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211-066
7. 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 18-03C Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 211-066 50-029-20776-03-00 11196 Surface Intermediate Liner Liner Liner 8802 2571 7712 6524 223 1981 11160 13-3/8" 9-5/8 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 8801 29 - 2600 28 - 7740 2690 - 9214 9061 - 9284 9215 - 11196 29 - 2600 28 - 7126 2690 - 8513 8372 - 8573 8514 - 8802 None 2670 4760 5410 / 7120 7500 10530 None 5380 6870 7240 / 8160 8430 10160 9635 - 11120 4-1/2" 12.6# 13Cr80 27 - 9069 8777 - 8800 Conductor 80 20" 30 - 110 30 - 110 4-1/2" Baker S3 Packer 9012 8326 Bo York Operations Manager David 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 0028307 27 - 8379 N/A N/A 207 372 18591 10852 407 630 1045 795 786 763 325-347 13b. Pools active after work:Prudhoe Oil No SSSV Installed 9012, 8326 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 12:29 pm, Jul 24, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.07.24 12:18:46 - 08'00' Bo York (1248) JJL 8/12/25 DSR-7/24/25 RBDMS JSB 073125 ACTIVITY DATE SUMMARY 7/1/2025 CTU #1 1.5 CT Job Scope: Drift/Log, ExtAdperf Travel to DS 18, MIRU CTU perform weekly BOP test. LTT failed test on SSV, Had a grease crew to come out and grease and cycle valve. BOP Test is Complete. Drifted MHA with 9/16" Ball to Disconnect Drifted everything else with 1/2" Ball. M/U CTC and BHA with Memory Logging Tool. RIH with Memory log and pump down backside to kill well. ******WRS 7/2/25******** ***Job in progress*** 7/2/2025 CTU #1 1.5 CT Job Scope: Drift/Log, ExtAdperf Cont RIH to Log from 10250'-8900'. flag @ 9900'. POOH while performing well kill, Good no-flow test. LD HES logging tools. good data +2' correction, Approved by OE. Perform kick while tripping drill with all crew involved. Deploy 250' of HES 2" maxforce guns. RIH, correct to top shot at flag and perforate 9950-10070, 10100- 10200'. POOH maintaining hole fill. Good no-flow test at surface. L/D spent guns. Recover 1/2" ball. Load well with 145bbls diesel. RDMO. ***Job Complete*** Daily Report of Well Operations PBU 18-03C 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 thes 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 18-03C Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 211-066 50-029-20776-03-00 341J ADL 0028307 11196 Surface Intermediate Liner Liner Liner 8802 2571 7712 6524 223 1981 11160 13-3/8" 9-5/8 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 8801 29 - 2600 28 - 7740 2690 - 9214 9061 - 9284 9215 - 11196 2470 29 - 2600 28 - 7126 2690 - 8513 8372 - 8573 8514 - 8802 None 2670 4760 5410 / 7120 7500 10530 None 5380 6870 7240 / 8160 8430 10160 9635 - 11120 4-1/2" 12.6# 13Cr80 27 - 90698777 - 8800 Conductor 80 20" 30 - 110 30 - 110 4-1/2" Baker S3 Packer No SSSV Installed 9012, 8326 Date: Bo York Operations Manager Dave Bjork david.bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY 7/1/2025 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 By Grace Christianson at 10:18 am, Jun 09, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.06.06 15:25:07 - 08'00' Bo York (1248) 325-347 A.Dewhurst 20JUN25 DSR-6/18/25JJL 6/9/25 10-404 Perforating gun BHA 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 before breaking containment *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.24 06:05:03 -08'00'06/24/25 RBDMS JSB 062425 ExtAddPerf 18-03C PTD:211-066 Well Name:18-03C API Number:50-029-20776-03 Current Status:Operable - Producer Rig:CTU Estimated Start Date:7/01/25 Estimated Duration:2days Reg.Approval Req’std?10-403 Date Reg. Approval Rec’vd: Regulatory Contact:Carrie Janowski (907) 564-5179 First Call Engineer:David Bjork (907) 564-4672 (907) 440-0331 Current Bottom Hole Pressure:3350 psi @ 8,800’ TVD 7.4 PPGE (offset producer 18-14C BHP) Max. Anticipated Surface Pressure:2470psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:850 psi (Taken on 5/25/25 Min ID:2.31” sliding sleeve in LTP assembly @ 9,193’ MD Max Angle:90 Deg @ 10,011’ MD, 70 Deg at 9,561’ MD Brief Well Summary: 18-03C was completed by Nordic 2 in late 2011 and is a gravity drainage well with open Z1A perfs. Unswept Z1A remains unperforated. The wellbore lies on the periphery of the GCWI area with recent evidence of water influx. We would like to perforate the remaining footage in the heel. Objective:Perforate remaining unswept Z1A interval Procedure: Coiled Tubing 1. MU drift BHA with GR/CCL in 2.25” carrier, drift to 10,250ft. Note: 2.31” ID in LTP assembly at 9,561ft 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 ~190 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 = 144 bbls b. 4-1/2” tubing/liner – 9,193’ X .0152 bpf = 140 bbls c. 3-1/2” liner 9,193 – 9,267’ X .0087bpf=0.64 bbls d. 3-1/4” liner 9,267’ – 9,635(top perf)’ X .0079bpf=2.9 bbls 3. At surface, prepare for deployment of TCP guns. 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. ExtAddPerf 18-03C PTD:211-066 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. e.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” Maxforce guns or similar Perf Interval (tie-in depths) Lengths Total Gun Length Weight of Gun (lbs) Run #1 9,950’ - 10,070’ 30’ blank 10,100’ - 10,200’ 9,950’ – 10,200’250’~1,400 lbs (5.6 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: x Wellbore Schematic x Proposed Schematic x Tie-In Log, x BOPE Schematic x Standing Orders x Equipment Layout x Sundry Change Form ExtAddPerf 18-03C PTD:211-066 Current Wellbore Schematic ExtAddPerf 18-03C PTD:211-066 Proposed Wellbore Schematic 9,950’ - 10,070’ 10,100’- 10,200’ New Perforations ExtAddPerf 18-03C PTD:211-066 Tie-in Log ExtAddPerf 18-03C PTD:211-066 BOP Schematic ExtAddPerf 18-03C PTD:211-066 ExtAddPerf 18-03C PTD:211-066 ExtAddPerf 18-03C PTD:211-066 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 HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date David Douglas Hilcorp North Slope Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 02/23/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL (23-FEB-2022) Folder Contents: Log Print Files, Reports and Digital Data Files: Well API #PTD #Log Company Log Date Log Type Notes: PBU L-207 50029237020000 221081 HALLIBURTON 1/12/2022 PPROF INCLUDES ANALYSIS PBU 04-51 50029235970000 218018 BAKER 11//24/2021 RPM INCLUDES ANALYSIS PBU 09-38 50029219190000 189021 BAKER 12/1/2021 RPM INCLUDES ANALYSIS PBU 09-39 50029221330000 191012 BAKER 12/6/2021 RPM INCLUDES ANALYSIS PBU 18-02C 50029207620300 213009 BAKER 11/25/2021 RPM INCLUDES ANALYSIS PBU 18-03C 50029207760300 211066 BAKER 11/26/2021 RPM INCLUDES ANALYSIS PBU 18-05A 50029215830100 202219 BAKER 12/8/2021 RPM INCLUDES ANALYSIS PBU Z-32C 50029219240300 213127 BAKER 12/10/2021 RPM INCLUDES ANALYSIS Please include current contact information if different from above. 211-066 T36372 PBU 18-03C 50029207760300 211066 BAKER 11/26/2021 RPM INCLUDES ANALYSIS Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.02.25 08:36:20 -09'00' Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. QI L - 01010 Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RES AN: OVERSIZED: NOTES: Color Items: ❑ s: Grayscale Items: MLogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: ` Maria Date: 7/15'//9. /s/ I Project Proofing BY: Maria Date: 7/'f5/f4.if. /s/ filif Scanning Preparation I x 30 = 3C, + at+ =TOTAL PAGES v T- BY: Date: 77/51/1/. (Count does not include cover sheet) 41:* /s/ Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover eet) Page Count Matches Number in Scanning Pre aration: YES NO BY: 4190 Date: 1115- gi- /s/ IV Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES C) TOTAL PAGES: Digital version Y appended b : Meredith Michal Date: /s/ P Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o v a a) 0 o Fs + m OS o c a o Q rn0 °,(�r m 2 m o LL 1 t _ m y > J O. J a m a m X co c 0 N. 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L .J W J J J J W W .J LU O 1 I O M 4 co O • z N N U5 i O .il N O z a Q I J U O i Z rn i Cl) (13 ci) a aZ '5. z a o U 1W�// o li J a W w > U m o 8 CD 0 Z C. z 0 Q m N 0 H .J a • = m T E C • m 1 G g 0 LL 1 O i; O ti E ✓ r. 0 1 J U ij 'CC M O I .- — r ~ O 2 N •:C • CO CO m 0 x O co a Q m a .� a 'CC o Z d Z 1// 3 0 • , co Z I o O co co a m o 2 ami N Oj a� Z c•' H 0 Q , a0 d cc co cs. . t .2 m— p o ai y N > 0 a 0 a '' Cl)o c o I E E 00. 2 a s U <rx 1 0 : U STATE OF ALASKA P • Al_ _KA OIL AND GAS CONSERVATION COMM -_iON APR 2 6 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well LI Plug Perforations U Perforate U Other LI AC)GCC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.ShutdownD Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc ❑ Exploratory ❑ Development 211-066-0 P 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20776-03-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028307 PBU 18-03C 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 11196 feet Plugs measured None feet true vertical 8802.32 feet Junk measured None feet Effective Depth measured 11160 feet ' Packer measured See Attachment feet true vertical 8801.13 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 2571 13-3/8"72#L-80 29-2600 29-2599.92 4930 2670 Intermediate None None None None None None Production 7712 9-5/8"47#L-80 28-7740 28-7126.18 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10200-11120 feet True Vertical depth 8783.73-8799.91 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 27-9069 27-8379.31 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): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 374 2226 8 0 347 Subsequent to operation: 1616 5847 17 0 617 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑✓ Service❑ Stratigraphic ❑ Daily Report of Well Operations x 16.Well Status after work: Oil 0 Gas U WDSPI11 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays .BP.com Printed Name Nita Summerhays , Title Petrotechnical Data Technician �, Signatu� z ��,//:4 .4r,-,,,,,„,_- Phone 564-4035 Date 4/25/2013 • vir ,w. f77-.2--/#4 RBDMS APR 26 201 R, I 13 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028307 ," 1rx ., �,, !!! 