot trailers & tanks. 19:30 - 00:00 4.50 RIGU P PRE RU injector. MU injector cage. Connect hydraulics. Rebuild stripper. 8/6/2004 00:00 - 04:00 4.00 RIGU P PRE Continue to RU injector. Install goose neck. Install goose neck support braces. While working on injector, fill pits wI 290 bbls of 1% KCI. 04:00 . 06:30 2.50 RIGU P PRE Install internal CTC. Prepare new reel to pull CT across pipe shed roof. Pull pipe across. 06:30 - 07:00 0.50 BOPSUF P PRE ACCEPT RIG @ 04:30 HRS ON 08/06/2004 (Time adjusted for N/U BOPE, R/U injector & stabbing CT). R/U to test BOPE. 07:00 - 12:00 5.00 BOPSUF P PRE PJSM. Perform initial BOPE pressure & function test. AOGCC test witness waived by John Crisp. Meanwhile R/U hardline to inner reel valve. Test H2S & LEL alarms. 12:00·12:15 0.25 ZONISO P WEXIT Held pre-operations safety meeting. Review well plan, prep work objectives, potential hazards & mitigation procedures. 12:15 - 12:30 0.25 ZONISO P WEXIT Open up well & observe Opsi WHP (well on vac). lAP = Opsi, OAP = 77psi. 12:30 - 13:30 1.00 ZONISO P WEXIT Install SLB CTC. Pull test to 40k - OK. Install dart catcher. 13:30 - 16:00 2.50 ZONISO P WEXIT Pump 5bbls 1 % KCL water. Shut inner reel valve & P/test hardline in reel house to 500/4200psi - OK. Fill CT. Got back lots of rust. P/test inner reel valve & MHA to 3500psi - OK. Load wiper dart. Launch & chase with 1% KCL. Dart hit @ 54.7bbls. UD dart catcher. 16:00 - 16:30 0.50 ZONISO P WEXIT M/U nozzle & MHA (OAL - 5.5'). Stab injector on well. 16:30 - 17:00 0.50 ZONISO P WEXIT RIH to 3000' to displace out MeOH FP. No returns - well on vac. 17:00 - 17:45 0.75 ZONISO P WEXIT POOH pumping 1 % KCL. Pumped a total of 160bbls 1 % KCL with no returns. Call for more KCL water. 17:45 - 18:00 0.25 ZONISO P WEXIT OOH. SIB injector & UD nozzle & MHA. 18:00 - 19:00 1.00 ZONISO P WEXIT Held PJSM with SLB Eline & BTT crew on Eline prep work. Printed: 8/16/2004 9:46:23 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-25 J-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/4/2004 Rig Release: 8/15/2004 Rig Number: N1 Spud Date: 7/24/1987 End: 8/15/2004 8/6/2004 19:00 - 20:45 20:45 - 22:45 22:45 - 00:00 8/7/2004 00:00 - 02:25 02:25 - 03:10 03:10 - 05:15 05:15 - 06:30 06:30 - 06:45 06:45 - 08:00 08:00 - 09:15 09:15 -11:00 11:00-11:15 11:15-12:15 12:15 - 14:30 14:30 - 15:15 15:15 - 15:45 15:45 - 17:15 17:15 - 17:30 17:30 - 17:45 17:45 - 19:30 19:30 - 20:30 20:30 - 21 :45 21:45 - 22:20 22:20 - 22:50 22:50 - 22:10 22:10 - 23:50 1.75 ZONISO P 2.00 ZONISO P 1.25 ZONISO P 2.42 ZONISO P 0.75 ZONISO P 2.08 ZONISO P 1.25 WHIP P 0.25 WHIP P 1.25 WHIP P 1.25 WHIP P 1.75 WHIP P 0.25 WHIP P 1.00 WHIP P 2.25 WHIP P 0.75 WHIP P 0.50 STWHIP P 1.50 STWHIP P 0.25 ZONISO P 0.25 ZONISO P 1.75 ZONISO P 1.00 ZONISO P 1.25 ZONISO P 0.58 ZONISO P 0.50 STWHIP P 23.33 STWHIP P 1.67 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT R/U SLB E-line sheaves, lubricator, greasehead & pump-in sub. Pull back lubricator and cap well. Bull head 360 bbls of 1% KCI at 5 bpm, 100 psi. MU baker bridge plug to wireline. MU lubricator. PT to 3,000 psi. RIH w/ wireline. RIH w/ baker CIBP. Log tie in pass. Set CIPB at 8,960'. Fill hole, took 49 bbls. POOH and fill pits wI 1% KCI. LD CIBP running tool. MU perf gun. Bring perf gun to rig floor. Stab on lubricator. RIH. Tie in log. Perforate from 8,910' - 8,920' w/2 1/2" 35B PU RDX gun. POOH. LD gun. RlU whipstock setting tools. Insert 3 RA pip tags into whipstock. RA PIP tag to TOWS = 10'. Calibrate POS tool & orient whipstock for LS setting. PJSM for P/U & RIH whipstock & setting tool on E-Line. M/U SLB E-line swivel, POS tool, CCL & Baker setting tool, wt bar & Gen II whipstock. CCL to TOWS = 26.5'. WS length = 17.53'. M/U lubricator. RIH with HD-swivel, POS tool, wt bar, setting tool, & Baker Gen II whipstock (OAL - 58'). RIH to @ 8915' ELM. P/U wt @ 8900' = 3.5k. Log up hole to 8680' ELM. Tie-into CET Log of 9/4/1987. Added 10' to ELMO. RBIH to 8915' ELM. Log back up to CCL depth of 8883.5' (TOWS @ 8910' ELM). Check tray orientation - 145L. Yo-yo whipstock up & down from 8915' to 8400' several times & finally managed to achieve a tray orientation of 166.5L. Set W/S with good wt loss indication & tray orientation of 13.5degs LOHS. S/O - W/S taking wt. Log off & confirm W/S setting depth of 8909.4' ELM. POOH Eline & W/S setting tools. PJSM for UD & R/D Eline setting tools, lubricator & sheaves. UO SWS Eline tools & RID SWS. M/U slick cementing BHA with nozzle, PH6 stinger X/over to CTC. M/U injector. RIH with cementing BHA#2 & lightly tag WS pinch pt @ 8913'. PIU to up wt & correct CTD to the ELMO of 891 Oft. P/U 10' to 8900' & flag pipe. Meanwhile RlU SLB Cementers & prime up. PJSM with all personnel concerning cementing operations. Perform injectivity test - Obpm @ 1000psi. Flush/PT lines to 4k. Mix & pump 12bbls 15.8ppg class 'G' cmt slurry & 2bbls of water behind @ 2.1/2.1 bpm & 1450psi. Chase with KCL water @ 2.5/2.5bpm & 1000psi. Pump 2 bbls out nozzle. Lay in remaining cement 1 :1. Pull up hole to 8,000'. Shut in choke and presure up to 1,000 psi. Squeeze 0.5bbls away. Hold 1000psi. Open choke & circulate down bio-KCL to nozzle. RBIH contaminating cement to 8900'. POOH displacing well bore to 2% KCI wI 2 ppb biozan. Dump contaminated cement returns. LD stinger. Jet BOP stack. Cut off OS CTC. MU Baker CTC. Pull test to 35,000 Ibs, PT to 3,500 psi. PJSM for MU window milling BHA. MU 3.8" diamond mill, 3.8" diamond string reamer, BOT Printed: 8/16/2004 9:46:23 AM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-25 J-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 8/4/2004 8/15/2004 N1 Spud Date: 7/24/1987 End: 8/15/2004 8/7/2004 22: 10 - 23:50 1.67 STWHIP P WEXIT Extreme motor, circ sub, disconnect, 2 jts 32 3/8" PH6, check valve, CTC. 23:50 - 00:00 0.17 STWHIP P WEXIT RIH. 8/8/2004 00:00 - 01 :30 1.50 STWHIP P WEXIT RIH. Tag wlo pump at 8,906'. PU=31 ,500 Ibs, SO=20,300 Ibs. Pit vol.=320. IA=O, OA=88 psi. 01 :30 - 01 :50 0.33 STWHIP P WEXIT Bring up pump to 2.6 bpm, 1,650 psi. SO=17,500 Ibs wI pump. Mill cement from 8,906.9' to 8,909.9' w/ 200 psi motor work at 60 fph. Stall at 8,909.9' , pinch point. 01 :50 - 06:30 4.67 STWHIP P WEXIT PU and ease back down. Start seeing motor work at 8,909.2'. Paint flag. Start milling. Mill to 8,911.5'. Stacking wt. P/U clean & ease back into milling from 8910'. Up wt = 32k. Own wt = 25k. Freespin @ 2.6bpm = 1205psi. lAP = 10psi & OAP = 145psi. 06:30 - 09:20 2.83 STWHIP P WEXIT Mill window from 8910' to 8914' with 2.6/2.6 bpm, 1205/1615psi, 6-7k WOB. 09:20 - 10:15 0.92 STWHIP P WEXIT Mill window to 8915' with 2.6/2.6 bpm, 1205/1410psi, 3-4k WOB. 10:15 -11:45 1.50 STWHIP P WEXIT Mill window to 8917' with 2.6/2.6 bpm, 1205/14000psi, 3-4k WOB. 11 :45 - 12:30 0.75 STWHIP P WEXIT Mill window to 8918' with 2.6/2.6 bpm, 1205/14000psi, 3-5k WOB. 12:30 - 13:15 0.75 STWHIP P WEXIT Mill window to 8919' with 2.6/2.6 bpm, 1205/14000psi, 3-5k WOB. Looks like we're out @ 8919". 13:15 - 14:30 1.25 STWHIP P WEXIT Mill formation to 8930' with 2.6/2.6bpm, 12050/1650psi, 1 Of ph ave ROP & 3-5k WOB. Geo seeing formation in BU samples. 14:30 - 15:30 1.00 STWHIP P WEXIT Swap well bore to 8.6 ppg reconditioned flopro mud. Meanwhile backream & dress windowlrat hole 3x & drift 2x. Window looks clean. Tentative window depths are: TOWS/TOW = 8910', BOW = 8919', RA PIP Tag = 8920'. BOWS = 8927'. 15:30 - 17:00 1.50 STWHIP P WEXIT Paint EOP flag @ 8700' & POOH window milling BHA#3. 17:00 - 17:30 0.50 STWHIP P WEXIT PJSM. UD BHA#3 & inspect mills. DWM & DSR gauge 3.80" go / 3.79" no-go. Wear on window mill face indicates center crossed the 1m wall. 17:30 - 17:45 0.25 DRILL P PROD1 Held PJSM for reheading CT & M/U drilling BHA. 17:45 -18:15 0.50 DRILL PROD1 Rehead & M/U OS CTC. Pull & pressure test. 18:15 - 19:00 0.75 DRILL P PROD1 Held pre-spud safety meeting. Reviewed well plan, potential hazards & drilling BHA M/U procedures. 19:00 - 20:30 1.50 DRILL P PROD1 M/U build section BHA #4 with a rebuilt Hughes RWD2ST 3-3/4" x 4-1/8" bicenter bit, 2.83deg bend motor, MWD/GR/RES, orienter & MHA. M/U injector. 20:30 - 23:35 3.08 DRILL P PROD1 RIH. Test orienter and MWD at 3,000'. RIH. Tie in to formation, +2'. RIH through window wI 0 problem. Tag at 8,931.5'. 23:35 - 00:00 0.42 DRILL P PROD1 Orient. Only getting 10 deg. clicks. 8/9/2004 00:00 - 00:20 0.33 DRILL P PROD1 Orient to LS. Getting 10 degree clicks. 00:20 - 01 :30 1.17 DRILL P PROD1 Drill at 2.6/2.6 bpm 3,100/3,400 psi. 01 :30 - 01 :50 0.33 DRILL P PROD1 Orient 2 clicks. Pull up to window to get clicks. 01 :50 - 02:05 0.25 DRILL P PROD1 Drill to 9,020' 02:05 - 02:40 0.58 DRILL P PROD1 Pull to just below window. Orient to 85R still w/ 10 degree clicks. 02:40 - 03:30 0.83 DRILL P PROD1 Drill to 9,061'. TF rolling right. 03:30 - 04:00 0.50 DRILL P PROD1 Pull to just below window. Orient to 85R still wI 10 degree clicks. Printed: 8/16/2004 9:46:23 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-25 J-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 8/4/2004 8/15/2004 N1 Spud Date: 7/24/1987 End: 8/15/2004 8/9/2004 04:00 - 04:12 0.20 DRILL P PROD1 Drill to 9,067'. TF rolled to 137R. 04:12 - 05:18 1.10 DRILL P PROD1 Pull to just below window. Orient to 85R still w/ 10 degree clicks. 05:18 - 05:50 0.53 DRILL P PROD1 Drill to 9,090' at 2.6/2.6 bpm, 3,100/3,550 psi, 90 fph ROP. 05:50 - 06:30 0.67 DRILL P PROD1 Orient TF around to 80L. P/U wt = 32k, S/O wt = 22k. PVT = 318bbls. lAP = 20psi & OAP = 312psi. 06:30 - 07:45 1.25 DRILL P PROD1 Drill to 9102' with 90L TF, 2.6/2.6bpm, 3200/3400psi, 2k WOB & 1 Of ph ave ROP. Stalling & not making any progress. Geo is seeing 40-50% chert & 2% pyrite in samples. Bit might be chewed up. Decide to pull for bit. 07:45 - 09:30 1.75 DRILL P PROD1 POOH drilling BHA#4. 