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Home My WebLink About202-0017. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 05-32A Extended Perforating w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-001 50-029-22190-01-00 12130 Conductor Surface Intermediate Liner Liner 8800 80 3468 9324 579 3264 11920 20" 10-3/4" 7-5/8" 5-1/2" 3-1/2" 8806 30 - 110 29 - 3497 28 - 9352 9056 - 9635 8866 - 12130 31 - 111 29 - 3496 28 - 8352 8115 - 8587 7969 - 8801 Unknown 470 2090 4790 6280 40530 11920 1490 3580 6890 7740 10160 9964 - 12010 3-1/2" 9.3# 13Cr80 27 - 8879 8803 - 8804 Structural 3-1/2" Baker S-3 Packer 8820 7934 Bo York Operations Manager Dave Bjork david.bjork@hilcorp.com 907.564.4672 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028326 27 - 7979 N/A N/A 177 108 195 2391 2273 1580 1400 305 295 325-218 13b. Pools active after work:Prudhoe Oil No SSSV Installed 8820, 7934 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 1:38 pm, May 15, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.05.15 12:55:26 - 08'00' Bo York (1248) DSR-6/3/25JJL 6/13/25 RBDMS JSB 051525 ACTIVITY DATE SUMMARY 5/9/2025 LRS CTU 2 w/1.75" x .156" WT Blue Coil. Job Objective: Drift/GR/CCL Log & Ext Adperfs Mobilize & MIRU CTU #2, Perform 7 Day BOP test. Nipple up BOPs to well and function test. Make up NS/HES 2.20" logging carrier with 2.65" nozzle & RIH to 10,400.14' CTM. Log up 50 fpm Flag Pink CT @ 10,019.29' CTM. Log up 50 fpm to 8700' CTM. POOH pumping pipe displacement. NO Flow. BD HES GR/CCL logging tools. -9' depth Correction. PT MHA. ***Continue on WSR 5/10/25*** 5/10/2025 LRS CTU 2 w/1.75" x .156" WT Blue Coil. Job Objective: Drift/GR/CCL Log & Ext Adperfs Continues Hole Fill. MIRU HES TCP & Crane. Deploy 295' of 2-1/2" Millennium HES perf guns 6spf 60 degree phasing. RIH and correct depth to top shot then perforate interval 10,070-10,365'. POOH and undeploy guns. FP well with 22bbls of diesel. RDMO CTU. ***Bump Test H2S/LEL Monitors, PT TIW/Safety Joint, Tag Stripper with Coil Connector, Perform Kick Drill w/ Day and Night crew, Verify Safety Joint XO makes up to Perf Gun thread *** ***Job Complete*** Daily Report of Well Operations PBU 05-32A 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 05-32A Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-001 50-029-22190-01-00 ADL 0028326 12130 Conductor Surface Intermediate Liner Liner 8800 80 3468 9324 579 3264 11920 20" 10-3/4" 7-5/8" 5-1/2" 3-1/2" 8806 30 - 110 29 - 3497 28 - 9352 9056 - 9635 8866 - 12130 2430 31 - 111 29 - 3496 28 - 8352 8115 - 8587 7969 - 8801 unknown 470 2090 4790 6280 40530 11920 1490 3580 6890 7740 10160 9964 - 12010 3-1/2" 9.3# 13Cr80 27 - 88798803 - 8804 Structural 3-1/2" Baker S-3 , 8820 , 7934 No SSSV Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY 5-5-2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-218 By Gavin Gluyas at 9:53 am, Apr 11, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.04.11 05:34:45 - 08'00' Bo York (1248) A.Dewhurst 11APR25JJL 4/15/25 Perforating gun not to exceed 500'. Reestablish pressure containment prior to perforating. Perform and document well control drill on each shift using attached standing orders. Ensure well is dead beforebreakingcontainment DSR-4/11/25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.16 11:54:56 -08'00'04/16/25 RBDMS JSB 041725 Ext Add Perf 05-32A PTD:202-001 Well Name:05-32A API Number:50-029-22190-01-00 Current Status:Operable - Producer Rig:CTU Estimated Start Date:5/05/25 Estimated Duration:2days Reg.Approval Req’std?10-403 Date Reg. Approval Rec’vd:Check status Regulatory Contact:Carrie Janowski (907) 564-5179 First Call Engineer:David Bjork (907) 564-4672 (907) 440-0331 Expected Rates Post Work ~4 MMSCFD, 250 BOPD and 2500BWPD Current Bottom Hole Pressure:3,310 psi @ 8,800’ TVD 7.3 PPGE | (Average Ivishak BHP) Maximum Expected BHP:3,310 psi @ 8,800 TVD 7.3 PPGE | (Average Ivishak BHP) Max. Anticipated Surface Pressure:2,430psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1,350 psi (Taken on 4/18/23) Min ID:2.75” #-1/2” XN @ 8,866’ MD Max Angle:99 Deg @ 11,446’ MD, 70 Deg at 9,950’ MD Brief Well Summary: 05-32 was sidetracked in March 2002. 05-32A is a gravity drainage well with open Z1A perfs in the 3-1/2” liner. Unswept Z1A remains unperforated. Current oil and gas rates are low with 94% watercut. Objective:Perforate remaining unswept Z1A interval. Procedure Coiled Tubing 1. MU drift BHA with GR/CCL in 2.25” carrier, drift to 10,400ft. 2. Correlate with attached log information. a. Correct flag and send to OE for confirmation. Coil – Extended Perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 2. Bullhead 1.2x wellbore volume ~120 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 87 bbls b. 3-1/2” tubing/liner – 9,964’ X .0087 bpf = 87 bbls 3. At surface, prepare for deployment of TCP guns. Ext Add Perf 05-32A PTD:202-001 4. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 5.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review standing orders with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. c.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 6.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 2-1/2” Millenium guns or similar Perf Interval (tie-in depths) Lengths Total Gun Length Weight of Gun (lbs) Run #1 10,070’ - 10,365’10,070’ – 10,365’295’~2,590 lbs (8.78 ppf) 7. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 8. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 9. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 10. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 11. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 12. RDMO CTU. 13. Turn well over to Operations POP. Attachments: Wellbore Schematic, Proposed Schematic, Tie-In Log, BOPE and rig-up diagram, Sundry Change Form Ext Add Perf 05-32A PTD:202-001 Current Wellbore Schematic Ext Add Perf 05-32A PTD:202-001 Proposed Wellbore Schematic 10,070’-10,365’ New Perforations Ext Add Perf 05-32A PTD:202-001 Tie-in Log Ext Add Perf 05-32A PTD:202-001 BOP Schematic Ext Add Perf 05-32A PTD:202-001 Ext Add Perf 05-32A PTD:202-001 Ext Add Perf 05-32A PTD:202-001 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date þ .,¿'= . . I. Project Well History File Cov1fage XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection òf the file. ~ ~ - 001 Well History File Identifier , ~ Organizing (done) RESCAN o Two-Sided, "' 11111111111 II III DIGITAL DATA V Diskettes, No. ~ o Maps: OVERSIZED (Scannable) Rescan Needed "' 1111111111 111111 Color items: o Grayscale items: Other. NofType o o o Poor Quality Originals: Other items scannable by large scanner o Other: OVERSIZED (Non-Scannable) o . Logs of various kinds o Other DATE4/tQblþ V\1f 1111/11111111111111 mP = TOTAL PAGES 5:3 NOTES: ~.'.'."" ff ----- . BY: LB Project Proofing ~~.~- DATElfl t5/Dlfl +~ BY: -~~'--- Scanning Preparation I x 30 = 3D BY: BEVERLY ROBIN VINCENT SHERY~INDY DATE: Production Scanning ------ Stage 1 PAGE COUNT FROM SCANNED FILE:' ;55 ~ ....-.- -~-- ¡( {AjECDUNT MA~CHE~ NUMBE",N ~C~:'NG p'REPARATION: _ fES BY: ~V'-' n _ _ ~ DATE: 7/~310lSI Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ï YES BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY . DATE: Isl (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE IlASIS DUE TO QUALITY . GRAYSCALE OR COLOR IMAGES) ReScanned (i/JIJivíâU;¡1 pag~ [!.POCi.1/.1tr()/Jliollj f.c<1l1nillg CDlIJp/el()â) 1111/11111111111111 .:,,~. . -----~_.---- . --~..-1i·~~~.~"':::7-·'--··~ . ---~--------- DA TE: ~. Isl .....;.- W11 :,/ NO NO 1111111111111111111 Quality Checked (don0\ 1111111111111111111 12/1 O/02Rev3NOTScanned. wpd A RECEIVED STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMA ION APR 2 4 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon Li Repair Well Li Plug Perforations LJ Perforate Lf OtherU Mill CIBP Performed: Alter Casing ❑ Pull Tubing0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ 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 0 Exploratory ❑ 202 -001 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22190 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028326 PBU 05 -32A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 12130 feet Plugs measured 11920 feet true vertical 8800.24 feet Junk measured 9063 feet Effective Depth measured 11920 feet Packer measured See Attachment feet true vertical 8806.15 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91 5# H -40 30 - 110 30 - 110 1490 470 Surface 3469 10 -3/4" 46# J -55 29 - 3498 29 - 3495.35 0 0 Intermediate None None None None None None Production 9324 7 -5/8" 29.7# L -80 28 - 9352 28 - 8351.7 6890 4790 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9964 - 9994 feet 10012 - 10037 feet 10380 - 10490 feet 10520 - 10820 feet 10880 - 11080 feet 11200 - 11650 feet 11850 - 12010 feet True Vertical depth 8803.13 - 8812.2 feet 8816.67 - 8821.29 feet 8832.41 - 8834.03 feet 8833.94 - 8843.42 feet 8843.27 - 8840.09 feet 8843.03 - 8817.71 feet 8811.21 - 8803.74 feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.3# 13Cr80 27 - 8879 27 - 7978.68 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): 0 8 8 n n 20 Treatment descriptions including volumes used and final pressure: JUL. SCANNED J 0 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 441 31394 92 0 1252 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 12 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil IISI Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCo 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 Nita Summerhays Email Nita.Summerha s • BP.com Printed Name Nita Summe _ a 1 Title Petrotechnical Data Technician Signatur. Phone 564 -4035 Date 4/24/2013 21.4:0 - i1■-.. . L VLiR R 3DMS APR 2 6 2013 v . -7-ii !I 3 .0e Form 10-404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028326 ACTMVITYDATE f SUMMARY 1' w cope; Y1 : Rig up. BHA Venturi run: Connector 1.9 ", .30', X -over 1.98 ", .36, dual checks. 2.375 ", 1.18', Up Jars 2.25 ", 7.38', Disconnect w /circ sub 2.187 ", 2.24', x -over 2 ", .58',venturi 2.625 ", 6.34', (AOL 18.38). Load well with 1% SLk KCL with Safe lube, RIH with Venturi. 3/30/2013 ***Continued on 03 -31 -13 WSR * ** CTU 8 w/ 1.75" CT. Scope; Mill CIBP. RIH. BHA Venturi run: Connector 1.9 ", .30', X -over 1.98 ", .36, dual checks. 2.375 ", 1.18', Up Jars 2.25 ", 7.38', Disconnect w /circ sub 2.187 ", 2.24', x -over 2 ", .58',venturi 2.625 ", 6.34', (AOL 18.38). Load well with 1% SLk KCL with Safe lube. Shut down pump, leak in reel house. Leak coming from CT connection to hard line in reel house. Freeze protect surface.lines. Discuss contingency plan & well control barriers. Called AK Wells Ops TL. notified situation & discussed options & barriers. Replaced hard line rubber seal on the CT reel to hard line connection. Hard line rubber seal was put in backwards in the connection. On line with pump meth down CT freeze protect. PT hard line connections, resume with vennturi run to CIBP at 11,160. recip several times on top of plug. pooh. (recovered 1 cup of sand and fine metal). RIH w/ BHA #2 1.9" ctc, crossover, 2.375" dfcv, 2.25" up jars, 2.18" disco, 2.375" motor, 2.68" 5 blade Mill (oal= 23.24') to 11,153'. Start milling. 3/31/2013 * *job in progress ** CTU 8 w/ 1.75" CT. Scope; Mill CIBP. RIH. BHA Venturi run: Connector 1.9 ", .30', X -over 1.98 ", .36, dual checks. 2.375 ", 1.18', Up Jars 2.25 ", 7.38', Disconnect w /circ sub 2.187 ", 2.24', x -over 2 ", .58',venturi 2.625 ", 6.34', (AOL 18.38). Load well with 1% SLk KCL with Safe lube. Shut down pump, leak in reel house. Leak coming from CT connection to hard line in reel house. Freeze protect surface.lines. Discuss contingency plan & well control barriers. Called AK Wells Ops TL. notified situation & discussed options & barriers. Replaced hard line rubber seal on the CT reel to hard line connection. Hard line rubber seal was put in backwards in the connection. On line with pump meth down CT freeze protect. PT hard line connections, resume with vennturi run to CIBP at 11,160. recip several times on top of plug. pooh. (recovered 1 cup of sand and fine metal). RIH w/ BHA #2 1.9" ctc, crossover, 2.375" dfcv, 2.25" up jars, 2.18" disco, 2.375" motor, 2.68" 5 blade Mill (oal= 23.24') to 11,153'. Start milling. Continued milling CIBP pushed down to 11611' in progress pushing CIBP to TD. 3/31/2013 * *Continued on 04 -01 -13 WSR ** CTU 8 w/ 1.75" CT. Scope; Mill CIBP. RIH w/ BHA #2 1.9" ctc, crossover, 2.375" dfcv, 2.25" up jars, 2.18" disco, 2.375" motor, 2.68" 5 blade Mill (oal= 23.24') to 11,153'. Start milling. Mill /Push CIBP to 11,882'. Pooh. Phone APE. Decision made to make another run with new mill. RIH w/ BHA; 1.9" ctc, 1.98" crossover, 2.375" dfcv, 2.25" BI -jars, 2.18" disco /circ sub, 2.375" motor, 2.74" DS mill (oat= 23.15' ). Discussed with Production Engineer on progress, agreed to do one more load of fluids. Continue milling & pushing CIBP to TD. 4/1/2013 * *Continued on 04 -02 -13 WSR ** • • Daily Report of Well Operations ADL0028326 CTU 8 w/ 1.75" CT. Scope; Mill CIBP. RIH w/ BHA #2 1.9" ctc, crossover, 2.375" dfcv, 2.25" up jars, 2.18" disco, 2.375" motor, 2.68" 5 blade Mill (oal= 23.24') to 11,153'. Start milling. Mill /Push CIBP to 11,882'. Pooh. Phone APE. Decision made to make another run with new mill. RIH w/ BHA; 1.9" ctc, 1.98" crossover, 2.375" dfcv, 2.25" BI -jars, 2.18" disco /circ sub, 2.375" motor, 2.74" DS mill (oal= 23.15' ). Milled & Pushed CIBP to 11920' CT Measured Depth. POOH. Freeze protect well & CT. 4/2/2013 ** *Job complete*** FLUIDS PUMPED BBLS 268 METH 1810 1% SLK KCL 2078 TOTAL Casing / Tubing Attachment ADL0028326 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H -40 30 - 110 30 - 110 1490 470 LINER 3264 3 -1/2" 9.2# L -80 8866 - 12130 7968.73 - 8800.24 10160 10530 LINER 585 5 -1/2" 17# 13Cr80 9050 - 9635 8110.22 - 8586.06 7740 6280 PRODUCTION 9324 7 -5/8" 29.7# L -80 28 - 9352 28 - 8351.7 6890 4790 TUBING 8852 3 -1/2" 9.3# 13Cr80 27 - 8879 27 - 7978.68 10159 10533 SURFACE 3469 10 -3/4" 46# J -55 29 - 3498 29 3495.35 • • ` • • Packers and SSV's Attachment ADL0028326 SW Name Type MD ND Depscription 05 -32A PACKER 8820 7869.95 3 -1/2" Baker S -3 Packer 05 -32A PACKER 8874 7911.35 5 -1/2" Baker LT Packer . 