1°1 .' , `` ***WELL SHUT IN ON ARRIVAL*** (profile mod) RAN 20' X 3.70" KB PACKER DRIFT -TAG LTP @ 9166' SLM *"*CONTINUED ON 3/30/13 3/29/2013 WSR*** ***CONTINUED FROM 3/29/13 WSR*** (profile mod) PULLED 4-1/2" LTP FROM DEPLOYMENT SLEEVE @ 9166' SLM (Missing one upper element from pkr) RIH W/ 3.50" BRUSH, 2.625" 3-PRONG GRAB to 9249' SLM (Recovered 80% of lost element). RIH W/2.50" S.BAILER TO DEVIATION AT 9580' SLM (Recover remainder of element, 1/4" cup scale). RAN 3.75" LIB- SAT DOWN AT © 9111' SLM - INCONCLUSIVE IMPRESSION RAN 3.77" CENT, 3.50" LIB TO 9111' SLM, TAP PAST, TAG DEP SLV AT 9195' SLM (Pic of sleeve). RAN 20' X 3.70" KB PACKER DRIFT TO 9195' SLM - NO ISSUE ***CONTINUED ON 3/30/2013 3/31/13 WSR*** ***CONTINUEISFROM 3/30/13 WSR*** (profile mod) SET BAKER LINER TOP PACKER (OAL = 25.94', max OD = 3.70") IN DEP SLV @ 9215' MD PULLED 2 7/8" PORTED SLEEVE FROM INSIDE LINER TOP PKR © 9177' SLM DRIFTED W/2.20" CENTRALIZER THROUGH LTP AND TO DEVIATION © 9585' SLM RAN PDS 24 ARM CALIPER FROM DEVIATION TO SURFACE (Difficult to tell if lower seals are deep enough) RIH W/2-7/8" B SHIFTING TOOL AND CLOSED 2-7/8" BAKER CMD SLIDING SLEEVE @ 9173' SLM CURRENTLY PERFORMING DRAWDOWN TEST TO TEST UPPER/LOWER 3/31/2013 ELEMENTS ***CONTINUED ON 4/1/13 WSR*** ***CONTINUED FROM 3/31/13 WSR*** (profile mod) FINISH DRAWDOWN TEST AND LTP APPEARS TO BE HOLDING. LOAD TBG & SHIFT SLIDING SLEEVE OPEN W/2-7/8" B SHIFTING TOOL © 9182' SLM. SET 2-7/8" X LOCK W/ORIFICE SLEEVE (two .188" 4/1/2013 ports) @ 9176' SLM. ***WELL TURNED OVER TO DSO*** T/I/0=1480/1260/380 Temp+SI Assist S-line ( Pre RWO) Pumped 50 bbls of 100*crude down TBG S-line on well on dep. Wing shut swab shut ssv open master open casing valves open to gauges Final 4/1/2013 Whp's=1412/1280/380 FLUIDS PUMPED BBLS 3 DIESEL 50 OIL 53 TOTAL as O Q,0OOM OOOO p ti N N- V �t'A' O O O CD (0 0 0 0 y O) CO M I- M M N- CO CSD O O CO V CO r r LO NT 0) CO N CO N N- T- CO CO M N- O) M - C7 N CO CO N CO 0) 0) - h- O N C) CO CO CO CO CO N CO O CO Nr O) CO CO O CO M CO N N N CT) LO LO (NI CO CO CO CO 072lloom O O O O) oom V OCO N N N CO Cn C) a) O) r-- C.) �V LO CO O O) CO — CO O Co CA N CV M COON N r- N N N C 0 N a) 0) 0) a) C Q O 09 0 0 0 p 0 C2 Nrp JaoaoaococO = C�o -J _J JJ •' # CO N CSO N • N CV • �CU NOOCOCO � _ N M M N O 4 Z a+ N N C COO L N � M N- t••••• O J Co CN N Cr) Z O O es) Lu 0 � UC� tsaCLCCcQQOLLZ ✓ Zwwwww0wm O ZZZZZ O J J J J J a_ Ci) f- Packers and SSV's Attachment ADL0028307 SW Name Type MD TVD Depscription 18-03C PACKER 9012 8281.4 4-1/2" Baker S-3 Perm Packer 18-03C PACKER 9061 8327.21 5" Baker ZXP Top Packer 18-03C PACKER 9187 8444.04 4-1/2" KB Packer 11-2h= /8"McEVOY WB-L}EAD= McEVOY 1 8-O 3 C CHROME **E NOTES: WELL ANGLE>70'@ 9561' " B- ACTUATOR= AXSON; ORIG.KB.B..B 46' ORIG.BF.BEV KOP= 2700', Max Angie= 30'@ 10011'; Datum MD= 11196'4 I O ' 2182 3.812;1 Datum TVD= 8758'SS; ` 20"CONDUCTOR,91.5#, - 110' 2690' H 9-5/8"X 7"LNR 11 ACK,13=7.50" H-40,D=19.124" 2697' �9-5/8"X 7"BKR LTP w/LNR HGR,D 6.270" J '' OAS LIFT MANDRE L3 13-3/8"CSG,72#,L-80 BTC,ID=12.347" I 2600' = ST MD ND DEV TYPE VLV LATCH FORT DATE TOP OF 7"SCAB LNR --{ 2690' /i 3 3289 3279 17 KBG-2 DOME BK 16 11/16/11 i' 2 5794 5483 32 KBG-2 SO BK 20 11/16/11 Minimum ID = 2.37" a@ 9187' t 1 7538 6952 31 KBG-2 DMY BK 0 06/22/03 4-1/2" BKR KB LINER TOP PACKER '• ►" 7585' -19-5/8"X 7"BKR H LTP,ID=6.188" 7"LNR,26#,L-80 BTC-M,.0383 bpf,ID=6.276" --{- 7584' • 7590' -{9-5/8"X 7"BKR HMC LNR HGR,D=6.184" 9-5/8"CSG,47#,L-80 BTC-M,D=8.681" -1 7740' 9-5/8"MLLOUT WINDOW (18-03A)7740'-7790' >c 4-1/2"TBG,12.6#,13CR-80 VAM ACE, H I 8981' I I 8991' -14-1/2"HES X NP,13=3.813" .0152 bpf,ID=3.958" C9012' -17"X 4-1/2"BKR S-3 PKR,D=3.875" ' I 9036' -14-1/2"HES X NP,D=3.813" 1 I ' 9056' -14-1/2"FES XN NP,PALLED TO 3.80"(6/26/11) 9061' -7"X 5"BKR ZXP LTP, 4-112"LNR 12.6#,L-80,.0152 bpf,D=3.958" 9068' II K.,,,, ,, w/11.35"TEET3ACK,D=4.39" 9069' --14-1/2"V11LEG,13=3.958" 9080' -17"X 5"BKR FLEX-LOCK LNR HSR,D=4.39" T LNR,29#,L-80 NSCC,.0372 bpf,D=6.184" --i -9214 — 9090' -15"X 4-1/2"XO,ID=3.98" 3-1/2"LNR 9.20#,L-80 STL, .0087 bpf,D=2.972" -I 9267' =' '=' 7"MLLOUT WINDOW (18-03B)9214'-9226' 4 1/2"WHPSTOCK(06/24/11) -� 9281' 9187' H4-112-KB LNR TOP PKR,ID=2.37'(06/15/12) 4-1/2"LW, 12.6#,L-80 BT-M -1 -9284 9215' -13.70"BTT DEPLOY SLV,13=3.00" .0152 bpf,13=3-958" 9267' -{3-1/2"X 3-1/4"XO,D=2.786" 3-1/4"LNR 6.6#,L-80 TCiI .0079 bpf,ID=2.80" -I 9705' 4-1/2"MLLOUT WIDOW (18-03C)9284'-9293.' PERFORATION SUMMARY REF LOG:SLM MCNL ON 11/03/11 ANGLE AT TOP FERE 90°@ 10200' Note:Refer to Roduction DB for historical pert data 9705' -{3-t/4'X 2-7/8"XO,D=2.377' SIZE SPF INTERVAL Opn/Sgz DATE I 2" 6 10200- 11120 0 11/04/11 11160' -1 FBTD 2-7/8'LNR,6.4#,L-80 STL, .0058 bpf,ID=2.441 - 11196• •�4 61 DATE REV BY COMMENTS TDATE REV BY COMMENTS PRUDHOE BAY UNIT 08/16/82 PKR 176 ORIGINAL COMPLETION 7 12/08/11 AK/PJC FINAL DRLG CORRECTIONS WELL: 18-03C 02/12/95 _N2ES_ SIDETRACK(18.03A) 06/18/12 JCM/PJC C/O LTP(06/15/12) PERMIT No:"1110660 06125/03 N2ES SIDETRACK(18-03B) API No: 50-029-20776-03 11/06/11 NORDIC 2 CTD SIDETRACK(18-03C) SEC 24,T11N, R14E, 1184'SNL 8 161'WEL 11/15/11 PJC DRLG DRAFT CORRECTIONS - 11/25/11 JLJ/JMD GLV C/O(11/16/11) BP Exploration(Alaska) • RECEIVED STATE OF ALASKA AL,.—,(A OIL AND GAS CONSERVATION COMMISSION AUG 2 3 2012 REPORT OF SUNDRY WELL OPERATEOak N$Oil & Gas Cons. Commission 1.Operations Abandon H Repair Well H Plug Perforations U Perforate Li Oltf3eno age Performed: Alter Casing ❑ Pull Tubing❑ 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 ❑✓ Exploratory ❑ - 211-066-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20776-03-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028307 PBU 18-03C 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRODHOE OIL 11.Present Well Condition Summary: Total Depth measured 11196 feet Plugs measured None feet true vertical 880P.32 feet Junk measured None feet Effective Depth measured 11160 feet Packer measured See Attachment feet true vertical 8801.13 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 2571 13-3/8"72#L-80 29-2600 29-2599.92 4930 2670 Intermediate None None None None None None Production 7712 9-5/8"47#L-80 28-7740 28-7126.18 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10200-11120 feet True Vertical depth 8739.08-8755.26 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 27-9069 27-8379.31 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): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 666 37775 31 0 1134 Subsequent to operation: 255 449 56 0 30 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Q ` Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil,. Q Gas ❑ WDSPL U GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Prepared by Garry Catron 564-4424 Printed Name Ma Summe ays TitlE petrotechnical Data Technician I Sin- . -'/A/' ,f.,_ Phone 564-4035 Date 8/23/2012 _. j r � SMS AUG 2 4 1011\ O R G1 N Lc-;- 6 Form 10-404 ' : G 4 .) R I G A\1 V Lk 1 i'' brfiit nginal Only v VVV A L �� Daily Report of Well Operations ADL0028307 T/I/O= 0/0/0 Conduct PJSM. Verified barriers. Rig up lubricator and test to 300 psi low and 3500 10/29/2011 psi high. Pulled 5" FMC ISA BPV @ 152"w/3-5'& 1-3' ext. RKB=28.40 +2.50' Nordic 2 T/I/O = 0/0/0 Conduct PJSM.Verify Barriers. Rig up lubricator and test to 300 psi low and 3500 psi 11/6/2011 high. Set 5"FMC ISA BPV @ 125"w/3-5' & 1-18"ext. RKB=25.84' + 1.30' Nordic 2 RDMO r/I/O= 0/200/0 Conduct PJSM. Verify barriers. Rig up lubricator and pull 5"FMC ISA BPV @ 104" w/ 1-2' ext. Set 5" FMC ISA TTP. Pressure test tree against TTP to 300 psi low and 5000 psi high. (passed) Pull 5" FMC ISA TTP. Lubricator was tested to 300 psi low and 3500 psi high each time it was rigged up. Tree cap was test to 500 psi after reinstallation.All tree studs torqued on day shift to 11/10/2011 API specificatiions. see log for details. ***job complete"** ***WELL S/I ON ARRIVAL***(post ctd) SET 4 1/2"X-CATCHER SUB IN X-NIPPLE @ 8,996' SLM PULLED 1"BK-DGLV'S FROM STA#2 @ 5,792' SLM (5,794' MD) &STA#3 @ 3,280' SLM (3,289' MD) 11/15/2011 *"""JOB STILL IN PROGRESS, WSR CONTINUED ON 11/16/2011**** *""WSR CONTINUED-FROM 11/15/2011*** (post ctd) SET BK-LGLV'S AT ST#3 (3,289' MD)& BK-OGLV AT ST#2 (5,794' MD). PULLED EMPTY 4 1/2"X CATCHER SUB FROM 8,996' SLM. 11/16/2011 ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** ASRC Test Unit#1. Spot unit, Rig up.***Job in Progress*** 11/17/2011 Inlet 18-03, Outlet 18-02 ASRC Test Unit#1. Pop well w/PBGL. SI PBGL to allow natural flow.***Job in Progress*** 11/18/2011 Inlet 18-03, Outlet 18-02 ASRC Test Unit#1. Rates dropped, Open PBGL back up, Test Well, 1139 STBOPD, 12 BWPD, 0.58%W/C, 0.841 MMSCFD Formation Gas, 3.5 MMscfd PBGL. Rig down ***Job in Progress*** 11/19/2011 Inlet 18-03, Outlet 18-02 11/19/2011 Freeze Protect (CTD) Standby for Well tester's to RDMO. ***WSR Continued on 11-20-11*** 11/20/2011 ASRC Test Unit#1. RDMO.***Job completed*** ***WSR Continued from 11/19/11*** T/I/O=SSV/400/330 Freeze ro ect F lowline (CTD) Pumped 5 bbls meth spear followed by 51 bbls crude down flowline. DSO closed IGV. Pressured up Flowline to 1500 psi with 3 bbls meth. SV, WV, SSV=C. MV=O. IA, OA=OTG. 11/20/2011 FWHP's=SSV400/330. T/I/O = 1870/1240/1090. Temp= Hot. WHPs (Eval Post POP). IAP increased 840 psi, OAP increased 760 psi since 11/20/11. 11/25/2011 SV= C. WV, SSV, MV= 0. IA, OA= OTG. 12:43. T/I/01890/1240/570. Temp= Hot. WHPs (Post OPs bleed). OAP increased 30 psi overnight. 11/28/2011 SV= C. WV, SSV, MV= 0. IA, OA=OTG. 08:55. ASRC Test Unit#2. 18-03 12hr Well Test. **Continued from WSR 1/16/12**On weather standby 1/17/2012 Phase 2. **Job in progress continued on WSR 1/18/12. ASRC Test Unit#2. 18-03 12hr well test. **continued from 1/17/12""Weather standby phase 2. 1/18/2012 Back on location SB for equip to continued RU. **Job in progress continued on WSR 1/19/12. ASRC Test Unit#2. 18-03 12hr Well Test. **Continued from WSR 1/18/12** Inlet well 18-03, Outlet 1/19/2012 well 18-02. Continued Rig Up. **Job in progress continued on WSR 1/20/12** ASRC Test Unit#2. 18-03 12hr well test. **Continued from WSR 1/19/12** Rig up complete. Pressure test complete. POP well to ASRC test separator. **Job in progress continued to WSR 1/20/2012 1/21/12 ASRC Test Unit#2. 18-03 12hr well test. **Continued from WSR 1/20/12** Working open IL Ck. IL well 18-03 OL well 18-02. Started 7hr Test at 11:00 and ended test at 18:00. 448 bfpd,-3.34%WC, 38.89 mmscf/d, 898 psi ftp.Well SI at 20:10. Start RD. **Job in progress continued on WSR 1/21/2012 1/22/12** T/I/0=2400/142010 Freeze Protect tbg post well test with 3 bbls neat methanol, 38 bbls crude. Tag well, IA/OA OTG, SSV, wing &swab closed. Notify operator, ASRC Testers on well upon 1/22/2012 departure. Final WHP's=2300/1420/0 1/29/2012 ASRC Test Unit#2 18-03. Cont. STBY Equipment. Move Unit. **Job Completed** ""'WELL FLOWING ON ARRIVAL(ELINE LDL)*** INITIAL T/I/O= 950/1300/100 PSI INITIAL VALVE POSITIONS: MASTER/WING/SSVNALVES TO CASING=OPEN, SWAB= CLOSED UNABLE TO RIH TO LOG LDL DUE TO SLIC CABLE NOT MOVING THROUGH DUAL PACK OFF ASSEMBLY SMOOTHLY. RIG DOWN FOR THE NIGHT TO TROUBLESHOOT. FINAL T/I/O=2500/1300/100 PSI FINAL VALVE POSITIONS: MASTER/VALVES TO CASING= OPEN, SWAB/WING/SSV= CLOSED 5/13/2012 ""JOB IN PROGRESS AND CONTINUED ON 14-MAY-2012*** ***WELL FLOWING ON ARRIVAL(ELINE LDL)*** INITIAL T/I/O=2400/1300/100 PSI INITIAL VALVE POSITIONS: MASTER/WING/SSVNALVES TO CASING= OPEN, SWAB= CLOSED WELL FLOWING AND PLACED IN TEST SEPARATOR FOR LOGGING. CHOKE=47 DEG, GAS= 9 MMSCFPD, FLUID= 0 BPD, FTT= 70 DEGF, FTP=2450 PSI RECORDED FLOWING STATION LOG AT 9151' LOGGED FLOWING DOWN PASS AT 60 FPM FROM 8900'-9243'. STOPPED DOWN LOG AND IMMEDIATLY PULLED UP TO 9150' DUE TO ANOMALY SEEN AT 9199' (BOTTOM OF PACKER). ESTIMATE FROM TUBING AND LINE ID AND PILS SPINNER IS THAT 13% OF THE TOTAL GAS IS COMING FROM BELOW THE ANOMALY AND 87% IS COMING FROM THE ANOMALY. LOGGED UP PASS FROM 9150'-8900', CORRELATED TO 4.5"TUBING PER APE. FINAL T/I/O=2400/1300/100 PSI FINAL VALVE POSITIONS: MASTERNALVES TO CASING= OPEN, SWAB/WING/SSV/= CLOSED 5/14/2012 ***JOB COMPLETE*** ***WELL SHUT IN PRIOR TO ARRIVAL***(post ctd) DRIFTED W/2.25"CENTRALIZER&SAMPLE BAILER TO DEVIATION @ 9548' SLM, BAILER EMPTY (had small amount of parrafin in bailer btm) CURRENTLY LOGGING W/PDS 24 ARM CALIPER FROM DEVIATION @ 9548' SLM TO 8800' SLM 5/25/2012 ***CONT ON 5-26-12*** *** CONT FROM 5-25-12 WSR*** (post-ctd) POOH,AFTER LOGGING W/24 ARM CALIPER FROM 9550'SLM TO 8800'SLM - NO DATA RE-RUN CALIPER, LOG FROM 9552'SLM TO 8800'SLM -GOOD DATA 5/26/2012 ***TURN WELL OVER TO DSO- LEFT WELL SHUT IN *** ***WELL SHU FIN ON ARRIVAL*** DRIFTED TUBING WITH 3.8" CENT AND SAMPLE BAILER. SD ON KB PAKER @ 9173' SLM/ 9204 ELMD. BAILER RETURNED EMPTY. PULLED KB LINER TOP PACKER FROM 9173' SLM/9204 ELMD. PACKER MISSING ONE FULL TOP ELEMENT AND 1/2 ELEMENT FROM LOWER SEAL ASSEMBLY. ATTEMPTED TO FISH ELEMENT WITH 4.5" BRUSH AND 3.5"WIRE GRAB. RECOVERED 1"x1.5"x .75" PIECE OF TOP ELEMENT. 