09:30 - 10:00 0.50 DRILL P PROD1 OOH. PJSM. SIB injector. UD BHA #4. Found AKO sleeve on motor to be a bit loose (could have led to a resultant bend of ca. 2.5degs). Bit grades - 8/3/1 & was ringed on the pilot. Changeout motor & orienter. 10:00 - 11 :00 1.00 DRILL P PROD1 M/U drilling BHA #5 with new Hughes RWD2ST 3-3/4" x 4-1/8" bicenter bit, 2.83deg bend motor, MWD/GR/RES, orienter & MHA (OAL = 90.21 '). Scribe tools & download RES data. M/U injector. 11 :00 - 12:45 1.75 DRILL P PROD1 RIH with BHA #5. SHT MWD & orienter - OK. RIH thru window without pumps. 12:45 - 12:50 0.08 DRILL P PROD1 Orient TF to SOL. 12:50 - 13:00 0.17 DRILL P PROD1 Continue RIH to btm tagged @ 9102'. 13:00 - 14:30 1.50 DRILL P PROD1 Drill to 9150' with 45L TF, 2.6/2.6bpm, 3250/3400psi, 2k WOB & 35fph ave ROP. Getting 25degs DLS. Decide to POOH to reset motor bend. 14:30 - 16:30 2.00 DRILL N DPRB PROD1 POOH drilling BHA#5. Chase solids to surface, jog back in hole to 400' @ 100fpm & chase back up to surface. 16:30 - 17:00 0.50 DRILL N DPRB PROD1 OOH. PJSM. SIB injector. Check bit - OK, grades - 2/1/1. Reset motor bend to 3.63degs. M/U drilling BHA #6 with same components. Scribe tools & M/U injector. 17:00 - 19:00 2.00 DRILL N DPRB PROD1 RIH with BHA #6. Orient to LS above window. RIH. 19:00 - 19:30 0.50 DRILL N DPRB PROD1 Tag bottom. Orient. 19:30 - 00:00 4.50 DRILL P PROD1 Drill from 9,150' to 9,278'. 8/10/2004 00:00 - 02:30 2.50 DRILL P PROD1 Drill build section to 9,375'. 02:30 - 03:20 0.83 DRILL P PROD1 CBU to confirm HOT. 03:20 - 05:00 1.67 DRILL P PROD1 Orient and drill to 9,405'. Shoot survey. 05:00 - 07:00 2.00 DRILL P PROD1 POOH to PU lateral drilling BHA. Chase solids to surface, jog back in hole to 400' @ 100fpm & chase back up to surface. 07:00 - 07:30 0.50 DRILL P PROD1 OOH. PJSM. SIB injector. UD BHA #4. Bit grades - 3/1/1 & was slightly ringed on the pilot. Changeout bit & reset motor bend to 1.37degs. 07:30 - 08:15 0.75 DRILL P PROD1 M/U drilling BHA #7 with used HYC DS100 3-3/4" x 4-1/4" bicenter bit, 1.37deg bend motor, MWD/GR/RES, orienter & MHA (OAL = 90.12'). Scribe tools & download RES data. M/U injector. 08:15 - 10:00 1.75 DRILL P PROD1 RIH with BHA #7. SHT MWD & orienter - OK. RIH thru window without pumps. 10:00-10:15 0.25 DRILL P PROD1 Log up GR & tie-into RA PIP tag. Added 2' to CTD. 10:15 - 10:30 0.25 DRILL P PROD1 Continue RIH to btm tagged @ 9405'. 10:30 - 11 :25 0.92 DRILL P PROD1 Drill to 9452' with 145L TF, 2.6/2.6bpm, 3450/3600psi, 3k WOB & 35fph ave ROP. 11 :25 - 12:00 0.58 DRILL N DPRB PROD1 Attempt to orient on btm - not getting clicks. PUH to window & Printed: 8/16/2004 9:46:23 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-25 J-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 8/4/2004 8/15/2004 N1 Spud Date: 7/24/1987 End: 8/15/2004 8/10/2004 11 :25 - 12:00 0.58 DRILL N DPRB PROD1 orient to 60L. RBIH to btm. 12:00 - 17:15 5.25 DRILL P PROD1 Drill to 9,557'. Start mud swap to reconditioned flo pro. New mud exiting bit at 9,225'. Slow ROP. Lots of stalls. Formation showing 5% chert. Will POOH to change bit. 17:15 - 19:00 1.75 DRILL P PROD1 POOH to change bit. 19:00 - 20:00 1.00 DRILL P PROD1 Stand back injector. Stand back / lay down BHA components. Download RES data. Verify orienter integrity. 20:00 - 20:30 0.50 DRILL P PROD1 Change out motor· 1.04 degree bend. · Bearing pre-load ring was loose. Failure of the pre-load ring prohibits proper loading of the bearings which would lead to internal damage to the motor with prolonged drilling. Change out bit to DS49 - 3.75" 00. - DS100 was balled up in the junk slots of the gauge mill, pilot was clear. - No additional tooth wear was seen (graded 1-2-BU). - Exceeded target depth of 9400' MD for 4.25" hole (9558' MD). - KlaGaurd content = 12 ppb in new system, as with old system. - DS49 was run to minimize bit balling. 20:30 - 21:10 0.67 DRILL P PROD1 RIH at 100 fpm, 0.4 bpm on the stroke counter, 1330 psi. 21:10 - 21:15 0.08 DRILL P PROD1 At 3000' MD, shallow hole test MWD. 21:15 - 22:20 1.08 DRILL P PROD1 Continue to RIH to 8970' MD at 100 fpm; 0.45 I 0.94 bpm; 1230 psi. 22:20 - 22:35 0.25 DRILL P PROD1 PUH. Tie in to pip tag at 8922' MD. · Add 4' correction. 22:35 - 23:00 0.42 DRILL P PROD1 RIH to bottom. - Window and hole in good condition. 23:00 - 23:20 0.33 DRILL P PROD1 Orient TF to 110 L. 23:20 . 00:00 0.67 DRILL P PROD1 Drill ahead in Zone 1from 9558' - 9626' MD. - 2.6/2.65 bpm. 3160 psi. 4600 WOB. 125 fph ROP. - PU = 36k; SO = 23.5k 8/11/2004 00:00 . 01 :00 1.00 DRILL P PROD1 Drill ahead in Zone 1from 9626' - 9700' MD. -2.65/2.75bpm. 3300psi. 10kWOB. 115fphROP. - PU = 36k; SO = 23.5k - Hole sticky on pick up, 5k overpull. - Surveys showing 7.71 to 9.79 deg DLS. Suspect magnetic interference from neighboring well bore. 01 :00 - 02:00 1.00 DRILL P PROD1 Wiper trip to window. - Hole in good condition. · Pump up long survey showing minimal magnetic interference. 02:00 - 02:40 0.67 DRILL P PROD1 Drill ahead in Zone 1from 9700' . 9750 ' MD. -2.65/2.75bpm. 3300 psi. 10kWOB. 115fphROP. - PU = 37k; SO = 24k - Hole sticky on pick up, 5k overpull. · DLS = 10.21 deg. Anticipating 12 deg DLS to make build within polygon. - Shut down pumps to minimum rate to pump up survey. - No magnetic interference. Printed: 8116/2004 9:46:23 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-25 J-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 8/4/2004 8/15/2004 N1 Spud Date: 7/24/1987 End: 8/15/2004 8/11/2004 02:40 - 02:45 0.08 DRILL N STUC PROD1 PU after pumping up survey. Temporarily detained. Pull in increments of 20k to 80k final PU. 02:45 - 03:00 0.25 DRILL N STUC PROD1 Allowing hole to relax as per Stuck Pipe SOP. Pick up. Pipe free. 03:00 - 03:30 0.50 DRILL P PROD1 Wipe hole to window. - Hole in good condition. 03:30 - 04:00 0.50 DRILL P PROD1 Orient to 70 left. Drill from 9750 - 9795' MD. Only getting 7 deg DLS. Decision to POOH for bigger bend to get the dog legs required to stay in the polygon. 04:00 - 06:00 2.00 DRILL N HMAN PROD1 Not achieving required DLS wI selected BHA. Trip to change to 1 .37 deg motor. POOH with lateral BHA from 9795' MD. - 2.6 / 2.55 bpm, 3100 psi at 35 fpm. 06:00 - 06:45 0.75 DRILL N HMAN PROD1 Change motor bend to 1.37 degrees. Some clay on BHA and bit. Rerun OS 49. 06:45 - 09:25 2.67 DRILL N HMAN PROD1 RIH. Tie in to RA marker logging up, +2' correction. RIH. 09:25 - 13:00 3.58 DRILL P PROD1 Drill to 9,955'. 13:00 - 14:30 1.50 DRILL P PROD1 Wiper trip to window. No hole problems. Run through shale/clay intervals from 9,500' - 9,550' and 9,810' - 9,865' oriented to the as drilled TF. 14:30 - 18:40 4.17 DRILL P PROD1 Drill from 9,955' to 10,091' at 2.7/2.7 3,250 13,450 psi. 18:40-19:15 0.58 DRILL P PROD1 Orient tool face to 80L. 19:15-19:25 0.17 DRILL P PROD1 Trouble getting the bit to drill. Short trip the BHA. 19:25 - 19:35 0.17 DRILL P PROD1 Drill ahead from 10,091' to 10,105' MD - 2.55 / 2.66 bpm; 3500 psi. - PU 38k; SO 25k 19:35 - 20:25 0.83 DRILL P PROD1 Wiper trip to window at 30 fpm. - 2.62 12.53 bpm, 3000 psi, 38 - 39k PU. - 2.65 - 2.92 bpm, 3120 psi, 27k SO. - MOTOR WORK <no overpull): - 9275 - 9220' MD while POOH. - 9290 - 9340' MD while RIH. - 9390 - 9420' MD while RIH. 20:25 - 21 :20 0.92 DRILL P PROD1 Orient tool face to 120L prior to RIH through 9500' shale. - Difficulty orienting due to DLS. 21 :20 - 21 :30 0.17 DRILL P PROD1 Continue wiping hole from 9500' - 9800' MD. Slick. 21 :30 - 21 :35 0.08 DRILL P PROD1 Orient tool face to 100L prior to RIH through 9800' shale. 21 :35 - 21 :45 0.17 DRILL P PROD1 Continue wiping hole from 9800' - 10105' MD. Slick. - Begin fluid swap. 21 :45 - 22:15 0.50 DRILL P PROD1 Orient tool face to 120 L. 22:15 - 00:00 1.75 DRILL P PROD1 Drill ahead from 10,105' to 10,162' MD - 2.63 I 2.78 bpm; 3300/3400 psi. - PU 38k / SO 26k - Difficulty drilling ahead in shale section. - New fluid in hole. 8/12/2004 00:00 - 01 :45 1.75 DRILL P PROD1 Drill ahead from 10,162' MD to 10,230' MD - Motor periodically stalling. - PU 38k; SO 24k - 2.7 12.75 bpm - 3300 psi - Maintaining toolface of 80 L. Printed: 8/16/2004 9:46:23 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-25 J-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/4/2004 Rig Release: 8/15/2004 Rig Number: N1 Spud Date: 7/24/1987 End: 8/15/2004 8/12/2004 01:45 - 02:15 0.50 DRILL P PROD1 Orient TF to 60 R. 02:15·03:00 0.75 DRILL P PROD1 Drill ahead from 10,230' MD to TO at 10,310' MD. · PU 39k; SO 24k ·2.6/2.7 bpm - 3100 psi 03:00·03:40 0.67 DRILL P PROD1 Wiper trip to 8970' at 30 fpm. · PU at 40k Ibs. · Motor work at 9,380' . 9,290' MD and 9,265' . 9,200' MD. 03:40 . 04:00 0.33 DRILL P PROD1 Log up to 8964' MD. Subtract l' for tie in (8963'). Charge pump failure on the P-14 pump. · Cannot move coil to get into casing. · MWD across window. · Maintaining pump rate at 2.71 /2.84 bpm, 2900 psi. · BHA length 89.86'. TOW at 8912' MD. Bit at 8963' MD. 04:00 - 06:00 2.00 DRILL N RREP PROD1 Failure of power pack hydraulic pump. Waiting on SLB mechanic for repair. - Maintaining 1.88 I 1.95 bpm; 1850 psi. 06:00 - 08:30 2.50 DRILL N RREP PROD1 Install new power pack hydraulic pump. Circulate at 1.0 bpm. 08:30 . 