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209-048
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 13-03A OA down-squeeze Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-048 50-029-20325-01-00 16320 Conductor Surface Intermediate Production Liner 8824 80 2674 1762 10478 5981 14910 20" 13-3/8" 9-5/8" 7" 4-1/2" 8986 29 - 109 28 - 2703 2218- 3980 26 - 10504 10337 - 16318 29 - 109 28 - 2702 2218 - 3916 26 - 8771 8619 - 8824 none 520 2670 4760 5410 7500 14910 1530 4930 6870 7240 8430 10650 - 16220 4-1/2" 12.6# 13Cr80 24 - 10344 8894 - 8830 Structural 4-1/2" Baker S-3 Perm 8556 10267 8556 Bo York Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY 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 0028330 , 0028315 24 - 8625 OA 146 132 274 174 5469 6187 1701 1712 384 398 322-710 13b. Pools active after work:PRUDHOE BAY No SSSV 10267 / 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 70 bbls of 15.8 ppg Class G cmt with Bridgemaker & 234 bbls of 15.8 ppg Class G cmt to 900 psi. By Samantha Carlisle at 10:03 am, Mar 09, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.03.08 14:57:40 -09'00' Repair Well OA down-squeeze 322-710 WCB 12-6-2024 Sundry Number PBU 13-03A 209-048 PRUDHOE BAY DSR-3/9/23 ACTIVITYDATE SUMMARY 1/18/2023 ***WELL O/L ON ARRIVAL, DSO NOTIFIED*** GREASE CREW SERVICED TREE. RAN KJ. 3.805" GAUGE RING, 2'x1-7/8" STEM, 4-1/2" BLB, BULL NOSE & BRUSHED TUBING FROM SURFACE DOWN TO XN @ 10,302' SLM (10,332' MD), NO RESTIRCTIONS. ***CONTINUE ON 1-19-23 WSR*** 1/18/2023 T/I/O= 1000/1500/390 Temp= SI TFS unit 4 Assist SL (Load & Test) FP FL with 3 bbls 60/40 followed by 57 bbls crude. ***Job continued on 01/19/2023*** 1/19/2023 ***CONTINUE FROM 1-18-23 WSR*** T-BIRD LOADED IA W/ 150bbls CRUDE & TUBING W/ 195bbls CRUDE. SET 4-1/2" PXN PLUG BODY (4- 1/4" ports, oal: 29") IN XN NIP @ 10,302' SLM (10,332' MD), GOOD PULL TEST, SHEARED OFF CLEAN, ALL PINS RECOVERED. SET P-PRONG IN PXN PLUG BODY @ 10,302' SLM (10,332' MD) T-BIRD CONDUCTS PASSING CMITxIA (see log) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED*** 1/19/2023 ***Job continued fom 01/18/2023*** TFS unit 4 assist SL (Load & Test) Loaded IA with 2 bbls 60/40 followed by 150 bbls crude. Pumped 1 bbls 60/40 followed by 195 bbls crude to load TBG. CMIT-TxIA ***PASSED*** to 1501psi. Pumped 4 bbls crude to reach max applied psi of 1500 psi with a target psi of 1350. 1st 15 min TxIA lost 8/10 psi. 2nd 15 min TxIA lost 3/4 psi. Total loss of 11/14 psi in 30 min, Bled back 3.9 bbls crude. Tags hung on MV & IAC, SL in control of well upon departure. FWHP=318/280/365 2/1/2023 T/I/O = SSV/1840/340. IA FL (Fullbore request). ALP = 1980 psi, SI @ CV. IA FL @ 660' (12 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:00 2/4/2023 Objective: OA downsqueeze MIRU HES pump equipment. Pumped 70bbls of 15.8 class G with bridgemaker and ~234bbls of 15.8 class G cement and squeezed to 900psi. See log for details. RDMO **Job complete** 2/6/2023 T/I/O = SSV/1600/20. Temp = SI. WHPs (post OA cement squeeze). ALP = 1920 psi, AL SI @ casing valve. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:30 2/12/2023 ***WELL S/I ON ARRIVAL*** PULLED PX-PRONG FROM 10,332' MD PULLED 4-1/2" PXN PLUG BODY FROM 10,332' MD ***JOB COMPLETE, WELL LEFT S/I*** 2/22/2023 WIE CONFIRMS MONITORING T/I/O POST OA CMT SQZ IS COMPLETE. Daily Report of Well Operations PBU 13-03A SET P-PRONG IN PXN PLUG BODY @ 10,302' SLM (10,332' MD)@ T-BIRD CONDUCTS PASSING CMITxIA (see log) Objective: OA downsqueeze T-BIRD LOADED IA W / 150bbls CRUDE & TUBING W / 195bbls CRUDE. SET 4-1/2" PXN PLUG BODY (4- 1/4" ports, oal: 29") IN XN NIP @ 10,302' SLM (10,332' MD), WIE CONFIRMS MONITORING T/I/O POST OA CMT SQZ IS COMPLETE CMIT-TxIA ***PASSED*** to 1501psi. BRUSHED TUBING FROM SURFACE DOWN TO XN @ 10,302' SLM (10,332' MD), NO RESTIRCTIONS PULLED PX-PRONG FROM 10,332' MD PULLED 4-1/2" PXN PLUG BODY FROM 10,332' MD ***JOB COMPLETE, WELL LEFT S/I*** MIRU HES pump equipment. Pumped 70bbls of 15.8 class G with bridgemaker and j g ~234bbls of 15.8 class G cement and squeezed to 900psi. See log for details. RDMO 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 planned perforations require a spacing exception?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 ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 13-03A OA down-squeeze Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-048 50-029-20325-01-00 ADL 0028330 , 00283315 16320 Conductor Surface Intermediate Production Liner 8824 80 2674 1762 10478 5981 14910 20" 13-3/8" 9-5/8" 7" 4-1/2" 8986 29 - 109 28 - 2703 2218- 3980 26 - 10504 10337 - 16318 2245 29 - 109 28 - 2702 2218 - 3916 26 - 8771 8619 - 8824 none 520 2670 4760 5410 7500 14910 1530 4930 6870 7240 8430 10650 - 16220 4-1/2" 12.6# 13Cr80 24 - 103448894 - 8830 Structural 4-1/2" Baker S-3 Perm No SSSV 10267 /8556 Date: Bo York Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY 1/5/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL 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 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Anne Prysunka at 11:17 am, Dec 20, 2022 322-710 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2022.12.19 17:35:02 -09'00' SFD 12/20/2022 ADL0028315 SFD 12/20/2022 2245 10-404 MGR21DEC22GCW 12/21/22 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.12.21 10:37:53 -09'00' RBDMS JSB 122222 OA Down-Squeeze Well: 13-03A PTD: 209048 API: 50-029-20325-01 Well Name:13-03 Permit to Drill Number:209048 Well Type PAL API Number:50-029-20325-01 Job Scope:OA down-squeeze Reg.Approval Req’d?Yes Current Status:Operable, Online Date Reg. Approval Rec’vd: Estimated Start Date:1/5/2023 Estimated Duration:2day Regulatory Contact:Carrie Janowski First Call Engineer:Oliver Sternicki Second Call Engineer:Jerry Lau Current Bottom Hole Pressure:3125 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2245 psi Gas Column Gradient (0.1 psi/ft) Last SI WHP:1700 psi Min ID:3.725” XN Nipple @ 10332’ MD Max Angle:101 deg @ 14930’ MD Brief Well Summary: 13-03 is an operable gas lifted producer. A rig sidetrack in 2009 cut the 9-5/8” PC at 2218’ MD and ran a 7” PC from surface to 10504’ MD with a window cut in the 9-5/8” at 3980’ MD. MIT-OA passed to 2000 psi on 2/15/2009, pre-sidetrack. OA has persistent pressure that will not bleed down below 260 psi. Current Status: OA has persistent pressure that will not bleed down below 260 psi. OA NFT on 9/12/22 bled back 5 bbls of fluid in 9.5 min through a half inch hose. Step rate OA injectivity test on 11/18/22, 5 bpm @ 1600 psi. Scope of Work: Cement OA from surface to 3980’ MD. Procedure: 1 Fullbore/ Slickline Load IA and Tubing, set TTP. Begin sundry work 2 Fullbore Downsqueeze OA with cement from surface to 3980’ MD. 3 DHD/ Fullbore Monitor, resqueeze with cement or sealant as necessary. End sundry work 3 Slickline/ Operations Pull TTP, POP, Monitor OAP. 2245 psi See expected pumping volumes and pressures appended at the end of this document.mgr OA Down-Squeeze Well: 13-03A PTD: 209048 API: 50-029-20325-01 Current Schematic OA Down-Squeeze Well: 13-03A PTD: 209048 API: 50-029-20325-01 Proposed Schematic 1 Rixse, Melvin G (OGC) From:Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent:Wednesday, December 21, 2022 8:56 AM To:Rixse, Melvin G (OGC) Subject:RE: [EXTERNAL] PBU 13-03A PTD209-048 OA Downsqueeze Sundry 322-710 Mel, Maxtreatingpressureisgoingtobe2000psi. OliverSternicki HilcorpAlaska,HilcorpNorthSlopeLLC WellIntegrityEngineer Office:(907)5644891 Cell:(907)3500759 Oliver.Sternicki@hilcorp.com From:Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov> Sent:Tuesday,December20,20225:09PM To:OliverSternicki<oliver.sternicki@hilcorp.com> Subject:[EXTERNAL]PBU13Ͳ03APTD209Ͳ048OADownsqueezeSundry322Ͳ710 Oliver, Whatisyourexpectedvolumeofcement? Whatisyourlimitingpressureforyoursqueeze? MelRixse SeniorPetroleumEngineer(PE) AlaskaOilandGasConservationCommission 907Ͳ793Ͳ1231Office 907Ͳ297Ͳ8474Cell CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION:Externalsender.DONOTopenlinksorattachmentsfromUNKNOWNsenders. 2 CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission(AOGCC), StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,useor disclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwardingit, and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactMelRixseat(907Ͳ793Ͳ1231)or(Melvin.Rixse@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA - -- ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program: 10 Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Set CIBP 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work5. Development 0 Exploratory ❑ Permit to Drill Number 209-048 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 1 S. API Number: 50-029-20325-01-00 7. Property Designation (Lease Number): ADL 028315 & 028330 8. Well Name and Number: PBU 13-03A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 16320 feet Plugs measured 14910 feet true vertical 8824 feel Junk measured None feet Effective Depth: measured 14910 feet Packer measured 10267 feel true vertical 8986 feet Packer true vertical 8556 feet Casing: Length: Size: MO: TVD: Burst: Collapse: Structural Conductor 80 20" 29-109 29-109 1530 520 Surface 2675 13-3/8" 28-2703 28-2703 4930 2670 Intermediate 1762 9-5/8" 2218-3980 2218-3916 8150 / 6870 5080/4760 Intermediate 10478 7" 26-10504 26-8771 7240 5410 Liner 5981 4-1/2" 10337 - 16318 8619-8824 8430 7500 Perforation Depth. Measured depth: 10650 - 16220 feet True vertical depth: 8894-8830 feet Tubing (size, grace, measured and free vertical depth) 4-1/2" 12.6# 13Cr80 24-10344 24-8625 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 10267 8556 true vertical depth) No SSSV Installed 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: 266 409 6501 1709 319 Subsequent to operation: 251 383 6627 1675 334 14. Attachments: (®qumd per 20 MC 25.070,25,071, &25,263) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Brown, Don L. Contact Name: Brown, Don L. Authorized Title: Petroleum Engineer Contact Email: bmwd2ABP.com Authorized Signature: Qwl) Date: OJx3 Ica Contact Phone. +1 9075644675 Form 10404 Revised 04/2017 efll� yansl'.20 " RBDMS-"'AUG 2 9 2019 Submit Original Only CTU#9 1.75" CT. Job Scope: Set Retainer / Pump Cement Plug MIRU CTU. Perform Weekly BOP Test. Shut in well and bleed IA. MU & RIH w/ HES 2-7/8" GR/CCL Logging Carrier w/ 3.68" JSN. Load well with 1% KCI w/ SafeLube. Tag PBTD at 16252' down / 16248' up. Log from compression up to 10100'. Flagged Pipe at 14850'. Pooh. Break down tools & check data. 7/29/2019 ***Continue Job on 7/30/19 WSR*** CTU#9 1.75" CT. Job Scope: Depth Log / Set CIBP Receive good data (-13' Correction ). Correlate to Sib Memory Jewelry Log 05 -Feb -2012. Corrected PBTD @ 16237.97'. MU & RIH w/ Baker CIBP. Correct depth at flag. Set top of CIBP at POOH. RDMO CTU. 7/30/2019 Fjj14910'. ***Job Com late""* TREE= CMI WELLHEAD= • FMC ACTUATOR=' BAKER C (5 B. ELEV = 76' REF ELEV= 7293' BF. ELEV = 44.43' KOP = 3960' Max Arqb = 101• 14930' Dalen MD = 1062T Dakin TVD= 8800'SS 9-5/8" �� I, D -19.124' :Owl& H) 2218' =1�� Minimum ID = 3.725" @ 10332' 4412" HES XN NIPPLE 95/8' WHIPSTOCK 3980- 19-5/8' 9-5/8' CSG, 47#, N-80 BTC, D = 8.681"11319' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 43" @ 10650' We: Refer b Ploduc8on DB br Nstodcal perfdata SIZE SPF NTERVAL OprgSqz I SHOT SQZ 2-7/8" 6 10650 -10665 O 07/11/09 KBG2 SO 2-71W 6 10759-10773 O 07/11/09 7232 2-71W 6 10940-10995 O 07/11109 2 2-7/8" 6 11600-11620 O 07/11)09 0 2-7/8" 6 11855-11890 O 07111)09 KBG2 DMY 2-7/8" 6 11945-12100 O 07/11/09 2-7/8" 6 12235 -12280 O 07/11/09 2-7/8" 6 12345-12370 O 07/11/09 2-7/8" 6 12605-12630 O 07/11/09 2-7/8" 6 12680-13120 O 07/11/09 2-7/8" 6 13440-13495 O 07/11109 2-7/8" 6 13870-13930 O 07/11/09 2-7/8" 6 13970-14105 O 07/11/09 2-71W 6 14395-14460 O 07111109 2-7/8" 6 M30-14880 O 07/11/09 2-718" 6 15600 -15645 C 07/11)09 2-7/8" 6 15750-16025 C 07111)09 2-7/8" 6 16085-16220 C 07/11)09 13-03A R QURSAFETY ESTA SSSSV L 472 E'CHROhE TBG & LNR - ORIG WBS NOT SHOWN BE_OW WFPSTOCK I� J 2119' 412"FES X NP, D=3.813" 5 3687 3659 25 KBG2 DOME BK 16 09/29/13 4 6646 5824 46 KBG2 SO BK 26 09/29/13 3 8643 7232 46 KBG2 OW BK 0 07/14/09 2 9803 8139 26 KBG2 DMY BK 0 07/14/09 1 10200 8495 26 KBG2 DMY BK 0 07/14/09 MLLOUT WINDOW (13-03A) 3980' - 3997' X4-12" HES X NP, D = 3.813- = 3.870' 10337 J-141/2" HES XN NP, D = 3.725" 10337'T75"BIR D ZXPLTP w/TESACK&KR FLFXLOCKHGR 4.93" 4-112- TBG, 12.6#,1� 0344 13CR80 VAM TOP, .0152 bpf, ID = 3.958" 10362' 5" X 412" XO, ID = 3.890" 7" CSG, 26#, 10360' L-80 TCI XO TO L-80 BTC -M: 56, 28#, L-80 BTG -M, ly 62710504' \ 6' 14910' 4-12" BKR CIBP 16237' iP, .0152 bpf, ID - 3.958" H 1631$" PRUDHOE BAYUNIT WELL: 13-03A PERMIT No: F1090480 APINo: 50-029-20325-01-00 SEC 14 T10N R14E 2051' FSL & 7' FEL DATE REV BY COMMENTS DATE REV BY COMMENTS 03118119 PKR 141 ORKUNALCOMPLETION 07/14/16 JTGIJMD SET VALVE 06/12/16) OIMOI82 N1ES RVYO 08/31/17 JGL/JMD PULLED K VALVE(OB/JN17 07116/09 N9ES SIDETRACK 13-0 07/31/19 JCF/JMD SET CBP(07/30/19) 02)03/16 GRC/TLH PB VLV UPDATE PER STATE REGS 0822119 DD/JMD ADDED OKB, BF, &REF ELEVS 0223/16 MJI SSSV K VLV CIO 2/11/16 BP Expbration (Alaska) 0426/16 GC/JMD PULLED K VLV (0421116) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 9& 41i zI(6 DATE: 3/29/2018 P. I. Supervisor l FROM: Lou Laubenstein SUBJECT: No Flow Test Petroleum Inspector PBU 13-03A - BPXA PTD 2090480 - 3129/18: I arrived on location and met up with Ryan Holt the BP rep and discussed the No-Flow procedure. PBU 13-03A was shut in on 3/28/18 @ 20:30, including the gas lift supplying the well. Bleeding down of the IA started @ 20:30 and bleeding of the tubing @23:30 on 3/28/18. The wellhead pressures prior to shut in were Tubing = 360psi, Inner Annulus (IA) = 1630psi, and Outer Annulus (OA) = 340psi. There was 2-inch hardline rigged up from the tree cap and IA to a flow Tee, then 1-inch hose to an inline low rate flow meter prior to entering a bleed trailer. The well was open to atmosphere (bleed trailer) when I arrived and all gauges where installed and ready to test. All calibrations where current. The following table shows test details: Time Pressures' Flow Rate2 Remarks (psi) Gas—scf/hr Liquid —gal/hr 10:10 0/0/300 Shut in for build up 10:40 8/0/300 30-minute pressure reading 11:10 14/0/300 2000+ ' 0 4 min to < 900scfh 6:15 min to Opsi 11:22 0/0/300 Shut in for build up 11:52 9/3/300 30-minute pressure reading 12:22 15/5/300 2000+ ' 0 - 4:05 min < 900scfh 6:30 min to 0psi 12:32 0/6/300 Shut in for build up 13:02 8/6/300 30-minute pressure reading 13:32 15/7/300 2000+ _ 0 - 4:05 min < 900scfh 5:45 min to Opsi 1 Pressures are T/IA/O 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr SUMO Attachments: Photos , Flow Meter Calibration Certificate Pressure and Injection Plots - Offset Injection Wells ' 2018-0329_No-Flow_PBU_13-03A_11.docx Page 1 of 4 1 0 • ♦ - .. 0 .... ,... ,_IAA. . 4 .4 Aiiirl. ,....a , ‘, '*,: .. t sst : i 0 c. 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H •'/..• •** •I.. . plaFpt4FFFppl!FlplFa* eeRee. Fl O `o 0 e m i E .n i N 0 0 Q ii'f P' u F c . C7 c mQ y 4 y d m L C rt 4 p o 7 i` �vSi iTi i!!!!,iii.Y o i' i'i"eiiis!Ipirgi.iii"i.1 N N V . • oF ew_�\I%% _s THE STATE Alaska Oil and Gas ,44>� "? . • OfA L Conservation Commission s _ " t=_=_ 333 West Seventh Avenue 411 tie:** �� Anchorage, Alaska 99501-3572 �� GOVERNOR BILL WALKER g \T� pF `� ;; Q, Main: 907.279.1433 LAel& Fax: 907.276.7542 www.aogcc.alaska.gov October 20, 2017 Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration(Alaska) Inc. P.O. Box 196612 Anchorage,AK 99519-6612 RE: No-Flow Verification PBU 13-03A SCANNEQty� j t PTD 2090480 Dear Ms. Cocklan-Vendl: On September 24, 2017, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit 13-03A. AOGCC's Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit 13-03A. This was the first AOGCC witnessed test performed by BP Exploration (Alaska)Inc. (BPXA)that used a calibrated no- flow test meter. Tubing pressures,gas flow rates and liquid flow rates were monitored during a four-hour test. The test result has been deemed inconclusive. The procedure followed by BPXA did not match test procedures typically used by operators seeking to eliminate the need for a well's subsurface safety valve. AOGCC regulation requires a no-flow test must be performed according to commission-approved procedues". 20 AAC 25.265(k)(1). We have no record of receiving a procedure from BPXA for performing a no-flow test using a flow meter. BPXA did previously reach out to the AOGCC with its approach for confirming a well's inability to flow unassisted to surface using the pressure discharge method allowed in 20 AAC 25.265(1). A fail-safe automatic safety valve system—including a subsurface safety valve as described in 20 AAC 25.265(d)—is required to be installed in this well based on the no-flow test result. Sincerely, .1044 James B. Regg /l Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors AKOPSFFWelIOpsCompRep@bp.com AKDC Well IntegrityCoordinator@bp.com Ryan Daniel, BPXA . • No Flow Verification,PBU 13-03A October 20,2017 Page 2 of 2 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 101)-111 1 DATE: 9/24/2017 i�� �. P. I. Supervisor FROM: Bob Noble SUBJECT: No Flow Test Petroleum Inspector PBU 13-03A ' BPXA PTD 209-048 - 9/24/2017: I traveled to BPX Prudhoe Bay Drillsite 13 for a witnessed no-flow test on PBU 13-03A. On arrival, I met with BPX representative Mr. Ryan Holt. We walked over their rig up for the no-flow test.This is the first time I've seen BPX use a flow meter for a no-flow test. I inspected the flow meter and it had a current calibration. We discussed their test procedure. The well had been open to flow with gas lift shut in for 4 hours prior to my arrival. Mr. Holt wanted to monitor flow through a 1-inch hose to a tank for 3 hours without shutting the well in for buildup. I told him I would like to shut the well in for pressure built up instead of flowing continuously for 7 hours. He was against shutting the well in but accommodated my request. The following table shows test details: Time Pressures Flow Rate2 Remarks (psi) Gas - scf/hr Liquid - gal/hr 12:00 0 0 0 Shut well in 12:30 12 0 0 S/I Opened well up briefly; flow rate 13:00 24 >1800 ✓ 0 max'd out meter; well SI immediately 13:15 0 0 0 Meter bypassed; opened well and bled pressure to zero 13:45 0 0 0 Well left open 14:15 0 350 0 Well left open 14:45 0 650 0 Well left open 15:15 0 200 0 Well left open 15:45 0 0 0 Well left open 16:15 0 0 0 Well left open 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr 2017-0924 No-Flow PBU_13-03A_bn.docx Page 1 of 2 • • S The well was shut in for 1 hour to monitor—tubing pressure built up to 24 psi. Mr. Holt then cracked open the valve to the flow meter and it pegged the flow meter (flow rate >1800 scf/hr). He slammed the valve closed and said "that's why I didn't want to shut it in". He then bypassed the meter and lined up the flow path from the well to another tank to bleed off pressure. It took 15 minutes to bleed to 0 psi. Mr. Holt next lined up the well to flow through the flow meter. This was monitored for 3 iv hours without shutting in the well. This was not a method that I agree with and it was not proved to me that the well passes a no-flow test. Attachments: none 2017-0 924_No-F low_PBU_13-0 3 A_bn.do cx Page 2 of 2 i STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMM N REPORT OF SUNDRY WELL OPERATI NS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Install K-Valve Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 209-048 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20325-01-00 7. Property Designation(Lease Number): ADL 0028330 8. Well Name and Number: PBU 13-03A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: 16320 RECEIVED Total Depth: measured feet Plugs measured feet i true vertical 8824 feet Junk measured feet JUL. 1 4 20 t6 Effective Depth: measured 16237 feet Packer measured 10268 feet true vertical 8829 feet Packer true vertical 8556.97 feet GCC Casing: Length: Size: MD: TVD: Burst: Collapse: �f Structural Conductor 80 20"94#H-40 29-109 29-109 1530 520 Surface 2678 13-3/8"72#N-80 28-2706 28-2706 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 5981 4-1/2"12.6#L-80 10338-16319 8620-8824 8430 7500 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 25-10345 25-8626 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) See Attachment See Attachment See Attachment 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SA ED JAN 3 7 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 198 82 4856 1770 553 Subsequent to operation: 158 74 4758 1763 619 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG 0 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: 316-249 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer SignaturefffVVV 4.4...r ( Phone +1 907 564 4424 Date 7/13/16 � 2/L Form 10-404 Revised 5/2015 V7-1.- /r' / /2_ / / 4- RBDMS l.k/JUL 1 8 2016 Submit Original Only • • to N 00000 (000 — (O - O r-- Ln I, N to in .1- C.)V i co co0L() N- C') co U) 0) N c- CO Nr �f (a t- N- CO (00000 O CO N O r- CO • 0 N- c- NN N co O) co co N CO N M CO CO F- 0) 0) 0 O') 00 (OANLo NNNNM (ON N N CO OOO N 00 - � N 0 co M (co O co A- 1- C.) c a 0 o) co co - N M �o _ N N N N N 0 N .1▪2 F•• N1 O a 0 p p 0 02 0) Z co O 00 O M O 4# ▪= dNJU) 4# p4t GO CA 00 N Nr 7d N.-a) N r- 000cod' O (0 M O W W W Q Q Q •01— w00 0 U Z 0 W W W UJ m OJF— F— HZD O Z Z Z J 1_ • • d m M O) to M Tr Tr CO M CD to n 00 n- N C n- 00 CD M M e- CO CO 0001 to N CO '— OCOOctOM nt to CDN n- N et CD O ONs n- 07 CO OD n- O M O M O CO OCA 00 CO tt M •- 00 N- O NT C4 CD CD 00 d' M 0 00 03 0 03 CO 00 0CD 0 00 00 0 000 OD 0CD 0 00 00 0CD 0 co0000 000 CIa 0 �- 0Tr00r- MOD00 — CO Nor NTN N- 0) 0) n r CO 00M000A0Tr00 Nr- 0N- CO0 ei 00 ni ai C6 06 0i CDOrn0D N- C1) � 0 0 CA001VCACD0000v W 00 CA O CD CA CD CD CD CD 0 0 0 CA O CD O) 00 00 00 > Ca 03 00 C)) 0D 0D 00 0D 00 00 °D °D 00 0 °O 03 00 00 00 0 w 0 w z 0 Li N CI g g Y o 0 CO 0 0 < Y Y g ▪ 0 Mtn 00000000 tn0000CDCD0 cn N J U U W Y Q. CO Ns 0) NCD O co N- M N CD 0 M O CO 00 nt N J CV J J a s U Z CO N- CD CO 00 n- N 01 CO NT CO CA — - 00 CO O N Q Q Q W g 000n- NNNNMMMMTrTrTrtnC000 U U U J W W O J U G1 H z z z o 0 o a W a 0 0 0 0 0 W Oe ZOZ ▪Vas M 2 00) 0) canv) (1) Q a _ r CD0) 00CD ncntntn00000tn000cc) O _, d CO N- 0) CO 000 Com) N C01 OY) CO CO ' tCD 00 nt on 00 ONs ff) M OM3 CO N-CD QD 0 ▪ M 0 000 — sr- NNCV NM000101Tr Trtntn4.0 CO LYY.a1l N O tY -1 _ l- O� a a 2 0 v) cn cn 0) 0) a, a 0 0 G Co W W W W W W W W W W W WWW W W W W W Qaaaaaaaa. arla. aan. aaaaa 0 0 a a1 j a CDcncDC) rnrnCna) rnCna) 0) Cs) rnrnrnrn0) rn0 0 0000000000000000000 0 D O• N N N N N CV N N N N NCV N N N NCV N N Z LL 1 1 Q W W O dna JJ J LO W G r- r- N- N. N- N- r- r- N- N- N- r- Ns r- Ns r- Ns N- rs Q O J '� I J J O J O w D_ 0 m O Y O Y W J -I O CZ O w W < < 330.. 330) LI LL ;n W Cn D_ cc 0 E zaQQaaaaQQQaQaQ « « M M M M M M M M M M M MMM M Ch M M 01 3 0000000000000000000 0 U 0 rL N LY LL Cn M M Cl) 01 Cr) Cl)YM Cl) C1) Cl) Cl)YM 01 Cl) M 01 M 01 Cl) Q Q m m 0 LL UO O w Y • • Packers and SSV's Attachment PBU 13-03A SW Name Type MD TVD Depscription 13-03A SSSV 2119 2118.94 4-1/2" K Valve 13-03A TBG PACKER 10268.32 8556.97 4-1/2" Baker S-3 Perm Packer 13-03A PACKER 10349.51 8630.26 5" Baker ZXP Top Packer • • ;•,. oo C -) L u ib o 0 N a CO CO cc E 2 V u) 0_ O Nr O c00 O o w O O O O ~ N CO ^, 11 � � "O ‘- 5 • Y � LL O y (0 U a 2 E C E c N o 05 c > O < O O - O a U) > ~ E 5 O " ` cacp am ,c0 � � .� YQ m _a c 3 � 0 -o c _c _o m } m - . (1) •c4 CD � � � Q3c� y Q * _ my) cow J N c O N U)• cp F- c = . 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Q =' TREE AD= ! 13-03A R tIRNOTES: SA SSVV�`L 4-1/T ANGLE CHROME TBG&LNR WELL ACTUATOR= BAKER C ORIG WBS NOT SHOWN BELOW WI-PSTOCK"' ORIG KB.ELEV 76' OPG BF.ELEV ? 2 KOP= 3980' ' 2119' J-14-1/2"FES X NP,D=3.813" Max Angle= 1"@ 14930' 20"CONDUCTOR,94#, -- 109' Datum MD= 10623' H-40,D=19.124" 2345 (9-518"FOC Datum ND= 8800'SS j 2469' —19-5/8"FOC 9-5/8"CSG STUB(06/18/09) H 2218' GAS LFT MANDRELS 13-3/8"CSG,72#,N-80,D=12.347" —I 2706' ST M3 ND DEV TYPE VLV LATCH PORT DATE 5 3687 3659 25 KBG2 DOME BK 16 09129/13 Minimum ID = 3.725" @ 10332' 4 6646 5824 46 KBG2 SO BK 26 09/29/13 3 8643 7232 46 KBG2 DMY BK 0 07/14/09 4-1/2" HES XN NIPPLE 2 9803 8139 26 KBG2 DMY BK 0 07/14/09 1 10200 8495 26 KBG2 DMY BK 0 07/14/09 9-5/8"WHPSTOCK —I 3980' NILLOUT WMNDOW(13-03A) 3980'-3997' 9-5/8"CSG,47#,N-80 BTC,D=8.681" --I 11319' 10236' H4-1/2"FES X NP,D=3.813" 111 10267' H r X 4-1/2"BKR S-3 PKR,D=3.870' PERFORATION SUMMARY 44 REF LOG: ii II ANGLE AT TOP FBF:43"@ 10650' 10301' —I4-u2"HES XNIP,I)=3.813' Note:Refer to Production DB for historical perf data SCE SPF INTERVAL Opn/Sqz SHOT SQZIli 10332' -I4-1/2"FES XN NP,D=3.725" 2-7/8" 6 10650-10665 0 07/11/09 2-7/8" 6 10759- 10773 0 07/11/09 10337' —7"X 5"I-RD ZXP LIP w/TIEBACK 2-7/8" 6 10940-10995 0 07/11/09 SLV&BKR FLEXLOCK HGR 2-7/8" 6 11600-11620 0 07/11/09 D=4.193" 2-718' 6 11855-11890 O 07/11/09 2-7/8" 6 11945-12100 O 07/11/09 10344' -14-112"WLEG,D=3.958" 2-7/8" 6 12235-12280 0 07/11/09 2-718" 6 12345-12370 0 07/11/09 4-1/2"TBG,12.6#, H 10344' I` 2-7/8" 6 12605-12630 0 07/11/09 13CR-80 VAM TOP, / 10362' H5"X 4-1/2"XO,D=3.890" 2-7/8" 6 12680-13120 0 07/11/09 .0152 bpf,D=3.958" 2-7/8" 6 13440-13495 0 07/11/09 7"CSG,26#, H 10360' 2-7/8" 6 13870-13930 0 07/11/09 2-7/8" 6 13970-14105 0 07/11/09 L-80 TCI XO 2-7/8" 6 14395- 14460 0 07/11/09 TO L-80 BTC-M ` 2-7/8" 6 14830-14880 0 07/11/09 r CSG,26#,L-80 BTC-M, 10504' ` 2-7/8" 6 15600-15645 0 07/11/09 D=6.276" 2-7/8" 6 15750-16025 0 07/11/09 111,2-7/8" 6 16085-16220 0 07/11/09 111 PBTD — 16237' 1���►�►�' 4-1/2"LNR,12.6#,13CR-80 VAM TOP,.0152 bpf,D=3.958" —I 16318' DATE REV BY CONVENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/18/79 PKR 141 ORIGINAL COMPLETION 01/06/16 GJB/JM)SET FLOW THRU GAUGES(1/4/16) WELL: 13-03A 01/10/82 NIP'S RWO 02/03/16 PV GS/n-H RLL FLOW Tt RU GAUGES(1/11/16) PERM(No:"2090480 07/15/09 N9ES SIDETRACK(13-03A) 02/03/16 GRCITLH PB VLV UPDATE PER STATE RE-GS AR No: 50-029-20325-01-00 11/07/11 VVECJPJC GLV GO(10/27/11) 02/23/16 /TLH SSSV K VLV C/O(02/11/16) SEC 14,T10N,R14E,2054'FSL&7'FEL 11/12/11 MBM PJC GLV C/O(11/08/11) 04/26/16 GC/JN0 PULLED K VLV(04/21/16) 10/09/13 GJB/JND GLV C/C(09/29/13) BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday,June 16, 2016 5:13 AM To: AK, OPS FS3 OSM;AK, OPS FS3 Field OTL;AK, OPS FS3 Facility OIL;AK, OPS FS3 DS Ops Lead;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC EOC IL;AK, OPS PCC Ops Lead; G GPB FS3 Drillsites;Odom, Kristine; Catron, Garry R (Wipro); Regg,James B (DOA) Cc: AK, D&C Projects Well Integrity Engineer;AK, D&C DHD Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep;AK, OPS Gas Lift Engr; McVey,Adrienne; 'chris.wallace@alaska.gov'; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel, Troy; Worthington,Aras J Subject: OPERABLE: Producer 13-03A(PTD#2090480)AOGCC-Witnessed K-Valve Testing All, Producer 13-03A(PTD#2090480) passed an AOGCC-witnessed K-valve closure test on June 14, 2016.The well is reclassified as Operable. Work Completed: 1. Slickline: Drift, Set K-Valve—DONE 06/12/16 2. Well Integrity Supt: Reclassify as Under Evaluation—DONE 06/13/16 3. Operations: POP well—DONE 06/13/16 4. Well Operations Compliance Rep: Coordinate SSSV closure test within 5 days of POP—PASSED 06/14/16 5. Well Integrity Supt: Reclassify as Operable pending passing closure test—DONE 06/16/16 Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 2O�7 0:(907)659-5102 `AN�EO JAN C:(907)943-0296 H:2376 Email: AKDCWelllntegrityCoordinator@BP.com From: AK, D&C Integrity Coordinator Sent: Monday, June 1 , 016 11:17 AM To: AK, OPS FS3 OSM; AK, •' FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintende • AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RE •B East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Odom, Kristine; Catron, Garry ' A ipro); 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov) Cc: AK, D&C Projects Well Integrity Engineer; AK, D&C D' a Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, OPS Gas Lift Engr; AK, D&C Well Integrity Coordinator; Mc - Adrienne; 'chris.wallace@alaska.gov'; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obri• itch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel,Troy; Worthington, Aras J Subject: UNDER EVALUATION: Producer 13-03A (PTD #2090480)AOGCC- 'essed K-Valve Testing 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg � � 6'(/4°( l DATE: 6/7/16 P. I. Supervisor FROM: Jeff Jones SUBJECT: No Flow Test Petroleum Inspector PBU 13-03A BPXA PTD 2090480 June 7, 2016: I traveled to BPXA's PBU well 13-03A to witness a No Flow test. The well had previously been bled down to zero tubing pressure through a 2" hard line terminating in a large flow back tank. The tubing was blocked in and the pressure was allowed to build for 3 hours. When opened, the tubing pressure dropped to 38 PSI and began increasing, flowing gas and fluid at 80 PSI at the end of 5 minutes. Gas flow is not measured with this (pressure build and bleed off in 5 minutes) method. Approximately 2 BBLS of fluid and a significant amount of gas was produced in the 5 - minute pressure monitoring period. Well 13-03A failed the No Flow test today. - The following table shows test details: Time Pressures Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 12:40 0 / 51 / 293 Start pressure build up , 13:10 16 / 51 / 293 - 13:40 33 / 51 / 293 - 14:10 45 / 51 / 293 - 14:40 57 / 51 / 293 15:10 70 / 51 / 293 15:40 - 80 / 51 / 293 Stop pressure build up 38/51/293- Open tubing 15:45 80/51/293 " End flow period - 1 Pressures are T/IA/OA Summary: I witnessed the unsuccessful attempt to achieve a passing No-Flow test on BPXA's PBU 13-03A - Attachments: Pressure record for No-Flow Test t 4 e iZ 012,114 , K_t L SCANNED Dir 1 #2016; 2016-0607_No-Flow_PBU_13-03 A_fail_i j.docx Page 1 of 1 t` • tu J, ack S Data Collection Report Chassis Left Scale Right Scale Serial Number 072845 073257 073251 Datatype Lower Upper Units PSI G PSI G •.,air Upper _ TP 13-03 NFT(TP) 06-07-16 120 100 80 60 40 20 r---- 0 . , , . , , . -20 0 6 P ry P ��p y�� ry6ry by ryFc$ hrye� ry^, 4, 41; . ^ CP o.° d°1 d'1 CP^ dal a. Actual Time MM-DD-YY hh:mm:ss I -m -cea 1 i • • • Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> f 3! Sent: Monday,June 13, 2016 11:17 AM f To: AK, OPS FS3 OSM;AK, OPS FS3 Field OIL;AK, OPS FS3 Facility OIL;AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC EOC IL;AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Odom, Kristine; Catron, Garry R (Wipro); Regg,James B (DOA) Cc: AK, D&C Projects Well Integrity Engineer;AK, D&C DHD Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep;AK, OPS Gas Lift Engr;AK, D&C Well Integrity Coordinator; McVey, Adrienne; 'chris.wallace@alaska.gov'; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel, Troy;Worthington, Aras J Subject: UNDER EVALUATION: Producer 13-03A (PTD #2090480) AOGCC-Witnessed K-Valve Testing Attachments: 13-03A 316-249.pdf All, Producer 13-03A (PTD#2090480) failed an AOGCC-witnessed no flow test on June 7, 2016 and was reclassified as Not Operable. On June 12, Slickline re-set a K-valve.The K-valve design was previously approved by the AOGCC(see attached Sundry 316-249). The well is reclassified as Under Evaluation for a period of 5 days, in order to facilitate an AOGCC- witnessed closure test. Work Completed/Plan Forward: 1. Slickline: Drift, Set K-Valve—DONE 06/12/16 2. Well Integrity Supt: Reclassify as Under Evaluation—DONE 06/13/16 3. Operations: POP well 4. Well Operations Compliance Rep: Coordinate SSSV closure test within 5 days of POP 5. Well Integrity Supt: Reclassify as Operable pending passing closure test Please reply if in conflict with proposed plan. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate: Jack Lau) 0:(907)659-5102 C:(907)943-0296 H: 2376 Email: AKDCWellIntegritvCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Tuesday, June 07, 2016 4:23 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites Cc: AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; 1 • S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Tuesday, June 07, 2016 4:23 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL;AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites Cc: AK, D&C Projects Well Integrity Engineer;AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric;AK, OPS Gas Lift Engr; 'chris.wallace@alaska.gov';AK, OPS Gas Lift Engr; Morrison, Spencer; Munk, Corey; Odom, Kristine Subject: NOT OPERABLE: Producer 13-03A (PTD #2090480) No Flow Testing All, Producer 13-03A(PTD#2090480)failed AOGCC witnessed no flow testing June 7, 2016.The well is now reclassified as Not Operable and will remain shut in. Plan Forward: 1. S: D&T Set K Valve Please call with any questions or concerns. Ryan Holt (Alternate. Lee Li ey) BP Alaska—Well IntegrityGW AEa 2��1 Global Wells ` JUL 1 Organization S Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com : AK, D&C Well Integrity Coordinator Sent: "" uesday, June 01, 2016 10:50 AM To: AK, OPS FS : u AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superin --.-nt; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, ' - PB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin Cc: AK, D&C Projects Well Integrity Engineer; AK, : C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; AK, .1'S Gas Lift Engr; 'chris.wallace@alaska.gov'; AK, OPS Gas Lift Engr; Morrison, Spencer; Munk, Corey; Odom, Kristine Subject: UNDER EVAULATION: Producer 13-03A (PTD #2090486 o Flow Testing All, Producer 13-03A(PTD#2090480)failed a non-witnessed closure test of K valve on Ma • 20, 2016.The well has been reclassified as Under Evaluation and placed on a 28 day clock to facilitate no flow testing.Th- ell may produce for no more than 5 days prior to a AOGCC witnessed no flow test. 1 • • tiOr Tit g \����y/�'c�� THE STATE Alaska Oil and Gas • Of Conservation Commission LAsKA 333 West Seventh Avenue ,..: C GOVERNOR BILL WALKER _ Anchorage, Alaska 99501-3572 . -...