6/13/2012 ***CONTINUED ON 6-14-12 WSR*** ""CONTINUED I-ROM 6-13-12 WSR"" RAN 3 1/2"PUMP BAILER TO LINER TOP @ 9186' SLM/9204' MD. BAILER RETURNED EMPTY. RAN 3.75" LIB TO LINER TOP. LIB SHOWED PARTIAL IMPRESSIONS OF LINER TOP& RUBBER ELEMENT. RAN A 3.5"CENT 4 1/2"BRUSH, 3 1/2" BRUSH &2.62"WIRE GRAB TO LINER TOP WITH NO RECOVERY. DRIFTED TUBING AND LINER W/2.67"CENTRALIZER. SET DOWN @ 9521' SLM. APPEAR TO HAVE PUSHED ELEMENT TO 9534' SLM. UNABLE TO WORK ANY DEEPER. RAN 3.75" LIB TO LINER TOP. LIB SHOWED G-SERIES FISH NECK WITH POSSIBLE ELEMENT. 6/14/2012 **CONTINUED ON 6-15-12 WSR""` ***CON I INUED FROM 6-14-12 WSR*** SET LINER TOP PACKER IN LINER TOP @ 9215' MD. TOP OF LINER TOP PACKER @ 9193' MD. CALIPER FROM 9300' SLM TO 8900' SLM W/PDS 24 ARM CALIPER. GOOD DATA. 6/15/2012 ***CONTINUED ON 6-16-12 WSR*** 171/0 = SSV/1000/30. Temp=Sl. Get Fluid Sample In Flutes, Call for Vac Truck(Eval Fluid In Flutes). No AL. Conductor is 20"dia. Fluid in conductor is 9"deep to RG-2401. Conductor is 9 1/2"from top of conductor to top of RG-2401. Fluid is clear w/a film of Hydro-Carbons on top. Sample taken and Vac truck called. 6/15/2012 SV/WV/SSV=Closed. MV=Open. IA,OA=OTG. NOVP. (0230 hrs) 6/16/2012 Assist Slickline RD to get procedure andt location drop oily waste off job postponed T/I/O=SSV/1000/40. Temp=Sl. Install spill containment& Increase OAP to 500 psi (Eval fluid in conductor). No AL. OA FL=near surface. Conductor has-5"of standing dark fluid on top of RG- 2401, fluid is level with top of flutes 2.5" below top of conductor. Cellar has-5"of clear standing fluid. Increased OAP from 40 psi to 500 psi in increments with IA gas. Observed no signs of leaks in conductor. Monitored for 30 minutes. During monitor OAP decreased 10 psi. Job complete. FWHPs=SSV/1000/490. 6/20/2012 SV, WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 22:10. 171/0= 370/960/480. Temp=Sl. WHP's. (Eval fluid in conductor) No AL. IAP decreased 40 psi& OAP decreased 10 psi in 3 days. Conductor has-3.5"of standing dark fluid on top of RG-2401, fluid is level with top of flutes 4" below top of conductor. Cellar has-5"of clear standing fluid. Observed no signs of leaks in conductor 6/23/2012 SV= C. MV, WV&SSV= O. IA&OA= OTG. NOVP. 13:43 T/I/O = 370/960/480. Temp = SI. WHPs TBG FL (Eval fluid in conductor) No AL. TBG FL @ -700' (11 bbls). WHPs unchanged since 6/23/12. Conductor has-3.5"of standing dark fluid on top of RG-2401, fluid is level with top of flutes 4" below top of conductor. Cellar has-5"of clear standing fluid. Observed no new fluid. 6/25/2012 SV, WV, SSV= C. MV= 0. IA, OA= OTG. NOVP. 1715 FLUIDS PUMPED BBLS 4 DIESEL 11 METH 89 CRUDE 104 TOTAL FLUIDS PUMPED TOTES I DIESEL 1 TOTAL Perforation Attachment ADL0028307 Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth ND Depth Name Date Code Top Base Top Base 18-03C 11/4/11 PER 10200 11120. 8783.73 8799.91 0 0 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028307 SW Name Type _ MD _ TVD Depscription 18-03C PACKER 9012 8281.4 4-1/2" Baker S-3 Perm Packer 18-03C PACKER 9061 8327.21 _5" Baker ZXP Top Packer 18-03C PACKER 9187 8444.04 4-1/2" KB Packer a) O Lo mo• a — mph- 0 L0 o '- aaa N- N U . 00) (o ( u3R1-- ) CC) Ni- p)• r co 0c0 O O Co .- CO r r LC) 'crONCON � c- Co CO C r- O) CO) CON00N (00) 0) v t` O O N O r-- Lo In 00 1.0 c) CO CO CO CO N- N CO m0000 ocri 4NNNN .1a Mints- WWW C O 42) A- W to O 0 O) r 00 0(o O (o � NNN � t` (oo = O) O) O) V M 00 orn (Cov— o000) r- ON C) NO0CNNNN CO 7 Q Q 00 0 0 0 c2 ao U C cD _JoaJocoo J '- N v. d J 0 *k *k rN •y N # N r` (o C N r• O) r O) co _ (V V � N " w000 '' A NOM a- t _ _ a+ CIO N M N O) - N Nt a) 00 (0N '- N- to N OO) z O PW H >> U C) (00CLCereCL0LLLZ vzwwwwowm Ozzzzc » UJJJJa mi- TREE= /8"McEVOY WELLFEAD= McEVOY 1 8-03 C SAFETY TBG : WELL ANGLE>70°@ 9561' •' ACTUATOR= AXELSON ORIG.KB.aa 46' ORIG.BF.ELD KOP= 2700' Max Angle= )0°@ 10011' Datum MD= 11196' 0 2182' –14-1/2"CAMCO BAL-O SV LN,D=3.812" Datum TVD= 8758'SS 20"CONDUCTOR,91.5#, 110' 2690' –19-518"X 7"LNR TIEBACK,ID=7.50" I-1-40,D=19.124" 2697' --19-5/8"X 7'BKR LTP w/LNR I-GR D 6.270" 13-3/8'CSG,72#,L-80 BTC,D=12.347' –{ 2600' OAS LFT MANOftF33 ST MD ND DEV TY FE VLV LATCH PORT DATE TOP OF 7"SCAB LNR –I 2690' 3 3289 3279 17 KBG-2 DOME BK 16 11/16/11 2 5794 5483 32 KBG-2 SO BK 20 11/16/11 Minimum ID = 2.37" @ 9187' I ,, 11 7538 6952 31 KBG-2 DMY BK 0 06/22ro3 4-1/2" BKR KB LINER TOP PACKER Iu11 T LNC 26#,L-80 BTC-M,.0383 bpf,ID=6.276" –{ 7584' 7585' 9-5/8"X 7"BKR H LW,ID=6.188" 7590' H 9-5/8"X 7"BKR HNC LNR HGF,D=6.184" 9-5/8"CSG,47#,L-80 BTC-M 13=8.681" – 7740' 9-5/8"MLLOUT WrDOW (18-03A)7740'-7790' 7C 4-1/2"TBG,12.6#,13CR-80 VAMACE, –I 8981' N ' 8991' –14-1/2"I-ES X NP,D=3.813" .0152 bpf,D=3.958' 9012' –7"X 4-1/2"BKR S-3 PKR,D=3.875" ' ' 9036' - 41/2"Its X NP,D=3.813" I I 9056' –14-1/2"FES XN NP,MLLED TO 3.80"(6/26/11) 9061' –17"X 5'BKR ZXP LTP, 4-1/2"LNR, 12.6#,L-80,.0152 bpf,D=3.958' 9068' w/11.35"TESACK,D=4.39' 9069' H4-1/2"WLEG,D=3.958' 9080' –,7"X 5"BKR FLEX-LOCK LNR HGR 13=4.39' 7'LIP,29#,L-80 MCC,.0372 bpf,D=6.184" –� –9214 — 9090' –15"X 41/2"XO,ID=3.98" 3-1/2"LNFZ 9.20#,L-80 STL,.0087 bpf,D=2.972" –1 9267' 7"MLLOUT WFNDOW (18-03B)9214'-9226' 4-1/2"WHPSTOCK(06/24/11) –1 9281' 9187' –4-1/2"KB LNR TOP PKR,ID=2.37'(06/15/12) 41/2"LNR,12.6#,L-80 BT-M, –1 –9284 9215' –3.70"BTT DEPLOY SLV,D=3.00" .0152 bpf,D=3.958" 9267' H3-12"X 3-1/4"XO,D=2.786" 3-1/4"LNR 6.6#,L-80 TCN .0079 bpf,D=2.80" 9705' 4-1/2"MLLOUT WINDOW (18-03C)9284'-9293.' PERFORATION SUMMARY FIEF LOG:SLM MCN_ON 11/03/11 ANGLE AT TOP F$2F: 90°@ 10200' Note:Refer to R-oduction DB for historical pert data r 9705' –13-1/4'X 2-7/8'XO,D=2.377' SIZE SPF NTERVAL Opn/Sqz DATE I 2' 6 10200-11120 0 11/04/11 111 11160' –I PBTD 2-7/8'LNR,6.4#,L-80 STL,.0058 bpf,ID=2.441 – 11196' '4 4,1 DATE REV BY COMMENTS _ DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/16/82 PKR 176 ORIGINAL COMPLETION 12/08/11 • AK/PJC FINAL DRLG CORRECTIONS WELL: 18-03C 02/12/95 N2ES SIDETRACK(18-03A) 06/18/12 JCM/PJC C/O LIP(06/15/12) PERMIT No:t110660 06/25/03 N2ES SIDETRACK(18-038) API No: 50-029-20776-03 11/06/11 NORDIC 2 CTD SIDETRACK(18-03C) SEC 24,T11N,R14E, 1184'SNL&161'WEL 11/15/11 PJC DRLG DRAFT CORRECTIONS 11/25/11 JLJ/JMD GLV C/O(11/16/11) BP Exploration(Alaska) 211-066 2105/ BAKER HUGHES PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION (ALASKA), INC COUNTY NORTH SLOPE BOROUGH WELL NAME 18-03C STATE ALASKA 1-ILLU PRUDHOE BAY UNIT DAIS 6/25/2012 THIS DISTRIBUTION LIST AUTHORIZED BY: Alfredo Martinez SO#4192391 Log CD Log CD Copies Copies Client/ Partners Copies Copies Client/ Partners 2 1 Company BP EXPLORATION (ALASKA),INC Company Person PETROTECHNICAL DATA CENTER Person Address LR2-1 Address 900 E BENSON BLVD ANCHORAGE,AK 99508 1 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082 A HOUSTON,TX 77002 1 1 Company STATE OF ALASKA-AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W.7TH AVE. Address SUITE 100 ANCHORAGE,AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Company Company Person Person Address Address Page 1 of 1 2--(l-nG 2lc, oI 0 0 0 0 0 0 0 - 0 0 0 0 U O O r r r r r r r N i.Z r r r O 0 O CL N Y 1. '., Y:.1— c N O al cn ',Z r r r r to — l!1 )a .o Ol f6 E x L Q N N N N N N N a0 CD C1 V.• to u� u 0 Z 0 0 0 2 2 Q vNi c -' ; ,w- N N �X a 0 Q 00 J H W _, F- W Le te' ' W r=_ J CD H Y '. , 0 W0 U. "'' O Y -I J H < _. V W J Q ,t5:,'; W J F F- J 0 W � Omace o0oc� 2u. 0 -I a2Wi- 1- Om2 W W J 2 J > > a 2 > 0 N N rl 0 2 o er N N ail Z X X X X X X XO G 0 OM • in N c ' ' p CC) M i- 0 a0 '� YJ a - N O 0 0 N • O. O.u 4 if"..-; 0 0 0 0 O Q O O ' QQ a, VOO 5a ,n O , � coC1r CO zneomaCO -0 N. H > ov `-+ !o) Q 0 3- O N 0 a) O co T) aJ Ji mo^� V m m m m U m do -a ul !3 •? 'TBqo N G1 N CO m Ol v�1 1 N O -P. . ` •--1 c Y F v < , W O < < O O 4 9 3 CV C CJ V u c v v J N IfT G? J GV. Q m _ i cc c foo L N O O H 0 W L "`?. m to in c0 a C v 0 ".`r Q N < _ X d m 01 2.11- 9c.- bp Date 01-27-2012 �12b Z Transmittal Number:93232 RECEIVED BPXA WELL DATA TRANSMITTAL IAN 2 7 Enclosed are the materials listed below. Alaska Oil& Gas Cons. Commission (BPXA FIELD LOG DATA) Anchorr If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 18-03C RE JAk rkklitOLI) )2-:). 0,c Please Sign and/Return one copy of this transmittal. Thank You, Doug Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Shartzer 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage,AK 99519-6612 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ® Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended lb. Well Class: 20AAC 25.105 20AAC 25.110 ® Development 0 Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions One 0 Service 0 Stratigraphic 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 11/6/2011 211-066 3. Address: 6.Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 10/30/2011 50-029-20776-03-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 11/1/2011 PBU 18-03C 1184' FNL, 161'FEL, SEC. 24,T11 N, R14E, UM 8. KB(ft above MSL): 44.65' 15.Field/Pool(s): Top of Productive Horizon: 4011' FNL, 826'FEL, SEC.24,T11 N, R14E, UM GL(ft above MSL): 16.15' Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD): Oil Pool 3882' FNL,2450'FEL,SEC. 24,T11 N, R14E, UM 11160' 8801' 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 691605 y- 5960680 Zone- ASP4 11196' 8802' ADL 028307 TPI: x- 691012 y- 5957837 Zone- ASP4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth:x- 689385 Y- 5957926 Zone- ASP4 None • 18. Directional Survey: ®Yes 0 No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD DIR, GR, RES, GR/CCL/MCNL 9284' 8573' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT.PER FT. GRADE Top BOTTOM Top BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 110' Surface 110' 30" 2940#Poleset 13-3/8" 72# L-80 Surface 2600' Surface 2600' 17-1/2" 2400 sx Fondu.400 sx Permafrost'C' 9-5/8" 47# L-80 1 S00-95 Surface 7740' Surface 7126' 12-1/4" 500 sx Class'G'. 300 sx Permafrost'C' 9-5/8"x 7" 47#/26# L-80 2690' 9214' 2690' 8513' 8-1/2" 525 sx Class'G' & 318 sx'G'.237 sx'G' 4-1/2" 12.6# L-80 9061' 9284' 8372' 8573' 6" 200 sx Class'G' 3-112"xs-114" 9.2#i6.9ni6.4# L-80 9215' 11196' 8514' 8$02' 4-1/8" 102 sx Class'G' 24. Open to production or injection? ® Yes 0 No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) _ PACKER SET(MD/TVD) (MD+TVD of Top&Bottom;Perforation Size and Number): 2"Gun Diameter,6 spf 4-1/2", 12.6#, 13Cr80 9069' 9012'/8326' MD TVD MD ND 10200'-11120' 8784'-8800' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. °=1 ' RECEIVED _DEPTH INTERVAL(MD� AMOUNT AND KIND OF MATERIAL USED 2500' Freeze Protected w/38 Bbls of Diesel v , NOV 29 2011 i _,4;44_'_ 27. Meeks Gd &Gas Coos_Commission oRODUCTION TEST Date First Production: AnchOfeQ^ Method of Operation(Flowing,Gas Lift,etc.): November 18,2011 Flowing Date of Test: Hours Tested: Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 11/20/2011 3 Test Period 4 225 4,459 3 54° 52,899 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. -0- 240 24-Hour Rate 4 674 35,674_ 25 27.6° 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No Sidewall Core(s)Acquired? 0 Yes ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS NOV 3 0 20eY11myl._ Form 10-407 Revised 12/2009 CONTINUED ON REVEE 1,00K / 4 -/l--•1/ Submit Original Only /' 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? 0 Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. 