09:30 1.00 DRILL P PROD1 Continue wiper trip. RIH and start pumping liner running pill. Orient to as drilled TF before running through clay intervals. Hole in good condition. Tag bottom at 10,306', corrected TO. 09:30 -11:15 1.75 DRILL P PROD1 Lay in liner running pill. POOH. 11 :15·13:00 1.75 DRILL P PROD1 Down load RES tool. LD BHA. 13:00 - 13:15 0.25 CASE P RUNPRD PJSM for running liner. 13:15·13:45 0.50 CASE P RUN PRO RU to run liner. Bring Baker tools to rig floor. 13:45 - 16:15 2.50 CASE P RUNPRD Run 2 7/8" x 3 3/16" liner. 16:15·16:30 0.25 CASE P RUNPRD MU CTLRT. 16:30 - 17:00 0.50 CASE P RUN PRO Cut off OS CTC. MU Baker CTC. Pull test to 35 kips and pressure test to 3,500 psi. 17:00 - 18:00 1.00 CASE P RUNPRD Load and pump volume dart. Dart hit at 57.4 bbls. 18:00 . 19:30 1.50 CASE P RUN PRO MU liner to CT. RIH wI liner on CT. 19:30 . 20:00 0.50 CASE P RUN PRO RIH through window. - PU 42k I SO 31 k · Pumping 0.17 I .27 bpm · Stack up at 10,268' MD. PU, fall through easily. Confirm liner is on bottom. -PU61k/S031k 20:00 - 20:30 0.50 CASE P RUN PRO Establish circulation at 2.6 I 2.7 bpm. Drop 5/8" steel ball. Pump down at 2.7 12.8 bpm to 40 bbls away. Pump down at 0.54 / 0.59 bpm. Ball on seat at 42.4 bbls. Ball shear at 3821 psi. Shut down pumps. PU wt 40k. Set down to 19k SO. 20:30 . 22:00 1.50 CASE P RUNPRD Displace well to 2% KCI at 2.65 / 2.75 bpm. · With KCI around, 2.62/2.54 bpm. - Begin rigging up cementers. 22:00 - 23:00 1.00 CASE P RUNPRD Continue rigging up cementers. 23:00 . 00:00 1.00 CEMT P RUN PRO Cement liner in place. - PJSM for cement job. Printed: 8/16/2004 9:46:23 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-25 J-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 8/4/2004 8/15/2004 N1 Spud Date: 7/24/1987 End: 8/15/2004 8/12/2004 23:00 . 00:00 1.00 CEMT P RUN PRO - Mix cement to 15.9 ppg class G gas block slurry. · Pressure test lines to 4000 psi with 1.9 bbls of fresh water. - Begin pumping at 1.9/ 1.7. - Zero in micromotion meter on density. - Pump 16.1 bbls cement (1.92/1.77 bpm. 1700 psi with cement pumped) - Load dart. Blow lines back to ensure Bio water behind dart. - Pump 25 bbls of 2 ppb Biozan water. Pressure decreasing from 2100 psi to 700 psi. 8/13/2004 00:00 . 00:30 0.50 CEMT P RUN PRO Continue with cement job. - Follow 25 bbls of bio water with 2% KCI water. Pressure = 500 psi. · At 57.7 bbls, cement entering liner. - Zero out micromotion at 66.7 bbls away (886 psi). - Hole started packing off with 70.7 bbls away, 4 bbls of cement on the backside. Pressure increased to 3,200 psi, then broke back. · Decreasing rate for latch, pressure broke over at 3500 psi. · Continued getting full returns and pressure climbing, indicating cement column filling the backside. - Saw dart latch at 57.1 bbls (coil volume at 57.4 prior to RIH). - Dart sheared at 3300 psi and 57.4 bbls. - Bumped plug at 66.1 bbls (coil volume 57.4 + liner volume 9.3 = 66.7 bbls). - Held 2400 psi (1000 psi over circ pressure). - Bled pressure. Checked floats. OK. · Pressure up to 260 psi. - Unsting from liner. Out at 10,298' MD. · Calculate approximately 1 bbl cement lost to formation. 00:30 . 01 :45 1.25 CEMT P RUNPRD POOH with CTLRT at 3.5 /3.0 bpm and 2100 psi. - Cement returns at 154 bbls away (bottoms up 158 bbls). - Divert all cement returns to cutting box. 01 :45 - 02:30 0.75 CEMT P RUNPRD LD CTLRT. PU nozzle. Clear rig floor. Bring little jerk equipment and logging tools to rig floor. 02:30 . 03:00 0.50 CEMT P RUNPRD Jet out BOP stack. RD Injector head. 03:00 . 04:00 1.00 EVAL P LOWER1 PJSM. Rig up little jerk attachments prototype. 04:00 . 05:00 1.00 EVAL P LOWER1 PJSM. PU BHA. Test little jerk prototype (spinners) on CSH. PU logging tools, circ sub, and disconnect. 05:00 - 06:00 1.00 EVAL P LOWER1 RIH with 23 stands + single of 1-1/4" CSH from the derrick. 06:00·07:15 1.25 EVAL P LOWER1 RIH with logginglcleanout assembly. 07:15·08:30 1.25 EVAL P LOWER1 Log down w/ MCNUCCUGR at 30 fpm. Tag landing collar at 10,274'. 08:30 - 10:45 2.25 EVAL P LOWER1 Log up at 60 fpm and lay in liner running pill. POOH. 10:45 . 12:30 1.75 EVAL P LOWER1 PJSM. Rack back CSH. LD logging tools. 12:30·13:15 0.75 PERFOB P LOWER1 Pressure up well bore to 2,000 psi to test liner lap. Lost 210 psi in 2 minutes. Bleed off pressure and repeat test. Min. Pressure 0 2000 Printed: 8/16/2004 9:46:23 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-25 J-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: Spud Date: 7/24/1987 End: 8/15/2004 8/4/2004 8/15/2004 N1 LOWER1 1 1920 2 1875 3 1846 4 1820 5 1800 6 1780 7 1750 8 1740 9 1725 Test failed. LOWER1 PJSM for running perf guns. LOWER1 PU 41 joints 2" perf guns. TIH wI 10 stands of CSH. LOWER1 RIH. Tag PBTD at 10,272', no depth correction needed. LOWER1 Load 5/8" ball. Launch and pump down ball to fire perf guns. Ball on seat. Pressure up to 3,000 psi. Perforate w/ 2",6 SPF, 2006 PJ from: 10,160' -10,270' 9,860' - 10,060' 9,560' - 9,810' 9,410' - 9,510'. POOH with perf guns pumping 0.62 bpm. - POOH at 120 fpm. - Holding 200 psi backpressure. Flow check well to ensure static. Continue out of hole racking back CSH. PJSM for clearing rig floor and POOH with perf guns. - Fill hole, seepage losses. Rig down little jerk prototype. LD 41 Perf guns. Clear rig floor. Bring up liner running tools. PU KB liner top packer assy and 2-Jts 2-3/8" PH6. MU injector head. RIH with KB liner top packer. Attempt to stab in to deployment sleeve. Cannot enter deployment sleeve. - Attempt to enter deployment sleeve with pumps on at 0.3 bpm, 30 psi. - Stack up at 8837.7' MD with 5k down, no pressure increase. - Repeatedly attempt to enter deployment sleeve - failed. - Maximum weight stack was 15k down (8842' MD). - Shut down pumps, pressure up on backside 150 psi. - Attempt to sting in. Failed. - Decision to POOH. HMAN RUNPRD POOH with L TP and seal assembly. - Evidence on mule shoe of stacking out on deployment sleeve. - Baker to re-dress mule shoe. Waiting on crossovers to be made for new L TP run. PJSM for MU liner top packer BHA. Bring eclipse packer, XOs, and seal assembly to rig floor. MU liner top packer BHA. RIH w/ eclipse liner top packer. Attempt to stab seal assembly into liner top. 8/13/2004 12:30 -13:15 0.75 PERFOB P 13:15 - 13:30 13:30 - 15:50 15:50 - 17:30 17:30 - 18:15 0.25 PERFOB P 2.33 PERFOB P 1.67 PERFOB P 0.75 PERFOB P 18:15-19:45 1.50 PERFOB P LOWER1 19:45 - 20:15 0.50 PERFOB P LOWER1 20:15 - 21 :00 0.75 PERFOB P LOWER1 21 :00 - 21 :20 0.33 PERFOB P LOWER1 21 :15 - 21 :30 0.25 PERFOB P LOWER1 21 :30 - 00:00 2.50 PERFOB P LOWER1 8/14/2004 00:00 - 00:30 0.50 CASE P RUNPRD 00:30 - 00:45 0.25 CASE P RUNPRD 00:45 - 02:45 2.00 CASE P RUNPRD 02:45 - 03:15 0.50 CASE P RUN PRO 03:15 - 04:30 1.25 CASE N 04:30 - 10:30 6.00 CASE N HMAN RUN PRO 10:30 - 12:30 2.00 CASE N HMAN RUN PRO 12:30 - 14:20 1.83 CASE N HMAN RUN PRO 14:20 - 15:00 0.67 CASE N HMAN RUNPRD Printed: 8/16/2004 9:46:23 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-25 J-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/4/2004 Rig Release: 8/15/2004 Rig Number: N1 Spud Date: 7/24/1987 End: 8/15/2004 8/14/2004 14:20 - 15:00 0.67 CASE N HMAN RUNPRD Pump at .5 bpm, 88 psi. Set down at 8,840'. Slight pressure increase, 20 psi. PU and set down at 8,843'. No pressure change. PU and set down at 8,846'. No pressure change. PU. Increase pump rate to 2 bpm, 680 psi. Set down at 8,846' and pressure increased to 750 Repeat several times. Also increase pump rate and did not see good pressure indication of being stung in. Getting full returns. 15:00 - 17:00 2.00 CASE N HMAN RUNPRD Unable to sting seals into deployment sleeve. POOH. - All indications that seal assembly was stung into deployment sleeve. 17:00 - 18:00 1.00 CASE N HMAN RUNPRD Cut coil. 18:00 - 18:30 0.50 CASE N HMAN RUNPRD PJSM and pre tour meeting w/ night crew. Discuss plan forward with Anchorage. 18:30 - 20:00 1.50 CASE N HMAN RUN PRO MU SLB coil connector. - Pressure test to 3000 psi. - Pull testt to 3700 Ibs. MU injector head. MU eclipse L TP and new seal assembly. 20:00 - 21:45 1.75 CASE N HMAN RUNPRD RIH with L TP at 75 fpm (slowing to 40 fpm for restrictions). 21 :45 - 23:30 1.75 CASE N HMAN RUNPRD No-go at deployment sleeve. Set Eclilpse liner top packer. - At 8800 ft, PU 37K, S032k with pumps off. - Pump at 2 bpm at 675 psi. - RIH at 20 fpm. 8841 ft 760 psi. - No-go at 8846' on deployment sleeve. - Unsting, repeat for confirmation. - PU to drop ball. - Drop 5/8" steel ball. Pump down 2 bpm, 800 psi. - RBIH to 8846', PU l' to 8845' MD. - Slow pump at 35 bbls away to 0.5 bpm, 50 psi. - Ball on seat at 42.3 bbls. - Pressure up to 1200 psi (slips set at 940 psi). - Pressure up to 1600 psi. - Increase pressure to shear ball at 2650 psi. - Obvious ball shear; however, pressure did not bleed off. Discuss with Weatherford. Bleed down to 800 psi and pick up. No bleed off. - Re-tag packer on depth at 8845' MD. Confirm. - Continue discussion with Weatherford. Discovered stroke length between setting adapter sleeve and locator sleeve is 6-7", stroke length required to open flow path is 1 0" -- tool design flaw. - Bled off pressure at coil. - Center of packer element: 8832' MD. - Official TOL: 8828' MD. 23:30 - 00:00 0.50 CASE P RUNPRD POOH with setting tool at 130 psi. - Filling hole from backside. - Hole fill accurate. 8/15/2004 00:00 - 01 :00 1.00 CASE P RUNPRD POOH with setting tool at 130 psi. - Filling hole from backside. - Hole fill accurate. 