'MEE= 4-1/16' aw • IDETY NOTES: WELL ANGLE> 70 9950' . UNER. D= FMC CHROME TBG 05-32A --- --- - -- • & R ACTUATOR = AXELSON INITIAL KB. ELE 70.0' BF. ELEV = .NA KOP= 4150' Max Angie = 99° r. 11446' ' ' I 2213' H3-1/2' HES X NP, D = 2.813' I Datum MD= Datum WO = 8800' SS 110 -3/4" CSG, 45.5#, J-55, D = 9.950° H 349T GAS LFT MANDRELS ST MD WD - DEV 'TYPE VLV LATCH PORT DATE 5 3241 3239 3 MMG DMY RK 0 02/21/05 4 4844 4796 27 MNG DAY FE 0 02/21/05 3 6321 5997 38 MMG OW RK 0 09/28/03 2 7609 6997 39 WAG DAY RFC 0 09/28/03 Minimum ID = 2.750" @ 8866' 1 8737 7870 40 MMG 0M' RK 0 09/28/03 3 -1/2" HES XN NIPPLE I I I 8797' H3 -1/2' HES X NP, D = 2.813" 8820' 1_17-518* X 3-1/2" BKR S-3 RCR, D= 2.920" I I 1 I 8848' H3-1/2* HES X NP, D= 2.813" I I 88$6' H3- 1/2" Fes XN MP, D= 2.750' I TOP OF BKR TEBACK SLV, D = 5.750" H 8888' I - 1 , 8878' H3- 112" TBG, 9.3#, 13-CR-80, .0087 bpf, ID= 2.992' 17-5/8' X 5-1/7' BKR LT RCR, D = 4.937" H 8874' ;_ 8879' 3-1/2" W EG, D = 2.992" I7 -5/8' X 5-1/2' BKR LNR HGR, D = 4.830' H 8888' I-- ` I 8883' H5 -112" BAKER RS NP, D = 4.875" I I 8895' H5 -1/2' X 3-1/2" LNR XO, D = 2.975" I ITOP OF TEBACK SLV H 9058' I I7 - 5/8' X 5-1/2" LNR HGR H 9063' I ? ? ?? FISH, KO TOOL ARM, KICK SPRING 7-5/8° CSG, 29.7 #, L -80, D = 6.875" H 8352' I — A (1/8" X 3/4° X 4 -1/2°) PERFORATION SUMMARY 5-1/2" LNR MLLOUT WINDOW REF LOG: TCP PEiF 9635' - 9647' (OFF VVHPSTOCK) ANGLE AT TOP PEiF: 89° • 10380' f. ` Nbte: Refer to F toduction DB for historical perf data SIZE SW INTERVAL Opn/Sqz SHOT SOZ 2 -1/2' 6 9964 - 9994 0 04/11/06 • 2 -1/2' 4 9910 - 9934 C" 08/28/91 2 -1/2' 6 10012 -10037 0 04/11/06 2" 4 11850 -12010 C 03/06/02 11920' CTMD I — 3-1'T WFD CBP 2" 4 11200 - 11650 C 03/06/02 IA-LED & PUSHED 2" 4 10880 -11080 0 03/06/02 (04/02/13) 2" 4 10520 -10820 0 03/06/02 2" 4 10380 -10490 0 03/06/02 740 i ih, , "PERM BELOW WHIPSTOCK - PARENT MBA. x'11 f c 1 5-1/2' LW. 170, 13- CR-80. D = 4.897H 10104' ' * * * * * **** * *; I R3TD H 12030' I TO H 10114' 3-1/2' LNR, 9.2#, L -80, .0087 bpf, 13= 2.992" 12130' DATE REV BY COMMITS DATE REV BY COMMENTS PR DHOE BAY MT 07131/91 ORIGINAL COMPLETION 01/17/06 KCF/TLH CEP DESCRPTION ADDED WELL: 05-32A 03/08102 RIG SIDETRACK (05 -32A) 04/17/06 SRB/PAG ADFET FS (04/11/06) PERMT No: "2020010 03/10/02 FIN(TP CORRECTIONS 04/09/13 RMYJMD MLLED & PUSHED MP (04032/13) AR Pb: 50 -029- 22190 -01 05/14/04 BJM. L/KK SET CIBP SEC 32, T11N, R15E, 2549' FTL & 1084' FWL 03/02/05 RMIllLH ASH & GLV CIO (02/21 /05) 12/11 /05 JO/PJC CHROIEIBG CORRECTION BP F3[ploratian (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 May 11, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission AUG 20 333 West 7 Avenue Q Q 1 Anchorage, Alaska 99501 A Subject: Corrosion Inhibitor Treatments of GPB DS -05 (J Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 05 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS-05 Date: 01/10/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date _ inhibitor sealant date ft bbls ft gal 05-01C 1990280 50029201360000 Sealed conductor NA NA N/A N/A NA 05 -02A 2012410 50029201440100 Sealed conductor NA NA N/A N/A NA 05 -03C 2000940 50029201470300 Sealed conductor NA NA N/A N/A NA 05 -04A 1960890 50029201520100 Sealed conductor NA NA N/A N/A NA 05 -05B 1961800 50029201700200 Sealed conductor NA NA N/A N/A NA 05 -06A 1950840 50029201730100 0 NA 0 N/A N/A NA 05 -07 1770130 50029202430000 Sealed conductor NA NA N/A N/A NA 05 -08A 2100550 50029202480100 Sealed conductor NA NA N/A N/A NA 05 -09A 1990140 50029202540100 Sealed conductor NA NA N/A N/A NA 05 -10C 2070980 50029202630300 Sealed conductor NA NA N/A N/A NA 05 -11A 1960970 50029202520100 Sealed conductor NA NA N/A N/A NA 05 -12B 2011800 50029202440200 Sealed conductor NA NA N/A N/A NA 05 -13B 2071460 50029202500200 Sealed conductor NA NA N/A N/A NA 05 -14A 1930820 50029202530100 Sealed conductor NA NA N/A N/A NA 05 -15B 1960230 50029202550200 Sealed conductor NA NA N/A N/A NA 05 -16B 1991000 50029202620200 Sealed conductor NA NA N/A N/A NA 05 -17B 1981040 50029202710200 Sealed conductor NA NA N/A N/A NA 05 -18A 1981740 50029219600100 Split conductor NA NA N/A N/A N/A 05 -19 1890780 50029219620000 1.4 NA 1.4 N/A 8.5 4/11/2011 05 -20B 2042340 50029221370200 1.2 NA 1.2 N/A 5.1 4/18/2011 05-21A 1981180 50029219690100 Dust Cover NA NA N/A N/A N/A 05 -22B 2071260 50029219760200 3.1 NA 3.1 N/A 18.7 4/17/2011 05 -238 2080610 50029219630200 1.2 NA 1.2 N/A 5.1 4/11/2011 05 -24A 2042180 50029222040100 1.5 NA 1.5 N/A 10.2 4/11/2011 05 -25C 2091240 50029219880300 6.0 NA 6.0 N/A 44.2 4/18/2011 05 -26A 2012210 50029219840100 0.5 NA 0.5 N/A 3.4 4/12/2011 05 -27B 2081910 50029219790200 Sealed conductor NA NA N/A N/A N/A 05 -288 2060890 50029222080200 0.6 NA 0.6 N/A 1.7 4/10/2011 05 -30 1911150 50029222130000 1.2 NA 1.2 N/A 10.2 4/11/2011 05-31B 2100850 50029221590200 1.3 NA 1.3 N/A 6.8 4/12/2011 --P 05 -32A 2020010 50029221900100 20.0 6.0 0.5 7/13/2011 3.4 7/23/2011 05 -338 2100810 50029221680200 4.8 NA 4.8 N/A 37.4 4/27/2011 05 -34A 2080370 50029222170100 3.9 NA 3.9 N/A 18.7 1/4/2012 05 -35A 2081340 50029221720100 2.7 NA 2.7 _ N/A 18.7 4/18/2011 05 -36A 2050700 50029221820100 2.3 NA 2.3 N/A 13.6 4/12/2011 05 -38 1961850 50029227220000 1.8 NA 1.8 N/A 15.3 4/10/2011 05 -39 1961730 50029227150000 1.3 NA 1.3 N/A 10.2 4/10/2011 05-40 1961590 50029227070000 1.6 N/A 1.6 N/A 16.2 1/10/2012 05-41A 2031700 50029226960100 5.0 NA 5.0 N/A 58.7 1/8/2012 I I 05-32A (PTD #2020010) UNDER EVALUATION for sustained cas... . . All, Well 05-32A (PTD #2020010) has been found to have sustained casing pressure on the IA. On 06/19/07 the well failed a TIFL following a report that the operator had bled the lAP from 2100 psi to 1320 psi on 06/17/07. The well has been classified as Under Evaluation and may be produced under a 28-day clock. The plan forward is: 1. D: TIFL - FAILED 2. F: MIT-IA to 3000 psi, LLR if fails A well bore schematic has been included for reference. «05-32A. pdf» Please call with any questions or concerns. Paul Austin for Andrea Hughes Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 '1 'lJ)U1 ""1'1\.\1\\1.. en J\j~ 2 S~'SJ'<i¡¡.v Thank you, From: Holt, Ryan P (ASRC) Sent: Tuesday, June 19, 2007 1:18 PM To: NSU, ADW Well Integrity Engineer Cc: Dean, James A Subject: 05-32 Failed TIFL Paul, 05-32 was found with a lAP of 2100 on 06/17/07. The operator bled the pressure to 1320 psi. 05-32 failed a TIFL by FTS & BUR (120 psi / hour) last night. The well has DGLV's installed and a caliper run in '05 indicates the tubing is in decent shape. I recommend swapping the to under evaluation and performing and MIT-IA to 3000 psi. Thanks, iRyan J{oCt BPAJaska \'{7ells Group \\7 ell Site Leader 907.659.5098 Office 943.5028 CeH Content-Description: 05-32A.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6/21/2007 11 :07 AM · 05-32 110-3/4" CSG, 45.5#, J-55, ID = 9.950" I Minimum ID = 2.750" @ 8866' 3-1/2" HES XN NIPPLE TOP OF BKR TIEBACK SLV, ID = 5.750" I 17-5/8" X 5-1/2" BKR L T PKR, ID = 4.937" 1 17-5/8" X 5-1/2" BKR LNR HGR, 10 = 4.830" I I TOP OF TIEBACK SL V I 17-5/8" X 5-112" LNR HGR I 9056' 9063' 17-5/8" CSG, 29.7#, L-80, 10 = 6.875" I 9352' ÆRFORA nON SUMfvtARY REF LOG: TCP ÆRF ANGLE AT TOP ÆRF: 89 @ 10380' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 9964 - 9994 0 04/11/06 2-1/2" 4 9910 - 9934 C'" 08/28/91 2-1/2" 6 10012 - 10037 0 04/11/06 2" 4 11850 - 12010 C 03/06/02 2" 4 11200 - 11650 C 03/06/02 2" 4 10880 - 11080 0 03/06/02 2" 4 10520 - 10820 0 03/06/02 2" 4 10380 - 10490 0 03/06/02 "'PERFS BELOW WHIPSTOCK - PARENT WELL I 5-1/2" LNR, 17#, 13-CR-80, ID = 4.892"1 I TO I OA TE REV BY COMMENTS 07/31/91 ORIGINAL COMPLETION 03108/02 RIG SIDETRACK (05-32A) 03/10í02 RNlTP CORRECTIONS 05114/04 BJMcL/K SET CIBP 03/02/05 RMH/TLH FISH & GLV C/O (02121/05) 12/11105 JD/PJC CHROME TBG CORRECTION ST MD 5 3241 4 4844 3 6321 2 7609 1 8737 I PBTO H DATE REV BY COMMENTS 01/17/06 KCF/TLH CIBP DESCRIPTION ADDED 04/17106 SRB/PAG ADPERFS (04/11/06) NOTES: WELL ANGLE> 700 @ 9950' & > 900 @ 10138'. CHROME TBG & LINER. 2213' -13-1/2"HESXNIP,ID-2.813" TVDDEV 3174 3 4732 25 5933 39 6932 40 7805 39 GAS LIFT fvtANDRELS TYÆ VLV LATCH MMG DMY RK MMG DMY RK MMG OMY RK MMG DMY RK MMG DMY RK DATE 02/21/05 02/21/05 02/21/05 02/21/05 02/21/05 PORT o o o o o 8797' -13-1/2" HES X NIP, ID - 2.813" I 8820' .J 7-5/8" X 3-1/2" BKR S-3 PKR, ID 2.920" 8846' -13-1/2" HES X NIP, 10 = 2.813" 1 -13-112" HES XN NIP, ID = 2.750" I -j 3-1/2" TBG, 9.3#, 13-CR-80, .0087 bpf, ID = 2.992" I -13-1/2" WLEG, 10 - 2.992" I -15-1/2" BAKER RS NIP, ID = 4.875" I -15-1/2" X 3-112" LNRXO, ID = 2.975" I ???? FISH, KO TOOL ARM, KICK SPRING (1/8" X 314" X 4-1/2") 5-1/2" LNR MILLOUT WINDOW 9635' - 9647' (OFF WHIPSTOCK) 11150' 1-13-1/2" WFO CIBP (05114/04) 1 -J 12130' PRUDHOE BA Y UNIT WELL: 05-32A ÆRMIT No: "2020010 API No: 50-029-22190-01 SEC 32, T11 N, R15E, 2549' FNL & 1084' BP Exploration (Alaska) RECEIVED 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Ope rat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS,Utlt!¡'ð nïlll. ~,_ ro. " Stimulate D Other r 1.- _v..... Waiver D Time Extension Lrnc.JIUI élye Re-enter Suspended Well D 5. Permit to Drill Number: JUN 1 2 2006 3. Address: Plug Perforations D Perforate New Pool D Perforate 0 4. Current Well Class: Development pj Stratigraphic [J 202-0010 [J 6. API Number: 50-029-22190-01-00 9. Well Name and Number: Exploratory Service P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 63.5 KB 05-32A 8. Property Designation: ADL-028326 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Fieldl PRUDHOE OIL Pool Total Depth measured 12130 feet Plugs (measured) 11150 true vertical 8800.24 feet Junk (measured) UNK MD jC~~'~~\rl~1 , ., Effective Depth measured 12030 feet 1 .... ~... ...~."..... .. true vertical 8803.59 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 34 - 114 34 - 114 1490 470 Surface 3458 10-3/4" 45.5# J-55 33 - 3497 33 - 3494.36 3580 2090 Production 9320 7-5/8" 29.7# L-80 32 - 9352 32 - 8351.7 6890 4790 Liner 585 5-1/2" 17# 13Cr80 9056 - 9635 8114.91 - 8586.06 7740 6280 Liner 3235 3-1/2" 9.2# L-80 8895 - 12130 7990.93 - 8800.24 10160 10530 Perforation depth: Measured depth: 9964 - 9994 True Vertical depth: 8803.13 - 8812.2 10012 - 10037 10380 - 10490 8832.41 - 8834.03 10520 - 10820 8833.94 - 8843.42 10880 - 11080 8843.27 - 8840.09 8816.67 - 8821.29 Tubing: (size, grade, and measured depth) 3-1/2" 9.3# 13CR80 30 - 8879 Packers and SSSV (type and measured depth) 3-1/2" Baker S-3 Packer 5-1/2" Baker LT Packer 8820 8874 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 523 645 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 28450 0 540 22882 0 500 15. Well Class after proposed work: Exploratory Development pj 16. Well Status after proposed work: Oil pj Gas C WAG C Tubing pressure 1079 1493 Service x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. GINJ [J WINJ C WDSPL ISundry Number or NIA if C.O. Exempt: IN/A C Contact Sharmaine Vestal Prioled N'me Sh"m,;oe V..tal ~ k Signatu~ Title Data Mgmt Engr Phone 564-4424 Date 6/7/2006 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only 05-32A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDA TE I SUMMARY 4/11/2006 CTU #5, Coil flag, Perforate; Cont' from WSR 4/10/06... Perform weekly BOP test. RIH w/ CCL. Logged interval from 10150' to 9600'. Flagged pipe @ 10000.6'. POOH. Depth correction of 0'. RIH with gun #1, 25' SWS 2.5" 2506 PJ HMX, 6 SPF. Perforate from 10012' - 10037' elmd. RIH with gun #2 30' SWS 2.5" 2506 PJ HMX, 6 SPF. Continue on WSR 4-12-06.... 4/12/2006 CTU #5, Perforating; ......Continue from WSR 4-11-06......RIH with gun #2, 2.5" x 30' PJ HMX 6 SPF. Perforate from 9964' - 9994' elmd. Freeze protect with 60/40 methanol while pulling out of hole. RD. Road to shop for unit maintenance. *** Job Complete *** FLUIDS PUMPED BBLS 158 Meth 23 KCL 38 Lube Tex 219 TOTAL . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc 05-32A (PTD #2020010) Classified as a Problem Well ') ) a()~,-ðol Su.bject: 05-32A (PTD #2020010) Classified as a Problem Well From: "Reeves, Donald F" <ReevesDf@bp.con1> Date: Mon, 14 Feb 2005 15:55:51 -0900. . To,: "GPB, FS lISIP/STP Area Mgrlt <GPBFS1TL@bp.com>, "GPB, FS IDS5 9Pèiato~~.~ '. . . «lPBFS 1 DSSoperator@bp.com>, "GPB,. w el1~ opt Eng" <GPJ3Wel1s9PtEng@bþ~cotn>; '''GPB, :; Ops Mgr" <G¡>BOpsMgr@bp.com>;' "NSU,. ADWWL & Completion Supervisor":' . , '. . .' . .,.'. : . <1\1SUi\DWWL&CompletionSupervisor@bp~con1>,. ftNSU,ADW::Welloperatio~s:S1Ìpervisor".. <NSUADWWel1Oper~tionsSupervisor@bp:coni>~'~'AOGCC ~ JiniRegg(E~ri1aiIY' . ". ' <jim_regg@íl:dmin.sÌ(lt~.ak.us>, HAOGCC":'Wmton-Aubert(E-mail)R :":::: .',' . ;'..: . '.' <~inton~aubert@admin.state.akuS>; "Dem,. Jamès A".<deanja@bp~cóm>,."GPBrFS.l'DS Ops,Lead" <GPBFSID'SOpsLead@bp.com>,"." .':'...:::". ...'" .::' . '.,,:,,:,.....','.:.. CC: "Corcotai1, KevinD'(VECO)"<Corc:oran~Kevin@bp.cóm>, uNSU;:AD'YWelI-lntegrity Etigineer" '<NSUADWWellIntegrityEngine~@bp.com>:' . '.:. . . :., . . ',. :: " . : All, Well 05-32A (PTD # 2020010) has sustained pressure on the IA and has been classified as a Problem Well. The well has passed two TIFLs in the past 3 months but more recently the IA rapidly re-pressurizes above 2000 psi. The TIO's on 02/13/05 were 2390/2350/230. Current plans are to: 1 ¡ SL: Run DGLVs in sta# 5 & 4 2. DHD: Re-TIFL Attached is the wellbore schematic. Please call if you have any questions «05-32A.pdf» ' Thanks, . Donald Reeves ~ filling in for Anna Dube , . . . Well Integrity Engineer (907) 659-5102 (907) 659-5100 #1154 Pgr Content-Description: 05-32A.pdf Content-Type: application/octet-stream Content-Encoding: base64 SCANNED fEB 2 3 {.DOS 1 of 1 2/16/2005 1: 15 PM 1 1 1 TOPOFTIEBACKSLV H 9056' 'I l 17-5/8" X5-1/2" LNR HGR H 9063' 1 . 17-5/8" CSG, 29.7#, L-80, ID = 6.875" H 9352' -----A ) TREE = 4-1/16" CIW WELLHEAD = FMC Acrui\.töR ;;.nnÄXELSÖÑ T<B~-'ELEV-;-'---"--"'--"'--~--63:5 ..... n. .. . BF. ELEV = NA KOP = 4150' ~."...... ......... .... ... .....m...........................................' Max Angle = 99 @ 11446' "batljï:¡:ïï'iii [i;.......n..... ............... ... ... DatÜmTVD';" n"ääöò'§s 110-3/4" CSG, 45.5#, J-55, ID = 9.950" H 3497 Minimum ID = 2.750" @ 8866' 3-1/2" HES XN NIPPLE 1 TOP OF BKR llEBACK SLV,ID =5.750" H 8866' 17 -5/8" X 5-112" BKR LT R<R, 10 = 4,937" H 8874' 17-5/8" X 5-1/2" BKR LNR !-\GR, ID= 4.830" H 8886' PERFORATION SUMIW\ RY REF LOG: TCP PERF ANGLEATTOPPERF: 89 @ 10380' Note: Refer to Roduction DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DA. TE 2-1/2" 4 9910 - 9934 C 08/28/91 2" 4 10380 - 10490 0 03/06/02 2" 4 10520 - 10820 0 03/06/02 2" 4 10880 - 11080 0 03/06/02 2" 4 11200 - 11650 C 03/06/02 2" 4 11850 - 12010 C 03106/02 05-32A ~ ~ -1 I I z ~ ) SAFET"YNOTES: WB.LANGLE> 700@ 9950' & >900@ 10138'. 5-112" LNRIS 13-CHROME. 2213' 1-13-1/2" HESX NIP, 10 =2.813" 1 .. ST MD - 5 3241 4 4844 3 6321 2 7609 1 8737 TVDOEV 3174 3 4732 25 5933 39 6932 40 7805 39 GAS LIFT IW\NORELS TYPE VLV LATCH RJRT MMG RP RK SHEAR MMG DMY RK 0 MMG DMY RK 0 MMG DMY RK 0 MMG DMY RK 0 DA. TE 09/19/03 09/19/03 09/28/03 09/28/03 09/28/03 ~f ) . ~ 8797 1-i3-1/2"HESXNIP,ID=2.813" 1 8820' \7-5/8"X 3-1/2" BKRS-3 PKR, ID=2.920" \ 1 8846' 1 8866' 1 8878' 1 8879' 1 8883' 1 8895' 1-13-1/2" HESX NIP, ID= 2.813" 1 1-13-1/2" HESXN NP, 10= 2.750" 1 1-f3-1/2"TBG, 9.3#, L-80,.0087þpf,ID;::?:~~~" J 1-i3-1/2" WLEG, 10= 2.992" I, h 1-15-1/2" BAKER RS NIP, 10=4.äl$~"F':'; ..- 1-i5-1/2" X 3-1/2" LNR XO, ID = 2.97~~'. I.' : .