` Main: 907.279.1433 OF ALAgl‘P Fax: 907.276.7542 www.aogcc.alaska.gov Mark Drotar Production Engineer CANNEi& r ; BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-03A Permit to Drill Number: 209-048 Sundry Number: 316-249 Dear Mr. Drotar: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 4y of May, 2016. RBDMS ' AY 0 5 2016 �g CC VE -1ECEID STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMON APR 2 7 2016 • APPLICATION FOR SUNDRY APPROVALS 07$ ,S'!CW/ (, 20 AAC 25.280 INOCr 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 perations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other K-Valve Design p • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 209-048 - Exploratory ❑ Development p 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-20325-01-00 ' 99519-6612 Stratigraphic 0 Service 0 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No RI PBU 13-03A 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028330 PRUDHOE BAY,PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 16320 • 8824 - 16237 8829 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 29-109 29-109 1530 520 Surface 2678 13-3/8"72#N-80 28-2706 28-2706 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 5981 4-1/2"12.6#L-80 10338-16319 8620-8824 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 25-10345 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No K Valve Installed No K Valve Installed 12.Attachments: Proposal Summary p Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development p Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil p WINJ 0 WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Drotar,Mark be deviated from without prior written approval. Email Mark.Drotar@bp.com Printed Name Drotar,Mark Title Production Engineer Signature '11714-- r— Phone +19075645367 Date L�/�1 d0// COMMISSION USE ONLY r O�W (fJ Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3ll.e.— 2.L1 c( Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No ❑ Subsequent Form Required: /b — 4 a 4- A APPROVED BYTHE Approved by: , / /� COMMISSIONER COMMISSION Date: �.– cp_I(, ORIGINAL RBDMS MAY 0 5 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate L.%l/ • • a, Qo000000 a, N ps v- OO C4 O � CO d' CD Ps to ") C N LO U F. N V lg M 00 CD 10 OsCD CD M COQ) U) CANY- O - NI.m r- OO CO 00 OO O CO N CA Is YtCO OPs- Y- NN O C) CA 00 CO N OO N M OO OO a CA CA O CA 00 CO r v- N U, N N N N N OD N 00 Q r- c)0 01 0 M co v) N M CD CO v a aa01O NQ C000 (0 NNN N CO MNC Or m 1.0 0 \ a 0 CA 0 OO Cf YZ000Oa9 —II M O Z = asNJ Cr) O N N 44 4# N- CV- hs CO CA a0 N d' _ CV V N• C? 6043 Q ZNA .c" O C 000 co� o 0 coO � ch J N O Y in O W W W QQ Q O WW .= UUWW u_ cececLVa ce (.9 Z a W W W W m OSI— H" I— Z � • • a) w to 00 MTCD L COt01 (00000ttoos- tO NCOr- tco to000TrO (o) Tf to CD N N d' 0 _O up r- r- M Cp 0) O C7 O op O 00) 00) c000) 00) 00) CDOM) 0) 03CO WCDNO) 0CD 0) co000 0003 CI CO CO CO CO 00 CO CO CO CO 00 CO CO CO co CO 00 CO a 0 ▪ U) T' CO r- 00 00 00 — CO Tr NN- 0) 0) tO « CO 00 00 000) 0 mr 0 � Cy � c- OI- COto - Oi0o0vuitri0i0orivi6CDvOic'') Oo LI) t.: o 0 0C to 0 0) CO I- Tr M T- N 0) co opTtc0 cu CD 0) CO CO Tr W CO CO 0) CO CO 00 CO CO CO CO c° O 00 CO 00 00 03 CO 00 0 2 Lua a a w LU W 0 I- 5 5 U 0 > O co L Lo 01 L O O O O O O O 0 LO O to O O t A u) O - - J 0 0 W - �„r gCL CO 0- 0) N CD O CO I- M _N 0) to 00 0 CO U) Tr N N J J J ¢ ¢ (n W 0_ 0 O O N CO 00 N N 01 N 00 CCV) COTr c0�) Tr Cr Tr Lo C00 CO 0 0 0 -J W W O Z O o o a W o k o Z 2 0 w w w d d Z O Z 0M M0 coccr)cg vaiaiu¢i Qi a M 12 _ . 0 0) 0 0 to tO to tO tO 0 0 0 0 0 tO 0 0 0 tO = dN010 0) 01 M0O CONC0CCO0) NCOCOvtt0OCDMOOCO00 CI) C] 000 - - - NCV NN010101 �) -Y � totoCD Y.1 Ia) (l) � = 0 0 co a a 2 0 0 cnn c0 0 c 0 �. a) V 0 2 w occew accrw cc w rtw w w w w ce or w 16 W W W W W W W W W W W W W W W LLI W W W Qaaaaaaaaaaaaaaaaaaa 0 t a a> F m 0) 0) CA O) 0) 0) 0) 0) 0) 0) 0) 0) CA O) CA O) 0) 0) 0) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a 0 c0000000000000000000 W Z o N N N N N N N N N N N N N N N N N N N Z a Q W 0 a w W U O N LL 0 Lu Lu cv N- 0N- N- N- 0- N- N- N- N- N- 0- 0- N- N- I,- 0N- N- < O J I- J J J CY 0. 0] O D W J J Q O W W < < 0_ co LL LL LL co 0_ CL' a) E c¢occooaMMMMCaMMCaM ¢ MMCCV) MMCCV) Ci)3' 0000000000000000000 LL a Cn 0 LL N tr LL CY) C+') M I M co co co co Cr) co co M C") Cr) M M C�') m 0_ 0_ 0_ 0 J O 0 W Q. < < CO CO U LL co co 0_ Ir . • Packers and SSV's Attachment PBU 13-03A SW Name Type MD TVD Depscription 13-03A TBG PACKER 10268.32 8556.97 4-1/2" Baker S-3 Perm Packer 13-03A PACKER 10349.51 8630.26 5" Baker ZXP Top Packer • 01 6/6101 WO Wireline Work Request 13-013 global wells organization Distribution Wireline(4) Well: 13-03 AFE: APBWELIRSL Reading File Date: 4/23/2016 Engineer: John Paul Kenda IOR: 50 FTS: Yes AWGRS Job Scope: SSSV H2S Level: Problem Description Increase K Valve set pressure to allow for passing State test and K-valve closure. • Initial Problem Review Previous design had set pressure at 403 psi @ 60 degrees. K-Valve failed to close for State test. Raise set pressure by 54 psi to allow for K-Valve to close at lower wellhead pressure. This design pressure was reached empirically. Gauge data used for original design did not match Well once K-Valve was installed. Remedial Plan -WIRELINE ACTION �w NOTE: For State Test shut in wells to common line and reduce pressure below 350 psi to shut valve DSO: Flow well at Wellhead pressure greater than 350 psi.Valve set to close at 350 psi Pwh. FOR HES SHOP INFO ONLY: Set K-Valve to Close at 457 psi 600 degrees sees Date Work Completed _ Well Status/Results Date _ by Problem Resolved ? Y N : Well Review(Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate (STBL/D) Expected NOB: Avg. WC (%) Actual NOB: Lift Gas (MMSCF/D) MGOR used for NOB: TGLR (SCF/STBL/D) FTP (psi)/Steady? MAINTENANCE ONLY CLP (psi)/Steady? (e.g. Fix AC, Shallower for Slugging) Casing Press. (psi)/Steady? RATE (Non-Post-WW) Orifice Depth: (e.g.deepen, optimize orifice) IA Fluid Level:-_ Post-Wellwork Date of FL Survey: / / Follow-up Recommendations: • • "K"Valve Calculation Sheet DS13-03 Date: 04/25/16 Test Date 01/06/16 Gross Fluid Rate 5250 BLPD Flowing Well Head Pressure 500 psi Flowing Well Head Temperature 169 deg F GOR 800 scf/bbl TGLR 762 scf/bbl Flowing Pressure Calculations Based on Hagedorn-Brown Multiphase Flow Correlation "K"Valve Setting Depth TVD 2119 ft Flowing Tubing Pressure With Gas Lift NA psi Flowing Tubing Pressure Without Gas Lift NA psi Valve set to close at 350 psi Pwh Flowing Tubing Pressure @ psi Pwh 750 psi "K"Valve Test Rack Set Pressure at 60 deg F 457 psi Valve Size&Volume Ratio 4.5" 1.314 NOTE: Well needs to flow at> 350 psi Pwh Valve set to close at 350 psi Pwh t FEE= CM/ NOTES: WELL ANGLE>70° 10813'"""WELL LFEAD_ 13-03A W REQ CARES A SSSV "'"4-1/2" TBG&L ' A ( AR " CTLAPcTOR= BAKE76C' I ORIG WBS NOT SHOWN BELOW WFC'STOCK"' C3SaG KB.ELEV t - ORIG BF ELEV ? /J K OP 3980 2119' 4-1/2'HES X NP,D=3.613' Max Angle= 1°@ 14930' 20'CXMDUCTC 94#' — 109' H_40,13=19,124" Datum MD= 10623' ._.... 2345' --19-518'FOC Datum TVD= 8800 SS / 11 2469' —9-5!8"FOC 9-5/8"CSG STUB(06/18/09) IH 2218' GAS LFT MANDRELS 13-3/8'CSG,72#,N-80,D=12.347" —1 2706' ST PAD TVD DEV TY FE VLV LATCH PORT DATE 5 3687 3659 25 KBG2 DOLE BK 16 09/29/13 4 6646 5824 46 KBG2 SO BK 26 09/29/13 Minimum ID = 3.725" @ 10332' 3 8643 7232 46 KBG2 DMY BK o 07/14/09 4-112" HES XN NIPPLE z $3 8139 26 KBG2 DMY BK o 07/14/09 1 10200 8495 26 KBG2I DMY BK 0 07/14/09 9-5/B'W-PSTOC K —f 3980' -------\ MLLOUT WINDOW(13-03A) 3980'-3997' 9-5/8'CSG,474,N-80 BTC,ID=8.681' — 11319' 10236' {4-1/2'HES X NP,D=3.813' 10267' —7'X 4-1/2'BKR S-3 Rff{D=3.870' l Ili PERFORATION SUMMARY 4. REF LOG: ►i illi 10301'ANGLE AT TOP PE RE:43° 10650' 4-1/2"I E X NIP,13=3,813' 1 kite:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ . 10337 —4-1/2'HES XN NP,D=3.725' 2-7/8 6 •10650-10665 0 07/11/09 2-7/8" 6 10759- 10773 0 07/11/09 10337' --7'X 5'I-RD ZXP LTP w/117BACK 2-7/8' 6 10940- 10995 0 07/11/09 SLV&BKR FLEXLOCK HGR 2-7/8" 6 11600- 11620 0 07/11/09 /11 D=4,193' 2-7/8" 6 11855- 11890 O 07/11/09 2-7/8" 6 11945- 12100 O 07!11/09 10344' —4-1/2'VILEG,D=3.958' J wik 2-7/8" 6 12235- 12280 0 07/11/09 2-7/8' 6 12345-12370 0 07/11/094 1/2"TBG, 12.6#, H10344' 1 ,1 2-7I8" 6 12605- 12630 0 07/11/09 13CR-80 VAM TOP, / 10367 j—5'X 4-1/2"XO,D=3.890' 2-7/8' 6 12680- 13120 0 07/11/09 .0152 bpf,D=3.958' 2-7/8' 6 13440- 13495 0 07/11/09 7"CSG,26#, — 10360;--- 2-7/8" 6 13870- 13930 0 07/11/09 2-7/8' 6 13970- 14105 0 07/11/09 L-80 TCI XO 2-7/8' 6 14395- 14460 0 07/11/09 TO L-80 BTC-M ` 2-7/8" 6 14830- 14880 0 07/11/09 7'CSG,264,L-80 BTC-M, 10504' ` 2-7/8" 6 15600- 15645 0 07/11/09 D=6.276' 2-7/8' 6 15750- 16025 0 07/11/09 ` 2-7/8' 6 16085- 16220 0 07/11/09 III • 110 4/4 FBTD H 16237' ;tN '' 4-1/2"LNR,12.6#, 13CR-80 VAM TOP,.0152 bpf,D=3.958" —i 16318' DATE REV BY CX*4 ENTS DATE REV BY CX)? FLATS PRUE:II-OE BAY UNIT 03/18/79 PKR 141 ORIGINAL COMPLETION 01/06/16 GJB/JMD SET FLOW THRID GAUGES(1/4/16) WELL: 13-03A 01/10/82 N1E5 IZY4O 02/03/16 1.1GS/TLH RLL FLOW THRU GAUGES(1/11/16) RERMr No: 80 07115/09 119E5 'SIDETRACK(13-03A) 02/03/16 GRC/TLH.PB VLV UPDATE PER STATE REGS AR No: 50-029-20325-01-00 11/07/11 WEC/PJC GLV CIO(10/27111) 02/23/16 /TLH SSSV K VLV C/O(02/11116) SEC 14,T1ON,R14E,2054'FSL&T FEL 11/12/11'M3M'PJC'GLV CJO(11/08/11) 04/26/16 GCIJMD PULLED K VLV(04/21/16) 10/09/13kGJB/PubT7 GLV CIO(09/29/13) J J BP Exploration(Alaska) 2,020460 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, March 22, 2016 4:09 PM To: Regg, James B (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: NOT OPERABLE: Producer 13-03A (PTD #2090480) Due for AOGCC SVS testing Jim, This is just a follow up on the message that I left early today. The plan for producer 13-03A(PTD#2090480) is to pull and inspect the K valve. If we find that the K valve is damage we will replace like for like. If we find no damage and have -- to change the dome pressure we will submit the proper paper work accordingly. Thank you, Kevin Parks BP Alaska -Well Integrity Coordinator lobi Weil OrganIzation SCANNED SEP 2 12016 Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Monday, March 21, 2016 1:49 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; 'Regg, James B (DOA)' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; AK, OPS Gas Lift Engr; 'chris.wallace@alaska.gov'; AK, OPS Gas Lift Engr; Morrison, Spencer; Munk, Corey; Odom, Kristine Subject: NOT OPERABLE: Producer 13-03A (PTD #2090480) Due for AOGCC SVS testing All, Producer 13-03A(PTD#2090480) was put on production to facilitate sub surface safety valve system (SSSVS testing).The well failed a non-witnessed closure test on March 20, 2016.This well has been reclassified as Not Operable and shall remain shut in until the downhole K valve can be optimized and updated AOGCC SVS testing obtained. Plan Forward: 1. Gas Lift Engineer: Design/replace like for like K valve 2. Well Integrity Coordinator: Obtain state approval for K valve replacement 3. Slickline: Reset new K valve 4. Operations: Place well on production, obtain updated SVS testing 5. Well Integrity Engineer: Additional diagnostics as needed Please call with any questions or concerns. • • Thank you, Kevin Parks BP Alaska-Well Integrity Coordinator Globa Wells Organtzatior Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, March 09, 2016 9:46 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; 'Regg, James B (DOA)' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney; 'chris.wallace@alaska.gov'; AK, OPS Gas Lift Engr; Morrison, Spencer; Munk, Corey; Odom, Kristine Subject: UNDER EVALUATION: Producer 13-03A (PTD #2090480) Place on Profuctio for for AOGCC SVS Compliance Testing All, Producer 13-03A(PTD#2090480) is now ready to be placed on production for updated safety valve system (SVS) testing. At this time, the well has been reclassified as Under Evaluation to facilitate compliance testing. This well requires a subsurface safety valve (SSSV) in order to flow and shall not remain online for more than five days prior to obtaining updated SVS testing. Please contact the integrity team if the well fails to stabilize in time for the state witnessed test or if the test fails. Plan Forward: 1. Operations: Place well on production 2. Operations: Perform AOGCC witnessed SVS testing 3. Gas Lift Engineer: Additional diagnostics as needed A copy of the approved sundry for the K valve SSSV design has been included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus (411et'trate: Kevin Pal ks) BP Alaska-Well Integrity Coordinator y WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com 2 • From: AK, D&C Well Integrity Coordinator Sent: Saturday, January 23, 2016 3:09 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; 'Regg, James B (DOA) (iim.regg@alaska.gov)' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney; 'chris.wallace@alaska.gov'; AK, OPS Gas Lift Engr Subject: NOT OPERABLE: Producer 13-03A (PTD #2090480) Due for AOGCC SVS testing All, Producer 13-03A (PTD#2090480) had a downhole subsurface valve (K valve) reset on January 11, 2016 following a failed non-witnessed No Flow test (NFT) on January 03, 2016. The well was placed on production January 12, 2015 but has failed to stabilize in sufficient time for upcoming AOGCC safety valve system (SVS) testing. This well has been reclassified as Not Operable and shall remain shut in until the downhole K valve can be optimized and updated AOGCC SVS testing obtained. AOGCC approval of the optimized K valve design shall be required prior to bringing the well back online. Plan Forward: 1. Gas Lift Engineer: Optimize K valve design—DONE 01/23/16 2. Well Integrity Coordinator: Obtain state approval for K valve design 3. Slickline: Reset new K valve 4. Operations: Place well on production, obtain updated SVS testing 5. Well Integrity Engineer: Additional diagnostics as needed Please call with any questions or concerns. Thank you, Whitney Pettus ( 1tcinc�P�:: Ace°in Parksf BP Alaska-Well Integrity Coordinator 3 e s, WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 3 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Wednesday, March 09, 2016 9:46 PM To: AK, OPS FS3 OSM;AK, OPS FS3 Field OTL;AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC EOC IL;AK, OPS PCC Ops Lead; G GPB FS3 Drillsites;Chou,Irwin; Regg,James B (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer;AK, D&C DHD Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Pettus,Whitney; 'chris.wallace@alaska.gov';AK, OPS Gas Lift Engr; Morrison, Spencer; Munk, Corey;Odom, Kristine Subject: UNDER EVALUATION: Producer 13-03A(PTD#2090480) Place on Profuctio for for AOGCC SVS Compliance Testing Attachments: Producer 13-03A(PTD#2090480)Approved K valve sundry approval 02_23_16.pdf All, Producer 13-03A(PTD#2090480) is now ready to be placed on production for updated safety valve system (SVS) testing. At this time,the well has been reclassified as Under Evaluation to facilitate compliance-te3ting This well requires a subsurface safety valve(SSSV) in order to flow and shall not remain online for more than five days prior to obtaining updated SVS testing. Please contact the integrity team if the well fails to stabilize in time for the state witnessed test or if the test fails. Plan Forward: ; ;'' 1. Operations: Place well on production 2. Operations: Perform AOGCC witnessed SVS testing 3. Gas Lift Engineer:Additional diagnostics as needed A copy of the approved sundry for the K valve SSSV design has been included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) h BBPPAlaska-Well Integrity Coordinator tO t,IGW9 U' l".-1a l'o'b WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C We -•rity Coordinator Sent: Saturday, January 23, • • •09 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Fie • ! • AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C ir- '•- 0.-rations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Op - • AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB 1 STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well.12(V T-1-- Re-enter Susp Well 0 Other:K-Valve IYI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 209-048 3. Address: P.O.Box 196612 Anchorage, Development I1 Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20325-01-00 7. Property Designation(Lease Number): ADL 0028330 8. Well Name and Number: PBU 13-03A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 16320 feet Plugs measured feet true vertical 8824 feet Junk measured feet FEB 2 5 2016 Effective Depth: measured 16237 feet Packer measured 10268 feet true vertical 8829 feet Packer true vertical 8556.97 feet AO 9p'°' CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 29-109 29-109 1530 520 Surface 2678 13-3/8"72#N-80 28-2706 28-2706 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 5981 4-1/2"12.6#L-80 10338-16319 8620-8824 8430 7500 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 25-10345 25-8626 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"K Valve 2119 2119 12.Stimulation or cement squeeze summary: Intervals treated(measured): y6 �/]�y yp�mL Treatment descriptions including volumes used and final pressure: , .1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 192 95 5516 1788 498 Subsequent to operation: 72 0 3969 1790 659 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil II Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: 316-087 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature .)-fa,41/ •-*--- Phone +1 907 564 4424 Date 2/25/16 Form 10-404 Revised 5/2015 3111/I� y/4 RBDMS 1-1, FEB Original Only FEB 2 6 2016 • • m RN 000000000 CO '1 O N L[) LO N- N- V C) M 0 I,- M M CD 7 0) N '— 00 V - m Vr r- CO 00 CO CO O00N0) f� vt (0 O O I- r- N N N- N- M 0) W 00 N 00 N M CO 00 I i I I I i I- 0) 0) Co 0) CO 00 N 0 N N NN N CO N it LU 0) 14) r— CD (MO O N N 01 C.) 03 Ii Q C CD000flT- Nch � N N N N N 0 N M_ W O CD O 0 0 ODZ CO O Z CO cU O = d = N J (n N N N-- - CO N- Nrr N 0D N _ - _ CV _ CO 0 O 4 %— cm 4 coOCV CCOCO V. 000ch J N O a- I[) O W W W Q Q Q c O W W W W U OCD . 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N Ns Ns Ns N- N- N- N- N- N- N- N- N- Is- Ns N- Is- Ns Ns <• tL C9 0 0 _1 0 F- J J LU WI 0 D a O m 0 E 0 ccW J J 0 Q Cf w w ma mcn li u_ N a cc m E 2 « « « « « « « « « < co co co co co co co co co co co co co co co co co co co 0000000000000000000 U- 0 U O lL N d' U- 01 L 0101M0100M 000h000'70`7010`7000h00MMM CO CL a a U J C7 C7 w a- < Q m co LL U cn a. 0_ • 0 Packers and SSV's Attachment PBU 13-03A SW Name Type MD TVD Depscription 13-03A SSSV 2119 2118.94 4-1/2" K Valve 13-03A TBG PACKER 10268.32 8556.97 4-1/2" Baker S-3 Perm Packer 13-03A PACKER 10349.51 8630.26 5" Baker ZXP Top Packer II 40 aUi , co d N 2Ua) m0 o) N `O a_0 V) i.,— „,a)• N c N II 03 cjN . LL N z N O N 2 2 ) ijm PLLM , - - coo rn o Z 'as , Zh c. 88 a a) Qcoc�aOm N7 OH ) •Li O � j a) 2 Q J * *20 � *t] D 3 0 c o . 46 ,O _ -s � ��co1 U) , co — Q 0.6Wa�7 N -0 (0 vim. 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KOP_ _ _____ 1 2119' H4-12'FES X1413,D=3.813' Mix Angle= 1" 14930' 20'COM1CT°R,94#, 109' 2119' H4-12'K VALVE(FES)C/0 02111/16 ■edurn MD= 10623' I+40,D=19.124' f H9-5l8'FOC Did=ND= 8800'SS 2489' H9-518°FOC 11 9-5/8'CSG STUB(06/18/09) }--I 2218' GAS LFT MANDRELS 13-3/8'CSG,720,N-80,D=12.347- H 2706' ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3687 3659 25 KBG2 DOBK 16 09/29/13 Minimum ID = 3.725" 10332' ME 4 6646 5824 46 KBG2 SO BK 26 09/29/13 3 8643 7232 46 KBG2 DMY BK 0 07/14/09 4-1/2" HES XN NIPPLE 2 9803 8139 26 KBG2 DMY BK 0 07/14/09 1 10200 8495 26 KBG2 DMY BK 0 07/14/09 9-5/8"WFPSTOCK 3980' MLLOUT U W4)OW(13-03A) 3980'-3997' 9-518'CSG,47#,N-80 BTC,D=8.681' H 11319' 10238' H4-12'HESS X NP,D=3.813' Illi 10267' Hr x 4-12'BKR S-3 PKR,D=3270' FEiFORATION SUMMARY -.A REF LOG: 44 , FES X NIP,D=3.813' 10301' I ANGLE AT TOP PERF:43" •? 10650' 4 12' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SO7 Ili 10332' 1-14-1/2'I-ES XN NP,D=3.725' 2-7/8' 6 10650-10665 0 07/11/09 2-7/8' 6 10759-10773 0 07/11/09 10337' 7"X 5"HRD ZXP LTP w/T83ACK 2-7/8' 6 10940-10995 0 07/11/09 SLV&BKR FLEXLOCK HGR 2-7/8' 6 11600-11620 0 07/11/09 D=4.193' 2-7/8' 6 11855-11890 0 07/11/09 2-7/8" 6 11945-12100 0 07/11/09 10344' 1--4-12"AUG,D=3.958' 2-7/8" 6 12235-12280 0 07/11/09 2-7/8' 6 12345-12370 0 07/11/09 4-12"TBG,12.6#, -j 10344' ,' 2-78" 6 12605-12630 0 07/11/09 13CR-80 VAM TOP, / 10367 1-15'X 4-1/7 XO,13=3.690' 2-7/8" 6 12680-13120 0 07/11/09 .0152 bpf,D=3.958' 2-78" 6 13440-13495 0 07/11/09 r CSG,26#, H 10380' 2-78" 6 13870-13930 0 07/11/09 2-78' 6 13970-14105 0 07/11/09 L-80 TCI XO 2-78" 6 14395-14460 0 07/11/09 ,TO L-80 BTC-M ` 2-7/8" 6 14830-14880 0 07/11/09 T CSG,26#,L-80 BTC-M, 10504' ` 2-78" 6 15600-15645 0 07/11/09 D=6.276' 2-78' 6 15750-16025 0 07/11/09 1112-7/8" 6 16085-16220 0 07/11/09 Ili MID H 16237' �1'i►�►�' 4-1/2'LW,12.6#,13CR-80 VAN TOP,.0152 bpi,I)=3.958' —I 16318' DATE REV BY COM ENTS DATE REV BY COM ENTS PRUDHOE BAY UGIT 03/18/79 PKR 141 ORIGINAL COMPLETION 01/06/16 G1B/JM)SET FLOW TFRL GAUGES(1/4/16) VVEL.L: 13-03A 01/10/82 RIES MAIO 02/03/16 MGS/TLH RLL FLOW T1-I J GAUGES(1/11/16) 143,84T Kb: 090480 07115/09 NOES SIDETRACK(13-03A) 02/03/16 GRCITLH FB VLV UPDATE PER STATE REQS AR No: 50-029-20325-01-00 11/07/11 WECdPJC GLV C/O(10/27/11) 02/23/16 ITCH SSSV K VLV CO(02/11/16) SEC 14,T10N,R14E 2054'FSL&7'FEL 11/12/11:M3M PJSGLV C/O(11108/11) 10/09/13 G EIMMD GLV C/0(09/29/13) _ BP Exploration(Alaska) SOF Ty • • • 4,„.1,yy-. THE STATE Alaska Oil and Gas �,�,-s-aa��, of/� T /� �` Conservation Commission KA 1t� -__:_____E___:__:::: 4 =z - 333 West Seventh Avenue "'le7sr GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 * Main: 907.279.1433 OF ALASlCr.' Fax: 907.276.7542 www.aogcc.alaska.gov Ryan Daniel Alaska Wells Integrity and Compliance Team Leader BP Exploration (Alaska), Inc. 1►SSEQ MAP 6i 9 90tt P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-03A Permit to Drill Number: 209-048 Sundry Number: 316-087 Dear Mr. Daniel: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, .-14 Cathy P. Foerster Chair DATED this 23 day of February, 2016. RBDMS I,t' FEB Z 5 2016 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM SION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 I1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tabing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other K-Valve Design Q • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: • 5. Permit to Drill Number: 209-048 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development Q 99519-6612 Stratigraphic 0 Service ❑ 6. API Number 50-029-20325-01-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No Q PBU 13-03A - •:, 9. Property Designation(Lease Number): 10. Field/Pools: r !n1 rt ADL 0028330 • PRUDHOE BAY,PRUDHOE OIL " FC.B l/ 201b 11. PRESENT WELL CONDITION SUMMARY 7-.S L!Z 3 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 16320 • 8824 - 16237 " 8829 • Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 29-109 29-109 1530 520 Surface 2678 13-3/8"72#N-80 28-2706 28-2706 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 5981 4-1/2"12.6#L-80 10338-16319 8620-8824 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 25-10345 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 4-1/2"PB Valve 2119, 2118.93 12.Attachments: Proposal Summary Q Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory 0 Stratigraphic 0 Development Q - Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil Q ' WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true an the .ro -dure approved herein will not Contact Daniel,Ryan be deviated from without prior written approv Email Ryan.Daniel@bp.com Printed Name Daniel,Ryan Title Alaska Wells Integrity&ComplianceTea Leader Signature v B i Phone +1 907 564 5430 Date (/k'''‘ ?OA COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No C$' Subsequent Form Required: gi4.7 ,D APPROVED BYTHE Approved by: / COMMISSIONER COMMISSION Date: a-23_f, ORIGINAL RBDMS1. [-- FEB 252016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. 19���Attachments in Duplicate • • w COet N O O coCD CD CO O O CO NI' O N L() in C N in L() 'CI' N 1- U o 0 0 o O o O 8- co co L[) 1- CO CO L[) 6) N c- CO NY m 1` CO CO 00 CO CA O N O ti �Y CO O O r N N CO C)) CO O N CO N Cr) CO 00 Cl i i i i i i N d) 00 CO W d) O LO N N N N M CO N N N CO C Q� CO O O C� LO cco O O M O M M N N M O•,_ CO Q a Do O 0 CO CO C Ln _c N N N N N • _ r -12 M_ W a O 0) O O 00 CO CD OO ao ao C) O Z •y N *k *k CV CO 00 N UNc0 � --- � NN LO (3) I �' co O 01 CN C 000 CCOO O COD CO C d N O W W W Q Q Q No00a w OOLtfQ z c ODHHHZ0 U 0) Z Z Z = • • d CC m CO OO 000MML0MstO0 CO0 - LOCO0 N CO r C(D CO O d' O M st CO O N r 0 CD CD CO QD 01 0 O O) 00) CA CA 0)) 0)) CA O) CD co 00) Off) 00) 0) CA OD OCD CD ODOD 00 0 CO CO OD CO CO 00 OD CO CO OD OD OD OD CO CO CO CO CZ 0 I- CO - C0 r M CO 00 r 0N N- 0) CA CC) L CO OD M O O CA O NI' O 0 N r r 0 C• CO t0 r Q M (bCAui CD CD cd ui 6 d C3) CO O O) OO N Co S O CO C70 m NrO CA CO CO rf W 0 OD 0) O 0) O) CA CA 0) 0) 0) Cb 00 0) 0) O 0) CO Cb Cb > a aD oD 0) oD CO aD aD CO Cb O O mm O CO CO oD Cb 0 > 2 w 0 0 0 LCIALTJ m I- � Jp a o g g Y 0 O > O mC0 M IC) 0 0 0 O O O O CO CO O CO O O CO CC) O O O J U U w W w -...4 (01"..- 0) N0) O CO N- Co N CA CO Co O CO CJD V N N J J J Q Q Ci) C O O CD M r N CM C r N CO 0) r NrCO CO O N Q Q Q W W Ll Z p OO N N N N M M M M cr 'sY NI CO CO CO Uw U U J W W O J O d Q Q Q O 0 0 a W a D 0 Q 0 w w a Qz pJ Qz M O W WWW (n Q 0I a M FO, C '- L O O) O O CO CO CO CO CO O O O O O l0 O O O CO CDCDD o = C] 0 O O c 0D 0) N M CO CO sr LCD CO (A Co CO O fin N N N N Co Co Co Co N CC) CO CD . . . . . r r r r r r r r r r r r r r W cn = 0 0 co Q /0� 20 CI) CI) cai) a) a) Y. a) 0 0 0 c CCX (XCrttWft W ECCCIYW (YIrCCfY [t CC W W W W W W W W W W W W W W W W W W W 0 [13. 1MMMCI_ Mma. MMO_ CLMMMCLM 0 0 m a a) I- coCA CA 0 CA CA (A CA 0 CA 0 CA (A C7) (A C3) (A CA (ACA 0 0 0 0 0 co0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 W Z O N N N N N N N N N N N N N N N N N N N Z Q . . . . . r r . . . . . . . . r r r r Q W D W LL . . . . . r r r r r r r . . . . . ---� DW W Z D_ J 0 W W LL W O CC 0 0 1- J J J 0 W' X M W E I U O a 0 E 2 « « « « « « « « « < O O O O O O O O O O O O O O O O O O O W C'M CM M C'7 Ch CM CM A M M CM MMMM MMM M CD d O d 00 J 00 CI) 0 111 C1 r r r . . . . r r r r r r r r r r r r Q Q CO (T) LL (L C/) C/) 0_ Li: • 1 Packers and SSV's Attachment i PBU 13-03A SW Name Type MD TVD Depscription 13-03A SSSV 2119 2118.94 4-1/2" PB Valve 13-03A TBG PACKER 10268.32 8556.97 4-1/2" Baker S-3 Perm Packer 13-03A PACKER 10349.51 8630.26 5" Baker ZXP Top Packer • • 6/6/01 • Wireline Work Request 13-03 global wells organization Distribution Wireline(4) Well: 13-03 AFE: APBWELIRSL Reading File Date: 1/16/2016 Engineer: Kenda IOR: 50 FTS: AWGRS Job Scope: SSSV H2S Level: Problem Description Reset K Valve at lower pressure. High commonline pressure requires K valve to be set high and prevents well from unloading properly against choke and high Pwh. Initial Problem Review After discussions with Justice, plan is to set valve at a lower pressure to allow well to unload against lower Pwh and to shut in wells going in the common line to reduce pressure to allow for state test. Remedial Plan -WIRELINE ACTION NOTE: For State Test shut in wells to common line and reduce pressure below 350 psi to shut valve DSO: Flow well at Wellhead pressure greater than 350 psi.Valve set to close at 350 psi Pwh. FOR HES SHOP INFO ONLY: Set K-Valve to Close at 403 psi @ 60 degrees Date Work Completed Well Status/Results Date _ by Problem Resolved ? Y N : Well Review (Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate (STBL/D) Expected NOB: Avg. WC (%) Actual NOB: Lift Gas (MMSCF/D) MGOR used for NOB: TGLR (SCF/STBL/D) FTP (psi)/Steady? MAINTENANCE ONLY CLP (psi)/Steady? (e.g. Fix AC, Shallower for Slugging) Casing Press. (psi)/Steady? RATE (Non-Post-WW) Orifice Depth: (e.g.deepen,optimize orifice) IA Fluid Level: Post-Wellwork Date of FL Survey: / / Follow-up Recommendations: • • "K"Valve Calculation Sheet DS13-03 Date: 01/16/16 Test Date 01/06/16 Gross Fluid Rate 5250 BLPD Flowing Well Head Pressure 500 psi Flowing Well Head Temperature 169 deg F GOR 800 scf/bbl TGLR 762 scf/bbl Flowing Pressure Calculations Based on Hagedorn-Brown Multiphase Flow Correlation "K"Valve Setting Depth TVD 2119 ft Flowing Tubing Pressure With Gas Lift NA psi Flowing Tubing Pressure Without Gas Lift NA psi Valve set to close at 350 psi Pwh Flowing Tubing Pressure @ psi Pwh 660 psi "K"Valve Test Rack Set Pressure at 60 deg F 403 psi Valve Size &Volume Ratio 4.5" 1.314 NOTE: Well needs to flow at> 350 psi Pwh Valve set to close at 350 psi Pwh S • I L I Tubing Pressure at Valve 660 BPT(psis) 674 >1238 <1238 Temperature(deg F) at Valve 178 a 2.171E-05 3.60372E-05 _ _ b 1.271164 1.228212 Base Pressure 549.667712 c -705.906 -674.66668 Base Temp(TV-60) 118 550.15283 540.7289952 Corrected Pressure 540.728995 psia TCF 0.8017927 /olume Ratio for Valve Size = 1.314 Pb @ 60 = 529.18318 Test Rack Pressure = 403 Volume Ratios 4 1/2" & 5 1/2" 1.314 _ 3 1/2" 1.257 2 7/8" 1.211 2 3/8" 1.204 IF = aw 0 = RC 1 3-03A s---lik NOTES: VVELL ANGLE>70"@ 10813' "WELL REQLIRES A SSSV V1f3.11-EAD ACTUATOR= BAKER C ORIG KB,Sly 76' 2 I OR1G WBS NOT SHOWN BELOW WHPSTOCK OM BF.REV --r?' --- 3980' { 2119' —4-1/2"HES X NF,ID=3.813' KOP= Iv] 11.43X Angie= 1.@ 14930 20'Cl3WLICMR'944' — 1°9. 2119' —4-1/2"Ff3 VALVE INSTALL/33 01/11r1-61 Datum MD= 10623. H-40,ID=19.124' /4- ill 2346 H9-5/8"FOC Datum TVD= 880(YSS 2469' —9-5/8"FOC 9-5/8"CSG STUB(06/18/09) ---E2218' ,. d GAS LFT MANDRELS 13-3/8"CSG, 72#,N-80,ID=12.347" H 2706' ST., A4) TVD DEV TYPE VLV ,LATCH PORT DATE Minimum ID = 3.725" @ 10332n IA 5 3687 3659 25 KBG2 DONE BK 16 09/29/13 4 6646 5824 46 KBG2 SO BK 26 09/29/13 3 8643 7232 46 KBG2 MY BK 0 07/14/09 4-1/2" HES XN NIPPLE j 2 9803 8139 26 KBG2 DMY BK 0 07/14/09 1 10200 8495 26 KBG2 DMY BK 0 07/14/09 9-5/8"WFIPSTOCK _i_ 3960' ----------\ Mt LOUT WINDOW(13-03A) 3980'-3997' -------1 9-5/8"CSG,47#,N-80 BTC,ID=8.681' — 11319' -- 10236' —4-1/2"HES X NIP,ID=3.813" 10267' —7"X 4-1/2'BKR S-3 PKR,D=3.870' Ili FERFORATON SUMARY -11 'p4 ANGLE REF LOG: 1i,o- Ili _ _ . 10301' 4 1/2"I-ES X NIP,ID 3,813 ANGLE AT TOP PEW:43°@ 10650' Nbter Refer to Rod uction DB for historical pert data SIZE SPF 141BRVAL Oprt/Sqz SHOT SQZ illi 10337 —14-1/2"FES XN NP,ID=3.725" 2-7/8" 6 10650- 10665 0 07/11/09 2-7/8" 6 10759- 10773 0 07/11/09 10337' —7"X 5"FRD ZXP LTP w/I ILBACK 2-7/8' 6 10940- 10995 0 07/11/09 SLV&BKR FLEXLOCK FIGR 2-7/8" 6 11600- 11620 0 07/11/09 ID=4.193' 2-7/8' 6 11855- 11890 0 07/11/09 _ 10344' —4-1/2"VVLEG,ID=3.958' 2-7/8" 6 11945- 12100 0 07/11/09 2-7/8" 6 12235- 12280 0 07/11/09 -,it, 11 2-7/8" 6 12345- 12370 0 07/11/09 4-1/2"TBG, 12 84, H 10344' 1p 2-7/8" 6 12605- 12630 0 07/11/09 13CR-80 VAM TOP, / 10367 —5'X 4-1/2"XO,ID=3.890' 2-7/8" 6 12680- 13120 0 07/11/09 .0152 bpf,ID=3.958" 2-7/8" 6 13440- 13495 0 07/11/09 7'CSG,26#, — 10360' 2-7/8' 6 13870- 13930 0 07/11/09 L-80 TCI X0 2-7/8' 6 13970- 14105 0 07/11/09 TO L-80 BTC-M 2-7/8" 6 14395- 14460 0 07/11/09 2-7/8' 6 14830- 14880 0 07/11/09 7'CSG,26#,L-80 BTC-M, 10504' 1111 2-7/8" 6 15600- 15645 0 07/11/09 II=6.276" 2-7/8" 6 15750- 16025 0 07/11/09 2-7/8" 6 16085- 16220 0 07/11/09 Ai 1141 PBTO H 16237' 4444i tti* 4-1/2'LNR, 12.64, 13CR-80 VAM TOP,.0152 bpf,D=3.958" — 16318' DATE REV BY COMMENTS DATE REV BY COMMENTS F1&D-IOE BAY UNIT 03/18/79 PKR 141 ORIGINAL COMPLETION 01/06/16 GJENJM3 SET FLOW Tl-FIU GAUGES(1/4/16) WELL 13-03A 01/10182 NI ES RWO 02/03/16 IVC2S/T1H RLL FLOW Tl-EU GAUGES(1/11/16) FERNAT No:'2090480 07/15/09 N9ES SIDETRACK(13-03A) 02/03/16 GRUTLF1 R3 VLV UPDATE PER STA TE REQS AR No: 50-029-20325-01-00 11/07/11 WEC/PJC GLV C/0(10f27/11) ' SEC 14,T10N,R14E,2054'FSL&7'FEL 11/12/114.43A4 RIC GLV CO(11/08/11) 10/09/13 GJB/JMD GLV C/0(09/29/13) _ BP Exploration(Alaska) • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, January 23, 2016 3:09 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL;AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; Regg, James B (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer;AK, D&C DHD Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney;Wallace, Chris D (DOA); AK, OPS Gas Lift Engr Subject: NOT OPERABLE: Producer 13-03A (PTD #2090480) Due for AOGCC SVS testing external-email: 0 All, Producer 13-03A(PTD#2090480) had a downhole subsurface valve (K valve) reset on January 11, 2016 following a failed non-witnessed No Flow test (NFT) on January 03, 2016. The well was placed on production January 12, 2015 but has failed to stabilize in sufficient time for upcoming AOGCC safety valve system (SVS)testing. This well has been reclassified as Not Operable and shall remain shut in until the downhole K valve can be optimized and updated AOGCC SVS testing obtained. AOGCC approval of the optimized K valve design shall be required prior to bringing the well back online. Plan Forward: 1. Gas Lift Engineer: Optimize K valve design—DONE 01/23/16 2. Well Integrity Coordinator: Obtain state approval for K valve design 3. Slickline: Reset new K valve 4. Operations: Place well on production, obtain updated SVS testing 5. Well Integrity Engineer: Additional diagnostics as needed Please call with any questions or concerns. Thank you, MAI 2 6 2010 Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com 1 • 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. - ~ ~-~ Well History File Identifier Organizing (done) ^ Two-sided III (I'I II II III II III ^ Rescan Needed III II'I II II II III III RE CAN DIGITAL DATA for Items: ^ Diskettes, No. Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: NOTES: BY: ~ Maria Date: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: / 1 v /s/ P IIIIIIIIIIIIII IIIII Project Proofing BY: Maria Date: 1 ~ ~s~ Scanning Preparation _~ x 30 = ~ + ~_ =TOTAL PAGES /`~ ~ ~ ~ (Count does not include cover sheet) BY: Maria Date: /s~ Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Pa a Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: ~ ~ ~ ~ ~ /s/ ~/ ~/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~s~ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned III IIIIII IIIII II III BY: Maria Date: ~s~ hisfile: QualityChecked IIIIIIIIIIIIIIIIIII Comments about t 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 8/26/2010 Permit to Drill 2090480 Well Name/No. PRUDHOE BAY UNIT 13-03A Operator BP EXPLORATION (ALASF(ly INC MD 16320 TVD 8824 Completion Date 7/12/2009 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-20325-01-00 UIC N REQUIRED INFORMATION c/ Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: DIR / GR / PWD /RES, DIR / GR / NEU /DEN /RES (data t aken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / T Med/Frmt Number me Scale Media No Start Stop CH Received Comments ED C Lis 1872 Induction/Resistivity 3657 16313 Open 10/2/2009 GR, ROP, FET, RPX, RPS, RPM, RPD, RAM, DRHI, NPHI Plus Graphics o Induction/Resistivity 25 Blu 3700 16290 Open 10/2/2009 MD Vision Service Log Induction/Resistivity 25 Blu 3700 16290 Open 10/2/2009 TVD Vision Service Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comme nts ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? .-1~-LAl- Analysis rY-tN~ Received? Daily History Received? `(-~/ N Formation Tops 1/ N Comments: • DATA SUBMITTAL COMPLIANCE REPORT 8/26/2010 Permit to Drill 2090480 Well Name/No. PRUDHOE BAY UNIT 13-03A MD 16320 TVD 8824 Completion Date 7/12/2009 Compliance Reviewed By: Operator BP EXPLORATION (ALASKA INC API No. 50-029-20325-01-00 Completion Status 1-OIL Current Status 1-OIL ~ UIC N Date: ___ l-- _~ V Schlwnherger Alaska Data & Consulting Services 2525 Gambetl Street, Suite 000 Anchorage, qK 99503-2638 ATTN: Beth Well Job # N0. 