01 :00 - 01 :15 0.25 CASE P RUNPRD LD running tool and PH6. - Measured stroke length to open flow path - 9.5" (needed Printed: 8/16/2004 9:46:23 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-25 J-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/4/2004 Rig Release: 8/15/2004 Rig Number: N1 Spud Date: 7/24/1987 End: 8/15/2004 8/15/2004 01 :00 - 01: 15 01 :15 - 02:30 0.25 CASE P 1.25 WHSUR P RUNPRD 10"). POST MU nozzle. RIH to 2200'. Freeze protect with 60/40 MeOH to 200' and 100% MeOH to surface. POOH. LD nozzle. 02:30 - 03:00 0.50 WHSUR P POST Off Critical Path: - Cleaning pits. - Rigging up N2 truck for blow down. PJSM. Pressure test to 3000 psi. Blow down reel with 20,500 scf N2. Blow down rig lines to tiger tank. 03:00 - 05:00 2.00 RIGD P POST Off Critical Path: - Cleaning pits. RD Injector head. NO BOPE. NU Tree cap, pressure test same to 4300 psi. Pits clean. RIG RELEASE: 05:00 HRS 08/15/04 Printed: 8/16/2004 9:46:23 AM . . 06-Sep-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well J-25A Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,908.90' MD 8,912.00' MD 10,306.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. :::o7~e;:~ Signed ~ ~/JJ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) ;)u'(~/~i Halliburton Sperry-Sun North Slope Alaska BPXA PBU_WOA J Pad J-25A Job No. AKMW3220865, Surveyed: 12 August, 2004 Survey Report 27 August, 2004 Your Ref: API 500292174101 Surface Coordinates: 5970533.00 N, 642472.00 E (700 19' 37.3048· N, 148050' 40.4060· W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 970533.00 N, 142472.00 E (Grid) Surface Coordinates relative to Structure Reference: 2282.55 N, 1361.33 E (True) Kelly Bushing Elevation: 77. 10ft above Mean Sea Level Kelly Bushing Elevation: 77. 10ft above Project V Reference Kelly Bushing Elevation: 77. 10ft above Structure Reference 5pa............y-5ul'l DFlILLING S..E!!FlVIC:ES A Halliburton Company DEFINITI e e Survey Ref: svy4361 Halliburton Sperry-Sun Survey Report for PBU_WOA J Pad - J-25A Your Ref: API 500292174101 Job No. AKMW3220865, Surveyed: 12 August, 2004 BPXA North Slope Alaska Measured True Sub-8ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8908.90 52.170 52.250 8689.13 8766.23 173.45 N 502.94 E 5970715.97 N 642971.56 E 451.31 Tie-on Point MWD Magnetic 8912.00 52.280 52.310 8691.03 8768.13 174.95 N 504.88 E 5970717.51 N 642973.47 E 3.860 453.70 Window Point 8942.71 46.780 55.560 8710.96 8788.06 188.72 N 523.74 E 5970731.63 N 642992.06 E 19.632 476.26 8975.29 35.950 60.240 8735.38 8812.48 200.22 N 541.89 E 5970743.47 N 643009.99 E 34.551 496.62 e 9007.16 25.730 67.120 8762.72 8839.82 207.57 N 556.43 E 5970751.10 N 643024.38 E 33.877 511.49 9029.89 22.250 74.690 8783.49 8860.59 210.63 N 565.13 E 5970754.32 N 643033.03 E 20.411 519.34 9068.00 19.300 100.470 8819.19 8896.29 211.39 N 578.31 E 5970755.34 N 643046.19 E 24.989 528.22 9100.45 21.760 103.650 8849.58 8926.68 209.00 N 589.43 E 5970753.15 N 643057.36 E 8.321 533.36 9131.10 27.750 91.490 8877.42 8954.52 207.47 N 602.10 E 5970751.86 N 643070.06 E 25.559 540.15 9159.46 36.740 80.210 8901.40 8978.50 208.74 N 617.11 E 5970753.42 N 643085.03 E 38.030 550.58 9190.95 49.160 72.630 8924.42 9001.52 213.92 N 637.85 E 5970759.00 N 643105.68 E 42.658 567.66 9229.15 62.200 80.560 8945.93 9023.03 221.05 N 668.48 E 5970766.70 N 643136.16 E 38.158 592.47 9262.78 70.130 94.660 8959.57 9036.67 222.21 N 699.09 E 5970768.44 N 643166.74 E 44.965 612.64 9290.26 66.170 90.780 8969.80 9046.90 220.99 N 724.55 E 5970767.71 N 643192.23 E 19.475 627.72 9322.46 67.220 84.090 8982.55 9059.65 222.32 N 754.07 E 5970769.60 N 643221.72 E 19.356 647.33 9352.02 81.500 84.620 8990.50 9067.60 225.11 N 782.33 E 5970772.92 N 643249.91 E 48.339 667.27 9384.78 94.360 81.270 8991.68 9068.78 229.12 N 814.75 E 5970777.55 N 643282.25 E 40.558 690.80 9414.59 95.250 65.670 8989.17 9066.27 237.54 N 843.13 E 5970786.51 N 643310.47 E 52.231 715.21 9447.56 90.220 64.170 8987.59 9064.69 251.50 N 872.95 E 5970801.03 N 643340.02 E 15.918 744.82 9481.63 93.830 59.770 8986.39 9063.49 267.49 N 902.99 E 5970817.59 N 643369.75 E 16.697 776.15 9513.13 96.210 56.250 8983.63 9060.73 284.11 N 929.60 E 5970834.71 N 643396.04 E 13.453 805.81 e 9549.29 92.860 52.540 8980.77 9057.87 305.09 N 958.90 E 5970856.25 N 643424.93 E 13.799 840.56 9582.18 91.450 50.430 8979.54 9056.64 325.56 N 984.61 E 5970877.20 N 643450.25 E 7.712 872.64 9622.31 90.660 48.670 8978.80 9055.90 351.59 N 1015.14 E 5970903.80 N 643480.29 E 4.807 912.09 9657.03 89.430 45.500 8978.77 9055.87 375.23 N 1040.57 E 5970927.92 N 643505.26 E 9.793 946.46 9695.37 89.250 45.320 8979.21 9056.31 402.14 N 1067.87 E 5970955.34 N 643532.04 E 0.664 984.55 9728.22 87.750 42.320 8980.07 9057.17 425.83 N 1090.61 E 5970979.46 N 643554.32 E 10.207 1017.27 9769.63 88.020 39.330 8981.60 9058.70 457.14 N 1117.66 E 5971011.28 N 643580.77 E 7.245 1058.63 9802.08 88.280 36.160 8982.65 9059.75 482.78 N 1137.51 E 5971037.30 N 643600.13 E 9.797 1091.05 9841.21 92.250 31.400 8982.47 9059.57 515.29 N 1159.25 E 5971070.21 N 643621.26 E 15.838 1130.00 27 August, 2004 - 10:15 Page 20f4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA J Pad - J-25A Your Ref: AP/500292174101 Job No. AKMW3220865, Surveyed: 12 August, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9872.57 93.130 25.410 8980.99 9058.09 542.83 N 1174.15 E 5971098.03 N 643635.63 E 19.285 1160.77 9904.90 91.100 18.360 8979.80 9056.90 572.79 N 1186.18 E 5971128.21 N 643647.09 E 22.677 1191.63 9937.55 87.910 12.160 8980.08 9057.18 604.27 N 1194.77 E 5971159.85 N 643655.08 E 21.353 1221.50 9968.96 87.670 2.850 8981.30 9058.40 635.35 N 1198.86 E 5971191.00 N 643658.58 E 29.628 1248.23 10004.20 92.780 356.510 8981.16 9058.26 670.56 N 1198.67 E 5971226.20 N 643657.72 E 23.102 1275.47 e 10039.84 93.480 352.460 8979.21 9056.31 705.98 N 1195.25 E 5971261.55 N 643653.63 E 11.515 1300.84 10069.48 93.130 345.230 8977.50 9054.60 734.99 N 1189.53 E 5971290.44 N 643647.36 E 24.381 1319.79 10100.46 95.150 336.770 8975.26 9052.36 764.18 N 1179.48 E 5971319.44 N 643636.76 E 28.005 1336.15 10139.00 91.630 334.660 8972.98 9050.08 799.24 N 1163.66 E 5971354.19 N 643620.27 E 10.643 1353.44 10170.62 88.900 327.080 8972.83 9049.93 826.83 N 1148.28 E 5971381.49 N 643604.37 E 25.477 1365.21 10204.82 89.250 318.270 8973.39 9050.49 854.00 N 1127.57E 5971408.26 N 643583.15 E 25.777 1373.28 10242.34 92.330 319.680 8972.87 9049.97 882.30 N 1102.94 E 5971436.08 N 643557.99 E 9.028 1379.78 10271.26 91.280 324.440 8971.96 9049.06 905.09 N 1085.18 E 5971458.53 N 643539.80 E 16.847 1386.31 10288.38 90.930 328.670 8971.63 9048.73 919.37 N 1075.75 E 5971472.63 N 643530.10 E 24.788 1391.47 10306.00 90.930 328.670 8971.34 9048.44 934.42 N 1066.59 E 5971487.50 N 643520.65 E 0.000 1397.40 Projected Survey All data is in Feet (US Survey) 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 . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 39.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10306.00ft., The Bottom Hole Displacement is 1418.01ft., in the Direction of 48.779° (True). e 27 August, 2004 - 10:15 Page 3 of4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA J Pad - J-25A Your Ref: API 500292174101 Job No. AKMW3220865, Surveyed: 12 August, 2004 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8908.90 8912.00 10306.00 8766.23 8768.13 9048.44 173.45 N 174.95 N 934.42 N 502.94 E 504.88 E 1066.59 E Tie-on Point Window Point Projected Survey e Survey tool program for J-25A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8908.90 0.00 8908.90 8766.23 10306.00 8766.23 BP Conventional Gyro (J-25) 9048.44 MWD Magnetic (J-25A) e 27 August, 2004 - 10:15 Page 4 of4 DrillQuest 3.03.06.006 ·1 TREE = W8..LHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max An~1e = DatumMD= Datum TVD = CAMffiON WCEVOY OTIS 77.14' 39.24' 8000' 94 @ 11429' 910Z 8800' S8 13-3/8" CSG, 72.#, L-80, ID'" H I Minimum ID :::::: 2.39" . Seal Assembly 8 ,84Q , , 9-5/8" CSG, 47#, L-80, NSCCX eTRS TOP 9410 9560 9860 10160 BOTTOM 9510 9810 10060 10270 OPEN 0P8\! 0P8\! ¡:v¡.1E 08114104 08114104 08114104 08114104 5-1IZ' TBG, 17#, L..aO, 9-518" CSG, 47#, L-80,D = 9459' HTW SL TO LNR. 17#, DA 1E REV BY COMMENTS 08123/87 07120101 R!\IITP CORRECTIONS 04116103 CI\IK)IKK MAX ANGLE CORR8JTlON 05130104 RI\IIHIKAK GLV C/O 07128104 08114104 BMH cm SIDETRACK .~ I I í I ~ .. SWIV8.. I .. .... ~ .~ I I ~ ~ I I ! ... SÄÆTY NOTES: . ST MD WD 2928 5114 6548 7440 7886 7804 1 8041 7957 GAS LIFT MANDRELS TYPE VLV OTIS OTIS so 2 OTIS DM'{ 4 OTIS 8 OTIS 11 OM'{ 8336' laP . . FRANK H. MURKOWSKI, GOVERNOR JtI,ASIiA. OIL AND GAS CONSERVATION COlWlISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay J-25A BP Exploration (Alaska) Inc. Permit No: 204-138 Surface Location: 800' SNL, 1881' WEL, SEC. 09, Tl1N, R13E, UM Bottomhole Location: 177' NSL, 730' WEL, SEe. 04, T11N, R13E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you trom obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 ager). el BY ORDER Sl~ THE COMMISSION DATED thi~ day of July, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. l;J6Æ 71i..