- ~ 5-1/2" LNRMILLOUTWINDOW 9635' - 9647' (OFF WHIPSTOCK) PBm l-t 12030' 1 I 5-112" Lf\R, 17#, 13-CR, ID ~ 4.8: ~ :: ::: ¡---'8 I 3-112" Lf\R, 9.2#, L-BO,.0087 bpI, ID = 2.992" H 12130' DA. TE REV BY COMrÆNTS 09/30/03 JUIlLH GLV CiO 05/14/04 BJM::UKK SEf ClBP FRUDHOE BAY UNIT WELL: 05-32A PERMIT No: 2020010 A A No: 50-029-22190-01 SEC 32, T11 N, R15E; 2549' FNL & 1084' OA TE REV BY COMVIENTS 07/31/91 ORIGINAL COM PLETION 03/08/02 RIG SIDETRACK (05-32A) 06/17/01 RWfP CORRECTIONS 03/10/02 RWfP CORRECTIONS 06/12/03 CMOrrLP KB ELEV A 1l0N CORRECllON 09/19/()3 JBM'KK GL V C/O BP Exploration (Alas ka) ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbandonD Alter CasingD Change Approved Program D 2. Operator Repair Well 0 PluQ PerforationslK] Pull TubingO Perforate New PoolD Operation Shutdown 0 Perforate D 4. Current Well Class: Stimulate D OtherO WaiverD Time ExtensionO Re-enter Suspended WeliO 5. Permit to Drill Number: 202-0010 Name: BP Exploration (Alaska), Inc. Total Depth measured 12130 feet true vertical 8800.2 feet Effective Depth measured 11150 feet true vertical 8841.5 feet 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 63.50 8. Property Designation: ADL-O028326 11. Present Well Condition Summary: Casing Conductor Liner Liner Production Surface Length 80 29 585 9314 3458 Perforation depth: ExploratoryD ServiceD Development 00 StratigraphicD 9. Well Name and Number: 05-32A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 6. API Number 50-029-22190-01-00 Plugs (measured) 11150 Junk (measured) None Size 20" 91.5# H-40 5-1/2" 17# L-80 5-112" 17# 13Cr80 7-5/8" 29.7# L-80 10-3/4" 45.5# J-55 MD TVD Burst Collapse 34 114 34.0 - 114.0 1490 470 8866 - 8895 7968.7 - 7990.9 7740 6280 9050 - 9635 8110.2 - 8586.1 7740 6280 32 - 9346 32.0 - 8346.9 6890 4790 33 - 3491 33.0 - 3488.4 3580 2090 Measured depth: 10380 -10490,10520 -10820,10880 -11080 REC. E"\lt~'r'.) . .... ~~ .,,¡f ..~.I \; ~::, t" JUL 0 1 2004 True vertical depth: 8832.41 - 8834.03, 8833.94 - 8843.42, 8843.27 - 8840.09 Tubing ( size, grade, and measured depth): 3-112" 9.3# L-80 @ 8879 P11aska Oil & Packers & SSSV (type & measured depth): 3-1/2" Baker S-3 Packer 5-1/2" Baker L T Packer @ @ 8820 8874 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Averaae Production or Iniection Data Gas-Me! Water-Bbl Casing Pressure 30.6 0 1000 Daily Report of Well Operations. 2S. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron J14 C~. 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - Signature Form 10-404 Revised 4/2004 30 Oil-Bbl 696 Tubing Pressure 973 990 658 30 0 0 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD 16. Well Status after proposed work: Oil 00 GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or NIA if C.O. Exempt: NIA Title Production Technical Assistant Phone 564-4657 Date 6/25/04 ORIGINAL RBDMS SF L JUl 0 6~- ~ ,~ 05-32A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/14/04 CTU #9: MEM GR/CCL CIBP: MIRU CTU, MU BOP'S AND FUNCTION TEST AFTER WWP JOB. MU PDS MEM GR/CCL W/2.38" OD CARRIER AND 2.72" OD CENTRALIZER AS DRIFT. RIH TO 11,300' AND LOG UP TO 11,100' AND FLAG COIL, FINISH LOGGING INTERVAL AND POOH. HAD TROUBLE AT 8838' CTM (XN-NIPPLE). BUT WORKED THROUGH AND CONTINUED OOHo MU WFRD 3-1/2" CIBP AND RIH. SET CIBP @ 11150' MD. POOH. «<CONTINUED ON 5/15/04»>. FLUIDS PUMPED BBLS 54 73 127 18/82 Methonal/Water 1 % KCL TOTAL Page 1 i~ TREE = 4-1/16"CIW WELLHEAD = FMC ACTUA. TOR = AXELSON KB. R.EV =' 63.5' BE R.EV = NA KOP= 4150' Max Angle = 99 @ 11446' Datu m 1;;'-0-;- --- Datum TVD = 8800' SS 05-32A 110-314" CSG, 45.5#, J-55, ID = 9.950" H ~ 349T Minimum ID =2.750" @ 8866' I 3-1/2" HES XN NIPPLE 1 TOP OF BKRllEBAO< SLV, ID =5.750" H 8866' I ~ 17-518" X 5-1/'Z' BKR L T A<R, ID = 4.937" H 8874' I 17-5/8" X 5-1/2" BKRLNR H3R, ID= 4.830" H 8886' I TOPOFTI83ACKSLV H 9056' I ~ 17-5/8" X 5-1/2" LNR HGR H 9063' I . 17-518" CSG, 29.7#, L-80, ID = 6.875' H 9352' r---- PERFORATION SUMMII. RY REF LOG: TCP PERF ANGLEATTOPPERF: 89 @ 10380' I'bte: Refer to A"oduction DB for historical perf data SIZ E SPF INTERII AL OpnlSqz DA TE 2-112" 4 9910-9934 C 08/28/91 2" 4 10380 - 10490 0 03106102 2" 4 10520 - 10820 0 03106/02 2" 4 10880 - 11080 0 03106/02 2" 411200-11650 C 03106/02 2" 4 11850 -12010 C 03106/02 15-1/2" LNR, 17#, 13-CR, ID = 4.89'Z' I TO H 10104' I H 10114' I ~ SAFETY NOTES: WB.L ANGLE> 70° @ 9950' & > 900@ 10138',5.112" LNRIS 13-CHROME 2213' H3-1/2" I-ES X NIP, ID = 2.813" I ~ I I ~ I j . REV BY DA lE REV BY COMrÆNTS 09/30/03 JLJIllH GLV C/O 05114/04 BJfvtUKK SET' OBP DATE 07/31/91 03/08/02 06/17/01 03/10102 06/12/03 09/19/03 COfl.fvlENTS ORIGINAL COM PLETION RIG SIŒTRACK (05-32A) RNlTP CORRECTIONS RNlTP CORRECTIONS CMO/TLP KB R.EV A llON CORRECllON JBM'KK GL V c/o .. GAS LIFT Mll.tÐRELS L ST M) TVDDEV TYPE VLV LATCH RJRT DATE - 5 3241 3174 3 MM3 RP RK SHEAR 09/19/03 4 4844 4732 25 MM3 DMY RK 0 09/19/03 3 6321 5933 39 MM3 DMY RK 0 09/28103 2 7609 6932 40 MM3 DMY RK 0 09/28/03 1 8737 7805 39 MM3 DMY RK 0 09/28/03 z 879T 8820' 8846' 8866' 8878' 8879' 8883' 8895' ~ H3-1/2" HES X NIp, ID = 2.813" I 17-5I8"X3-1/'Z'BKRS-3PKR,ID=2.920" I H3-1/2" HESX NIP, ID= 2.813" I H3-1/2" HES XN NP, ID = 2.750" I H 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" I H3-1/2"WLEG, ID =2.99'Z' I H5-1/2" BAKER RS NIp, ID = 4.875" I H5-1/2" X 3-1/'Z' LNR XC, ID = 2.975" I 5-1/2" LNR MILLOUTWINDOW 9635' - 9647' (OFF WHIPSTOCK) PBTO H 12030' I .. 1'.112" ""- 9.2#. '.a0..0087 bp'. "' ~ 2.002' H 12130" I FRLDHOE BA Y UNIT WELL: 05-32A PERIv1IT No: 2020010 AA No: 50-029-22190-01 SEC 32, T11 N, R15E: 2549' FNL & 1084' BP Exploration (Alaska) k3s C!\J II. WELL LOG TRANSMITTAL ProActive Diagnostic Services, 'nc. To: State of Alaska AOGCC 333 W. 7"'Street Suite # 700 Anchorage. Alaska 99501 RE: Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. o. Box 1389 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center lR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WEll DATE LOG TVPE DIGITAL OR CD-ROM 1 MVLAR / SEPIA FilM 1 BLUE LINE PRINT(S) REPORT OR COLOR Open Hole 1 Res. Eva!. CH 1 1 1 2 ûÀ'" ~ 0. \ DS5-32A 5/14/04 J A >-Àf,- Mech. CH 1 Caliper Survey Print Name: 'Jh~,J O/)v,j d k l(~ V\ ~ Date: ::? )' J~~ ...l-è't1 y. Signed: M-o'.J \;~ ~{I ~ PRoAoivE DiAGI'IOSTic SERViCES, INC., PO ßox I }b9 STAffORd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds.g.memorylog.com \Vebsite: \\ww.memorylog.com Log/ Data Type t~ II!c)g I -beg t/1Ê D ,-ED --ED- ßÐ s fJ-P ÀOO"( DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 )f1. ~L Ä¥ i-J ÃM-~ API No. 50-029-22190-01-00 PermittoDrill 2020010 Well Name/No. PRUDHOE BAY UNIT 05-32A Operator BP EXPLORATION (ALASKA) INC MD 12130 ",/ TVD 8800 / Completion Date 3/8/2002 /' 1-01L Current Status 1-01L UIC N Completion Status REQUIRED INFORMATION Yes ~ Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: MWD, GR, RES, MEMORY CNL (data taken from Logs Portion of Master Well Data Maint) ) Electr Digital Dataset Med/Frmt Number 5 5 BS BS Interval OH I Start Stop CH Received 8745 10032 Case 4/19/2002 9620 12097 Case 1/14/2003 8745 10032 Case 4/19/2002 8745 10032 Case 4/19/2002 Comments Log Log Run Scale Media No 5 BS 1 1 Name D C CAse C Pdf 25 9620 8745 12097 Case 1/14/2003 10032 Case 4/19/2002 9614 9640 12130 12130 Open ROP, NGP Well CoresfSamples Information: Name Interval Start Stop Sample Set Number Comments ) Received Sent ADDITIONAL INFORMATION Y,G) Chips Received? ~ ~ Well Cored? Daily History Received? GIN ÐN Formation Tops Analysis Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 Permit to Drill 2020010 Well NamelNo. PRUDHOE BAY UNIT 05-32A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22190-01-00 MD 12130 co~n Date 3/8/2002 Completion Status Current Status 1-01L UIC N Date: s'-l'Ip 2..4d '1 1-01L TVD 8800 Compliance Reviewed By: J ) ..,,-..., ,-\. dO~ .-' DOl WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COmIn. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 l\nchorage,AJaska 99501 May 09,2003 RE: MWD Formation Evaluation Logs: 05-32A, AK-MW-22027 05-32A: Digital Log Images 50-029-22190-01 1 CD Rom I '1+5 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING ANn RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. l\nchorage, Alaska 99518 BP Exploration (AJaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. l\nchorage, Alaska 99508 Date: ~ to- 03 Si~edß ~ S""\.'~.'.""'.'~./"':k ~\V.. ti~~~'O'. !í'~lt-(Ì ,'L:'~' :::' ~ '\;._.,~"""... MAY 13 2003 Alastœ 01'1 6; G~ Gont:!. vommìleion And1øge ~ "-"". WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1 LDWG formatted Disc with verification listing. API#: 50-029-22190-01 January 10, 2003 05-32A, AK-MW-22027 ~~-rol I/LJ1ltJ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LEITER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 sd.(~ Date: RECEIVED JAN 1 4 2003 Ai.! Oii &~ Cons. Con~ 1'1I'JCh~ ( f Sc~lInbepger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Well Job # J.16A . ~...,~to~ . D.S. 5-32A,-i0rl-OO , C-28A aO~-Ot..J S 22166 SCMT 22162 MCNL 22164 MCNL Log Description Date 03/29/02 03/05/02 03/20/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: RECEIVED LPP 1 9 2002 . ,. . \ I Alaska Oil & Gas Cons. CùtIlIMion Anchorage Bluellne 04/15/02 NO. 1982 Company: State of Alaska Alaska 011 & Gas Cons Comm Aftn: LIsa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prlnfs CD 2 Schlumberger GeoQuest 3940 Arctic Blvd. Suite 300 Anchorage. AK 99503-5711 ATTN: Sherrle Rec..ved~ ,~.J " ~ ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well II Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 202-001 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ' ;,"T-~n"cr',' 50-029-22190-01 l~r~' 4. Location of well at surface ""--'-n-_.,,- . V~' ,," ~¡ 9. Unit or Lease Name 2549' SNL, 1084'.EVt{L, SEC. 32, T11N, R15E, UM,t,,!, ,~;f);','¡, C,:",>;;" ',' 1', ' " I,),', Prudhoe Bay Unit At top of produc~lve Interval ~ '" ;:,;",: i ~ SUI. .^) 4863 SNL, 2526 WEL, SEC. 29, T11N, R15E, UM ð ~, ~,¥, "',6,2-,! ~~U~,". ",. 10. Well Number 4:g?~~~~~~4' WEL, SEC. 29, T11 N, R15E, UM i \5i~ ¡ ,~~~ 05-32A 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease disÎÏJñäUÓìîafid Serial No. 11. F~~~d~~~ ~~~I Field / Prudhoe Bay Pool RKB = 63.50' ADL 028326 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 116. No. of Completions 2/24/2002 3/3/2002 3/8/2002 N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV setl21. Thickness of Permafrost 12130 8800 FT 12030 8804 FT liVes ONo (Nipple) 2213'MD 1900'(Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, Memory CNL 23. CASING SIZE 20" 10-3/4" 7-5/8" 5-1/2" 3-1/2" Classification of Service Well -r/ kh~ ~'Sr WT. PER FT. 91.5# 46# 29.7# 17# 9.2# GRADE H-40 J-55 L-80 13Cr-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 30" 11 VardsAS Surface 3498' 13-1/2" 2152 cu It CS III, 405 cu It 'G' ;Top Job 240 cu It CS II Surface 9352' 9-7/8" 1420 cu ft 'G', 318 cu ft 'G' 9056' 9635' 6-3/4" 170 cu ft ARC Class 'G' 8866' 12130' 4-3/4" 281 cu ft Class 'G' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 SPF MD TVD MD TVD SIZE 3-1/2",9.3#, 13Cr80 TUBING RECORD DEPTH SET (MD) 8879' PACKER SET (MD) 8820' 25. 10380' - 10490' 10520' -10820' 10880' - 11080' 11200' - 11650' 11850' - 12010' 8831' - 8834' 8834' - 8843' 8843' - 8840' 8843' - 8818' 8811' - 8804' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 95 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 21, 2002 Flowing Date of Test Hours Tested ~=~~~~~~~FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 28. CORE DATA WltCt-'V"'" ) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit c~e~ IPS. " No core samples were taken. APR 1 1 ZO02 AI8O1& G8&COOt. (Ã"',d~:iion AftdøIge Form 10-407 Rev. 07-01-80 RBOMS BFl Submit In Duplicate APR , 5 2002 ~ ç: ~ ~ Marker Name Geologic Markers Measured Depth 30. Formation Tests 29. True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 23SB 9703' 8643' 22TS 9746' 8677' 21TS 9808' 8723' Top of Zone 18 9895' 8775' Zone 1A 10021 ' 8819' Base of Zone 1 B 11740' 8814' RECEIVED APR 11 2002 Al8lllaataGIBo.<ø ~III'" ~ 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak-Off Test Summary. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ ~ Title Technical Assistant Date 01-1 (.~ 05-32A Well Number 202-001 Permit No. / Approval No. Prepared By Name/Number: Sandra Stewman, 564-4750 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ~ ~ Well: Field: API: Permit: OS-32A Prudhoe Bay Field / Prudhoe Bay Pool 50-029-22190-01 202-001 Rig Accept: Rig Spud: Rig Release: Drilling Rig: 02/17/02 02/24/02 03/08/02 Nabors 2ES PRE RIG WORK 01/19/02 PULL 41/2 DSSSV FROM BVN @ 2189' WLM -- PULL DGLV FROM GLM # 1 @ 3673' WLM -- PULL DGLV FROM GLM # 7 @ 8878' WLM. 01/20/02 PULL DGLV FROM GLM # 7 @ 8878' WLM -- SET NEW DGLV IN GLM # 1 @ 3673' WLM -- PURGE INJECTION GLM LINE IN GLM # 7 @ 8878' W/ DIESEL -- SET NEW DGLV IN STA.# 7 @ 8878' WLM -- PULL 31/2 XXN PLUG @ 9095' WLM -- DRIFT FOR CHEMICAL CUTTER W/2.50" DUMMY GUN TO 9978' WLMD. 02101/02 RIH WITH 1.56" (4 SPF) TUBING PUNCHER, TIE INTO TBG TALLY & PERFORATE TAIL PIPE FROM 9040- 9042 MD (JUST BELOW PACKER). RIH WITH STRING SHOT AND FIRE @ 8980' MD (PRE CHEM CUT). RIH WITH 2 3/8" CHEMICAL CUTTER, CUT TUBING IN THE MIDDLE OF FIRST FULL JOINT ABOVE PACKER AT 8980' MD. GOOD CUT INDICATION. 02107/02 LOAD 95 BBL DIESEL, RU TO IA AND WATER TANK, PUMP 400 BBLS SEAWATER,THEN 60 BBLS DSL DOWN IA AT 4.5 BBLS/MIN, RO lA, RU TO TBG, PUMP 100 BBLS SEAWATER AT 4.2 BBUMIN , THEN 35 BBLS DSL DOWN TBG AT 3.7 BBLS/MIN, RDMO. NN ('I) ('I) I I LOLO 00 a.> E .. m Q) Z E m c: Z 0 - E m E 0> 0 ~() OJ Q. .e- ~ 0 ó ~ ~ "00 .e- N r-- V ..¡ ~ "00 .e- m t: OJ Q. .e- o v cO g C! 0 CD aj g 0 <ri It) CD a> f- ¡¡: N 0 0 N M N N ~ ~ ::;: « "- " ,;.: ö '" a a ~ '" ¡;; ij Q) ë it ~. ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-32 05-32 REENTER+COMPLETE NABORS NABORS 2ES Start: 2/17/2002 Rig Release: 3/8/2002 Rig Number: Spud Date: 7/15/1991 End: 3/8/2002 2/17/2002 00:00 - 02:30 2.50 MOB P PRE Move camp, shop and pit module. Move sub base from well 5-02A. 02:30 - 03:30 1.00 MOB P PRE Lay Herculite in cellar area. Spot and level Sub Base over well. 03:30 - 05:00 1.50 MOB P PRE Set shop, pit module and camp in place. 05:00 - 07:00 2.00 MOB P PRE Lay Herculite, set cuttings tank and berm same. Hook up high pressure mud lines. 07:00 - 08:00 1.00 BOPSURP DECOMP Accept Rig at 07:00 hrs 2/17/2002. Pre-spud, safety and environmental meeting. Review Pre-spud check list. 08:00 - 10:30 2.50 BOPSUR P DECOMP Rig up lines to circulate out freeze protect. 10:30-11:30 1.00 BOPSURP DECOMP Pull back pressure valve with DSM lubricator. 11:30-17:00 5.50 BOPSURP DECOMP Circulate out diesel freeze protect through choke. Lost a total of 195 bbl sea water. 17:00 -18:00 1.00 BOPSURP DECOMP Spot 35 bbl LCM pill in tubing and let fall. Fill tubing. 18:00 -18:30 0.50 BOPSURP DECOMP Rig down circulating lines. 