23SB/Zone 2B 9321' 8602' None 22TS 9334' 8613' 21TS/Zone 2A 9417' 8678' Zone 1B 9470' 8716' TDF/Zone 1A 9523' 8746' Formation at Total Depth(Name): TDF/Zone 1A 9523' 8746' 31.List of Attachments: Summary of Daily Drilling Reports,Well Schematic Diagram,Surveys 32. I hereby certify that the foregoing's true and correct to the best of my knowledge. l' ze/11 Signed: Terrie Hubble l U 1[.P, iiiietet Title: Drilling Technologist Date: PBU 18-03C 211-066 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No./Approval No. Drilling Engineer: Matt Ross, 564-5782 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • North America -ALASKA- BP Page 1 of 6 Operation Summary Report Common Well Name: 18-03 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 10/26/2011 End Date: X3-0107Y-C(1,602,431 00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:NORDIC 2 Spud Date/Time:7/30/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292077600 Active Datum: 18-03:©46.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/26/2011 18:00 - 19:00 1.00 MOB P PRE CREW CHANGE,DISCUSS ONGOING OPS FOR RIG MOVE. NORDIC FIELD SUPERINTENDANT PRESENT FOR MOVING OFF WELL. HAVE DETAILED PJSM FOR MOVING RIG OFF 14-28A 19:00 - 21:00 2.00 MOB P PRE WARM UP MOVE SYSTEM.JACK RIG UP. MOVE OFF WELL.STAGE RIG ON PAD. 21:00 - 21:30 0.50 MOB P PRE P/U RIG MATS AROUND WELL.P/U LOCATION. WSL AND PAD OPERATOR CLOSE OUT WELL WORK TRANSFER PERMIT. 2200 HRS UPDATE AOGCC ON RIG ARRIVAL TIME. 21:30 - 22:00 0.50 MOB P PRE PJSM WITH ALL CREW MEMBERS,SECURITY ,TOOLPUSHER, NORDIC FIELD SUPERINTENDANT, WSL,AND SLB. DISCUSS DRIVE ROUTE IN DETAIL.MATTING DETAIL AND OBSTICALES. 22:00 - 00:00 2.00 MOB P PRE MOVE TO DS 18 10/27/2011 00:00 - 04:00 4.00 MOB P PRE MOVE RIG TO DS 18-03C 04:00 - 05:30 1.50 MOB P PRE R/U MATS,SET EQUIPMENT.PREP TO BACK RIG OVER 18-03C 05:30 - 10:00 4.50 MOB P PRE RIG ACCEPT 1000 HRS. CONDUCT AAR ON RIG MOVE. 10:00 - 11:00 1.00 MOB P PRE CONTINUE WITH RIG PREP FOR OPERATIONS. PJSM ON NU BOP. _ 11:00 - 13:00 2.00 MOB P PRE NU BOP. AAR OF OPERATION. 13:00 - 20:00 7.00 MOB P PRE PJSM OF CHANGING OUT LINE IN REEL HOUSE GANTRY CRANE. RUN CABLE UP AND DOWN ON DRUM SEVERAL TIMES TO ALIGN ON SPOOL. 20:00 - 21:00 1.00 MOB P' PRE INSPECT PITS. BEGIN CHANGING OUT LINERS AND SWAB ON PUMP#1. 21:00 - 22:30 1.50 MOB P PRE TAKE ON KCL INTO PITS. PJSM ON PU REEL WITH CH2MHILL,SLB,NORDIC CREW,WSL, TP. PU REEL. REEL PUW 74K. 22:30 - 00:00 1.50 MOB P PRE FILL STACK AND CHOKE MANIFOLD,MGS. INSPECT FOR ANY LEAKS,ALL GOOD. 10/28/2011 00:00 - 03:30 3.50 MOB P PRE BODY TEST OF BOP STACK. COMPLETE REPLACING LINER AND SWAB IN MUD PUMP #1. INSTALL HARDLINE IN REEL,CONNECT E-LINE INTO PRESSURE BULKHEAD. TIGER TANK HARDLINE INSTALLED AND PRESSURE • TESTED TO 300/4000 PSI. LUBRICATE, FUNCTION BOP VALVES. FUNCTION BOP COMPONENTS FROM COIL OPS CAB CONSOLE. TEST CONDUCTIVITY IN E-LINE. 03:30 - 06:00 2.50 MOB P PRE PJSM ON PULLING REEL ACROSS. INSTALL GOOSENECK AND PACKOFFS,PULL REEL ACROSS. AAR ON OPERATION. 06:00 - 09:00 3.00 MOB P PRE CUT GRAPPLE OFF OF COIL.SET INJECTOR AND STAB COIL.PUMP 5 BBLS MEOH FOLLOWED BY WARM KCL TO FILL COIL. Printed 11/14/2011 1:34:31PM .orth America -ALASKA- BP Page 2 of 6 Operation Summary Report Common Well Name: 18-03 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 10/26/2011 End Date: X3-0107Y-C(1,602,431.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time:7/30/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292077600 Active Datum: 18-03: @46.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 09:00 - 13:00 4.00 BOPSUR P PRE PJSM FOR TESTING BOPE.SHELL TEST TO 4500#.TEST ALL RAMS,ANNULAR,AND VALVES TO 250#LOW AND 3500#HIGH.NO FAILURES.(JEFF JONES W/AOGCC WAIVED RIGHT TO WITNESS AT 0845) 13:00 - 13:30 0.50 BOPSUR P PRE PJSM,BLOW DOWN KILL LINE. 13:30 - 15:30 2.00 MOB P PRE CONDUCT RIG EVACUATION DRILL W/AAR. CONDUCT PRE-SPUD MEETING W/RIG CREW AND SUPPORT PERSONNEL 15:30 - BOPSUR P PRE INSTALL COIL CONNECTOR AND RE-HEAD COIL.TEST ALL RIG GAS DETECTORS. 18:00 - 19:30 1.50 BOPSUR P PRE CREW CHANGE OUT, CLEAR AND CLEAN RIG FLOOR. LINE UP VAC TRUCKS THAT ARRIVE 'ON LOCATION DURING CHANGEOUT. CONDCUT RIG EVAC DRILL WITH CREW, THIRD PARTY PERSONNEL. AAR WITH ALL PERSONNEL. RECORD LESSONS LEARNED. 19:30 - 00:00 4.50 BOPSUR P PRE PJSM WITH LUBRICATOR CREW. MOBILIZE LUBRICATOR TO RIG FLOOR. MU, PT • LUBRICATOR AND MASTER VALVE TO 250/3500 PSI. PULL BPV WITH NO ISSUES. NO PRESSURE INDICATED. CLOSE MASTER, SSV AND RD LUBRICATOR. PUMP SSV OPEN, INSTALL FUSIBLE LINK. VALVE CREW INSPECT TREE. RD VALVE CREW EQUIPMENT. 10/29/2011 00:00 - 02:00 2.00 MOB P PRE PJSM ON MU BHA AND RIH. PREPARE TO OPEN CHOKE FOR FLOW CHECK;LINE TO TIGER TANK NOT CLEAR. INSPECT LINE, FROZE AT CONNECTION TO RIG. CLEAR LINE. RE-PRESSURE TEST HARDLINE DUE TO BREAKING CONNECTION. FLOW CHECK, NO FLOW. 02:00 - 03:00 1.00 STWHIP P WEXIT MU MILLING BHA: 3.80"WINDOW MILL, STRING MILL,XTREME MOTOR WITH.6 AKO, XO,2 JTS PH6,XO, HOT,DGS,DPS,EDC, POWERCOMMS,SUB WEAR PROTECTOR, LQC,UQC,XO,CTC. WINDOW MILL GAUGED AT 3.80"GO,3.79"NO-GO,STRING MILL GAUGED AT 3.79". STAB ON WITH INJECTOR, PT QTS. 03:00 - 06:00 3.00 STWHIP P WEXIT PJSM WITH C2MHILL PERSONNEL WHILE RIH. DISPLACE DIESEL TO TIGER TANK. CONTINUE TO RIH TO 6000'(AS OF 0515). 06:00 - 07:30 1.50 STWHIP P WEXIT TIH TO 9126.9.RESET DEPTH TO 9121.7(-5.2' CORRECTION)MAINTAIN 105 ROHS&RIH W/ WT OF 26K PUMING 2.5 BPM @ 1900#W/ OPEN EDC 07:30 - 07:40 0.17 STWHIP P WEXIT RIH AND TAG TOW @ 9284'.PU 10'TO 9274 AND PAINT FLAG.UP WEIGHT 42K. 07:40 - 08:15 0.58 I STWHIP P WEXIT INCREASE RATE TO 2.6 BPM @ 2240#AND RIH TO 9284 AND START MILLING WINDOW. 2270#FS/2333#WP,450#WOB. MW IN AND OUT 8.6 PPG. 08:15 - 08:40 0.42 STWHIP P WEXIT #2 PUMP HAS SLIGHT LEAK/SWAP TO#1 PUMP. IA 100#,OA 491#,WHP 84#.SPR#1 PUMP=1.5 BPM/1811##,.5 BPM /648# b3C 08:40 - 09:20 0.67 STWHIP P WEXIT TIME DRILL WINDOW 1 FPH,2.6 BPM,325# MW,680#-1390#WOB. Printed 11/14/2011 1:34:31PM orth America -ALASKA- BP Page 3 of 6 Operation Summary Report Common Well Name: 18-03 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 10/26/2011 End Date: X3-0107Y-C(1,602,431.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time:7/30/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292077600 Active Datum: 18-03:@46.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:20 - 10:15 0.92 STWHIP P WEXIT TIME DRILL WINDOW @1 FPH,2.6 BPM,505# MW,1390#-3010#WOB. BLEED DOWN IA FROM 938#-238# 10:15 - 14:00 3.75 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH,2.6 BPM,295# MW,3010#- 1670#WOB. BLEED DOWN IA FROM 734#TO 200#, OA 934 TO 229,WHP 62, ECD 9.6 14:00 - 15:00 1.00 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. -2.6 BPM,2560-2580 PSI ON,1.6-1.88K WOB -BLEED DOWN IA FROM 734#TO 200#,OA 934-229 PSI,WHP 62,ECD 9.6 15:00 - 16:00 1.00 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. -2.6 BPM,2565-2590 PSI ON,1.85-2.35K WOB 16:00 - 17:00 1.00 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. -2.6 BPM,2565-2635 PSI ON,2.1-3.3K WOB 17:00 - 18:00 1.00 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. 2.6 BPM,2630-2635 PSI ON,1.7-2.25K WOB 18:00 - 19:00 1.00 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. -2.6 BPM,2615-2645 PSI ON,1.7-2.2K WOB -MW IN AND OUT 8.6 PPG,ECD 9.60 PPG 19:00 - 20:00 1.00 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. -2.6 BPM,2615-2670 PSI ON,1.8-2.5K WOB EXITED WINDOW AT 9293' 20:00 - 00:00 4.00 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. -2.6 BPM,2620-2670 PSI ON,2.0-4.5K WOB -MW IN AND OUT 8.6 PPG,ECD 9.60 PPG 10/30/2011 00:00 - 00:30 0.50 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. -2.6 BPM,2620-2670 PSI ON,2.0-4.5K WOB -MW IN AND OUT 8.6 PPG,ECD 9.60 PPG -COMPLETE RAT HOLE TO 9303' 00:30 - 01:30 1.00 STWHIP._ P WEXIT REAM THROUGH WINDOW AT 1 FPM THREE TIMES. DRY DRIFT THROUGH WINDOW,NO PROBLEMS NOTED. PULL INTO WINDOW FOR FLOW CHECK. NO FLOW. 01:30 - 03:30 2.00 STWHIP P WEXIT POH WITH MILLING ASSEMBLY. CONDUCT PJSM ON LD MILLING BHA,PU AND MU OF BUILD BHA WHILE PULLING OUT OF HOLE. STOP AT 200'FOR FLOW CHECK. 03:30 - 04:00 0.50 STWHIP P WEXIT FLOW CHECK WELL,NO FLOW. 04:00 - 04:30 0.50 STWHIP P WEXIT PULL UP WITH BHA TO STACK. BREAK OFF INJECTOR. LD BHA. MILL GAUGED AT 3.80' GO,3.79"NO-GO.STRING MILL GAUGED AT 3.79"GO,3.78"NO-GO. -INSPECT TREE,FIND 2 BOLTS NOT TORQUED TO SPEC. CALLED VALVE SHOP; CREW ON WAY OUT TO CHECK AND RE-TORQUE IF NECESSARY. 04:30 - 05:30 1.00 DRILL P INTI MU BUILD BHA:3"X4.125"BI-CTR BIT,2-7/8"HI FLOW LO SPEED MOTOR,HOT,DGS,DPS, EDC,POWERCOMMS,WEAR SUB,LQC,UQC, XO,CTC. MU INJECTOR, PT QTS. 05:30 - 07:10 1.67 DRILL P INTI RIH WITH BUILD BHA TO 9000'@ 95-100 FPM. IA 137,OA 468,WHP 29,ECD 9.29,PITS 385 07:10 - 07:55 0.75 DRILL P INTI START LOGGING DOWN AT 150 FPH.PARK COIL AT 9052.1 AND ADJUST DEPTH TO 9056. (+3.9 FT CORRECTION)CHECK INJ COUNTER WHEEL AND FOUND SHIPPING PLASTIC- CLEANED IT Printed 11/14/2011 1.34:31PM orth America -ALASKA- BP Page 4 of 6 Operation Summary Report Common Well Name: 18-03 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 10/26/2011 End Date: X3-0107Y-C(1,602,431.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time:7/30/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292077600 Active Datum: 18-03:@46.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:55 - 08:15 0.33 DRILL P INTI RIH TO 9250.CLOSE EDC.WT CHK 42K. RETRIEVE SLOW PUMP RATES BEFORE ENTERING OPEN HOLE.#1 PMP= 1.34BPM/1487#,.5BPM/1084#.#2 PMP= 1.33BPM/1600#,.5 BPM/1333 08:15 - 08:30 0.25 DRILL P INTI CONTINUE TO RIH @ 1.2 FPM TO BTM @9303' AND BREAK BIT IN PER HCC RP 08:30 - 10:15 1.75 DRILL P INTI DRILL AHEAD AT 50 FPH,2500#WOB. PU AND RETRIEVE SURVEYS FOR BHI@ 9345',9375' 10:15 - 11:30 1.25 DRILL P INTI STALL MTR @ 9432'-PU AND RESTART MTR. DRILL TO 9446 AND PU TO RETRIEVE SURVEY FOR BHI.2.33 BPM,2256#FS, PITS 384, IA 522,OA 693,ECD 9.62.TOP OF ZONE 1B=9470' 11:30 - 14:45 3.25 DRILL P INTI DRILL TO 9480'.WIPER TRIP UP HOLE TO 9020'TO TIE IN CORRECTED WINDOW DEPTHS.OPEN EDC @ 9261 TO KEEP CUTTINGS GOING UP HOLE.TIE CORRECTION OF 0'. CORRECTED TOW=9284',BOW=9293',RA=9293' 14:45 - 17:30 2.75 DRILL P INTI BOBD @ 9480'.WORK THROUGH SHALE AREA AT 9570'. DRILL TO9630 WITH NO ISSUES. 17:30 - 20:00 2.50 DRILL P INTI POH WITH BUILD BHA. PULL INTO WINDOW, FLOW CHECK. STATIC. OPEN EDC, POH WITH MAX RATE. PULL TO 100'. FLOW CHECK WHILE CONDUCTING PJSM ON BREAKING DOWN BHA AND MU LATERAL BHA. STATIC. JOG DOWN,PULL BACK UP INTO TREE. LD BHA. BIT GRADE 3-3-CT-A-X-I-NO-BHA. 20:00 - 21:30 1.50 DRILL P INTI MU LATERAL BHA:3.75"X4.125"BI-CENTER BIT,3.125"ULTRA XL MOTOR WITH 1.2 AKO, HOT, USMPR, DGS, DPS, EDC, POWERCOMMS,FLOAT SUB,WEAR SUB, LQC,UQC,CTC. CONDUCT WALK THROUGH OF MU SAFETY JOINT AND STABBING SAFETY VALVE. MU INJECTOR,PT QTS. 21:30 - 23:45 2.25 DRILL P INTI RIH WITH LATERAL ASSEMBLY TO 9030'. CONDCUT TIE-IN. -4'CORRECTION. CLOSE EDC. 23:45 - 00:00 0.25 DRILL P INTI ORIENT MOTOR AND BIT,COME ON WITH PUMPS AT MIN RATE. RIH THROUGH WINDOW WITH NO ISSUES. BRING PUMPS UP AND CONTINE TO RIH. 10/31/2011 00:00 - 00:15 0.25 DRILL P INTI OBTAIN AND RECORD SLOW PUMP RATES. PUMP 1 1470 PSI AT 41 SPM,PUMP 2 1465 PSI AT 41 SPM. RIH WITH LATERAL BHA TO 9630'. 