&!2-{)04 , 1 a. Type of work 0 Drill C B Redrill ORe-EntrY; 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 800' SNL, 1881' WEL, SEC. 09, T11N, R13E, UM Top of Productive Horizon: 744' SNL, 1561' WEL, SEC. 09, T11N, R13E, UM Total Depth: 177' NSL, 730' WEL, SEC. 04, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 642472 y- 5970533 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 8910 feet Maximum Hole Angle: 101 _ STATE OF ALASKA . ALASKA ~ AND GAS CONSERVATION COM'lfSSION PERMIT TO DRILL 20 AAC 25.005 1b. Current Well Class 0 Exploratory B Development Oil 0 Multiple Zone o Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU J-25A / 6. Proposed Depth: 12. Field I Pool(s): MD 10300 TVD 8980ss Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool / ADL 028281 8. Land Use Permit: 13. Approximate Spud Date: August 15, 2004 J 14. Distance to Nearest Property: 21,700' 9. Acres in Property: 2560 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 77.1' feet J-01A is 71' away at 9131' MD 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 3170 Surface: 2290 ,,/ Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4-1/8" x 3-3/4" 3-3/16" x 2-7/8" 6.2# 16.16# L-80 TCII I STL 1450' 8850' 8652' 10300' 8980' 73 cu ft Class 'G' (' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD 11659 8987 None 11658 8987 Structural Conductor 110' 20" 8 cu yds Concrete 110' 110' Surface 2684' 13-3/8" 3250 cu ft Permafrost 'E', 465 cu ft PF 2684' 2686' Intermediate 8580' 9-5/8" 1750 cu ft Class 'G' 8580' 8528' Production Liner 3319' 5-1/2" 465 cu ft Class 'G' 8340' - 11659' 8319' - 8987' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): Slotted Section: 8998' - 8987' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 18120 MC 25.050 Requirements Perforation Depth MD (ft): Slotted Section: 9532' - 11658' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Mary CT Drilling Engineer Date: Contact Mary Endacott, 564-4388 Permit To Drill Number: Permit Approval Number: 50- 029-21741-01-00 Date: ?y'-:;>~~ Conditions of Approval: Samples Required 0 Yes ~ No Mud Log ReqUired Hydr Sulfide Measures ~ Yes 0 No Directional Survey Required Other: Test- ß'[) ¡) F i ~Soo y;t;e' p-e.ý C. o· s ¡(P, 000. See cover letter for other requirements o Yes ß1,No )8Yes 0 No APPROVED BY o RIG I N A LTHE COMMISSION Date ~/()f.// %~ In -Dt"icate . BP J-25A Sidetrack . CTD Sidetrack Summary 1) Mill window off whipstock 2) Drill sidetrack 3) Run liner, cement and perforate Mud Program: · Well kill: 8.4 - 8.9 pp~ · Milling/drilling: 8.5 c:~g used Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: · 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: · 3 3/16" x 27/8" cemented liner completio~' -10,300'. / · The liner cement volume is planned to bet~ls of 15.8 ppg class G. Casin2lLiner Information 13 3/8", L-80, 72#, Burst 5380 psi; collapse 2670 psi 95/8", L-80 47#, Burst 6870, collapse 4750 5 Yz" L-80, 17#, Burst 7740 psi; collapse 6280 psi planned 33/16" L-80 TCll, 6.2#, Burst 8520 psi; collapse 7660 psi (hole size 4.125") 27/8" L-80 STL 6.16#, Burst 10570 psi; collapse 11170 psi (hole size 3.75") Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi./' · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 100deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · Distance to nearest property 21,700ft · Distance to nearest well within pool 71ft to J-01A at 9,131' Logging · MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. · MCNL will be run cased hole. Hazards · Wellbore stability problems due to shales · Max H2S on Pad 60ppm at J-26 Reservoir Pressure · Res. press. is estimated to be 3170 psi at 8800'ss (6.9 ppg EMW). / Max. surface pressure with gas (0.10 psi/ft) to surface is 2290 psi. TREE = WELLHEAD = Æ, ACTUA TOR = _~ "~",,,,~.m"" KB. ELEV = BF. ELEV = KOP= Max Angle = Datul11M[) "" . . .. Datum lVO = CAMERON MCEVOY OTIS 77.14' 39.24' 8000' 94 @ 11429' .. .. . 91Ö2; 8800' SS . J-25 ~OTES: Proposed CTD Sidetrack 13-3/8" CSG, 72#, L-80, 10 = 12.347" l-i 2686' ~ 9-5/8" CSG, 47#, L-80, NSCCX BTRS H 4337' I ~ Minimum ID = 4.455" @ 9531' 5-1/2" OTIS XN NIPPLE 5-1/2" TBG, 17#. L-80, .0232 bpf, 10 = 4.892" H 8336' I TOP OF 5-1/2" LNR H 8340' 9-5/8" CSG, 47#, L-80, 10 = 8.681" H 8580' I Liner Top Packer H 8845' I Mechanical Whipstock H 8910' 9459' HTIW 5-1/2" CSG SWIVEL I 5-1/2" LNR, 17#, L-80, .0232 bpf, 10 = 4.892" H 9532' I TOP OF 5-1/2" SL TO LNR1-f 9532' I PaTO H 11658' 5-1/2" SL TO LNR, 17#, L-80, .0232 bpf, 10 = 4.892" H 11659' DA TE REV BY COMMENTS 08/23/87 ORIGINAL COM PLETION 07/20/01 RNlTP CORRECTIONS 04/16/03 CMO/KK MAX ANGLE CORRECTION 05/30/04 RMHlKAK GL V C/O DATE REV BY ! ~ J ~ ~ ~ I I ~ . L I I ~ ì~ . ... ZJ ~ I I I ~ COMMENTS r 2109' H5-1/2" CAMCO SSSV LAND. NIP,ID=4.562" I . GAS LIFT MANDRELS ST MD lVD OEV TYÆ VLV LATCH 6 3006 2928 5 OTIS DOME 5 5193 5114 0 OTIS SO 4 6628 6548 2 OTIS DMY RA 3 7520 7440 4 OTIS DMY RA 2 7886 7804 8 OTIS DMY RA 1 8041 7957 11 OTIS DMY RA PORT DA TE 16 05/30/04 20 05/30/04 o o o o / 8154' H5-1/2" OTIS XA SLIDING SLEEVE, 10 = 4.562" 8219' H SBR SEAL ASSY I 8219' H 9-5/8" x 5-1/2" TIW HBBP PKR, 10 = 4.75" I 8292' 8336' 8336' H5-1/2" OTIS X NIP, 10 = 4.562" I H5-1/2" SEAL ASSY W/O SEALS I HELMDTTLOGGED12/27/95 I ~ 8850' 8850' 8860' ¡-iTOP of Cement -i Top of 3-1/2" Liner IJ3-1f2" XNNIP, 10=2.75" I /' 3-3/16" X 2-7/8" emt'ed and perfedl-f 10300' I 9463' H TIW PORT JOINT I I 9472' H GTe PKR, MUD-FILLED I 9531' H5-1/2"OTISXNNIP,ID=4.455" I PRUDHOE BA Y UNIT WELL: J-25 ÆRMIT No: 1870680 API No: 50-029-21741-00 SEe 9, T11N, R13E BP Exploration (Alaska) Plan: Plan #6 (J~25¡Plan#6 J-25A) Created By: Srij Potnis Date: 712212004 Azimuths to True North Magnetic North: 25.110 Magnetic Field Strength: 57591 n T Dip Angle: 80.860 Date: 7/22/2004 Model: bggm2003 T 9~ 16 AM 7/22/2001 1300 1350 Vertical Section at 39.00· [50fflin] 'ë' i! o o 'f" .... -. + - .c 1: o ~ -. . - .c .. ::& o tn BP Amoco WEU.PATH DETAILS Plalt#$ J·25A 5002:$2174101 Paml'lt Wetfpath: J.2S Tie 01'1 MD: 890&.90 Rig: u¡: = 2$ 712411981 00:00 77.1Oft Ref. Dl!lbun; V.s.CfiOll ~~~ Origin Starting ..... +Ef-W F~TVD 39,Of}' 0.... 0.... 31'.$0 REFERENCE INFORMATION Well Centre: J-25, True North System: Mean Sea Level Slot· 25 (O.OON.O.ODE) 36: 25 7/24/1987 00:00 77.10 Minimum Curvature secTfON OETAU.5 ,"0 ", n¡. ..,.. ...... Ot.eg Tf'=e VSI.'Ic Target , 52.17 &eaIM4 173.44- ~¡i~ o..~ 2~: 451,03 , 52,21 86.69A!1 173.'97 451.88 , $.41 8702.31 183.52 515..iAOO 1Sa.DO 461.07 , .22,41 8766.06 212.:2:9 552.14 00 160,00 512.83 , ".M -6812.55 216.66 570.0 ·35..00 110,00 527,13 · ..... 8658.40 ""'~7 !Ul6.68 35.tIO 100.00 529,75 7 ...... 8&64.00 294.12 758.6$ 35.00 2:8a.OO 636.07 · 100.$0 $962.24 213.80 78&.67 35..00 0.... 661.35 · &0.00 6979>50 :1;23,48 81$.0& 35.00 1$0,00 S86.33 ,. ..... IW7tt5Q 752.551131.31 12.00 270.00 1296.80 " 90.00 89tS,5O ö77.14 1148..23 12.00 90,00 14tH,99 ANNOTATtONS '" MD Äftnøtation f4 8&0 TOP " KOP " End e. DLS f hsln 3S DL$ ,. 4 IS · .. · " 7 .. · .. End 35 !)L$ I eegll'l 12 DJ..S ,. ,. .. T' .... C. ~~, It) .... .c8 .... i:I. iii 8 D i81 u :e 8850 iii >8 IIì 28 ... ObP . . ... ...... INTEQ BP-GDB Baker Hughes INTEQ Planning Report Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: PB J Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5968224.22 ft 641155.79 ft Latitude: 70 19 Longitude: 148 51 North Reference: Grid Convergence: 14.845 N 20.092 W True 1.08 deg Well: J-25 Slot Name: 25 J-25 Well Position: +N/-S 2283.80 ft Northing: 5970533.00 ft Latitude: 70 19 37.305 N +Ef-W 1359.50 ft Easting : 642472.00 ft Longitude: 148 50 40.406 W Position Uncertainty: 0.00 ft Wellpath: Plan#6 J-25A 500292174101 Current Datum: 36 : 25 7/24/1987 00:00 Magnetic Data: 7/22/2004 Field Strength: 57591 nT Vertical Section: Depth From (TVD) ft 37.60 +Nf-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +Ef-W ft 0.00 J-25 8908.90 ft Mean Sea Level 25.11 deg 80.86 deg Direction deg 39.00 Height 77.10 ft Targets J-25A Polygon6.1 0.00 344.88 853.77 5970894.00 643319.00 70 19 40.696 N 148 50 15.482 W -Polygon 1 0.00 344.88 853.77 5970894.00 643319.00 70 1940.696 N 148 50 15.482 W -Polygon 2 0.00 247.33 512.83 5970790.00 642980.00 70 19 39.737 N 148 50 25.435 W -Polygon 3 0.00 95.90 532.96 5970639.00 643003.00 70 19 38.248 N 148 50 24.848 W -Polygon 4 0.00 109.53 816.29 5970658.00 643286.00 70 19 38.382 N 148 50 16.577 W -Polygon 5 0.00 189.24 1095.88 5970743.00 643564.00 70 1939.165N 148 50 8.415 W -Polygon 6 0.00 267.90 1167.39 5970823.00 643634.00 70 19 39.939 N 148 50 6.327 W -Polygon 7 0.00 1001.65 1243.34 5971558.00 643696.00 70 1947.155 N 148 50 4.106 W -Polygon 8 0.00 981.41 1044.90 5971534.00 643498.00 70 19 46.956 N 148 50 9.900 W -Polygon 9 0.00 483.81 964.44 5971035.00 643427.00 70 1942.062 N 148 50 12.251 W J-25A Fault 1 0.00 1018.67 1400.70 5971578.00 643853.00 70 19 47.322 N 148 49 59.512 W -Polygon 1 0.00 1018.67 1400.70 5971578.00 643853.00 70 19 47.322 N 148 49 59.512 W -Polygon 2 0.00 1273.83 2132.74 5971847.00 644580.00 70 19 49.830 N 148 4938.138 W J-25A Fault 3 0.00 354.83 645.90 5970900.00 643111.00 70 19 40.794 N 148 5021.550 W -Polygon 1 0.00 354.83 645.90 5970900.00 643111.00 70 19 40.794 N 148 50 21.550 W -Polygon 2 0.00 200.85 115.84 5970736.00 642584.00 70 19 39.280 N 148 50 37.024 W J-25A Fault 2 0.00 305.64 1445.18 5970866.00 643911.00 70 19 40.309 N 148 49 58.218 W -Polygon 1 0.00 305.64 1445.18 5970866.00 643911.00 70 19 40.309 N 148 49 58.218 W -Polygon 2 0.00 400.50 1875.09 5970969.00 644339.00 70 1941.241 N 148 4945.667 W J-25A T6.2 8980.00 364.12 1052.19 5970917.00 643517.00 70 19 40.885 N 148 50 9.690 W J-25A T6.3 8980.00 979.46 1147.89 5971534.00 643601.00 70 1946.937 N 148 50 6.893 W J-25A T6.1 8985.00 209.87 747.18 5970757.00 643215.00 70 19 39.368 N 148 50 18.594 W Obp . . B.. ...... INTE.Q BP-GDB Baker Hughes INTEQ Planning Report Annotation 8908.90 8689.14 TIP 8910.00 8689.81 KOP 8930.00 8702.31 End 9 DLS / Begin 35 DLS 9010.00 8766.06 4 9060.00 8812.55 5 9110.00 8858.40 6 9342.63 8984.98 7 9372.63 8982.24 8 9402.63 8979.50 End 35 DLS / Begin 12 DLS 10072.63 8979.50 10 10300.00 8979.50 TO Plan: Plan #6 Date Composed: 7/22/2004 Identical to Lamar's Plan #6 Version: 