18:30 -19:00 0.50 BOPSUR P DECOMP Install back pressure valve and test same. 19:00-21:00 2.00 BOPSURP DECOMP Nipple down tree. Install blanking plug. 21 :00 - 00:00 3.00 BOPSURP DECOMP Nipple up BOP. 2/18/2002 00:00 - 00:30 0.50 BOPSUR P DECOMP Nipple up BOP. 00:30 - 04:00 3.50 BOPSURN RREP DECOMP Repair high pressure test pump. 04:00 - 05:00 1.00 BOPSURP DECOMP Test Top Drive upper and lower BOP and floor valves to 250 psi and 3500 psi for 5 minutes. 05:00 - 06:30 1.50 BOPSUR N SFAL DECOMP Attempt to test BOP and choke manifold. Thaw out choke line 06:30 - 10:00 3,50 BOPSURP DECOMP Tets BOP to 250 psi and 3500 psi for 5 minutes. Witness of BOP test waived by AOGCC rep Lou Grimaldi 10:00 - 10:30 0.50 BOPSUR P DECOMP Pull blanking plug from tubing hanger. 10:30 - 13:00 2.50 PULL P DECOMP Rig up DSM lubricator. Retrieve back pressure valve after 3 attempts. 13:00 -14:30 1.50 BOPSURP DECOMP Install landing joint. Test upper and lower pipe rams. 14:30 - 15:30 1.00 PULL P DECOMP Rig up to pull tubing. PJSM. Pick up tubing with 125,000 Ibs. No over pull, pipe free. 15:30 - 17:30 2.00 PULL P DECOMP Rig up Camco spooling unit and tubing equipment. Lay down landing joint and tubing hanger. 17:30 - 23:00 5.50 PULL P DECOMP POH. Lay down 4 1/2" tubing. Recovered 73 x 3/8" injection line clamps. 23:00 - 23:30 0.50 PULL P DECOMP Change out tubing handling equipment to 3 1/2". 23:30 - 00:00 0.50 PULL P DECOMP POH. Lay down 3 1/2" tubing 2/19/2002 00:00 - 13:00 13.00 PULL P DECOMP POH. Lay down 3 1/2" tubing and completion equipment. Recovered 73 - 41/2" chemical injection line clamps, 184 - 3 1/2" clamps, and 18 of 23 SS bands. 13:00 -15:00 2.00 PULL P DECOMP Rig down tubing and spooling equipment. Clear rig floor. 15:00 -15:30 0.50 PULL P DECOMP Install WB. 15:30 - 17:00 1.50 PULL P DECOMP MU overshot BHA. 17:00 - 20:30 3.50 PULL P DECOMP PU 4" DP singles, RIH to 4,972'. 20:30 - 22:00 1.50 PULL P DECOMP Continue in hole wI stands of 4" DP to 8,900', DNW = 150K, UPW = 182K, 22:00 - 22:30 0.50 PULL P DECOMP Circ 63 spm, above tbg stump, @ 250 psi. Engage fish at 8,971', swallow 4'. Pull 30K over. Stab back in wI SA and pumps on to verify fish was caught. Pressure increased from 250 psi to 480 psi, shut down pumps. 22:30 - 00:00 1.50 PULL P DECOMP POOH, monitor well, fluid level static, POOH. 2/20/2002 00:00 - 02:30 2.50 PULL P DECOMP POH with tubing tail pipe and seal assembly. 02:30 - 04:00 1.50 PULL P DECOMP LD overshot BHA. LD fish (28'). 04:00 - 05:00 1.00 PULL P DECOMP PUIMU Packer Rerieving Tool BHA. Printed: 3/12/2002 10:17:54 AM r--, ,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-32 05-32 REENTER+COMPLETE NABORS NABORS 2ES Start: 2/17/2002 Rig Release: 3/8/2002 Rig Number: Spud Date: 7/15/1991 End: 3/8/2002 2/20/2002 05:00 - 08:00 3.00 PULL P DEcaMP RIH to 8,930'. 08:00 - 09:00 1.00 PULL P DEcaMP Cut and slip 110' of DL, clean under draw works. 09:00 - 09:30 0.50 PULL P DECaMP Servce Top Drive. 09:30 - 10:00 0.50 PULL P DECOMP Tag packer at 9,006'. Engage with 23' into packer bore. 10:00 - 14:00 4.00 PULL P DECOMP Mill pkr. Torque 4/7 ft-Ibs. Pull free with 15-20K overpull. Set dwn with 15K to verify fish on. Push down to 9,010'. 14:00 - 15:00 1.00 PULL P DECOMP Circ btms up. Gas on bottoms up, lost 10 bbls of sea water while circ. Monitor well, static. 15:00 - 19:30 4.50 PULL P DECOMP POOH to BHA w/1 0-15K overpull during first 5 stds off btm. 19:30 - 20:30 1.00 PULL P DECOMP LD BHA. No fish, 20:30 - 21 :00 0.50 PULL P DECOMP Clear rig floor, PU spear BHA. 21 :00 - 21 :30 0.50 PULL P DECOMP MU spear BHA. 21 :30 - 00:00 2,50 PULL P DECaMP RIH to 7,307' 2/21/2002 00:00 - 01 :00 1.00 PULL N DFAL DECOMP Continue RIH with spear to 8,995'. 01 :00 - 01 :30 0.50 PULL N DFAL DECOMP Tag top offish at 8,995'. UWT = 175K, DWT = 155K. Pump press = 270 psi, at 50 SPM. Stab into fish and push to 9,031'. Pump pressure increase of 200 psi, Shut down pumps. 01 :30 - 05:00 3.50 PULL N DFAL DECOMP POOH to BHA/fish. 05:00 - 05:30 0.50 PULL N DFAL DECOMP LD spear BHA. 05:30 - 06:30 1.00 PULL P DECaMP LD packer and tubing tail fish. Full recovery. 06:30 - 07:00 0.50 PULL P DECaMP Clear rig floor. 07:00 - 07:30 0.50 PULL P DECOMP RU wireline equipment. 07:30 - 10:00 2.50 PULL P DECaMP Run Guage Ring/Junk Basket to 9,850' WLM - okay. 10:00 - 12:00 2.00 PULL P DECaMP RIH to 9,660' WLM, and set 5-1/2" EZSV. 12:00 - 13:00 1.00 PULL P DECaMP POOH with wireline, LD same. 13:00 - 13:30 0.50 PULL P DECaMP Pressure test 7-5/8" x 5-1/2" casing to 3,500 psi - okay. 13:30 - 14:30 1.00 STWHIP P WEXIT RU handling equipment. 14:30 - 17:00 2.50 STWHIP P WEXIT PJSM. MU whipstock and milling BHA. 17:00 - 17:30 0.50 STWHIP P WEXIT Surface test MWD - okay. 17:30 - 18:30 1.00 STWHIP P WEXIT PU 3-1/2" DCs, and RIH. 18:30 - 19:00 0.50 STWHIP P WEXIT CIO handling equipment. 19:00 - 00:00 5.00 STWHIP P WEXIT RIH with 4" DP to 9,592', fill every 10 stds, and check MWD. 2/22/2002 00:00 - 01 :00 1.00 STWHIP P WEXIT Orient whipstock 85 deg R. Shear pins, set whipstock with top at 9,634'. 01 :00 - 02:30 1.50 STWHIP P WEXIT Displace well to 8.4 ppg, Quick-Drill mud at 3-1/2 BPM and 1,120 psi. 02:30 - 06:00 3.50 STWHIP P WEXIT Mill window from 9,635' - 9,647' 06:00 - 10:00 4.00 STWHIP P WEXIT Drill 4' of new hole to 9,651'. Penetration rate decreased to less than 1 ftlhr. (Upper, Full Guage String mill had not fully passed thru the window). 10:00 -10:30 0.50 STWHIP N DFAL WEXIT POOH to above liner top at 9,056' 10:30 - 12:00 1.50 STWHIP N DFAL WEXIT Drop dart, open pump out sub, circulate sweep at 6 BPM and 1000 psi. Monitor wellbore - static. Pump slug. 12:00 -15:30 3.50 STWHIP N DFAL WEXIT POOH to 2-7/8" DP at 875'. 15:30 - 16:00 0.50 STWHIP N DFAL WEXIT RU 2-7/8" handling equipment. 16:00 - 18:30 2.50 STWHIP N DFAL WEXIT LD milling BHA, Starting mill worn bald. Lower string mill 1/32 out of guage. 18:30 - 19:00 0.50 STWHIP N DFAL WEXIT Clear rig floor. 19:00 - 21:00 2.00 STWHIP N DFAL WEXIT MU new milling BHA. 21 :00 - 21 :30 0.50 STWHIP N DFAL WEXIT RD 2-7/8" handling equipment. 21 :30 - 00:00 2.50 STWHIP N DFAL WEXIT RIH to 7,173', filling pipe at 4,800'. 2/23/2002 00:00 - 01 :30 1.50 STWHIP P WEXIT Continue RIH to 9,650'. Work through and dress window. (no MWD/Mtr). Printed: 3/12/2002 10:17:54 AM .~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-32 05-32 REENTER+COMPLETE NABORS NABORS 2ES Start: 2/17/2002 Rig Release: 3/8/2002 Rig Number: Spud Date: 7/15/1991 End: 3/8/2002 2/23/2002 01 :30 - 04:30 3.00 STWHIP P WEXIT Drill to 9,657', with last foot drilled at 1 ftlhr. 04:30 - 05:00 0.50 STWHIP P WEXIT POOH to 9,043', monitor well- okay, pump slug. 05:00 - 08:00 3.00 STWHIP P WEXIT Continue POOH to BHA. 08:00 - 11 :00 3.00 STWHIP P WEXIT Change out elevators, LD milling BHA, clear floor. 11:00-12:00 1.00 STWHIP P WEXIT Service wear bushing and flush stack, 12:00 - 12:30 0.50 STWHIP P WEXIT Perform FIT to 10 ppg EMW, with 720 psi surface SI pressure. 12:30 - 13:30 1.00 DRILL P PROD1 PU Angle Build BHA, orient MWD. 13:30 - 15:00 1.50 DRILL P PROD1 RIH with 2-7/8" DP to 1,596'. 15:00 - 15:30 0.50 DRILL P PROD1 Change out handling equipment. Shallow test MWD - okay. 15:30 - 16:30 1.00 DRILL P PROD1 RIH with 4" DP to 3,888', filling pipe every 10 stands. 16:30 - 18:00 1.50 DRILL P PROD1 Check MWD at 3,888' - no pulse. Check surface equipment - okay, recheck MWD, no pulse. 18:00 - 19:00 1.00 DRILL N DFAL PROD1 POOH to 1,596'. 19:00 - 19:30 0.50 DRILL N DFAL PROD1 Shallow test MWD - no pulse. 19:30 - 20:00 0.50 DRILL N DFAL PROD1 Cange out to 2-7/8" handling tools. 20:00 - 21 :00 1.00 DRILL N DFAL PROD1 POOH to 174'. 21 :00 - 22:30 1.50 DRILL N DFAL PROD1 Change out probelpulser. Surface test at 85' - okay. 22:30 - 23:00 0.50 DRILL N DFAL PROD1 PU BHA to 174', 23:00 - 00:00 1.00 DRILL N DFAL PROD1 RIH with 2-7/8" DP to 1,596'. 2/24/2002 00:00 - 00:30 0.50 DRILL N DFAL PROD1 Change out 2-7/8" handling tools, contine RIH to 1,689'. Shallow test MWD - okay. 00:30 - 03:30 3.00 DRILL N DFAL PROD1 Continue in hole to 8,975'. 03:30 - 05:30 2.00 DRILL P PROD1 Cut and slip 113' of DL. Service Top Drive. 05:30 - 06:30 1.00 DRILL N DFAL PROD1 Continue RIH to 9,450'. 06:30 - 08:00 1.50 DRILL P PROD1 MAD pass with MWD: 9,420' - 9,456', for geo tie-in. 08:00 - 08:30 0.50 DRILL P PROD1 RIH to 9,569'. Orient TF to 85R. 08:30 - 09:00 0.50 DRILL P PROD1 Pass thru window - okay. RIH to 9,656'. 09:00 - 00:00 15.00 DRILL P PROD1 Drill Build section of hole with 1.83 deg motor. - 2/25/2002 00:00 - 18:00 18.00 DRILL P PROD1 Drill 4 3/4" Build section of hole with 1.83 deg motor. Rotate and slide to obtain angle and direction. 18:00 -19:30 1.50 DRILL P PROD1 Monitor well - okay. Secure service line for wind conditions. POOH to 8,972'. 19:30-21:30 2.00 DRILL P PROD1 Drop dart, open circulating sub (3,310 psi). Circ sweep at 6 BPM, Monitor well - okay, pump slug. 21 :30 - 00:00 2.50 DRILL P PROD1 POOH to 4,024' while testing choke manifold 250/3,500 psi, for 5/5 min. 2/26/2002 00:00 - 01 :00 1.00 DRILL P PROD1 POOH to 2-7/8" DP, 01:00 - 01:30 0.50 DRILL P PROD1 cIa to 2-7/8" handling tools. 01 :30 - 02:30 1.00 DRILL P PROD1 POOH to BHA. 02:30 - 03:30 1.00 DRILL P PROD1 LD angle build BHA, clear rig floor. 03:30 - 04:30 1.00 DRILL P PROD1 Pull WB, RU BOPE testing equipment. 04:30 - 06:00 1.50 DRILL P PROD1 Test BOPE - Blind Rams, Upper and Lower Pipe Rams, Annular, floor valves, TD to 250-3,500 psi - okay. 06:00 - 11 :00 5.00 DRILL P PROD1 PU Horiz. Drlg BHA, PU additonal 2-7/8" DP to TD the well. Surface test MWD - okay. 11 :00 - 12:00 1.00 DRILL P PROD1 RIH wI 2-7/8" DP to 3,279'. cIa to 4" handling tools. Shallow test MWD - okay. 12:00 - 16:30 4.50 DRILL P PROD1 Continue RIH to 9,535', orient TF to 85R, pass thru window wlo pumping or rotating. RIH to 10,130'. 16:30 - 00:00 7.50 DRILL P PROD1 Drill 4-3/4" hole with 1.5 deg motor to 10,297'. 2/27/2002 00:00 - 00:00 24.00 DRILL P PROD1 DRILL 4-3/4" HOLE WITH 1.5 DEG MOTOR TO 10,855'. 2/28/2002 00:00 - 00:00 24.00 DRILL P PROD1 DRILL 4-3/4" HOLE WITH 1.5 DEG MOTOR TO 11,260'. 3/1/2002 00:00 - 12:30 12.50 DRILL P PROD1 DIR. DRILL TO 11,278', W/OUT MAKING PROGRESS Printed: 3/12/2002 10:17:54 AM ~ ,-..., Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-32 05-32 REENTER+COMPLETE NABORS NABORS 2ES Start: 2/17/2002 Rig Release: 3/8/2002 Rig Number: Spud Date: 7/15/1991 End: 3/8/2002 3/1/2002 00:00 - 12:30 12.50 DRILL P PROD1 BUILDING ANGLE. HOLE STICKY WHILE SLIDING, MOTOR STALLING, DRAG WHEN PU = 30-35K. ART 2.6 HRS, AST .4 12:30 - 14:00 1.50 DRILL P PROD1 SHORT TRIP TO 10,110' (NO PROBLEMS), 14:00 - 16:00 2.00 DRILL P PROD1 DRILL AHEAD, SLIDING TO 12,283'. AST 1.6 HRS 16:00 - 17:30 1.50 DRILL P PROD1 POOH TO 8,975' (NO PROBLEMS). 17:30 - 18:30 1.00 DRILL P PROD1 CBU AT 330 GPM, 2170 PSI. MONITOR WELL - OKAY. PUMP SLUG. 18:30 - 21:00 2.50 DRILL P PROD1 POOH TO 3,279'. 21:00 - 21:30 0.50 DRILL P PROD1 RU 2-7/8" HANDLING TOOLS. 21 :30 - 22:30 1.00 DRILL P PROD1 POOH TO BHA. 22:30 - 00:00 1.50 DRILL P PROD1 LD 1.5 DEG BHA, PULL MWD PROBE. 3/2/2002 00:00 - 01 :00 1.00 DRILL P PROD1 CONTINUE TO MU 1.83 DEG MTR-BHA. 01 :00 - 01 :30 0.50 DRILL P PROD1 SHALLOW TEST MWD - OKAY. 01 :30 - 02:30 1.00 DRILL P PROD1 RIH WI 2-7/8" DP TO 3,266'. CIO HANDLING TOOLS. 02:30 - 03:00 0.50 DRILL P PROD1 FILL PIPE, TEST MWD - OKAY. 03:00 - 04:00 1.00 DRILL P PROD1 RIH WI 4" DP TO 6,537'. 04:00 - 04:30 0.50 DRILL P PROD1 FILL PIPE, TEST MWD - OKAY. 04:30 - 05:30 1.00 DRILL P PROD1 RIH TO 9,541'. 05:30 - 06:00 0.50 DRILL P PROD1 FILL PIPE. CONNECT SERVICE HOSE TO TO. 06:00 - 06:30 0.50 DRILL P PROD1 RIHTO11,281'. 06:30 - 07:30 1.00 DRILL P PROD1 WASH TO BTM AND CHK SHOT SURVEY AT 11,281'. MAD PASS 11,263-11,283'. 07:30 - 12:00 4.50 DRILL P PROD1 DRILL TO 11,298, HOLE STICKY AND POOR ROP WHILE SLIDING. ART=O, AST=2.2. 12:00 - 17:00 5.00 DRILL P PROD1 DRILL TO 11,434' ADDING 13-15 LB/BBL OF FINE WALNUT HULLS TO THE MUD SYSTEM. 17:00 - 18:00 1.00 DRILL N DPRB PROD1 TROUBLE-SHOOT MWD TOOL (NO PULSE). CIRCULATED AROUND FRESH WATER SWEEP. WILL MAD PASS THIS SECTION AFTER SHORT TRIP). 18:00 - 00:00 6.00 DRILL P PROD1 DRILL 4-3/4" HOLE WITH 1.83 DEG MTR, TO 11,681'. ART=4.2, AST=3.3. 3/3/2002 00:00-11:30 11.50 DRILL P PROD1 DRILL 4-314" HOLE WITH 1.83 DEG MTR, TO 12,130'. ART=5.9, AST=2.4. 11:30-12:30 1.00 DRILL P PROD1 CIRCULATE BTMS UP. 12:30 - 13:00 0.50 DRILL P PROD1 SHORT TRIP TO 11,446' WITH TIGHT SPOTS AT 11,915' AND 11,620'. 13:00 - 14:00 1.00 DRILL P PROD1 MAD PASS 11,446' - 11,400'. 14:00 -15:00 1.00 DRILL P PROD1 CONTINUE POOH TO 9,521'. 15:00 - 16:00 1.00 DRILL P PROD1 SERVICE TD AND ADJUST BRAKES. 16:00 - 17:30 1.50 DRILL P PROD1 RIH TO 12,130', NO PROBLEMS. 17:30 -18:30 1.00 DRILL P PROD1 SPOT 80 BBL LINER RUNING PILL IN OPEN HOLE, WI 5% LUBTEX.UP175K,DN145K,ROT160K 18:30 - 20:30 2.00 DRILL P PROD1 POOH TO LINER TOP AT 9,056' (SLM) WITH NO PROBLEMS. 20:30 - 21 :30 1.00 DRILL P PROD1 DROP DART, OPEN PUMP OUT SUB WITH 3,130 PSI. CIRCULATE HI-VIS SWEEP. PUMP SLUG. 21 :30 - 00:00 2.50 DRILL P PROD1 POOH TO 4,014' (SLM). 3/4/2002 00:00 - 00:30 0.50 DRILL P PROD1 CONTINUE POOH WI 4" DP TO 3,266' (SLM). 00:30 - 02:30 2.00 DRILL P PROD1 RU 2-7/8" HANDLING TOOLS, POOH TO BHA, LD 2-7/8" DP. 02:30 - 03:30 1.00 DRILL P PROD1 LD BHA. 03:30 - 04:00 0.50 DRILL P PROD1 CLEAR RIG FLOOR. 04:00 - 05:30 1.50 DRILL P PROD1 RU CASING EQUIPMENT. 05:30 - 06:30 1.00 DRILL P PROD1 PU, BAKER-LOK, AND RUN SHOE JTS, CHK FLOAT Printed: 3/12/2002 10:17:54 AM ~ ,~, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-32 05-32 REENTER+COMPLETE NABORS NABORS 2ES Start: 2/17/2002 Rig Release: 3/8/2002 Rig Number: Spud Date: 7/15/1991 End: 3/8/2002 3/4/2002 05:30 - 06:30 1,00 DRILL P PROD1 EQUIPMENT - OKAY. 06:30 - 14:00 7.50 DRILL P PROD1 RUN TOTAL OF 106 JTS OF 9.2#/FT, L-80, TCII LINER TO 3,230' WI CENTS AS PLANNED. MU TORQUE = 2,300 FT-LB. 14:00 - 15:30 1.50 DRILL P PROD1 PUlMU 7-5/8" X 3-1/2" BOT FLEX-LOCK HNGR, ZXP LNR TOP PKR, AND TIE-BACK 15:30 - 16:00 0.50 DRILL P PROD1 CONTINUE RIH TO 3,420', CIRCULATE LINER VOL UP. 16:00 - 20:30 4.50 DRILL P PROD1 CONTINUE RIH WI 4" DP TO 9,635', FILLING EVERY 10 STDS. 20:30 - 21 :00 0.50 DRILL P PROD1 CIRC UP LINER + DP VOL. UWT = 150K, DWT= 140K, ROT = 145K. TRQ = 3,000 FT-LB AT 5-15 RPM. 21:00 - 21:30 0.50 DRILL P PROD1 PJSM, PU CMT HEAD (24'), (DRY RUN), LD ON SKATE. 21 :30 - 00:00 2.50 DRILL P PROD1 CONTINUE RIH TO 12,130' MD WI TIGHT SPOTS AT 10,665' AND 11,695'. WASH AND WORK THROUGH TIGHT SPOTS. 3/5/2002 00:00 - 00:30 0.50 CEMT P COMP RIG UP CEMENT HEAD AND LINES. 00:30 - 04:00 3,50 CEMT P COMP CIRCULATE AND CONDITION MUD AT 5 BPM WITH 1800 PSI. CIRCULATE 3 TIMES LINER VOLUME, HOLD PRE JOB SAFETY MEETING WHILE CIRCULATING. 