5405 Company: State of Alaska Alaska Oil 6 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL r~l,,. ~~ K-11 AY1M-00033 SBHP SURVEY - L4-30 P2-31 AWL6.00031 AP30-00045 PRODUCTION PROFILE LDL _ ~ 09/12/09 09/06/09 .y 1 1 1 01-29 86JE-00009 PRODUCTION PROFILE _ 07/11/09 1 1 J-22A W'44 12-25 L5-33 B69K-00013 8148-00071 6581-00010 AYKP-00051 PRODUCTION PROFILE INJECTION PROFILE INJECTION PROFILE SBHP SURVEY _ 08/11/09 08/30/09 09/06/09 09/22/09 1 1 1 1 1 1 1 1 P2-08 B69K-00015 SBHP SURVEY 09/01/09 1 1 Z-28 B68K-00016 INJECTION PROFIL 09/01/09 1 1 O-02A AP30-00054 IBP/LDL _ ~ 09/19/09 1 1 N-t0A W-24 V-03 H-148 P1.01 P1-05 AX80.00040 AWJI-00044 82NJ-00021 B2WY•00026 AY1M-00031 8581-00009 MEM PROD PR FILE MEM INJECTION PROFILE MEM PROD PROFILE V _ ~ MEM PROD PROFILE ~ INJECTION PROFILE PRODUCTION PROFIL _ 07/24/09 08/25/09 6115/09 09/03/09 06/27/09 06/20/09 1 1 1 1 1 1 1 1 1 1 1 1 NK-10 13-27A 82WV-00023 82NJ-00019 MEM INJECTION PROFILE - G MEMORY SCMT 06/20/09 08/22/09 1 1 1 1 18-028 82WY-00021 MEMORY SCMT 08/13/09 1 i NK-36A AYKP-00049 USIT 08/19/09 1 1 06-09 SWLB-00026 USIT 08/17/09 07/30/ 1 i 13.03A C-188 09AKA0150 82NJ-00017 OH MWD/LWD EDIT _ MCNL - 09 07/06/09 2 1 1 1 1-3510-25 B69K-00011 RST 08/09/09 1 1 04-35A AXB0.00025 MCNL 08/26/09 1 1 05/13/09 1 1 PLEASE ACKNOWLEDGE REC 0o c.,..~_.,..:__ ~ _ EIPT BY SIGNIN G AND RETURNING ONE COPY EACH TO: _ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Dafa 8 Consulting Services 2525 Gamhell Street, Sude 400 Anchorage, AK 99503-2836 /. f olot los may, i~ r~. Maunder, Thomas E (DOA) CJ Page 1 of 2 From: Maunder, Thomas E (DOA) Sent: Thursday, August 27, 2009 11:23 AM To: 'Warren, Abigail M' Cc: 'Hobbs, Greg S (ANC)'; DOA AOGCC Prudhoe Bay; Aubert, Winton G (DOA); Schwartz, Guy L (DOA) Subject: RE: DS 13-03A (209-048) Abby and Greg, Thanks for your call and the response to my questions. On item 2, it would appear that there are several ways to assure that all components/items are tested prior to exposure to wellbore pressures. I believe we are in agreement that relying on a pressure test accomplished in Houston or elsewhere prior to shipment is not appropriate. Please keep me advised on the outcome of your internal discussions. Colt or message with any questions. Tom Maunder, PE AOGCC From: Warren, Abigail M [mailto:Abigail.Warren@bp.com] Sent: Thursday, August 27, 2009 11:06 AM To: Maunder, Thomas E (DOA) Subject: DS 13-03A (209-048) Tom, Answers are in blue, the LOT plot is attached. As always, please let me know if you have any other questions! Thanks, Abby 1. Could you provide some comments regarding the gyro surveys needed from the window depth of 3980' - 4557'. I don't believe I've seen comments such as these included in the report regarding magnetic interference like this before. Was the trajectory just close to remains of DS 13-03? Yes we were close and we did get magnetic interference with the original parent wellbore. The kick off paint was at ~30 degree inclination. We typically run a gyro if there are close approaches or the well is vertical or near vertical 2. When the plug is bumped on the 7", the casing was then tested to 3500 psi for 30 minutes. Work proceeds to set slips, cut off, set packoff, NU tubing head and then the test plug is set to test the BOP. The BOP is tested 250/3500. Does employing this operations sequence field test afl connections on the tubing head, in particular the outlet valves? Based on my review of the operations report, it appears that until the full wellbore pressure test (4500 psi) after cleaning out to the liner top that the maximum test pressure applied to some portions of the tubing head was only 960 psi when the LOT was conducted. The annular valves are not tested on the slope. They are tested before being shipped to the slope but neither Cameron nor FMC test the annular valves on the slope. Our test procedure on this well did not test them either, it test from the tubing hanger sealing area up and the packoff tests the break at the base of the spool and the packoff only. In the future one option would be to set slips, cut off, set packoff, NU tubing head, test BOP's, and then go about the 30 minute casing test. This would then test the body and also the outlet valves. Another option would be to test the outlet valves on the slope before the tubing head is installed. A third option may be running a storm packer and test against the storm packer. ~~~J 10/27/2009 ~~ I believe that this is a solution that we need to decide within the group. Page 2 of 2 3. What analysis does BP employ to validate LOT/FIT results when there is a large difference in the compressible fluid volume in the wellbore when the casing is tested after bumping the plug (no DP in the hole) and LOTs/FITs are conducted with DP in the hole? I calculate the casing displacement to the FC at ~ 387 bbls and the DP steel volume at ~65 bbls_ The WSL's calculate the volume each time we do a pressure test, in this case though it would take 21 strokes to pressure up with no drill pipe and 18 strokes with drill pipe in the hole. 10/27/2009 CASING AND LEAK-OFF FRACTURE TESTS Well Name: 13-03A Date: 6/22/2009 Csg Size/WUGrade: 9 5/8" / 47# / L-80 Supervisor: Neufeld/Vazquez Csg Setting Depth: 3980 TMD 3916 TVD Mud Weight: 9.2 ppg Leakoff pressure = 780 psi LOT= 13.03 ppg Hole Depth = 4022 and Fluid Pumped= 3.4 Bbls Volume Back = bbls Estimated Pump Output: 0.058 Barrels/Stroke LEAK-OFF DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here -a 4 20 -> 0 0 _> $ - - 120 _ -> - -_ 6 41 •> 16 320 -> 12 253 > 20 390 > - 18 _ 470 -> - --- 24 - - 430 -> - - 24 696 28 520 -> - -- 30 897 ~ -> 32 580 -> 36 - 1047 `~ :, -> 36 620 > - 42 1220 ' „::~ -- - 40 680 -> - 48 1416 :".> - 44 ~ - 700 _> ' 54 1610 `` > 48 - -- 710 > 60 1800 '"~ -> 52 -- 730- > 66 2000 -> 56 780 > 70 2168 o,-> - - 59 __-560.._ -- _> ~ Enter Holding Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here _> 7 -> ~, a 1 € 530 > _- 1 2000 ;~ -> 2 500 -> 2 200 _;.> 3 450 - - ' _> 3 20 "~-> ' 4 420 - -> - 4 - ~~ -> ' S - -~ - 400 -- > 5 2000 ~ ,~~;_, ~z~ -> 6 380 -> _ 6 2000 t ~ ---- 7 --- 350 > - 7 -- 2000 .°.~> :~~- 8 320 _> 8 2000 '` -> 9 310 -> 9 - 2000 €.> 10 310 > 10 2000 rc. > -> .> -> .> -> • (LEAK-OFF DATA ~-CASING TEST DATA 4000 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 c 2100 . 2000 a d 1900 a` 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 - 600 500 400 --- 300 200 100 -- - 0 0 10 20 30 40 50 60 70 80 Strokes (# of) • • -F LEAK-OFF DATA f CASING TEST DATA 4000 ---- ------.. 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 c 2100 . m zooo 1900 N i a a 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 0 5 10 15 20 25 30 Time (Minutes) • CASING AND FORMATION INTEGRITY TESTS Well Name: 13-03A Date: 7/1/2009 Csg Size/WUGrade: 7 26# L-80 Supervisor: LeBlanc/Rebol Csg Setting Depth: 10501 TMD 8769 TVD Mud Weight: 8.4 ppg Maximum pressure = 960 psi FIT / EMW = 10.51 ppg Hole Depth = 10650 and Fluid Pumped= Bbls Volume Back = bbls Estimated Pump Output: 0.058 Barrels/Stroke LEAK-OFF DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here -> 3 200 > 6 _ - 260 ~ 9 370 -> 12 - 500 -> 15 610 ~:~ _- 18 720 .~ - 21 810 -> 24 910 > 25 960 _> - - - ~~ _>„" a - - --- - - - > Enter Holding Enter Holding Time Here Pressure Here -> 0 960 -> 2 922 > __ 4 - - - - 918 -> 6 --- 913 - - $- ? _ .__91.3 ~'. °' 10 913 - -> 12 902 > .> ;.> .> ~:.-=' -> .> _y .> _> -> .> _> .> ~'° -> _> _> ': m> -> .> Enter Holding Enter Holding Time Here Pressure Here • • ~- LEAK-OFF DATA f CASING TEST DATA 4000 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 o. 2100 m ~ 2000 w aNi 1900 a` 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 0 10 20 30 Strokes (# of) f LEAK-OFF DATA --f- CASING TEST DATA 4000 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 a 2100 d ~ 2000 N m 1900 a 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 0 5 10 15 20 25 30 Time (Minutes) Page 1 of 2 Fleckenstein, Robert J (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.comJ Sent: Wednesday, August 19, 2009 1:14 PM To: Fleckenstein, Robert J (DOA) Cc: G ANC PDC Subject: RE: 13-03A, PTD # 209-048 Yikes! Okay... I'm hurrying too much. I'm leaving on vacation tomorrow and I'm down to my last couple of hours to wrap things up. I do apologize for the mistakes. Please make the correction as follows: 3764' FSL, 4250' FWL, Sec. 13, T10N, R14E I hope that is the final error of the day! See ya in a couple of weeks. Terrie From: Fleckenstein, Robert J (DOA) [mailto:bob.fleckenstein@alaska.gov] Sent: Wednesday, August 19, 2009 1:03 PM To: Hubble, Terrie L Subject: RE: 13-03A, PTD # 209-048 You are really having a bad day!!!!!!! Look at your FWL distance. Robert J. Fleckenstein Statistical Technician II Alaska Oil and Gas Conservation Commission Office: 907-793-1242 Fax: 907-276-7542 *Please note new crnail address bob.fleckenstein(a,alaska•gov From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Wednesday, August 19, 2009 12:22 PM To: Fleckenstein, Robert J (DOA) Cc: G ANC PDC Subject: RE: 13-03A, PTD # 209-048 Oops... I still didn't get it right. The Top of Productive should read: 3764' FSL, 42050' FWL, Sec. 13, T10N, R14E 8/19/2009 Page 2 of 2 That should do it! Terrie From: Fleckenstein, Robert J (DOA) [mailto:bob.fleckenstein@alaska.gov] Sent: Wednesday, August 19, 2009 12:11 PM To: Hubble, Terrie L Subject: RE: 13-03A, PTD # 209-048 Terrie, That change made it worse. Call me and we will compare numbers. BobF Robert J. Fleckenstein Statistical Technician II Alaska Oil and Gas Conservation Commission Office: 907-793-1242 Fax: 907-276-7542 *Please note new email address bob.fleckenstein(e~alaska.gov From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Wednesday, August 19, 2009 11:35 AM To: Fleckenstein, Robert J (DOA) Cc: G ANC PDC Subject: 13-03A, PTD # 209-048 Hi Bob, You are correct, I did make a typo on the Completion Report for this well in the Top of Productive Interval (4a). Please correct the section to 13 (instead of 18). Other than that I think it is correct. Thanks for catching it! Terrie 8/19/2009 Li' STATE OF ALASKA ALASKA I AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~; ~ ~ 2~~~ 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ~ Development, ^ Service ,~, 017111ti88i F~xploratory Strati raphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban ~ 7/1 2009 12. Permit to Drill Number 209-048 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/ 2009 - 13. API Number 50-029-20325-01-00~ 4a. Location of Well (Governmental Section): Surface: ' ~ ' 7. Date T.D. Reached 7/6/2009 14. Well Name and Number: PBU 13-03A- FSL, 7 FEL, SEC. 14, T10N, R14E, UM ~ 2055 Top of Productive Horizon: ~ ~~/ ~f/g/~ 3764' FSL, 4250' FWL, SEC., T10N, R1.81`, UM 8• KB (ft above MSL): 72.93' Ground (ft MSL): 15. Field /Pool(s): _ Prudhoe Bay Field / Prudhoe Bay Total Depth: 2868' FSL, 4142' FWL, SEC. 18, T10N, R15E, UM 9. Plug Back Depth (MD+TVD) 16237' 8829' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 687206 y- 5932121 Zone- ASP4 10. Total Depth (MD+TVD) 16320' 8824' 16. Property Designation: ADL 028315 & 028330 TPI: x- 691418 y- 5933937 Zone- ASP4 - 5933174 Zone- ASP4 Total De th: x- 696611 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: y p 18. Directional Survey ®Yes ^ No mi I ctroni and rinted information r 20 AA 5. 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 25.071): DIR 1 GR / PWD /RES, DIR / GR / NEU /DEN /RES ~~(/d o!/ 39~O'MD ~~/~ ~TT/~A 22. CASING, LINER AND CEMENTING RECORD . CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT . " Wr. PER FL GRADE TOP. BOTTOM - TOP BOTTOM SIZE CEMENTING RECORD r PULLED 0" H-4 S rf ce 1 9' urf 1 9' 4" 151 sx P rmafr s - /" 7# rf 7 2 17- /" 4 r I 9-5/8" 47# N-80 / Soo-95 2218' 18' 1 1 -114" 1 sx Class ' ' 7" 26# -80 2 ' 10 25' 8771' 8-1/2" 7 x Li Cret 2 sx Class'G' 4-1/2" 1 1 1 8 -1/ " 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, IISt each I (MD+TVD of To & Bottom Pe ntefVal Open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD p ; See Attached 4-1/2", 12.6#, 13Cr80 10344' 10267` MD TVD MD TVD 25. ACED, FRACTURE,.CEMENT:SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Hi KIND OF MATERIAL USED 2277' Freeze Protect with 77 Bbls of Diesel 26. PRODUCTION TEST Date First Production: August 5, 2009 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date Of Test: 8/9/2009 HOUrS Tested: 10 PRODUCTION FOR TEST PERIOD OIL-BBL: g3 GAS-MCF: 1,010 WATER-BBL: 2,638 CHOKE SIZE: 84 GAS-OIL RATIO: 10,938 Flow Tubing Press. 350 Casing Press: 1,600 CALCULATED 24-HOUR RATE OIL-BBL: 223 GAS-MCF: 2,425 WATER-BBL: 6,332 OIL GRAVITY-API (CORK): Not Available 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac wired? ®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. ......__[ai)E~! None 09 s - .~... _...m.;~..a.r Form 10-407 Revised 02/2007 CONTINUED ON R~ _ ~N ~i~~ ~ ~ 2D~9 ~~~~~ ~' ~~~'~C'~`p ~~ 28. 7l.`~OLOGIC MARKERS (LIST ALL FORMATIONS AND MA ENCOUNTERED): 29. FORMATION TESTS NAME MD ND Well Tested? Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 10497' 8765' Sadlerochit /Zone 4B 10611' 8864' None 45N 10647' 8891' 44N 10704' 8930' 43N 10784' 8970' 42N /Zone 4A 10938' 9009' 42N /Zone 4A (Inverted) 11476' 9003' 43N (Inverted) 12100' 8963' 44N (Inverted) 12535' 8920' 45N (Inverted) 12896' 8883' 45N (Revert) 13577' 8890' 44N (Revert) 13765' 8918' 44N (Revert) 13860' 8933' 43N (Revert) 14233' 8979' 43N (Inverted) 14883' 8990' 44N (Inverted) 15140' 8950' 43N (Inverted) 15295' 8929' 44N (Inverted) 15580' 8888' 45N (Inverted) 16025' 8843' Formation at Total Depth (Name): Sadlerochit /Zone 46 (f/ Base) 16025' 8843' 30. List of Attachments: .Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys / 31. I hereby certify that the foregging is true and correct to the best of my knowledge. ~~ ~ ~ Signed Terrie Hubble ~ Title Drilling Technologist Date PBU 13-03A 209-048 Prepared By NameAVumaer. Terrie Hubble, 564-4628 Well Number Permit No. / A rOV21 NO. Drilling Engineer: Abby Warren, 564-5720 INSTRUCTIONS GeNew-~: 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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 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.. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: 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. IreM 29: 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 02/2007 Submit Original Only STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Form 10-407 Attachment WELL NAME: 13-03A 23. Perforations o en to Production MD TVD Gun Diameter SPF Status 10650' - 10665' 8894' - 8904' 2-7/8" 6 Open 10759' - 10773' 8959' - 8965' 2-7/8" 6 Open 10940' - 10995' 9009' - 9020' 2-7/8" 6 Open 11600' - 11620' 8994' - 8993' 2-7/8" 6 Open 11855' - 11890' 8985' - 8882' 2-7/8" 6 Open 11945' - 12100' 8976' - 8963' 2-7/8" 6 Open 12235' - 12280' .8949' - 8945' 2-7/8" 6 Open 12345' - 12370' 8938' - 8936' 2-7/8" 6 Open 12605' - 12630' 8913' - 8911' 2-7/8" 6 Open 12680' -13120' 8906' - 8867' 2-7/8" 6 Open 13440' -13495' 8869' - 8877' 2-7/8" 6 Open 13590' -13655' 8892' - 8902' 2-7/8" 6 Open 13870' - 13930' 8934' - 8943' 2-7/8" 6 Open 13970' - 14105' 8949' - 8967' 2-7/8" 6 Open 14395' -14460' 8994' - 9000' 2-7/8" 6 Open 14830' -14880' 8999' - 8991 ' 2-7/8" 6 Open 15600' - 15645' 8886' - 8880' 2-7/8" 6 Open 15750' - 16025' 8868' - 8843' 2-7/8" 6 Open 16085' -16220' 8840' - 8830' 2-7/8" 6 Open BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: 13-03 Common Name: 13-03 Test Date Test Type 6/22/2009 LOT 7/2/2009 FIT -__ - -~- Test Depth (TMD~Test Depth (TVD) ~ AMW _ Surface Pressure Leak Off Pressure (BHP) ~ EMW 3,980.0 (ft) 3,916.0 (ft) 9.20 (ppg) 780 (psi) 2,652 (psi) 13.03 (ppg) 10,502.0 (ft) 8,769.0 (ft) 8.40 (ppg) 960 (psi) 4,786 (psi) 10.51 (ppg) • Printed: 8/3/2009 8:36:27 AM BP EXPLORATION Page 1 of 28 Operations Summary Report Legal Well Common W Event Name Contractor Rig Name: Date !, Name: 1 ell Name: 1 : R Name: N N From - To 3-03 3-03 EENTE ABOBS ABOBS Hours R+COM ALASK 9ES Task PLET A DRI Code E LLING NPT Start I Rig R Rig N Phase ~, Spud Date: 2/14/1979 : 6/4/2009 End: 7/15/2009 elease: 7/15/2009 umber: Description of Operations __ - __ - 6/9/2009 _ __ 00:00 - 05:00 5.00 MOB P PRE PJSM. Move Taylor camp, shops and pit module from DS02 to DS13; spot on location. LD derrick, move sub off 02-33B. Nabors 9ES off DS02 location C~3 06:OOhrs. 05:00 - 16:00 11.00 RIGU P PRE Move Nabors 9ES from 02-336 to 13-03A via Oxbow, then Spine road. Jockey rig into position over well. Rig accept @ 16:OOhrs, 6/9/09. 16:00 - 00:00 8.00 WHSUR P DECOMP Continue RU operations; install kelly hose, service top drive, load pipe shed w/ DP, take on 9.8ppg brine. Prep cellar and wellhead- RU secondary working valves in prep for circulating/testing OA and IA. 6/10/2009 00:00 - 01:00 1.00 WHSUR P DECOMP PJSM. RU open top tank and 2" hardline to cellar. 01:00 - 04:00 3.00 WHSUR P DECOMP Pressure test OA and IA; 2000psi for 30 minutes each, chart both tests. OA test passed: ~~ ~ Omin : 2000psi 15min: 1950psi 30min: 1900psi ~~~ ~~~~ IA failed pressure test; pumping C~? 154gpm, pump pressure @ ~ ` "0 150psi. No pressure building on IA, OA pressured up to ~jE. ~ 500psi. Stop pumping- 81 bbls pumped away. Bleed off r ~ ~ pressure on OA, attempt to pressure up again on IA. Pump @ ~~ ~` bQr~ 167gpm, pump pressure C~ 180psi. Still no pressure build up on IA, OA pressured up to 200psi. Stop pumping- 67bbls pumped away- and bleed off OA to Opsi. 04:00 - 05:30 1.50 WHSUR P DECOMP RU DSM and test lubricator to 500psi; good. Pull BPV and re to circulate out diesel. 05:30 - 12:00 6.50 WHSUR P DECOMP Pump 40bbls 9.8ppg brine down annulus; pump 4bpm, 166gpm, 170psi. No returns. Pump down tubing; 4bpm, 166gpm, 210psi. Still no returns. Reduce brine weight in an effort to gain returns. Pump 9.5ppg brine down the tubing at 5.5bpm, 370psi; increase rate to 6bpm and start seeing partial returns at the tiger tank. 12:00 - 17:00 5.00 WHSUR P DECOMP Reduce brine weight to 9.2ppg. Pump 7bpm, 740psi with partial returns (584bb1s pumped). 9.2ppg in, 9.8ppg out. Change RU to take returns to the mud pits, not the tiger tank; continue to pump brine at 6bpm, 540psi (71 bbls pumped). 17:00 - 19:30 2.50 WHSUR P DECOMP Pump 40bb1 Safe-Surf-O pill, chase with 1054bb1s of 9.2ppg brine. Pump C~ 7bpm, 680psi. 720bb1s into pumping, start seeing Safe-Surf-O coming to surface. Large slug of SS-O seen in returns at 778bb1s pumped. Continue to pump until SS-O returns taper off. Losses at a rate of -230bph. 1..9:30 - 23:00 3.50 WHSUR P DECOMP Monitor well; on vaccuum. Install BPV and test from below; pressure test to 670psi while pumping 6bpm. ND tree; check blanking plug- 6LH turns. Crossover- 8 RH turns. 23:00 - 00:00 1.00 BOPSU P DECOMP PJSM; start NU BOPs. 6/11/2009 00:00 - 04:00 4.00 BOPSU P DECOMP PJSM. NU BOPs. 04:00 - 04:30 0.50 BOPSU N RREP DECOMP Pressure test BOP equipment to 250psi low, 3500psi high w/ 4" and 5.5" test joints. Attempt to pressure up against shear rams; pressure up to 3550psi; pressure bled off immediately. Function rams and attempt to pressure up twice more; pressure still not holding. 04:30 - 08:00 3.50 BOPSU N RREP DECOMP PJSM to change out seal on shear rams. Drain stack and rnnzeo: oiai~u~a a:ao:ac ram BP EXPLORATION Page 2 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Hours Task j Code NPT Date From - To _' Spud Date: 2/14/1979 Start: 6/4/2009 End: 7/15/2009 Rig Release: 7/15/2009 Rig Number: Phase Description of Operations 6/11/2009 04:30 - 08:00 3.50 BOPSU N RREP DECOMP open ram doors. Pull shear rams and send to truck shop for reuild; install blind shear rams. 08:00 - 12:00 4.00 BOPSU N RREP DECOMP Fill stack and pressure test BOPs to 250psi low, 3500psi high; chart all tests. BOP test witnessed by AOGCC rep Lou Grimaldi, WSLs Blair Neufeld and Mitch Skinner and NAD Toolpusher Kelly Cozby. Attempted to test blinds three times; function blinds and re-test; test good on fourth time. Packing leaking on manual choke valve; repair. 12:00 - 19:30 7.50 BOPSU P DECOMP Complete BOP testing; 250psi low, 3500psi high; chart all tests. BOP test witnessed by AOGCC rep Lou Grimaldi, WSLs Blair Neufeld and Mitch Skinner and NAD Toolpusher Kelly Cozby. 19:30 - 21:30 2.00 BOPSU P DECOMP LD testing equipment. RU DSM lubricator and test to 500psi. Pull BPV w/lubricator. 21:30 - 22:30 1.00 PULL P DECOMP Fill hole w/ 9.Oppg brine; took 25bbls to fill. Monitor well for 30minutes, fluid falling. Top off again; 18.3bbls to fill. Monitor for another 30minutes, fluid falling. Top off; 16.3bbls required to fill. 22:30 - 23:30 1.00 PULL P DECOMP RU Baker fishing spear and grappel and one joint of 4" HW. 5-ft-stick spear assy into stack. Engage tubing hanger with spear; PU to 150k to free hanger. Continue to pull to get past siezed lock-down screw; pulled past screw ~ 225k. Pull tubing hanger to rig floor; 145k up. 23:30 - 00:00 0.50 PULL P DECOMP With tubing hanger at rig floor, stage pumps up to swap fluids over to 9.Oppg brine (from 9.2ppg brine). Bring pumps up to 1 270psi C~ 210gpm. Returns seen @ 34bbls pumped. 6/12/2009 00:00 - 01:30 1.50 PULL P DECOMP PJSM. Continue to circulate wellbore over to 9.Oppg brine (from 9.2ppg brine). Circulate surface-to-surface volume C~ 270psi and 210gpm. At 530bb1s pumped, 9.Oppg brine in and out. While pumping, losses at -100bph. 01:30 - 06:30 5.00 PULL P DECOMP Release spear from hanger and LD. Terminate control lines at hanger; LD tubing hanger and two pup joints- two stainless steel bands on hanger pups. 06:30 - 17:00 10.50 PULL P DECOMP Pull 5.5" 17# L-80 LTC tubing from cut ~ 7200' MD to surface. Spool control line; remove clamps from tubing and collect. 27 control line clamps recovered. LD a total of 179 joints of tubing, 3 GLMs and 1 SSSV. Static losses at 50-60bph. 17:00 - 20:00 3.00 BOPSU P DECOMP RU test equipment to test lower pipe rams; unable to seat test plug in tubing hanger due to siezed lock-down screw. 20:00 - 21:30 1.50 BOPSU P DECOMP Service top drive and crown. 21:30 - 00:00 2.50 BOPSU P DECOMP RU Halliburton RTTS packer. RIH w/ packer; single in w/ 4" DP. Losing fluid at 30bph. 6/13/2009 00:00 - 02:30 2.50 BOPSU P DECOMP PJSM. RIH to 1875' MD; single in w/ 4" DP and HES RTTS packer. Set packer as per HES hand. 02:30 - 03:30 1.00 BOPSU P DECOMP Close lower pipe rams on 4" DP. Pressure test rams to 250psi low, 3500psi high. Test charted and witnessed by BP WSL Amanda Rebol and NAD Toolpusher Brian Tiedmann. 03:30 - 05:30 2.00 BOPSU P DECOMP POOH from 1875' to HES RTTS packer, racking back stands of 4" DP. Break out and LD packer. 05:30 - 08:30 3.00 CLEAN P DECOMP PU 8-1/2" used bit, bit sub, float sub and string mill. PU 6-1/4" drill collars and 9jts of HWDP for cleanout run. 08:30 - 18:00 9.50 CLEAN P DECOMP RIH with cleanout assembly; single in with 4" DP out of pipe shed. Static fluid losses to wellbore at -30bph; fill over the top rnnteo: bisiwua C:Jb3Z HM • BP EXPLORATION Page 3 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABOBS 9ES Rig Number: Date j From - To Hours Task Code NPT Phase 6/13/2009 08:30 - 18:00 9.50 CLEAN P 1 18:00 - 00:00 6.00 CLEAN P 6/14/2009 00:00 - 03:30 3.50 CLEAN P 03:30 - 04:00 0.50 CLEAN P 04:00 - 06:00 2.00 DHB N 06:00 - 07:00 1.00 DHB P 07:00 - 08:30 1.50 DHB P 08:30 - 11:00 2.50 DHB P 11:00 - 13:00 2.00 DHB P 13:00 - 20:00 7.00 DHB P 20:00 - 00:00 4.00 DHB P 16/15/2009 ~ 00:00 - 05:00 05:00 - 06:00 06:00 - 10:00 10:00 - 10:30 5.00 DHB P 1.00 DHB P 4.00 DHB P 0.50 DHB P Description of Operations DECOMP w/ 8.7ppg brine. Tag up on tubing stump C~ 7209' MD. DECOMP Circulate wellbore to clean 8.7ppg brine; reciprocate pipe in 95' strokes. Pump 150psi C~ 110gpm, 47spm. Once surface-to-surface circulated, monitor well for losses before POOH; losses ~ 15bph. DECOMP PJSM. POOH, racking back stands of 4" DP from 7209' MD to surface. Rack back HW and drill collars. DECOMP Break out and LD string mill, float and bit sub, and 8-1/2" used drill bit. Clean and clear rig of third party tools and equipment. Monitor well; 15-18bph static losses. WAIT DECOMP PJSM w/ SLB wireline crew. Wireline unit not functioning properly; wait on new unit to arrive on location. DECOMP While waiting on new SLB wireline unit, PU DP in prep for RIH and future drilling operations. PU and rack back 10 stands of 4" DP. DECOMP RU SLB wireline and attempt to RIH 2/ 8.29" gauge ring. Unable to get GR deeper than 5370' (in area of casing damage). POOH w/ wireline. DECOMP Change out to 8.00" gauge ring and attempt to RIH w/ wireline again. Again, unable to continue beyone 5370' MD. Suspect GR laying on low side of the hole and hanging up. DECOMP Change out to 6.78" gauge ring and re-attempt wireline run. RIH from surface to 7205' MD and tag up on tubing stump. POOH w/ wireline. DECOMP LD gauge ring and RU CCL/USIT logging tools. RIH on wireline from surface to tubing stump (tag up ~ 7205' MD) and log up to determine TOC. TOC @ 2316' MD. Indications of damaged/corroded casing from 4290' MD - 4300' MD as well as from 5370' MD - 5380' MD. DECOMP RU HES EZSV on wireline and attempt to RIH. Turn off hole fill while running wireline. While RIH, hanging up C~ 5350' MD. PU and attempt to go past damaged casing area a second time; no go. PU on wireline and run back down to 5350' MD; tool slacked off a third time; turn on hole fill and attempt to push tool past damage zone with hydrostatic; no go. POOH w/ wireline and EZSV; no damage to EZSV. DECOMP PJSM w/HES crew. MU EZSV, setting tool, float sub and 8.5" string mill. RIH w/ EZSV setting assembly from surface to 6708' MD; allow pipe to fill via ports on setting tool and monitor for losses. Two indications of damaged casing; hung up C«~ 5376' MD and 5384' MD. PU and ran back past areas where string took weight and was able to work past without additional problems. Max weight down = 10-15k. DECOMP RIH to 6711'; 137k up, 125k down. Wash from 6711' and PU to 6705 ;pump 120psi ~ 130gpm and 53spm. Rotate C~3 15rpm and 2k torque; 37 turns to the right. Stop rotating and release torque; 1/2 turn to the left. PU to 155k, hold 5 min. Increase to 170k up, hold 5 min. PU to 187k; packer shears- SO to confirm set. Top of EZSV ~ 6707'. DECOMP Pump dry job and POOH, racking back DP from 6707' MD to surface. LD 8.5" string mill, float sub and setting tool. Mud in/out = 8.7ppg. DECOMP Service top drive and crown. rrmcea: oisizuua 23:Jb:3Z HNI • BP EXPLORATION Page 4 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task 'Code NPT -- _ __ _ '- 6/15/2009 10:30 - 14:30 4.00 DHB P 14:30 - 16:00 ~ 1.50 ~ DHB ~ P 16:00 - 17:30 1.50 ~ DHB ~ P 17:30 - 19:00 ~ 1.50 ~ DHB ~ P 19:00 - 20:30 I 1.501 DHB I P 20:30 - 21:30 I 1.001 DHB I P 21:30 - 22:00 0.501 DHB ~ P 22:00 - 23:30 I 1.501 DHB I P 23:30 - 00:00 I 0.501 DHB I P 16/16/2009 100:00 - 00:30 0.501 DHB P 00:00 - 02:30 2.501 DHB ~ P 02:30 - 03:00 0.50 DHB P 03:00 - 04:30 1.50 DHB P Phase Description of Operations DECOMP PJSM w/ SLB wireline unit. RU wireline to run second EZSV; second EZSV will be set above casing damage at 4300' and 5350'-5370'. RIH w/ EZSV on wireline from surface to 4200'. No problems while running in. PU to 4005' and set EZSV; top of EZSV ~ 4005'. DECOMP RD SLB wireline. Close blind rams and attempt to pressure test 9-5/8" casing and EZSV 04005' MD. Pressure up to 3500psi; pressure bled off. While PT, OA pressured up to 400psi, but bled off when the 9-5/8" casing was bled off. Attempt to pressure up a second time; pressure up to 3500psi; no good. Again, OA pressured up when testing, to 600psi. When 9-5/8" casing was bled down, the OA beld down to 250psi; was bled down the rest of the way to Opsi. DECOMP Call for RTTS tool to determine leak path in 9-5/8" casing. PU 4" drill pipe and rack back 6stands in derrick. DECOMP PJSM w/HES hand; RU RTTS tool and RIH on 4" DP. RIH to 2006' MD and set RTTS. Test below to 3500psi; pressure fell off immediately, and OA pressured up to 450psi. Bleed off; OA pressure fell off to 200psi, and had to be bled off. Test above RTTS to 3500psi; GOOD TEST. OA pressured up to 400psi while testing above RTTS, but bled off to Opsi once testing was completed. Release RTTS. DECOMP RIH to 2580' (this depth below the 9-5/8" FOCs C~ 2345' and 2469' MD). Set RTTS. Test below to 3500psi; GOOD TEST. No pressure on OA while testing. Test above RTTS to 3500psi; pressure fell off. OA pressured up to 500psi while testing, bled to 250psi when 9-5/8" was bled off, had to be bled off to Opsi. Release RTTS. DECOMP PU to 2388'; in-between two FOCs, so as to determine leak path. Test below to 3500psi; GOOD TEST. No pressure on OA while testing. Lower FOC at 2469' not open. Test above to 3500psi; pressure fell off. OA pressured up to 600psi, beld to 250psi once 9-5/8" was bled off, had to be bled off to Opsi. FOC ~ 2345' open to annulus. Release RTTS. DECOMP PU one stand to bring RTTS to 2293' to confirm leak location. Test above RTTS to 3500psi; GOOD TEST. OA pressured up to 425psi during testing, but bled off when 9-5/8" was bled off. Open FOC ~ 2345' MD confirmed. Release RTTS. DECOMP RIH from 2293' MD to just above EZSV ~ 3928'. 105k up, 100k down. DECOMP Displace to 9.8ppg brine from 8.7ppg brine. Displace C~3 215psi, 6bpm, 100spm. Losses to formation during RTTS testing and displacement = 80bbls. DECOMP Continue displacing to 9.8 ppg brine from 8.7 ppg brine at 247 gpm with 239 psi. DECOMP PJSM. POH from 3928' MD to 20.70' MD, racking back 4" DP. Monitor well prior to POH -static. Fluid loss during TOH: 70 bbls. DECOMP LD 9 5/8" Halliburton RTTS. DECOMP PJSM w/HES. RU Fas-Drill plug and setting tool. RIH w/ packer from surface to -2293' MD C~ 100fph. PU 3 stands of 6-1/4" drill collars and 3 stands of 5" HWDP in order to have adequate string weight for upcoming storm packer run. Printetl: 8/3/LOOy k3::iti::1L AM i ~ BP EXPLORATION Page 5 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 9ES Date ~, From - To ~ Hours ~~, Task Code NPT ___ _ _ 6/16/2009 104:30 - 05:30 1.00 DHB P 05:30 - 06:30 1.001 CASE ~ P 06:30 - 07:30 1.001 CASE P 07:30 - 08:30 ~ 1.00 ~ CASE ~ P 08:30 - 09:30 1.00 CASE P 09:30 - 12:00 2.50 CASE P 12:00 - 15:00 3.00 CASE P 15:00 - 17:30 2.50 DHB P 17:30 - 21:00 3.501 DHB ~ P 21:00 - 23:00 I 2.001 DHB I P 23:00 - 00:00 I 1.001 DHB I P 6/17/2009 100:00 - 01:00 I 1.001 DHB I P 01:00 - 03:00 I 2.001 DHB I P 03:00 - 07:30 4.501 DHB P 07:30 - 09:00 ~ 1.501 DHB I P 09:00 - 12:00 3.00 DHB P 12:00 - 14:30 2.50 DHB P Spud Date: 2/14/1979 Start: 6/4/2009 End: 7/15/2009 I Rig Release: 7/15/2009 Rig Number: Phase Description of Operations DECOMP POH and rack back pipe; LD Fas-Drill. Prep for RIH w/ FOC shifting tool DECOMP MU FO Closing Tool BHA with 3 stands 6 1/4" DC and 3 stands 5" HWDP. DECOMP RIH with FO Closing Tool from 564' MD to 2236' MD on 4" DP stands. DECOMP RIH with FO Closing Tool from 2236' MD to 2365' MD attempting to close FOC three times with no indication of success. PUW 100k, SOW 1OOk. Pressure test FOC to 1000 psi and bled off 50 psi in 5 minutes. DECOMP RIH with FO Closing Tool from 2336' MD to 3989' MD. PUW 105k. DECOMP Displace from 9.8 ppg brine to 8.5 ppg seawater at 195 gpm with 195 psi. DECOMP POH from 3989' MD to surface and LD FO Closing Tool BHA. Fluid loss while POH: 7 bbls. DECOMP PU Halliburton 9 5/8" RBP and RIH on 4" DP Stands to 2500' MD. PUW 80k, SOW 77k. Set RBP as follows: 3/4 left turn, set down 15k, PU 5k over pull to ensure set. No fluid loss noted after setting 9 5/8" RBP. DECOMP POH from 2500' MD to 854' MD. RIH to 2500' MD to retrieve 9 5/8" RBP. Encountered tight spot at 2440' MD with 20k drag. Attempt to pass through tight spot twice without success. Rotated at 10 rpm with 0.2k ft-Ibs torque and passed through tight spot with 77k SOW. Retrieve 9 5/8" RBP as follows: set down 15k, 1/4 left turn, PU 30' to ensure free. Fluid loss while RIH to retrieve RBP: 1 bbl. DECOMP POH with 9 5/8" RBP from 2500' MD to surface and LD RBP. Fluid loss while POH: 7 bbls. DECOMP PU 9 5/8" Halliburton RTTS and RIH on 4" DP stands in preparation to pressure test EZSV at 4005' MD. DECOMP PJSM. Continue to RIH with 9 5/8" RTTS to 2515' MD. PUW 80k, SOW 80k. Pump one DP annular volume at 3 bpm with 27 psi. Set RTTS with 1 right turn and 20k set down weight. RTTS set at 2518' MD. DECOMP Pressure test 9 5/8" EZSV at 4005' MD against 9 5/8" RTTS to 1000 psi for 10 charted minutes -good test. PU to 80k to release RTTS. POH and LD 9 5/8" RTTS. DECOMP PU 9 5/8" Halliburton RBP and RIH to 2500' MD. PUW 80k, SOW 80k. Set RBP with 1/2 left turn, slack off 65k and then picked up 85k. RBP set in place at 2500' MD. POH and LD 9 5/8" RBP running tool. DECOMP PU 9 5/8" Halliburton RTTS and RIH on 4" DP stands to 2388' MD, in order to pressure test RBP. PUW 80k, SOW 80k. Pump one DP annular volume at 3 bpm with 27 psi. Set RTTS with 1 right turn and 20k set down weight. RTTS set at 2388' MD. DECOMP Pressure test 9 5/8" RBP at 2500' MD against 9 5/8" RTTS to 1000 psi for 10 charted minutes -good test. PU to 80k to release RTTS and monitored well. POH and LD 9 5/8" RTTS. DECOMP PJSM. PU 9 5/8" Halliburton RBP retrieval tool, 6 1/2" Drill collars (x9), 5" HWDP (x9), and a XO. RIH on 4" DP stands to 2268' MD and PU 9 5/8" HES Storm Packer and one single Printed: 8/3/2009 8:36:32 AM s • BP EXPLORATION Operations Summary Report Page 6 of 28 Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABORS 9ES Rig Number: Date i From - To Hours ' Task Code NPT Phase I Description of Operations 6/17/2009 12:00 - 14:30 2.50 DHB P DECOMP joint of 4" DP. Set Storm Packer at 30' MD. 14:30 - 15:00 0.50 DHB P DECOMP Pressure test 9 5/8" HES Storm Packer from above to 1000 psi for 10 charted mintues -good test. 15:00 - 17:00 2.00 BOPSU P DECOMP PJSM. Drained the stack, nippled down the BOPE, and backed out the lock down screws on the lower spool. 17:00 - 18:00 1.00 WHSUR P DECOMP Pull the tubing spool, with the primary and secondary packoffs, "J"-into the packoff and pulled in 5k Ib increments. Tubing spool came free with 18-20k lbs. 18:00 - 20:30 2.50 WHSUR P DECOMP Installed the new tubing spool and ring gaskets. 20:30 - 22:30 2.00 BOPSU P DECOMP PJSM. Nippled up the BOPE. 22:30 - 23:30 1.00 WHSUR P DECOMP Pressure test new tubing spool breaks, by pumping against the RTTS at 30' and the blind rams, to 2000 psi for 10 charted minutes -good test. 23:30 - 00:00 0.50 WHSUR P DECOMP Installed the wear ring in the tubing spool - 8 9/16" ID. 6/18/2009 00:00 - 01:00 1.00 WHSUR P DECOMP PJSM. Service top drive -during the top drive inspection a sheared bolt and broken die were found and replaced on the back-up grabber. Both pieces of the broken die were accounted for. 01:00 - 02:00 1.00 DHB P DECOMP Picked up a single joint of 4" DP, torqued the full-opening safety valve to the top, and the HES Storm Packer retrieval tool to the bottom and RIH. Engage storm packer with 20 turns to the right to open float valve. Slowly open safety valve at top of assembly, DP was on a slight vacuum for 5 seconds. Release the storm packer, picked up and LD same. No debris found on Storm Packer. 