00:15 - 03:00 2.75 DRILL P INTI / DRILL AHEAD IN LATERAL SECTION. FREE SPIN 2580 PSI AT 2.6 BPM. -2.60-2.66 BPM,2685-3100 PSI,ECD 9.66-9.72 PPG,WOB 1.4-3.83 K -MW IN 8.70 PPG,MW OUT 8.68 PPG -CUTTING ACROSS SHAKERS DO NOT SHOW SHALES,PRIMARILY SOME CHERT BUT MOSTLY SANDSTONE FROM 1A 03:00 - 04:15 1.25 DRILL P INTI WIPER TRIP FROM 9750'TO WINDOW WITH MAD PASS INCORPORATED,2.65 BPM,2550 PSI. NO ISSUES NOTED ON WIPER TRIP. Printed 11/14/2011 1:34:31PM lorth America -ALASKA- BP Page 5 of 6 Operation Summary Report Common Well Name: 18-03 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 10/26/2011 End Date: X3-0107Y-C(1,602,431.00) Project: Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time:7/30/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292077600 Active Datum: 18-03:@46.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:15 - 04:30 0.25 DRILL P INTI RUN BACK IN HOLE FROM WIPER TO 9300'. 04:30 - 06:00 1.50 DRILL P INTI DRILL AHEAD IN LATERAL SECTION. FREE SPIN 3000 PSI AT 3 BPM. -2.99-3.03 BPM,3230-3400 PSI,ECD 9.76-9.85 PPG,WOB 3.59-3.71 K -MW IN 8.73 PPG,MW OUT 8.72 PPG 06:00 - 07:15 1.25 DRILL P INTI WIPER TO WINDOW FROM 9900-RETRIEVE SLOW PUMP RATES 07:15 08:15 1.00 DRILL P INTI DRILL AHEAD IN LATERAL SECTION.FS 3000# AT 3.03 BPM.PIT 381,IA 508,OA 746,WHP 88, ECD 9.84 08:15 - 09:00 0.75 DRILL P INTI DRILL AHEAD TO 10050'.MOTOR STALLS @ 9968,9970 09:00 - 10:50 1.83 DRILL P INTI WIPER TO WINDOW FROM 10050. (+4' CORRECTION)---HAVE DISCUSSION ON INCREASING FLOW RATE TO 3.7 BPM W/3 1/8 MTR.TRY VARIOUS EQUIPMENT ITERATIONS AND END UP WITH 1 PUMP ON HOLE WITH 2 GENERATORS RUNNING.68 MAX AMPS PULLED WHEN COMING OFF BOTTOM AT HIGH RATE TO SIMULATE RESPONSE TO DIFFERENTIAL STICKING EVENT.NORDIC TP AND SUPT OK WITH THESE PARAMETERS. 10:50 - 11:20 0.50 DRILL P INTI DRILL AHEAD W/NEW PARAMETERS.3.71 BPM,3830 FS, PITS 379,IA 697,OA 881 WHP 125, ECD 10.1 11:20 - 12:45 1.42 DRILL P INTI BLEED OA FROM 920 TO 650.IA FROM 730 TO 690. 12:45 - 13:50 1.08 DRILL P INTI WIPER TO WINDOW FROM 10200 13:50 - 14:50 1.00 DRILL P INTI DRILL AHEAD IN LATERAL SECTION.3.7 BPM, 3790 FS,PITS 377,IA 881,OA 801,WHP 132 ECD 10.1 14:50 - 15:05 0.25 DRILL P INTI BLEED IA FROM 952 TO 685. 15:05 - 16:45 1.67 DRILL P INTI WIPER TO WINDOW,9310',FROM 10375. REDUCE PUMP RATE TO 2 BPM ON TRIP BACK IN HOLE 16:45 - 18:15 1.50 DRILL P INTI DRILL AHEAD IN LATERAL SECTION.3.7 BPM, 3820 FS, PITS 377, IA 481,OA 542,WHP 132 ECD 10.1 18:15 - 19:00 0.75 DRILL P INTI WIPER TRIP TO WINDOW AT FULL RATE. CONDUCT TIE-IN WITH+4'CORRECTION 19:00 - 20:00 1.00 DRILL P INTI RIH AT 2 BPM FROM WIPER TRIP WITH NO ISSUES 20:00 - 21:30 1.50 DRILL P INTI DRILL AHEAD IN LATERAL SECTION. FREE SPIN 3890 PSI AT 3.65 BPM. -3.65 BPM,3950-4200 PSI, ECD 9.73-10.13 PPG,WOB 3.42-3.45 K -CHANGE TO NEW MUD SYSTEM WHILE DRILLING AHEAD;MW IN 8.7 PPG,MW OUT 8.6 PPG -ECD AND PUMP PRESSURE DROPPED WITH NEW MUD SYSTEM 21:30 - 22:15 0.75 DRILL P INTI WIPER TRIP TO WINDOW AT FULL RATE 22:15 - 23:00 0.75 DRILL P INTI RIH AT 2 BPM FROM WIPER TRIP WITH NO ISSUES Printed 11/14/2011 1:34:31 PM orth America -ALASKA- BP Page 6 of 6 Operation Summary Report Common Well Name: 18-03 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 10/26/2011 End Date: X3-0107Y-C(1,602,431.00) Project: Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time:7/30/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292077600 Active Datum: 18-03:@46.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:00 - 00:00 1.00 DRILL P INTI DRILL AHEAD IN LATERAL SECTION. FREE SPIN 4100 PSI AT 3.65 BPM. -3.5-3.6 BPM,4200-4275 PSI,ECD 9.73-10.2 PPG,WOB 2.85-3.78 K -MW IN 8.7 PPG,MW OUT 8.6 PPG 11/1/2011 00:00 - 00:15 0.25 DRILL P INTI WIPER TRIP FROM 10,925'TO WINDOW AT MAX RATE. NO ISSUES ON TRIP. 00:15 - 02:30 2.25 DRILL P INTI RIH FROM WINDOW AT 2 BPM WITH NO ISSUES 02:30 - 03:30 1.00 DRILL P INTI DRILL AHEAD IN LATERAL SECTION. FREE . SPIN 4080 PSI AT 3.5 BPM. -3.65 BPM,3950-4200 PSI,ECD 9.73-10.13 PPG,WOB 3.42-3.45K -MW IN 8.7 PPG,MW OUT 8.6 PPG 03:30 - 04:30 1.00 DRILL P INTI UNABLE TO GET ACCURATE SURVEYS; CANNOT GET SIGNAL FOR SURVEYS DUE TO LOCAL MAGNETIC STORM. DECIDE NOT TO DRILL AHEAD. CONDUCT WIPER TRIP TO WINDOW. FLOW CHECK IN WINDOW. 04:30 - 05:15 0.75 DRILL P INTI CONDUCT TIE-IN WITH+6'CORRECTION. CONDUCT CCL LOG FROM 9300'TO WINDOW TO LOG DEPLOYMENT SLEEVE AND LINER TOP PACKER SETTING AREA. 05:15 - 06:00 0.75 DRILL P INTI RIH WITH LATERAL DRILLING BHA. 06:00 - 11:30 5.50 DRILL P INTI DRILL AHEAD TO 11055'W/4330PSI @ 3.6BPM TO 11198' 11:30 - 14:00 2.50 DRILL P INTI WIPER TO WINDOW. -TIE IN TO 3'CORRECTION,TD @ 11196' 14:00 - 14:30 0.50 DRILL P INTI PUMP LINER PILL -LAY IN PILL AS POOH 14:30 - 19:00 4.50 DRILL P INTI PJSM,POOH, -FLOW CHECK @ TOL STATIC -FLOW CHECK @ SURFACE STATIC 19:00 - 20:00 1.00 DRILL P INTI PJSM -L/D BHA -BIT GRADE OF 2-1-CT-A-X-I-PN-TD 20:00 - 22:00 2.00 DRILL P INTI PJSM, -SLACK MNGT.CUT 335'OF E-LINE,50'COIL AND RE-HEAD 22:00 - 22:30 0.50 DRILL P INTI PUMP 3/4 BALL THROUGH COIL -SET INJECTOR ON LEGS 22:30 - 00:00 1.50 DRILL P INTI GATHER EQUIPMENT TO RIG FLOOR, -RU TO RUN LINER Printed 11/14/2011 1:34:31PM North America -ALASKA- BP Page 1 of 5 Operation Summary Report Common Well Name: 18-03 AFE No Event Type:COM-ONSHORE(CON) Start Date: 11/1/2011 End Date: 11/6/2011 X3-0107Y-C: (1,248,750.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time:7/30/1982 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:500292077600 Active Datum: 18-03:@46.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/2/2011 00:00 - 02:00 2.00 RUNCOM P RUNCMP PJSM FOR RUNNING LINER. -GATHER TOOLS. -CONTINUE TO RU TO RUN LINER. 02:00 - 06:00 4.00 RUNCOM P RUNCMP RIH WITH LINER AS PER TALLY AND BAKER REP -DRIFT CONNECTIONS FOR THE FIRST 10 JOINTS. -FILL LINER EVERY 10 JOINTS. 06:00 - 06:30 0.50 RUNCOM P RUNCMP CREW CHANGE-PJSM FOR CONTINUING IN HOLE W/LINER 06:30 - 09:10 2.67 RUNCOM P RUNCMP FINISH RUNNING LINER.PU SELRT AND 4 JTS OF CSH.STAB INJECTOR.TEST QTS.SET BHA LENGTH TO 2118.5 FT 09:10 - 11:25 2.25 RUNCOM P RUNCMP RIH W/LINER ON COIL 11:25 - 11:50 0.42 RUNCOM P RUNCMP DISCUSS DISCREPANCY OF FLAG VS ELECTRONIC CTDS COUNTER.MECHANICAL COUNTER ON DEPTH SO DECIDE TO RIH TO BOTTOM 11:50 - 12:35 0.75 RUNCOM P RUNCMP RIH TO TD W/LINER.WT CHECK OFF BOTTOM 40K,RIH W 20K.TAG TD @11201'X CTDS 12:35 - 12:45 0.17 RUNCOM P RUNCMP PU AND CONFIRM DEPTH AND WEIGHT.PU WT IS 46K AND BREAK OVER IS 11191'. 12:45 - 13:25 0.67 RUNCOM P RUNCMP LAUNCH 5/8 STEEL BALL AND CIRCULATE AROUND COIL.LANDED ON SEAT AT 42 BBLS. _ 13:25 - 13:40 0.25 RUNCOM P RUNCMP PRESSURE UP TO 4385# AND RELEASE FROM LINER. PU AND CONFIRM LINER IS RELEASED.PU WT=35K @ 11193' 13:40 - 17:00 3.33 RUNCOM P RUNCMP START CLEANING PITS FOR KCL CIRCULATING 17:00 - 20:00 3.00 RUNCOM P RUNCMP START KCL DOWN HOLE WHILE CONTINUING TO CLEAN PITS FILL PITS WITH KCL 20:00 - 23:00 3.00 RUNCOM P RUNCMP CLEAN PIT#5 FOR BIOZAN PILL. BUILD 100 BBL BIOZAN PILL 23:00 - 00:00 1.00 RUNCOM P RUNCMP PJSM,FOR CEMENT JOB. BATCH UP CEMENT. 11/3/2011 00:00 - 00:30 0.50 RUNCOM P RUNCMP CEMENTERS PRESSURE TESTED LINES TEST TO 6300 PSI GOOD TEST. FILL LINES WITH 6 BBLS BIOZAN. 00:30 - 01:00 0.50 RUNCOM P RUNCMP START PUMPING CEMENT. 1 BPM @ 370 PS1.15.86 PPG. AT 12:45 HRS PUMP AT 1.5 BPM WITH 1030 PSI AT 15.86 PPG WITH 2.3 BBLS AWAY. AT 12:53 HRS PUMP AT 1.5 BPM WITH 2311 PSI AND 15.86 PPG AND 21 BBLS OF CEMENT PUMPED SHUT DOWN PUMPS. Printed 11/14/2011 1:34:53PM orth America -ALASKA- BP Page 2 of 5 Operation Summary Report Common Well Name: 18-03 AFE No Event Type: COM-ONSHORE(CON) Start Date: 11/1/2011 End Date: 11/6/2011 X3-0107Y-C: (1,248,750.00) Project: Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time:7/30/1982 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:500292077600 Active Datum: 18-03:@46.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1 01:00 - 03:00 2.00 RUNCOM P RUNCMP 12:56 HRS DISPLACING CEMENT WITH RIG PUMPS. 01:03 HRS-1.53 BPM @ 1740 PSI AND 31.5 BBLS AWAY. 01:20 HRS-PUMP RATE OF 1 BPM AT 355 PSI AND 59 BBLS AWAY CEMENT AT SELRT. 01:29 HRS-1.5 BPM AT 1377 PSI AND 72.2 BBLS AWAY CEMENT AT SHOE. 01:33 HRS-SHUT DOWN PUMP AT 78.5 BBLS AWAY P/U TO 35K THEN 13'FROM 11193'TO 11180' SLACK OFF TO 11184'WITH 10K DOWN RELEASING PEE WEE.BRING PUMPS ONLINE AND APPLY 1000 PSI AND HOLD PRESSURE. P/U TO 11180'AND PRESSURE DROPPED TO 0 PSI. BRING ON PUMPS AND PUMP TE 2 BBLS OF CEMENT AND 3 BBLS OF BIOZAN OUT SIDE EXHAUST AT.75 BPM AND 677 PSI. SLACK OFF TO 11184'AND APPLY 10K DOWN. ZERO MM. BRING PUMPS ON AND RELEASE LWP AT 3400 PSI. 02:02 PUMP AT 1 BPM WITH 1800 PSI FOR A TOTAL OF 12.8 BBLS WHEN PLUG BUMPED TO 2800 PSI. SHUT DOWN PUMPS AND ENSURE LINE UP. CHECK FLOATS. FLOATS HOLDING. 02:26 PRESSURE UP TO 1000 PSI.AND P/U TILL PRESSURE DROPPED.PUMP 5 BBLS AT .75 BPM. CEMENT IN PLACE AT 02:17 HRS. (500#,- COMPRESSIVE 500#COMPRESSIVE STRENGTH WILL BE ACHIEVED AT 10:15 HRS) 03:00 - 05:00 2.00 RUNCOM P RUNCMP HOLD AAR ON CEMENT JOB. RE ALIGN PITS AND SET UP TRIP SHEETS. POH AT 98 FPM WITH PUMPS AT 1.29 BPM AND 692 PSI. CEMENT IN RETURNS ON BOTTOMS UP SEEING A DENSITY OUT INCREASE TO 9.8 PPG FROM 8.4 PPG. INCREASE PUMP RATE TO 2.31 BPM. STOP POOH AND CIRCULATE TILL RETURNS CLEANED UP. DUMPED 50 BBLS TO CUTTING BOX. CONTINUE TO POOH. TAG UP AND MONITOR WELL-STATIC. 05:00 - 06:00 1.00 RUNCOM P RUNCMP PJSM L/D BHA. RECOVER 5/8"BALL. 06:00 - 06:30 0.50 RUNCOM P RUNCMP CLEAN AND CLEAR RIG FLOOR. 06:30 - 10:30 4.00 RUNCOM P RUNCMP PJSM FILL STACK. TEST MASTER AND SWAB VALVE.GOOD TEST OPEN STACK AND INSPECT RAMS.GOOD. RECOVER SMALL AMOUNT OF CEMENT. 10:30 - 11:00 0.50 RUNCOM P RUNCMP FILL STACK SHELL TEST TO 250 PSI LOW AND 4500 PSI HIGH.GOOD TEST. 11:00 - 12:00 1.00 RUNCOM P RUNCMP SERVICE TREE. M/U SAFETY JOINT. PJSM FOR P/U PIPE. Printed 11/14/2011 1:34:53PM orth America -ALASKA- BP Page 3 of 5 Operation Summary Report Common Well Name: 18-03 AFE No Event Type:COM-ONSHORE(CON) Start Date: 11/1/2011 End Date: 11/6/2011 X3-0107Y-C: (1,248,750 00) Project: Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time:7/30/1982 12:00:00AM Rig Release. Rig Contractor:NORDIC CALISTA UWI:500292077600 Active Datum: 18-03:©46.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 16:00 4.00 RUNCOM P RUNCMP M/U BHA P/U 1-1/4"CSH. 16:00 - 17:30 1.50 RUNCOM P RUNCMP PJSM TEST QTS GOOD TEST. RIH TO 8700' 17:30 - 19:30 2.00 RUNCOM P RUNCMP LOG FROM 8700'TO 11160'AND TAG UP ON LANDING COLLAR WITH 2K DOWN. LOG DOWN AT 30 FPM AND PUMPING 2.45 BPM WITH 3790 PSI. 19:30 - 20:00 0.50 RUNCOM P RUNCMP LOG OUT FROM 11160'TO 8700' 60' PER MIN. LAYING IN PERF PILL. PAINT FLAG AT 10247.82'BIT DEPTH OR EOP AT 8025'.CORRECTED TO 8022 48'FROM LOGS. UDAC AT 8048.7'. MONITOR WELL AT TOP OF LINER.STATIC 20:00 - 22:00 2.00 RUNCOM P RUNCMP POOH TO BHA MONITOR WELL AT BHA.STATIC 22:00 - 00:00 2.00 RUNCOM P RUNCMP L/D BHA STANDING 1-1/4"PIPE IN DERRICK. 11/4/2011 00:00 - 02:00 2.00 RUNCOM P RUNCMP L/D BHA RACKING BACK 1.25"CSH. 02:00 - 02:30 0.50 RUNCOM P RUNCMP CLEAR AND CEAN RIG FLOOR. 02:30 - 03:30 1.00 RUNCOM P RUNCMP PJSM LOAD PERF GUNS AND EQUIPMENT IN PIPE SHED. 03:30 - 04:00 0.50 RUNCOM P RUNCMP R/U AND PRESSURE TEST LINER LAP TEST TO 250 PSI LOW AND 2400 PSI HIGH. 250 PSI GOOD TEST 2400 PSI TEST FAILED.ABLE TO PUMP INTO FORMATION AT 1.5 BPM a 145D PSI 04:00 - 04:30 0.50 RUNCOM P RUNCMP HAVE PJSM AND POWER POINT PRESENTATION ON P/U PERF GUNS WITH CREW AND SCHLUMBERGER. DISCUSSED WITH STEVE ROSSBERG ON FAILED LINER LAP TEST.PERMISSION TO MOVE AHEAD WITH PERFORATING WELL AND SETTING LINER TOP PACKER. 