04:00 - 05:00 1,00 CEMT P COMP TEST LINES TO 4000 PSI. PUMP 30 BBL 9.4 PPG ALPHA SPACER. PUMP 50 BBL 15.9 PPG CLASS 'G' CEMENT AT 4.5 TO 5 BPM. DROP WIPER DART AND DISPLACE WITH MUD. LATCH UP WITH WIPER PLUG AND SHEAR OUT WITH 3250 PSI. LINER HANGER SET. CONTINUE DISPLACING WITH 115.5 BBL. BUMP PLUG. CEMENT IN PLACE AT 0510. FLOATS HELD. 05:00 - 06:00 1.00 CEMT P COMP PRESSURE UP TO 4000 PSI TWICE, UNABLE TO RELEASE FROM LINER. PRESSURE UP TO 4800 PSI AND RELEASE FROM LINER. SET ZXP LINER TOP PACKER WITH 60,000 LBS DOWN WEIGHT AND ROTATION SEVERAL TIMES. 06:00 - 07:00 1.00 CEMT P COMP PULL OUT OF LINER HANGER. CIRCULATE AT 13 BPM. TRACE OF CEMENT RETURN. MUD WEIGHT INCREASE FROM 8.5 TO 9.0 PPG AND PH INCREASE FROM 9 TO 10 07:00 - 08:00 1.00 CEMT P COMP DISPLACE WELL TO 8.4 PPG SEA WATER. 08:00 - 09:00 1,00 CEMT P COMP RIG DOWN CEMENT HEAD AND LINES. 09:00 - 13:00 4.00 CEMT P COMP POH. LAY DOWN LINER RUNNING TOOLS. 13:00 - 20:00 7.00 EVAL P COMP RIG UP HALLIBURTON SLICK LINE. RUN MEMORY CNL FROM 10045' TO 8750'. NOTE: TEST CHOKE MANIFOLD WHILE LOGGING. 20:00 - 20:30 0.50 PERF P COMP PULL WEAR BUSHING. 20:30 - 00:00 3,50 BOPSUR P COMP TEST BOP EQUIPMENT TO 250 AND 3500 PSI FOR 5 MINUTES, RIG DOWN TESTING EQUIPMENT. NOTE: TEST WITNESSED BY CHUCK SHEEVE OF AOGCC. 3/6/2002 00:00 - 00:30 0.50 BOPSURP COMP INSTALL WEAR BUSHING. 00:30 - 01 :30 1.00 CASE P COMP TEST 7 5/8" CASING, 3 1/2" LINER AND LINER TOP PACKER TO 3500 PSI AND HOLD FOR 30 MINUTES. 01 :30 - 02:30 1.00 PERF P COMP RIG UP PERF GUN HANDLING EQUIPMENT. HOLD PJSM WITH CREW AND HALLIBURTON PERF TECH. 02:30 - 06:00 3.50 PERF P COMP RUN 2" TCP GUNS. 1220' LOADED AND 410' BLANK. 06:00 - 06:30 0.50 PERF P COMP RIG UP 21/16" TUBING HANDLING EQUIPMENT. 06:30 - 09:00 2.50 PERF P COMP RIH WITH TCP GUNS ON 2 1/16" TUBING TO 3203' 09:00 - 09:30 0.50 PERF P COMP RIG UP 4" DRILL PIPE HANDLING EQUIPMENT. 09:30 - 13:30 4.00 PERF P COMP RUH WITH TCP GUNS ON 4" DRILL PIPE. TAG LANDING Printed: 3/12/2002 10:17:54 AM ..~ ~. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-32 05-32 REENTER+COMPLETE NABORS NABORS 2ES Start: 2/17/2002 Rig Release: 3/8/2002 Rig Number: Spud Date: 7/15/1991 End: 3/8/2002 3/6/2002 09:30 - 13:30 4.00 PERF P COMP COLLAR AT 12030' 13:30 - 14:30 1.00 PERF P COMP PJSM. SPACE OUT AND FIRE GUNS. 4SPF. BOTTOM SHOT AT 12010' TOP SHOT AT 10380'. GOOD SURFACE INDICATION. OPEN WELL, FLUID LEVEL DOWN 5'. WELL STATIC. 14:30 - 15:00 0.50 PERF P COMP MONITOR WELL, STATIC. POH TO 10350' 15:00 - 16:00 1.00 PERF P COMP CIRCULATE. 2000 PSI AT 7 BPM. NO FLUID LOSS. 16:00 - 16:30 0.50 PERF P COMP MONITOR WELL, STATIC. PUMP DRY JOB. 16:30 - 00:00 7.50 PERF P COMP POH. LAY DOWN 4" DRILL PIPE. 3/7/2002 00:00 - 00:30 0.50 PERF P COMP POH. LAY DOWN 4" DRILL PIPE. 00:30 - 01 :00 0.50 PERF P COMP RIG UP 21/16" HANDLING EQUIPMENT. 01 :00 - 02:00 1 ,00 PERF P COMP LAY DOWN 50 JTS 21/16" TUBING. 02:00 - 05:30 3,50 PERF P COMP PJSM. LAY DOWN 1220' FIRED AND 410' BLANK 2" PERF GUNS. ALL GUNS FIRED. 05:30 - 06:00 0.50 RUNCOr.tP COMP PULL WEAR BUSHING. 06:00 - 07:00 1.00 RUNCOr.tP COMP RIG UP TO RUN 3 1/2" COMPLETION. 07:00 - 07:30 0.50 RUNCOr.tP COMP PRE JOB SAFETY MEETING WITH ALL HANDS. 07:30 - 20:00 12.50 RUNCOr.tP COMP RUN 3 1/2" 9.2# VAM ACE 13CR TUBING COMPLETION STRING. 20:00 - 21 :30 1.50 RUNCOr.tP COMP SPACE OUT STRING AND LAND ON TUBING HANGER WITH WLEG AT 8879'. 21 :30 - 23:30 2.00 RUNCOr.tP COMP REVERSE CIRCULATE CORROSION INHIBITED SEA WATER. 23:30 - 00:00 0.50 RUNCOr.tP COMP DROP BALL AND ROD. SET S-3 HYDRAULIC PACKER AND TEST TO 3500 PSI. 3/8/2002 00:00 - 01 :00 1.00 RUNCOr.tP COMP TEST TUBING TO 3500 PSI FOR 30 MINUTES. BLEED TO 1500 PSI. TEST ANNULUS TO 3500 PSI. 01 :00 - 02:00 1.00 RUNCOr.tP COMP BLEED TUBING PRESSURE AND SHEAR "RP" VALVE. SET TWO WAY CHECK VALVE IN TUBING HANGER. TEST TWC TO 1000 PSI. 02:00 - 04:00 2.00 RUNCOr.tP COMP CHANGE OUT DRILLING LINE. INSTALL NEW DRILLING LINE. 04:00 - 05:30 1.50 BOPSURP COMP NIPPLE DOWN BOP. 05:30 - 08:30 3.00 WHSUR P COMP INSTALL TREE AND TEST TO 5000 PSI. 08:30 - 09:30 1,00 WHSUR P COMP INSTALL DRILL SITE MAINTENACE LUBRICATOR. PULL TWC. 09:30 - 10:00 0.50 WHSUR P COMP RIG UP HOT OIL UNIT AND LINES. 10:00 - 12:30 2.50 WHSUR P COMP FREEZE PROTECT TUBING AND ANNULUS WITH 95 BBL DIESEL. 12:30 - 13:30 1.00 WHSUR P COMP SET BACK PRESSURE VALVE AND TEST TO 1000 PSI. 13:30 - 14:00 0.50 WHSUR P COMP REMOVE SECONDARY ANNULAR VALVE. NOTE: RELEASE RIG AT 14:00 HRS 3/8/20 Printed: 3/1212002 10:17:54 AM ?"""""" ..-.., C{ O;)~ OOJ 19-Mar-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 5-32A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,621.20' MD Window / Kickoff Survey 9,652.87' MD Projected Survey: 12,130.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED r,¡~.~ p I) 0 ')002 .", \ L L. Alaska Oil & Gas Cons. Commission Anchorage DEF=/NITIVE North Slope Alaska BPXA PBU _EOA DS 05, Slot 05-32 05-32 - 5-32A Job No. AKZZ22027, Surveyed: 3 March, 2002 ) SURVEY REPORT 19 March, 2002 Your Ref: API 500292219001 Surface Coordinates: 5948922.02 N, 698156.02 E (70015' 52.3932" H, 148023' 51.9586" W) Kelly Bushing: 63.5Oft above Mean Sea Level '~.. ) ....,.. .¡ -y-SLJI! OAILLING __"VICES A Halliburton Company Survey Ref: svy11138 'Sperry-Sun Drilling Services 8, Survey Report for 05-32 . 5.32A DEFINITIVE Your Ref: API 500292219001 Job No. AKZZ22027, Surveyed: 3 March, 2002 BPXA North Slope Alaska PBU_EOA DS 05 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth locI. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9621.20 32.150 24.580 8510.86 8574.36 2855.89 N 1520.16E 5951816.93 N 699600.49 E 3051.69 Tie On Point ) 9652.87 32.720 28.770 8537.59 8601.09 2871.06 N 1527.79 E 5951832.29 N 699607.71 E 7.319 3067.57 Window Point 9682.18 34.290 35.660 8562.04 8625.54 2884.71 N 1536.42 E 5951846.17 N 699615.98 E 14.030 3083.17 9715.44 36.510 42,770 8589.16 8652.66 2899.60 N 1548.60 E 5951861.37 N 699627.77 E 14.058 3102.21 9744.91 38.790 48.430 8612.50 8676.00 2912.16N 1561.47 E 5951874.27 N 699640.30 E 14.047 3120.19 9776.07 41.880 55.880 8636.26 8699.76 2924.48 N 1577.40 E 5951887.01 N 699655.90 E 18.366 3140.25 9807.19 46.740 60.160 8658.53 8722.03 2935.96 N 1595.84 E 5951898.96 N 699674.03 E 18.329 3161.59 9838.19 50.840 63.700 8678.95 8742.45 2946.91 N 1616.42 E 5951910.45 N 699694.32 E 15.767 3184.15 9869.81 55.810 67.330 8697.84 8761.34 2957.39 N 1639.49 E 5951921.53 N 699717.11 E 18.212 3208.24 9902.07 61.460 69.270 8714.62 8778.12 2967.55 N 1665.08 E 5951932.37 N 699742.42 E 18.250 3233.96 9932.57 66.220 70.140 8728.07 8791.57 2977.04 N 1690.75 E 5951942.53 N 699767.83 E 15.815 3259.28 9964.72 70.700 71.230 8739.87 8803.37 2986.93 N 1718.97 E 5951953.15 N 699795.78 E 14.287 3286.74 9996.03 74.420 73.640 8749.25 8812.75 2995.93 N 1747.44 E 5951962.91 N 699824.00 E 13.966 3313.80 10027.20 79.840 77.600 8756.19 8819.69 3003.46 N 1776.86 E 5951971.21 N 699853.21 E 21.345 3340.56 10058.46 85.000 79.510 8760.32 8823.82 3009.61 N 1807.22 E 5951978.15 N 699883.40 E 17.582 3367.07 10091.49 86.920 78.720 8762.64 8826.14 3015.83 N 1839.57 E 5951985.22 N 699915.58 E 6.283 3395.11 10137.54 90.000 77.540 8763.88 8827.38 3025.30 N 1884.61 E 5951995.87 N 699960.36 E 7.162 3434.68 10169.53 89.040 77,810 8764.15 8827.65 3032.13 N 1915.87 E 5952003.52 N 699991.42 E 3.117 3462.31 10200.11 87.970 77.210 8764.95 8828.45 3038.74 N 1945.71 E 5952010.91 N 700021.08 E 4.011 3488.76 ) 10294.47 88.860 75.780 8767.56 8831.06 3060.76 N 2037.42 E 5952035.35 N 700112.18 E 1.785 3571.19 10325.54 89.350 75.180 8768.04 8831.54 3068.55 N 2067.50 E 5952043.92 N 700142.04 E 2.493 3598.61 10372.10 88.880 76.360 8768.76 8832.26 3080.00 N 2112.62 E 5952056.55 N 700186.85 E 2.728 3639.58 10417.85 89.070 77.250 8769.58 8833.08 3090.44 N 2157.16E 5952068.16 N 700231.09 E 1.989 3679.44 10460.14 89.100 77.470 8770.25 8833.75 3099.69 N 2198.42 E 5952078.50 N 700272.09 E 0.525 3716.08 10512.10 90.400 78.130 8770.48 8833.98 3110.67N 2249.20 E 5952090.81 N 700322.57 E 2.806 3760.90 10543.37 89.450 78.280 8770.52 8834.02 3117.06 N 2279.81 E 5952098.01 N 700353.00 E 3.076 3787,76 10636.74 86.650 76.790 8773.70 8837.20 3137.20 N 2370.92 E 5952120.53 N 700443.55 E 3.396 3868.47 10698.29 87.520 75.850 8776.83 8840.33 3151.74 N 2430.64 E 5952136.64 N 700502.87 E 2.079 3922.29 10760.38 88.830 76.560 8778.81 8842.31 3166.53 N 2490.91 E 5952153.02 N 700562.72 E 2.400 3976.68 10822.94 89.040 75.790 8779.97 8843.47 3181.48 N 2551.64 E 5952169.56 N 700623.05 E 1.276 4031.51 19 March, 2002 - 9:07 Page2of4 DrilfQuest 2.00.08.005 Sperry-Sun Drilling Servié~~ (I Survey Report for 05-32 . 5-32A Your Ref: API 500292219001 Job No. AKZZ22027, Surveyed: 3 March, 2002 BPXA North Slope Alaska PBU_EOA OS 05 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Ea.tlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10884.47 91.550 76.030 8779.65 8843.15 3196.46 N 2611.32 E 5952186.10 N 700682.30 E 4.098 4085.59 ) 10916.55 92.060 75.210 8778.64 8842.14 3204.42 N 2642.38 E 5952194.88 N 700713.14 E 3.009 4113.84 10979.31 91.170 76.100 8776.87 8840.37 3219.97 N 2703.15 E 5952212.02 N 700773.49 E 2.005 4169.11 11028.47 90.120 76.670 8776.32 8839.82 3231.54 N 2750.93 E 5952224.84 N 700820.94 E 2.430 4212.12 11072.32 89.410 76.560 8776.50 8840.00 3241.69 N 2793.59 E 5952236.11 N 700863.32 E 1.638 4250.40 11165.10 88.200 77.780 8778.43 8841.93 3262.28 N 2884.03 E 5952259.08 N 700953.19 E 1.852 4330.93 11196.85 88.180 77.810 8779.44 8842.94 3268.99 N 2915.05 E 5952266.60 N 700984.02 E 0.114 4358,31 11230.95 89.260 77.000 8780.20 8843.70 3276.43 N 2948.32 E 5952274.91 N 701017.08 E 3.959 4387.84 11300.97 91.510 73.720 8779.73 8843.23 3294.12 N 3016.05 E 5952294.38 N 701084.32 E 5.680 4449.68 11355.29 98.720 73.760 8774.89 8838.39 3309.26 N 3067.95 E 5952310.88 N 701135.81 E 13.273 4498.14 11446.17 98.750 74.500 8761.09 8824.59 3333.82 N 3154.35 E 5952337.71 N 701221.54 E 0.805 4578.38 11492.69 92.520 72.230 8756.52 8820.02 3347.07 N 3198.69 E 5952352.12 N 701265.50 E 14.244 4619.99 11539.12 92.310 73.030 8754.56 8818.06 3360.92 N 3242.96 E 5952367.13 N 701309.40 E 1.780 4661.96 11583.90 89.510 72.220 8753.85 8817.35 3374.29 N 3285.68 E 5952381.62 N 701351.76 E 6.509 4702.47 11632.58 89.630 73.150 8754.22 8817.72 3388.78 N 3332.16E 5952397.33 N 701397.83 E 1.926 4746.49 11682.23 91.990 72.750 8753.52 8817.02 3403.33 N 3379.62 E 5952413.12 N 701444.89 E 4.821 4791.28 11725.09 94.290 74.350 8751.17 8814.67 3415.45 N 3420.66 E 5952426.32 N 701485.60 E 6.534 4829.70 11775.92 91.530 72.900 8748.59 8812.09 3429.76 N 3469.36 E 5952441.91 N 701533.90 E 6.132 4875.24 11818.56 89.510 72.140 8748.20 8811.70 3442.57 N 3510.02 E 5952455.78 N 701574.22 E 5.061 4913.85 ) 11877.65 94.750 74.730 8746.01 8809.51 3459.40 N 3566.60 E 5952474.09 N 701630.33 E 9.890 4966.90 11912.53 94.500 73.800 8743.19 8806.69 3468.83 N 3600.06 E 5952484.40 N 701663.53 E 2.753 4997.92 11928.25 92.960 74.910 8742.17 8805.67 3473.06 N 3615.16 E 5952489.02 N 701678.52 E 12.067 5011.90 12003.44 89.970 73.820 8740.25 8803.75 3493.31 N 3687.54 E 5952511.18 N 701750.34 E 4.232 5078.90 12091.84 92.460 75.340 8738.37 8801.87 3516.81 N 3772.73 E 5952536.91 N 701834.88 E 3,300 5157.53 12130.00 92.460 75.340 8736.74 8800.24 3526.46 N 3809.61 E 5952547.52 N 701871.50 E 0.000 5191.21 Projected Survey 19 March, 2002 - 9:07 Page30f4 DriflQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 05-32 - 5-32A Your Ref: API 500292219001 Job No. AKZZ22027, Surveyed: 3 March, 2002 8- BPXA PBU_EOA os 05 North Slope Alaska All data is in Feet (US) 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 . Magnetic Declination at Surface is 26.55r (20-Feb-O2) ) -~ The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 47.420° (True). Based upon Minimum Curvature type calculations. at a Measured Depth of 12130.00ft., The Bottom Hole Displacement is 5191.25ft., in the Direction of 47.210° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9621.20 9652.87 12130.00 8574.36 8601.09 8800.24 2855.89 N 2871.06 N 3526.46 N 1520.16 E 1527.79 E 3809.61 E Tie On Point Window Point Projected Survey ) Survey tool program for 05-32 - 5-32A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 12130.00 8800.24 AK-6 BP _IFR-AK (5-32A) DrillQuest 2.00.08.005 19 March, 2002 - 9:07 page4of4 r---.. AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ~ Re: Distribution of Survey Data for Well 5-32A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,621.20' MD Window / Kickoff Survey 9,652.87' MD Projected Survey: 12,130.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) aOd~OOI 19-Mar-O2 RECEIVED r.~ .'~. 1.') I) O. 'J002 ,f"" L L Alaska Oil & Gas Cons. CommÌ88Îùo Anchorage " North Slope Alaska BPXA PBU _EOA DS 05, Slot 05-32 05-32 - 5-32A MWD Job No. AKMW22027, Surveyed: 3 March, 2002 ) SURVEY REPORT 19 March, 2002 Your Ref: API 500292219001 Surface Coordinates: 5948922.02 N, 698156.02 E (70015' 52.3932- N, 148023' 51.9586- W) Kelly Bushing: 63. 50ft above Mean Sea Level ) 551=1= .1 .y-'" .., DRILI-ING seRVices A Halliburton Company Survey Ref: svy11139 Sperry-Sun Drilling Services 8. Survey Report for 05-32 - 5-32A MWD Your Ref: API 500292219001 Job No. AKMW22027, Surveyed: 3 March, 2002 BPXA North Slope Alaska PBU_EOA OS 05 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9621.20 32.150 24.580 8510.86 8574.36 2855.89 N 1520.16 E 5951816.93 N 699600.49 E 3051.69 Tie On Point ) 9652.87 32.720 28.770 8537.59 8601.09 2871.06 N 1527.79 E 5951832.29 N 699607.71 E 7.319 3067.57 Window Point 9682.18 34.290 35.660 8562.04 8625.54 2884.71 N 1536.42 E 5951846.17 N 699615.98 E 14.030 3083.17 9715.44 36.510 42.770 8589.16 8652.66 2899.60 N 1548.60 E 5951861.37 N 699627.77 E 14.058 3102.21 9744.91 38.790 47.780 8612.50 8676.00 2912.24 N 1561.40E 5951874.35 N 699640.23 E 12.945 3120.19 9776.07 41.880 54.860 8636.26 8699.76 2924.80 N 1577.14 E 5951887.31 N 699655.64 E 17.725 3140.28 9807.19 46.740 58.860 8658.53 8722.03 2936.64 N 1595.35 E 5951899.63 N 699673.53 E 18.008 3161.70 9838.19 50.840 62.320 8678.95 8742.45 2948.07 N 1615.67 E 5951911.59 N 699693.54 E 15.663 3184.39 9869.81 55.810 65.730 8697.83 8761.33 2959.15 N 1638.47 E 5951923.27 N 699716.03 E 17.937 3208.67 9902.07 61.460 67.660 8714.62 8778.12 2970.03 N 1663.76 E 5951934.81 N 699741.03 E 18.242 3234.66 9932.57 66.220 68,520 8728.06 8791.56 2980.24 N 1689.15E 5951945.68 N 699766.15 E 15.810 3260.26 9964.72 70.700 69.280 8739.86 8803.36 2991.00 N 1717.04 E 5951957.17 N 699793.75 E 14.107 3288.08 9996.03 74.420 71.490 8749.25 8812.75 3001.02 N 1745.18 E 5951967.93 N 699821.61 E 13.656 3315.58 10027.20 79.840 75.320 8756.19 8819.69 3009.68 N 1774.28 E 5951977.36 N 699850.47 E 21.112 3342.87 10058.46 85.000 77.370 8760.31 8823.81 3016.99 N 1804.38 E 5951985.45 N 699880.37 E 17.740 3369.98 10091.49 86.920 76.530 8762.64 8826.14 3024.43 N 1836.48 E 5951993.74 N 699912.26 E 6.342 3398.65 10137.54 90.000 77.740 8763.88 8827.38 3034.68 N 1881.35 E 5952005.16 N 699956.85 E 7.186 3438.62 10169.53 89.040 77.990 8764.14 8827.64 3041.40 N 1912.62 E 5952012.71 N 699987.93 E 3.101 3466.20 10200.11 87.970 77.470 8764.94 8828.44 3047.90 N 1942.49 E 5952019.99 N 700017.62 E 3.890 3492.59 ) 10294.47 88.860 76.070 8767.55 8831.05 3069.48 N 2034.31 E 5952043.98 N 700108.84 E 1.758 3574.80 10325.54 89.350 75.520 8768.04 8831.54 3077.11 N 2064.43 E 5952052.40 N 700138.74 E 2.371 3602.14 10372.10 88.880 76.370 8768.76 8832.26 3088.41 N 2109.59 E 5952064.89 N 700183.59 E 2.086 3643,04 10417.85 89.070 77.270 8769.57 8833.07 3098.84 N 2154.12 E 5952076.48 N 700227.84 E 2.010 3682.89 10460.14 89.100 77.580 8770.25 8833.75 3108.05 N 2195.39 E 5952086.77 N 700268.85 E 0.736 3719.51 10512.10 90.400 78.160 8770.48 8833.98 3118.97N 2246.19 E 5952099.02 N 700319.35 E 2.740 3764.30 10543.37 89.450 78.330 8770.52 8834.02 3125.34 N 2276.81 E 5952106.20 N 700349.78 E 3.086 3791.15 10636.74 86.650 76.980 8773.69 8837.19 3145.28 N 2367.95 E 5952128.54 N 700440.37 E 3.329 3871.76 10698.29 87.520 76.490 8776.82 8840.32 3159.39 N 2427.78 E 5952144.21 N 700499.81 E 1.622 3925.36 10760.38 88.830 77.240 8778.80 8842.30 3173.49 N 2488.22 E 5952159.90 N 700559.85 E 2.431 3979.40 10822.94 89.040 76.350 8779.96 8843.46 3187.78 N 2549.11 E 5952175.79 N 700620.35 E 1.461 4033.91 .