3 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 8908.90 52.17 52.25 8689.14 173.44 502.52 0.00 0.00 0.00 0.00 8910.00 52.21 52.27 8689.81 173.97 503.21 3.91 3.64 1.82 21.56 8930.00 50.41 52.27 8702.31 183.52 515.56 9.00 -9.00 0.00 180.00 9010.00 22.41 52.27 8766.06 212.29 552.74 35.00 -35.00 0.00 180.00 9060.00 22.94 98.73 8812.55 216.68 570.05 35.00 1.06 92.92 110.00 9110.00 26.02 141.19 8858.40 206.57 586.68 35.00 6.16 84.91 100.00 9342.63 90.00 71.07 8984.98 204.12 758.65 35.00 27.50 -30.14 288.00 9372.63 100.50 71.07 8982.24 213.80 786.87 35.00 35.00 0.00 0.00 9402.63 90.00 71.07 8979.50 223.48 815.09 35.00 -35.00 0.00 180.00 10072.63 90.00 350.67 8979.50 752.55 1131.31 12.00 0.00 -12.00 270.00 10300.00 90.00 17.95 8979.50 977.14 1148.23 12.00 0.00 12.00 90.00 Survey 8908.90 52.17 52.25 8689.14 173.44 502.52 5970715.93 642971.10 451.03 0.00 0.00 TIP 8910.00 52.21 52.27 8689.81 173.97 503.21 5970716.48 642971.78 451.88 3.91 21.56 KOP 8925.00 50.86 52.27 8699.14 181.15 512.50 5970723.84 642980.93 463.31 9.00 180.00 MWD 8930.00 50.41 52.27 8702.31 183.52 515.56 5970726.26 642983.94 467.07 9.00 180.00 End 9 Dl 8950.00 43.41 52.27 8715.97 192.45 527.10 5970735.41 642995.31 481.28 35.00 180.00 MWD 8975.00 34.66 52.27 8735.37 202.08 539.54 5970745.27 643007.57 496.59 35.00 180.00 MWD 9000.00 25.91 52.27 8756.94 209.79 549.50 5970753.17 643017.38 508.85 35.00 180.00 MWD 9010.00 22.41 52.27 8766.06 212.29 552.74 5970755.73 643020.57 512.83 35.00 180.00 4 9025.00 21.17 66.05 8780.00 215.14 557.48 5970758.67 643025.25 518.03 35.00 110.00 MWD 9050.00 21.79 90.04 8803.30 216.97 566.26 5970760.67 643034.00 524.98 35.00 97.20 MWD 9060.00 22.94 98.73 8812.55 216.68 570.05 5970760.44 643037.78 527.13 35.00 74.83 5 9075.00 22.60 112.29 8826.40 215.14 575.61 5970759.01 643043.37 529.43 35.00 100.00 MWD 9100.00 24.51 133.79 8849.35 209.72 583.81 5970753.75 643051.68 530.38 35.00 87.49 MWD 9110.00 26.02 141.19 8858.40 206.57 586.68 5970750.66 643054.61 529.75 35.00 67.74 6 9125.00 28.06 130.53 8871.77 201.71 591.43 5970745.89 643059.45 528.96 35.00 288.00 MWD 9150.00 32.95 116.16 8893.33 194.88 602.02 5970739.26 643070.16 530.31 35.00 297.50 MWD 9175.00 39.08 105.50 8913.56 189.77 615.74 5970734.41 643083.98 534.98 35.00 309.91 MWD 9200.00 45.94 97.44 8931.99 186.49 632.28 5970731.45 643100.57 542.84 35.00 318.56 MWD 9225.00 53.25 91.11 8948.20 185.13 651.23 5970730.45 643119.55 553.71 35.00 324.51 MWD 9250.00 60.84 85.91 8961.79 185.72 672.18 5970731.43 643140.48 567.34 35.00 328.62 MWD 9275.00 68.60 81.43 8972.46 188.23 694.62 5970734.38 643162.86 583.42 35.00 331.46 MWD 9300.00 76.47 77.41 8979.96 192.63 718.03 5970739.21 643186.19 601.57 35.00 333.38 MWD 9325.00 84.39 73.65 8984.12 198.79 741.88 5970745.82 643209.91 621.37 35.00 334.59 MWD 9342.63 90.00 71.07 8984.98 204.12 758.65 5970751.48 643226.58 636.07 35.00 335.21 7 ObP . . B.. ..... IN1'E.Q BP-GDB Baker Hughes INTEQ Planning Report Survey 9350.00 92.58 71.07 8984.81 206.51 765.62 5970754.00 643233.50 642.31 35' 0.00 MWD 9372.63 100.50 71.07 8982.24 213.80 786.87 5970761.69 643254.61 661.35 35.00 0.00 8 9375.00 99.67 71.07 8981.82 214.56 789.07 5970762.49 643256.80 663.32 35.00 180.00 MWD 9400.00 90.92 71.07 8979.52 222.63 812.60 5970771.00 643280.16 684.40 35.00 180.00 MWD 9402.63 90.00 71.07 8979.50 223.48 815.09 5970771.90 643282.63 686.63 35.00 180.00 End 35 C 9425.00 90.00 68.38 8979.50 231.23 836.07 5970780.05 643303.46 705.86 12.00 270.00 MWD 9450.00 90.00 65.38 8979.50 241.05 859.06 5970790.30 643326.26 727.95 12.00 270.00 MWD 9475.00 90.00 62.38 8979.50 252.05 881.50 5970801.72 643348.49 750.63 12.00 270.00 MWD 9500.00 90.00 59.38 8979.50 264.22 903.34 5970814.30 643370.09 773.82 12.00 270.00 MWD 9525.00 90.00 56.38 8979.50 277.51 924.51 5970827.99 643391.00 797.48 12.00 270.00 MWD 9550.00 90.00 53.38 8979.50 291.88 944.96 5970842.75 643411.17 821.52 12.00 270.00 MWD 9575.00 90.00 50.38 8979.50 307.31 964.62 5970858.55 643430.54 845.89 12.00 270.00 MWD 9600.00 90.00 47.38 8979.50 323.75 983.46 5970875.34 643449.06 870.51 12.00 270.00 MWD 9625.00 90.00 44.38 8979.50 341.15 1001.40 5970893.08 643466.67 895.33 12.00 270.00 MWD 9650.00 90.00 41.38 8979.50 359.47 1018.41 5970911.72 643483.33 920.27 12.00 270.00 MWD 9675.00 90.00 38.38 8979.50 378.65 1034.44 5970931.20 643498.99 945.26 12.00 270.00 MWD 9700.00 90.00 35.38 8979.50 398.65 1049.44 5970951.47 643513.60 970.24 12.00 270.00 MWD 9725.00 90.00 32.38 8979.50 419.40 1063.38 5970972.48 643527.14 995.14 12.00 270.00 MWD 9750.00 90.00 29.38 8979.50 440.85 1076.21 5970994.17 643539.56 1019.89 12.00 270.00 MWD 9775.00 90.00 26.38 8979.50 462.95 1087.90 5971016.48 643550.83 1044.42 12.00 270.00 MWD 9800.00 90.00 23.38 8979.50 485.62 1098.42 5971039.36 643560.92 1068.66 12.00 270.00 MWD 9825.00 90.00 20.38 8979.50 508.82 1107.74 5971062.72 643569.79 1092.55 12.00 270.00 MWD 9850.00 90.00 17.38 8979.50 532.47 1115.83 5971086.52 643577.43 1116.02 12.00 270.00 MWD 9875.00 90.00 14.38 8979.50 556.51 1122.67 5971110.69 643583.81 1139.01 12.00 270.00 MWD 9900.00 90.00 11.38 8979.50 580.88 1128.24 5971135.16 643588.92 1161.46 12.00 270.00 MWD 9925.00 90.00 8.38 8979.50 605.51 1132.53 5971159.86 643592.74 1183.29 12.00 270.00 MWD 9950.00 90.00 5.38 8979.50 630.33 1135.53 5971184.72 643595.27 1204.46 12.00 270.00 MWD 9975.00 90.00 2.38 8979.50 655.27 1137.22 5971209.69 643596.48 1224.91 12.00 270.00 MWD 10000.00 90.00 359.38 8979.50 680.26 1137.60 5971234.68 643596.39 1244.58 12.00 270.00 MWD 10025.00 90.00 356.38 8979.50 705.24 1136.68 5971259.64 643595.00 1263.41 12.00 270.00 MWD 10050.00 90.00 353.38 8979.50 730.14 1134.45 5971284.49 643592.30 1281.36 12.00 270.00 MWD 10072.63 90.00 350.67 8979.50 752.55 1131.31 5971306.84 643588.73 1296.80 12.00 270.00 10 10075.00 90.00 350.95 8979.50 754.89 1130.93 5971309.17 643588.31 1298.38 12.00 90.00 MWD 10100.00 90.00 353.95 8979.50 779.67 1127.65 5971333.88 643584.55 1315.57 12.00 90.00 MWD 10125.00 90.00 356.95 8979.50 804.58 1125.67 5971358.75 643582.10 1333.68 12.00 90.00 MWD 10150.00 90.00 359.95 8979.50 829.57 1124.99 5971383.72 643580.95 1352.68 12.00 90.00 MWD 10175.00 90.00 2.95 8979.50 854.56 1125.62 5971408.71 643581.11 1372.50 12.00 90.00 MWD 10200.00 90.00 5.95 8979.50 879.48 1127.56 5971433.67 643582.57 1393.09 12.00 90.00 MWD 10225.00 90.00 8.95 8979.50 904.27 1130.81 5971458.51 643585.34 1414.39 12.00 90.00 MWD 10250.00 90.00 11.95 8979.50 928.85 1135.34 5971483.17 643589.41 1436.35 12.00 90.00 MWD 10275.00 90.00 14.95 8979.50 953.16 1141.15 5971507.59 643594.76 1458.90 12.00 90.00 MWD 10300.00 90.00 17.95 8979.50 977.14 1148.23 5971531.69 643601.38 1481.99 12.00 90.00 TO Nordic 1 bighole All Measurements are from top of Riser 7/21/2004 ~ CD (/) a: bUm of bag BAG 7 1/16" 5000psi top of bag middle of slips Blind/Shears .......................... middle of pipes .23/8" combi ram/slips I I TOTs I.................········· 7 1/16" 5000psi ......---. ......-. middle of flow cross Mud Cross Mud Cross 71/16" 5000psi -- ----' middle of blind/shears I variable bore pipe :3 1/2"-27/8" I 23/8" combi ram/slips I'· ........................ TOTs I ..................·····7 1/16" 5000psi ..' middle of pipe/slips \ ;. "F-· <,.! "¡¡<~ Flow Tee . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /!If 0f (F/s/l PTD# 209-;:?~ Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API Dum ber last two (2) digits are between 60-69) PILOT (PH) Exploration Stratigraphic ·'CLUEn The permit is for a new weJJbore segment of existing well' . Permit No, .' API No. Production. should continue to be reported as a function 'of tbe original API number. stated above. HOLE In accordance with 20 AAC 25.005(f), an records, data and logs acquired for tbe pilot bole must be clearly differentiated 'in both name (name on permit plus PH) and API Dum ber (SO 70/80) from records, data and logs acquired for we)) (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fuO compliance with 20 AAC 25.055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing eneption. {Company Name) assumes tbe liability of any protest to tbe spacing ,exception tbat may occur. All dry ditch sample sets submitted to the Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from where samples are fint caugbt and ] 0' sample inter-va)s tbrougb target Zones. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT J-25A Program DEV PTD#: 2041380 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV / 1-01l GeoArea 890 Unit 11650 On/Off Shore On Administration 1 Permittee attachej:!