04:30 - 08:15 3.75 RUNCOM P RUNCMP PJSM AND START TO P/U PERFORATING GUNS 08:15 - 08:30 0.25 RUNCOM P RUNCMP PJSM FOR CREW CHANGE AND CONTINUE TO PU GUNS 08:30 - 09:45 1.25 RUNCOM P RUNCMP FINISH PU GUNS AND RIH W/33 STANDS OF 1 1/4 CSH 09:45 - 10:15 0.50 RUNCOM P RUNCMP PU INJECTOR AND MU TO BHA 10:15 - 10:35 0.33 RUNCOM P RUNCMP TEST QTS TO 300 LOW AND 3500 HIGH 10:35 - 12:25 1.83 RUNCOM P RUNCMP RIH W/PERF GUNS ON COIL 12:25 - 13:20 0.92 RUNCOM P RUNCMP WT CHECK BEFORE ENTERING LINER=36K PUMPING.42 BPM.CORRECT DEPTH AT FLAG. 11101.02-CORRECT TO 11094.13(- 6.8'CORRECTION) 13:20 - 13:25 0.08 RUNCOM P RUNCMP TAG BOTTOM AT 11152.7,PU TO GET WEIGHT AND RESET DEPTH TO 11156' 13:25 - 13:45 0.33 RUNCOM P RUNCMP TCP SAFETY MEETING W/GUN HAZARDS VIDEO 13:45 - 14:05 0.33 RUNCOM P RUNCMP PU AND PARK AT 11123.5 VERIFY DEPTHS AND INITIATE E-FIRE SEQUENCE. Printed 11/14/2011 1 34 53P orth America -ALASKA- BP Page 4 of 5 Operation Summary Report Common Well Name: 18-03 AFE No Event Type:COM-ONSHORE(CON) Start Date: 11/1/2011 End Date: 11/6/2011 X3-0107Y-C: (1,248,750.00) Project: Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time:7/30/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292077600 Active Datum: 18-03:©46.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:05 - 14:25 0.33 RUNCOM P RUNCMP START MOVING SLOWLY UPHOLE.GUNS _FIRED ON DEPTH AT 11122'-GOOD SHOT DETECTION AT SURFACE-LOSS OF 2 BBLS INITIALLY (PERFORATE 10200'-11120'W/SLB 2"HSD PJ 6 GUNS W/6SPF 60 DEGREE PHASING) 14:25 - 14:45 0.33 RUNCOM P RUNCMP POOH W/1:1 FLUID RETURNS-FLOW CHECK WELL AT 10500'-NO FLOW 14:45 - 16:45 2.00 RUNCOM P RUNCMP POOH/FLOW CHECK WELL AT 100'-NO FLOW-PJSM FOR LAYING DOWN BHA 16:45 - 17:15 0.50 RUNCOM P RUNCMP TAG AT SURFACE-POP OFF INJECTOR AND STAND BACK OVER CIRCULATION HOLE 17:15 - 22:30 5.25 RUNCOM P RUNCMP STAND BACK 1 1/4 CSH L/D PERF GUNS. ALL SHOTS FIRED. 22:30 - 00:00 1.50 RUNCOM P RUNCMP PJSM REMOVE GUNS FROM PIPE SHED. R/D HANDLING EQUIPMENT. CLEAR AND CLEAN RIG FLOOR 11/5/2011 00:00 - 01:30 1.50 RUNCOM P RUNCMP PJSM M/U BHA FOR LINER TOP PACKER 01:30 - 04:00 2.50 RUNCOM P RUNCMP TEST QTS.-GOOD TEST RIH WITH LTP AT 75 PM RATE OF.30 BPM AND 115 PSI. 04:00 - 07:00 3.00 RUNCOM P RUNCMP OBTAIN PARAMETERS AT 9000' UP WT OF 39K AND DOWN WT OF 22K RIH WITH PUMPS AT.5 BPM AND PSI OF 110 AT 9210'PSI INCREASED TO 220. RIH TO 9218.8'WITH 10K DOWN WT. P/U OUT AND RECONFIRM DEPTHS. SAME. MARK PIPE P/U AND DROP BALL. PUMP BALL AROUND. RIH TO TAG DEPTH OF 9218.8'P/U TO 9215' AND PRESSURE UP TO 1800 PSI.SLACK OFF AND AGAIN TAG AT 9218.8'WITH 10K DOWN WT. P/U TO 9215'AND PRESSURE UP TO 2200 PSI.SLACK OFF AND TAG AGAIN AT 9218.8' WITH 10K.AGAIN NOT SEEING IT SET 1' HIGHER.P/U TO 9215'AND PRESSURE UP TO 2500 PSI.SLACK BACK OFF TO 9218.8'WITH 10K DOWN.FOR THE FOURTH TIME P/U TO 9213'SEEING A 7K INCREASE IN UP WEIGHT PRESSURE UP TO 2500 PSI.SLACK OFF TO 9218.8'WITH 10K. DECIDE TO PRESSURE UP w \ BACK SIDE AND TEST. TEST BACK SIDE TO 250 PSI LOW FOR 5 MIN. GOOD TEST. PRESSURE UP TO 2500 PSI FOR 30 MIN. ✓ LOST 12 PSI IN THE 1ST 15 MIN AND 4 PSI IN THE SECOND 15 MIN.-GOOD TEST. DISCUSSED WITH STEVE ROSSBERG AND AGREED A GOOD TEST. 07:00 - 09:30 2.50 RUNCOM P RUNCMP PRESSURE UP TO 3400 PSI AND SHEAR OUT OF LTP. POOH AT 74 FT/MIN AND 1.8 BPM WITH 858 PSI. POOH, L/D PACKER RUNNING TOOL 09:30 - 13:00 3.50 RUNCOM P RUNCMP M/U AND RIH W/NOZZLE AND FREEZE PROTECT FROM 2500'TO SURFACE W/ 38BBLS AS POOH DISPLACING WELL TO DIESEL. Printed 11/14/2011 1:34:53PM orth America -ALASKA- BP Page 5 of 5 Operation Summary Report Common Well Name: 18-03 AFE No Event Type: COM-ONSHORE(CON) Start Date: 11/1/2011 End Date: 11/6/2011 X3-0107Y-C:(1,248,750.00) Project: Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time:7/30/1982 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292077600 Active Datum: 18-03: @46.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 20:00 7.00 RUNCOM P RUNCMP PJSM,PUMP SLACK INTO COIL,CUT 250 FT OF COIL,PUMP WIRE FORWARD TEST WIRE TO 44 OHMS GREATER THEN 2000 MEGA OHMS INSTALL COIL CONNECTOR AND PULL TEST TO 37K M/U BAKER UQC PUMP FRESH WATER PJSM N2 BLOW DOWN PUMP 5 BBLS OF MEOH PT N2 LINES TO 2500 GOOD TEST DISPLACE COIL W/N2 AND R/D 20:00 - 00:00 4.00 RUNCOM P RUNCMP CLEAN PITS WHILE WAITING WELLS GROUP VALVE CREW. WELLS GROUP VALVE CREW ON LOCATION AT 2230 HRS. PJSM FOR LUBRICATING IN BPV. INSTALL BPV. 11/6/2011 00:00 - 02:00 3.00 RUNCOM P RUNCMP R/U DSM LUBRICATOR, P/T AGAINST SURFACE SAFTY VALVE 250 LOW 3500 HIGH,GOOD TEST P/T AGAINST MASTER 250 LOW 3500 HIGH, GOOD TEST INSTALL BPV 02:00 - 12:00 10.00 RUNCOM P RUNCMP TIME CHANGE BY 1 HR FOR DAYLIGHT SAVINGS. DRAIN STACK AND INSPECT RAMS. N/D BOPE SECURE WELL MOB RIG FROM WELL. CLEAN AROUND WELL HEAD. RIG RELEASED AT 12:00 HRS 11/6/2011 Printed 11/14/2011 1:34:53PM riilI BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB DS 18 18-03 - Slot 03 500292077600 18-03C Survey: MWD Survey Report - Geographic 02 November, 2011 Øbp Will BAKER HUGHES Survey Report-Geographic 0 by INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 18-03-Slot 03 Project: Prudhoe Bay TVD Reference: 18-03B:@ 44.65ft(18-03B:) Site: PB DS 18 MD Reference: 18-03B:@ 44.65ft(18-03B:) Well: 18-03 North Reference: True Wellbore: 18-03C Survey Calculation Method: Minimum Curvature Design: 18-03C Database: EDM.16-ANC Prod-WH24P Project Prudhoe Bay,GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 18,TR-11-14 Site Position: Northing: 5,959,213.15ft Latitude: 70°17'35.252 N From: Map Easting: 691,583.44ft Longitude: 148°26'55.555 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 1.46 ° Well 18-03 API No 500292077600 Well Position +N/-S 0.00 ft Northing: 5,960,680.25 ft Latitude: 70°17'49.672 N +El-W 0.00 ft Easting: 691,604.91 ft Longitude: 148°26'53.839 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 16.15ft Wellbore 18-03C API No 500292077603 * E Model Sample Date Declination Dip Angle Field Strength ,3 . (°) 1°) (nT) BGGM2011 10/21/2011 21.44 81.03 57,671 Design 18-03C Audit Notes: Version: Phase: ACTUAL Tie On Depth: 9,275.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) 11 28.50 0.00 0.00 220.32 Survey Program Date: 11/2/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 100.00 9,275.00 Gyro(18-03B) GYD-CT-CMS Gyrodata cont.casing m/s 9,284.00 11,196.00 MWD(18-03C) MWD MWD-Standard 1122011 10:33:42AM Page 2 COMPASS 2003.16 Build 73 BAKER HUGHES Survey Report-Geographic 0 bp INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 18-03-Slot 03 Project: Prudhoe Bay TVD Reference: 18-036:@ 44.65ft(18-03B:) Site: PB DS 18 MD Reference: 18-03B:@ 44.65ft(18-03B:) Well: 18-03 North Reference: True Wellbore: 18-03C Survey Calculation Method: Minimum Curvature Design: 18-03C Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,275.00 36.07 157.51 8,565.42 -2,714.77 -578.23 5,957,951.78 691,096.11 70°17'22.972 N 148°27'10.688 W TIP 9,284.00 37.21 158.27 8,572.64 -2,719.75 -576.21 5,957,946.86 691,098.25 70°17'22.923 N 148°27'10.629 W KOP 9,314.43 35.96 173.90 8,597.13 -2,737.21 -571.85 5,957,929.51 691,103.06 70°17'22.751 N 148°27'10.502 W 9,344.56 38.31 188.99 8,621.20 -2,755.28 -572.37 5,957,911.44 691,103.00 70°17'22.574 N 148°27'10.517 W 9,374.56 38.69 205.47 8,644.74 -2,772.97 -577.87 5,957,893.61 691,097.96 70°17'22.400 N 148°27'10.677 W 9,404.36 38.96 220.94 8,668.01 -2,788.50 -588.04 5,957,877.83 691,088.19 70°17'22.247 N 148°27'10.973 W 9,434.59 41.86 233.43 8,691.06 -2,801.71 -602.39 5,957,864.26 691,074.18 70°17'22.117 N 148°27'11.391 W 9,466.65 49.42 243.74 8,713.49 -2,813.50 -621.96 5,957,851.97 691,054.92 70°17'22.001 N 148°27'11.961 W 9,495.69 54.11 253.16 8,731.49 -2,821.81 -643.15 5,957,843.13 691,033.95 70°17'21.919 N 148°27'12.579 W 9,531.36 61.11 261.94 8,750.61 -2,828.20 -672.51 5,957,835.99 691,004.76 70°17'21.857 N 148°27'13.435 W 9,560.76 69.24 267.32 8,762.95 -2,830.65 -699.05 5,957,832.86 690,978.29 70°17'21.832 N 148°27'14.208 W 9,590.76 77.83 273.28 8,771.45 -2,830.47 -727.78 5,957,832.31 690,949.57 70°17'21.834 N 148°27'15.045 W 9,610.31 82.77 277.15 8,774.74 -2,828.71 -746.96 5,957,833.58 690,930.35 70°17'21.851 N 148°27'15.604 W 9,630.47 87.85 281.35 8,776.39 -2,825.48 -766.78 5,957,836.30 690,910.46 70°17'21.883 N 148°27'16.181 W 9,660.46 88.40 285.05 8,777.37 -2,818.64 -795.95 5,957,842.40 690,881.12 70°17'21.950 N 148°27'17.031 W 9,680.68 88.62 286.96 8,777.90 -2,813.06 -815.38 5,957,847.48 690,861.56 70°17'22.005 N 148°27'17.597 W 9,710.66 88.77 283.94 8,778.58 -2,805.08 -844.27 5,957,854.72 690,832.48 70°17'22.084 N 148°27'18.439 W 9,740.74 89.48 281.10 8,779.04 -2,798.56 -873.63 5,957,860.49 690,802.97 70°17'22.148 N 148°27'19.295 W 9,770.77 89.75 278.37 8,779.24 -2,793.48 -903.22 5,957,864.81 690,773.25 70°17'22.198 N 148°27'20.157 W 9,800.69 89.45 275.37 8,779.45 -2,789.91 -932.92 5,957,867.63 690,743.47 70°17'22.233 N 148°27'21.022 W 9,830.67 89.39 272.27 8,779.76 -2,787.91 -962.83 5,957,868.86 690,713.52 70°17'22.252 N 148°27'21.894 W 9,860.56 89.29 269.03 8,780.10 -2,787.57 -992.71 5,957,868.44 690,683.65 70°17'22.256 N 148°27'22.765 W 9,890.74 89.42 266.08 8,780.44 -2,788.86 -1,022.86 5,957,866.38 690,653.54 70°17'22.243 N 148°27'23.643 W 9,920.70 89.57 263.20 8,780.71 -2,791.66 -1,052.68 5,957,862.83 690,623.80 70°17'22.215 N 148°27'24.512 W 9,956.41 89.36 259.54 8,781.04 -2,797.01 -1,087.98 5,957,856.57 690,588.65 70°17'22.163 N 148°27'25.541 W 9,980.71 89.75 257.00 8,781.23 -2,801.95 -1,111.77 5,957,851.03 690,565.00 70°17'22.114 N 148°27'26.234 W 10,010.91 90.18 254.05 8,781.25 -2,809.50 -1,141.01 5,957,842.74 690,535.96 70°17'22.040 N 148°27'27.086 W 10,040.05 90.00 251.10 8,781.20 -2,818.23 -1,168.81 5,957,833.31 690,508.40 70°17'21.954 N 148°27'27.896 W 10,070.58 88.86 250.64 8,781.50 -2,828.23 -1,197.65 5,957,822.57 690,479.82 70°17'21.856 N 148°27'28.736 W 10,100.90 88.71 253.53 8,782.15 -2,837.55 -1,226.49 5,957,812.52 690,451.23 70°17'21.764 N 148°27'29.576 W 10,130.98 88.56 257.09 8,782.86 -2,845.18 -1,255.57 5,957,804.15 690,422.35 70°17'21.689 N 148°27'30.424 W 10,160.79 89.20 260.27 8,783.45 -2,851.03 -1,284.80 5,957,797.56 690,393.29 70°17'21.631 N 148°27'31.275 W 10,190.99 89.85 263.75 8,783.70 -2,855.22 -1,314.70 5,957,792.60 690,363.51 70°17'21.590 N 148°27'32.146 W 10,221.09 89.48 267.55 8,783.87 -2,857.51 -1,344.70 5,957,789.56 690,333.57 70°17'21.567 N 148°27'33.021 W 10,251.02 88.62 271.07 8,784.37 -2,857.87 -1,374.62 5,957,788.43 690,303.67 70°17'21.564 N 148°27'33.892 W 10,281.00 89.29 275.14 8,784.92 -2,856.24 -1,404.55 5,957,789.29 690,273.72 70°17'21.580 N 148°27'34.764 W 10,311.04 89.29 278.94 8,785.29 -2,852.56 -1,434.35 5,957,792.21 690,243.83 70°17'21.616 N 148°27'35.633 W 10,340.72 88.80 282.84 8,785.78 -2,846.96 -1,463.49 5,957,797.07 690,214.56 70°17'21.671 N 148°27'36.482 W 10,370.77 88.56 286.70 8,786.48 -2,839.30 -1,492.53 5,957,803.99 690,185.33 70°17'21.746 N 148°27'37.328 W 10,400.79 88.86 291.16 8,787.15 -2,829.57 -1,520.91 5,957,812.99 690,156.71 70°17'21.842 N 148°27'38.155 W 10,431.17 88.80 295.63 8,787.77 -2,817.51 -1,548.78 5,957,824.34 690,128.55 70°17'21.960 N 148°27'38.967 W 10,460.82 88.07 295.16 8,788.58 -2,804.80 -1,575.56 5,957,836.36 690,101.46 70°17'22.085 N 148°27'39.748 W 10,490.98 88.62 292.31 8,789.45 -2,792.67 -1,603.15 5,957,847.78 690,073.57 70°17'22.205 N 148°27'40.552 W 10,520.90 89.20 290.03 8,790.02 -2,781.86 -1,631.05 5,957,857.87 690,045.41 70°17'22.311 N 148°27'41.365 W 10,551.03 88.90 287.55 8,790.52 -2,772.16 -1,659.56 5,957,866.84 690,016.65 70°17'22.406 N 148°27'42.196 W 10,580.63 88.50 284.04 8,791.20 -2,764.11 -1,688.04 5,957,874.17 689,987.99 70°17'22.485 N 148°27'43.025 W 10,610.75 88.47 281.65 8,791.99 -2,757.41 -1,717.39 5,957,880.11 689,958.48 70°17'22.551 N 148°27'43.881 W 10,641.19 89.23 278.66 8,792.60 -2,752.05 -1,747.34 5,957,884.71 689,928.40 