02:00 - 04:30 2.50 DHB P DECOMP RIH from 2268' MD to 2459' MD. PUW 103k, SOW 103k. Continue RIH and tag Halliburton 9 5/8" RBP at 2500' MD. Engage RBP by setting 20k down weight. Pull 10k over to confirm RBP engaged. Set down 20k and applied 1/2 surface turn to the right. Pull 10k over to release tool. POH to 2480' MD with no overpull and RIH to 2520' MD with no loss in surface weight -RBP released. 04:30 - 05:00 0.50 DHB P DECOMP RIH from 2520' MD to 3885' MD Qust above 9 5/8" EZSV at 4005' MD). 05:00 - 06:00 1.00 DHB P DECOMP Displace annulus from 4005' MD to 2100' MD from 8.5 ppg to 9.8 ppg brine in preparation for the 9 5/8" cut and pull operation at 318 gpm with 276 psi. Full annular column of 9.8 ppg brine would have increased the hydrostatic pressure at the leaking upper FOC at 2338' MD. Monitor well -static. 06:00 - 08:00 2.00 DHB P DECOMP POH from 3885' MD to 566' MD filling up the hole with 8.5 ppg seawater. MW in /out 8.5 ppg. 08:00 - 09:30 1.50 DHB P DECOMP Continue to POH from 566' MD standing back HWDP and DC. LD RBP and retrieval tool. 09:30 - 10:00 0.50 STCTPL P DECOMP Change out elevators and finish LD Baker tools. Clean and clear rig floor. 10:00 - 11:00 1.00 BOPSU P DECOMP Pull wear ring, install upper test plug with 4" test joint and floor valve assembly in preparation for BOP test. Fill lines with H2O. 11:00 - 15:30 4.50 BOPSU P DECOMP Test BOP equipment to 250psi low, 3500psi high for 5min each; chart all tests. AOGCC rep John Crisp waived witness of BOP test. Test witnessed by WSL Blair Neufeld and Nabors TP Bill Bixby. Test using 4" test joint; good test. 15:30 - 16:30 1.00 BOPSU P DECOMP Pull test plug and install wear ring 8 9/16 ID. Blow down all test equipment. Printed: 8/3/2009 8:36:32 AM • BP EXPLORATION Operations Summary Report Page 7 of 28 ~ 'Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To 3-03 3-03 REENTE NABOR NABOR Hours R+COM S ALAS S 9ES Task PLET KA DRI Code E LLING NPT Start I Rig Rig Phase Spud Date: 2/14/1979 : 6/4/2009 End: 7/15/2009 Release: 7/15/2009 Number: Description of Operations 6/18/2009 16:30 - 18:00 1.50 STCTPL P DECOMP Make up 8 1/4" Baker multi string cutter assembly with: 8 1/4" Multi String cutter, XO Sub, 8 1/2" Bladed Stabilizer, 9 6-1/2" Drill Collars, 9 5" HWDP, XO Sub. 18:00 - 20:30 2.50 STCTPL P DECOMP RIH from 563' MD to 2225' MD on 4" DP stands. PUW 100k, SOW 100k. Pump at 178 gpm with 350 psi to open knives. With knives open, slowly RIH to locate collar. Find collar at 2239' MD with 13k down weight. Shut pumps off to close knives. Pick up 1' and RIH pass collar at 2239' MD without tagging -knives closed. Lay down 2 singles and pick up 15' pup to allow cutting point 19' above collar at 2218' MD while spotting and RU Little Red Services. Obtain parameters: 100k ROTW at 40 rpm with 0.73k ft-Ibs torque. 20:30 - 21:00 0.50 STCTPL P DECOMP Rotate at 40 rpm with 0.7k ft-Ibs torque and slowly bring pumps on to open knives as follows: GPM PSI Torque 166 355 1.4k 171 410 2.2k 191 525 2.6k 230 230 0.6k (casing cut) Positive indication that 9 5/8" casing was cut with a pressure drop of 295 psi and a decrease in torque of 2.Ok ft-Ibs. Shut pumps down to close knives and pick up to 2216.3' MD. Bring pumps on at 149 gpm with 300 psi. RIH to cut point at 2218' MD while pumping and saw pressure drop of 116 psi at cutting point. Establish circulation through the cut up the 13 3/8" x 9 5/8" annulus at 2.3 bpm with 184 psi and saw returns at the open top tank. 70% of returns were Artic Pack and rest were diesel. 21:00 - 00:00 3.00 STCTPL P DECOMP Spot 21 bbls of 130 deg F hot diesel down drillpipe to the cut point at 2918' MD as follows: 0.5 bbls away at 1.7 bpm with 100 psi 13 bbls away at 1.7 bpm with 200 psi 21 bbls away at 1.7 bpm with 200 psi 6/19/2009 00:00 - 02:30 2.50 STCTPL P DECOMP With the hot diesel at the cut point (2218' MD), open the annular valve and close the bag on the 4" DP. Establish circulation through the cut up the 13 3/8" x 9 5/8" annulus by pumping 101 bbls of 130 deg F diesel. Approximately 50 bbls of Arctic Pack were circulated out, rest of returns were diesel. Stopped pumping diesel after Arctic Pack stopped coming out of annulus and clean diesel returns were observed. Pump 101 bbls of 130 deg F diesel down drillpipe to the cut point at 2918' MD as follows: Resume pumping with 200 psi at 1.8 bpm. 26 bbls away at 1.8 bpm with 300 psi 101 bbls away at 1.8 bpm with 100 psi Allow diesel to soak for 1 hour as per MI Swaco Mud Engineer. Printed: 8/3/2009 8:36:32 AM • BP EXPLORATION Page 8 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task I Code'. NPT Phase Description of Operations __.. __ -_ 6/19/2009 02:30 - 05:00 2.50 STCTPL P DECOMP Switch over to rig pump and pumped 43 bbl, 9.8 ppg brine, hi-vis sweep with 3 sacks Flowzan, followed by 28 bbls of fresh water with 1 drum of Safe-Surf-O, followed by 44 bbl, 9.8 ppg brine, hi-vis sweep with 3 sacks Flowzan. Chased sweeps by circulating 250 bbls of 9.8 ppg brine at 8 bpm and 1614 psi, taking returns to the open top tank to clean up diesel. 05:00 - 07:00 2.00 STCTPL P DECOMP PJSM. Layed down the 15' drilling sub and picked back up the 2 singles that were layed down before making the cut. POH from 2218' MD to 563' MD, standing back the 4" DP. 07:00 - 08:30 1.50 STCTPL P DECOMP POH and stand back 3 stands of HWDP and 3 stands of DC. LD the 8 1/4" Baker multi-string cutter, XO, and 8 1/2" stabilizer. Clean and cleared the rig floor. 08:30 - 10:00 1.50 BOPSU P DECOMP Pulled wear bushing and installed test plug. Changed out the upper rams to 9 5/8". 10:00 - 11:00 1.00 BOPSU P DECOMP Pressure tested rams to 250 psi low and 3500 psi high for 5 charted minutes each -good test. Pulled test plug and LD 9 5/8" test joint. 11:00 - 15:00 4.00 STCTPL P DECOMP PJSM with Baker fishing hand. MU 9 5/8" casing spear assembly; 4 1/2" IF Bull nose, 9 5/8" 47# Spear pack-off, ITCO spear, 4 1/2" spear extension, 10 3/4" spear stop sub, XO sub back to 4" HT40. Rigged up 9 5/8" casing running equipment on the floor. Speared the 9 5/8" casing below the hanger and pulled 170k Ibs to free the casing, after pulling the casing free the PU weight was 135k lbs. Pulled the hanger above the floor, broke out and LD the 9 5/8" casing hanger. Hanger connection broke free with -44k ft-Ibs of torque. The rig tongs did crush/egg the hanger pup slightly at that break-out torque. LD the 9 5/8" casing spear assembly and rigged up the crossover and headpin to cementing line. 15:00 - 17:00 2.00 STCTPL P DECOMP PJSM with Little Red Hot Oil Service. Rigged up LRHOS to the cement line and pumped 5 bbls of diesel to fill the lines. Pressure tested the lines to 2500 psi -good test. Established circulation and began pumping 130 deg F diesel down the 9 5/8" casing, taking returns through the 13 3/8" x 9 5/8" annulus and out to the open top tank. Pumped a total of 140 bbls of 130 deg F diesel as follows: 20 bbls away at 2 bpm and 250 psi. 60 bbls away at 2 bpm and 350 psi. 100 bbls away at 2 bpm and 400 psi. 140 bbls away at 2 bpm and 400 psi. 17:00 - 18:00 1.00 STCTPL P DECOMP Switched over to rig pumps and chased hot diesel with 40 bbl, 9.8 brine, high-vis sweep followed by 250 bbls of 9.8 brine at 11.5 bpm and 1500 psi taking returns to the open top tank. Pumped until the diesel was displaced, recovered a small amount of Arctic Pack with the diesel. 18:00 - 19:30 1.50 STCTPL P DECOMP Built and pumped a 40 bbls Safe-Surf-O pill and chased it with 360 bbls of 9.8 brine at 11.5 bpm and 1500 psi taking the returns to the cuttings tank. Recovered some Arctic Pack back Nnntea: ai~rzuua C:Jb:JZ HM BP EXPLORATION Page 9 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABOBS 9ES Rig Number: Date From - To I Hours ~' Task Code NPT Phase Description of Operations 6/19/2009 18:00 - 19:30 1.50 STCTPL P DECOMP to surface, pumping until the returns cleared up. 19:30 - 20:30 1.00 STCTPL P DECOMP PJSM with Nabors Casing; emphasized tong safety and PPE for dealing with Arctic Pack. Rigged down the 9 5/8" pump-in assembly and rigged up to pull and LD 9 5/8" casing. 20:30 - 00:00 3.50 STCTPL P DECOMP Pull and LD 12 jts of 9 5/8", 47#, casing. The first joint of casing pulled very easy with no hang-ups, PU weight was 130k lbs. The exterior of the casing showed no noticable signs of corrosion. There was still quite a bit of Arctic Pack stuck on the casing, however, the rig crew was able to wipe most of it off using a tong pull-back rubber and sorbant. The connections broke out between 40-46k ft-Ibs, with the tongs crushing/egging the majority of the casing tubes. There were bow spring centraiizers located on the bottom of jts. 7 and 12. 6/20/2009 00:00 - 09:30 9.50 STCTPL P DECOMP Continue to pull and LD 9 5/8", 47# casing. The connections break out between 40-46k ft-Ibs, with the tongs crushing/egging the the casing tubes. Total of 55 joints recovered, one cut off joint (18.70') and 10 bow spring centralizers. 09:30 - 13:00 3.50 STCTPL P DECOMP Clean and clear rig floor and pipeshed from diesel and Arctic Pack residual from 9 5/8" cut and pull operations. 13:00 - 14:00 1.00 STCTPL P DECOMP Pick up 9 5/8" Baker Spear, service break it, and lay down. 14:00 - 15:00 1.00 STCTPL P DECOMP Flush stack with hot fresh water (120 deg F) mixed with 15 gallons Safe-Surf-O. 15:00 - 16:00 1.00 STCTPL P DECOMP Change upper pipe rams from 9 5/8" to 3 1/2" x 6" variable rams. 16:00 - 16:30 0.50 STCTPL P DECOMP RU testing equipment and test upper variable rams with 4" test joint to 3500 psi High / 250 psi Low for 5 minutes and chart - good test. 16:30 - 17:00 0.50 STCTPL P DECOMP RD testing equipment. Install 12 7/16" wear ring. 17:00 - 20:30 3.50 STCTPL P DECOMP MU 9 5/8" Dressing BHA #13 with the following components: 12 1/8" x 9 5/8" Dress Off Shoe, 11 3/4" Wash Pipe Extension, 9 5/8" Inner Dressing Mill, 11 3/4" Washover Boot Basket, double pin sub, 13 3/8" Casing Scraper, bit sub, string float, bumper sub, 9 6-1/2" Drill Collars, 9 5" HWDP and XO. 20:30 - 21:30 1.00 STCTPL P DECOMP Ream down with 9 5/8" Dressing BHA #13 from 682' MD to 953' MD with the following parameters: 506 gpm, 410 psi, 30 rpm, 980 ft-Ibs torque, 80k ROTW. MW in /out 9.5 ppg 120 deg F. Clean returns of 9.5 ppg brine from 682' MD to 857' MD with very small traces of Artic Pack. 50% increase of Artic Pack returns from 857' MD to 953' MD. 21:30 - 00:00 2.50 STCTPL P DECOMP Rapid decrease in surface pump pressure of 162 psi while pumping at 530 gpm followed by metal-to-metal cling-like noise heard on DP and pumps. Shut both pumps down and inspect surface equipment -okay. Continue to ream down with one pump while inspecting the other pump. Ream down with one pump at 249 gpm with 86 psi, rotating at 30 rpm with 980 ft-Ibs torque from 953' MD to 1084' MD while inspecting suction pods, discharge cylinders, pulsation dampers, charge pumps and suction chambers -all equipment seems to be in good condition. Decrease in Artic Pack returns (-30% of returns). 6/21/2009 00:00 - 02:00 2.00 STCTPL P DECOMP PJSM. Continue to ream down from 1084' MD to 1445' MD with one pump at 257 gpm with pressure fluctuating from 70 psi rnrnea: w~~uua °:~°:~~ Nm • • BP EXPLORATION Page 10 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date II From - To Hours I~ Task Code NPT Spud Date: 2/14/1979 Start: 6/4/2009 End: 7/15/2009 Rig Release: 7/15/2009 Rig Number: Phase Description of Operations 6/21/2009 00:00 - 02:00 2.00 STCTPL P DECOMP to 120 psi. Rotating at 30 rpm with 743 ft-Ibs torque. Low amounts of Arctic Pack seen across shakers. Continue to inspect surface equipment. 02:00 - 04:00 2.00 STCTPL P DECOMP Switch suction pit from pit #1 to pit #2. Continue to ream down from 1445' MD to 2000' MD with both pumps on at 506 gpm with 549 psi and rotating at 30 rpm with 692 ft-Ibs torque. 100% increase in Acrtic Pack returns at 1643' MD, slow down reaming speed accordingly to ensure good casing cleaning until shakers clean up. Continue to ream down from 1445' MD to 2200' MD with no issues. 04:00 - 05:00 1.00 STCTPL P DECOMP Picked up stand #18 of 4" DP and eased down with the pumps off. PU/SO/Rot =100k lbs. Tagged top of stump 17' in, at 2218' MD. Picked up several feet and established milling parameters: PU/SO/ROt =100k Ibs, 40 rpm, for -1.2k ft-Ibs, 208 spm, 509 gpm, 696 psi. Eased down and torque increased, 8-10k, increased rpms to 65 and slowed desent to keep torque under 5k ft-Ibs. Tagged top of stump and eased guide shoe over with 3-6k ft-Ibs torque and no noticable weight on bit. Continued to wash down over top of stump 7.5 ft and engaged mill. 05:00 - 06:30 1.50 STCTPL P DECOMP 06:30 - 07:30 1.00 STCTPL P DECOMP 07:30 - 10:00 2.50 STCTPL P DECOMP 10:00 - 12:30 2.50 STCTPL P DECOMP 12:30 - 14:30 2.00 STCTPL P DECOMP 14:30 - 16:00 1.50 STCTPL P DECOMP 16:00 - 19:00 3.00 STCTPL P DECOMP 19:00 - 20:30 1.50 STCTPL P DECOMP Began milling on 9 5/8" casing stub; WOB 8-10k Ibs, for 3.4-5.2k ft-Ibs, 60 rpms, 509 gpm, 742 psi. Continued milling for 20 min, milling down -4". Circulated a bottoms up at 563 gpm and 825 psi. Picked up and stood back one stand of 4" DP and pumped a 40 bbl Safe-Surf-O and fresh water pill. Chased that pill with 10 bbls of brine and a 45 bbl high-vis sweep. Pumped 400 bbls of 9.6 ppg brine at 560 gpm and 760 psi . Pulled out of the hole from 2199' to 588' MD, standing back the 4" DP. Stood back 3 stand of 5" HWDP and 3 stands of 6-1/2" DC in the derrick and LD BHA #13, 9 5/8" Dress-off ass'y with a 13 3/8" casing scraper. Good indication of dressing on the casing stump was noticed on the inner mill.. Pick up and make up BHA #14, 9 5/8" Clean out ass'y, as follows: 8 1/2" Window mill (5 #20 jets), 8 3/8" Lower mill, 5" Flex jt., 8.510" Upper mill, string float, (9) 6 1/2" DC, (9) 5" HWDP, and a XO. Total length of BHA #14 is 578.96'. RIH with BHA #14, Clean out ass'y, on 4" DP picking up 52 singles out of the pipe shed. Tagged the 9 5/8" stump at 2218', Set down on the stump two times with 5k Ibs, rotated the pipe to the right one full turn and the mill entered the stump. Continued to run in to 2319' MD picking up 3 more singles from the pipe shed for a total of 55 singles. PU/SO = 100k lbs. Serviced top drive, crown, and drawworks. Slip and cut 104' of drilling line. Continued to RIH with BHA #14, Clean out ass'y, picking up 23 more singles from the pipe shed for a total of 78 jts. Tagged the 9 5/8" EZSV at 4006'. PU = 125k Ibs, SO = 100k lbs. Circulated a 40 bbl High-vis, pill followed by 540 bbls of 9.6 brine at 500 gpm and 1210 psi while reciprocating the pipe in Printetl: 8/3/2009 8:36:31 AM • BP EXPLORATION Page 11 of 28 Operations Summary Report 6/21/2009 19:00 - 20:30 1.50 STCTPL P DECOMP 90' strokes. 20:30 - 22:00 1.50 STCTPL P DECOMP Pulled out of the hole from 4006' to 566' MD, standing back the 4" DP. 22:00 - 00:00 2.00 STCTPL P DECOMP Stood back the 3 stands of 5" HWDP and the 3 stands of 6 1/2" DC. LD BHA #14, Clean out ass'y, as one piece to save time when PU the whipstock BHA. 6/22/2009 00:00 - 02:30 2.50 STWHIP P WEXIT PJSM. Pick up and make up BHA #15, 9 5/8" Whipstock, as follows: 4 1/2" Stinger, Whipstock anchor (pinned with 4 shear screws -26k Ibs and shipping bolt removed), Whipstock, 8 1/2" Window mill (5 #20 jets), 8 3/8" Lower mill, 5" Flex jt., 8.510" Upper mill, (1) jt 5" HWDP, Non-mag XO, MWD, UBHO sub, (9) 6 1/2" DC, (9) 5" HWDP, XO, Float sub w/float. Total length of BHA #15 is 666.49'. 02:30 - 05:30 3.00 STWHIP P WEXIT RIH with Whipstock BHA #15 on 4" DP stands from 666' to 760' MD. Shallow test MWD at 760' MD at 550 gpm with 980 psi -good test. Blow down kill line and install air slips. Continue RIH from 760' MD to 3902' MD. Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABORS 9ES Rig Number: Date From - To ~' Hours ' Task Code NPT Phase Description of Operations NOTE: Tag at 9 5/8" casing stump with upper mill with 20k Ibs at 2242' MD. Picked up 10' and rotated string 1/2 turn to the right. RIH through stump with no further issues. 05:30 - 06:30 1.00 STWHIP P WEXIT Orient whi stock 57 de ri ht of hi h side while pumping at 500 gpm with 1580 psi, PUW 127, SOW 125k. Tag 9 5/8" EZSV at 4006' MD and SO 26k to set bottom tri anchor. Pick up to confirm anchor set and saw 10k Ibs overpull -anchor set. SO 45k Ibs to shear mills from whipstock assembly. Picked up and confirmed mills had sheared from whipstock assembly. 06:30 - 08:00 1.50 STWHIP P WEXIT Pump 50 bbl Hi-Vis Spacer (fresh water and 6 sacks of Flowzan). Displace well from 9.5 ppg brine to 9.2 ppg LSND Milling Fluid. 08:00 - 08:30 0.50 STWHIP P WEXIT r test 13 3/8" x 9 5/8" casin to 2000 si for 10 minutes - ood test. 08:30 - 12:30 4.00 STWHIP P WEXIT Mill 8 1/2" window in 9 5 8" casing wit the o owing parameters: 500 gpm, 1083psi, 90 rpm, 2-3k ft-Ibs torque, ROTW 118k. ~ ~ -Q ~ Top of Window: 3980' MD ~ Bottom of Window: 3997' MD Whipstock oriented 57 deg right of high side Cement found behind 9 5/8" casing 12:30 - 13:30 1.00 STWHIP P WEXIT ump i- is weep at 500 gpm with 1014 psi while rotating at 40 rpm with 1.2k ft-Ibs torque. 20% increase in steel returns with return of Hi-Vis Sweep. 13:30 - 15:00 1.50 STWHIP P WEXIT Monitor well -static. POH from 3997' MD (bottom of window) to 2217' MD (above 9 5/8" casing stump). PUW 130k, SOW 120k. MW in /out 9.2 ppg. 15:00 - 16:00 1.00 STWHIP P WEXIT Pump 30 bbl Hi-Vis Sweep at 643 gpm with 1111 psi while reciprocating with no rotation. No significant increase in cuttings returns. 16:00 - 16:30 0.50 STWHIP P WEXIT Service Top Drive. 16:30 - 17:30 1.00 STWHIP P WEXIT RIH from 2217' MD to 3971' MD with Window Milling BHA #15. NOTE: Tagged 9 5/8" casing stump, picked up and rotated string 1 full turn to the right, RIH through stump with no further Printed: 8/3/2009 8:36:32 AM BP EXPLORATION Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date From - To '. Hours Task Code NPT 6/22/2009 16:30 - 17:30 1.00 STWHIP P 17:30 - 19:00 1.50 STWHIP P Start: 6/4/2009 Rig Release: 7/15/2009 Rig Number: Phase Page 12 of 28 Spud Date: 2/14/1979 End: 7/15/2009 Description of Operations WEXIT issues. WEXIT Wash down from 3971' MD to 3997' MD at 4 bpm with 313 psi. Drill new formation from 3997' MD to 4022' MD at 500 gpm with 1240 psi while rotating at 90 rpm with 3k ft-Ibs torque, 4k - 8k Ibs weight on mills. Work mills through window several times with and without rotation, with pumps on and off, no drag seen. Average milling ROP through casing = 4.42 fUhr NOTE: The 8 1/2" upper mill stopped at 4002' MD providing 5' of 8 1/2" gauge hole from the bottom of the window. 19:00 - 20:30 1.50 STWHIP P WEXIT Circulate 1.5 bottoms up at 604 gpm with 1693 psi while reciprocating and rotating at 10 rpm with 1 k ft-Ibs torque. Clear indications of cement with bottoms up with no significant increase in metal cuttings. 20:30 - 21:30 1.00 STWHIP P WEXIT Pull Window Milling BHA #15 inside 9 5/8" casing at 3969' MD and perform FIT to EMW of 10.8 ppg with 9.2 ppg LSND milling fluid in the hole at a de th of 3916' TVD, 325 si surface ressure. 21:30 - 22:00 0.50 STWHIP N HMAN WEXIT Pump dryjob and POH from 3969' MD to 2784' MD. MW in / out 9.2 ppg. 22:00 - 22:30 0.50 STWHIP N HMAN WEXIT RIH from 2784' MD to 3962' MD. 22:30 - 23:00 0.50 STWHIP N HMAN WEXIT Circulate dryjob out in preparation for LOT at 14 bpm with 1651 psi for a total of 431 bbls pumped. 23:00 - 00:00 1.00 STWHIP N HMAN WEXIT Perform LOT to EMW of 13.03 ppg with 9.2 ppg LSND mud in 6/23/2009 00:00 - 02:30 2.50 STWHIP P ~, 02:30 - 05:00 2.50 STWHIP P 05:00 - 07:00 2.001 STWHIP P 07:00 - 09:30 2.501 STWHIP P 09:30-12:00 ~ 2.50~STWHIP~P 12:00 - 12:30 0.50 STWHIP P 12:30 - 13:00 0.50 STWHIP P 13:00 - 14:30 1.50 STWHIP P 14:30 - 17:00 I 2.501 DRILL I C surface pressure of 780 psi. WEXIT POH from 3962' MD to 389' MD. MW in /out 9.2 ppg. WEXIT LD Window Milling BHA #15. All mills in full gauge. Clean and clear rig floor. WEXIT Pull wear bushing. MU ported sub, blow down choke and kill lines, fush BOP Stack, function all rams. Install 12 7/16" wear ring. WEXIT MU 8 1/2" Drillin BHA #16 with the following components: 8 1/2" DTX-619M-D6 Hycalog PDC Bit, 6 3/4" 1.83 deg Mud Motor, ARC6 LW D, PowerPulse, NM Stabli2er, UBHO, 3 NM Flex Collar, Float Sub, Hydraulic Jars, 8 jts 5" HWDP. WEXIT RIH with 8 1/2" Drilling BHA #16 on 4" DP stands from 453' MD to 2065' MD. Shallow test MWD at 2065' MD at 453 gpm with 803 psi. Continue to RIH from 2065' MD to 2218' MD. Tag 9 5/8" casing stump with 3k Ibs, pick up and rotate 1/4 turn to the n t, slack o f and tag casing stump again with 3k Ibs, rotate 1/4 turn to the right while holding 3k Ibs on casing stump and BHA passed through. Continue to RIH from 2218' MD to 3306' MD. PUW 104k, SOW 98k. WEXIT RU to run Gyro in preparation to orient drilling BHA #16 WEXIT RIH with 8 1/2" Drilling BHA #16 from 3306' MD to 3700' MD. WEXIT Log for tie-in purposes from 3700' MD to 3820' MD at 400 fUhr while pumping at 450 gpm with 1083 psi for real. time data. Log without pumping at 600 fUhrfrom 3820' MD to 3977' MD in recording mode. INT1 RIH from 3977' MD to 4021' MD with no drag seen while going through 9 5/8" casing window. Drill ahead 8 1/2" hole from 4021' MD to 4168' MD. Printetl: 8/3/2009 8:36:32 AM BP EXPLORATION Page 13 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours I Task Code NPT Phase '; Description of Operations 6/23/2009 14:30 - 17:00 2.50 DRILL C INT1 - 550 gpm, 1445 psi on, 1420 psi off - 5k-10k WOB, 40 rpm, 3k-4k ft-Ibs torque on, 2k ft-Ibs torque off - ADT 1.09 hrs, ART 0.22 hrs, AST 0.87 hrs, Bit 1.09 hrs, Jars 1.09 hrs -Added 290 bbls of 9.2 ppg LSND 15 YP to dilute the high yield milling fluid from 31 YP to 25 YP while adding water at 10 bph. - No fluid loss noted. - MW in /out - 9.2 ppg magnetic interference, need to RIH with gyro to obtain survey. 17:00 - 18:30 1.50 DRILL N SFAL INTi PU Gyro and RIH. Unable to get Gyro depth due to Depth Control Software failure. Re-install Depth Control Software several times while inspecting Gyro unit. Depth Control Software working fine after several installations. 18:30 - 19:30 1.00 DRILL C INTi Continue to RIH with Gyro and sting in to UBHO Sub at 4076' MD. Take survey and POH with Gyro. 19:30 - 20:00 0.50 DRILL C INT1 POH from 4168' MD to 4076' MD and install 8 1/2" Ghost Reamer. Top of Ghost Reamer: 4079.88' away from the bit. Bottom of Ghost Reamer: 4073.25' away from the bit. RIH from 4076' MD to 4168' MD. 20:00 - 21:00 1.00 DRILL C INT1 Drill ahead 8 1/2" hole from 4168' MD to 4270' MD. - 550 gpm, 1465 psi on, 1402 psi off - 5k-10k WOB, 40 rpm, 3k-4k ft-Ibs torque on, 2k ft-Ibs torque off - ADT 0.45 hrs, ART 0.18 hrs, AST 0.27 hrs, Bit 1.54 hrs, Jars 1.54 hrs -Adding water at 10 bph. - No fluid loss noted. - MW in /out - 9.2 ppg MW D survey fails Field Acceptance Criteria (FAC) due to ma netic interference, need to RIH with gyro to obtain survey. 21:00 - 22:30 1.50 DRILL C INT1 PU Gyro and RIH to UBHO at 4178' MD. Sting in Gyro to UBHO, take survey and POH. 22:30 - 23:30 1.00 DRILL C INT1 Drill ahead 8 1/2" hole from 4270' MD to 4366' MD. - 550 gpm, 1800 psi on, 1434 psi off - 5k-15k WOB, 40 rpm, 4k-5k ft-Ibs torque on, 2k ft-Ibs torque off - 120k PUW, 115k SOW, 110k ROT Wt - ADT 0.37 hrs, ART 0.10 hrs, AST 0.27 hrs, 1.91 Bit hrs, Jars 1.91 hrs - Adding water at 10 bph. - No fluid loss noted. - Calculated ECD 9.53 ppg, Actual ECD 9.77 ppg - MW in /out - 9.2 ppg MWD survey fails Field Acceptance Criteria (FAC) due to magnetic interference; however, surveys show tendency towards the Acceptance range. Need to RIH with gyro to obtain survey. P~nletl: 8/3/"LVV9 tl:3ti:J"L AM i BP EXPLORATION Page 14 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date From - To ll Hours Task 'Code NPT 6/23/2009 23:30 -00:00 I 0.50 DRILL P 6/24/2009 00:00 - 01:00 ( 1.00 ~ DRILL ~ C 01:00 - 02:00 I 1.001 DRILL I C 02:00 - 03:30 1.501 DRILL C 03:30 - 04:30 1.00 DRILL C 04:30 - 05:00 0.50 DRILL C 05:00 - 12:00 7.00 DRILL C 12:00 - 00:00 12.00 DRILL C 16/25/2009 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ P Spud Date: 2/14/1979 Start: 6/4/2009 End: 7/15/2009 Rig Release: 7/15/2009 Rig Number: Phase Description of Operations INT1 PU Gyro and RIH to UBHO at 4274' MD. Sting in Gyro to UBHO, take survey and POH. INT1 Continue to RIH with Gyro to UBHO at 4274' MD. Sting Gyro into UBHO, take survey and POH. INT1 Drill ahead 8 1/2" hole from 4366' MD to 4461' MD. - 550 gpm, 1580 psi on, 1440 psi off - 5k-10k WOB, 40 rpm, 3k-4k ft-Ibs torque on, 2k ft-Ibs torque off - 120k PUW, 115k SOW, 115k ROT Wt -Adding water at 10 bph - No fluid loss noted. - Calculated ECD 9.44 ppg, Actual ECD 9.65 ppg - MW in /out - 9.2 ppg INT1 PU Gyro and RIH to UBHO at 4369' MD. Sting Gyro into UBHO, take survey and POH. INT1 Drill ahead 8 1/2" hole from 4461' MD to 4557' MD. - 550 gpm, 1640 psi on, 11460 psi off - 10k-15k WOB, 60 rpm, 4k-5k ft-Ibs torque on, 2.2k ft-Ibs torque off - 121k PUW, 115k SOW, 115k ROT Wt -Adding water at 10 bph - No fluid loss noted. - Calculated ECD 9.40 ppg, Actual ECD 9.64 ppg - MW in /out - 9.2 ppg NOTE: First ood MWD surve obtained. INTi RD Gyro unit. INT1 Drill ahead 8 1/2" hole from 4557' MD to 5225' MD. - 550 gpm, 1810 psi on, 1530 psi off - 10k-15k WOB, 60 rpm, 4k-5k ft-Ibs torque on, 2.2k ft-Ibs torque off - 127k PUW, 116k SOW, 115k ROT Wt -ADT 4.27 hrs, ART 1.85 hrs, AST 2.42 hrs, Bit 6.18 hrs, Jars 6.18 hrs -Adding water at 25 bph. Pumped Hi Vis Sweep at 4586' MD, no significant increase in cuttings with return of sweep. - No fluid loss noted. - Calculated E D 9.40 ppg, Actual ECD 9.59 ppg - MW in /out - 9.2 ppg INT1 Drill ahead 8 1/2" hole from 5225' MD to 6784' MD. - 580 gpm, 2463 psi on, 2168 psi off - 15k-25k WOB, 80 rpm, 5k-7k ft-Ibs torque on, 5k ft-Ibs torque off - 152k PUW, 125k SOW, 135k ROT Wt -ADT 6.76 hrs, ART 4.54 hrs, AST 2.22 hrs, 12.94 Bit hrs, Jars 12.94 hrs -Adding water at 25 bph. Pumped Hi Vis Sweep at 5703' MD and 6658' MD, no significant increase in cuttings with return of sweeps. - No fluid loss noted. - Calculated ECD 9.40 ppg, Actual ECD 9.59 ppg - MW in /out - 9.2 ppg INT1 Drill ahead 8 1/2" hole from 6784' MD to 8187' MD. Nnnted: aisizuua t3::tti::t~ Hm ~J BP EXPLORATION Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I ',Rig Name: NABOBS 9ES Date ~ From - To I! Hours Task Code NPT 16/25/2009 00:00 - 12:00 ~ 12.00 DRILL P 12:00 - 00:00 12.001 DRILL ~ P Page 15 of 28 ~ Spud Date: 2/14/1979 Start: 6/4/2009 End: 7/15/2009 Rig Release: 7/15/2009 Rig Number: Phase Description of Operations INTi - 580 gpm, 3080 psi on, 2710 psi off - 20k-25k WOB, 80 rpm, 7k-8k ft-Ibs torque on, 5k ft-Ibs torque off - 170k PUW, 135k SOW, 146k ROT Wt -ADT 8.23 hrs, ART 5.43 hrs, AST 2.80 hrs, 21.17 Bit hrs, Jars 21.17 hrs -Adding water at 25 bph. Pumped Hi Vis Sweep at 7614' MD, 10% increase in cuttings with return of sweep. - No fluid loss noted. - Calculated ECD 9.52 ppg, Actual ECD 10.54 ppg - MW in /out - 9.4 ppg INT1 Drill ahead 8 1/2" hole from 8187' MD to 9335' MD. - 580 gpm, 3280 psi on, 3110 psi off - 20k-25k WOB, 80 rpm, 8k-10k ft-Ibs torque on, 8k ft-Ibs torque off - 201 k PUW, 140k SOW, 162k ROT Wt -ADT 8.4 hrs, ART 4.57 hrs, AST 3.83 hrs, Bit 29.57 hrs, Jars 29.57 hrs -Adding water at 30 bph - No fluid loss noted. - Calculated ECD 9.54 ppg, Actual ECD 10.38 ppg, prior to adding Spike Fluid - MW in /out - 9.4 ppg Started to slowly add 11.6 ppg spike fluid at 9335' MD to raise mud weight from 9.4 ppp to 10.3 ppg in preparation to drill 16/26/2009 100:00 - 12:00 12.00 ~ DRILL ~ P 12:00 - 00:00 ~ 12.00 ~ DRILL ~ P INT1 Drill ahead 8 1/2" hole from 9335' MD to 9908' MD. - 580 gpm, 3663 psi on, 3480 psi off - 20k-25k WOB, 80 rpm, 9k-10.5k ft-Ibs torque on, 9k ft-Ibs torque off - 227k PUW, 148k SOW, 148k ROT Wt -ADT 8.25 hrs, ART 5.53 hrs, AST 2.72 hrs, Bit 37.82 hrs, Jars 37.82 hrs -Adding water at 15 bph - No fluid loss noted. - Calculated ECD 10.53 ppg, Actual ECD 11.01 ppg - MW in /out - 10.3 ppg Mud weight of 10.3 ppg in and out was achieved at -9500' MD after 3 full circulations and with a total of 290 bbls of spike fluid and -400 sacks of MI-Wate (barite). Continue to drill with intermittent stick and slip of up to 200% with no recorded shocks to MWD or ARC. INT1 Drill ahead 8 1/2" hole from 9908' MD to 10350' MD. - 580 gpm, 3680 psi on, 3440 psi off - 25k-30k WOB, 80 rpm, 9k-9.5k ft-Ibs torque on, 8.5k ft-Ibs torque off - 215k PUW, 146k SOW, 168k ROT Wt -ADT 9 hrs, ART 3.9 hrs, AST 5.1 hrs, Bit 46.82 hrs, Jars 46.82 hrs -Adding water at 15 bph - No fluid loss noted. rnmeo: °iaiLUUa °:JD:SL HNI BP EXPLORATION Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date ~~ From - To ~I Hours Task Code NPT 6/26/2009 12:00 - 00:00 12.00 DRILL P 6/27/2009 100:00 - 06:30 I 6.501 DRILL I P 06:30 - 08:00 I 1.501 DRILL I P 08:00 - 09:00 1.00 DRILL P 09:00 - 10:00 I 1.001 DRILL I P 10:00 - 12:00 I 2.001 DRILL I P 12:00 - 13:00 1.00 DRILL P 13:00 - 13:30 0.50 DRILL P 13:30 - 15:00 1.501 DRILL P 15:00 - 00:00 I 9.001 DRILL I P Start: 6/4/2009 Rig Release: 7/15/2009 Rig Number: Page 16 of 28 ~ Spud Date: 2/14/1979 End: 7/15/2009 Phase Description of Operations INT1 -Calculated ECD 10.53 ppg, Actual ECD 11.16 ppg - MW in /out - 10.3 ppg Pumped 45 bbl De-balling Sweep (10 ppb Nut Plug coarse and 3 ppg SAPP) at -10,200' MD, no significant improvement to drilling parameters with use of sweep. Added Screen Kleen and Drill Zone for bit balling. Continue to drill with intermittent stick and slip of up to 200% with no recorded shocks to MWD or ARC. INT1 Drill ahead 8 1/2" hole from 10350' MD to 10502' MD. - 568 gpm, 3645 psi on, 3460 psi off - 25k WOB, 85 rpm, 10k-13k ft-Ibs torque on, 9k ft-Ibs torque off - 245k PUW, 145k SOW, 180k ROT Wt - ADT 6.88 hrs, ART 6.88 hrs, AST 0.0 hrs, Bit 53.7 hrs, Jars 53.7 hrs - Adding water at 10 bph - No fluid loss noted. - Calculated ECD 10.53 ppg, Actual ECD 10.87 ppg - MW in /out - 10.3 ppg Drilling ahead with intermittent stick and slip of up to 200%. Arc Shocks (level 1) started to occur at 10367' MD. Parental wellbore log and Isopach project Top of Sag River at -10,500' MD. ROP continued to slow down to a lowest of 10.3 ft/hr at 10495' MD. From 10495' MD ROP slowly started to pick up from 10.3 ft/hr to 26.7 ft/hr at 10502' MD while maintaining constant 87 RPM and 20k Ibs WOB. Stopped drilling at 10502' MD for sample collection as er eolo ist. INT1 Circulate samples for geologist at 562 gpm with 3480 psi while rotating at 85 rpm with 12k ft-Ibs torque and reciprocating. ROTW 180k. Initial Actual ECD 10.83 ppg, Final Actual ECD 10.78 ppg. Samples showed 1 % gluconite, 1 % Sag River sand, mostly shale. Monitor well -static. INT1 POH on elevators from 10502' MD to 9462' MD (above THRZ) with no overpull greater than 20k. PUW 245k, SOW 145. MW in /out 10.3 ppg. INTi RIH from 9462' MD to 10502' MD with no issues. MW in /out 10.3 ppg. INT1 Circulate at 562 gpm with 3600 psi while rotating at 85 rpm with 12k ft-Ibs torque, ROTW 180k lbs. Initial Actual ECD 10.96, Final Actual ECD 10.81, Calculated ECD 10.46. Monitor well - static. INTi POH on elevators from 10502' MD to 9526' MD. MW in /out 10.3 ppg. PUW 225k, SOW 135k. INT1 Pump 20 bbl 12.2 ppg dry job. Install stripping rubbers and air slips. Blow down Top Drive. INTi POH on elevators from 9526' MD to 7850' MD. PUW 210k. Saw 30k overpull at 7850' MD. Continue to POH from 7850' MD to 7720' MD. Saw 30k overpull from 7720' MD to 7703' MD, wipe out spots without success. Continue to POH and 60k overpull at 7703' MD. MW in /out 10.3 ppg. INTi Bring pumps on to 550 gpm with 3228 psi, lost 15 bbls of 10.3 rrinteo: ai~rtuua °:s°:s~ Hnn BP EXPLORATION Page 17 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code ICI NPT I Phase Description of Operations 6/27/2009 15:00 - 00:00 9.00 DRILL P INT1 ppg LSND to the formation. Bring flow rate down from 550 gpm to 303 gpm with 1323 psi while continuing to lose 10.3 ppg LSND for a total of approximately 35 bbls loss. Backream out from 7703' MD to 7670' MD while stagging up pumps from 303 gpm to 395 gpm as follows: 303 gpm with 1323 psi 315 gpm with 1400 psi 395 gpm with 1980 psi Reduce pump rate to 350 gpm with 1600 psi at 7670' MD while continuing to backream out at 80 rpm with 6k-12k ft-Ibs torque from 7670' MD to 7550' MD. Continue to backream from 7550' MD to 7360' MD at 80 rpm with 8k-12k torque while stagging pumps up to drilling rate as follows: 350 gpm with 1462 psi 396 gpm with 1881 psi 426 gpm with 2034 psi 477 gpm with 2440 psi 500 gpm with 2610 psi 526 gpm with 2818 psi 550 gpm with 3040 psi Bottoms up from 7703' MD show no change in cuttings amount or structure. Attempt to POH on elevators at 7360' MD, saw see a e wellbore breathin and 30k overpull. Continue to backream out from 7360' MD to 6850' MD at 80 rpm with 7k-14k ft-Ibs torque, ROTW 137k. No significant increase in cuttings with bottoms up from 7360' MD but coarser cuttings, particularly coal were noted. Calculated ECD 10.45, Actual ECD 11.19. Total of 118 bbls of 10.3 ppg LSND lost to formation while backreamin .Still adding 12 bph of water while backreaming. 6/28/2009 00:00 - 02:30 2.50 DRILL P INT1 Continue to backream out of the hole from 6850' MD to 6620' MD at 80 rpm with 6k-14k ft-Ibs torque, 550 gpm 2830 psi. 02:30 - 03:30 1.00 DRILL P INTi Replace swab valve on pump no. 2 while reciprocating pipe. PUW 160k, SOW 125k. No fluid loss noted while static. 