_ Yes - - - - - - 2 lease number appropriate_ _ - - - - - - Yes_ 3 _U_nique well_n_ame_and ol!mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ Yes __ - . - - - - - - - - - - - - - - - - - - 4 We.lUocated ina qefine~ -poo) Yes _ - - - - - ~ - - - - - 5 WeJUocated pcoper _distance_ from driJling unitb_ound_al)' _ _ _ Yes_ 6 WelUocated prpper _distance from other wells_ _ Yes 7 _S_ufficient acrea~e_aYailable indrilJio~ unit. _ _ _ _ _ Yes_ - - - -- 8 Jtdeviated, is_ weJlbore platincJuded _ - - - - - - _ Yes_ 9 O-per_ator only: affected party _ _ - - -- - - - - - - _Yes _ 10 _O-pecator bas_apprppriate_b.ond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . - - - _ Yes__ - - - - - - - - - - - - - - - - - . - - 11 Permit can þe issl!ed without conservation order - - -- yes_ Appr Date 12 Permit c_an Þe issued witbout ad_ministratille_a-pprpvaJ _ _ _ Yes - - - - 4C 7/26/2004 13 Can permit be approved before 15-day wait Yes 14 WeJUocated within area andstrç¡taautOQrizeq by_'njection Order #I (puUO# in_cpmments>-(For_ _NA _ _ - - - - - 15 _AJlwells_witJ1lnJl4JlJile_area_oJreyiewideotlfied(Fprservjcewe!lonlYL _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA __ - - - - - - - - - - - -. - - - - - - - 16 Pre-produ~eq injector; tluratiQn_of pre.,protluction Less_ toan 3 montbs. (Forßervlce well onJy) _ _ _NA - - - -- 17 _ACMP. finding.of Con_si$tencyhas ÞeeJlJssued for_ tbis pr_oject - - - - -- _NA - - - - - Engineering 18 _C_oodu_ctor string_provided _ - - - - - _NA _ 19 _Surface _cç¡sin9_protects_ all_known USOWs _ _ _NA - - - - - - - - - - 20 _CMTv_oladeQl!ateJocirculateon_cond_uctoC&SUJtC$g _ . _ _ _ . _ _ _NA - - - - - - - - - - 21 _CMTvpladeQu_ateJo tie-iJlJongstring to surf csg_ _ _ _ - - - - - - - - -- _NA _ 22 _CMT will coyera]l j<r)ownpro_ductiye bori~on_s_ - - - - - - Yes_ - - - - 23 _Casing de_signs ad_equate fpr CoT, B&_ permafr_ost _ Yes - - - -- 24 _Atlequatetan_kage OJ re_serve pit _ Yes_ CTOU. 25 Jta_re-j:!rilt oasa_ to-403 for abandonme_nt beeo apPJQved _ Yes * - - - - - - - - - - - - -- 26 Adequatewe!lb.ore_separatio_n_pro-posed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YeS_ - - - - - - - - - - - - - - - - - - - - 27 Jtdjvei1er req_uired, does it meet reguJations_ - - - - - - - - - - - - _ NA Sidetrack. _ Appr Date 28 Drillio9 fluid_program schemç¡tic_& eCluipJistadequate_ _ _ _ Yes Mç¡x MW_8~9 ppg. WGA 7/26/2004 29 _BPPEs,.d_othey meet reguJation . - - - - - - - -- · Yes . 30 _BOPE_press ratill9 ap-propriate; test to (pu_t psig i-" _comlJ1ents)_ · .Yes T~st to 35QO psi. _MSF' 2290 psi. 31 _Choke_manifold compJies w/API RF'-53 (May 84>- _ . . _ _ · .Yes 32 Work will occ_ur withoytoperatio-" _sOutdow.n_ _ . _ _ Yes 33 Js presence Qf H2S gas prob_aÞle _ _ . - - - - - - - - - - - · Yes 60_ ppm. 34 Meçbanicalcond.ition pt wells within ,1\013. yeriJied (For_s_ervjce welJ only)_ - - - - - NA Geology 35 Permit c_an Þe issued wlo hYdrogen_ s.ulfide measu(e~ _ No_ 36 _D_ata_PJesellted on pote_ntial oveJpres_sure _zones _ . _ _ _ _ . · NA Appr Date 37 _Seism[ca-"alysjs Qf ~baJlow gaszplles _ .NA - - - - - - RPC 7/26/2004 38 _Seabed .conditioo survey (if off-shore) . . .NA - - - - - - - - - - - - - - -- ~ ':"""~" ,,"'¡phonefQ, """'''''''''''",'0''' (''''''''.10'''0,.1 ~ ~ ~ ~ ~ ~ . ~ . J~A ~ ~ ~ E",neo"", c~r \ 'f\J~\~~ Comm.,'on" D,,. 0 ',,"e< '\ ~ \:~ Well bore seg D Annular Disposal D e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infonnation. . Sperry-Sun Drilling Services LIS Scan Utility . ~ðrfl.$7 $Revision: 3 $ LisLib $Revision: 4 $ Thu Oct 28 15:05:15 2004 11 (lÎt¡} Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............. ...UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments............. ... .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. ........... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.. .... ......... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA J-25A 500292174101 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 28-0CT-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003220865 S. LATZ EGBEJIMBA/KO MWD RUN 2 MW0003220865 S. LATZ EGBEJIMBA/KO MWD RUN 3 MW0003220865 S. LATZ EGBEJIMBA/KO JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003220865 S. LATZ EGBEJIMBA/KO MWD RUN 5 MW0003220865 B. JAHN KOLSTAD/HOLT MWD RUN 6 MW0003220865 B. JAHN KOLSTAD/HOLT # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 9 llN 13E 800 1881 77.10 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 5.500 8919.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE J-25 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 8912'MD/8691'TVDSS¡ THE BOTTOM WAS AT 8919'MD/8695'TVD. 5. MWD RUNS 1 - 6 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4). 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN ON 13 AUGUST 2004. THESE LOG DATA WERE PROVIDED BY K. COONEY (SIS/BP) ON 18 OCTOBER 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 6 REPRESENT WELL J-25A WITH API#: 50-029-21741-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10306'MD/8971'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP == SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY ( SHALLOW SPACING) . SEMP == SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP == SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE == SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name.......... ...STSLIB.OOl Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..04/10/28 Maximum Physical Record..65535 File Type........... .....LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves¡ all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ . START DEPTH 8706.5 8900.5 8900.5 8900.5 8900.5 8900.5 8935.5 STOP DEPTH 10258.0 10272.0 10272.0 10272.0 10272.0 10272.0 10302.5 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH 8706.5 8707.5 8711.5 8714.0 8716.5 8720.0 8723.5 8725.0 8728.0 8732.5 8734.5 8737.5 8740.0 8744.5 8747.0 8748.5 8752.5 8757.0 8759.0 8865.5 8890.0 8901. 5 8905.5 8921.5 8923.5 8927.0 8978 . 5 8981.0 9001. 5 9004.0 9006.0 9014.5 9028.5 9038.0 9040.5 9046.5 9054.0 9059.0 9067.5 9083.5 9086.0 9088.0 9112.5 9116.5 9120.0 9137.0 9147.0 9155.0 9171.0 9197.5 9214.0 9222.0 9225.0 9229.5 GR 8707.0 8708.0 8710.0 8711.5 8714.0 8718.0 8721.0 8722.5 8726.0 8730.5 8734.5 8737.0 8739.5 8743.0 8745.0 8747.0 8751.0 8755.0 8756.0 8866.0 8891. 5 8902.5 8907.5 8919.5 8921. 0 8923.5 8978.0 8979.5 8998.0 9000.5 9002.0 9011.5 9029.5 9036.5 9038.0 9043.0 9050.5 9055.5 9065.5 9081. 0 9082.5 9085.0 9111.0 9114.5 9117.0 9136.0 9145.0 9152.5 9170.0 9199.0 9213.5 9221.0 9223.5 9227.0 9238.5 9241.5 9250.5 9255.5 9259.0 9265.0 9274.5 9282.5 9294.0 9306.0 9321.0 9331. 5 9347.5 9364.0 9369.5 9379.0 9384.5 9387.5 9390.0 9409.0 9424.5 9435.0 9444.5 9449.0 9480.5 9491.0 9501. 0 9511. 0 9517.5 9521. 5 9524.0 9527.0 9533.5 9543.5 9550.0 9596.0 9608.5 9671.5 9697.0 9710.5 9751.0 9804.0 9808.5 9828.0 9850.5 9860.5 9894.5 9900.0 9908.5 9937.0 9971.0 9998.5 10018.5 10033.0 10039.5 10050.5 10063.5 10116.5 10121.0 10138.5 10149.0 10164.0 10185.5 10302.5 $ # MERGED DATA SOURCE PBU TOOL CODE . 9234.5 9236.0 9246.0 9251.5 9256.0 9263.5 9271. 0 9280.0 9292.0 9304.0 9321.0 9331. 0 9346.5 9362.0 9366.5 9373.5 9384.5 9387.0 9389.0 9406.5 9421.0 9429.5 9440.0 9444.0 9478.5 9489.5 9501.0 9514.5 9521.0 9524.5 9526.0 9527.5 9534.0 9543.0 9550.5 9600.0 9611.0 9675.0 9701.0 9713.5 9754.0 9806.5 9812.0 9828.5 9850.5 9858.0 9896.5 9902.5 9909.0 9935.5 9970.0 9997.5 10018.0 10034.0 10038.5 10049.5 10062.5 10112.0 10118.0 10137.0 10148.5 10166.0 10189.5 10306.0 BIT RUN NO MERGE TOP . MERGE BASE . . MWD MWD MWD MWD MWD MWD $ 1 2 3 4 5 6 8707.0 9102.0 9150.0 9405.0 9558.0 9805.0 9102.0 9150.0 9405.0 9558.0 9805.0 10306.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type. ....0 Logging Direction............ .....Down Optical log depth units.. .... ... ..Feet Data Reference Point... ......... ..Undefined Frame Spacing.... .... ..... ...... ..60 .1IN Max frames per record.. .......... . Undefined Absent value.................... ..-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8706.5 10302.5 9504.5 3193 8706.5 10302.5 ROP MWD FT/H 0.26 1033.42 103.68 2735 8935.5 10302.5 GR MWD API 12.52 301. 07 53.2417 2862 8706.5 10258 RPX MWD OHMM 0.28 1720.88 13.1055 2744 8900.5 10272 RPS MWD OHMM 0.1 2000 21.7783 2744 8900.5 10272 RPM MWD OHMM 0.12 2000 26.2767 2744 8900.5 10272 RPD MWD OHMM 0.14 2000 27.1045 2744 8900.5 10272 FET MWD HOUR 0.21 7.78 1.70926 2744 8900.5 10272 First Reading For Entire File......... .8706.5 Last Reading For Entire File......... ..10302.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/28 Maximum Physical Record..65535 File Type.......... ..... .LO Next File Name... ....... .STSLIB.002 Physical EOF File Header Service name........ ... ..STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 . Date of Generation.. .... .04/10/28 Maximum Physical Record..65535 File Type....... ...... ...LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPX RPS RPD RPM ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 8707.0 8901. 5 8901. 5 8901. 5 8901. 5 8901. 5 8932.5 STOP DEPTH 9058.0 9071.0 9071.0 9071.0 9071.0 9071.0 9102.0 # 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 VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD 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): 09-AUG-04 Insite 4.3 Memory 9102.0 8932.0 9102.0 19.3 52.3 TOOL NUMBER 78012 171170 4.125 8919.0 Flo Pro 8.70 65.0 9.0 20000 5.5 .150 .080 .160 .210 70.0 144.0 70.0 70.0 . . # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction..... ........... . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ... . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 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 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8707 9102 8904.5 791 8707 9102 ROP MWD010 FT/H 0.585 118.89 61.4697 340 8932.5 9102 GR MWD010 API 12.52 301.07 26.6957 452 8707 9058 RPX MWD010 OHMM 0.28 1720.88 36.459 340 8901.5 9071 RPS MWD010 OHMM 0.1 2000 85.0435 340 8901.5 9071 RPM MWD010 OHMM 0.12 2000 110.519 340 8901. 5 9071 RPD MWD010 OHMM 0.13 2000 119.697 340 8901.5 9071 FET MWD010 HOUR 0.42 3.12 1.21394 340 8901. 5 9071 First Reading For Entire File......... .8707 Last Reading For Entire File....... ....9102 File Trailer Service name.. .......... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. .... ..04/10/28 Maximum Physical Record. .65535 File Type............ ....LO Next File Name.. ....... ..STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation... ....04/10/28 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER . FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 9058.5 9071.5 9071.5 9071.5 9071.5 9071 . 