70°17'22.604 N 148°27'44.753 W 10,670.94 89.14 276.03 8,793.03 -2,748.25 -1,776.84 5,957,887.76 689,898.81 70°17'22.641 N 148°27'45.613 W 10,700.12 89.23 273.18 8,793.44 -2,745.90 -1,805.92 5,957,889.36 689,869.68 70°17'22.664 N 148°27'46.460 W 10,730.90 89.20 270.51 8,793.86 -2,744.91 -1,836.68 5,957,889.57 689,838.91 70°17'22.674 N 148°27'47.357 W 10,765.49 89.02 268.52 8,794.40 -2,745.21 -1,871.26 5,957,888.39 689,804.35 70°17'22.671 N 148°27'48.364 W 10,791.17 88.74 265.95 8,794.90 -2,746.44 -1,896.91 5,957,886.50 689,778.75 70°17'22.659 N 148°27'49.111 W 11/2/2011 10:33:42AM Page 3 COMPASS 2003.16 Build 73 BAKER HUGHES Survey Report-Geographic 0 bp INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 18-03-Slot 03 Project: Prudhoe Bay TVD Reference: 18-03B:@ 44.65ft(18-03B:) Site: PB DS 18 MD Reference: 18-03B:@ 44.65ft(18-03B:) Well: 18-03 North Reference: True Wellbore: 18-03C Survey Calculation Method: Minimum Curvature Design: 18-03C Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 10,826.53 88.68 260.96 8,795.70 -2,750.47 -1,932.02 5,957,881.58 689,743.75 70°17'22.619 N 148°27'50.134 W 10,850.96 88.59 258.94 8,796.28 -2,754.73 -1,956.06 5,957,876.70 689,719.82 70°17'22.577 N 148°27'50.835 W 10,880.88 89.23 261.96 8,796.85 -2,759.70 -1,985.56 5,957,870.99 689,690.47 70°17'22.528 N 148°27'51.695 W 10,909.69 89.51 265.93 8,797.17 -2,762.73 -2,014.20 5,957,867.23 689,661.91 70°17'22.498 N 148°27'52.529 W 10,944.33 89.48 270.80 8,797.47 -2,763.72 -2,048.82 5,957,865.36 689,627.34 70°17'22.488 N 148°27'53.538 W 10,970.22 89.08 274.14 8,797.80 -2,762.61 -2,074.68 5,957,865.81 689,601.46 70°17'22.499 N 148°27'54.291 W 11,001.08 88.89 277.90 8,798.34 -2,759.37 -2,105.36 5,957,868.26 689,570.71 70°17'22.531 N 148°27'55.185 W 11,030.84 89.39 281.30 8,798.79 -2,754.41 -2,134.69 5,957,872.47 689,541.26 70°17'22.580 N 148°27'56.040 W 11,060.75 89.69 284.68 8,799.03 -2,747.69 -2,163.83 5,957,878.45 689,511.96 70°17'22.646 N 148°27'56.889 W 11,090.83 89.17 288.28 8,799.33 -2,739.16 -2,192.67 5,957,886.24 689,482.91 70°17'22.729 N 148°27'57.730 W 11,119.93 88.56 291.93 8,799.91 -2,729.16 -2,219.99 5,957,895.54 689,455.35 70°17'22.828 N 148°27'58.526 W 11,146.15 88.10 295.55 8,800.67 -2,718.61 -2,243.97 5,957,905.48 689,431.11 70°17'22.931 N 148°27'59.225 W 11,196.00 88.10 295.55 8,802.32 -2,697.12 -2,288.92 5,957,925.81 689,385.62 70°17'23.143 N 148°28'0.535 W TD-2 7/8" 11/2/2011 10:33.42AM Page 4 COMPASS 2003.16 Build 73 TREE 7 5-1/8"Mc_I WELLHEAD= Mc EVOY 3 f-0^ SAFETY N‘ ;: WELL ANGLE>70°@ 8563' ACTUATOR= KB.ELEV= 46' PJC DRAFT BF.ELEV KOP= 2700' Max Angle= 90°@ 9771' Datum MD= 11196' 0 2182' --I4-1/2"CAMCO BAL-O SVLN, ID=3.812" Datum TVD= 8758'SS 20"CONDUCTOR,91.5#, 110' 2690' -19-5/8"X 7"LNR TIEBACK,ID=7.50" H-40, ID=19.124" 2697' -I 9-5/8"X 7"BKR LTP w/LNR HGR, ID 6.270" 13-3/8"CSG,72#,L-80 BTC, ID=12.347" 2600' GAS LIFT MANDRELS 'A ST MD TVD DEV TYPE VLV LATCH PORT DATE TOP OF 7"SCAB LNR -I 2690' ' 3 3289 3279 17 KBG-2 DOME BK 16 11/16/11 Minimum ID = 2.377" @ 9405' 25794 5483 32 KBG-2 SO BK 20 11/16/11 3-1/4" X 2-7/8" XO PIN 1® 7538 6952 31 KBG-2 DMY BK 0 06/22/03 7585' H 9-5/8"X 7"BKR H LTP, ID=6.188" 7"LNR,26#,L-80 BTC-M, .0383 bpf, ID=6.276" -I 7584' I 3 7590' -19-5/8"X 7"BKR HMC LNR HGR, ID=6.184" 9-5/8"CSG,47#, L-80 BTC-M, ID=8.681" - 7740' H 9-5/8"MILLOUT WINDOW (18-03A)7740'-7790' • 8991' -14-1/2"HES X NIP, ID=3.813" 9012' -17"X 4-1/2"BKR S-3 PKR, ID=3.875" • 9036' -4-1/2"HES X NIP, ID=3.813" • 9056' --I4-1/2"HES XN NIP,MILLED TO 3.80"(6/26/11) 9061' -7"X 5"BKR ZXP LTP, 4-1/2"LNR, 12.6#,L-80, .0152 bpf,ID=3.958" 9068' w/11.35"TIEBACK, ID=4.39" 9069' H4-1/2"WLEG, ID=3.958" 7"LNR,29#,L-80 NSCC, .0372 bpf, ID=6.184" - -9214 -I- 9080' -7"X 5"BKR FLEX-LOCK LNR HGR, ID=4.39" •7.•• C► 9090' -15"X 4-1/2"XO, ID=3.98" 3-1/2"LNR,9.20#,L-80 STL, .0087 bpf, ID=2.992" S \ 7"MILLOUT WINDOW (18-03B)9214'-9226' 4-1/2"WHIPSTOCK(06/24/11) - 9281' \ 9267' -13-1/2"X 3-1/4"XO, ID=2.786" 4-1/2"LNR, 12.6#, L-80 IBT-M, - -9284 .0152 bpf, ID=3.958" 3-1/4"LNR,69#, L-80 TCII, .???? bpf, ID=2.80'1 9705' 4-1/2"MILLOUT WINDOW (18-03C)9284'-9293.' PERFORATION SUMMARY REF LOG: ????? ANGLE AT TOP PERF: 90°@ 10200' 9705' -13-1/4"X 2-7/8"XO, ID=2.377" Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10200- 11120 0 11/04/11 11160' - PBTD 2-7/8"LNR,6.4#, L-80 STL, .0058 bpf, ID=2.441 -I 11196' i4 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/16/82 PKR 176 ORIGINAL COMPLETION WELL: 18-03C 02/12/95 N2ES SIDETRACK(18-03A) PERMIT No:"2110660 06/25/03 N2ES SIDETRACK(18-03B) API No: 50-029-20776-03 11/06/11 NORDIC 2 CTD SIDETRACK(18-03C) SEC 24,T11 N,R14E, 1184'SNL&161'WEL 11/15/11 PJC DRLG DRAFT CORRECTIONS 11/25/11 JLJ/JMD GLV C/O(11/16/11) BP Exploration(Alaska) sisg\Tfl ggazgA n [1: SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-03C BP Exploration (Alaska), Inc. Permit No: 211-066 Surface Location: 1184' FNL, 161' FEL, SEC. 24, T11N, R 14E, UM Bottomhole Location: 3884' FNL, 2554' FEL, SEC. 24, T11N, R14E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. 14 Chair DATED this /d dy of May, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED/ ALAF OIL AND GAS CONSERVATION COMM' 'ON PERMIT TO DRILL SAY 11 2011 S 20 AAC 25.005 la.Type of work: lb.Proposed Well Class: ®Development Oil 0 Service-Winj 0 Single Zone AO. kag €Gr assign ❑ Drill ®Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed [Hydrates ❑ Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp ale Gas 2. Operator Name: 5.Bond: ® Blanket 0 Single Well 11. Well Name and Number: BP Exploration(Alaska)Inc. Bond No. 6194193 PBU 18-03C 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 11286' TVD 8756'ss Prudhoe Bay Field/Prudhoe 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Bay Oil Pool Surface: ADL 028307 1184'FNL, 161'FEL, SEC.24,T11 N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4175'FNL, 563'FEL,SEC.24,T11 N, R14E, UM June 20,2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3884'FNL,2554'FEL,SEC.24,T11N, R14E, UM 2560 27,100' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 44.65' feet 15.Distance to Nearest Well Open Surface: x- 691605 y-5960680 Zone- ASP4 GL Elevation above MSL: 16.15' feet to Same Pool: 1670' 16.Deviated Wells: Kickoff Depth: 9294 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3326 Surface: 2446 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4-1/8" 3-1/2"x 3-3/16" 9.3#/6.2# L-80 STL/TCII 2085' 9200' 8456'ss 11285' 8756'ss 102 sx Class'G' / x 2-7/8" /6.4# STL 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured): 11823' 8769' 9594',9655'&10750' 11823' 8769' None Casing Length Size Cement Volume MD TVD Conductor/Structural , 110' 20" 2940#Poleset 110' 110' Surface 2600' 13-3/8" 2400 sx Fondu.400 sx Permafrost'C' 2600' 2600' Intermediate 7740' 9-5/8" 500 sx Class'G'.300 sx Permafrost'C' 7740' 7126' Production _ Liner 1637' 7" 525 sx Class'G' . 757T-9214' 6985'-8513' Liner 2762' 4-1/2" 200 sx Class'G' 9061'-11823' 8372'-8769' Scab Liner 4895' 7" 318 sx Class'G'.237 sx Class'G' 2690'-7585' 2690'-6992' Perforation Depth MD(ft): 9566'-11791' Perforation Depth ND(ft): 8744'-8770' 20.Attachments: 0 Property Plat ®BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report IN Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the forego"'g i true and correct. Contact Matt Ross,564-5782 Printed Name (1, Title Engineering Team Leader / Prepared By Name/Number Signatu, .if Phone 564-4711 Date 51/67/ Terrie Hubble,564-4628 Commission Use Only Permit o DrillAPI Number: Permit A ov te: See cover letter for Number: I If-Q 6 50-029-20776-03-00 1\ other requirements Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coalbed1711)& �ethhane,gas hydrates,or gas contained shales:[ Other: 14 354:2 PSi, BOP /e'& Samples Req'd: ,Yes❑ pQ No Mud Log Req'd: ❑ es Ib No ii.-zsoo dos . Ar,„ J GSTL�,Z t)HZS Measures: 1:1M Yes ❑No Directional Survey Req'd: Yes ❑No / 41APPROVED BY THE COMMISSION � G , Date ,COMMISSIONER Form 10-401_454,/ i/7/ evised 07/2009 This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit In Duplicate 714— „s-./7, ORIGINAL /r/i6/u To: Alaska Oil & Gas Conservation Commission From: Matthew Ross 0 b p CTD Engineer Date: May 5, 2011 Re: 18-03C Permit to Drill request Approval is requested for a permit to drill a CTD sidetrack from well 18-03B. 18-03B is a 2003 horizontal rotary in Zone 1A. The well was brought online with competitive rates until 2009 with the well making high GOR. At current operating conditions, 18-03B is uncompetitive with no remaining wellwork options to return it to production. The proposed plan for well 18-03C is to sidetrack out of the 18-03B 4-1/2" liner with a Coiled Tubing Drilling rig on or around June 20, 2011. The existing perforations will be isolated by the primary CST liner cement job. The sidetrack will exit the 4-1/2" liner in Zone 2 and drill a 4.125"hole in the target zone lA sands. CTD Sidetrack Summary Pre-Rig Work: (scheduled to begin June 1, 2011). 1. S Dummy WS drift to 9,400' MD. 2. F Load& kill well prior to setting WS. Freeze protect well to 2000'MD. 3. E Set 4-1/2" KB packer WS at 9,274' MD. 4. C Mill XN profile at 9,056' MD. 5. V PT MV, SV, WV. 6. D Bleed gas lift and production flowlines down to zero and blind flange. 7. 0 Remove wellhouse, level pad. 8. V Set 4" `H"TWC -24hr prior to rig arrival. Rig Work: (scheduled to begin on June 20, 2011) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. Pull TWC. 2. Mill 3.8"window at 9,274' MD and 10' of rathole. 3. Drill Build: 4.125" OH, 331' (34°/100). 4. Drill Lateral: 4.125" OH, 1681' (12°/100). • 5. Run 3-1/2"x3-3/16"x2-7/8" solid cemented completion leaving TOL at 9,200' MD. • �/ 6. Pump primary cement leaving TOC at 9,200' MD, 21 bbls of 15.8 ppg liner cmt planned. . 1�'" 7. Cleanout run. FTD 8. Run MCNL/GR/CCL log. • 9. Perforate 1300ft. . 10. Freeze protect well, set BPV and RDMO. • Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Run generic GLV's. 3. ASRC flowback. Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Power-Vis mud for milling window and drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.125" Casing Program: • 3-1/2" STL, 9.3 pounds per foot, L-80 solid liner—9,200' MD to 9,230' MD. • 3-3/16"TCII, 6.2 pounds per foot, L-80 solid liner—9,230' MD to 9,600' MD. • 2-7/8" STL, 6.4 pounds per foot, L-80 solid liner—9,600' MD to 11,285' MD.4 • A minimum of 21 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 9,200' MD. . Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 3500 psi. Directional • See attached directional plan. Maximum planned hole angle is 90.24°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property—27,100 ft. • Distance to nearest well within pool— 1670ft to 18-24B Logging • MWD directional, Gamma Ray and resistivity will be run over all of the open hole section. • Cased hole GR/CCUMCNL logs will be run. Anti-Collision Failures • None. Hazards • No planned fault crossings. • The maximum recorded H2S level on Drill Site 18 was 70 ppm on well 18-24B on 5/22/2010. • Lost circulation risk is considered low for this well due to uncertain faulting. Reservoir Pressure • The reservoir pressure on 18-03C is expected to be 3326 psi at 8,800' TVDSS. 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'- ■■■�■i■■■■■ 0 ..111111111111111111MMM 79 42; -,;. 2,9'; 1 1 0 minim : ." it riot'.2g ■■�E1 ■■■■aY - aFW<W.otiwm.. ca,a ��m -I—illim P _ 1111111111111•111P H a3 �N� ;I■�■■ o$�000000000000008 �� -0 P, r `4 � ���od000'"e •U®■■ 11:2 � � � A N N N _ 49, em�U4 - ”��N8. iS�� MIME aoom 24 o o o ■ IEEE o aM1 � _ Q. .ai, mom" "' m m� a J o ^ —Ate'—'— E ■ _ .