03:30 - 06:00 2.50 DRILL P INT1 Backream out of the hole from 6620' MD to 5894' MD at 80 rpm, 6k-10k ft-Ibs torque, 553 gpm, 2660 psi. No issues getting Ghost Reamer through 9 5/8 casing stump at 2218' MD. Torque smoothed out considerably at 6502' MD (-5.7k ft-Ibs) and bottoms up from same depth showed clean returns together with a decrease in Actual ECD of 0.42 ppg. 06:00 - 09:00 3.00 DRILL P INT1 POH on elevators from 5894' MD to 2256' MD with no issues. PUW 150k, SOW 125k. MW in /out 10.3 ppg. 09:00 - 11:00 2.00 DRILL P INTi Pump 44 bbl Hi-Vis Sweep (10.3 ppg LSND with 4 sacks of Flowzan) at 590 gpm with 1670 psi while rotating at 90 rpm with 0.7k ft-Ibs torque while slowly pulling out of the 9 5/8" casing stump at 2218' MD. 20% increase in returns with Hi-Vis Sweep. Once 8 1/2" drilling BHA was out of 9 5/8" stump, run back in and tagged stump with 3k-5k Ibs, rotate 3/4 turn to right and no go. Pick up and release trapped torque, run back in and Printetl: 8/3/2009 8:36:32 AM BP EXPLORATION Operations Summary Report Legal Well Name: 13-03 Page 18 of 28 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code ~, NPT Phase Description of Operations 6/28/2009 09:00 - 11:00 11:00 - 14:00 14:00 - 14:30 14:00 - 17:30 17:30 - 20:00 20:00 - 00:00 2.00 DRILL P 3.00 DRILL P 0.50 BOPSU P 3.50 BOPSU P 2.50 CASE P 4.001 CASE I C 6/29/2009 ~ 00:00 - 04:30 ~ 4.50 ~ CASE ~ C 04:30 - 06:00 1.501 CASE ( P 06:00 - 11:00 5.001 CASE ~ C 11:00 - 00:00 ~ 13.00 ~ CASE ~ P 6/30/2009 00:00 - 01:00 1.00 CEMT P 01:00 - 02:30 1.50 CEMT P INT1 slightly tagged again (-3k Ibs) on stump but slid through inmediately with no issues. Resume POH once Hi-Vis Sweep at surface and BHA out of stump to 453' MD. INT1 Lay down 8 1/2" drilling BHA #16. DTX-619M-D6 graded 4-4-BT-X-2-HC-TD, 1/8" under gauge. Clean and clear rig floor of all 8 1/2" BHA and handling equipment. INT1 Drain BOP stack, pick up 7" test joint and remove wear ring. INT1 Chan a out u er ram from 3 1/2" x 6" to 7". Test u er rams with 7" test 'oint and test plug to 250 psi low and 3500 psi high. Record on chart. Good test. -. INTi RU to run 7", 26#, L-80, TC-II Intermediate Long String. Change bails and RU 7" casing handling tools, torque turn equipment, and Frank's fill-up tool. Wellbore losing 10.3 ppg LSND at 4 bph static. INTi Run in the hole with 7", 26#, L-80, TC-II to 1262', torque each connection to 10100 ft-Ibs. Filled every joint using the Frank's tool and circulated down every 10th joint (first 30 joints) at 4 bpm. Losina 2 - 4 bbls per hour while running in the hole. Reduce pump rate from 4 bpm to 3 bpm when circulating down every 10th joint starting with joint 40th. No losses noted after having washed down joint 40th at 3 bpm with 128 psi. String weight at 1262' - 76K Ibs PUW, 74k Ibs SOW. Total of 50 bbls of 10.3 ppg LSND lost to the wellbore. INTi Run in the hole with 7", 26#, L-80, TC-II from 1262' to 3957' MD ,torque each connection to 10100 ft-Ibs. Filled every joint using the Frank's tool and circulated down every 10th joint at 3.5 bpm. Losing 0 - 2 bbls per hour while running in the hole. No issues oin throw h 9 5/8" casin stum at 2218' MD. INTi Circulate 1.5 times annulus volume at 3957' MD (inside 9 5/8" casing window) stagging pumps up as follows: 3.5 bpm with 216 psi, 4 bpm with 226 psi, 4.5 bpm with 258 psi, 5 bpm with 290 psi, 5.5 bpm with 320 psi. No significant losses noted while circulating. INT1 Run in the hole with 7", 26#, L-80, TC-II from 3957' MD to 6548' MD, torque each connection to 10100 ft-Ibs. Filled every joint using the Frank's tool and circulated down every 10th joint at 3.5 bpm. Losing 2-4 bbls per hour while running in hole. INT1 Run in the hole with 7", 26#, L-80, TC-II from 6548' MD to 9294' MD, torque each connection to 10100 ft-Ibs. Filled every joint using the Frank's tool and circulated down every 10th joint at 3.5 bpm. No issues getting centralizers through 9 5/8" casing stump at 2218' MD. Circulate down the next 10 joints at 5 bpm with 636 psi, 8 min/joint to obtain bottoms up at Top of the HRZ from 9294' MD to 9747' MD. Continue to run 7" casing from 9747' MD to 10172' MD with approximate losses of 2 - 6 bbls every 10 joints. Continue running in the hole from 10172' to 10502' while workin throw h ti ht s ots. Pick up 1' to set casing shoe at 10501' MD. PUW 390k, SOW 155k. Total of 160 bbls of 10.3 ppg LSND lost to formation. INT1 PJSM. RD casing running equipment; MU cement head. INT1 Circulate and condition mud for cement job; stage pumps up to 4bpm and 885psi. Could not break over on the up stroke, Printed: 8/3/2009 8:36:32 AM ! • BP EXPLORATION Page 19 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABORS 9ES Rig Number: Date ;From - To Hours j Task Code NPT Phase Description of Operations 6/30/2009 01:00 - 02:30 1.50 CEMT P INTi worked casing stretch only while reciprocating casing. 02:30 - 06:00 3.50 CEMT P INTi PJSM w/ SLB cementers. Pump 7" intermediate longstring as follows: 02:23 Pump 5bbl 10.5 MudPush, test lines to 4500psi; good. 02:32 Pump 25bb1 10.5ppg MudPush away. Drop bottom plug; good indication that plug dropped. 02:45 Start pumping 11.Oppg Lead Crete C~3 4.1bb1/min. 02:59 50bb1 cement away, 4.2bpm, 594psi 03:04 70bb1 cement away, 4.1 bpm, 526psi 03:12 104bb1 cement away, 4.1 bpm, 461 psi 03:23 146bb1 cement away, 4.2bpm, 530psi Lead Crete away; start hatching tail cement. 03:28 Start pumping 15.8ppg Class G tail cement 03:33 19bb1 cement away; done pumping tail cement. Drop top plug; kick out with 5 bbls water; positive indication that plug dropped. 165bb1 cement away; isolate SLB and displace with rig pumps 03:48 Chasing cement with rig pumps, 10.5ppg mud. Good returns during cement job until last 900 strokes, last 30 bbls of lead and 16 bbls of tail had minimal returns. Plug bump C~ 6812strokes, 397bb1s displaced- final pump pressure 1500psi. CIP ~ 05:15hrs Estimated TOC in gauged hole considering losses, -5,607'. At olua bump. pressure up to 3500psi for 30 minutes to test 7" Cement job volume: 146 bbls Lead Crete pumped; 260 sacks C~? 3.32cuft/sx 19 bbls Class G tail pumped, 93 sacks ~ 1.16cuft/sx While reciorocatino, only stretch was reciprocated. 06:00 - 07:00 1.00 CEMT P INT1 07:00 - 09:30 2.50 CEMT C INTi 09:30 - 12:00 2.50 CASE C INT1 12:00 - 15:00 3.00 CASE N HMAN INT1 15:00 - 16:30 ~ 1.50 CASE C INTi RD SLB and cementing equipment; blow down lines. Wait on cement thickening time before breaking stack. Inject 18bbls total of 10.5ppg mud down backside C~ 2bpm, 670psi to confirm infectivity capability. 10 bbls initial injection C~ 670 psi 08:00 3 bbls injection ~ 670 psi 09:00 3 bbls injection C~ 670 psi 09:30 3 bbls injection @ 670 psi Cement reached 100 be ND BOPs; install emergency slips w/ 200k. Experiencing difficultly installing slips; determine that slips are inappropriate size. Expedite new slips to location; install correct slips w/ 110k. PU 2k over block weight to cut 7" casing. Using Wach's Cutter; make cut on 7" casing as per FMC rep. Lay down cut 7" joint; rnncea: oi~izvua cso:a~ rim BP EXPLORATION Page 20 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABORS 9ES Rig Number: I, Task Code NPT Phase Description of Operations - - Date From - To Hours ~ 6/30/2009 15:00 - 16:30 1.50 CASE C INT1 - cut joint length = 17.68'. 16:30 - 18:00 1.50 BOPSU C PROD1 PJSM. ND BOPs; set stack aside. Remove tubing spool. C/O bales and swap casing elevators for 4" elevators in preparation for drilling ahead in next phase. 18:00 - 22:00 4.00 BOPSU P PROD1 Set packoff and tubing spool. Torque bolts on tubing spool, and test packoff to 4300psi for 15 minutes; good. NU BOPS and torque bolts on stack. Install mouse hole and flow nipple. Confirm injection capability by pumping 33bbls @ 2bpm, 510psi of 10.5ppg mud down backside. 22:00 - 00:00 2.00 BOPSU P PROD1 Change out upper rams from 7" rams to 3-1/2" x 6" VBRs. 7/1/2009 00:00 - 00:30 0.50 BOPSU P PROD1 PJSM. Finish changing out upper rams. Fill stack, RU test joints and install test plug. 00:30 - 05:00 4.50 BOPSU P PROD1 Test BOPs to 3500 si hi h, 250 si low. Test witness waived by AOGCC rep Lou Grimaldi. BOP test witnessed by WSL Amanda Rebol and Nabors TP Roy Hunt. Chart all tests; good. 05:00 - 05:30 0.50 BOPSU P PROD1 RD test joints, pull test plug. Clean and clear rig floor of test equipment. Install 8.5625" wear ring. 05:30 - 09:00 3.50 DRILL P PROD1 PJSM. PU 6-1/8" XR20DOD1GVPS Smith bit, 1.83deg bend mud motor, and logging tools (BHA #17). PJSM for nuclear source. RIH w/ BHA to 817' and shallow test MWD tools; 1280psi ~ 225gpm. Good test. 09:00 - 12:00 3.00 DRILL P PROD1 PU 4" DP singles from the pipe shed and RIH from 817' to 3731' MD. 12:00 - 15:30 3.50 DRILL P PROD1 PJSM; preform stripping drill operation; blow down choke manifold and kill line. RIH w/ 4" DP stands from the derrick from 3731' to 10,227', filling every 20 stands. 252k up, 118k down. SimOps: RU LRHOS and freeze protect 9-5/8" x 7" annulus. Pum 100bb1s 10.3 mud C~ 630 si, 2b m. Chase mud with 225bb1s of crude ~ 880 si, 3bpm. 15:30 - 18:00 2.50 DRILL P PROD1 Slip and cut 102' of drilling line. Service top drive and crown. 18:00 - 20:30 2.50 DRILL N RREP PROD1 Glycol leaking around off-driller's side brake drum while cleaning under drawworks. Trouble shoot leak, and change out glycol hoses on brake rim. 20:30 - 00:00 3.50 DRILL P PROD1 Wash down from 10,227' to 10,416' MD and tag float collar. Pumping 2395psi C~ 247gpm. Drill out shoe track to within 10' of new formation. 40rpm, 12k torque, 155k rotating. 7/2/2009 00:00 - 01:30 1.50 DRILL P PROD1 PJSM. Displace wellbore over from 10.3ppg old mud system to fresh 8.4ppg FloPro. Reciprocate in 60-70' strokes while displacing. 01:30 - 02:00 0.50 DRILL P PROD1 Drill remainder of shoe track and 20' of new formation. 02:00 - 03:00 1.00 DRILL P PROD1 POOH so that BHA is inside 7" casing shoe. Pump 50bbls of 10% concentration, 8.4ppg Steel Lube pill surface to surface. Clean Steel Lube product from pits. 03:30 - 04:30 1.00 DRILL P PROD1 Perform FIT to 10.51 ppg; MW = 8.4ppg, TVD = 8769', surface pressure = 960psi. 04:00 - 12:00 8.00 DRILL P PROD1 Run back to bottom and drill 6-1/8" hole ahead in production interval. Drill from 10,522' to 10,705' MD; 8937' TVD. 190k up, 150k down, 170k rotating. 1790psi off, 1905psi on C~ 240gpm, 98spm. Torque = 3k off, 4k on ~ 25rpm and 5-15k WOB. AST = 5.32hrs, ART = 0.50hrs. Mud weight: in =out = 8.4ppg. 12:00 - 00:00 12.00 DRILL P PROD1 PJSM. Drill ahead from 10,705' to 11,086' MD; 9030' TVD. rnmea: ~si;~i~uuy iS::Sti::31 HM BP EXPLORATION Page 21 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date From - To 'Hours Task Code NPT Spud Date: 2/14/1979 Start: 6/4/2009 End: 7/15/2009 Rig Release: 7/15/2009 Rig Number: Phase Description of Operations 7/2/2009 12:00 - 00:00 12.00 DRILL P PROD1 190k up, 150k down, 170k rotating. 1790psi off, 1905psi on ~ 240gpm, 98spm. Torque = 4k off, 5.7k on ~ 25rpm and 5-15k WOB. AST = 2.62hrs, ART = 3.15hrs. No losses; mud weight: in =out = 8.4ppg. 7/3/2009 00:00 - 02:30 2.50 DRILL P PROD1 PJSM. Drill 6-1/8" production build interval from 11,086' MD to section TD ~ 11,279' MD, 9020' TVD. 190k up, 150k down, 170k rotating. 1830psi off, 2020psi on C~240gpm, 98spm. Torque: 4k off, 6k onw w/ 20k WOB and 30rpm. Land interval at 90 deg inclination, with 200' of tangent section for upcoming rotary steerable run. AST = 0.25hrs, ART = 1.87hrs. 8.4ppg ~ MW in and out. 02:30 - 05:30 3.00 DRILL P PRODi Backream from 11,279' to 10514' MD, until BHA is inside 7" shoe; watch for overpulls. Once inside shoe, drop ball to shift open PBL circulation sub. Slow pump rates as ball reaches sub, but no indication of tool shifting open. Bring pumps back up to drilling rate; 600psi pressure drop from previous pump rates indicate that PBL is open. Rack back one stand and drop ball to lock PBL open. Circulate bottoms-up to confirm PBL locked in the open position; reciprocate pipe while circulating; 195k up, 151 k down. 05:30 - 06:00 0.50 DRILL P PROD1 Monitor well; static. 8.5ppg in and out. Pump dry job and install stripping rubbers; prepare to POOH. 06:00 - 11:00 5.00 DRILL P PROD1 POOH from 10,418 to BHA #17. 11:00 - 12:30 1.50 DRILL P PROD1 Break out logging tools, PJSM for handling nuclear source. LD 1.83deg bend mud motor and roller cone bit. Bit grade: 1-1-WT-A-E-I-ER-BHA. Clean and clear rig floor. 12:30 - 15:30 3.00 DRILL P PROD1 PU BHA #18: Hycalog MSR513M-A1 B, PowerDrive RSS, Impulse MWD, PWD/ADN, drill collars and 4-3/4" PBL circ sub. PJSM for handling nuclear source. Surface test rotary steerable; 225gpm, 455psi; good. RIH with new BHA, picking up 4" DP singles from the pipe shed. Shallow test MWD 1204' MD; 227gpm, 908psi; good. 15:30 - 19:30 4.00 DRILL P PROD1 RIH from 1204' to 10476' MD; PU 76joints of 4" DP from the pipe shed while RIH. 19:30 - 20:30 1.00 DRILL P PROD1 Service topdrive, drawworks, crown and blocks. Inspect and adjust brakes. 20:30 - 22:00 1.50 DRILL P PROD1 Continue to RIH from 10,476' tp 11,279' w/ stands from the derrick. Perform MWD roll test C~3 10,600' and 10,800' MD. 22:00 - 00:00 2.00 DRILL P PROD1 Drill 6-1/8" hole ahead from 11,279' to 11,336' MD, 9014' TVD. 190k up, 145k down, 163k rotating. 2040psi on and off C~ 108spm, 265gpm. Torque = 4k off, 6.8k on ~ 110rpm and 10k WOB. ADT = 0.58hrs. MW in and out = 8.5ppg. 7/4/2009 00:00 - 12:00 12.00 DRILL P PROD1 PJSM. Drill ahead with PowerDrive rotary steerable system and BHA #18 from 11,336' to 12,130' MD. 185k up, 145k down, 165k rotating. 2180psi on and off C~ 270gpm. Torque: 4k off, 7k on ~ 100rpm. ADT = 8.78hrs. 12:00 - 00:00 12.00 DRILL P PROD1 Continue to drill ahead from 12,130' to 13,151' MD; no sign of anticipated fault C~ 12,540' MD. 190k up, 135k down, 160k rotating. 2330psi ~ 265gpm and 108spm. Torque: 6k off, 9-10k on ~ 100-130rpm and 10-15k WOB. ADT = 10.23hrs. 7/5/2009 00:00 - 01:00 1.00 DRILL P PROD1 PJSM. Drill ahead from 13,151' to 13,319' MD; at 13,319' fluid returns dro ed and um ressure ro a ;stop drilling ahead and monitor well. Drilling parameters before losses: rnmea: aitiruua a:sa:s~ Hm • • BP EXPLORATION Page 22 of 28 Legal Well Name: 13-03 Operations Summary Report Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task I Code I NPT I 7/5/2009 100:00 - 01:00 1.001 DRILL I P 01:00 - 05:00 ~ 4.001 DRILL ~ P 05:00 - 12:00 I 7.001 DRILL I P 12:00 - 00:00 12.001 DRILL ~ P 7/6/2009 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ P 12:00 - 00:00 I 12.001 DRILL I P 7/7/2009 100:00 - 02:00 I 2.001 DRILL I P 02:00 - 08:00 I 6.001 DRILL I P 08:00 - 13:30 ~ 5.50 ~ DRILL ~ P 13:30 - 16:00 2.501 DRILL ~ P 16:00 - 18:00 2.001 CASE ~ P 18:00 - 00:00 I 6.001 CASE I P Phase I Description of Operations PROD1 195k up, 135k down, 160k rotating. 2360psi on and off l~ 265gpm. Torque: 8k off, 9-10k on. Mud = 8.7ppg in and out. ADT = 1.49hrs. PROD1 Determine loss rate; 200bph static, losing all fluid when pumps are at drillin rate. Fill backside and pump down DP C~? 2bpm; wait on additional mud from mud plant and build 340bb1s in the pits in order to drill ahead past loss zone. PROD1 Drill ahead -100' past initial loss zone in preparation for healing up with drill cuttings (no LCM actually pumped at this time); drilling with loss rate at 30bph. 195k up, 140k down, 165k rotating. 2360psi ~ 265gpm. Torque = 8k off, 9-10k on ~ 120rpm. Mud in and out = 8.6ppg. ADT = 3.67. PROD1 Continue to drill 6-1/8" production hole from 13,629 to 14,585' MD. 195k up, 135k down, 170k rotating. 2330psi @ 265gpm. Torque: 6k off, 9-10k on ~ 100-130rpm and 10-15k WOB. ADT = 9.42hrs. Continuing to deal with losses; pump 40bb1 of 30ppb LCM sweep ~ 13,724'. After pumping sweep, losses reduced from -30bph to 20bph. PROD1 PJSM. Drill ahead to 15,446' MD w/ BHA #18 and PowerDrive BSS. Stream in LCM and build mud to deal with losses (at around 20bph). 200k up, 130k down, 160k rotating. 2490psi off, 2530psi on C~? 280gpm. Torque: 8k off, 11-12k on at 120rpm and 15k WOB. Mud weight in and out = 8.6ppg. ADT = 7.64hrs. PROD1 Drill to 6-1/8" production hole TD @ 16,320' MD, 8822' TVD. 200k up, 120k down, 160k rotating. 2620psi on and off at 265gpm, 108spm. Torque: 8k off, 12k on at 130rpm and 15k WOB. Streaming in LCM to deal with losses; steady around 15-20ti h. Mud weight: 8.7ppg in and out. ADT = 9.44hrs. PROD1 PJSM. Pump weighted sweep at TD of 16,320' to clean cuttings from the wellbore; increase in cuttings and LCM in returns when sweep made it back to surface. Continue to reciprocate and circulate until 2 bottoms-up have been reached; shakers cleaned up. PROD1 Pull out first two stands; no overpulls. Well breathing back a small amount on first two stands; monitor well, breathing stopped. Continue to POOH from TD to the 7" casing shoe; mud falling out of pipe on its own. Losses at 15-20bph. Stop pulling and monitor well C~ 10,476' MD for 10 minutes; well still drinking. Continue to POOH to 6,177' MD. PROD1 Break out and LD 4" DP from 6,177' MD to BHA. Fuction test BOP pipe rams. PROD1 LD BHA #18; Hycalog MSR513M-A1 B, PowerDrive rotary steerable, Impulse MWD and PWD/ADN tools, drill collars and 4-3/4" PBL circ sub. Bit grade: 3-2-CT-A-X-I-ER-TD. PJSM w/ SLB hands before handling nuclear source. Clean and clear rig floor of 3rd party tools. RUNPRD RU casing running equipment as per Nabors casing hand; RU double stack, torque-turn equip and compensator. C/O to long bales and RU stabbing board. RUNPRD PJSM w/ Nabors casing hand. PU and run shoe track; fill pipe and check float- good. Run 4.5" 12.6# 13Cr-80 VamTop liner Nnmea: aisiluua a::te::te Hnn 8.50 CASE P 2.00 CASE P 1.50 CASE P BP EXPLORATION Page 23 of 28 ~ Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABORS 9ES Rig Number: Date From - To 'Hours Task ~ Code NPT 7/7/2009 18:00 - 00:00 6.00 CASE P 7/8/2009 100:00 - 08:30 08:30 - 10:30 10:30 - 12:00 12:00 - 15:00 15:00 - 17:30 17:30 - 18:30 18:30 - 22:00 22:00 - 22:30 22:30 - 00:00 7/9/2009 100:00 - 03:00 Phase Description of Operations RUNPRD from surface to 2509'; utilize compensator to PU joints, and torque-turn to 4440ft-Ibs. Baker-Lok all joints below landing collar. Lightly dope all joints with JetLube Seal Guard and mustache brush RUNPRD PJSM. Continue to run 4.5" 12.6#, 13Cr-80, VamTop production liner from 2509' to 5950'. RU liner hanger and ZXP liner top packer as per Baker hand. Fill running tool with PalMix and allow to set for 30 minutes. RUNPRD Rig down casing running tools, c/o bales; clean and clear rig floor. RUNPRD PU 10' DP pup and 15' DP pup to space out cement head above rig floor. PU one stand out of the derrick and RIH; liner weight = 100k. Circulate one full liner volume ~ 620psi and 3.00 CASE P RUNPRD RIH w/ 4.5" production liner on 4" DP from 5950' to 10,472'. MW in and out = 8.7ppg. Stop inside 7" shoe and circulate 200bb1s; stage up to 5bpm, 860psi. 170k up, 140k down. 2.50 CASE P RUNPRD Continue into open hole w/ 4.5" VamTop production liner on 4" drillpipe. Fill pipe and break circulation; high circulating pressure at 14,581' MD' 980 si ~ 1 b m. Work pipe down. 1.00 CASE P RUNPRD Circulate to improve hole conditions; stage pumps up to 1340 si and 4b m. Circulate 1 openhole volume before continuing to RIH. 3.50 CASE P RUNPRD Work pipe down, circulating every third stand in the hole. RIH from 14,581' to 16,301', pumps C~ 1340psi ~ 2bpm. 0.50 CEMT P RUNPRD RU for cement job; install cement lines and RU cement head to single joint of 4" DP. 1.50 CEMT P RUNPRD Circulate and condition in prep for 4.5" production liner cement job. 200k up, 125k down. PU single joint of DP and cement head; RIH from 16,301' to 16.320' MD. Stage pumps up to 2.5bpm, 1440psi. Losing -14bph while pumping. 3.00 CEMT P RUNPRD PJSM w/ SLB cementers. Cement 4.5", 12.6# 13Cr-80 VamTop production liner as follows: 00:19 Pump 10bb1 12.5 MudPush, test lines to 4500psi; good. 00:34 Pump 10bb1 13.5ppg MudPush away. Start pumping 15.8 ppg, Class G w/ Latex, 15.8ppg cement. 00:47 20bbls cement away ~ 3.3bpm, WHP = 100psi 00:54 40bb1 cement away, 3.7bpm, 124psi 00:58 60bb1 cement away, 3.3bpm, 120psi 01:05 80bb1 cement away, 3.5bpm, 119psi 01:10 120bb1 cement away, 4.9bpm, 233psi 01:12 150bb1 cement away, 5.Obpm, 233psi 01:24 168.6bbls cement away; 5.Obpm, 238psi. Drop top plug; kick out with 5bbls 8.7ppg FloPro; tattletale indicated that plug dropped. Good, consistent returns while pumping cement. 1 ppb CemNet added to first 50 bbls of slurry pumped. 168.6bb1 cement away; isolate SLB and displace with rig pumps Reciprocate pipe stretch while pumping cement; reciprocate Printed: 8/3/2009 8:36:32 AM ~ ~ BP EXPLORATION Page 24 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABOBS 9ES Rig Number: Date From - To II Hours Task 'Code NPT ~ Phase Description of Operations - _ - __- 7/9/2009 00:00 - 03:00 3.00 CEMT P RUNPRD stretch while displacing until 56bbls displaced, then stop pipe movement. 01:43 Start displacement; S.Sbbl away, 4.8bpm, 64psi. 01:50 38bbls displaced, 5.1 bpm, 69psi 01:55 62bbls displaced, 4.8bpm, 1061 psi 02:00 84bbls displaced, 4.5bpm, 1771 psi Slow pumps from -4.5bpm to 3.Obpm in anticipation for plug latch. 02:05 Plug latched in liner top; pressure spiked to 2800psi. 103bb1s displaced, 2.8bpm. 02:11 121bb1s displaced, 2.8bpm, 2297psi 02:21 149bb1s displaced, 2.8bpm, 2334psi 02:26 161 bbls displaced, 2.8bpm, 2362psi 02:33 181 bbls displaced, 2.7bpm, 2403psi Slow pump rate to below 2bpm in anticipation for plug bump. Plug bumped C~3 02:38 192bb1s dimlaced, 1.5bpm, 2600psi Returns dropped a little while displacing, but still good. Fair returns throughout displacement; estimate 69bbls lost during CIP C~ 02:45hrs 03:00 - 05:00 2.00 CEMT P RUNPRD 05:00 - 06:00 1.00 CEMT P RUNPRD 06:00 - 08:30 2.50 CEMT P RUNPRD 08:30 - 13:30 5.00 CEMT P RUNPRD 13:30 - 14:00 0.50 CEMT P RUNPRD 14:00 - 15:00 1.00 CEMT P RUNPRD 15:00 - 16:00 1.00 CEMT N DFAL RUNPRD 16:00 - 21:30 5.50 CEMT N DFAL RUNPRD Cement job volume: 169 bbls 15.8ppg Class G w/ Latex cement pumped; 846sxs @ 1.17cufUsx At plug bump continue to pressure up to 3500psi and hold tc ensure liner hanger set, then continue to pressure up to a200osi to neutralize pusher and release hanger setting tool. release good Continue to 'dogs out' PU and slack off to set ZXP liner too packer. PU again and repeat slack off with rotation to ensure packer set. PJSM. PU out of liner top and circulate at max rate to clean liner top; 2650psi ~ 520gpm. CBU x2 to ensure liner top is clean. -30bbls cement-contaminated mud returned to surface LD cement head and 2 joints of DP. Circulate wellbore over to clean 8.5ppg seawater for perforating. Slip and cut 104' of drilling line. Service top drive, crown and drawworks. Clean under shakers and trip tank. POOH, racking back DP from 10,335' to Baker liner running tools. Note cement on some of the drillpipe joints near the running tools. Break out liner running tools; dog sub sheared. LD third party tools, clean and clear rig floor. Service rig. RU to do scraper/cleanout run. PU used 6-1/8" used tri-cone bit, 7" OD casing scraper, bit sub with float, 3 joints of HWDP, jars, and additional 3joints of HWDP. RIH w/ cleanout assy from surface to 9873' MD. Wash down Nnntea: w~iluua ts:so::se ttnn • BP EXPLORATION Page 25 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABORS 9ES Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations 7/9/2009 116:00 - 21:30 5.501 CEMT N DFAL RUNPRD from 9873' to 10,337' and slow running speed near 4.5" liner 21:30 - 22:30 I 1.001 CEMT top @ 10,337'. No indication of encountering cement stringers on casin .Circulate 50bb1 high vis sweep around to push any cement to surface; no cement seen in returns. Reciprocate pipe while circulating; 965psi @ 281 gpm. Circulate wellbore over to clean 8.5ppg seawater ~ 1600psi and 362gpm before POOH. P RUNPRD Close i e rams and ressure test 4.5" liner to 3500 si for 30 22:30 - 00:00 I 1.50 I CEMT I N 7/10/2009 100:00 - 03:30 I 3.501 CEMT I N 03:30 - 06:30 I 3.001 PERFOBI P 06:30 - 20:00 13.50 ~ PERFOB~ P 20:00 - 20:30 I 0.501 PERFOBI P 20:30 - 00:00 3.501 PERFOB~ P 7/11/2009 100:00 - 03:00 I 3.001 PERFOBI P 03:00 - 04:00 I 1.001 PERFOB, P 04:00 - 07:30 3.501 PERFOB~ P 07:30 - 10:00 I 2.501 PERFOBI P 10:00 - 12:00 2.001 PERFOBI P minutes. Chart test: ood. Test witnessed by NAD TP Brian Tiedmann and WSL Amanda Rebol. 0 min = 3710psi 15 min = 3710psi 30 min = 3710psi DFAL RUNPRD Bleed off pressure and monitor hole; static. Pump dry job and POOH; install stripping rubbers and air slips for trip. POOH from 10,337' to 8439' MD. 190k up, 150k down. DFAL RUNPRD PJSM. Continue to POOH w/ 4" DP from 8439' to cleanout BHA. Break out and LD cleanout BHA; clean and clear rig floor of third parry tools. OTHCMP Change out handling equipment; bring slips and tongs for handling 2-7/8" FOX up to the rig floor. PU perf gun running equipment, and crossovers for gun assem y ayou . oa perf guns into pipe shed, check FOX tbg strap to finalize perf assy tally. OTHCMP PJSM w/SLB perforating crew. PU 2-7/8" PowerJet Omega perf guns, spaced out with 2-7/8" 7.8# FOX tbg. Torque to 2100ft-Ibs and lightly dope pin ends w/ a mustache brush. MU crossovers to multiple firing heads, and handle guns gently. RIH from surface to 1739' MD on guns and FOX tubing; continue to RIH to 6030' MD, picking up singles of 4" DP from pipe shed. RA tag in 2-7/8" FOX tubing, in coupling of third joint above Baker Hydraulic disconnect; 129' from top shot. OTHCMP RD perf guns and FOX tubing handling equipment; RU 4" DP handling equipment. OTHCMP RIH from 6030' to 12,431' MD, taking stands of 4" DP out of the derrick. 165k up, 135k down. No indication when passing into 4.5" liner to ~ 10,337' MD. OTHCMP PJSM. RIH from 12,431' to 16,234' MD. Slow running speed when nearing tag-up depth; 200k up, 150k down. Tag up on de th n PU to u wei ht. LD single of DP and PU two pup joints to expedite wireline rig-up. OTHCMP PJSM w/ SLB perforating and wireline crews. RU wireline unit; PU two weight bars and GR logging tool (1-11/16" OD). OTHCMP RIH w/ GR logging tools on wireline from surface to 10,521' (RA tag location in 2-7/8" FOX collar) and log up to 10,600' to locate RA tag in FOX tbg. OTHCMP Correlate wireline to to perforation space-out. PU on DP and perf assy 17' as per correlation calculation. heck corre anon w/ GR on wireline, and POOH with wireline. RD same. OTHCMP PJSM w/ SLB perforating crew. Guns on depth with top shot ~ 10 650' MD bottom shot Cam? 16 220' MD. Fill lines and confirm circulation ability. Close upper pipe rams and function test detection equipment. Printetl: 8/3/2009 8:36:32 AM n L~ CJ BP EXPLORATION Page 26 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABOBS 9ES Rig Number: Date From - To I Hours Task I Code NPT Phase Description of Operations 7/11/2009 12:00 - 12:30 0.50 PERFO N RREP OTHCMP Washpipe packoff leaking; change out fitting on packoff. 12:30 - 16:00 3.50 PERFO P OTHCMP Initiate firin se uence as per SLB pert specialist. Good indication on surface that firing heads #5 and #6 fired. Wait for redundant firing heads; wait 97 minutes. Firing heads #1, #2 and #3 fired. No indication that firing head #4 (pert interval from 13 440' - 14 105' MD detonated. Wait another 90 minutes as per SLB specialist to safe-out guns. Still no-go on firing head #4. Loss of 23bbls to perforations after firing. 16:00 - 17:00 1.00 PERFO P OTHCMP Pick up drillstring and perforating assembly to verify that guns can be pulled uphole. Circulate bottoms up; 920psi C~ 255gpm. Losses to perforations while circulating = 18bbls. 17:00 - 22:00 5.00 PERFO N DFAL OTHCMP POOH from 16,220' to 6125' MD; rack back all 4" DP. Stop POOH ~ one stand above the 2-7/8" FOX tubing and 2-7/8" PowerShot pert assembly. 22:00 - 00:00 2.00 PERFO P OTHCMP Cut and slip 85' of drilling line. Service drawworks, crown and top drive. 7/12/2009 00:00 - 02:00 2.00 PERFO P OTHCMP PJSM. POOH w/ FOX tubing and pert gun assembly as per SLB hand. Remove RA-tagged collar from 10th jt of FOX out of the hole. LD 12 joints of 2-7/8" FOX tbg. 02:00 - 05:00 3.00 PERFO P OTHCMP PJSM w/ SLB crew for laying down top set of guns; LD firing head and 2-7/8" pert guns; all shots fired. 05:00 - 06:30 1.50 PERFO P OTHCMP POOH with and LD 18 joints of 2-7/8" FOX tubing. 06:30 - 19:30 13.00 PERFO P OTHCMP Continue to POOH w/ pert gun and FOX tubing assy as per SLB hand. LD perf guns and blanks; all shots fired. LD tubing and guns to 3100' MD. 19:30 - 20:00 0.50 PERFO P OTHCMP Service drawworks, blocks and crown. 20:00 - 21:00 1.00 PERFO P OTHCMP Continue to lay down 2-7/8" PowerJet perf guns and 2-7/8" FOX tubing assembly from 3100' to surface. All shots from all erforation intervals fired. ~ 21:00 - 00:00 3.00 PERFO P OTHCMP LD perf gun handling equipment and FOX tubing handling equipment. Clear floor of all third party tools; clean floor in preparation for RIH w/ 4" DP. 7/13/2009 00:00 - 06:30 6.50 PERFO N DFAL OTHCMP PJSM. RIH w/ stands of 4" DP from the derrick; run in w/ 110 stands to 10,301' MD. 06:30 - 07:00 0.50 PERFO N RREP OTHCMP Repair pipe skate; driller-side elevator cylinder broken between cylinder and shaft. Repair weld and replace shaft. Circulate while finishing repairs; 258psi C~3 144gpm. 07:00 - 15:30 8.50 PERFO P OTHCMP PJSM. Come out sideways w/ 4" DP from 10,301' MD to surface. Clean and clear rig floor. 15:30 - 16:30 1.00 BUNCO P RUNCMP Pull wear bushing. Function test BOP rams. 16:30 - 18:30 2.00 BUNCO P RUNCMP PJSM w/ Nabors casing hand. RU to run tubing; c/o bales, RU compensator and stabbing board. PU casing handling tools, including double-stack tongs. 18:30 - 00:00 5.50 BUNCO P RUNCMP PJSM w/ Nabors casing hand and Baker hands. MU and run 4.5" 12.6# 13Cr-80 VamToo tubing from surface to 2482' MD. Baker-lok all connections below Baker S-3 production packer. Torque turn each joint to 4440 tt-Ibs utilitzing torque-turn equipment and double-stack tongs. 7/14/2009 00:00 - 13:30 13.50 BUNCO RUNCMP Continue to run 4 1/2" 13Cr-80 completion from 2482' to depth, inside SBR bottom of SBR at 10,348' MD). Hand start all connections, then utilize torque-turn equipment to MU all connections to optimum torque 4440 ft-Ibs. Completion weight: 155k PUW, 125k SOW. Tag up inside SBR and LD 2 joints of Printed: 8/3/2009 8:36:32 AM • BP EXPLORATION Page 27 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABOBS 9ES Rig Number: Date I From - To Hours ' Task Code NPT Phase Description of Operations 7/14/2009 00:00 - 13:30 13.50 BUNCO P RUNCMP tubing, PU 3.84' and 9.84' pup joints and space out completion. PU final joint and tubing hanger. MU landing joint and RIH, land completion. Total of 239 joints run. Tubing is landed with WLEG 4' from full inserted in SBR. 13:30 - 15:30 2.00 BUNCO P RUNCMP RILDS as per FMC hand. LD landing joint and break circulation. Reverse circulate 156 bbls clean seawater, 70 bbls corrosion inhibited seawater and 123 bbls clean seawater at 3 bpm with 220 psi. 15:30 - 17:30 2.00 BUNCO RUNCMP MU landing joint, and drop 1-7/8" ball and rod. Close rams, and ressure u a ainst ball and rod to 3500psi to set Baker S-3 acker. Hold ressure for 30min to test tubin and chart; ood test. Bleed tubin to 2000 si ressure u annulus to 3500 psi for 30 min and record on chart; good test. Bleed tubin and shear DCK valve at 2500 si• ood indication of shear. Bleed off pressure and establish circulation through DCK; pump each way at 3 bpm with 1600 psi circulating pressure. 17:30 - 19:30 2.00 BUNCO SFAL RUNCMP Install TWC with T-bar as er FMC. Attem t to test TWC from above to 1000 psi and 1500 psi without success. Test TWC from below to 1000 si for 10 charted minutes - ood test. Attempt to test TWC from above once again to 1000 psi - failed, pressure up to 1500 psi -TWC not holding, pressure up to 3000 si -TWC notholdin No visual leaks noticed while attem tin to ressure test TWC. Mobilize TWC from DSM. Pull TWC with T-bar as er FMC. Take apart and inspect TWC (Serial Number 258) and found no visual damage to any of its components. 19:30 - 20:00 0.50 BUNCO SFAL RUNCMP Waiting on DSM to bring 4" H Plug (TWC). 20:00 - 21:00 1.00 BUNCO RUNCMP Install new TWC with T-bar as per FMC. Test from below and above to 1000 psi for 10 charted minutes, good tests. Blow down surface lines and drain stack in re aration for ND BOP. 21:00 - 00:00 3.00 BOPSU P RUNCMP Power wash top drive, rotary table and iron roughneck in preparation for Summer Maintenance. 7/15/2009 00:00 - 03:00 3.00 BOPSU P RUNCMP Continue to clean under rotary table, replace hatch and install master bushing in preparation for Summer Maintenance prior to ND BOP. 03:00 - 10:30 7.50 BOPSU P RUNCMP Remove Upper, Blind and Lower rams. Pull riser, RD turn buckles. ND BOP, remove from wellhead and set back on stump. 10:30 - 18:00 7.50 WHSUR P RUNCMP NU adapter flange and 4 1/8" tree. Test adapter flange and tubing hanger pack off to 5000 psi for 30 minutes -good test. Test 4 1/16" tree to 5000 psi for 10 minutes -good test. RU DSM test lubricator to 500 psi and lubricate out TWC. 18:00 - 21:00 3.00 WHSUR P RUNCMP PJSM with Little Red Services and rig crew. LRS rigged up to the IA (7" x 4 1/2") and pressure tested their lines to 3000 psi. Reverse circulate 77 bbls of 60 deg F diesel down the inner annulus in order to freeze rotect to 2277' TVD. LRS pumped diesel at an average rate of 3.0 bpm with 1800 psi. Allow diesel to U-tube from annulus to tubing for 1 hr 45 min. RU DSM and lubricate in BPV. Test BPV with LRS from below to 1000 psi or 10 mins- ood test. RD DSM and LRS - Pflllt2tl: 8/3/LUU9 k3::1li::iL AM BP EXPLORATION Page 28 of 28 Operations Summary Report Legal Well Name: 13-03 Common Well Name: 13-03 Spud Date: 2/14/1979 Event Name: REENTER+COMPLETE Start: 6/4/2009 End: 7/15/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2009 Rig Name: NABOBS 9ES Rig Number: Date From - To 'Hours Task Code NPT Phase Description of Operations 7/15/2009 18:00 - 21:00 3.00 WHSUR P RUNCMP Remove secondary annular valves. Secure tree -all annular valves closed. Ria Released at 21:00 f llfltBtl: k3/:i/"LUUS tl::ifi::i"L AM ^~ ~~~ - ww~ w ww ~ w w v~ i.s-us~- purvey riepvr~ Report Date: July 7, 2009 Survey /DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 65.010° Field: Prudhoe Bay Unit - EOA Vertical Section Origin: N 0.000 tt, E 0.000 tt Structure/Slot: DS-13/13-03 TVD Reference Datum: RoiaryTable Well: 13-03 TVD Reference Elevation: 72.93 ft relative io MSL Borehole: 13.03A Base Flange Elevation: 45.03 ft relative to MSL UWVAPI#: 500292032501 Magnetic Declination: 22.717° Survey Name /Date: 13-03A /July 7, 2009 Total Field Strength: 57713.461 nT Tort /AHD / DDI / ERD ratio: 403.660° / 10332.08 ft / 6.878 / 1.145 Magnetic Dip: 80.885° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: June 25, 2009 Location LaULong: N 7013 9.953, W 148 29 22.671 Magnetic Declination Model: BGGM 2008 Location Grid NIE Y/X: N 5932121.110 ftUS, E 687206.490 ftUS North Reference: True North Grid Convergence Angle: +1.42128859° Total Corr Mag North -> True North: +22.717° Grid Scale Factor: 0.99993981 Local Coordinates Referenced To: Well Head • Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de ft ft ft ft ft ft ft de 00 ft ftUS ftUS Projected-Up o.oo D.uv U.UU -/2.y3 u.uu uvu u.uu u.uu v.vv u.vv v.vv J~3L IL I.II oaicvo.4y rv iv is a.n6s vv 146 L~LL. O/I W RP 26.93 0.00 0.00 -46.00 26.93 0.00 0.00 0.00 0.00 0.00 0.00 5932121.11 687206. 49 N 70 13 9.953 W 148 29 22. 671 GYD CT CMS 96.93 0.03 301.49 24.00 96.93 -0.01 0.02 0.02 0.01 -0.02 0.04 5932121.12 687206. 47 N 7013 9.953 W 148 29 22. 671 Gyrodata 5/3/9 196.93 0.05 242.99 124.00 196.93 -0.07 0.08 0.08 0.00 -0.08 0.04 5932121.11 687206. 41 N 70 13 9.953 W 148 29 22. 673 296.93 0.11 222.60 224.00 296.93 -0.20 0.22 0.20 -0.09 -0.18 0.07 5932121.02 687206. 31 N 70 13 9.952 W 148 29 22. 676 396.93 0.16 204.22 324.00 396.93 -0.39 0.45 0.42 -0.29 -0.30 0.07 5932120.82 687206. 19 N 70 13 9.951 W 148 29 22. 680 496.93 0.15 183.00 424.00 496.93 -0.56 0.72 0.66 -0.54 -0.37 0.06 5932120.56 687206. 14 N 70 13 9.948 W 148 29 22. 681 596.93 0.14 161.63 524.00 596.93 -0.64 0.97 0.86 -0.79 -0.34 0.05 5932120.31 687206. 17 N 70 13 9.946 W 148 29 22. 680 696.93 0.10 166.55 624.00 696.93 -0.67 1.18 1.03 -0.99 -0.28 0.04 5932120.11 687206. 24 N 70 13 9.944 W 148 29 22. 679 796.93 0.05 172.85 724.00 796.93 -0.70 1.31 1.15 -1.12 -0.25 0.05 5932119.99 687206. 27 N 70 13 9.942 W 148 29 22. 678 896.93 0.21 156.40 824.00 896.93 -0.72 1.54 1.34 -1.33 -0.17 0.16 5932119.78 687206. 35 N 70 13 9.940 W 148 29 22. 676 996.93 0.38 138.74 924.00 996.93 -0.63 2.05 1.75 -1.75 0.12 0.19 5932119.37 687206. 65 N 70 13 9.936 W 148 29 22. 1096.93 0.49 149.01 1023.99 1096.92 -0.49 2.80 2.43 -2.36 0.56 0.13 5932118.76 687207. 11 N 70 13 9.930 W 148 29 22. 1196.93 0.61 160.75 1123.99 1196.92 -0.50 3.76 3.37 -3.23 0.95 0.16 5932117.90 687207. 52 N 70 13 9.922 W 148 29 22. 643 1296.93 0.62 168.54 1223.98 1296.91 -0.68 4.83 4.44 -4.26 1.24 0.08 5932116.88 687207. 83 N 70 13 9.911 W 148 29 22. 