------.--- 19 March, 2002 - 9:11 Page 2 0'4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services (t, Survey Report for 05-32 - 5-32A MWD Your Ref: API 500292219001 Job No. AKMW22027, Surveyed: 3 March, 200~ BPXA North Slope Alaska PBU_EOA DS 05 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 10884.47 91.550 75.800 8779.65 8843.15 3202.59 N 2608.83 E 5952192.16 N 700679.65 E 4.176 4087.90 ) 10916.55 92.060 75.160 8778.64 8842.14 3210.62 N 2639.87 E 5952201.01 N 700710.47 E 2.550 4116.19 10979.31 91.170 76.230 8776.87 8840.37 3226.12 N 2700.66 E 5952218.11 N 700770.83 E 2.217 4171.44 11028.47 90.120 76.730 8776.31 8839.81 3237.62 N 2748.45 E 5952230.85 N 700818.31 E 2.366 4214.41 11072.32 89.410 75.890 8776.49 8839.99 3247.99 N 2791.05 E 5952242.35 N 700860.62 E 2.508 4252.80 11165.10 88.200 78.420 8778.43 8841.93 3268.61 N 2881.48 E 5952265.34 N 700950.48 E 3.022 4333.34 11196.85 88.180 77.940 8779.43 8842.93 3275.11 N 2912.54 E 5952272.66 N 700981.36 E 1.512 4360,61 11230.95 89.260 77.220 8780.19 8843.69 3282.45 N 2945.84 E 5952280.86 N 701014.44 E 3.806 4390.08 11300.97 91.510 73.880 8779.72 8843.22 3299.92 N 3013.63 E 5952300.11 N 701081.75 E 5.751 4451.82 11355.29 98.720 73.990 8774.88 8838.38 3314.88 N 3065.58 E 5952316.43 N 701133.29E 13.275 4500.20 11446.17 98.750 74.770 8761.08 8824.58 3339.06 N 3152.09 E 5952342.89 N 701219.14 E 0.849 4580.26 11492.69 92.520 72.490 8756.52 8820.02 3352.11 N 3196.48 E 5952357.10 N 701263.17 E 14.252 4621.78 11539.12 92.310 73.320 8754.56 8818.06 3365.74 N 3240.82 E 5952371.90 N 701307.13 E 1.842 4663.65 11583.90 89.510 72.570 8753.85 8817.35 3378.88 N 3283.62 E 5952386.15 N 701349.57 E 6.473 4704.05 11632.58 89.630 73.900 8754.21 8817.71 3392.92 N 3330.23 E 5952401.41 N 701395.80 E 2.743 4747.87 11682.23 91.990 73.190 8753.51 8817.01 3406.98 N 3377.84 E 5952416.72 N 701443.02 E 4.964 4792.44 11725.09 94.290 74.640 8751.16 8814.66 3418.83 N 3418.95 E 5952429.65 N 701483.81 E 6.341 4830.74 11775.92 91.530 73.460 8748.58 8812.08 3432.78 N 3467.76 E 5952444.88 N 701532.23 E 5.904 4876.11 11818.56 89.510 72.120 8748.20 8811.70 3445.40 N 3508.49 E 5952458.57 N 701572.61 E 5.685 4914.64 ) 11877.65 94.750 74.830 8746.00 8809.50 3462.19 N 3565.07 E 5952476.84 N 701628.73 E 9.981 4967.66 11912.53 94.500 73.690 8743.19 8806.69 3471.62 N 3598.53 E 5952487.15 N 701661.93 E 3.336 4998.68 11928.25 92.960 74.810 8742.17 8805.67 3475.88 N 3613.63 E 5952491.80 N 701676.91 E 12.104 5012.68 12003.44 89.970 73.430 8740.24 8803.74 3496.44 N 3685.92 E 5952514.26 N 701748.63 E 4.379 5079.82 12091.84 92.460 75.230 8738.37 8801.87 3520.31 N 3771.00 E 5952540.36 N 701833.06 E 3.475 5158.62 12130.00 92.460 75.230 8736.73 8800.23 3530.03 N 3807.87 E 5952551.05 N 701869.66 E 0.000 5192,34 Projected Survey 19 March, 2002 - 9:11 Page30f4 DrillQuest 2.00.08.005 Sperry-Sun Drilling' Services Survey Report for 05-32 - 5-32A MWD Your Ref: API 500292219001 Job No. AKMW22027, Surveyed: 3 March, 2002 8- BPXA PBU_EOA DS 05 North Slope Alaska All data is in Feet (US) 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. Magnetic Declination at Surface is 26.55JO (20-Feb-02) ) ',-- The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 47.420° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12130.00ft.. The Bottom Hole Displacement is 5192.39ft., in the Direction of 47.168° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9621.20 9652.87 12130.00 8574.36 8601.09 8800.23 2855.89 N 2871.06 N 3530.03 N 1520.16 E 1527.79 E 3807.87 E Tie On Point Window Point Projected Survey ) Survey tool program for 05-32 - 5-32A MWD F ra m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 12130.00 8800.23 MWD Magnetic (5-32A MWD) DrillQuest 2.00.08.005 19 March, 2002.9:11 Page4of4 ..-.., ~ ~~ fÆ~ EmF !Æ~!Æ ~ ~~!Æ JtIIASIiA OIL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit 05-32A BP Exploration (Alaska), Inc. Permit No: 202-001 Sur Loc: 2549' SNL, 1084' EWL, Sec. 32, TllN, R15E, UM Btmhole Loc. 4307' SNL, 377' WEL, Sec. 29, T11N, R15E, UM Dear Mr. Crane: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit 05-32A. Blowout prevention equipment (HOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~ ~~f:~ C~~hSli Taylor Chair BY ORDER OF THE COMMISSION DATED this11th day of January, 2002 jjc/Enclosures cc: Department ofFish & Game, Habitat Section wlo encL Department of Environmental Conservation wlo encL STATE OF ALASKA .~ . AND GAS CONSERVATION COMM ION PERMIT TO DRILL 20 AAC 25.005 11 b Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil . 0 Service 0 Development Gas S Single zon~ 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned RKB = 65' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028326 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 05-~2A 9. Approximate spud date 01/18/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12130' MD / 8815' TVD 17. Anticipated pressure {see 20 MC 25.035 (e) (2)} 0 95 Maximum surface 2555 psig, At total depth (TV D) 8800' / 3435 psig Setting Depth TQP Botom Lenath MD TVD MD TVD 2640' 8800' 7920' 12130' 8815' II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements 564-4897 Prepared By Name/Number: Sandra Stewman, 564-4750 to the best of my knowledge Title Senior Drilling Engineer Permit Number G" Number AP~ro~1 Aate See cover letter 2Ð.2- -e;;o I 50- 029-22190-01 \ \ \ ~'('\ for other requirements Conditions of Approval: Samples Required 0 Yes .~ No Mud Log eq ired 0 Yes I!SrNo Hydrogen Sulfide Measures 0 Yes fiðNo Directional Survey Required !lYes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: Tê<;,t ~r& +0 '3C;oo fe;., ~qk Original Signed By --- Approved By Cammy Qadl.no, R' \ G \ N A L Commissioner Form 10-401 Rev. 12-01-85 ~ .. ,.-..... ALASKA' 1a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface .2549' SNL, 1084' EWL, SEC. 32, T11N, R15E, UM At top of productive interval , 4634' SNL, 2306' WEL, SEC. 29, T11 N, R15E, UM At total depth , 4307' SNL, 377' WEL, SEC. 29, T11 N, R15E, UM 12. Distance to nearest property line 113. Distance to nearest well ADL 028325, 377' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9640' MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize Hole Casina Weicht Grade Couclina 4-3/4" 3-1/2" 9.2# L-80 NSCT 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 10114 feet 9006 feet 10061 feet 8958 feet Length Cemented Plugs (measured) Junk (measured) Size 110' 20" 3498' 10-3/4" 9352' 7-5/8" 1047' 5-1/2" 11 Yards AS 2152 cu ft CS III, 405 cu ft 'G', Top Job w/ 240 cu ft CS II 1420 cu ft 'G', 318 cu ft 'G' 170 cu ft 'G' Perforation depth: measured Open: 9910'. 9934' true vertical Open: 8823' - 8844' 20. Attachments 21. I hereby certify Signed Lowell by order of the commission VJ6A j11Art i{r:¡(Ol.- 1/10 f {)Û' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Quantitv of Cement (include staae data) {2.74 sx Class 'G' RF=CJ-IV~ U DEC 2 1 2001 Alaska Oil & Gas Cons. Commission Anchorage MD TVD 110' 110' 3498' 3495' 9352' 8352' 9057' . 10104' 8117' - 8997' Date J Z -Z'::::> - Date \ \J \ Ù ~ S~ mil In Triplicate ~ /"""\ IWell Name: I DS5-32A Drill and Complete Plan Summary I Type of Well (service I producer I injector): 1 Sidetrack Horizontal Producer Surface Location: Estimated Target Location: Sadlerochit Zone 1 A Bottom Hole Location: x = 698,156.02 2549' FNL , 1084' FEL X = 699,950.00 4634'FNL,2306'FEL X = 701,869.00 4307'FNL,377'FEL Y = 5,948,922.02 Sec. 32, T11N, R15E Umiat Y = 5,952,165.00 TVDss 8775 Sec. 29, T11 N, R15E Umiat Y = 5,952,543.00 TVDss 8750 Sec. 29, T11 N, R15E Umiat I AFE Number: 14J0499 I Estimated Start Date: 101/18/2002 1 I MD: 112,130' 1 I Rig: 1 Nabors 2ES I Operating days to complete: 123.5 I TVD: 18815' I BF/MS: 135.0' 1 I AKB: 165.0' I Well Design (conventional, slimhole, etc.): 1 Horizontal Sidetrack out of 5-1/2" liner I Objective: 1 Zone 1 A / 1 ß, Sadlerochit CasinglTubing Program Hole Size Csg/ WtlFt Grade Conn Length Top Btm Tbg O.D. MDrrVD MDrrVD 4%" 3 Y2" 9.2# L-80 NSCT -2640' 8800' / 7920' 12,130' / 8815' Tubing 3 Y2" 9.2# 13Cr-80 Vam Ace -9400' GL 8800'/7920' Directional KOP: I 9,640' MD Maximum Hole Angle: Close Approach Well: Survey Program: DS5-32A Sidetrack -400 In original wellbore at 6700' MD -95.00 Through reservoir section of planned sidetrack All wells pass major risk criteria and no shut in's will be required while drilling. See Tolerable Collision Worksheet Attached. Standard MWD Surveys from kick-off to TD. Page 1 .1""""'-- /..--..., Mud Program Window Milling Mud Properties: Quickdril-N Density (ppg) 1 Viscosity I PV 1 8.4 - 8.5+ 45 - 60 5 - 8 I Whipstock Window in 5 W' I YP I tauO 1 MBT 25 - 35 5 - 8 <3 I pH 1 A~A I 8.5 - 9.0 NIC Production Mud Properties: Quickdril-N Density (ppg) I Viscosity I PV 8.4 - 8.5+ 45 - 60 5 - 8 I 4 %" hole section YP 1 tauO 20 - 25 5 - 8 I MBT <3 I pH I API FI I 8.5 - 9.0 NIC Logging Program 4 %" Production: Sample Catchers - None Drilling: MWD IGR 1 Res- Real time over entire interval. Open Hole: None Cased Hole: Memory CNL, on slickline (DPC contingency) Cement Program I Casing Size I 3 1/2" Production Liner Basis: Lead: None Tail: Based on 90' of 3-1/2" shoe track, 2490' of open hole with 50% excess, 584' of 3 W' x 5W' liner lap, 200' of 3 W' x 7 5/8" liner lap, and 200' of 7 5/8" x 4" DP annulus volume. Tail TOC: -8900' /' MD (7996'TVD).- Liner top. I Fluid Sequence & Volumes: Pre 10 Bbls Water Flush Spacer Lead Tail 30 bbls Alpha Spacer at 9.7 ppg None 56 bbl I 316 fe I 274 sks of Halliburton 'G' at 15.9 ppg and 1.15 disk, BHCT = ---OF I BHST 187°F TT = Batch Mix + 4 to 4.5 hrs Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blindlshear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- . Maximum anticipated BHP: 3435 psi @ 8800' TVDss - Ivishak . Maximum surface pressure: 2555 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psilft) . Planned BOP test pressure: Planned completion fluid: 3500 psi 8.6 ppg seawater I 7.2 ppg Diesel . Disposal . No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . . OS5-32A Sidetrack Page 2 Formation Markers Formation Tops (wp2) KINGAK T JFITOP KINGAK F T JDITOP KINGAK D T JAITOP KINGAK A TSGR TSAD TCGL (TZ3) BCGL (TZ2C) 23SB (TZ2B) 21TS (TZ2A) TZlB TDF (TZIA) BSAD TD Criteria: Target polygon ~ ,~ MD TVDss Comments Above casing window " " " " " " -8230 -8329 " " -8462 " " 9,655 -8520 9,707 -8581 9,807 -8656 9,893 -8708 7.5 ppg EMW expected pore pressure 10,000 -8753 -8774 NOT PENETRATED Sidetrack and Complete Procedure Summary RiQ Operations: 1. MIRU Nabors 2ES. 2. Pull BPV. Circulate out freeze protection anjdisplace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull seals from upper production packer at 8800' MD. POOH laying down 4W' x 3W' completion. 5. Make-up packer mill with packer retrieving tool. RIH and mill 7-5/8" packer. Catch packer with packer retrieving tool via mill out extension. POOH with packer and tubing tail. 6. RU E-line and make g.R/JB run to top of tubing cut. MU bridge plug. RIH and set at 9,657'. 7. Test wellbore to 3500 psi for 30 minutes. 8. RIH with 5-1/2" Baker whipstock assembly. Orient ~pstock as desired and set on bridge plug. Mill window in 5-1/2" casing at 9,640'MD. Perform FIT to 10.0 ppg EMW. POOH. 9. MU 4-3/4" drilling assembly with MWD/GR/Res and RIH. Kick-off and drill the 4-3/4" production interval, building at -12°/100' to horizontal, targeting the Zone 1 sands. Drill ahead to an estimated total depth of 12, "!,9°' MD (8815' TVD). 10. Run and cement a 3-1/2",9.2# solid production liner throughout the 4-3/4" wellbore and back into the 5-1/2" and 7-5/8" casing to the liner top at -8,800'. Displace well to seawater above liner top. POOH. 11. Test the 3-1/2" and 7-5/8" casing from the 3-1/2" landing collar to surface to 3500psi for 30 minutes. 12. PU Schlumberger memory CNL and RIH on slickline. Run log through build section of well. POOH and download log to identify GOC prior to perforating. 13. PU Halliburton 2" perf guns and RIH on DP. Perforate -1000' of Zone 1 in the horizontal section POOH LD DP. 14. Run 3-1/2", 9.3# 13Cr-80 completion tying into the 3-1/2" liner top. 15. Set packer and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 16. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 17. Freeze protect the well to -2200' and secure the well. 18. Rig down and move off. Post-Riq Work: 1. MIRU slickline. Pull the ball and rod I RHC plug from IX' nipple below the production packer and install gas lift valves. DS5-32A Sidetrack Page 3 .~ ~ .",_w,; ..",- ~'m mL..".."=....".""".....M',,".',, ,. """,_'n .,"=......~=- Job 1: MIRU Hazards and Contingencies ~ No wells will require shut-in for the rig move to DS5-32. DS5-1 C to the north is on 60' center and DS5-2 to the south is on 120' center from DS5-32. Only DS5-1 C is currently producing, though DS5-28 and 5-02A are expected to be drilled prior to DS5-32A and will possibly be on production by rig accept on DS5-32 ~ DS-5 is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Adjacent producers at Surface: 5-13A 3 ppm March-97 5-02 No recorded H2S Closest BHL Wells 5-1C No recorded H2S 5-02 No recorded H2S The maximum recorded level of H2S on the pad was 27 ppm. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud ~,=,=,,"~,= Job 2: Decomplete Well Hazards and Contingencies ~ The perforations and bottom section of this well will be open until the bridge plug has been set. Keep the hole full with seawater and pump LCM as required until after the de-completion. ~ The tubing pull is somewhat complicated by the dual SSSV control line and the chemical injection line and associated clamps. A thorough pre-job safety meeting will help ensure a safe process is in place to manage the recovered equipment. ~ NORM test all retrieved well head and completion equipment. ...,-- Job 3: Run Whipstock Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which may have settled out. _m ,==,....,'~ ._.