■■■ $ UfPN N. °p m 11111.1111.11.1 0 3 61 � MIN ill e< 1 ■■■■ N --------------- �gios32o&-..vg -00000�rz illl g LS!e, crmmM�Mo0. 00 l ■■Iirti■I g maCD E Q�8 8�A P,P1M P'g3 8 - ■■�I■■i■■111 mP (ui/;J OL)gidaQ 1 ! °A 3111 N..■ BP SAKUbp NYONES Travelling Cylinder Report INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 18-03-Slot 03 Project: Prudhoe Bay TVD Reference: 18-038:©44.65ft(18-03B:) Reference Site: PB DS 18 MD Reference: 18-038:@ 44.65ft(18-03B:) Site Error: 0.00ft North Reference: True Reference Well: 18-03 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 18-03C Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 4 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB DS 18 18-01 -18-01 -18-01 Out of range 18-01 -18-01A-18-01A Out of range 18-02-18-02-18-02 Out of range 18-02-18-02A-18-02A Out of range 18-02-18-02APB1 -18-02APB1 Out of range 18-02-18-02B-18-02B 10,009.60 11,251.00 1,028.29 145.45 891.88 Pass-Major Risk 18-02_DIMS-18-02-18-02 Out of range 18-02_DIMS-18-02A-18-02A Out of range 18-02_DIMS-18-02B-18-02B Out of range 18-03-18-03-18-03 9,827.22 9,550.00 83.04 24.38 62.78 Pass-Major Risk 18-03-18-03A-18-03A Out of range 18-03-18-03B-18-038 9,274.97 9,275.00 0.20 3.91 -2.51 FAIL-Major Risk 18-03_DIMS-18-03-18-03 Out of range 18-03_DIMS-18-03A-18-03A Out of range 18-03_DIMS-18-03B-18-03B Out of range 18-04-18-04-18-04 Out of range 18-04-18-04A-18-04A Out of range 18-04-18-04B-18-04B Out of range 18-04-18-04BPB1 -18-04BPB1 Out of range 18-04-18-04C-18-04C Out of range 18-04_DO NOT USE-18-04-18-04 Out of range 18-04_DO NOT USE-18-04A-18-04A Out of range 18-04_DO NOT USE-18-04B-18-048 Out of range 18-04_DO NOT USE-18-04BPB1 -18-04BPB1 Out of range 18-04_DO NOT USE-18-04C-Plan 8 Out of range 18-05-18-05-18-05 Out of range 18-05-18-05A-18-05A Out of range 18-05-18-05A-18-05A wp07 Out of range 18-06-18-06-18-06 Out of range 18-06-18-06A-18-06A Out of range 18-06-18-06B-18-06B Out of range 18-14-18-14B-18-14B 9,350.00 12,270.00 399.89 170.72 245.08 Pass-Major Risk 18-17-18-17-18-17 Out of range 18-19-18-19-18-19 10,789.69 9,625.00 653.17 175.56 480.82 Pass-Major Risk 18-23-18-23-18-23 Out of range 18-23A-18-23A-18-23A Out of range 18-24-18-24AL1 -18-24AL1 10,150.00 10,410.00 659.27 136.29 524.15 Pass-Major Risk 18-27-18-27-18-27 Out of range 18-27-18-27A-18-27A Out of range 18-27-18-27B-18-27B Out of range 18-27-18-27C-18-27C Out of range 18-27-18-27D-18-27D Out of range 18-27-18-27DPB1 -18-27DPB1 Out of range 18-27-Plan 18-27E-18-27E WP2.1 Out of range 18-28-18-28-18-28 Out of range 18-28PB1 -18-28PB1 -18-28PB1 Out of range 18-29-18-29-18-29 11,284.67 9,450.00 436.41 232.59 357.50 Pass-Major Risk 18-29-18-29A-18-29A 11,125.00 9,375.00 956.00 179.59 788.94 Pass-Major Risk 18-29-18-29B-18-29B 11,286.00 9,925.00 938.93 228.28 720.32 Pass-Major Risk 18-29-18-29BPB1 -18-29BPB1 11,286.00 9,925.00 938.93 228.26 720.35 Pass-Major Risk 18-29-18-29C-18-29C Out of range 18-31 -18-31 -18-31 Out of range 18-31 -18-31A-18-31A Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/3/2011 4:23:09PM Page 3 of 20 COMPASS 2003.16 Build 73 1 A y r t, .r. g $9aS6p'A..'�v'�'$$v�i$$m.aa C5. - t- g1 Q$$$ $$$$$$8$$$$$$ IWA8$$$$8$888888it % 2Sw �w 'h'mg'.Qdn$�v$�&'m =m� z sss sss g% ■s iiF 6 s pspi ¢¢ ¢s¢ $ g4,Fm ."2573?gym '°.^ O '° 2m Si% S iyy433ii; $A 3SS5 344 u z R %yy%!y%y S g w$ $p�3o$��3$ Axa$ cis iiIIIIIIIHHMI MilliiIs,$k il$$ s8Ii#ii813'e�"OIlli33 'I p iryryVgpA gryryMry�4IF N F n th14111t111141/1111 i1f111 1/IIIkI•kh=141114t/1+Ih1 1// $:1 py V M JYk N gXili o$ gAAq$$$882m$$2222 o li 0M ; i' Hid z/ pi8$2MM4R444M44224 `gage am � $o cw W /a 1s I 1 0 W n O 0 O N W ~ O U fD 8 (h O _ 4 E m C N 2 to O r^gy Z arm C fA C b c Z m U s Q m J a G m 7:74\\\\ Q i ng c0' - II: fgt. ):ill iti ((); 6. ‘ eo 105::+m' Um .:1 IIVP'1 . 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Oe F- 8 Milig RIIIM, , S 9 TREE= 5-1/8"McEVOY WELLHEAD= McEVOY 1 8-03 B SAFETY NOTES: ACTUATOR= AXELSON KB.ELEV= 44.7' BF.ELEV= ( I KOP= 9214' t j Max Angle= 96 @ 10774' Datum MD= N/A ® 2182' -i4-1/2"CAMCO BAL-O SVLN, ID=3.812" Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,ID=12.347" — 2600' TOP OF 7"SCAB LNR --1 2689' 0 11 2690' —19-5/8"X 7"BKR ZXP LTP,ID=? 1� •� Minimum ID = 3.725" @ 9056' I., 4 GAS LIFT MANDRELS 4-1/2" HES XN NIPPLE I 4 ST MD TVD DEV TYPE VLV LATCH PORT DATE �� �1 3 3289 3279 17 KBG-2 DMY BK 0 07/25/10 2 5794 5480 32 KBG-2 DMY BK 0 07/25/10 0, 4 11 7538 6947 31 KBG-2 DMY BK 0 06/23/03 7"LNR,26#,L-80,.0383 bpf, ID=6.276" —I 7585' :? ,e ,/ 0 7585' —19-5/8"X 7"BKR H PKR,ID=6.188" a , 7590' —19-5/8"X 7"BKR HMC LNR HGR, ID=6.184" 9-5/8"CSG,47#,L-80,ID=8.681" —I 7740' I— I 8991' -14-1/2"HES X NIP, ID=3.813" 9012' -7"X 4-1/2"BKR S-3 PKR,ID=3.875" 9036' �4-1/2"HES X NIP, ID=3.813" I 9056' —4-1/2"HES XN NIP, ID=3.725" 9061' —17"X 4-1/2"BKR ZXP LRP,ID=? 4-1/2"LNR, 12.6#,L-80, .0152 bpf, ID=3.958" H 9068' 9069' —14-1/2"WLEG,ID=3.958" I 9594' —14-1/2"HES CIBP(11/20/10) MILLOUT WINDOW (18-03B)9214'-9226' 9655' —14-1/2"WFD CIBP(08/02/09) 7"EZSV —I 9237' #1141; `` 10729' I— BKR ECP PKR 7"LNR,29#,L-80,.0372 bpf,ID=6.184" 9735' "kir 11821' — PBTD PERFORATION SUMMARY MI i410 �� . REF LOG: xxxxxx ON MNVDD/YY ►'�'�'�'�'�'�'�'1 :: ANGLE AT TOP PERF: 65°@ 9566' Note:Refer to Production DB for historical perf data4-1/2"BKR CIBP(08/17/08) —I 10750' SIZE SPF _ INTERVAL Opn/Sqz DATE 2-7/8" 6 9566-9586 0 11/20/810 / 2-7/8" 6 9600 9625 C 08/02/09 ' 4-1/2"SOLID LNR, 12.6#,L-80,.0152 bpf,ID=3.958" — 10843' - ' 2-7/8" 6 9850-10200 C 04/21/05 2-7/8" 6 10260-10430 C 08/18/08 2-7/8" 6 10470- 10590 C 04/21/05 4-1/2"SLTD LNR, 12.6#,L-80,.0158 bpf, ID=3.958" 11791' 2-7/8" SLOT 10843- 11791 SLOTTED 06/07/03 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/16/82 ORIGINAL COMPLETION 08/22/09 RRD/PJC CIBP/PERFS(08/02/09) WELL: 18-03B 02/12/95 RIG SIDETRACK(18-03A) 06/25/10 RCT/PJC SET PXN(05/15/10) PERMIT No: 2030860 06/25/03 DAC/KK RIG SIDETRACK(18-03B) 07/28/10 JLJ/PJC PULL PXN/GLV C/O(07/25-26/10 API No: 50-029-20776-02 07/29/07 CJN/SV SET PXN PLUG(07/28/07) 11/24/10 RRD/PJC CIBP/PERFS(11/20/10) SEC 24,T11N,R14E, 1184'SNL&161'WEL 08/26/07 JRP/SV PULLED PXN PLUG(08/24/07) 09/05/08 JKC/PJKC PERF/CIBP(08/17/08) BP Exploration(Alaska) 5-1/8"McEVOY WELLHEAD= McEVOY 1803C SAFE, -DTES: ACTUATOR= AXELSON KB.ELEV= 44.7' Proposed CTD Sidetrack BF.ELEV= • litiI KOP= 9214' Max Angle= 96 @ 10774' Datum MD= N/A r0 11 2182' --141/2"CA MCO BAL-O SV LN, ID=3.812" Datum ND= 8800'SS �� ��✓✓ �� 13-3/8"CSG,72#,L-80,ID=12.347" —I 2600' TOP OF 7"SCAB LNR — 2689' 2690' —9-5/8"X 7"BKR ZXP LTP, ID=? GAS LIFT MANDRELS ST_ MD ND DEV TYPE VLV LATCH PORT DATE 3 3289 •3279 17 KBG-2 DMY BK 0 07/25/10 Minimum ID = 3.725" @ 9056' 2 5794 5480 32 KBG-2 DMY BK 0 07/25/10 4-1/2" HES XN NIPPLE 1 I 7538 6947 31 KBG-2 DMY BK 0 06/23/03 7"LNR,26#,L-80,.0383 bpf, ID=6.276" H 7585' 7585' +75/8"X 7"BKR H PKR, ID=6.188" 7590' —19-5/8"X 7"BKR HMC LNR HGR, ID=6.184" I I 8991' —4-1/2"HES X NIP, ID=3.813" 9-5/8"CSG,47#,L-80, ID=8.681" H 7740' F- ® X 9012' —7"X 4-1/2"BKR S-3 PKR, ID=3.875" TSGR 8949' I I 9036' —4-1/2"HES X NIP, ID=3.813" I I 9056' H4-1/2"HES XN NIP,ID=3.725"!Ville 1 3.7" deployment sleeve /4.5" KB LTP 4-1/2"LNR, 12.6#, L-80,.0152 bpf, ID=3.958" H 9068' J • 9200' - TOL/TOC 3-3/16" x 2-7/8" XO —9600' 370 9274' -4-1/2" x 7" TT whipstock 11,285' - TD 7"EZSV 9237' i 7"LNR,29#,L-80, .0372 bpf, ID=6.184" 9735' PERFORATION SUMMARY REF LOG: xxxxxx ON MM/DD/YY �Q��j�Q�.01 ANGLE ATTOPPERF: 65°@ 9566' #.0.0......: ' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9566-9586 0 11/20/810 2-7/8" 6 9600-9625 08/02/09 2-7/8" 6 9850- 10200 C 04/21/05 2-7/8" 6 10260- 10430 C 08/18/08 2-7/8" 6 10470- 10590 C 04/21/05 2-7/8" SLOT 10843- 11791 SLOTTED 06/07/03 MILLOUT WINDOW (18-03B)9214'-9226' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/16/82 ORIGINAL COMPLETION 08/22/09RRD/PJC CIBP/PERFS(08/02/09) WELL: 18-03B 02/12/95 RIG SIDETRACK(18-03A) 06/25/10. RCT/PJC SET PXN(05/15/10) PERMIT No:' 030860 06/25/03 DAC/KK RIG SIDETRACK(18-03B) 07/28/10 JLJ/PJC PULL PXN/GLV C/O(07/25-26/10) API No: 50-029-20776-02 07/29/07 CJN/SV SET PXN PLUG(07/28/07) ' 11/24/10 RRD/PJC CIBP/PERFS(11/20/10) SEC 24,T11 N,R14E, 1184'SNL&161'WEL 08/26/07 JRP/SV PULLED PXN PLUG(08/24/07) 09/05/08 JKC/PJKC PERF/CIBP(08/17/08) BP Exploration(Alaska) ii:E§M/ 1 e • Ta Y .... O • r m a r a T. 7 tea•: - • - . _46 �� I . . • 0 • - ....., ,.. Ow .+w. T o m J F i • 1- LJ • cI�•1,... I n I • 6 U .- Y Ya q m P. a v .I a • 2 G q am .. 1) MI c F m I I J .. U m v. C • c a S' U 111 111 1111 43:(c Elall / o .. : U . -• r.. U s I S m MI 1 4 111 1111 s4:4 a m miE 2 11 .c O (14 QN N U r_I Om - Il J23!IF •�1 U • I � 1 0 f m COK I I I t O m U 40► 111 mto co m A O .. mam 41 El LL U o v m O Z m T. Ip f m Qm (7 C m• .e' 11 c m O i C �- _> S V F Ili. , � J u ~ = a 3 Z . • • ' = W m c a a O p J'_ •.. ••• R Y Z r U _ U i U fig Is m H I— u m• m f ZQ WJH f = O f O0 7 C/) 2sij •Ii .. ec cr 1:14. ... .... Ce a V ii •f 2 2 O = C ®U x` m Z UN f Z i C W • • p• 111 1111 W • C 0 f U it II I I LL f 2 i• I 1I . =•• ` U U I11 m ' I V WI t t N U CO 04 O. U U 1n n WI 2 /' 141.......4.40. 0 L.: m O I l l I ; C 'u E a d a 2 N 1111111111111111U • 2 0 • I 1 11 I". N JO 71. U. it O = Z aim II hir It 2 a v m _ V `_° 3 .0 2 �1 N N a ,4` a 3 U "� .,r.. LL o 0 0 Cl I� m mL„ H cc O J Li' Q Q J 2(7 a ll a o U J V o' 3 U 1 Jmc E In = N N U F Et rr._... ., It U n O m h, liphl- II I ZJ III V 9 :-'• i x x Alaska Department of Natural Resources Land Administration System Page 1 of 1 Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources I find Alaska DNR Case Summary File Type: ADL File Number. 28307 d Printable Case File Summary See Township,Range,Section and Acreage? 0Yes No ( New Search j LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28307 Map Search for Status Plat Updates As of 05/12/2011 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E.BENSON BL ATTN:LAND MANAGER-ALASKA ANCHORAGE AK 995196612 Case Type:784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status:35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated:05/28/1965 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction:AA-NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 014E Section: 13 Section Acres:640 Search Plats Meridian: U Township: Ol1N Range: 014E Section: 14 Section Acres:640 Meridian: U Township: 011N Range: 014E Section: 23 Section Acres:640 Meridian: U Township: 011N Range: 014E Section: 24 Section Acres:640 Legal Description 05-28-1965 *SALE NOTICE LEGAL DESCRIPTION* C14-12811N 14E UM 13,14,23,24 2560.00 U-3- 7 End of Case Summary Last updated on 0511212011. Not sure who to contact?Have a question about DNR?Visit the Public Information Center. Report technical problems with this page to the Webmaster. Site optimized for Netscape 7,IE 6 or above. This site also requires that all COOKIES must be accepted. State of Alaska Natural Resources LAS Home Copyright Privacy System Status http://dnr.alaska.gov/projects/las/Case_Summary.cfm?FileType=ADL&FileNumber=283 0... 5/12/2011 D OVERSIZED INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME . .674/ /R 2YC PTD# 'l>066 2 V Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ,�db 442 POOL: ,e146.1,0 ' /©iG Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 0 'o o t- a m 0 'a S o m 0 ( o a 3 cn a Xt I- 3 3 G) CD n _ r 'o N — _. Cn.(p N d v 0 N O O) 2. 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