635 1396.93 0.63 176.13 1323.98 1396.91 -1.00 5.92 5.52 -5.34 1.38 0.08 5932115.80 687208. 00 N 70 13 9.901 W 148 29 22. 631 1496.93 0.72 197.25 1423.97 1496.90 -1.63 7.09 6.61 -6.49 1.23 0.26 5932114.65 687207. 88 N 70 13 9.889 W 148 29 22. 635 1596.93 0.81 219.09 1523.96 1596.89 -2.68 8.41 7.66 -7.64 0.60 0.30 5932113.49 687207. 28 N 70 13 9.878 W 148 29 22. 653 1696.93 0.69 227.14 1623.95 1696.88 -3.89 9.71 8.60 -8.60 -0.29 0.16 5932112.51 687206. 42 N 70 13 9.869 W 148 29 22. 679 1796.93 0.57 234.46 1723.95 1796.88 -4.95 10.81 9.37 -9.30 -1.13 0.14 5932111.79 687205. 59 N 70 13 9.862 W 148 29 22. 704 1896.93 0.43 225.31 1823.94 1896.87 -5.80 11.68 10.01 -9.85 -1.80 0.16 5932111.22 687204. 93 N 70 13 9.856 W 148 29 22. 723 1996.93 0.30 215.29 1923.94 1996.87 -6.38 12.32 10.56 -10.33 -2.22 0.14 5932110.73 687204. 53 N 70 13 9.852 W 148 29 22. 735 2096.93 0.40 204.11 2023.94 2096.87 -6.87 12.93 11.15 -10.86 -2.52 0.12 5932110.19 687204. 24 N 70 13 9.847 W 148 29 22. 744 2196.93 0.53 192.88 2123.94 2196.87 -7.42 13.73 11.95 -11.63 -2.76 0.16 5932109.42 687204. 02 N 70 13 9.839 W 148 29 22. 751 2296.93 0.60 166.69 2223.93 2296.86 -7.81 14.70 12.89 -12.59 -2.74 0.26 5932108.46 687204 .06 N 70 13 9.830 W 148 29 22. 750 SurveyEditor Ver SP 2.1 Bld( users) 13-03\13-03\13-03A\13-03A Generated 8/4/2009 2:08 PM Page 1 of 7 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS Tie-In Survey TOW (Blind) GYD GC SS L:i`Jb.`J3 V.00 i Jy. / L GJLJ.~3 LJ.7V.00 -/ ./ V i J.oV 1 J. / Y - 1 J.JJ c.GY ~ y r ~vt..'J i v i v i J ~. v~v r r i ~tv c.a t:t.. i ~v 2496.93 0.76 132.96 2423.92 2496.85 -7.35 17.06 14.52 -14.46 -1.37 0.12 5932106.62 687205.48 N 70 13 9. 811 W 148 29 22.711 2596.93 0.85 127.26 2523.91 2596.84 -6.76 18.46 15.36 -15.36 -0.30 0.12 5932105.75 687206.58 N 70 13 9. 802 W 148 29 22.679 2696.93 0.97 146.21 2623.90 2696.83 -6.28 20.03 16.53 -16.51 0.77 0.32 5932104.62 687207.67 N 70 13 9. 791 W 148 29 22.648 2796.93 1.71 124.05 2723.87 2796.80 -5.38 22.34 18.22 -18.05 2.47 0.89 5932103.13 687209.41 N 70 13 9. 776 W 148 29 22.599 2896.93 5.48 103.64 2823.66 2896.59 -0.88 28.56 21.69 -20.01 8.35 3.92 5932101.31 687215.34 N 70 13 9. 757 W 148 29 22.428 2996.93 6.57 74.43 2923.13 2996.06 8.49 38.84 26.96 -19.60 18.51 3.21 5932101.97 687225.48 N 70 13 9. 761 W 148 29 22.133 3096.93 9.42 60.06 3022.15 3095.08 22.29 52.67 34.11 -13.98 31.11 3.46 5932107.91 687237.94 N 70 13 9. 816 W 148 29 21.767 3196.93 12.36 55.23 3120.34 3193.27 41.00 71.55 47.15 -3.79 47.00 3.08 5932118.49 687253.57 N 70 13 9. 916 W 148 29 21.306 3246.93 13.30 50.66 3169.10 3242.03 51.84 82.65 55.92 2.91 55.84 2.77 5932125.40 687262.24 N 70 13 9. 982 W 148 29 21.049 3271.93 13.74 48.25 3193.40 3266.33 57.47 88.50 60.65 6.71 60.28 2.86 5932129.31 687266.58 N 70 13 10. 019 W 148 29 20.920 3296.93 14.17 45.83 3217.67 3290.60 63.21 94.52 65.59 10.82 64.69 2.90 5932133.53 687270.89 N 70 13 10. 060 W 148 29 20.7 3321.93 14.82 45.62 3241.87 3314.80 69.11 100.78 70.82 15.18 69.17 2.61 5932138.00 687275.26 N 70 13 10. 103 W 148 29 20.6 3346.93 15.27 46.41 3266.01 3338.94 75.25 107.27 76.42 19.69 73.84 1.98 5932142.63 687279.82 N 70 13 10. 147 W 148 29 20.52 3371.93 15.93 46.78 3290.09 3363.02 81.63 113.99 82.39 24.31 78.73 2.67 5932147.36 687284.58 N 70 13 10. 192 W 148 29 20.385 3396.93 16.56 47.86 3314.09 3387.02 88.29 120.99 88.76 29.05 83.87 2.79 5932152.23 687289.61 N 70 13 10. 239 W 148 29 20.235 3421.93 17.09 48.11 3338.02 3410.95 95.21 128.22 95.46 33.89 89.24 2.14 5932157.20 687294.86 N 70 13 10. 287 W 148 29 20.079 3446.93 17.81 49.45 3361.87 3434.80 102.41 135.72 102.52 38.83 94.88 3.30 5932162.28 687300.38 N 70 13 10. 335 W 148 29 19.915 3471.93 18.49 50.07 3385.63 3458.56 109.92 143.51 109.96 43.86 100.83 2.83 5932167.46 687306.19 N 70 13 10. 385 W 148 29 19.743 3496.93 19.20 50.98 3409.29 3482.22 117.74 151.58 117.74 48.99 107.06 3.07 5932172.74 687312.30 N 70 13 10. 435 W 148 29 19.562 3521.93 19.83 51.49 3432.85 3505.78 125.85 159.93 125.86 54.22 113.58 2.61 5932178.13 687318.68 N 70 13 10. 487 W 148 29 19.373 3546.93 20.56 52.14 3456.32 3529.25 134.25 168.56 134.29 59.56 120.36 3.05 5932183.63 687325.33 N 70 13 10. 539 W 148 29 19.176 3571.93 21.27 52.82 3479.67 3552.60 142.96 177.49 143.05 64.99 127.44 3.00 5932189.24 687332.27 N 70 13 10. 593 W 148 29 18.970 3596.93 22.26 53.23 3502.89 3575.82 152.03 186.76 152.19 70.57 134.84 4.01 5932195.00 687339.53 N 70 13 10. 647 W 148 2918.755 3621.93 22.83 54.00 3525.97 3598.90 161.43 196.34 161.67 76.25 142.56 2.57 5932200.87 687347.11 N 70 13 10. 703 W 148 29 18.531 3646.93 23.80 54.64 3548.93 3621.86 171.15 206.24 171.49 82.02 150.60 4.01 5932206.84 687355.00 N 70 13 10. 760 W 148 29 18.297 3671.93 24.83 54.95 3571.72 3644.65 181.28 216.53 181.72 87.96 159.01 4.15 5932212.98 687363.26 N 70 13 10. 818 W 148 29 18.053 3696.93 25.70 55.31 3594.32 3667.25 191.79 227.20 192.33 94.06 167.76 3.53 5932219.29 687371.86 N 70 13 10. 878 W 148 29 17.799 3721.93 26.73 55.76 3616.75 3689.68 202.69 238.24 203.33 100.30 176.87 4.20 5932225.76 687380.81 N 70 13 10 .940 W 148 29 17.535 3746.93 27.58 56.17 3639.00 3711.93 213.95 249.65 214.71 106.69 186.33 3.48 5932232.38 687390.10 N 70 13 11 .003 W 148 29 17.~ 3771.93 28.24 56.32 3661.09 3734.02 225.52 261.36 226.38 113.19 196.05 2.65 5932239.12 687399.66 N 70 13 11 .067 W 148 29 16. 3796.93 28.58 56.53 3683.08 3756.01 237.28 273.25 238.26 119.77 205.96 1.42 5932245.94 687409.41 N 70 13 11 .131 W 148 29 16.690 3821.93 28.77 56.60 3705.01 3777.94 249.15 285.25 250.23 126.38 215.98 0.77 5932252.80 687419.25 N 70 13 11 .196 W 148 29 16.399 3846.93 28.93 56.67 3726.91 3799.84 261.08 297.31 262.28 133.01 226.05 0.65 5932259.68 687429.16 N 70 13 11 .262 W 148 29 16.106 3871.93 29.10 56.72 3748.77 3821.70 273.08 309.44 274.39 139.67 236.18 0.69 5932266.59 687439.12 N 70 13 11 .327 W 148 29 15.812 3896.93 29.29 56.72 3770.59 3843.52 285.15 321.63 286.58 146.36 246.38 0.76 5932273.53 687449.15 N 70 13 11 .393 W 148 29 15.516 3921.93 29.25 56.75 3792.40 3865.33 297.24 333.85 298.79 153.07 256.60 0.17 5932280.49 687459.20 N 70 13 11 .459 W 148 29 15.219 3946.93 29.28 56.95 3814.21 3887.14 309.34 346.07 311.00 159.75 266.83 0.41 5932287.42 687469.26 N 70 13 11 .524 W 148 29 14.922 3971.93 29.28 57.04 3836.02 3908.95 321.45 358.30 323.22 166.41 277.09 0.18 5932294.33 687479.35 N 70 13 11 .590 W 148 29 14.624 3980.00 29.30 57.04 3843.06 3915.99 325.36 362.25 327.16 168.56 280.40 0.25 5932296.56 687482.60 N 70 13 11 .611 W 148 29 14.528 3997.57 29.56 58.86 3858.36 3931.29 333.92 370.88 335.79 173.14 287.72 5.30 5932301.32 687489.80 N 70 13 11 .656 W 148 29 14.316 4027.97 30.83 60.75 3884.63 3957.56 349.15 386.17 351.08 180.82 300.93 5.22 5932309.33 687502.82 N 70 13 11 .732 W 148 29 13.932 4056.46 32.70 63.37 3908.86 3981.79 364.12 401.17 366.05 187.84 314.18 8.15 5932316.68 687515.90 N 70 13 11 .801 W 148 29 13.547 SurveyEditor Ver SP 2.1 Bld( users) 13-03\13-03\13-03A\13-03A Generated 8/4/2009 2:08 PM Page 2 of 7 Comments Measured Inclination Azimuth SutrSea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de tt tt tt ft n n n de 100 n ttUS ftUS 4U/b.41 :S4.Vb bS.J`J J`.1L.7..7G J`J`J0.4.7 J/.7.IV 41L.14 J/0..70 1.7L..70 JL4.V0 O./O .77JLJG1.00 VO/JLJ.O/ IV /V IJ 11.04/ VV IYOG.7 IJ.GVV 4086.86 34.43 66.25 3934.16 4007.09 380.98 418.02 382.82 194.99 329.44 5.89 5932324.20 687530.97 N 70 13 11.871 W 148 29 13.104 4176.14 36.02 70.49 4007.10 4080.03 432.35 469.50 433.73 213.93 377.30 3.27 5932344.32 687578.34 N 70 13 12.057 W 148 29 11.714 4273.02 39.38 76.22 4083.76 4156.69 490.89 528.70 491.57 230.77 434.03 5.01 5932362.56 687634.64 N 70 13 12.223 W 148 29 10.067 4368.00 41.79 81.89 4155.92 4228.85 550.76 590.46 550.86 242.42 494.65 4.64 5932375.71 687694.95 N 70 13 12.337 W 148 29 8.306 MWD+IFR+MS 4463.25 42.74 88.34 4226.44 4299.37 610.84 654.48 610.94 247.84 558.42 4.66 5932382.70 687758.55 N 70 13 12.391 W 148 29 6.454 4494.85 43.33 90.37 4249.54 4322.47 630.48 676.05 630.80 248.08 579.98 4.76 5932383.48 687780.10 N 70 13 12.393 W 148 29 5.828 4590.30 43.36 88.59 4318.95 4391.88 690.11 741.56 691.73 248.67 645.48 1.28 5932385.70 687845.57 N 70 13 12.399 W 148 29 3.926 4686.30 43.23 85.89 4388.83 4461.76 751.04 807.39 754.50 251.84 711.23 1.93 5932390.50 687911.21 N 70 13 12.430 W 148 29 2.017 4781.18 43.60 83.78 4457.75 4530.68 812.37 872.59 817.83 257.71 776.16 1.58 5932397.98 687975.98 N 70 13 12.488 W 148 29 0.131 4876.94 44.65 80.71 4526.50 4599.43 876.04 939.25 883.43 266.72 842.21 2.49 5932408.62 688041.77 N 70 13 12.576 W 148 28 58.213 4971.24 45.25 76.12 4593.26 4666.19 940.81 1005.86 949.68 280.11 907.43 3.50 5932423.62 688106.64 N 70 13 12.708 W 148 28 56.3 5067.76 46.11 70.38 4660.72 4733.65 1009.10 1074.88 1018.68 300.02 973.49 4.35 5932445.16 688172.18 N 70 13 12.903 W 148 28 54.40 5163.04 46.54 65.30 4726.54 4799.47 1077.89 1143.78 1087.30 326.01 1037.27 3.88 5932472.72 688235.29 N 70 13 13.159 W 148 28 52.548 5257.62 46.31 65.04 4791.73 4864.66 1146.41 1212.30 1155.28 354.78 1099.46 0.31 5932503.03 688296.74 N 70 13 13.442 W 148 28 50.742 5352.93 45.05 60.06 4858.34 4931.27 1214.49 1280.46 1222.54 386.16 1159.95 3.96 5932535.90 688356.43 N 70 13 13.750 W 148 28 48.985 5447.52 45.32 59.04 4925.01 4997.94 1281.29 1347.56 1288.24 420.17 1217.79 0.82 5932571.33 688413.41 N 70 13 14.085 W 148 28 47.305 5545.20 45.02 58.51 4993.88 5066.81 1350.15 1416.84 1356.03 456.08 1277.03 0.49 5932608.70 688471.74 N 70 13 14.438 W 148 28 45.585 5640.82 44.52 58.45 5061.76 5134.69 1417.06 1484.18 1422.00 491.29 1334.44 0.52 5932645.31 688528.25 N 70 13 14.784 W 148 28 43.918 5735.54 47.67 61.00 5127.45 5200.38 1485.00 1552.41 1489.23 525.65 1393.38 3.85 5932681.12 688586.31 N 70 13 15.122 W 148 28 42.206 5832.16 47.70 64.32 5192.50 5265.43 1556.36 1623.85 1560.19 558.45 1456.82 2.54 5932715.49 688648.93 N 70 13 15.444 W 148 28 40.363 5927.29 47.72 63.56 5256.51 5329.44 1626.72 1694.22 1630.30 589.37 1520.04 0.59 5932747.96 688711.35 N 70 13 15.748 W 148 28 38.527 6022.85 47.34 64.38 5321.04 5393.97 1697.20 1764.71 1700.55 620.30 1583.38 0.75 5932780.45 688773.90 N 70 13 16.052 W 148 28 36.687 6118.22 46.20 62.19 5386.36 5459.29 1766.64 1834.19 1769.74 651.52 1645.45 2.06 5932813.20 688835.17 N 70 13 16.359 W 148 28 34.885 6213.91 46.43 59.06 5452.46 5525.39 1835.62 1903.38 1838.31 685.46 1705.73 2.38 5932848.62 688894.59 N 70 13 16.693 W 148 28 33.134 6309.01 46.04 58.21 5518.24 5591.17 1903.88 1972.06 1906.08 721.21 1764.37 0.76 5932885.81 688952.32 N 70 13 17.044 W 148 28 31.430 6405.46 46.36 57.32 5585.00 5657.93 1972.93 2041.67 1974,67 758.34 1823.26 0.74 5932924.39 689010.26 N 7013 17.409 W 148 28 29.720 6500.47 46.18 57.00 5650.68 5723.61 2040.94 2110.32 2042.27 795.57 1880.94 0.31 5932963.04 689067.00 N 70 13 17.775 W 148 28 28.044 6596.25 46.25 59.89 5716.96 5789.89 2109.62 2179.47 2110.64 831.75 1939.85 2.18 5933000.66 689124.99 N 70 13 18.131 W 148 28 26. 6691.22 46.65 60.26 5782.39 5855.32 2178.20 2248.30 2179.02 866.08 1999.50 0.51 5933036.47 689183.77 N 70 13 18.469 W 148 28 24. 6786.66 47.31 62.63 5847.51 5920.44 2247.83 2318.07 2248.52 899.43 2060.79 1.94 5933071.32 689244.21 N 7013 18.796 W 148 28 22.8 6882.98 46.75 63.13. 5913.16 5986.09 2318.26 2388.55 2318.86 931.56 2123.52 0.69 5933104.99 689306.12 N 70 13 19.112 W 148 28 20.998 6978.00 44.95 63.36 5979.35 6052.28 2386.41 2456.72 2386.94 962.25 2184.39 1.90 5933137.18 689366.21 N 70 1319.414 W 148 28 19.230 7073.58 44.93 63.28 6047.00 6119.93 2453.89 2524.24 2454.37 992.56 2244.72 0.06 5933168.98 689425.76 N 70 13 19.712 W 148 28 17.478 7168.76 45.36 61.89 6114.14 6187.07 2521.30 2591.71 2521.71 1023.63 2304.61 1.13 5933201.52 689484.86 N 70 13 20.017 W 148 28 15.738 7264.79 44.39 64.23 6182.19 6255.12 2589.00 2659.46 2589.37 1054.33 2365.00 1.99 5933233.71 689544.46 N 70 13 20.319 W 148 28 13.984 7360.37 43.75 64.18 6250.86 6323.79 2655.48 2725.94 2655.82 1083.26 2424.85 0.67 5933264.11 689603.58 N 70 13 20.603 W 148 28 12.245 7456.44 43.86 63.96 6320.20 6393.13 2721.97 2792.44 2722.28 1112.34 2484.66 0.20 5933294.66 689662.64 N 70 13 20.889 W 148 28 10.508 7551.78 44.31 63.18 6388.68 6461.61 2788.28 2858.77 2788.56 1141.87 2544.05 0.74 5933325.65 689721.28 N 70 13 21.179 W 148 28 8.783 7647.42 44.66 62.61 6456.92 6529.85 2855.25 2925.78 2855.49 1172.40 2603.71 0.56 5933357.65 689780.16 N 70 13 21.479 W 148 28 7.050 7743.18 44.97 64.46 6524.85 6597.78 2922.71 2993.27 2922.93 1202.47 2664.13 1.40 5933389.21 689839.81 N 70 13 21.775 W 148 28 5.295 7839.03 44.52 64.12 6592.93 6665.86 2990.18 3060.75 2990.38 1231.74 2724.92 0.53 5933419.98 689899.85 N 70 13 22.063 W 148 28 3.529 SurveyEditor Ver SP 2.1 Bld( users) 13-03\13-03\13-03A\13-03A Generated 8/4/2009 2:08 PM Page 3 of 7 I Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de ft ft ft n ft ft ft de o0 ft ftUS ftUS /y~ff.y.~ 45./1 b5.bl bb.7`J.`JU O/3L.03 3Ub/.41 JIL/.~O JVJ/.OI ILOV.Ja L/OO.// I.OJ V.7JJ4VV.V0 00.`f.`1J.'J.O/ IV /V IJ GG. JY4 YV 140 G0 I./VI 8029.38 45.05 65.02 6726.94 6799.87 3125.35 3195.92 3125.55 1288.77 2847.47 0.78 5933480.03 690020.95 N 70 13 22. 623 W 148 27 59.969 8124.26 46.01 67.16 6793.41 6866.34 3193.04 3263.63 3193.24 1316.20 2909.37 1.90 5933508.98 690082.14 N 70 13 22. 893 W 148 27 58.171 8220.06 45.42 65.97 6860.30 6933.23 3261.59 3332.21 3261.81 1343.47 2972.29 1.08 5933537.81 690144.36 N 70 13 23. 161 W 148 27 56.343 8316.94 43.68 65.81 6929.34 7002.27 3329.55 3400.17 3329.77 1371.23 3034.32 1.80 5933567.09 690205.68 N 70 13 23. 433 W 148 27 54.541 8411.79 45.61 65.78 6996.82 7069.75 3396.19 3466.82 3396.42 1398.56 3095.11 2.03 5933595.92 690265.77 N 70 13 23. 702 W 148 27 52.775 8508.21 44.77 66.46 7064.77 7137.70 3464.58 3535.22 3464.83 1426.25 3157.66 1.00 5933625.15 690327.61 N 70 13 23. 974 W 148 27 50.958 8603.29 46.20 64.42 7131.43 7204.36 3532.37 3603.01 3532.61 1454.44 3219.31 2.15 5933654.86 690388.54 N 70 13 24. 251 W 148 27 49.167 8698.90 45.41 63.62 7198.08 7271.01 3600.91 3671.56 3601.13 1484.47 3280.93 1.02 5933686.40 690449.39 N 7013 24. 546 W 148 27 47.377 8794.61 46.54 61.54 7264.60 7337.53 3669.65 3740.38 3669.85 1516.17 3342.01 1.96 5933719.61 690509.66 N 70 13 24. 858 W 148 27 45.603 8890.38 45.62 60.80 7331.03 7403.96 3738.48 3809.36 3738.63 1549.43 3402.44 1.11 5933754.35 690569.24 N 70 13 25. 184 W 148 27 43.847 8986.18 44.57 60.66 7398.66 7471.59 3806.14 3877.21 3806.25 1582.60 3461.63 1.10 5933788.98 690627.59 N 70 13 25. 510 W 148 27 42.1 9081.40 42.36 64.14 7467.78 7540.71 3871.55 3942.70 3871.63 1612.97 3519.64 3.42 5933820.78 690684.82 N 70 13 25. 809 W 148 27 40.4 9177.27 40.93 66.99 7539.42 7612.35 3935.24 4006.40 3935.32 1639.34 3577.62 2.48 5933848.58 690742.12 N 70 13 26. 068 W 148 27 38.75 9272.42 38.36 68.12 7612.68 7685.61 3995.88 4067.10 3995.98 1662.53 3633.71 2.81 5933873.15 690797.62 N 70 13 26. 296 W 148 27 37.128 9368.16 33.60 71.81 7690.15 7763.08 4051.89 4123.32 4052.02 1681.89 3686.48 5.46 5933893.81 690849.90 N 70 13 26. 486 W 148 27 35.595 9463.44 32.07 77.48 7770.22 7843.15 4102.78 4174.95 4102.99 1695.60 3736.24 3.60 5933908.75 690899.29 N 7013 26. 620 W 148 27 34.150 9558.80 30.71 81.65 7851.63 7924.56 4150.84 4224.60 4151.19 1704.63 3785.05 2.69 5933918.99 690947.86 N 70 13 26. 709 W 148 27 32.732 9655.28 29.55 87.52 7935.09 8008.02 4196.43 4273.00 4197.02 1709.24 3833.21 3.28 5933924.79 690995.89 N 70 13 26. 754 W 148 27 31.333 9750.50 26.11 89.14 8019.29 8092.22 4237.26 4317.44 4238.17 1710.57 3877.63 3.70 5933927.22 691040.26 N 70 13 26. 767 W 148 27 30.043 9845.38 25.61 87.47 8104.67 8177.60 4275.26 4358.82 4276.53 1711.79 3918.99 0.93 5933929.46 691081.58 N 70 13 26. 779 W 148 27 28.841 9939.87 27.26 83.35 8189.28 8262.21 4314.68 4400.87 4316.32 1715.19 3960.90 2.61 5933933.91 691123.38 N 70 13 26. 812 W 148 27 27.624 10035.98 25.88 84.21 8275.24 8348.17 4355.39 4443.86 4357.40 1719.86 4003.63 1.49 5933939.63 691165.98 N 7013 26. 858 W 148 27 26.383 10132.27 26.65 88.59 8361.60 8434.53 4395.03 4486.45 4397.52 1722.51 4046.13 2.17 5933943.34 691208.40 N 70 13 26. 884 W 148 27 25.148 10227.05 25.39 90.68 8446.77 8519.70 4432.83 4528.03 4435.91 1722.79 4087.70 1.64 5933944.65 691249.95 N 70 13 26. 886 W 148 27 23.941 10322.60 25.56 92.81 8533.03 8605.96 4469.52 4569.12 4473.30 1721.54 4128.77 0.98 5933944.41 691291.04 N 70 13 26. 874 W 148 27 22.748 10354.33 25.35 93.46 8561.68 8634.61 4481.55 4582.76 4485.59 1720.79 4142.39 1.10 5933944.01 691304.67 N 7013 26. 866 W 148 27 22.353 10435.10 23.71 96.00 8635.16 8708.09 4510.68 4616.29 4515.42 1718.05 4175.80 2.41 5933942.10 691338.14 N 70 13 26. 839 W 148 27 21.382 7" ~ 10501'md 10528.42 24.34 95.82 8720.40 8793.33 4543.28 4654.28 4548.92 1714.14 4213.59 0.68 5933939.12 691376.01 N 70 13 26. 800 W 148 27 20.285 10559.74 30.06 95.37 8748.24 8821.17 4555.60 4668.59 4561.59 1712.75 4227.84 18.27 5933938.09 691390.28 N 70 13 26. 787 W 148 27 19.8 10591.39 34.65 92.89 8774.97 8847.90 4570.40 4685.52 4576.80 1711.56 4244.72 15.09 5933937.31 691407.19 N 70 13 26. 775 W 148 27 19.3 10623.02 38.65 95.66 8800.34 8873.27 4586.86 4704.40 4593.73 1710.13 4263.54 13.68 5933936.35 691426.04 N 70 13 26. 761 W 148 27 18.834 10655.08 44.09 96.46 8824.40 8897.33 4605.00 4725.58 4612.45 1707.88 4284.60 17.05 5933934.63 691447.15 N 70 13 26. 738 W 148 27 18.222 10686.61 50.21 94.47 8845.83 8918.76 4624.92 4748.68 4633.02 1705.70 4307.60 19.95 5933933.02 691470.20 N 70 13 26. 717 W 148 27 17.554 10718.16 56.01 94.00 8864.76 8937.69 4646.94 4773.90 4655.74 1703.84 4332.76 18.42 5933931.79 691495.39 N 7013 26 .698 W 148 27 16.823 10749.88 60.28 90.89 8881.50 8954.43 4670.85 4800.84 4680.37 1702.71 4359.66 15.83 5933931.32 691522.31 N 70 13 26 .687 W 148 27 16.042 10781.16 65.64 89.32 8895.72 8968.65 4696.07 4828.69 4706.31 1702.67 4387.51 17.71 5933931.97 691550.15 N 70 13 26 .687 W 148 27 15.233 10813.49 71.30 90.96 8907.58 8980.51 4723.28 4858.75 4734.32 1702.59 4417.57 18.13 5933932.63 691580.20 N 70 13 26 .686 W 148 27 14.360 10844.76 76.33 89.87 8916.29 8989.22 4750.40 4888.77 4762.27 1702.37 4447.59 16.43 5933933.16 691610.22 N 70 13 26 .683 W 148 27 13.488 10877.08 77.91 87.96 8923.50 8996.43 4779.20 4920.28 4791.91 1702.97 4479.09 7.56 5933934.54 691641.69 N 70 13 26 .689 W 148 27 12.573 10908.61 78.05 88.44 8930.06 9002.99 4807.55 .4951.12 4821.07 1703.94 4509.92 1.55 5933936.28 691672.48 N 70 13 26 .698 W 148 27 11.678 10940.37 78.48 89.46 8936.52 9009.45 4835.97 4982.21 4850.37 1704.51 4541.01 3.42 5933937.62 691703.54 N 70 13 26 .704 W 148 27 10.775 10972.79 78.99 90.13 8942.85 9015.78 4864.84 5014.01 4880.19 1704.62 4572.80 2.57 5933938.52 691735.32 N 70 13 26 .705 W 148 27 9.851 ~, SurveyEditor Ver SP 2.1 Bld( users) 13-03\13-03\13-03A\13-03A Generated 8/4/2009 2:08 PM Page 4 of 7 Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de ft ft ft ft tt ft ft de 00 tt ttUS ttUS 11004.0:3 tsL.tiy yU.y/ t5y4/.// `JU'1U./U 4CyL.b/ bU44.i5b 4yVy.VV 1/V4.3J 4bU3.b4 lL./b by33yJi5.yy byl /bb.lb IV /V 73 Lb./VL VV 1415 L/ 25. `J55 11036.86 87.13 90.45 8950.63 9023.56 4922.13 5077.55 4939.53 1703.92 4636.34 13.01 5933939.39 691798.85 N 70 13 26.697 W 148 27 8. 006 11069.09 89.84 90.76 8951.48 9024.41 4951.19 5109.77 4969.67 1703.58 4668.55 8.46 5933939.85 691831.06 N 70 13 26.694 W 148 27 7. 070 11100.44 91.33 87.96 8951.16 9024.09 4979.74 5141.11 4999.24 1703.93 4699.90 10.12 5933940.98 691862.39 N 70 13 26.697 W 148 27 6. 160 11133.05 90.22 89.17 8950.72 9023.65 5009.63 5173.72 5030.17 1704.75 4732.49 5.04 5933942.60 691894.95 N 70 13 26.705 W 148 27 5. 213 11164.52 91.11 88.50 8950.35 9023.28 5038.42 5205.19 5060.00 1705.39 4763.95 3.54 5933944.02 691926.38 N 70 13 26.711 W 148 27 4. 299 11196.51 91.11 88.79 8949.73 9022.66 5067.72 5237.17 5090.37 1706.14 4795.93 0.91 5933945.57 691958.33 N 70 13 26.718 W 148 27 3. 370 11228.42 93.24 89.17 8948.52 9021.45 5096.85 5269.06 5120.60 1706.71 4827.81 6.78 5933946.93 691990.18 N 70 13 26.724 W 148 27 2. 444 11266.93 93.11 88.99 8946.39 9019.32 5131.96 5307.51 5157.07 1707.33 4866.25 0.58 5933948.50 692028.60 N 70 13 26.729 W 148 27 1. 328 11298.58 93.83 89.03 8944.47 9017.40 5160.82 5339.10 5187.07 1707.88 4897.84 2.28 5933949.83 692060.16 N 70 13 26.735 W 148 27 0. 410 11330.22 95.34 88.76 8941.95 9014.88 5189.66 5370.64 5217.05 1708.48 4929.37 4.85 5933951.22 692091.67 N 70 13 26.740 W 148 26 59. 494 11362.06 95.03 88.64 8939.07 9012.00 5218.70 5402.35 5247.25 1709.20 4961.07 1.04 5933952.73 692123.34 N 70 13 26.747 W 148 26 58. 57 11394.50 94.24 88.77 8936.45 9009.38 5248.30 5434.68 5278.06 1709.93 4993.40 2.47 5933954.26 692155.63 N 70 13 26.754 W 148 26 57. 63 11489.23 94.52 88.78 8929.21 9002.14 5334.75 5529.13 5368.13 1711.95 5087.83 0.30 5933958.62 692249.98 N 70 13 26.774 W 148 26 54. 892 11521.81 94.41 89.52 8926.68 8999.61 5364.39 5561.61 5399.07 1712.44 5120.31 2.29 5933959.91 692282.43 N 70 13 26.778 W 148 26 53. 949 11553.37 94.17 89.52 8924.31 8997.24 5393.02 5593.09 5429.01 1712.70 5151.78 0.76 5933960.95 692313.88 N 70 13 26.780 W 148 26 53. 034 11585.82 93.86 89.18 8922.04 8994.97 5422.52 5625.46 5459.85 1713.07 5184.15 1.42 5933962.12 692346.23 N 70 13 26.784 W 148 26 52. 094 11617.43 94.00 88.35 8919.88 8992.81 5451.38 5656.99 5490.01 1713.75 5215.67 2.66 5933963.58 692377.73 N 70 13 26.790 W 148 26 51. 179 11649.33 93.93 88.29 8917.67 8990.60 5480.61 5688.82 5520.53 1714.68 5247.48 0.29 5933965.30 692409.51 N 70 13 26.799 W 148 26 50. 255 11680.62 92.11 88.45 8916.02 8988.95 5509.29 5720.06 5550.50 1715.57 5278.72 5.84 5933966.97 692440.71 N 70 13 26.808 W 148 26 49. 347 11713.23 89.75 89.30 8915.49 8988.42 5539.11 5752.66 5581.70 1716.21 5311.31 7.69 5933968.41 692473.27 N 70 13 26.814 W 148 26 48. 401 11744.20 89.40 89.82 8915.72 8988.65 5567.28 5783.63 5611.25 1716.45 5342.28 2.02 5933969.42 692504.23 N 7013 26.816 W 148 26 47. 501 11776.09 90.50 90.78 8915.75 8988.68 5596.11 5815.52 5641.57 1716.28 5374.17 4.58 5933970.04 692536.11 N 7013 26.814 W 148 26 46. 575 11807.88 92.28 91.71 8914.98 8987.91 5624.61 5847.30 5671.64 1715.59 5405.94 6.32 5933970.14 692567.88 N 70 13 26.807 W 148 26 45. 652 11840.15 93.93 91.71 8913.23 8986.16 5653.40 5879.52 5702.05 1714.63 5438.15 5.11 5933969.98 692600.10 N 70 13 26.797 W 148 26 44. 717 11871.28 95.72 92.25 8910.61 8983.54 5681.04 5910.54 5731.31 1713.55 5469.15 6.00 5933969.68 692631.12 N 70 13 26.787 W 148 26 43. 816 11903.44 96.07 90.76 8907.31 8980.24 5709.67 5942.53 5761.58 1712.71 5501.13 4.74 5933969.63 692663.10 N 70 13 26.778 W 148 26 42 .887 11966.51 95.51 89.89 8900.95 8973.88 5766.40 6005.28 5821.41 1712.36 5563.87 1.63 5933970.83 692725.84 N 70 13 26.774 W 148 26 41 .065 11998.51 95.10 89.88 8897.99 8970.92 5795.30 6037.14 5851.89 1712.42 5595.74 1.28 5933971.69 692757.69 N 70 13 26.775 W 148 26 40 . 12030.35 94.62 89.68 8895.29 8968.22 5824.11 6068.87 5882.27 1712.54 5627.46 1.63 5933972.59 692789.40 N 70 13 26.776 W 148 26 39 . 12062.25 94.07 90.00 8892.87 8965.80 5852.98 6100.68 5912.74 1712.63 5659.27 1.99 5933973.47 692821.19 N 70 13 26.776 W 148 26 38 .2 12158.21 96.24 90.29 8884.25 8957.18 5939.49 6196.24 6004.20 1712.39 5754.84 2.28 5933975.60 692916.73 N 70 13 26.773 W 148 26 35 .518 12253.72 95.79 89.65 8874.24 8947.17 6025.61 6291.23 6095:31 1712.44 5849.82 0.82 5933978.01 693011.67 N 70 13 26.773 W 148 26 32 .760 12348.73 95.20 88.78 8865.15 8938.08 6111.86 6385.80 6186.48 1713.74 5944.38 1.10 5933981.65 693106.17 N 70 13 26.785 W 148 26 30 .013 ~I 12444.78 95.72 88.26 8856.01 8928.94 6199.54 6481.41 6279.05 1716.21 6039.96 0.76 5933986.49 693201.65 N 70 13 26.808 W 148 26 27 .237 12539.77 95.65 86.32 8846.60 8919.53 6287.00 6575.94 6371.13 1720.68 6134.38 2.03 5933993.30 693295.92 N 70 13 26.852 W 148 26 24 .494 12635.27 95.76 86.33 8837.10 8910.03 6375.53 6670.96 6464.11 1726.77 6229.21 0.12 5934001.74 693390.57 N 7013 26.911 W 148 26 21 .740 12730.32 96.00 86.11 8827.36 8900.29 6463.67 6765.51 6556.72 1733.00 6323.55 0.34 5934010.31 693484.72 N 70 13 26.971 W 148 26 18 .999 12826.18 95.89 88.01 8817.44 8890.37 6552.04 6860.86 6649.87 1737.89 6418.77 1.97 5934017.56 693579.78 N 70 13 27.019 W 148 26 16 .234 12921.74 95.86 91.97 8807.65 8880.58 6638.19 6955.92 6741.66 1737.91 6513.81 4.12 5934019.93 693674.78 N 70 13 27.018 W 148 26 13 .473 13017.04 94.55 93.21 8799.00 8871.93 6722.31 7050.82 6832.22 1733.62 6608.61 1.89 5934017.99 693769.66 N 70 13 26.975 W 148 26 10 .719 13112.88 91.70 94.00 8793.78 8866.71 6806.32 7146.51 6923.13 1727.60 6704.11 3.09 5934014.35 693865.27 N 70 13 26.915 W 148 26 7 .946 SurveyEditor Ver SP 2.1 Bld( users) 13-03\13-03\13-03A\13-03A Generated 8/4/2009 2:08 PM Page 5 of 7 ~~ Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de tt tt ft tt ft ft ft de 100 ft ttUS ftUS 1:i1Uti.tlt3 yU.li4 `.!'L./.i 8/`,il.BL 88b4. /5 b8`JU./8 /L4L.4y /U14.bb I/LI.y/ b/~~.~L 1./L by34Vl I.Uy Oy3y0l.ly IV /V 13Gb.8by VV 148 GOb.103 13304.11 90.67 90.21 8790.73 8863. 66 6976.03 7337.71 7106.28 1719.52 6895.10 2.65 5934011. 01 694056.40 N 70 13 26.834 W 148 26 2.398 13335.67 89.92 88.56 8790.57 8863. 50 7004.77 7369.27 7136.99 1719.86 6926.66 5.74 5934012. 13 694087.93 N 70 13 26.837 W 148 26 1.482 13367.74 88.07 86.62 8791.13 8864. 06 7034.38 7401.33 7168.40 1721.21 6958.69 8.36 5934014. 27 694119.92 N 70 13 26.850 W 148 26 0.551 13399.11 86.01 85.39 8792.75 8865. 68 7063.62 7432.66 7199.26 1723.39 6989.94 7.65 5934017. 23 694151.11 N 70 13 26.871 W 148 25 59.644 13432.23 84.04 84.44 8795.62 8868. 55 7094.64 7465.65 7231.87 1726.32 7022.81 6.60 5934020. 97 694183.88 N 70 13 26.899 W 148 25 58.689 13463.85 81.70 83.42 8799.55 8872. 48 7124.32 7497.03 7262.96 1729.63 7054.01 8.06 5934025. 06 694214.99 N 70 13 26.932 W 148 25 57.783 13495.20 80.69 83.91 8804.35 8877. 28 7153.67 7528.01 7293.68 1733.05 7084.80 3.57 5934029. 24 694245.68 N 70 13 26.965 W 148 25 56.888 13591.07 81.45 83.96 8819.23 8892. 16 7243.26 7622.71 7387.55 1743.06 7178.97 0.79 5934041. 58 694339.58 N 70 13 27.063 W 148 25 54.153 13686.36 81.39 84.98 8833.44 8906. 37 7332.10 7716.94 7480.84 1752.14 7272.76 1.06 5934052. 98 694433.10 N 70 13 27.151 W 148 25 51.428 13781.78 81.21 86.65 8847.88 8920. 81 7420.27 7811.26 7573.92 1759.02 7366.82 1.74 5934062. 19 694526.96 N 70 13 27.218 W 148 25 48.696 13878.63 81.42 87.27 8862.50 8935. 43 7509.07 7907.00 7668.11 1764.10 7462.43 0.67 5934069. 64 694622.40 N 70 13 27.267 W 148 25 45.9 13973.85 81.35 88.07 8876.77 8949. 70 7595.95 8001.14 7760.55 1767.93 7556.50 0.83 5934075. 80 694716.34 N 70 13 27.304 W 148 25 43.1 14069.04 83.25 89.59 8889.52 8962. 45 7682.23 8095.47 7852.84 1769.85 7650.80 2.55 5934080. 06 694810.56 N 70 13 27.322 W 148 25 40.44 14164.65 84.63 89.21 8899.62 8972. 55 7768.82 8190.55 7945.71 1770.85 7745.87 1.50 5934083. 41 694905.57 N 70 13 27.330 W 148 25 37.686 14260.22 85.01 89.30 8908.24 8981. 17 7855.61 8285.72 8038.79 1772.08 7841.04 0.41 5934087. 01 695000.68 N 70 13 27.342 W 148 25 34.922 14355.85 84.53 90.63 8916.96 8989. 89 7941.95 8380.96 8131.72 1772.14 7936.27 1.47 5934089. 43 695095.87 N 70 13 27.341 W 148 25 32.156 14451.47 84.70 90.26 8925.93 8998. 86 8027.92 8476.15 8224.49 1771.40 8031.46 0.42 5934091. 05 695191.05 N 70 13 27.333 W 148 25 29.391 14547.51 84.94 91.53 8934.61 9007. 54 8113.97 8571.80 8317.59 1769.91 8127.10 1.34 5934091. 93 695286.68 N 70 13 27.317 W 148 25 26.613 14579.25 86.59 91.82 8936.95 9009. 88 8142.25 8603.45 8348.31 1768.98 8158.74 5.28 5934091. 79 695318.33 N 70 13 27.308 W 148 25 25.694 14610.85 88.03 92.17 8938.43 9011. 36 8170.38 8635.02 8378.91 1767.88 8190.28 4.69 5934091 .48 695349.90 N 70 13 27.297 W 148 25 24.778 14642.78 89.81 91.93 8939.03 9011. 96 8198.81 8666.94 8409.86 1766.74 8222.18 5.63 5934091 .13 695381.81 N 70 13 27.285 W 148 25 23.851 14674.57 91.22 91.84 8938.75 9011. 68 8227.17 8698.73 8440.70 1765.70 8253.95 4.44 5934090 .87 695413.60 N 70 13 27.275 W 148 25 22.929 14706.48 92.73 91.82 8937.65 9010. 58 8255.63 8730.62 8471.66 1764.68 8285.83 4.73 5934090 .64 695445.49 N 7013 27.264 W 148 25 22.003 14738.35 94.14 91.03 8935.74 9008. 67 8284.12 8762.43 8502.60 1763.89 8317.63 5.07 5934090 .64 695477.30 N 70 13 27.256 W 148 25 21.079 14770.57 95.76 91.89 8932.96 9005. 89 8312.86 8794.53 8533.83 1763.07 8349.72 5.69 5934090 .62 695509.39 N 70 13 27.248 W 148 25 20.147 14802.45 96.96 92.35 8929.43 9002. 36 8341.06 8826.21 8564.57 1761.90 8381.38 4.03 5934090 .23 695541.07 N 70 13 27.236 W 148 25 19.228 14834.22 98.17 93.39 8925.25 8998 .18 8368.90 8857.71 8595.03 1760.32 8412.83 5.00 5934089 .44 695572.55 N 70 13 27.220 W 148 25 18.314 14866.57 99.35 95.63 8920.32 8993 .25 8396.73 8889.68 8625.71 1757.81 8444.70 7.75 5934087 .71 695604.47 N 70 13 27.195 W 148 25 17.388 14897.90 100.54 96.69 8914.91 8987 .84 8423.14 8920.54 8655.08 1754.50 8475.38 5.05 5934085 .17 695635.22 N 70 13 27.162 W 148 25 16.4 14930.38 100.92 97.80 8908.86 8981 .79 8450.13 8952.45 8685.27 1750.47 8507.04 3.56 5934081 .93 695666.97 N 70 13 27.122 W 148 25 15.5 14961.71 100.12 99.12 8903.14 8976 .07 8475.83 8983.25 8714.20 1745.94 8537.51 4.87 5934078 .15 695697.54 N 70 13 27.077 W 148 25 14.693 14993.70 99.60 101.00 8897.66 8970 .59 8501.63 9014.77 8743.51 1740.44 8568.54 6.01 5934073 .42 695728.69 N 70 13 27.023 W 148 25 13.792 15025.38 98.97 103.63 8892.55 8965 .48 8526.50 9046.03 8772.12 1733.77 8599.08 8.43 5934067 .51 695759.39 N 70 13 26.957 W 148 25 12.905 15057.37 98.24 105.99 8887.76 8960 .69 8550.79 9077.66 8800.51 1725.68 8629.66 7.64 5934060 .19 695790.16 N 70 13 26.877 W 148 25 12.017 15089.04 97.65 107.35 8883.38 8956 .31 8574.23 9109.03 8828.22 1716.68 8659.71 4.64 5934051 .94 695820.42 N 70 13 26.788 W 148 25 11.145 15120.99 97.34 110.40 8879.22 8952 .15 8597.06 9140.71 8855.64 1706.44 8689.68 9.51 5934042 .44 695850.63 N 70 13 26.687 W 148 25 10.275 15152.65 97.38 111.18 8875.16 8948 .09 8618.96 9172.11 8882.31 1695.29 8719.03 2.45 5934032 .03 695880.25 N 70 13 26.577 W 148 25 9.423 15184.67 97.48 112.45 8871.02 8943 .95 8640.69 9203.86 8909.01 1683.49 8748.51 3.95 5934020 .96 695910.01 N 70 13 26.461 W 148 25 8.567 15216.63 97.59 115.27 8866.83 8939 .76 8661.54 9235.54 8935.06 1670.68 8777.48 8.75 5934008 .87 695939.29 N 70 13 26.334 W 148 25 7.726 15248.56 97.73 116.91 8862.57 8935 .50 8681.42 9267.19 8960.40 1656.76 8805.90 5.11 5933995 .67 695968.04 N 70 13 26.197 W 148 25 6.901 15280.35 97.83 118.59 8858.27 8931 .20 8700.49 9298.68 8985.10 1642.10 8833.77 5.25 5933981 .70 695996.27 N 70 13 26.052 W 148 25 6.092 15311.65 98.21 121.28 8853.90 8926 .83 8718.30 9329.68 9008.70 1626.63 8860.63 8.60 5933966 .90 696023.50 N 70 13 25.900 W 148 25 5.312 SurveyEditor Ver SP 2.1 Bld( users) 13-03\13-03\13-03A\13-03A Generated 8/4/2009 2:08 PM Page 6 of 7 S !~ J• t~ Comments Measured Inclination Azimuth SulrSea ND TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North n de de n tt ft ft n tt tt de 100 n ftUS ttUS 15344.01 ytS.l/ 111.~J'L 884y.Ly 2f`JLG.'LL 8/35./U `J3bI./1 `JV3L.34 IbU`J.bl 888/./b S.UC b`J33`J5U.5b 15375.91 98.28 125.14 8844.73 8917.66 8751.95 9393.28 9054.96 1591.95 8913.93 6.90 5933933.55 15406.69 98.52 127.52 8840.23 8913.16 8766.56 9423.73 9075.97 1573.91 8938.45 7.69 5933916.13 15439.32 98.76 129.34 8835.33 8908.26 8781.00 9455.99 9097.41 1553.86 8963.72 5.56 5933896.71 15471.15 98.76 131.26 8830.48 8903.41 8794.15 9487.45 9117.60 1533.51 8987.72 5.96 5933876.97 15503.21 98.62 132.88 8825.63 8898.56 8806.50 9519.14 9137.26 1512.28 9011.24 5.01 5933856.33 15535.67 97.90 134.92 8820.97 8893.90 8818.07 9551.26 9156.43 1490.00 9034.39 6.60 5933834.63 15567.02 97.31 137.55 8816.82 8889.75 8828.07 9582.34 9174.02 1467.56 9055.88 8.53 5933812.74 15598.51 96.86 139.23 8812.94 8885.87 8837.00 9613.58 9190.80 1444.20 9076.63 5.48 5933789.90 15630.03 96.52 141.38 8809.26 8882.19 8844.95 9644.89 9206.80 1420.11 9096.62 6.86 5933766.31 15661.75 96.65 143.07 8805.63 8878.56 8851.92 9676.40 9222.07 1395.21 9115.92 5.31 5933741.90 15693.95 97.00 144.96 8801.80 8874.73 8858.02 9708.37 9236.77 1369.34 9134.71 5.93 5933716.50 15725.80 97.34 146.61 8797.82 8870.75 8863.09 9739.97 9250.52 1343.21 9152.48 5.25 5933690.82 15757.74 97.79 148.76 8793.62 8866.55 8867.12 9771.63 9263.42 1316.45 9169.40 6.82 5933664.50 15789.69 98.24 150.60 8789.16 8862.09 8870.06 9803.27 9275.40 1289.14 9185.37 5.87 5933637.59 15821.48 97.38 150.82 8784.84 8857.77 8872.42 9834.77 9286.88 1261.67 9200.78 2.79 5933610.52 15853.14 95.07 149.93 8781.41 8854.34 8874.97 9866.24 9298.62 1234.32 9216.34 7.81 5933583.56 15885.37 93.69 151.57 8778.95 8851.88 8877.35 9898.37 9310.51 1206.28 9232.04 6.64 5933555.92 15980.90 93.73 151.62 8772.77 8845.70 8883.03 9993.70 9345.04 1122.43 9277.39 0.07 5933473.22 16076.31 92.46 151.61 8767.62 8840.55 8888.68 10088.97 9380.35 1038.61 9322.68 1.33 5933390.56 16171.86 95.17 153.59 8761.26 8834.19 8892.69 10184.30 9415.00 953.98 9366.55 3.51 5933307.05 16267.89 92.89 155.86 8754.51 8827.44 8893.16 10280.09 9447.34 867.37 9407.44 3.35 5933221.48 Last Survey 16282.45 93.97 155.83 8753.64 8826.57 8892.95 10294.62 9452.06 854.11 9413.39 7.42 5933208.38 TD (Projected) 16320.00 93.97 155.83 8751.04 8823.97 8892.41 10332.08 9464.31 819.93 9428.73 0.00 5933174.59 Survey Type: Definitive Survey NOTES: GYD CT CMS - (Gyrodata -cont. casing m/s -- Gyrodata multishot surveys with continuous toll (RGS-CT) in casing. OD 13-3/8" or less. ) GYD GC SS - (Gyrodata - gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD + IFR + MS - (In-fiel d referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) (ftUSI Easting (X) fftUSl Surface : 2054 FSL 7 FEL S14 T10N R14E UM 5932121.11 687206.49 BHL : 2868 FSL 928 FEL S18 T10N R15E UM 5933174.59 696611.39 b`JbVb I.V4 IV /V 13 Lb./3Z VV 148 GO 4.OLb 696077.63 N 70 13 25.558 W 148 25 3.765 696102.60 N 70 13 25.381 W 148 25 3.053 696128.36 N 70 13 25.183 W 148 25 2.320 696152.85 N 70 13 24.983 W 148 25 1.624 696176.89 N 70 13 24.774 W 148 25 0.941 696200.58 N 70 13 24.554 W 148 25 0.270 696222.62 N 70 13 24.333 W 148 24 59.647 696243.94 N 70 13 24.103 W 148 24 59.045 696264.53 N 70 13 23.866 W 148 24 58.465 696284.44 N 70 13 23.621 W 148 24 57.905 696303.86 N 70 13 23.366 W 148 24 57.3 696322.27 N 70 13 23.109 W 148 24 56.84 696339.85 N 70 13 22.846 W 148 24 56.355 696356.49 N 70 13 22.577 W 148 24 55.892 696372.58 N 70 13 22.307 W 148 24 55.445 696388.81 N 70 13 22.037 W 148 24 54.994 696405.20 N 70 13 21.762 W 148 24 54.539 696452.61 N 70 13 20.936 W 148 24 53.225 696499.96 N 70 13 20.111 W 148 24 51.913 696545.91 N 70 13 19.279 W 148 24 50.642 696588.94 N 70 13 18.426 W 148 24 49.457 696595.21 N 70 13 18.296 W 148 24 49.285 696611.39 N 7013 17.959 W 148 24 48.841 •I SurveyEditor Ver SP 2.1 Bld( users) 13-03\13-03\13-03A\13-03A Generated 8/4/2009 2:08 PM Page 7 of 7 VELI_HEAJ = ~~.