~'m='m =- Job 7: Drill 4 3/4" Production Hole Hazards and Contingencies ~ There are no faults or significant structural concerns in this well. Polygon runs parallel to the well trajectory about 200' either side such that well path will bisect the drainage between 5-13A to the north and 5-02A to the south. ~ BHP is an estimate only; there have been no recent pressure static surveys in the area. The likely range is from 3300 psi to 3430 psi. ~ In zone 1, only DS5-15B has experienced losses while drilling (70 bbls). The Sag River and Shublik appear to be the only serious lost circulation zones on DS-5. DS5-32A will be kicking off significantly deeper at the base of Zone 3. ~ Drilling Close Approach: All wells BP Close Approach guidelines. See the "Directional" section for a description of the two nearest wells. ~ Stuck pipe (presumed differential sticking) has been an issue on DS-5 as well as lost circulation. Review the pad data sheet for details. Though most of the incidents occurred above Zone 2, lower zones are not immune to these problems. ~ The wellsite geologist should make every attempt to correlate shales in the build section, and adjust the SSTVD of the landing if necessary, to avoid drilling into Kavik. We aim to land 5-10' above Kavik DS5-32A Sidetrack Page 4 ,---, ~ ~ If the reservoir q~ity in Zone 1 A is favorable, we may decide to not toe up into 1 B and perhaps even TD the well early (when we have 1000' of perf-able sand in 1 A) ~,~,' Job 9: Install 4112" Production liner Hazards and Contingencies --- ~ Differential sticking could be a problem. The 8.5 ppg Ouickdril will be -500 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~.. ==m. nm=.._...- ~=, Job 10: OPC Perforate Hazards and Contingencies ~ The well will be perforated overbalanced after running- cased hole logs. Ensure all personnel are well-briefed on Halliburton's perforating procedures and that all responsibilities are understood. Essentially personnel only should be present on the rig floor while making up DPC guns. ~ Expect to lose fluid to the formation after perforating. Have ample sea water on location and be prepared with LCM if necessary. _.Æ~=~~' _.m.."m___...~. Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. ,...........-.-- .m_~..""-,, Job 13: NO/NU/Release Ria Hazards and Contingencies ~ See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. M.M"""~' ,-.., ""M" DS5-32A Sidetrack Page 5 TR~= , WELLHEAD= CrN ~.~~,~,~-" ,.,~-"-,-,~"'" ACTUATOR= Axelson '" -"~,, KB. ELEV = 70' ~--""""~'"""" w , w,'~'w , BF. ELEV = 35 '°, m..w..~.. KOP= 4176' """,M'"'~~"~~.W",'M"""'~"W~~',,,, Max Angle = 4~m~8900' Datum MD = -'-"".""'w'."W~~~"""'.""~ Datum TVD= 8800' ss ,~ r--l SAFETY NOTES: 5-32A 12200' 1 X-Nipple, 2.813" ID I STA MD TVD DEV TYÆ MAN LATCH 110-3/4" 45.5# J-55 1 BTC I 3497' 1---4 ~ 3-1/2" 9.2#/ft 13-Cr Vam ACE Tubing l GLMS TBD GLM4 TBD GLM3 TBD GLM2 TBD GLM1 TBD 3 1/2x1 1/2" 3 1/2x1 1/2" 3 1/2x1 1/2" 3 1/2x1 1/2" 3 1/2x1 1/2" Minimum 10 = 2.725" XN nipple ~ORATIONSUMMARY REF LOG: BHCA 07/28/1991 I IS,7S0' I 3-1/2" X 2.813" ID I ANGLEAT'roPÆRF:"1 29 at 9910' I Note: Refer to Production DB for historical perf data Z Z IS,SOO' 1 7-5/8" x 3-1/2" Pkr ¡- SIZE SPF INTERVAL Opn/Sqz I DATE I IS,S45' 1 3-1/2" X 2.813" ID I 2.5" 4 9910' - 9934' Open below bridge plug ~ S,S65' 3-1/2" XN 2.725" ID l IS,SSO' 1 WLEG/Liner Top I . . IS,9O0' 1 I ~ ~ 5-1/2" Hanger/Pkr .... I 19,056' 1 5-1/2" Liner Top I ¡¡¡¡ ~ ~ 19,352' 1 7-5/8" 29.7# L-80 I 19,640' 1 5-1/2"window '- " ~Î 3-1/2" 9.2#/ft L-80 NSCT PBTD 12,045' MO WellTD 12,130' MO""- I 5-1/2" 17#/ft 13-Cr I I 10,144' I ~X X X, DA TE REV BY COMMENTS 07131/91 Original Corrpletion 10/15/01 PGS Sidetrack Proposed Corrpletion PRUDHOE BA Y UNfT WELL: 5-32A ÆRMfT No: 91-089 API No: 50-029-22190-01 Prudhoe Bay Unit OOIA'3lJmlE 1)"00) mMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM BPAm"", Cel","tloo Móhod, Mlrnmmn """""" Enot Sy"'m, ISCWSA S",Mothod, TmvCylittdotNooh EnotS,""œ, EII~ti"I+C~ing W.ml""Móhod, Rw,,""'" Co-omlœte(NÆ) Rofo"'<!<e' WoIlCe",re,O'.32,T~Nooh Vo",,1 (1VD) Rofo"'<!<e' "65.00 Soctim (VS) Rof"""", Slot - 32 (O.OON,O.ooE) M"~redDopthRof""",,," 65.00 Cakol,tio,Mothod MinintwnCtoM,"", Dopth Fm Dopth To SaNoylPl~ %40.00 12131.13 _5.32A."o2VI Tool Wellpath, (05-321P1an 5-32A) Created By, Ken Allen Oat., 8130/200 I MWD Checked, - Dal"_~ Oat., --~ Reviewed, WEll DETAILS N""" +Nt.S +I"-W Noohl"" ""'921.71 F~"'"" '~tito'" I.mglto'" Slot 7200-- //~ I //>~ // / ~ / / / /~ . '~ " ø ///~/ / /~=:~ ~ l / />~/ /~--------~~ I////I//~------------ ~------ 1/// //1/ /------------- ¡-- ------~ ~ .I / / /1 / /'-~ '----i-. . ~ ~/. / ---- 1----------------------------- ". // ~ 1// /, ~ -1/// ' 1// ,1/ ,I .l OS-32 1697.44 71222 698156.32 70"15'52.39ON 148"23"1.950W 32 TARGET DETAilS N"", 1VD +Nt-S +EI.W NonhI08 595227029 5951970.19 595238033 595254338 Ea""" Shape 700J19,65 Point 699969,69 Polot 701309,64 Point 701869,63 Poinl 5-32A 1'2 5.32A TI 5.32AD 5-32A T4 8845,00 3274,87 2850,67 8840.00 2999,86 1893.08 8815.00 3374.61 3243.44 881',00 3522,89 3807,55 7800-- .# #' ~() "., '/~ " SECTION DETAILS See MD Ine Azi TVD +N/-S +EI-W DLeg TFace VSee Target I 9640.00 32.15 24.58 8590,51 2864.22 1524.01 0.00 0.00 3063.83 ) 2 9660.00 33.10 28.67 8607,35 2873.85 1528.85 12.00 68.37 3073,92 3 10058.59 80.78 87.85 8831.40 2989.74 1809.11 16.50 68.37 3358,35 4 10062.64 80.78 87.85 8832,05 2989.89 1813.10 0.00 0,00 3361.38 5 10143.77 88.00 78.00 8840,00 2999.86 1893.08 15.00 -54.18 3426,85 5-32A Tl 6 10181.12 89,74 73.87 8840,74 3008,94 1929,29 12,00 -67,19 3459,59 7 11108.49 89,74 73.87 8844,93 3266,58 2820,14 0.00 0.00 4288.47 8 11140,13 90,00 75.75 8845,00 3274,87 2850,67 6.00 82.16 4316,51 5-32A T2 9 11231.00 95.45 75.75 8840,68 3297,21 2938.61 6.00 0,01 4396,23 10 11455.78 95.45 75.75 8819.32 3352,28 3155.49 0.00 0,00 4592,82 II 11546,66 90.00 75.75 8815.00 3374,61 3243.44 6.00 -179,99 4672.55 5-32A T3 12 11558,69 90.00 75.27 8815,00 3377.63 3255,09 4.00 -90,00 4683,15 13 12129,93 90.00 75.27 8815.00 3522.89 3807.55 0.00 0,00 5187,31 5-32A T4 CASING DETAILS 7500-- :s 4': 0 Ë '" ß- CI õI 'f! 8100-- " > ~ No. TVD MD Name Size 8815.00 12129.92 3 1/2" 3.500 All TVD depths are ssTVD plus 65' for RKBE. FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 8646.00 9707.04 23SB (TZ2B) 2 8721.00 9807.47 2ITS(TZ2A) 3 8773.00 9892,88 TZIB 4 8818.00 10000.39 TDF (TZIA) 5 8839.00 10123.94 BSAD ) 8400 \ StartDir 121100': 9MO'MD,8590.5I'TVD - \\'\.::/~ Start D:r 165/100': ~660 MD, 8607.3~'TVD - I :, ",°R (T7"-) 8700 \ ~ End Dlr : 10058.59' MD 8831.4' TVI: '\~' lT~T7?A)' \.. 4\ u . / / :;, art VIr I ,/lOW: I JO61.64' \1D,883l.05'TVD \ ~ WI~ 1/ , I ~4 (TZIA) , ~ , 10000 --¡ \~AD \ End Dir 10181.12' MD, 8840.~4' TVD 1\ Start Dif 12100': 10143.77' lD. 8840TVD 1 \ I Start Dir 61100': 11108.49' MD, 8844.93'TVD I End Dir-: ¡1231'MD,1;840;68'TVD I SUrt I:ir61100': 1 1"55.i8' w.D, ~19.32'TVD -~_. ! Start Dir 41100': 1154?66'MD, 8815'T"D i End Dir : 115:8,69' MD, 8815' TV.D / 31/2" I I ri ' r'T7'" 4' I , I D. "-"'J '" --=----'--<\- I \ ~ "i: 12000 \ MAr 0 Toul Depth 12L29.93' MD, 8H5' TVD llOoœ 9000 3000 3300 3600 3900 4200 4500 Vertical Section at 47.220 [300ft/in] 4800 5100 5400 I 5700 3600 :s <= 0 ~ :;- ~ 3300 ~ :Ei :; 0 '" 3000 2700 1200 ffiMPANY DETAILS BP Am"'" REFERENCE INFORMATION Co.m"i..'" (NIE) Rer,re~, wen O'n"" 05.32, Tnæ N- V,""',I (lVD) Rerere~' 6565.00 "'tioo (VS) Relère~, Slot. 32 (O.OON,O.OOE) M,,",ured Dopth Rereren", 65 65.00 C.kul,tionM,- MinimwnCu"""'" SURVEY PROGRAM Dop", Fm Doptb To Su""yIP"" Plan, 5.32A wp02 (05-32IPlan 5.32A) Created By, Ken Allen Date, 8/30/2001 Tool MWD 9640.00 12129.93 P- 5.32A wpO2 VI OokuJ"iooMothod, MinimwnCwv,ture EnmSy""" ISCWSA ",..Method, Tœ,Cyti"""N- E~su...", Ellipti'" +ea.m, W,mi""Mothod Rul",.""" Checked, -.--------. Date' - Dat" ----- Reviewed, --- WEll DETAILS FORMATION TOP DETAILS No. TVDPath MDPalh Formation ""'" +NI-S 05.32 1697.44 +F).W Long,"..k Slot NO<thi"" 5948921.71 Eo""" Latitu'" 698156.32 70"15'52390N 148OZ3'51.950W 32 77222 8646.00 9707,04 23SB (TZ2B) 8721.00 9807.47 2ITS(TZ2A) 8773.00 9892.88 TZIB 8818.00 10000,39 TDF(TZIA) 8839.00 10123.94 BSAD I 2 3 4 5 TARGET DETAILS +EJ.W NO<thin, 595227029 5951970.19 5952380.33 5952543.3' F-""'"" Sh'p' 700919.65 Point 699969.69 Point 701309.64 Point 701869.63 Point TVD +Nt-S N~ CASING DETAILS 5.32A T2 5.32A TI 5.32A T3 5.32A T4 8845.00 3274.87 2850.67 8840.00 2999~6 1893.08 8815.00 3374.61 3243.44 8815.00 3522.89 380755 MD Name Size 3.500 SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFace VSee Target 1 9640.00 32.15 24.58 8590.51 2864.22 1524.01 0.00 0.00 3063.83 ) 2 9660.00 33.10 28,67 8607.35 2873.85 1528.85 12,00 68.37 3073.92 3 10058.59 80.78 87.85 8831.40 2989.74 1809.11 16,50 68.37 3358.35 4 10062.64 80,78 87.85 8832.05 2989.89 1813.10 0,00 0,00 3361.38 5 10143,77 88.00 78.00 8840.00 2999.86 1893.08 15.00 .54.18 3426.85 5-32A Tl 6 1018\,\2 89.74 73.87 8840.74 3008.94 1929.29 12,00 -67.19 3459.59 7 III 08.49 89.74 73.87 8844.93 3266.58 2820.14 0.00 0.00 4288.47 8 11140.13 90,00 75.75 8845,00 3274.87 2850.67 6,00 82.16 4316.51 5-32A T2 9 11231.00 95.45 75.75 8840.68 3297.21 2938.61 6,00 0,01 4396.23 10 11455,78 95.45 75.75 8819.32 3352.28 3155.49 0,00 0,00 4592,82 II 11546.66 90.00 75.75 8815.00 3374.61 3243.44 6,00 -179.99 4672.55 5-32A T3 12 11558.69 90,00 75.27 8815.00 3377.63 3255.09 4,00 -90,00 4683.15 13 12129,93 90,00 75.27 8815.00 3522.89 3807.55 0.00 0,00 5187.31 5-32A T4 No. TVD 8815.00 12129.92 31/2" All TVD depths are ssTVD plus 65' for RKBE. Totl! D th. , ep : 212 .93' MD ,8g15' TVD '."A n ---------- ~ '."A r. ~ I ,."^ n ' "" .\.---~ -- EncDir,115' I - ~ ,', .,~"""",'¡~~~ID,..'" ------, -------- ,'" 0;" """" ~, 0;, "' '" , t"" ~, ' Mn, "t~" '"A " -------~ ... œ, ,.,'" o. ....... NO . , ~. """'M> ~ ------- " """ M -'1 ~- "" ' ' D,~""~ SIanDrIDIT:018112' End~' I.: 10058 ' ,2/(ùù': lùI4~, n~b 8840.74' TVD S,an Dir 16:S114 Scan 'r 15/1O0;.,5ioOMD, 8831.4' TVD ,0840" vu . "0--:-<'.6'60' ' m.64' MD . Stan Djr 121100': 9640' "'\>If), 6ß7::35TVD . g832.05TVD - ~"T"~ ) 1---'- . ---------- / ! ! ! I I ! ! ! I ! ! ! ! ! I I 3000 3300 3600 3900 1500 1800 2100 2700 West(-)Æast(+) [300ft/in] 2400 .~ ~ BP Amoco Planning Report - Geographic 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 BGGM2001 PB DS 05 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5947204.70 ft 697428.91 ft Latitude: 70 15 35.696 N Longitude: 148 24 14.424 W North Reference: True Grid Convergence: 1.50 deg Well: 05-32 05-32 Suñace Position: +N/-S 1697.44 ft +E/-W 772.22 ft Position Uncertainty: 0.00 ft Reference Point: +N/-S 1697.44 ft +E/-W 772.22 ft Slot Name: 32 Northing: 5948921.71 ft Latitude: 70 15 52.390 N Easting: 698156.32 ft Longitude: 148 23 51.950 W Northing: 5948921.71 ft Latitude: 70 15 52.390 N Easting: 698156.32 ft Longitude: 148 23 51.950 W Measured Depth: 31.00 ft Inclination: 0.00 deg Vertical Depth: 31.00 ft Azimuth: 0.00 deg Wellpath: Plan 5-32A Current Datum: Magnetic Data: Field Strength: Vertical Section: 65 Drilled From: 05-32 Tie-on Depth: 9640.00 ft Height 65.00 ft Above System Datum: Mean Sea Level Declination: 26.72 deg Mag Dip Angle: 80.80 deg +N/-S +E/-W Direction ft ft deg 0.00 0.00 47.22 Date Composed: 8/30/2001 Version: 1 Tied-to: From: Definitive Path 8/27/2001 57508 nT Depth From (TVD) ft 0.00 Plan: 5-32A wp02 Principal: Yes Plan Section Information 9640.00 32.15 24.58 8590.51 2864.22 1524.01 0.00 0.00 0.00 0.00 9660.00 33.10 28.67 8607.35 2873.85 1528.85 12.00/ 4.76 20.44 68.37 10058.59 80.78 87.85 8831.40 2989.74 1809.11 16.50: 11.96 14.85 68.37 10062.64 80.78 87.85 8832.05 2989.89 1813.10 0.00 0.00 0.00 0.00 10143.77 88.00 78.00 8840.00 2999.86 1893.08 15.00 8.90 -12.14 -54.18 5-32A T1 10181.12 89.74 73.87 8840.74 3008.94 1929.29 12.00 4.66 -11.06 -67.19 11108.49 89.74 73.87 8844.93 3266.58 2820.14 0.00 0.00 0.00 0.00 11140.13 90.00 75.75 8845.00 3274.87 2850.67 6.00 0.82 5.94 82.16 5-32A T2 11231.00 95.45 75.75 8840.68 3297.21 2938.61 6.00 6.00 0.00 0.01 11455.78 95.45 75.75 8819.32 3352.28 3155.49 0.00 0.00 0.00 0.00 11546.66 90.00 75.75 8815.00 3374.61 3243.44 6.00 -6.00 0.00 -179.99 5-32A T3 11558.69 90.00 75.27 8815.00 3377.63 3255.09 4.00 0.00 -4.00 -90.00 12129.93 90.00 75.27 8815.00 3522.89 3807.55 0.00 0.00 0.00 0.00 5-32A T4 Section 1: Start 9640.00 32.15 24.58 8590.51 2864.22 1524.01 3063.83 0.00 0.00 0.00 0.00 9650.00 32.61 26.65 8598.96 2869.05 1526.33 3068.81 12.00 4.59 20.70 68.37 9660.00 33.10 28.67 8607.35 2873.85 1528.85 3073.92 12.01 4.91 20.20 66.73 ~ /"'"'.., BP Amoco Anticollision Report GLOBAL SCAN APPLIED: All wellpaths within 200'+ 10011000 of reference - There ar~...ells in th¡¡>~al Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 9640.00 to 12129.93 ft Scan Method: Trav Cylinder North Maximum Radius: 1409.89 ft Error Surface: Ellipse + Casing I I Survey Program for Definitive Well path -I Date: 8/30/2001 Validated: No Version: 3 Planned From To Survey Toolcode ft ft ~--- 65.20 9640.00 9640.00 12129.93 Tool Name 1 : Schlumberger GCT multishot Planned: 5-32A wp02 V1 GCT-MS MWD Schlumberger GCT multishot MWD - Standard Casing Points 12129.92 8815.03 3.500 4.750 31/2" Summary PB DS 05 05-02 Plan 05-02A V4 Plan: 0 12115.29 11625.00 917.36 615.82 301.55 Pass: Major Risk PB DS 05 05-13 05-13 V1 11230.61 10975.00 932.98 475.78 461.32 Pass: Major Risk PB OS 05 05-13A 05-13A V1 12061.57 11925.55 729.01 489.51 264.96 Pass: Major Risk PB DS 05 05-30 05-30 V1 9640.00 9550.00 1013.65 238.15 782.96 Pass: Major Risk PB DS 05 05-32 05-32 V1 9669.93 9675.00 1.32 188.10 -174.72 FAIL: Major Risk PB DS 05 05-32 Plan 05-32A COIL VO PI 12129.92 12225.80 0.17 285.25 -284.97 FAIL: Major Risk PB OS 11 11-34 11-34 V1 Out of range --- ._----~- Site: PB OS 05 Well: 05-02 Wellpath: Plan 05-02A V4 Plan: 05-02a wp03 V1 Rule Assigned: Inter-Site Error: Major Risk 0.00 ft 10706.33 8843.12 10150.00 8859.26 25.74 150.01 164.57 90.70 6.125 1404.03 560.37 843.56 Pass 10722.94 8843.19 10175.00 8859.47 25.89 150.01 164.58 90.71 6.125 1385.34 560.88 824.37 Pass 10740.50 8843.27 10200.00 8859.67 26.06 150.02 164.60 90.73 6.125 1367.56 561.42 806.04 Pass 10758.96 8843.36 10225.00 8859.87 26.22 150.02 164.61 90.74 6.125 1350.71 561.97 788.64 Pass 10778.28 8843.44 10250.00 8860.06 26.40 150.03 164.63 90.76 6.125 1334.85 562.55 772.21 Pass 10798.41 8843.54 10275.00 8860.24 26.59 150.04 164.64 90.77 6.125 1320.03 563,14 756.79 Pass 10819.28 8843.63 10300.00 8860.41 26.79 150.05 164.65 90.78 6.125 1306.28 564.21 741.98 Pass 10840.85 8843.73 10325.00 8860.58 27.00 150.06 164.66 90.79 6.125 1293.64 564.87 728.68 Pass 10863.05 8843.83 10350.00 8860.73 27.22 150.07 164.67 90.80 6.125 1282.15 565.54 716.51 Pass 10885.81 8843.93 10375.00 8860.88 27.44 150.08 164.68 90.81 6.125 1271.83 566.23 705.51 Pass 10909-09 8844.04 10400.00 8861.02 27_68 150.09 164.69 90.82 6.125 1262.72 567.36 695.26 Pass 10932.81 8844.15 10425.00 8861.15 27.92 150.11 164.69 90.82 6.125 1254.84 568.11 686.64 Pass 10956.82 8844.25 10450.00 8861.26 28.17 150.13 164.70 90.83 6.125 1247.87 568.86 678.92 Pass 10980.84 8844.36 10475.00 8861.38 28.42 150.14 164.70 90.83 6.125 1240.95 569.62 671.24 Pass 11004.87 8844.47 10500.00 8861.50 28.67 150.16 164.71 90.84 6.125 1234.03 570.84 663.10 Pass 11028.89 8844.58 10525,00 8861.62 28.94 150.18 164.71 90.84 6.125 1227.10 571.64 655.38 Pass 11052.91 8844.69 10550.00 8861.74 29.20 150.20 164.72 90.85 6.125 1220.18 572.44 647.65 Pass 11076.93 8844.80 10575.00 8861.85 29.46 150.22 164.72 90.85 6.125 1213.26 573.24 639.93 Pass 11100.95 8844.91 10600.00 8861.97 29.72 150.24 164.73 90.86 6.125 1206.33 574.04 632.21 Pass 11163.79 8844.72 10625.00 8862.09 30.20 148.97 166.63 90.88 6.125 1198.75 571.97 626.62 Pass 11187.09 8843.86 10650.00 8862.21 30.49 149.01 166.68 90.93 6.125 1191.06 572.80 618.04 Pass 11210.33 8842.44 10675.00 8862.32 30.78 149.05 166.76 91.01 6.125 1183.38 573.76 609.32 Pass 11233.53 8840.45 10700.00 8862.44 31.07 149.10 166.88 91.13 6.125 1175.71 574.89 600.44 Pass 11257.20 8838.21 10725.00 8862.56 31.35 149.13 167.00 91.25 6.125 1168.05 575.76 591.89 Pass 11280.86 8835.96 10750.00 8862.68 31.63 149.15 167.12 91.37 6.125 1160.40 576.63 583.34 Pass ---_____--n___.