5 9102.5 STOP DEPTH 9106.5 9120.0 9120.0 9120.0 9120.0 9120.0 9150.0 # 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 VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD 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): # REMARKS: $ # Data Format Specification Record Data Record Type.. ...... ..........0 Data Specification Block Type.....O 09-AUG-04 Insite 4.3 Memory 9150.0 9102.0 9150.0 21.8 21.8 TOOL NUMBER 78012 171170 4.125 8919.0 Flo Pro 8.70 65.0 9.0 20000 5.5 .150 .070 .160 .210 70.0 150.0 70.0 70.0 . Logging Direction................ . Down Optical log depth units...... .....Feet Data Reference Point..... ....... ..Undefined Frame Spacing.... ..... ... ........ .60 .1IN Max frames per record............ . Undefined Absent value. .................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9058.5 9150 9104.25 184 9058.5 9150 ROP MWD020 FT/H 0.26 97.48 40.2295 96 9102.5 9150 GR MWD020 API 14.2 43.31 24.7327 97 9058.5 9106.5 RPX MWD020 OHMM 4.68 41.16 13.2473 98 9071.5 9120 RPS MWD020 OHMM 7.23 40.9 16.9137 98 9071 . 5 9120 RPM MWD020 OHMM 9.16 42.31 19.5914 98 9071.5 9120 RPD MWD020 OHMM 12.65 36.51 20.8033 98 9071.5 9120 FET MWD020 HOUR 0.65 7.78 5.09061 98 9071.5 9120 First Reading For Entire File........ ..9058.5 Last Reading For Entire File.......... .9150 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation..... ..04/10/28 Maximum Physical Record. .65535 File Type............. ...LO Next File Name..... .., ...STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .04/10/28 Maximum Physical Record. .65535 File Type............. ...LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY 4 header data for each bit run in separate files. 3 .5000 VENDOR TOOL CODE GR RPX RPS FET RPD RPM ROP $ . START DEPTH 9107.0 9120.5 9120.5 9120.5 9120.5 9120.5 9150.5 STOP DEPTH 9360.5 9374.5 9374.5 9374.5 9374.5 9374.5 9405.0 # 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 VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD 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): # REMARKS: $ # Data Format Specification Record Data Record Type. .................0 Data Specification Block Type.....O Logging Direction... .... ......... . Down Optical log depth units.......... .Feet Data Reference Point.. ........ ....Undefined Frame Spacing.... ....... ......... .60 .1IN Max frames per record............ . Undefined Absent value........ .... ......... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . . 10-AUG-04 Insite 4.3 Memory 9405.0 9150.0 9405.0 27.8 94.4 TOOL NUMBER 78012 171170 4.125 8919.0 Flo Pro 8.70 65.0 8.5 20000 5.2 .190 .090 .190 .120 70.0 155.0 70.0 70.0 . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9107 9405 9256 597 9107 9405 ROP MWD030 FT/H 1. 97 128.13 73.1348 510 9150.5 9405 GR MWD030 API 17.96 141.64 39.9084 508 9107 9360.5 RPX MWD030 OHMM 3.93 23.21 9.12293 509 9120.5 9374.5 RPS MWD030 OHMM 4.52 28.25 10.1452 509 9120.5 9374.5 RPM MWD030 OHMM 4.8 29.72 11.0364 509 9120.5 9374.5 RPD MWD030 OHMM 6.17 27.52 11.331 509 9120.5 9374.5 FET MWD030 HOUR 0.31 5.92 1.80138 509 9120.5 9374.5 First Reading For Entire File... ...... .9107 Last Reading For Entire File....... ....9405 File Trailer Service name......... ....STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/10/28 Maximum Physical Record..65535 File Type........ ....... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name.. .......... .STSLIB.005 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .04/10/28 Maximum Physical Record. .65535 File Type........... .... .LO Previous File Name. ..... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX 5 header data for each bit run in separate files. 4 .5000 START DEPTH 9361.0 9375.0 9375.0 9375.0 9375.0 9375.0 STOP DEPTH 9513.5 9528.0 9528.0 9528.0 9528.0 9528.0 ROP $ . 9405.5 9558.0 # 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 VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTRO MAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD 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): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing................. ....60 .1IN Max frames per record. ........ ....Undefined Absent value.......... .... ........-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR RPX Service Order Code MWD040 MWD040 MWD040 Units Size Nsam Rep FT 4 1 68 FT/H 4 1 68 API 4 1 68 OHMM 4 1 68 . 10-AUG-04 Insite 4.3 Memory 9558.0 9405.0 9558.0 90.2 96.1 TOOL NUMBER 78012 171170 4.125 8919.0 Flo Pro 8.70 65.0 8.5 20000 5.2 .190 .090 .190 .120 70.0 155.9 70.0 70.0 Offset o 4 8 12 Channel 1 2 3 4 . . RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9361 9558 9459.5 395 9361 9558 ROP MWD040 FT/H 1. 02 237.06 72.4852 306 9405.5 9558 GR MWD040 API 29.69 163.6 54.2002 306 9361 9513.5 RPX MWD040 OHMM 5.36 14.28 8.50762 307 9375 9528 RPS MWD040 OHMM 5.71 13.43 8.84625 307 9375 9528 RPM MWD040 OHMM 6.2 13.66 9.4842 307 9375 9528 RPD MWD040 OHMM 8.05 12.89 10.2611 307 9375 9528 FET MWD040 HOUR 0.46 7.97 2.45059 307 9375 9528 First Reading For Entire File... ...... .9361 Last Reading For Entire File.......... .9558 File Trailer Service name......... ... .STSLIB.005 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation.... ...04/10/28 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name.......... ...STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/28 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 9514.0 9528.5 9528.5 9528.5 9528.5 9528.5 9558.5 STOP DEPTH 9760.5 9775.0 9775.0 9775.0 9775.0 9775.0 9805.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 11-AUG-04 Insite . 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 VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD 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): # REMARKS: $ # Data Format Specification Record Data Record Type..... ......... ....0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . .Down Optical log depth units...........Feet Data Reference Point....... ...... . Undefined Frame Spacing. ................... .60 .1IN Max frames per record. ........ ....Undefined Absent value....... ..... ......... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 4.3 Memory 9805.0 9558.0 9805.0 . 87.8 92.9 TOOL NUMBER 78012 171170 3.750 8919.0 Flo Pro 8.60 65.0 9.5 21000 10.8 .155 .070 .175 .170 70.0 153.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDOSO FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWDOSO OHMM 4 1 68 12 4 RPS MWDOSO OHMM 4 1 68 16 5 RPM MWDOSO OHMM 4 1 68 20 6 RPD MWDOSO OHMM 4 1 68 24 7 FET MWDOSO HOUR 4 1 68 28 8 · 1st Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9514 9805 9659.5 583 9514 9805 ROP MWD050 FT/H 33.57 869.95 140.982 494 9558.5 9805 GR MWD050 API 29.55 190.7 60.105 494 9514 9760.5 RPX MWD050 OHMM 6.07 12.47 8.93708 494 9528.5 9775 RPS MWD050 OHMM 6.56 12.56 9.27492 494 9528.5 9775 RPM MWD050 OHMM 7.26 13.17 9.81358 494 9528.5 9775 RPD MWD050 OHMM 7.48 12.91 9.73356 494 9528.5 9775 FET MWD050 HOUR 0.21 7.4 1. 41597 494 9528.5 9775 First Reading For Entire File...... ....9514 Last Reading For Entire File.......... .9805 File Trailer Service name....... .... ..STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/28 Maximum Physical Record. .65535 File Type......... ..... ..LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name........ .....STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .....04/10/28 Maximum Physical Record. .65535 File Type........... .....LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 7 header data for each bit run in separate files. 6 .5000 START DEPTH 9761.0 9775.5 9775.5 9775.5 9775.5 9775.5 9805.5 STOP DEPTH 10261.5 10275.5 10275.5 10275.5 10275.5 10275.5 10306.0 # 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 12 -AUG-04 Insite 4.3 Memory 10306.0 9805.0 10306.0 . MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD 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): # 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 .1IN Max frames per record......... ... . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 87.7 95.2 . TOOL NUMBER 78012 171170 3.750 8919.0 Flo Pro 8.70 65.0 8.5 20000 4.8 .160 .080 .150 .180 75.0 155.9 75.0 75.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9761 10306 10033.5 1091 9761 10306 ROP MWD060 FT/H 17.53 1033.42 129.787 1002 9805.5 10306 GR MWD060 API 16.54 204.64 70.0693 1002 9761 10261. 5 RPX MWD060 OHMM 3.67 17.23 8.58514 1001 9775.5 10275.5 RPS MWD060 OHMM 3.73 16.09 8.88428 1001 9775.5 10275.5 · _775.5 RPM MWD060 OHMM 3.94 16.21 9.56334 1001 10275.5 RPD MWD060 OHMM 4.83 14.59 9.32429 1001 9775.5 10275.5 FET MWD060 HOUR 0.22 5.99 1. 41623 1001 9775.5 10275.5 First Reading For Entire File......... .9761 Last Reading For Entire File..... ..... .10306 File Trailer Service name.... ........ .STSLIB.007 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation. ..... .04/10/28 Maximum Physical Record. .65535 File Type........... .... .LO Next File Name. ......... .STSLIB.008 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name... .., ......... . UNKNOWN Continuation Number. .... .01 Next Tape Name.. ........ . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.... ........ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.......... ..... .UNKNOWN Continuation Number..... .01 Next Reel Name...... .... .UNKNOWN Comments.... ... ......... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File