~ ~CTUA1'OR = :~E1EV = 76' IF. ELEV = 27.9' --- .OP = 3980 Flax Angle = 100.92 )atum MD = 10623' )atum TVD = 8800' SS )" CONDUCTOR, 94#, H-40, ID = 19.124" 109' 3-3/8" CSG, 72#, N-80, ID = 12.347" 2706' 9-5/8" Casing Cut 2218' Min ID = 3.725" @ 10332" 4-1 /2" HES XN NIPPLE HES EZSV 6708' Jet Cut 7200' -1/2" TBG-PC, 17#, L-80 BTC, .0232 bpf, ID = 4.892" ~~ 10814 -1/2" TBG-NPC, 12.6#, N-80, .0152 bpf, ID = 3.958" 10316' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 43 @ 10650' Note: SQE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10650'-10665' O 07/11/09 2-7/8" 6 10759'-10773' O 07/11/09 2-7/8" 6 10940'-10995' O 07/11/09 2-7/8" 6 11600'-11620' O 07/11/09 2-7/8" 6 11855'-11890' O 07/11/09 2-7/8" 6 11945'-12100' O 07/11/09 2-7/8" 6 12235'-12280' O 07/11/09 2-7/8" 6 12345'-12370' O 07/11/09 2-7/8" 6 12605'-12630' O 07/11/09 2-7/8" 6 12680'-13120' O 07/11/09 2-7/8" 6 13440'-13495' O 07/11/09 2-7/8" 6 13590'-13655' O 07/11/09 2-7/8" 6 13870'-13930' O 07/11/09 2-7/8" 6 13970'-14105' O 07/11/09 2-7/8" 6 14395'-14460' O 07/11/09 2-7/8" 6 14830'-14880' O 07/11/09 2-7/8" 6 15600'-15645' O 07/11/09 2-7/8" 6 15750'-16025' O 07/11/09 2-7/8" 6 16085'-16220' O 07/11/09 SAFJ~.Y NOTES: ***4-1 /2" CHROMETBG & LNR**" 13-03A 2119' 4-1 /2" X NIP, ID 3.813" ~ 2345' 9-5/8" Foc 2469' 9-5/8" FOC GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3687 3659 25 KBG-2 DOME BK 16 07/22/C 4 6646 5824 46 KBG-2 SO BK 20 07/22/C 3 8643 7232 46 KBG-2 DNIY BK 0 07/14/C 2 9803 8139 26 KBG-2 DMY BK 0 07/14/C 1 10200 8495 26 KBG-2 DMY BK 0 07/14/C 3,980' Top of 9 5/8"window 3,997' Bottom of 9 5/8"window '~"T' 16318' ~--~4-1/2" Liner, 12.6# 13Cr-80, VamTop 9-5/8" CSG, 47#, N-80, .0733 bpf, ID = 8.681" ~-j 11319' ~/~0000000000~ DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 03/18/79 PKR 141 ORIGINAL COMPLETION 07/24/09 TLH DRLG HO CORRECTIONS WELL: 13-03A 01/10/82 N1 ES RWO PERMIT No: 209048 09/05/08 OOP/PJC DRAWING CORRECTIONS API No: 50-029-20325-01 03/02/09 OOP/PJC DRAWING CORRECTIONS SEC 14, T10N, R14E; 2054' FSL & 7' FEL 07/15/09 N9ES SIDETRACK (13-03A) 07/22/09 DAV/TLH GLV C/O BP Exploration (Alaska) 5,607' Estimated TOC based on losses 10236' 4-1/2" HES X Nip, ID 3.813" 10267' 7" x 4-1/2" BKR S-3 PKR ID=3.870" 10301' 4-1/2" HES X Nip, ID 3.813" 10332' 4-1/2" HES XN Nip, ID 3.725" 10342' 4-1/2" TBG, 12.6# 13 CR-80 10344' 4-1/2" WLEG ID=4.654" 10337' BKR 5"x7" Hanger/ LTP ID=4.193" 10504' 7" Csg, 26#, L-80, TCII ID=6.276" 13-03A PTD 209-048 AAA under, T,~otn~ls E (D4Aj From: Maunder, Thomas E {QOA) Sent:. Tuesday, July 14, 2Q09 14:Q2 AM To; 'Warren, Abigail M' Cc: Hobbs, Greg S (ANC); Tirpack, Robert B Subject: R€: 9 3-03A PTQ 209-048 Page 1 of 1 Abby, +~t a!, There is non to test the 13UPt `!"he 11 rk wi!! finished and the welt secured. 11! the SUP untlerg® trrairrterran~ as well? If ,the initial P t when the rig returns tts well worm is that we normally like to ~+itness. Torr- I!~aunder, R~ A ~U From: Warren, Alaigail M [mailto:Abigali,Warren@bp.com] Sent: Tuesday, July 14, 2009 9:56 AM To: Maunders Thomas E (QUA) Cc: Mobbs, Greg S (ANC); Tirpack, Robert B Sub3ect; 13-03A PTQ 2fl9-048 PTQ;2Q9-048 Tom, Nabors 9es is currently on 93-03A, we are in the process of running our completron and it should be landed by this afternoon by ^~ 2 p.m. We witl them go into circulating corrosion inhibi#or and then drop the ball and rod to se# the packer., test to 3500 psi for 30 min, test the annulus pressure to 3500 psi fQr 30 minutes. This operation should be done by this evening, and the TWC should be installed and tested by 10 prn tonight, We will proceed with Hippie down operations of the F3UF' with cleaning and prepping for Maintenance which is the next operation fops the rig. When fibs maintenance prep is done, the stack will be removed from the wellhead and the tree nippled up, potentially after midnight. With the well secured during these Nipple down and cleaning ©perations, and the tree installation being next, we were not planning on testing the BUP stack at midnight. It will be tested after its maintenance and inspection on the next well. We wanted to make you aware of this plan and make sure you concurred with !t. Please get back with me for any questions or comments. Thank you, Abby Warren BF'X~1 Drilling engineer Work: (907)564-5720 Cell; (907)240-9293 '7/14/2009 13-03A Cement Volumes PT1~9-048 ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Warren, Abigail M [Abigail.Warren@bp.com] Sent: Wednesday, June 24, 2009 4:33 PM To: Maunder, Thomas E (DOA) Subject: 13-03A Cement Volumes PTD 209-048 Tom, PTD 209-048 Sundry 309-185 Due to recent changes in the well plan (the higher KOP and the long string to surface), I wanted to give you the new volumes of cement that we will be pumping for the 7" job for this well. Casing Size: 7" 26#, L-80 Intermediate Liner Basis: Lead: -4978 of open hole with 30% Lead TOC: -5000' MD (1000' outside the window) Tail: 500' of open hole with 40% excess, plus 80' shoe track Tail TOC: -9978' MD (500' above 7" shoe depth) Total Cement Volume: Spacer 25 bbls of viscosified, 10.5 ppg weighted Spacer (Mud Push II) Lead 146.2bbls, 821 cuft, 297 sks 11.0 Ib/gal LiteCrete, -2.76 cuft/sk (planned) Tail 18.9 bbls, 106 cuft, 91 sks 15.8 Ib/gal Class G + adds -1.16 cuft/sk Temp BHST = 200° F, BHCT TBD by Schlumberger Please let me know if you need any other information Thanks Abby Warren BPXA Drilling Engineer Work: (907)564-5720 Cell: (907)240-9293 6/25/2009 13-03A ~ ~ Page 1 of ~ ~.,, Maunder, Thomas E (DOA) From: Warren, Abigail M [Abigail.Warren@bp.com] Sent: Thursday, June 18, 2009 4:24 PM To: Maunder, Thomas E (DOA) Subject: RE: 13-03A Tom, The old KOP was 6700' compared to the new KOP of -4000'. The 9-5/8" does have cement below the cut which was confirmed by a USIT log that was run. It is right below the top FOC which is at 2345', and we will be cutting above that point. It was very diffcult to get a plug set below the cut and we were not comfortable running a whipstock past this point. This spot was giving us significant issues and that is why the decision was made to move the KOP up higher. Thanks, Abby From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, June 18, 2009 4:19 PM To: Warren, Abigail M Cc: Roach, Frank Subject: RE: 13-03A Abby, It appears you are already on the well. Can you provide some additional operational information? I presume that 9-5/8" has cement below the cut, is that correct? Without going to the file, how much higher is the KOP? Thanks, Tom From: Warren, Abigail M [mailto:Abigail.Warren@bp.com] Sent: Thursday, June 18, 2009 4:13 PM To: Maunder, Thomas E (DOA) Cc: Roach, Frank Subject: 13-03A Tom, PTD 209-048 Sundry 309-185 13-03A had a cut and pull planned with a rerun of the 9-5/8". Due to a cretaceous leak that was found prerig and issues that we have had running through it, we have decided to kick out shallower in the well to cover this area and run a long 7" string to surface. To mitigate adding another spool, we will not be re-running the 9-5/8". Our cement top for the 7" is planned to be pumped 750' outside the window. Attached is the new Wellbore schematic and the new directional. 6/25/2009 TREE _ WELLHEAD= FMC ACTUATOR = AXELSON KB. ELEV = 76' BF. ELEV = ? KOP= Max Angle = Datum MD = Datum TV D = 8800' SS 20" CONDUCTOR, 94#, H-40, ID = 19.124" 109' ' 13-3/8" CSG, 72#, N-80, ID = 12.347" 2706' _ 9-5/8" Casing Cut 2220' Baker 9-5/8" WS -4000 HES ¢sv 4005' Jet Cut 7200' Min ID = X.XXX" @ XXXX' ~~ 5-1/2" TBG-PC, 17#, L-80 BTC, .0232 bpf, ID = 4.892" 11 10814 14-1/2" TBG-NPC, 12.6#, N-80, .0152 bpf, ID = 3.958" I~ 10316; PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 2-7/8" 2-7/8" 2-7/8" 2-7/8" 10623' ~ FISH - KINLEY CUTTER BAR 1 "-6" X 49" (1 11221' FISH -TBG TAIL DEBRIS (1' SHOT OFF 01, 9-5/8" CSG, 47#, N-80, .0733 bpf, ID = 8.681 " 11 13 -0 3 A SA NOTES: PROPOSED - ~~1~~S~c; 2000' 4-1/2" X NIP, ID 3.813" ' 2345' 9-5/8" FOC 2469' 9-5/8" FOC A 1 ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 3 4 5 r DATE REV BY COMMENTS DATE REV BY COMMENTS 03/18/79 PKR 141 ORIGINAL COMPLETION 09/21 /08 JRA/SV FISH @ 10217' (09/12/08) 01/10/82 N1 ES RWO 03/02/09 OOP/PJC DRAWING CORRECTIONS 12!03/05 SRB/TLH CMT & FISH (MILL) CORRECTIO 06/18/09 AMW Proposed Schematic 01/07/06 DAV/PJC FISH @ 10623' 03/08/08 JIM~TLH IBPSET(11/20/07) 09/05/08 OOP/PJC DRAWING CORRECTIONS I4-112" HES X Nip, ID 3.813" 7" x 4-1/2" BKR S-3 PKR ~~14-1/2" HES X Nip, ID 3.813" 4-1/2" HES XN Nip, ID 3.725" D WLEG ~~ 41/Z' lB",~ 128# 13 Q~80 ~ I 10323' I-I Hanger/ LTP 10473' 1~7" Casing, TCII 16314' I-14-1/2" Liner, 12.6# 13Cr-80 PRUDHOE BAY UNff WELL: 13-03A PERMIT No: API No: SEC 14, T10N, R14E, 2054' FSL & 7' FEL BP Exploration (Alaska) by DS13-03A (P17) Proposal Schlumberger Report Date: June 15, ZUU9 Survey 1 DLS Computation Method: Minimum Curvature / Lubmskl Client: BP Exploration Alaska Vertical Section Azimuth: 86.020° Field: Structure I Slot: Prudhoe Bay Unit - EOA DS-13 / 13-03 Vertical Section origin: 'O9 TVD Reference Datum: N 0.000 ft, E 0.000 ft Rotary Table well: 13-03 ed O~'~ ND Reference Elevation: 72.93 ft relative to MSL Borehole: Plan 13-03A ro~ A p Base Flange Elevation: 45.03 ft relative to MSL UWUAPI#: 500292032501 p Magnetic Declination: 22.724° Survey Name I Date: 13-03A (P17) /June 15, 2009 Total Field Strength: 57712.928 nT Tort 1 AHD 1 DDI I ERD ratio: 293.369° / 10334.38 ft / 6.739 / 1.146 Magnetic Dip: 80.884° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: June 20, 2009 Location LaVLong: N 70.21943148, W 148.48963076 Magnetic Declination Model: BGGM 2008 Location Grid NIE YIX: N 5932121.110 ftUS, E 687206.490 ftUS North Reference: True North Grid Convergence Angle: +1.42128859° Total Corr Mag North •> True North: +22,724° Grid Scale Factor: 0.99993981 Local Coordinates Referenced To: Well Head • Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty (ft) de) (de) ft (ft) ft ft) (ft) de (de 100 ft) Index ftUS) ftUS ) r.i ~n na nooc~n ~n/ aeo eo~oncc~ Ile-In SUNey 3`J/l.`J3 G`J.Lb O/.U4 3b30.VL 3yV8.70 Lol.7/ 100.'rl LI I.V.7 OA9R V.io ti. iJ a~JCCa-~.JJ VO/YI J.JJ - ~ •. ~+J.wiJJJVJ ~ Top Whipstock 3980.00 29.30 57.05 3843.06 3915.99 291.42 168.56 280.40 65.OOR 0.26 4.14 5932296.56 687482.60 N 70.21989197 W 148.48736890 -,? Base Whipstock 3996.00 30.16 60.51 3856.95 3929.88 298.47 172.67 287.18 --- 12.00 4.17 5932300.84 687489.28 N 70.21990319 W 148.48731418 Crv 4/100 4009.00 30.16 60.51 3868.19 3941.12 304.37 175.88 292.87 63.05R 0.00 4.18 5932304.19 687494.89 N 70.21991197 W 148.48726832 4100.00 31.96 66.65 3946.16 4019.09 347.73 196.69 334.89 57.79R 4.00 4.27 5932326.03 687536.38 N 70.21996881 W 148.48692934 4200.00 34.24 72.67 4029.95 4102.88 400.09 215.57 386.06 52.75R 4.00 4.36 5932346.17 687587.06 N 70.22002037 W 148.48651655 4300.00 36.78 77.99 4111.37 4184.30 457.13 230.18 442.22 48.41 R 4.00 4.45 5932362.17 687642.84 N 70.22006029 W 148.48606351 4400.00 39.53 82.69 4190.01 4262.94 518.57 240.46 503.10 44.72R 4.00 4.53 5932373.96 687703.44 N 70.22008837 W 148.48557245 4500.00 42.45 86.86 4265.49 4338.42 584.12 246.36 568.39 41.57R 4.00 4.61 5932381.48 687768.56 N 70.22010447 W 148.48504575 Crv 4/100 4583.61 45.00 90.00 4325.91 4398.84 641.84 247.90 626.14 97.21 L 4.00 4.67 5932384.45 687826.25 N 70.22010868 W 148.48457990 4600.00 44.92 89.08 4337.51 4410.44 653.40 248.00 637.72 96.56E 4.00 4.68 5932384.83 687837.83 N 70.22010893 W 148.4844864 4700.00 44.60 83.41 4408.55 4481.48 723.76 252.59 707.93 92.53E 4.00 4.75 5932391.17 687907.90 N 70.22012147 W 148.4839201 4800.00 44.57 77.72 4479.79 4552.72 793.58 264.09 777.13 88.47E 4.00 4.81 5932404.38 687976.78 N 70.22015286 W 148.48336194 4900.00 44.82 72.04 4550.91 4623.84 862.53 282.43 844.96 84.44E 4.00 4.87 5932424.39 688044.14 N 70.22020294 W 148.48281471 5000.00 45.34 66.44 4621.55 4694.48 930.26 307.53 911.11 80.48E 4.00 4.93 5932451.12 688109.64 N 70.22027148 W 148.48228106 UG3 5057.76 45.77 63.26 4662.00 4734.93 968.70 325.05 948.43 78.25E 4.00 4.96 5932469.57 688146.50 N 70.22031935 W 148.48198005 End Crv 5059.13 45.78 63.18 4662.96 4735.89 969.61 325.50 949.31 --- 4.00 4.96 5932470.03 688147.37 N 70.22032056 W 148.48197295 UG 1 6047.12 45.78 63.18 5352.00 5424.93 1622.16 644.95 1581.20 --- 0.00 5.20 5932805.04 688771.11 N 70.22119301 W 148.47687507 WS2 6908.87 45.78 63.18 5953.00 6025.93 2191.32 923.59 2132.36 - 0.00 5.35 5933097.25 689315.16 N 70.22195386 W 148.47242820 WS1 7328.94 45.78 63.18 6244.57 6317.50 2467.45 1058.77 2399.75 -- 0.00 5.40 5933239.01 689579.09 N 70.22232294 W 148.47027073 CM3 7559.23 45.78 63.18 6406.57 6479.50 2620.87 1133.88 2548.32 --- 0.00 5.43 5933317.77 689725.74 N 70.22252800 W 148.46907197 CM2 8296.24 45.78 63.18 6920.57 6993.50 3107.65 1372.18 3019.69 - 0.00 5.51 5933567.68 690191.03 N 70.22317855 W 148.46526836 WeIlDesign Ver SP 2.1 Bld( users) 13-03\13-03\Plan 13-03A\13-03A (P17) Generated 6/15/2009 11:08 AM Page 1 of 3 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty (ft) de) (de ) ft) (ft) ft) (ft) (ft) (de) (de 100ft) Index ftUS) (ftUS) t,rw~ ylVa.oc 40./0 oJ. /o Crv 4/100 9140.24 45.78 63. 18 9200.00 43.65 64. 71 9300.00 40.13 67. 56 9400.00 36.69 70. 86 9500.00 33.36 74. 72 9600.00 30.17 79. 31 9700.00 27.17 84. 84 End Crv 9778.45 25.00 90. 00 THRZ 9790.57 25.00 90. 00 BHRZ 9974.83 25.00 90. 00 TJB 10252.88 25.00 90. 00 TJA 10384.18 25.00 90. DO 10478.45 25.00 90 .00 7" Csg 10478.46 25.00 90. 00 Bld 12/100 10483.45 25.00 90 .00 10500.00 26.99 90 .00 TSHC 10554.63 33.54 90. 00 TSAD 10599.27 38.90 90. 00 10600.00 38.99 90 .00 10700.00 50.99 90 .00 10800.00 62.99 90 .00 10900.00 74.99 90 .00 End Bld Crv 6/100 End Crv Crv 6/100 13-03A Tgt 1 Fault End Crv Crv 6/100 13-03A Tgt 2 End Crv Crv 6/100 Target 3 /HO/.V/ 7509.19 7551.66 7626.10 7704.46 7786.35 7871.38 7959.12 8029.58 8040.57 8207.57 8459.57 8578.57 8664.00 8664.01 8668.53 8683.41 8730.57 8766.57 8767.14 8837.74 8892.12 8927.91 8943.55 8944.21 8944.21 8943.59 8918.18 8918.04 8908.86 8907.00 8902.29 8891.29 8832.99 8820.07 8820.00 8809.51 8790.81 8789.30 8786.42 / JVV.VV JVY'f. IY I VJY. VG JJJJ.G I 7582.12 3665.09 1645.08 3559.49 7624.59 3704.05 1663.55 3597.26 7699.03 3766.79 1690.60 7777.39 3826.22 1712.71 7859.28 3882.03 1729.76 7944.31 3933.96 1741.67 8032.05 3981.76 1748.39 8102.51 4016.22 1750.00 8113.50 4021.33 1750.00 8280.50 4099.01 1750.00 8532.50 4216.24 1750.00 8651.50 4271.59 1750.00 8736.93 4311.34 1750.00 8736.94 4311.34 1750.00 8741.46 4313.44 1750.00 8756.34 4320.68 1750.00 8803.50 4348.13 1750.00 8839.50 4374.44 1750.00 8840.07 4374.89 1750.00 8910.67 4445.29 1750.00 8965.05 4528.79 1750.00 9000.84 4621.74 1750.00 9016.48 4720.09 1750.00 9017.14 4745.13 1750.00 9017.14 5368.62 1750.00 9016.52 5403.49 1749.86 8991.11 6111.97 1744.19 8990.97 6115.81 1744.16 8981.79 6215.01 1742.93 8979.93 6227.19 1742.72 8975.22 6254.31 1742.20 8964.22 6304.96 1741.01 8905.92 6542.03 1734.70 8893.00 6603.17 1733.35 8892.93 6603.54 1733.34 8882.44 6681.38 1732.31 8863.74 6882.63 1730.45 8862.23 6900.57 1730.35 8859.35 6977.38 1731.34 3658.27 3716.30 3771.07 3822.30 3869.74 3904.17 3909.29 3987.16 4104.67 4160.16 4200.00 4200.00 4202.11 4209.37 4236.89 153.74R 152.65R 150.53R 147.95R 144.78R 140.88R 136.02R HS HS HS 0.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 12.00 12.00 4263.25 HS 12.00 4263.71 HS 12.00 4334.28 HS 12.00 4417.98 HS 12.00 4511.16 HS 12.00 4609.74 HS 12.00 4634.84 --- 12.00 5259.84 12.59R 0.00 5294.80 --- 6.00 6005.39 4.42R 0.00 6009.24 4.42R 6.00 6108.77 4.46R 6.00 6121.00 6.05R 6.00 6148.21 6.08R 6.00 6199.07 --- 6.00 6437.15 172.26E 0.00 6498.53 172.36E 6.00 6498.90 174.28E 6.00 6577.00 --- 6.00 6778.87 158.07E 0.00 6796.86 158.10E 6.00 6873.79 159.85E 6.00 5.59 5933853.86 690723.87 N 70.22392345 W 148.46091225 5.61 5933873.27 690761.16 N 70.22397388 W 148.46060748 5.64 5933901.82 690821.48 N 70.22404770 W 148.46011512 5.66 5933925.36 690878.94 N 70.22410801 W 148.45964684 5.69 5933943.76 690933.26 N 70.22415451 W 148.45920492 5.71 5933956.94 690984.18 N 70.22418699 W 148.45879153 5.73 5933964.83 691031.44 N 70.22420527 W 148.45840868 5.75 5933967.29 691065.81 N 70.22420963 W 148.45813095 5.75 5933967.42 691070.93 N 70.22420962 W 148.45808962 5.75 5933969.35 691148.78 N 70.22420951 W 148.4574613 5.77 5933972.27 691266.24 N 70.22420933 W 148.4565132 5.77 5933973.64 691321.71 N 70.22420925 W 148.45606551 5.77 5933974.63 691361.53 N 70.22420919 W 148.45574410 5.77 5933974.63 691361.54 N 70.22420919 W 148.45574406 5.77 5933974.68 691363.65 N 70.22420919 W 148.45572705 5.78 5933974.86 691370.90 N 70.22420918 W 148.45566851 5.81 5933975.55 691398.41 N 70.22420913 W 148.45544649 5.83 5933976.20 691424.76 N 70.22420909 W 148.45523374 5.83 5933976.21 691425.22 N 70.22420909 W 148.45523005 5.88 5933977.96 691495.76 N 70.22420898 W 148.45466071 5.93 5933980.04 691579.43 N 70.22420885 W 148.45398539 5.97 5933982.35 691672.58 N 70.22420870 W 148.45323360 6.02 5933984.79 691771.12 N 70.22420854 W 148.45243819 6.03 5933985.42 691796.22 N 70.22420849 W 148.45223568 6.10 5934000.92 692420.98 N 70.22420737 W 148.44719303 6.11 5934001.65 692455.93 N 70.22420693 W 148.44691097 6.19 5934013.60 693166.40 N 70.22418997 W 148.44117778 6.19 5934013.66 693170.25 N 70.22418988 W 148.4411467 6.21 5934014.90 693269.77 N 70.22418631 W 148.4403437 6.22 5934015.00 693282.00 N 70.22418571 W 148.44024509 6.22 5934015.16 693309.22 N 70.22418424 W 148.44002549 6.24 5934015.22 693360.09 N 70.22418086 W 148.43961517 6.26 5934014.82 693598.23 N 70.22416308 W 148.43769435 6.28 5934015.00 693659.63 N 70.22415925 W 148.43719911 6.28 5934015.00 693660.00 N 70.22415923 W 148.43719611 6.30 5934015.90 693738.09 N 70.22415621 W 148.43656601 6.32 5934019.05 693939.93 N 70.22415064 W 148.43493730 6.32 5934019.39 693957.92 N 70.22415032 W 148.43479216 6.34 5934022.29 694034.80 N 70.22415285 W 148.43417146 WeIlDesign Ver SP 2.1 Bld( users) 13-03\13-03\Plan 13-03A\13-03A (P17) Generated 6/15/2009 11:08 AM Page 2 of 3 11000.00 11025.11 11650.11 11685.08 12396.15 12400.00 12500.00 12512.37 12540.00 12592.05 12837.24 12900.00 12900.38 12979.21 13181.95 13200.00 13277.01 86.99 90.00 90.00 92.05 92.05 92.28 98.26 99.00 100.65 103.75 103.75 100.02 100.00 95.29 95.29 94.29 90.00 90.00 90.00 90.00 90.46 90.46 90.48 90.94 91.00 91.18 91.52 91.52 91.00 91.00 90.53 90.53 90.12 88.40 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty (ft) (de) (de) ft) (ft) ft) (ft) ft) (de ) (de 1100ft) Index ftUS) ~nnn7 cn ftUS) CnAnC~ ~c n1 7n 77A1cA 4r\ \A/ FAQ A'2'10S2Ftl~ ISSUU.VV if tf./ ~ 8/.`JL b/bO.tlb bb~y.01 /l1UV.JJ 1/JL.VO 00 yo.lo IJ~.OYL v.w V.J:J JJJYVLJ.VV - 13400.00 83.07 85.85 8793.84 8866.77 7100.04 1737.49 6996.31 159.69E 6.00 6.37 5934031.48 694157.12 N 70.22416934 W 148.43318286 End Crv 13452.16 80.14 84.74 8801.46 8874.39 7151.62 1741.72 7047.73 --- 6.00 6.38 5934036.98 694208.42 N 70.22418076 W 148.43276799 Crv 6/100 13835.95 80.14 84.74 8867.17 8940.10 7529.66 1776.36 7424.27 40.92R 0.00 6.41 5934080.95 694583.95 N 70.22427442 W 148.42972974 13-03A Tgt 4 13887.85 82.50 86.80 8875.00 8947.93 7580.95 1780.14 7475.43 52.14R 6.00 6.42 5934086.00 694635.00 N 70.22428461 W 148.42931695 13900.00 82.95 87.38 8876.54 8949.47 7593.01 1780.75 7487.46 52.07R 6.00 6.42 5934086.91 694647.02 N 70.22428625 W 148.42921981 End Crv 13943.38 84.55 89.44 8881.26 8954.19 7636.09 1781.95 7530.57 -- 6.00 6.43 5934089.17 694690.08 N 70.22428939 W 148.42887203 Fault 14105.00 84.55 89.44 8896.61 8969.54 7796.69 1783.52 7691.45 --- 0.00 6.44 5934094.73 694850.86 N 70.22429323 W 148.42757399 Crv 6/100 14544.37 84.55 89.44 8938.32 9011.25 8233.29 1787.77 8128.81 3.06R 0.00 6.48 5934109.83 695287.95 N 70.22430361 W 148.42404521 14600.00 87.89 89.62 8941.99 9014.92 8288.69 1788.23 8184.31 3.05R 6.00 6.49 5934111.66 695343.42 N 70.22430469 W 148.42359740 14700.00 93.88 89.94 8940.45 9013.38 8388.42 1788.61 8284.25 3.05R 6.00 6.51 5934114.53 695443.32 N 70.22430544 W 148.422791 13-03A Tgt 5 14718.74 95.00 90.00 8939.00 9011.93 8407.06 1788.62 8302.94 50.OOR 6.00 6.51 5934115.00 695462.00 N 70.22430541 W 148.422640 14800.00 98.12 93.77 8929.71 9002.64 8487.34 1785.97 8383.60 50.43R 6.00 6.53 5934114.35 695542.69 N 70.22429793 W 148.42198954 14868.74 100.73 97.01 8918.45 8991.38 8554.24 1779.62 8451.10 92.19R 6.00 6.54 5934109.67 695610.33 N 70.22428035 W 148.42144497 14900.00 100.66 98.91 8912.65 8985.58 8584.28 1775.36 8481.51 92.54R 6.00 6.55 5934106.18 695640.84 N 70.22426864 W 148.42119961 15000.00 100.33 105.01 8894.42 8967.35 8678.78 1754.99 8577.66 93.66R 6.00 6.57 5934088.20 695737.45 N 70.22421270 W 148.42042409 15100.00 99.89 111.08 8876.85 8949.78 8770.00 1724.51 8671.21 94.72R 6.00 6.59 5934060.05 695831.73 N 70.22412913 W 148.41966954 15200.00 99.35 117.14 8860.12 8933.05 8856.93 1684.25 8761.16 95.74R 6.00 6.60 5934022.03 695922.64 N 70.22401884 W 148.41894424 15300.00 98.70 123.18 8844.43 8917.36 8938.63 1634.64 8846.50 96.68R 6.00 6.62 5933974.56 696009.18 N 70.22388305 W 148.41825613 Fault 15355.00 98.30 126.50 8836.30 8909.23 8981.00 1603.57 8891.14 97.17R 6.00 6.63 5933944.60 696054.57 N 70.22379802 W 148.41789628 15400.00 97.95 129.20 8829.94 8902.87 9014.19 1576.24 8926.31 97.56R 6.00 6.64 5933918.15 696090.41 N 70.22372324 W 148.41761276 15500.00 97.12 135.20 8816.81 8889.74 9082.80 1509.67 8999.72 98.34R 6.00 6.66 5933853.44 696165.44 N 70.22354116 W 148.41702118 15600.00 96.21 141.17 8805.19 8878.12 9143.69 1435.68 9065.91 99.04R 6.00 6.67 5933781.12 696233.44 N 70.22333881 W 148.41648786 15700.00 95.24 147.12 8795.20 8868.13 9196.21 1355.08 9124.16 99.63R 6.00 6.69 5933701.98 696293.67 N 70.22311840 W 148.41601866 15800.00 94.21 153.05 8786.96 8859.89 9239.78 1268.74 9173.84 100.12R 6.00 6.71 5933616.91 696345.47 N 70.22288236 W 148.41561871 End Crv 15823.43 93.96 154.44 8785.29 8858.22 9248.64 1247.78 9184.18 --- 6.00 6.71 5933596.21 696356.33 N 70.22282507 W 148.41553550 TD / 4-1/2" Lnr 16319.77 93.96 154.44 8751.00 8823.93 9430.79 801.10 9397.85 --- 0.00 6.75 5933155.00 696581.00 N 70.22160405 W 148.41381615 Legal Description: Northing IY) fftUSl Eastina (X) fftUSl Surface : 2054 FSL 7 FEL S14 T10N R14E UM 5932121.11 687206.49 13-03A Tgt 1 : 3794 FSL 4231 FEL S18 T10N R15E UM 5934015.00 693282.00 TD / BHL : 2849 FSL 959 FEL S18 T10N R15E UM 5933155.00 696581.00 WeIlDesign Ver SP 2.1 Bld( users) 13-03\13-03\Plan 13-03A\13-03A (P17) Generated 6/15/2009 11:08 AM Page 3 of 3 3600 4800 ~ 6000 O O N C N f0 to 7200 H saoo 9600 by Schlumberger WELL DS13-03A (P17) FIELD Prudhoe Bay Unit - EOA STRUCTURE DS-13 MegneNC Parameters Surface L°ca9on NA027 Alaska 6Rle Planes.20ne 04. US Feet Miscellaneous Motlel: BGGM 2006 Dip 80.694" Dafe June 20, 2009 Lal N70139963 Noflbing 3932121.11 flU6 Gnd Conv: +1.42128959° 6101-. 13-03 ND Rer. Rodry Table (R.93fl above MSL) Mag Dec +22.124' FS. 5])12.9 nT Lon: W1482922.fi71 Easbng. 597205.49 flU6 6cale Fact: 09999399126 Plan 13-03A (P1]) Srvy Date'. June 16,2W9 0 1200 2400 3600 4800 6000 7200 8400 960( ..... ~~ 3-03°°°°Tie-In Survey ..................................... ............................................... .................:...................................:................... Top Whipstock: Base Whipstotk Crv4/100 i Crv 4/190 End Crv ..................................... 3.... ................................-. ..................................... ..........................-.................... .................,...................................................... -.._.._ _.._.._.._.. _.._.._.._ _.._.._.._.._.._ .:Z. _. ._.._.._.._.._.._.._ - _.. _.._.._.._.._.._.._ _.._.._.._. ._.._.._.._ - _.._.._.._..-.._.._.._ _.._.._.._.. .._.._..i.._.._.._.._.._.._.._.. _.. i.. _.. _.. _.._.._.._.._.. _.. . .~ .._.._.._.._.._.._..i.._.. _.._.._.._.._.._.._..i.._.._.._.._. ._.._.._.._..i..-.._.._.._.._.._.._.. _.. i.. _.._.._.._.. .._.._..~.._.._.._.._.._.._.._.._.. F.._.._.._.._.._.._.._.._..i.. .._.. _.. _.._.._.. f.._.. .. _.._.._.._.._.._.._..~.._.._.._.._. ._.._.._.._..~.._.._.._.._.._.._.._.._..~.. _.._.._.. _.. 3 ._.._ _ _.._.._.._.._.._.._.._ _ _.._.._.._.._.._.. _.._ _ _. . _.._.._ 2"" - _.. _.._.._.._.._.._.._ - _.._.._.._. . _.._.._.._ - _.._.._.._.._.._.._.._ _ _.._.._.._.. ............: .................................. ~ ...................................}...... ............... .. ............... .............................; .................. crv ato6 ................ y...................................................... End Crv .._.._..i.._.._.._.._.._.._.._.._..~.._.._.._.._.._.._.._.._.. i.. _. . _.. _.. _.. _.. _.. _.. _.. i.. °° _. _ _ ._.._.._..i.._.._.._.._. ._.._.._.._..i.._.._.._.. _.. _.. _.. _.. _.. i.. _.. _.._..-. H Crv 6/100 .._.._..i.._.._.._.._.._.._.._.._..i.._..-.._.._.._.._.._.._..i.. _. . _.. _.. _.. _.. _.. _.._.. i.._ _ _ HRZ _.._.._..i.. _.. _.. _.._. .._.._.._.._. ._.._.._.. _.. i.. _.. End Crv _.._ .._.._..~.._.._.._.._.._.._.._.._..~.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._..~.._.. 13-03A Tyt 2 @nd Crv _ _ _. E'>td Bld dry 6/100_. ................:.................. _.. _.. _.. _.. i.. _.. _.. _.. _. _.. _.. _.. _.. i.. _.. _.. _.. _. ._.._.._.._:.i.._.._.. _.. _.. _.. _.. _.. _..... _.. _.._. ._.._.._:._..i.._.._.. _.. _.. _.. _.. _.. _.. i.. _.. _.. _. Crv 6/100 End Crv Crv 6/100 :: ~.. .._.._.._.._.._.._.._.._.._.._.._..*.._.._.._.._.._.._.._.._..t.._.._.. _.. _.. _.. _.. _.. _..... _.. _.._. .._ t.. _.. _.. _.. _.._.. _.. _.. ~.. _.._.. _.. .._ ._. .._.._.. _.. _.. _.. _.._ _.. _.._ ~" Cs9 Bld 12/100 13-03A (P17) End Crv Crv 6/700 Faun Crv 6/Y00 13-43A Tgt 4 Fault End Crv U-03A Tgt 1 3600 • 4800 6000 7200 8400 9600 0 1200 2400 3600 4800 6000 7200 8400 960 Vertical Section (ft) Azim = 86.02°, Scale = 1(in):1200(ft) Origin = 0 N/-S, 0 E!-V by Schlumberger WELL DS13-03A (P17) FlELD Prudhoe Bay Unit - EOA STRUCTURE DS-13 .~.~.in~ ~~ ~... -n ~^~-~~ _u . ce location NAD21 Alaska Slate Planes. Zona o4, US Feel c Rv Miscellaneous ~~ ~. ~I-~l ii^~~9 Nart~n9 .9321.^1 11 rtuS Grid COfIV: X1.42128859' P.ota Table )2.93fl aboae MSL) Sbl 13-03 NO ReY ry - ~ E -ft'27i E9 ttU5 Scale Fac109a593991M Clan. 13-03A (P t]1 Sivy Dale.J e15. 3o09 ~ 2400 A A Z 0 1200 2400 3600 4800 6000 7200 8400 9E • 2400 O O N _- 1200 O) <9 U V V V 3R FN 1 .... ,K 13-03A Tg11 Fautt Entl C Bld 12/100 Crv 6/100 ~ End~Crv Fauh Crv 6/100: 7" Cs 13 0 End Crv 13-03A Tgt 4 Crv 61100 Crv6/1A0 is-03A Tg15 Fauh 13-03F~ Flt 13-03A Flt 4 ' End Bld End:Crv End :Crv •5!100......... ..:... ....... .... ........:...................................:............................ ....:....... ...............Grvbla04......Entl.C[V..................:...................... ..........;,E'rv .Ta(g?t.~........... ..................... ............ ....... 13-03A Tgt 2 Crv 5/100 ; 13-03A Flt 5 End Crv 'TD / 4-112' 13-03A (P17) Crv 4/100 13-03A F0 2 ' .. ..Crv b/400...... EnA.~!" ......:...................................:................................. ................................i...................................:.... Base Whipstock . Top Whipstock Tiean Survey 0 1200 2400 3600 4800 6000 7200 8400 9E «< W Scale=1(in):1200(ft) E »> 1200 Lnr 0 . Anticollision Report Cori-par~r North America -ALASKA - BP Locai Co-rsrdin~te Reference: Well 13-03 -Slot 03 Prpject .,, _ Prudhoe Bay Tyfl Reference: 13-03A @ 72.93ft (Naobrs 9ES) Reference Site: PB DS 13 tiAD Reference: 13-03A @ 72.93ft (Naobrs 9ES) bite Error: O.OOft North Reference: :True Aefe;rertce Wetl: 13-03 Survey CalculatfDq IUe~-od. ': Minimum Curvature i1Ueq Errx~ri ~ O.OOft Output artt~rs are at. ;- 1.00 sigma Rcf~rence Weilbore Plan 13-03A database: EDM .16 - Anc Prod - WH24P l2e#erence Design:., Plan #17 13-03A t~et'tYD'f~eference: Offset Datum Reference Plan #17 13-03A , Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refen Interpolation Method: MD Interval 5.OOft Error Model: ISCWSA Depth Range: 3,980.00 to 16,319.77ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,829.13ft Error Surface: Elliptical Conic -- Survey Tool Program Date 6115!2009 '. ~ : - ~ (ft) ~ (ft1 Surve~i.{Wefiborej ~ T,oolName - :.Description' 96.93 3,971.93 13-03 Srvy 2 GYD CT CMS (13-03} GYD-CT-CMS Gyrodata cont.casing m!s 3,971.93 4,300.00 Plan #17 13-03A (Plan 13-03A) GYD-GC-SS Gyrodata gyro single shots 4,300.00 5,700.00 Plan #17 13-03A (Plan 13-03A) MWD MWD -Standard 4,300.00 10,477.00 Plan #17 13-03A (Plan 13-03A) MWD+IFR+MS MWD +IFR + Multi Station 10,477.00 11,900.00 Plan #17 13-03A (Plan 13-03A) MWD MWD -Standard ', ~ 10,477.00 16,319.77 Plan #17 13-03A {Plan 13-03A) MWD+IFR+MS MWD +IFR + Multi Station 6115/2009 11:03:34AM Page 2 oi4 COMPASS 2003.16 Build 70 ~otnpany: `" ~-; North America -ALASKA - BP Project: _ ' Prudhoe Bay Referene~a 5tte: ' ' PB DS 13 Stt2 Errol: O.DOft Reference We11: 13-03 YVell Errot`r O.OOft ReferenceYVeflbtue Plan 13-03A Reference DesigrW,? Plan #17 13-03A • Anticollision Report Local Co-ordinate Reference- Well 13-03 -Slot 03 ND Reference: 13-03A @ 72.93ft (Naobrs 9ES) fdD Reference: 13-03A @ 72.93ft (Naobrs 9ES) NortF+ Reference: ~ 'True Survey ~2tlCr~lat~Dfr Mefftod: Minimum Curvature Output errors are ai 1.00 sigma Database:. EDM .16 - Anc Prod - WH24P t)ffsef TVD References -- Offset Datum ~SunvnarX .~ ,. ._ "Reference ~ Offse"t ' '~~ntre fo . ~ No-Go ' ~' Atl6wable Measured Measured ~ Centre D+stance Oe~iatton Warniflg -Site Narhe Depth ~ Depth Distance ~jft} : ~ from Plan ~ . Qifse~t 3Ate11- Wellbore r D~sigh . ~ _ - d~j ,; (~? : , , ~~? _ ' lR) _ PB DS 01 01-18 - 01-18 - 01-18 15,622.40 11,600.00 151.92 207.87 -47.09 FAIL -Major Risk PB DS 12 12-12 - 12-12 - 12-12 13,270.32 10,110.00 185.15 517.50 -319.93 FAIL -Major Risk 12-12 -12-12A -12-12A 15,012.17 9,550.00 1,10$.57 241.79 913.47 Pass -Major Risk 12-17 -12-17 - 12-17 11,835.60 10,930.00 1,008.61 765.62 261.71 Pass -Major Risk 12-19 - 12-19 -12-19 12,357.99 10,880.00 1,274.60 750.83 602.32 Pass -Major Risk 12-20 - 12-20 - 12-20 14,330.86 10,195.00 1,276.59 202.52 1,093.84 Pass -Major Risk 12-20 - 12-20A - 12-20A 14,058.55 10,525.00 864.76 179.78 686.54 Pass -Major Risk 12-20 - 12-20A - 12-20A wp10 13,984.24 10,515.00 844.06 179.06 666.46 Pass -Major Risk 12-21 - 12-21 - 12-21 15,500.00 9,155.00 1,569.27 487.15 1,134.34 Pass -Major Risk 12-37 -12-37 - 12-37 15,287.79 9,185.00 940.91 171.38 791.74 Pass -Major Risk Delete me Plan 12-37 -delete me Plan 12-37PB1 15,286.46 9,180.00 932.89 183.61 772.77 Pass -Major Risk Delete me Plan 12-37 -delete mePlan 12-37 - Pla 15,286.46 9,180.00 932.89 183.60 772.77 Pass -Major Risk PB DS 13 13-01 - 13-01 - 13-01 3,980.00 4,175.00 686.83 73.24 627.83 Pass -Major Risk 13-02 - 13-02 - 13-02 3,980.00 4,085.00 347.38 53.90 293.51 Pass -Major Risk 13-02A - 13-02A - 13-02A 3,980.00 4,085.00 347.39 53.91 293.52 Pass -Major Risk 13-026 - 13-028 - 13-026 3,980.00 4,040.00 254.22 52.15 205.08 Pass -Major Risk 13-026L1 - 13-026L1 - 13-02BL1 3,980.00 4,040.00 255.34 52.11 206.26 Pass -Major Risk 13-02BPB1 - 13-02BPB1 - 13-026PB1 3,980.00 4,0$5.00 347.59 53.83 293.81 Pass -Major Risk 13-026P62 - 13-026P62 - 13-026P62 3,980.00 4,085.00 347.63 53.84 293.83 Pass -Major Risk 13-02BP63 - 13-02BPB3 - 13-02BPB3 3,980.00 4,040.00 254.22 52.15 205.08 Pass -Major Risk 13-03 -13-03 - 13-03 3,981.93 3,985.00 0.00 9.73 -9.58 FAIL -Major Risk 13-04 -13-04 -13-04 3,980.00 4,115.00 410.73 55.98 354.87 Pass -Major Risk 13-05 - 13-05 -13-05 4,745.47 4,735.00 652.30 128.74 523.96 Pass -Major Risk 13-06 - 13-06 -13-06 4,001.78 4,160.00 836.79 64.40 772.76 Pass -Major Risk 13-06A - 13-06A - 13-06A 4,001.79 4,160.00 836.74 64.14 772.97 Pass -Major Risk 13-O6APB1 - 13-06APB1 - 13-06APB1 4,001.79 4,160.00 836.74 64.14 772.97 Pass -Major Risk 13-O6B - 13-066 - 13-066 10,725.00 11,099.68 1,593.95 1,162.32 520.34 Pass -Major Risk 13-09 -Plan 13-09A - 13-09A wp01 3,980.00 4,850.00 854.31 71.01 790.20 Pass -Major Risk 13-10 -13-10A -13-10A Wp 2 4,696.45 4,885.00 392.43 72.50 334.29 Pass -Major Risk 13-21 - 13-21 -13-21 14,318.54 12,795.00 1,579.36 1,840.87 -253.44 FAIL -Major Risk 13-22 - 13-22 -13-22 4,380.47 4,375.00 262.84 108.30 155.28 Pass -Major Risk 6/1512009 11:09:34AM Page 3 of 4 COMPASS 2003.16 Build 70 • Project: Prudhoe Bay Site: PB DS 13 Well: 13-03 Weltbore: Plan 13-03A Design: Plan #17 13-03A • From KOP to TD Scan interval 100 ft Scale 1:100 01-18, 12-12, 13-21 Risk 1:200 so iao Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [100 ftlin] ALASSA OIL Ai~TD GAS COI~TSERQATIOI~T COMl-IISSIOIQ Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-66129 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-03A BP Exploration Alaska Inc. Permit No: 209-048 Surface Location: 2055' FSL, 7' FEL, SEC. 14, T10N, R14E, UM Bottomhole Location: 2849' FSL, 4111' FWL, SEC. 18, T10N, R15E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to redrill 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 Comnssion 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). cerely, ~~ ~~ Daniel" T. Seamount, Jr. `~ Chair DATED this ~- day of April, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASt~tL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 a~~ ~,~~ a~~; ~ ~ 2009 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if'we~l is"prb~` ~ ~ f~: ~• Of>'1-111SSI ^ Coalbed Methane $~~r~rates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 13-03A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 16279' TVD 8825' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 0 7. Property Designation: ADL 028315 a~3.~0 Oil Pool FSL, 7 FEL, SEC. 14, T1 N, R14E, UM 2055 Top of Productive Horizon: 3794' FSL, 835' FWL, SEC. 18, T10N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: June 10, 2009 Total Depth: 2849' FSL, 4111' FWL, SEC. 18, T10N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 18,038' 4b. Location of Well (State Base Plane Coordinates): Surface: x-687206 y-5932121 Zone-ASP4 10. KB Elevation (Hei ht above GL)Plan 58.5' feet 15. Distance to Nearest Well Within Pool: 267' 16. Deviated Wells: Kickoff Depth: 6700 feet Maximum Hole An le: 104 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4052 Surface: 3172 t., 'n Pr m: ' i 'o n n T- in h- m n~ f n f r Hole Casin Wei ht Grade lin Coi Len th MD TVD MD TVD includin sta edata 8-1/2" 7" 26# L-80 BTC-M 5 5750' 1449' 7 8' 164 x Lite re 16 x lass' ' 1/ " 4-1/2" 12. 