__------- .----- " ".-... .~ . OST THIS NOTICE IN THE DOGHOUSE 5.32A Rig site Summary of Drilling Hazards ./ Standard Operating Procedures for H2S precautions should be followed at all times. Very little recent data on H2S on DS-5 exists. The highest concentration currently on record is on DS5-05 @ 27 ppm, (November 1990). ./ The perforations and bottom section of this well will be open until the bridge plug has been set. Keep the hole full with seawater and pump LCM as required until after the de-completion. ./ The tubing pull is somewhat complicated by the dual SSSV control line and the chemical injection line and associated clamps. A thorough pre-job safety meeting will help ensure a safe process is in place to manage the recovered equipment ./ All wells pass major risk criteria. No wells will require shut-in for the rig move to 085-32. 085-1C to the north is on 60' center and 085-2 to the south is on 120' center from 085-32. Only 085-1 C is currently producing, though 085-28 and 5- 02A are expected to be drilled prior to DS5-32A and will possibly be on production by rig accept on DS5-32. ./ Lost circulation may also be experienced while drilling, especially through the fault crossing at ::1:11,400' MD. The SSD lost circulation tree should be followed if lost fluid returns are encountered. ./ Differential sticking is of great concern in this depleted reservoir. Overbalance is approximately 500 psi. Always follow established drilling and connection practices for stuck pipe prevention. ./ Follow all service company rules and regulations while handling perf guns and ensure only the necessary people are on the rig floor during make up and RIH. ./ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. DS5-32A / /' H 202451 DATE INVOICE I CREDIT MEMO 120501 CK120501A PYMT COMMENTS: HANDLING INST: ~ DESCRIPTION Permit to Drill ~ee SIH - Terrie Hub)le D~-~M THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY TOTAL ~ i / ¡ ~/ """""" " "r' ,." GROSS 1 DATE I I CHECK NO. I 12/07/01 00202451 VENDOR ALASKAOILA 00 DISCOUNT NET 100.00 100.00 H X4628 100.00 100_00 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK ClEVELAND, OHIO No. H 202451 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 ---:IT2' 00202451 ONE HUNDRED & 00/100************************************* US DOLLAR To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK99501 DATE 12/07101 I I NOT VALID AFTER 120 DAYS Ç( ~ ß(V: L( AMOUNT $100. 001 11.202~S¡II. I:O~¡20~BqSI: OOB~~¡qll. r--, ~, TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERIPARAGRAPHS TO BE INCLUDED IN TRANSNDTTALLETTER WELL NAME æd CHECK 1 STANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) DEVELOPME7 REDRILL V PILOT HOLE (PH) EXPLORA nON ANNULf~OSAL , NO INJECTION WELL ANNULAR DISPOSAL <-> YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL o~ç~¿4 "CLUE" The permit is for a new wellbore segment of existing weD ~PermitNo, ,API No. " Production should continue to be reported as a function of the original API number stated above. . In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated.. . ANNULUS <-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .súbject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. ~ß¿t WELL PERMIT CHECKLIST COMPANY ~x: - WELL NAME {)Ç 3zA PROGRAM:.exp - dev Iredrll /' serv - well bore seg _ann. disposal para req- FIELD & POOL (at.jD/~ INITCLASS -d)E:1/ 1'O/L- GEOLAREA 89ò UNIT# O//hS7:) ON/OFFSHORE V/L ADMINISTRA TION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . rY)N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . roN 3. Unique well name and number... . . . . . . . . . . . . . . . 4. Welilocatedinadefinedpool.. .., . ..... . . . . .. . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficientacreageavailable'indrillingunit............ Y N 8. If deviated, is wellbóre plat induded.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . , . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . \ N APPR DATE 12. Permit can be issued without administrative approval.. . . . . N ft ¡,1,~ 13.Canpermitbeapprovedbefore15-daywait........... éJ)N 14. Conductor string provided. . . . . . . . .. . . . . . . . . . Y N /'il A 15. Suñace casing protects all known USDWs. . . . . . . . . .." Y N NIA. 16. CMT vol adequate to circulate on conductor & suñ csg. . . . . Y N NIA 17. CMT vol adequate toUe-in long string to suñ csg. . . . . . . . Y N ¡J/A 18. CM~ will co~er all known productive horizons. . . . . '. . . . . iN A&.e '6 I.Ul- t fVtLC . c.e WI.. ~~ 19. Casing designs adequate for C. T, B & permafrost. . . . . . . 'N I 20. Adequatetankageorreservepit........ .. .. " ... N Ak.f)or'" 2(£<;' 21. If a re-drill, has a 10-403 for abandonment been approved. . . N'N Clt I>.fp Yild. t I e>{o'Z- 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . Y N ¡JI¡:'" 24. Drilling fluid program schematic & equip list adequate. . . . . tf2 N ' 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . IN ¡J.. 'Z.. G,:> . 26. BOPE press rating appropriate; test to '~S 00 psig. .. N M S P -:: z..~5S f ~ ' , 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N , 28. Work will occur without operation shutdown. . . . . 0 . . . . 0 N ' 29. Is presence of H25 gas probable.. . . . . . 0 . . . . . . 0 . 0 Y @:ì GEOLOGY, 30. Permit can be issuedw/o hydrogen sulfide measures. . . o. .....-1Y)N CltJsti':;.--I- dh.l~&>d1.X~ IL4-NL. /10 ~CiPd II~~ '~~I?L~~. 31. Data presented on potential overpressure zones . . 0 . . . . '-VA ¡<fd.jaL':-IL"¿ ~Is. ~ s,(..<,...ç~ ~t.A-e..iM..¿<f..:SVrl'-<::I ~<1 ()- 3F(frl1. ~S'.49- 32. Seismic anal~~is of shallow gas zones. . . 0 . . . . 0 ;.do .0 A?f N /l^-hL~qW ~J.o/t:Þ¿!7' ~<;!:UvE- v<J7.S> õiffI é#7tJ. ~ AP~ DATE 33. Seabed condition survey (If off-shore). . . . . 0 . 0 0 . . . . Y N ~ v (. ì. Oz....-- 34. Contact name/phone for weekly progress reports [exp/ora only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . 0 . . . . . Y N (B) will not contaminate freshwater, or cause drilling waste. " Y N to suñace; , (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing fonnation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ~~~¿ <~ V' WM8t's I/~ ~~ . ~ t~~ JMHO~~f( Ó~?/ fD/6'2/ { ENGINEERING A~cfÅ llfJ¿ ( ~',- APPR DATE c 0 Z 0 -I :E ::0 -I m Ai 0 C1AAJ¡tI/LiAv dA ~~$ 4./ Z -I :I: - en )- ::0 m > Comments/Instructions: c:\msoffice\wordianldiana\checklist (rev. 11/01/100) ~ ,-., Well History File APPENDIX Information of detailed nature that is not particulariy gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, infonnation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. --------- ~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jan 09 15:17:12 2003 Reel Header Service name.............LISTPE Date.................... .03/01/09 Origin...................STS Reel Name................UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Tape Header Service name............ .LISTPE Date.....................03/01/09 Origin...................STS Tape Name................UNKNOWN Continuation Number..... .01 Previous Tape Name..... ..UNKNOWN Comments.................STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-MW-22027 R.PUDDIPHATT D.FERGUSON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD Writing Library. Writing Library. 5-32A 500292219001 BP Exploration Sperry Sun 09-JAN-03 MWD RUN 4 AK-MW-22027 D.HAWKINS R.BORDIS 32 llN 15E 2549 1084 .00 63.50 35.00 ~. Scientific Technical Services Scientific Technical Services Alaska MWD RUN 5 AK-MW-22027 D.HAWKINS R.BORDIS OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.750 5.500 9657.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. WELL KICKED OFF FROM 5-32 WITH TOP OF WHIPSTOCK SET AT 9653' MD, é1oa.-Oðj / Itf1~ .~ ~ 8601.5' TVD. 4. MWD RUN 1-3 WERE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. 5. MWD DATA WAS DEPTH SHIFTED TO THE SCHLUMBERGER DEPTH CONTROL LOG OF 3/5/2002, PER THE 4/15/2002 E-MAIL FROM D. SCHNORR (BP EXPLORATION). HEADER DATA ONLY RETAIN DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1-3 REPRESENT WELL 5-32A WITH API # 50-029-22190-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12130' MD / 8670' TVD. SROP ~ SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD ~ SMOOTHED GAMMA RAY COMBINED (SCINTILLATION DETECTORS) $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation...... .03/01/09 Maximum Physical Record..65535 File Type................LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 9620.0 9664.0 STOP DEPTH 12097.0 12139.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 9642.0 9664.5 9710.0 972 6.5 9737.5 9760.5 9777.5 9851. 5 9878.5 9912.0 9940.5 9967.0 9979.5 10010.0 10022.5 $ DEPTH # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE # REMARKS: GR 9636.5 9659.0 9704.5 9722.0 9733.5 9755.5 9772.5 9846.0 9873.0 9906.0 9933.0 9961.5 9973.5 10001.5 10013.5 BIT RUN NO 3 4 5 MERGE TOP 9614.5 10130.5 11284.0 MERGE BASE 10130.0 11283.5 12130.0 MERGED MAIN PASS. $ # 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 Name Service Order DEPT ROP MWD GR MWD Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9620 12139 10879.5 5039 9620 12139 ROP MWD FT/H 0.01 218.53 48.9725 4951 9664 12139 GR MWD API 13.16 290.62 56.1325 4955 9620 12097 First Reading For Entire File......... .9620 Last Reading For Entire File....... ....12139 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/09 Maximum Physical Record..65535 File Type........... .... .LO Next File Name......... ..STSLIB.002 Physical EOF File Header Service name............ .STS1IB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/09 Maximum Physical Record. .65535 File Type................LO Previous File Name..... ..STSLIB.OOI Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 3 .5000 START DEPTH 9614.5 9658.5 STOP DEPTH 10088.0 10130.0 # 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: 25-FEB-02 Insite 3.3 Memory 10130.0 9656.0 10130.0 32.0 r---- MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # 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 86.9 TOOL NUMBER 015 4.750 9657.0 Quikdril-N 8.40 55.0 9.6 1300 2.0 .000 .000 .000 .000 Name Service Order DEPT ROP MWD030 GR MWD030 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 ~ .0 112.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9614.5 10130 9872.25 1032 9614.5 10130 ROP MWD030 FT/H 0.08 173.88 30.6299 944 9658.5 10130 GR MWD030 API 13 .16 161. 54 45.9411 948 9614.5 10088 First Reading For Entire File..........9614.5 Last Reading For Entire File...........10130 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/09 Maximum Physical Record..65535 File Type................LO Next File Name.......... .STSLIB.003 r--- Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/09 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 ROP $ 3 /"""""\ header data for each bit run in separate files. 4 .5000 START DEPTH 10088.5 10130.5 STOP DEPTH 11228.0 11283.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # 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 01-MAR-02 Insite 3.3 Memory 11283.0 10130.0 11283.0 86.7 92.1 TOOL NUMBER 015 4.750 9657.0 Quikdril-N 8.40 53.0 9.4 900 15.0 .000 .000 .000 .000 .0 141.7 .0 .0 ~ ~ Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.....................60 .lIN Max frames per record............ .Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 GR MWD040 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10088.5 11283.5 10686 2391 10088.5 11283.5 ROP MWD040 FT/H 0.01 126.26 43.5821 2307 10130.5 11283.5 GR MWD040 API 29.18 141.31 57.4237 2280 10088.5 11228 First Reading For Entire File......... .10088.5 Last Reading For Entire File...........11283.5 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/09 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...... .03/01/09 Maximum Physical Record. .65535 File Type................LO Previous File Name.......STSLIB.003 Conunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 header data for each bit run in separate files. 5 .5000 START DEPTH 11242.0 11284.0 STOP DEPTH 12088.0 12130.0 # 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: 03-MAR-02 Insite 3.3 Memory 12130.0 11283.0 12130.0 89.5 98.8 # ,r--, TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # 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 ~ TOOL NUMBER 191 4.750 9657.0 Quikdril-N 8.40 56.0 9.0 500 .0 .000 .000 .000 .000 .0 138.0 .0 .0 Name Service Order DEPT ROP MWD050 GR MWD050 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11242 12130 11686 1777 11242 12130 ROP MWD050 FT/H 0.02 218.53 66.7114 1693 11284 12130 GR MWD050 API 31.16 290.62 60.9901 1620 11242 12088 First Reading For Entire File...... ....11242 Last Reading For Entire File...........12130 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/09 Maximum Physical Record..65535 File Type.............. ..LO Next File Name...........STSLIB.005 Physical EOF /"""'""'- Tape Trailer Service name. ............LISTPE Date.....................03/01/09 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Reel Trailer Service name.............LISTPE Date.................... .03/01/09 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.... .......UNKNOWN Comments........... ......STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. Writing Library. ,-., Scientific Technical Services Scientific Technical Services