13Cr80 Vam To 98 ' 1 9' 8 5 ' 1 7 ' 825' 704 x la s' ' ~ g, PRESE NT WELL CONDITIONSUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth Mp (ft): 11340' Total Depth TVD (tt): Plugs (measured): 514' 10253' Effective Depth MD (tt): 11276' Effective Depth TVD (ft): 9461' Junk (measured): Multiple, See Diagram Casing',.. Length Size Cement Volume MD TVD Conductor /Structural 2 1 1 1 9' 1' Surface 270 ' 13-3/8" 0 x Ar i e II 27 6' 706' Intermediate Pr in 11 1 -/" 1 x 1 1' Liner Perforation Depth MD (tt): 10417' - 10744' Perforation Depth TVD (ft): 8755' - 9020' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the fore oing is true and correct. Printed Name Gre ob Si nature Contact Abby warren, 564-5720 Title En ineering Team Leader Prepared By Name/Number. Phone 564-4191 Date Terrie Hubble, 564-4628 Commtsslon Use Onl Permit To Drill tuber: o?O O d' API Number: 50-029-20325-01-00 Permit Approval See cover letter for p -~ ©~ o erre it n Conditions of Approval: ~ cF~ If box is` checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: a~vd~S` ~*~-"~`s~ Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No a,5~ ~~ ~Z ~~ ~v ~..C3.t~i~a1`car ~ ~ HZS Measures: ~ Yes ^ No Directional Survey Req'd: Yes ^ No Other. _ ~# ---~ APPROVED BY THE COMMISSION ~~ Date ~'`f ,COMMISSIONER Form 10-401 Revised 2/20 ~,,, F ~ ) ~+ Submit In~`D/uplicate ~`~~ by • To: Alaska Oil & Gas Conservation Commission From:Abby Warren, ODE Date: April 20, 2009 Re: 13-03A Sidetrack Permit to Drill The 13-03A well is scheduled to be drilled by Nabors Rig 9ES which is currently scheduled to move onto the location 6/10/09. A 9-5/8" cut and pull will be done first and then the plan is to exit the parent 13-03 wellbore from the 9-5/8" casing at N6700' MD with an 8-1/2" BHA. The 8-1/2" hole will then be drilled to the top of the Sag River formation where a 7" casing string will be run and cemented. A 6-1/8" hole will then be drilled building to horizontal in the Ivishak Zone 4. The planned well then runs horizontally for approximately 5250' to a final well TD at 16,279' MD. A solid 4-1/2" chrome production liner will be run and cemented in place and a chrome completion will be run. Please note the following Well Summary as detailed on the next few pages: 13-03A Permit to Drill Application Page 1 Planned Well Summary Well 13-03A Type Production Object ve Zone 4 API Number: 50-029-20325-00 Current Status 13-03 Shut-In Estimated Start Date: June 10 Time to Complete: 35.32 Days 2009 Surface Northin Eastin Offsets TRS Location 5932121.12 687206.48 2054' FSL / 7' FEL T10N, R14E, S14 Northing Easting TVDss Offsets TRS Target Locations 5,934,015 693,282 -8907 3794 FSL / 4231 FEL T10N, R15E, S18 Bottom Northin Eastin TVDss Offsets TRS Location 5,933,155 696,581 -8,751 2849' FSL / 959' FEL T10N, R15E, S18 Planned KOP: 6700'MD / 5803'TVDss Planned TD: 16,279'MD / 8,750' TVDss Ri Nabors 9es BFE: 30.0' RTE: 58.5' D~rect~onal - scrnumuer KOP: 6700' MD ger ri4 Maximum Hole Angle: ~50° in the 8-1 /2" intermediate section 104° in the 6-1/8" horizontal section C~ TD Surve Pro ram: MWD Standard + IFR / MS Nearest Pro ert Line: 18,038' to the PBU S property line Nearest Well within Pool: 12-12 is the closest well at 267'. Contacts Drilling Engineer Geologist Pad Engineer Name Phone # Abby Warren 564-5720 Daniel Schafer 564-5098 Olivia Bommarito 564-4096 E-mail Abigail. W arren @ bp.com Daniel.Schafer@b~com Olicia.Bommarito @bp.com 13-03A Permit to Drill Application Page 2 Formation Markers 13-03A (Ba~ on SOR) Formation SSTVD MD TVD Thick MD Thick Angle/Pore Pressure SV2 -3429 3520 387 431 20.4 SV1 -3816 3951 846 1099 29.8 UG3 -4662 5050 690 972 44.6 UGl -5352 6022 451 678 47.4 KOP Lower UGl U nu -5803 6700 150 220 47.3 WS2 -5953 6920 290 388 43.5 WS1 -6243 7308 162 214 40.7 CM3 -6405 7522 514 678 40.8 CM2 -6919 8200 641 846 40.7 CM1 -7560 9046 479 621 40.7 THRZ -8039 9667 167 209 37.0 BHRZ -8206 9876 252 316 37.0 TJB -8458 10192 119 149 37.0 TJA -8577 10341 87 108 37.0 Sa River SS -8664 10449 26 33 37.0 Shublik A -8690 10482 21 26 37.0 Shublik B -8711 10508 18 23 37.0 Shublik C -8729 10531 36 48 38.6 TSAD -8765 10579 183 470 42.6 41P Invert Point -8948 11049 35 1370 90.0 42P Revert up to 12-12 Crest -8913 12419 126 811 96.2 46P Crest near 12-12 -8787 13230 156 1370 90.0 43P Invert between 12-12 -- 01-18 -8943 14600 126 850 88.9 46P / 45P EW Graben Fault _gg17 15450 66 829 97.4 46P TD -8751 16279 94.0 Casing/Tubing Program Hole Csg / Wt/F Grade Conn Burst Collapse Length Top Bottom Size Tb O.D. t (si) (si) MD /TVD MD /TVD 8-1 /2" 7" 26# L-80 BTC-M 7,240 5,410 3899' 6,550' / 5,750 10,449 / 8,738 6-1/8" 4'h" 12.6# 13Cr- 80 Vam Top 430 8, 7,500 5980' 10,299' / 8,550' 16,279' / 8,825' Tubing 4'/z" 12.6# 13Cr- 80 Vam Top 8,430 7,500 10299' Surface 10299' / 8,550 13-03A Permit to Drill Application Page 3 Mud Program Whi stock Millin Mud Pro erties: LSND Whip Stock Window 9-5/8", 47# Densi PV YP API FL MBT PH 9.0 15-22 30-40 6-8 <10 9.0-9.5 I Intermediate Mud Properties. LSND I 8-3/4" hole section I Depth Interval Density (ppg) PV YP API FL MBT PH 6,700'-9,667' 9.0 - 9.5 10-18 18-28 <6.0 <15 9.0-10 9,667'-10,449 10 8 12-22 18-28 4.0-6.0 <20 9.0-10 HRZ to Sa . Production Mud Pro erties: FLOPRO SF Reservoir Drill-in Fluid 6-1 /8" hole section De th Interval Densi PV YP LSVR API FI H MBT 10,449'-16,279' 8.5 - 9.0 6-12 22-28 >20,000 6.0-8.0 9.0-9.5 < 3 Logging Program 8-1/2" Intermediate: Drillin Dir/GR/PWD/Res Open Hole: None Cased Hole: None 6-1/8" Production• Sample Catchers - as required by Geology Drillin Dir/GR/Neu/Den/Res Open Hole: None Cased Hole: None Cement Program Casin Size: 7" 26#, L-80 Intermediate Liner Lead: 2,749 of open hole with 40% excess + 150' of liner 7" x 9-5/8" liner lap and 200' of 9-5/8" Basis: x 4" DP excess Lead TOC: --6550' MD 150' from the window Tail: 1,000' of open hole with 40% excess, plus 80' shoe track Tail TOC: 9450'. MD 1000' above 7" shoe de th Total Cement Spacer 35 bbls of viscosified, 11.0 ppg weighted Spacer (Mud Push II) Volume• Lead 102.3 bbls, 575 cuft, 164 sks 11.5 Ib/ al LiteCrete --3.51 cuft/sk tanned Tail 34.7 bbls, 195 cult, 168 sks 15.8 Ib/ al Class G + adds -1.16 cuft/sk Tem BHST = 200° F, BHCT TBD b Schlumber er Casin Size 4.5" 12.6#, 13Cr-80 Production Liner Basis: Lead: None Tail: 5830' of open hole with 40% excess, 80' shoe track, 150' 4-'/z" x 7" liner lap, and 200' of 7" x 4" DP excess. Tail TOC: 10,300' MD (TOL) Total Cement Volume• Spacer 25 bbls of viscosified, weighted Spacer (Mud Push II) Lead None Tail 145.4 bbls, 816.7cuft, 704 sks 15.8 Ib/ al Class G + adds -1.16 cuft/sk Tem BHST = 205° F, BHCT TBD b Schlumber er 13-03A Permit to Drill Application Page 4 Surface and Anti-Collin Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. At surface 13-02 and 13-04 are on 120' center to center spacing from 13-03. Close Approach Shut-in Wells: Three wells fail major risk anti-collision criteria in Schlumberger P14. A Tolerable Collision Risk Worksheet will be filled out for all wells that fail the major risk anti-collision criteria, and the corresponding wells will be shut-in as necessary. Hydrogen Sulfide Drill Site 13 is a designated high H2S site. Recent H2S data from the pad is as follows: #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Faults Wall Nama H9S I PVPI r)afp of Rpatlinn 13-026L1 25 m 1/13/2009 13-04 200 m 10/12/2008 12-12 40 m 1 /4/2004 01-18 50 m 4/4/2006 13-02A 300 m 9/24/1994 Formation Where Encounter Fault ftMD Intersect ftTVDss Intersect Est. Throw Throw Direction Occurance robabilit Fault #1 -NOT CROSSED Fault #2 - CROSSED IN UPPER ZONE 4 15400 -8824 67 UP 100% Fault #3 -CROSSED IN LOWER ZONE 4 12550 -8891 15 UP 40% Fault #4 -CROSSED IN LOWER ZONE 4 14080 -8898 20 DOWN 40% Fault #5 -NOT CROSSED Fault #6 - NOT CROSSED Well Control 13-03A Permit to Drill Application Page 5 Well control equipment consis~ of 5,000 psi working pressure pipe ~s (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP regular test frequency for 13-03A will be 14 days during drilling phase and 7 days during de- completion work. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP 4052 si @ 8660' TVDss 9.0 EMW Maximum surface ressure 3172 si .10 si/ft as radient to surface Kick tolerance 111.6 bbls over 11.3 LOT assumin 9.0 reservoir and 4" drill i e Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 7" Casin Test 3500 si ressure test Inte ri Test -8-1/2" hole LOT after drillin 20' from middle of window Production Interval Maximum antici ated BHP 3296 si C«~ 8800' TVDss 7.2 EMW Maximum surface ressure 2416 si .10 si/ft as radient to surface) Kick tolerance Infinite with a 10 FIT Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 4-1/2" Liner Test 3500 si surface ressure Inte ri Test - 6-1/8" hole Minimum 10 FIT after drillin 20' of new hole Planned com letion fluids 8.5 Seawater / 7.2 Diesel Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead. height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: All Class II liquid waste (including drilling muds and/or brines that have been downhole) are to be hauled to GNI at DS-04 for injection. For the disposal of Class I wastes, contact the GPB Environmental Advisors (659-5893) for the appropriate disposal method at Pad 3 or GNI. NOTE: Generally, Class I solids will be directed to the GNI on DS-04 and Class liquids will be directed to Pad 3. 13-03A Permit to Drill Application Page 6 ~~J~111111 1~ POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ivishak Zone in 13-03A is expected to be under-pressured at 7.2 ppg EMW. This pressure is estimated based on offset well pressures and a pressure taken from the parent wellbore in 2006. 3500 psi test pressure is in accordance with the RP for Prudhoe production well casing tests. II. Faults /Lost Circulation /Breathing A. Although 13-03A is expected to cross three faults in Zone 4 near 12550',14080', and 15400', lost circulation risk is considered medium to low. The lost circulation occurrence in surrounding wells is average in the production zone. Lost circulation is normally not a problem in the intermediate section on DS13. III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for the intermediate hole section is 112 bbls with a 11.3 ppg FIT out of the 9-5/8" window. The production hole section's kick tolerance is infinite with a 9.5 ppg FIT. These given FIT's will be our minimum for kick tolerance, and may increase due to ECD management. B. Integrity Testing Test Point Test Depth Test EMW (Ib/gal) t e 9-5/g" 20-ft minimum from the 9 5/g" LOT 11.3 minimum window window 7" shoe 20-ft minimum from the 7" shoe FIT 10.0 minimum IV. Stuck Pipe A. Significant directional work will be required in the production hole section. Hole cleaning and differential sticking tendency will be of concern. Watch for signs of tight hole and short trip /back ream as required to avoid stuck pipe. VI. Hydrogen Sulfide A. Drill Site 13 is designated as a high H2S drill site. Standard precautions will be followed at all times. VII. Anti-Collision Issues A. Three wells fail major risk anti-collision criteria in Schlumberger P14. A Tolerable Collision Risk Worksheet will be filled out for all wells that fail the major risk anti-collision criteria, and the corresponding wells will be shut-in as necessary. CONSULT THE DRILL SITE 13 DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 13-03A Permit to Drill Application Page 7 Operations Summary C_ urrent Condition and history: • This well is completed with 5-1/2" x 4-1/2" tubing • Tubing: A caliper log from 11/14/2007 shows the 5-1/2" liner in decent condition (max penetration of 36%). There is an IBP in the 4-1/2" tubing tail, an attempt to pull it was unsuccessful due to the tool string being left down hole by SL, so the P&A will need to be done by a tubing punch above the fish and squeezing cement past it. • MIT-IA, and MIT-T have both failed w/ a LLR of 2 bpm @ 450 psi • MIT-OA Passed to 2000 psi on February 15'h of this year Scope Notify the field AOGCC representative with intent to plug and abandon Pre-Riq Operations: 1. O Install cellar liner, im ermeable s ra -sealed Herculite 2. E Run G ro down to 9000' due to anti collision issues 3. E Run USIT in 5-1/2" tubing down to 9900' for confirmation of cement top in the 5-1/2" x 9-5/8" annulus 4. E RIH w/ tubin unch 5' of 4 s f , unch holes in 4-1 /2" tubin above fish @ 10,217' SLM 5. C Set Cement retainer in 5-1/2" tubing at 9890' (mid joint as per tubing tally 1-7-1982), perform in~ectivi test . C Sting into cement retainer and Bullhead /Squeeze 87.5 bbls of 15.8 Class G cement to plug and abandon the old perfs, and lay 100' of cement above cement retainer (2.5 bbls extra bbls) 976' of 9-5/8" 47# w/ capacity of .0733 bbls/ft + 10% excess for perfs = 80 bbls of cement 70' of 4.5" 12.6 #, w/ cap of .0152 bbls/ft = 1 bbl of cement 283' of 5-1/2" 17# w/ cap of .0232 bbls/ft = 6.5 bbls of cement 100' above the cement retainer w/ cap of .0232 = 2.5 bbls of cement Max Allowable TOC - 9500' Minimum Allowable TOC - 9800' BOC - 11,276', (no clean out necessary to meet P&A objectives) Total of 90 bbls um ed. 7. S Drift tubin , to TOC 8. F Pressure Test Cement Plu u to 3500 si 9. F Pressure Test to verif Abandonment & Barriers MIT-OA to 2,000 si Done 2/15/09 PPPOT-T to 5,000 si Done 2/19/09 PPPOT-IC to 5,000 si Failed 2/19/09 Function Test Tub LDS-T & Prod Casin Han er LDS-IC LDS Done 10 E RIH and 'et cut tubin X7200' 11. F CMIT-TxIA up to 3500 psi If it fails contact DE 12. Drill out stuck LDS, see 2/19/09 AWGRS for details of LDS 13. O Circulate the well to seawater. Freeze- rotect the IA and tubin with diesel to 2,200'. 14. O Bleed all ressures to zero. Set BPV. Secure well. 15. O Remove the well house. If necessa ,level the ad. Riq Operations: 1. MI / RU Nabors rig 9ES 02-33B Permit to Drill Application Page 8 2. Pull BPV. Circulate out die freeze protection and displace the well to~water. 3. Set and test TWC to 1,000 psi from above and below. 4. Hook up OA to a bleeder tank and monitor (OA will not pass pressure test / no OA test required). 5. Nipple down tree & tubing adapter. Nipple up and test BOPE to 3,500psi high/ 250psi low. Pull TWC. 6. R/U & pull 5-'/z" tubing from the cut depth at 7200' MD. 7. R/U & Run bit w/ a mill above it to 7200' (do not run casing scraper due to 2 FOC's in this well C~ 2345' & 2469') 8. RU E-line and RIH w USIT (in PDC Mode)/CCL to 7200' and log to surface. 9. RIH with HES EZSV bridge plug on E-line and set at 6700' MD, as required to avoid cutting a casing collar while milling the window. Test CSG to 3,500 psi. POOH. 10. MU a Baker 9 5/8" multi-string cutting assembly. RIH picking up DP to planned cut depth. Cut the 9 5/8" casing per Baker representative instructions. Spot a pill of hot diesel for 30-60 minutes at cut, then pump 40 bbl of Safe-Surf-O mixed in fresh water, followed by heated brine (2.5 volumes) to remove Arctic Pack (-130 bbl). POOH, VD assembly. 11. Change out to 9 5/e" rams, and test rams. 12. BOLDS, RU/MU casing spear assembly, and unseat the 9 5/8". Circulate the annulus. Pull the 9-5/8" casing from the cut. 9 5/8" casing will be pulled through the wellhead/BOPE. 13. MU wash-over assembly and 13 3/8" casing scraper and 9 5/8"dress off assembly. 14. RIH, clean-out the 13 3/" casing, and the 9 5/" casing stub, dress off the 9 5/8" casing stub to accept a casing patch. POOH, UD the assembly. 15. Run new 9-5/8" L-80 HYD 563 casing w/ HES ES cementer, ECP, Baker Type II Landing collar, and Bowen casing patch. 16. Pull test new 9 5/e" / ES cementer /casing patch to 250k. PT Casing patch to 1000 psi 17. Inflate ECP, continue ramping up pressure to 2000 psi to shear close ECP. PT to 2000 psi for 10 mins. Bleed pressure to 0. 18. Bring pumps up to 2 bpm to shear open ES cementer. Before cementing, ensure fluid returns are above 80° F (this ensures cement achieves compressive strength). Cement 9 5/s" x 13 3/s' annulus with class G 15.8ppg cement to surface. 19. Split stack and install FMC 13" x 9 5/" slip type hanger with primary pack off per FMC wellhead specialist in the casing head. Set slips. Cut and LD excess 9 5/" casing. Set back BOPE test breaks to 3,500 psi and test packoff to 3800 psi. 20. NU BOPE. Change BOP rams back to VBR's and test rams to 250 psi / 3,500 psi with a 4" test joint. 21. PU 4" DP and 8-~/z "mill tooth bit. 22. Make clean out run through the ES Cementer, ball seat and down to EZSV. 3~1-1i"'~~o 23. Pressure-test the 9 5/8" casing to 3,500 psi for 30 minutes. Record test. 24. P/U and RIH with 9 5/e" Baker bottom-trip anchor whip stock assembly. Orient whipstock and set on EZSV bridge plug. Shear off of whip stock. 25. Displace the well to LSND based milling fluid. Completely displace the well prior to beginning milling operations. 26. Mill window in 9 5/e" casing at ± 6700' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 27. Pull up into 9 5/8" casing and perform LOT. POOH. 28. M/U 8-'/z" GR/RES/PWD/MWD assembly. RIH, kick off and drill the 8-'h" intermediate section with - ~~ ~ LSND drilling fluid. ~ 29. Drill ahead to the 7" liner point at top of the Sag River, as per the directional plan. Circulate the well ~~-- clean, short trip to THRZ or higher as needed. POOH. 30. Change out to 7" rams, and test to 250 psi / 3,500 psi 31. MU and run 7", 26#, L-80, BTC-M liner to bottom on drill pipe. Circulate and condition the hole. 32. Cement the entire 7" liner through the 8-'/z" hole and back 150' into the 9-5/a" casing to the liner top. a. Note: if there is a cretaceous leak after the 9-5/8" cut and pull, run 7" up above cretaceous 33. Set the hanger and packer, displace cement with mud. 34. Circulate bottoms up, POOH, UD liner running tool (LRT). 35. Change out rams to variable and test to 250 psi / 3,500 psi 36. Test the liner to 3,500 psi for 30 charted minutes. 37. M/U the first 6-%8" Dir/GR/Res assembly with an insert bit. Pick Up DP as necessary. 38. RIH, Drill out of cement and 7" liner float equipment. 39. Displace to 8.4 ppg Flo Pro Fluid. 40. Continue drilling out the 7" shoe plus ~20' new formation, pull up into the shoe and perform a FIT. 41. Drill the 6-%a" production interval as per directional plan to end of the build section. 42. POOH for RSS and PDC. 02-33B Permit to Drill Application Page 9 43. PU second BHA with the Rand a PDC bit. 44. RIH, drill ahead to TD (16280', single in as needed). 45. POOH. UD BHA. 46. MU and RIH to bottom with 4-'/z", 12.6#, L-80 solid liner. This will include 150' liner lap inside the 7" drilling liner. 47. Cement the liner. 48. Set liner top packer and displace well to clean seawater above the liner top. a. A pert pill will be left in the 4-~/z" liner. 49. POOH, UD LRT. 50. Pressure test casing and liner to 3,500 psi for 30 minutes. 51. RU DPC pert guns, RIH and perforate. Perf intervals to be supplied by asset. 52. R/U and run a 4-~h", 12.6#, 13Cr, VamTop tubing completion, stinging into the 4-~/z" liner tie back sleeve. 53. Space out and make up tubing hanger per FMC Rep. 54. Land the tubing hanger, and run in lock down screws. 55. Circulate Corrosion Inhibitor. 56. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each test. 57. Shear Circulating Valve 58. Set a BPV. 59. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. 60. Freeze protect the well to 2,200' TVD. Secure the well. 61. RD and Move Off. 02-336 Permit to Drill Application Page 10 TREE = FMC GEN 2 WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV - 76 BF. ELEV = KOP = 3100' Max Angle = 49° @ 6600' Datum MD _ 10568' Datum TV D = 8800' SS 20" CONDUCTOR, 94#, H-40, ID = 19.124" 109' 9-5/8" CSG, 47#, S0095 XO TO N-80 BTC 2321' 13-3/8" CSG, 72#, N-80, ID = 12.347" 2706' 9-5/8" CSG, 47#, N-80 XO TO S0095 BTC 9671' ESTIMATED TOC (04/28/99) 9822' 5-1/2" AVA DWP PATCH, ID = 2.35" (06/08/98) ~-1 9932' - 9947' Minimum ID = 2.350" @ 9932' AVA RET TBG PATCH TBG PUNCH (04/06/99) i~ 10096' I4-1/2" HES RETR PATCH, ID = 2.35" (01105/95) ~- j 10173' 5-1/2" TBG-PC, 17#, L-80 BTC, .0232 bpf, ID = 4.892" 10814' 4-1 /2" TBG-NPC, 12.6#, N-80, .0152 bpf, ID = 3.958" i~ 10316' PERFORATION SUMMARY REF LOG: BHCS ON 03/10/79 ANGLE AT TOP PERF: 38° @ 10417' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 1 10417 - 10423 C 08/25/91 3-3/8" 4 10526 - 10546 C 01/23/86 3-3/8" 4 10530 - 10550 C 08/25/91 3-318" 4 10561 - 10593 C 08/25/91 3-1/8" 4 10561 - 10593 C 05/20/79 3-1/8" 4 10606 - 10643 C 05/20/79 3-3/8" 4 10606 - 10646 C 08/25/91 3-1/8" 4 10658 - 10691 C 05/20/79 3-3/8" 4 10692 - 10702 C 01/23/86 3-3/8" 4 10724 - 10744 C 01/23/86 SAFETY NOTES: """ LDL LEAK @ PKR 10183' *** 13-03 2131' ~ 5-1/2" OTIS RQM SSSV NIP, ID = 4.56" 2345' 9-5/8" FOC 2469' 9-5/8" FOC GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2884 2884 5 OT DMY T2 0 08/24/05 2 5160 4815 45 OT DMY T2 0 08/24/05 3 7074 6124 48 OT DMY T2 0 01/07/82 4 8361 7047 39 OT "`*DMY T2 0 08/24/05 5 9020 7572 36 OT DMY T2 0 01 /07/82 6 9099 7637 35 OT DMY T2 0 01!07/82 7 9492 7967 31 OT DMY RA 0 01 /07/82 8 9568 8033 30 OT DMY RA 0 01 /07182 9 9719 8165 29 OT DMY RA 0 01 /07182 10 9799 8235 28 OT DMY RA 0 01 /07/82 11 9875 8302 28 OT DMY T2 0 01 /07/82 12 9950 8368 28 OT DMY T2 0 01 /07/82 ""ST#4 POGICtf POKERISHORIT DGLV ON OSIZ4/05 10024' 5-1/2" OTIS SLD SLV, ID = 4.562" 10099' S-1/2" OTIS XN NIP, ID = 4.455" 10140' 51/2" BKRSBRw/SEALS, ID=? 10175' SBR w /EXTENSION, ID = ? 10188' 9-5/8" X 5-1/2" BKR SAB PKR, ID = 4.75" 10188' 7" MILLOUT EXTENSION, ID = ? 10194' 7" X 4-1/2" XO, ID = 3.958" 10217' SLM SL TOOLSTRING (09/12/08) 10253' ELM 4-112" IBP(11/20/07) 10254' 4-1/2" CAMCO DB-6 LAND NIP, ID = 3.81" 10316' BTM OF TAILPIPE, ID = 3.958" 10420' ~~ FISH -MOTOR ROTOR & 2.34" MILL 10623' ~-~ FISH - KINLEY CUTTER BAR 1 "-6" X 49" (1 11221' ~--~ FISH -TBG TAIL DEBRIS (1' SHOT OFF 01/08/82 PBTD 11276' 9-5/8" CSG, 47#, N-80, .0733 bpf, ID = 8.681" 11319' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/18/79 PKR141 ORIGINAL COMPLETION 09/21/08 JRA/SV FISH @ 10217' (09/12/08) 01/10!82 N1 ES RWO 03/02/09 OOP/PJC DRAWING CORRECTIONS 12/03/05 SRB(fLH CMT $ FISH (MILL) CORRECTION 01/07/06 DAV/PJC FISH @ 10623' 03/08!08 JIMlTLH IBP SET (11/20/07) 09105/O8 OOP/PJC DRAWING CORRECTIONS PRUDHOE BAY UNff WELL: 13-03 PERMff No: 1780620 API No: 50-029-20325-00 SEC 14, T10N, R14E, 2054' FSL & 7' FEL BP Exploration (Alaska) WELLHEAD = ACTUATOR = KB. ELEV = 76' BF. ELEV = ? KOP = 3100' Max Angle = 49° @ 6600' Datum MD = 10568' Datum TV D = 8800' SS 20" CONDUCTOR, 94#, H-40, ID = 19.124" 109' 9-518" CSG, 47#, SOO95 XO TO N-80 BTC 2321' 13-3/8" CSG, 72#, N-80, ID = 12.347" 2706' Jet Cut 7200' 9-5/8" CSG, 47#, N-80 XO TO SOO95 BTC 9671' ~ F~TIMATED TOC in 5-1/2" 9 F~TIMATED TOC (04/28/99) ~ 9822' 5-1/2" AVA DWP PATCH, ID = 2.35" (06/08/98) 9932' - 9947' ., I4-1/2" HES RETR PATCH, ID = 2.35" (01/05/95) ~-~ 10173' 5-1/2" TBG-PC, 17#, L-80 BTC, .0232 bpf, ID = 4.892" 10814' Tubing punch 10215' 4-1/2" TBG-NPC, 12.6#, N-80, .0152 bpf, ID = 3.958" 10316' PERFORATION SUMMARY REF LOG: BRCS ON 03/10/79 ANGLEATTOPPERF: 38° @ 10417' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 1 10417 - 10423 S 08/25/91 3-3/8" 4 10526 - 10546 S 01/23/86 3-3i8" 4 10530 - 10550 S 08/25/91 3-3/8" 4 10561 - 10593 S 08/25/91 3-1/8" 4 10561 - 10593 S 05/20/79 3-1/8" 4 10606 - 10643 S 05/20/79 3-3/8" 4 10606 - 10646 S 08/25/91 3-1/8" 4 10658-10691 S 05/20/79 3-3/8" 4 10692 - 10702 S 01 /23/86 3-3/8" 4 10724 - 10744 S 01/23/86 PBTD 11276' 9-5/8" CSG, 47#, N-80, .0733 bpf, ID = 8.681" 11319' T \r~ ~, • , SAFETY NOTES: '"* LDL LEAK @ PKR 10183' *** 2131' -~5-1/2" OTIS ROM SSSV NIP, ID = 4.56" 2345' 9-5/8" FOC 2469' 9-5/8" FOC GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2884 2884 5 OT DMY T2 0 08/24/05 2 5160 4815 45 OT DMY T2 0 08/24/05 3 7074 6124 48 OT DMY T2 0 01 /07/82 4 8361 7047 39 OT **DMY T2 0 08/24/05 5 9020 7572 36 OT DMY T2 0 01/07/82 6 9099 7637 35 OT DMY T2 0 01 /07/82 7 9492 7967 31 OT DMY RA 0 01 /07/82 8 9568 8033 30 OT DMY RA 0 01 /07/82 9 9719 8165 29 OT DMY RA 0 01 /07/82 10 9799 8235 28 OT DMY RA 0 01 /07/82 11 9875 8302 28 OT DMY T2 0 01 /07/82 12 9950 8368 28 OT DMY T2 0 01 /07/82 **ST#4 POCKET POKER/SHORTY DGLV ON 08/24/05 10024' S-1/2" OTIS SLD SLV, ID = 4.562" 10099' 5-1/2" OTIS XN NIP, ID = 4.455" 10140' S 1/2" BKRSBRw/SEALS, ID=? 10175' SBR w /EXTENSION, ID = ? 10188' 9-5/8" X 5-1/2" BKR SAB PKR, ID = 4.75" 10188' 7" MILLOUT ETTENSION, ID = ? 10194' 7" X 4-1/2" XO, ID = 3.958" 10217' SLM SL TOOLSTRING (09/12/08) 10253' ELM 4-1/2" IBP(11/20/07) 10254' 4-1/2" CAMCO DB-6 LAND NIP, ID = 3.81" 10316 BTM OF TA ILPIPE, ID = 3.958" FISH -MOTOR ROTOR & 2.34" MILL (06/99) 10623' -~ FISH - KINLEY CUTTER BAR 1 "-6" X 49" (1 /7106) 11221' FISH -TBG TAIL DEBRIS (1' SHOT OFF 01/08/82) DATE REV BY COMMENTS DATE REV BY COMMENTS 03/18/79 PKR 141 ORIGINAL COM PLEiION 09/21/08 JRA/SV FISH @ 10217' (09/12/08) 01/10/82 N1 ES RWO 03/02/09 OOP/PJC DRAWING CORRECTIONS 12/03/05 SRB/TLH CMT ~ FISH (MILL) CORRECTION 01/07/06 DAVlPJC FISH @ 10623' 03/08/08 JIM/TLH IBPSET(11/20/07) 09/05/08 OOP/PJC DRAWING CORRECTIONS FMCG ~ Minimum ID = 4.56" @ 2131' AXELSON OTIS RQM SSS IP 3 ~0 3 PRUDHOE BAY UNfT WELL: 13-03 PERMff No: 1780620 API No: 50-029-20325-00 SEC 14, T10N, R14E, 2054' FSL & 7' FEL BP Exploration (Alaska) WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 76' BF. ELEV = ? KOP= Max Angle = Datum MD = Datum TV D = 8800' SS 13-03A PROPOSED 20" CONDUCTOR, 94#, H-40, ID = 19.124" 109' l 13-3/8" CSG, 72#, N-80, ID = 12.347" 2706' 9-5/8" CSG, 47#, Hydril 563 ~~ r 9-5/8" HES Cementer 9-5/8" ECP 9-5/8" Bowen Casing Patch -~ Baker 9-5/8" WS -6700 HES EZSV 6700' Jet Cut 7200' Min ID = X.XXX" @ XXXX' II 5-1/2" TBG-PC, 17#, L-80 BTC, .0232 bpf, ID = 4.892" I--I 108 I ~ 4-1/2" TBG-NPC, 12.6#, N-80, .0152 bpf, ID = 3.958" I-I 1031 PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 2-718" 2-7/8" 2-7/8" 2-7/8" 10623' I-1 FISH - KINLEY CIfrTER BAR 1"-6" X 49" (1/7/06) 11221' FISH -TBG TAIL DEBRIS (1' SHOT OFF 01/08/82 9-5/8" CSG, 47#, N-80, .0733 bpf, ID = 8.681" 11319' ~.. . „® 10177' -- i4-1/2" HES X Nip, ID 3.813" 10207' 7" x 4-1/2" BKR S-3 PKR 10237' 4-1/2" HES X Nip, ID 3.813" 10267' 4-1/2" HES XN Nip, ID 3.725" 10287' WLEG 10287' 4-1/2" TBG, 12.6# 13 CR-80 10299' Hanger/ LTP 10449' 7" Casing 26#, L-80 BTGM 16279' I-~4-1/2" Liner, 12.6# 13Cr-80 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/18/79 PKR 141 ORIGINAL COMPLETION 09/21/08 JRA/SV FISH @ 10217' (09/12/08) 01/10/82 N1 ES RWO 03/02/09 OOP/PJC DRAWING CORRECTIONS 12/03/05 SRB/TLH CMT & FISH (MILL) CORRECTIO 04/06/09 AMW Proposed Schematic 01/07/06 DAV/PJC FISH @ 10623' 03/08/08 JIMITLH IBPSET(11/20/07) 09/05/08 OOP/PJC DRAWING CORRECTIONS SAFETY NOTES: 2000' 4-1/2" X NIP, ID 3.813" 2345' 9-5/8" Foc 2469' 9-5/8" FOC GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 3 4 5 6550' ~-~ Hanger /liner top PRUDHOE BAY UNIT WELL: 13-03A PERMIT No: API No: SEC 14, T10N, R14E, 2054' FSL & 7' FEL BP Exploration (Alaska) by DS73-03A (P14) Proposal Schlumberger Report Date: April 7, 2009 Survey 1 DLS Computation Method: Mwmum Curvature / Lubmskl Client: BP Exploration Alaska Vertical Section Azimuth: 92.390° Field: Structure 1 Slot: Prudhoe Bay Unit - EOA DS•13 / 13-03 M ~~ Vertical Section Origin: ay ND Reference Datum: N 0.000 ft, E 0.000 ft Rotary Table Well: 13-03 '' ND Reference Elevation: 74.50 ft relative to MSL Borehole: Plan 13-03A 1leasi b' Sea Bed 1 Ground Level Elevation: 46.00 ft relative to MSL UWIIAPgF: 500292032500 ^ Magnetic Declination: 22.731 ° Survey Name 1 Date: 13-03A (P14) I April 7, 2009 Total Field Strength: 57712.406 nT Tort 1 AHD 1 DDI 1 ERD retie: 295.580° 110351.97 ft / 6.742 11.147 Magnetic Dip: 80.884° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: June 15, 2009 Location LaULong: N 70.21943148, W 148.48963076 Magnetic Declination Model: BGGM 2008 Location Grid NIE YIX: N 5932121.110 ftUS, E 687206.490 ftUS North Reference: True North Grid Convergence Angle: +1.42128859° Total Corr Mag North -> True North: +22.731 ° Grid Scale Factor: 0.99993981 Local Coordinates Referenced To: Well__Head Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS Tie-In survey titi'itf .bu 4y.UU 5o .uu ouuzsa aaro.aa Top Whipstock 6700 .00 49.00 55 .00 5803.33 5877.83 Base Whipstock 6716 .00 49.83 57 .28 5813.74 5888.24 Crv 4/100 6729 .00 49.83 57 .28 5822.13 5896.63 6800 .00 47.75 59 .84 5868.90 5943.40 6900 .00 44.92 63 .75 5937.95 6012.45 WS2 6921. 14 44.34 64. 63 5953.00 6027.50 7000 .00 42.24 68 .06 6010.41 6084.91 End Crv 7058 .12 40.76 70 .76 6053.94 6128.44 WS1 7307. 70 40.76 70. 76 6243.00 6317.50 CM3 7521. 56 40.76 70. 76 6405.00 6479.50 CM2 8200. 11 40.76 70. 76 6919.00 6993.50 CM1 9046. 31 40.76 70. 76 7560.00 7634.50 Crv 4/100 9314 .33 40.76 70 .76 7763.02 7837.52 9400 .00 39.43 75 .67 7828.58 7903.08 9500 .00 38.16 81 .73 7906.55 7981.05 9600 .00 37.21 88 .09 7985.71 8060.21 End Crv 9629 .34 37.00 90 .00 8009.12 8083.62 THRZ 9666. 76 37.00 90. 00 8039.00 8113.50 BHRZ 9875. 87 37.00 90. 00 8206.00 8280.50 TJB 10191. 41 37.00 90. 00 8458.00 8532.50 TJA 10340. 41 37.00 90: 00 8577.00 8651.50 Ia4r.oo 1848.45 1858.25 1866.38 1910.73 1972.94 1986.02 2034.57 2070.01 2221.47 2351.26 2763.05 3276.59 3439.24 3491.31 1114.U0 1114.70 1121.47 1126.84 1154.71 1188.93 1195.40 1217.12 1230.67 1284.36 1330.36 1476.31 1658.33 1715.98 1731.93 3552.11 1744.24 3612.64 1749.70 3630.31 1750.00 3652.81 1750.00 3778.54 1750.00 3968.27 1750.00 4057.87 1750.00 10`.7.7.00 I IJ.OJL 1..71 J.JO J~JJLO I./ / 1896.59 65.OOR 0.16 5.38 5933282.44 1906.68 -- 12.00 5.39 5933289.45 1915.03 138.05R 0.00 5.39 5933295.03 1960.59 136.36R 4.00 5.41 5933324.02 2024.28 2037.65 2087.14 2123.17 2277.01 2408.83 2827.08 3348.66 3513.86 3566.64 133.66R 4.00 5.45 5933359.81 133.04R 4.00 5.45 5933366.61 130.54R 4.00 5.48 5933389.54 --- 4.00 5.49 5933403.98 --- 0.00 5.52 5933461.47 114.64R 110.89R 3628.00 106.16R 3688.81 101.13R 3706.51 --- 3729.03 --- 3854.87 --- 4044.77 --- 4134.44 --- 0. 00 5.55 5933510.72 0. 00 5.61 5933666.99 0. 00 5.69 5933861.88 0 .00 5.71 5933923.61 4 .00 5.73 5933940.86 4 .00 5.75 5933954.69 4 .00 5.77 5933961.66 4 .00 5.78 5933962.39 0. 00 5.78 5933962.95 0. 00 5.79 5933966.07 0. 00 5.81 5933970.78 0. 00 5.82 5933973.00 V0.7V/J.VL IV /V.LLLY/YJV YY IYV.Y/YJJl JJ 689074.73 N 70.22247613 W 148.47432991 689084.65 N 70.22249462 W 148.47424849 689092.87 N 70.22250928 W 148.47418106 689137.71 N 70.22258540 W 148.47381350 689200.53 N 70.22267884 W 148.47329958 689213.73 N 70.22269650 W 148.47319171 689262.67 N 70.22275580 W 148.47279235 689298.36 N 70.22279279 W 148.47250162 689450.81 N 70.22293934 W 148.47126037 689581.44 N 70.22306490 W 148.46 689995.91 N 70.22346324 W 148.4 1 690512.78 N 70.22395992 W 148.46 323 690676.49 N 70.22411721 W 148.46128018 690728.85 N 70.22416073 W 148.46085428 690789.89 N 70.22419428 W 148.46035915 690850.54 N 70.22420911 W 148.45986846 690868.23 N 70.22420989 W 148.45972567 690890.74 N 70.22420986 W 148.45954399 691016.54 N 70.22420969 W 148.45852865 691206.36 N 70.22420942 W 148.45699653 691296.00 N 70.22420929 W 148.45627303 WeIlDesign Ver SP 2.1 Bld( users) 13-03\13-03\Plan 13-03A\13-03A (P14) Generated 4/7/2009 4:09 PM Page 1 of 3 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty ft de de ft ft ft ft ft de de 100 ft Index ftUS ftUS 7" Csg TSHA TSHB Bld 10/100 TSHC TSAD End Bld Crv 6/100 End Crv Crv 6/100 13-03A Tgt 1 Fault End Crv Crv 6/100 13-03A Tgt 2 End Crv Crv 6/100 Target 3 End Crv Crv 6/100 13-03A Tgt 4 End Crv Fault Crv 6/100 1 U44y..74 10449.36 10481.90 10508.20 10519.34 10530.82 10578.19 10600.00 10700.00 10800.00 10900.00 11000.00 11049.34 11674.34 11700.00 11718.36 12364.84 12400.00 12471.94 12500.00 12550.00 12551.63 12796.82 12800.00 12859.95 12900.00 12938.78 13141.52 13200.00 13236.58 13300.00 13400.00 13411.73 13795.52 13800.00 13847.42 13900.00 13902.96 14080.00 14503.94 3/.VV 37.00 37.00 37.00 37.00 38.15 42.88 45.07 55.07 65.07 75.07 85.07 90.00 `JU.VU 6004.UU O/JO.OV 90.00 8664.01 8738.51 90.00 8690.00 8764.50 90.00 90.00 90.00 90.00 90.00 8711.00 8719.90 8729.00 8765.00 8780.69 8785.50 8794.40 8803.50 8839.50 8855.19 90.00 90.00 90.00 90.00 90.00 8844.80 8894.64 8928.69 8945.92 8948.05 90.00 90.00 8948.x5 91.51 90.29 8947.71 92.59 90.50 8947.05 92.59 90.50 8917.81 94.70 90.67 8915.58 99.00 91.00 8907.00 100.67 91.18 8902.21 103.66 91.51 8891.67 103.75 91.52 8891.29 103.75 91.52 8832.99 103.56 100.00 97.61 95.29 95.29 92.04 90.00 86.43 80.80 80.14 80.14 80.34 82.50 84.44 84.55 91.49 91.00 90.76 90.53 90.53 89.22 88.40 87.09 84.99 84.74 84.74 84.92 86.80 89.30 89.44 8832.24 8820.00 8813.87 8809.51 8790.81 8787.07 8786.42 8788.39 8799.51 8801.46 84.55 84.55 8867.17 8867.93 8875.00 8880.98 8881.26 8919.30 8969.14 9003.19 9020.42 9022.55 9022.55 9022.21 9021.55 8992.31 8990.08 8981.50 8976.71 8966.17 8965.79 8907.49 8906.74 8894.50 8888.37 8884.01 8865.31 8861.57 8860.92 8862.89 8874.01 8875.96 H I LJ.J / 4123.38 4142.95 4158.76 4165.46 4172.45 4203.19 4218.32 4294.84 4381.31 4475.12 4573.41 4622.65 5247.10 5272.74 5291.08 5936.54 5971.61 6043.00 6070.64 6119.50 6121.08 6359.21 6362.30 6420.97 6460.53 6499.04 6700.81 6759.11 6795.61 6858.78 6957.50 6968.97 8941.67 7343.73 8942.43 7348.11 8949.50 7394.69 8955.48 7446.77 8955.76 7449.71 89.44 8898.07 8972.57 7625.72 89.44 8938.32 9012.82 8047.19 I/VV.VV 1750.00 1750.00 1750.00 1750.00 1750.00 1750.00 1750.00 YLVV.VV 4200.01 4219.59 4235.42 4242.13 4249.13 4279.89 4295.03 1750.00 4371.62 1750.00 4458.17 1750.00 4552.05 1750.00 4650.43 1750.00 4699.71 1750.00 5324.71 1749.93 5350.37 1749.80 5368.72 1744.12 6014.50 1743.76 6049.59 1742.72 1742.19 1741.05 1741.01 1734.70 1734.62 1733.34 1732.74 1732.30 1730.45 1730.58 1731.34 1733.83 1740.68 1741.72 1776.36 1776.76 1780.14 1781.92 1781.95 1783.66 1787.77 6121.00 6148.64 6197.49 6199.07 6437.15 --- V.VV J.VJ --- 0.00 5.83 5933974.63 --- 0.00 5.83 5933975.12 HS HS HS HS HS HS HS HS 11.01 R 11.01 R 4.37R 4.38R 6.05R 6.OSR 6.15R 172.26E 0.00 0.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 0.00 6.00 6.00 0.00 6.00 6.00 6.00 6.00 6.00 0.00 5.83 5933975.51 5.83 5933975.68 5.84 5933975.85 5.86 5933976.61 5.87 5933976.99 5.91 5933978.89 5.95 5933981.03 5.98 5933983.36 6.02 5933985.80 6.04 5933987.02 6.11 5934002.53 6.12 5934003.10 6.13 5934003.42 6.20 5934013.75 6.20 5934014.26 6.22 5934015.00 6.23 5934015.16 6.24 5934015.23 6.24 5934015.22 6.27 5934014.82 6.27 5934014.82 6.28 5934015.00 6.29 5934015.37 6.30 5934015.90 6.32 5934019.05 6.34 5934020.63 6.34 5934022.29 6.36 5934026.36 6.38 5934035.66 6.38 5934036.98 6.41 5934080.95 6.41 5934081.46 6.42 5934086.00 6.43 5934089.07 6.43 5934089.17 6440.24 172. 26E 6.00 6498.91 174. 28E 6.00 6538.48 174. 32E 6.00 6577.00 --- 6.00 6778.87 158. 07E 0.00 6837.22 158. 15E 6.00 6873.79 159. 85E 6.00 6937.12 159. 81 L 6.00 7036.21 159. 57E 6.00 7047.73 -- 6.00 7424.27 40. 92R 0.00 7428.66 40. 89R 6.00 7475.43 52. 14R 6.00 7527.63 51. 86R 6.00 7530.57 --- 6.00 7706.81 --- 0.00 8128.81 3. 06R 0.00 6.45 5934095.26 6.48 5934109.83 691361.54 N 70.22420919 W 148.45574402 691381.12 N 70.22420916 W 148.45558600 691396.94 N 70.22420913 W 148.45545832 691403.65 N 70.22420912 W 148.45540419 691410.64 N 70.22420911 W 148.45534773 691441.40 N 70.22420906 W 148.45509951 691456.53 N 70.22420904 W 148.45497733 691533.09 N 70.22420892 W 148.45435946 691619.60 N 70.22420878 W 148.45366116 691713.46 N 70.22420863 W 148.453694 691811.80 N 70.22420846 W 148.4 2 691861.06 N 70.22420838 W 148.45 29 692485.83 N 70.22420725 W 148.44666964 692511.48 N 70.22420702 W 148.44646267 692529.82 N 70.22420663 W 148.44631462 693175.51 N 70.22418976 W 148.44110429 693210.60 N 70.22418870 W 148.44082119 693282.00 693309.64 693358.51 693360.09 693598.24 693601.33 693660.00 693699.57 693738.10 693939.94 693998.26 694034.80 694098.04 694196.93 694208.42 694583.96 694588.34 694635.00 694687.14 694690.08 694866.21 695287.95 N 70.22418571 W 148.44024507 N 70.22418421 W 148.44002209 N 70.22418097 W 148.43962790 N 70.22418085 W 148.43961516 N 70.22416308 W 148.43769434 N 70.22416285 W 148.43766940 N 70.22415923 W 148.43719610 N 70.22415748 W 148.43687684 N 70.22415620 W 148.43656600 N 70.22415064 W 148.43493730 N 70.22415086 W 148.450 N 70.22415284 W 148.4 45 N 70.22415950 W 148.43366053 N 70.22417796 W 148.43286093 N 70.22418076 W 148.43276797 N 70.22427442 W 148.42972973 N 70.22427549 W 148.42969426 N 70.22428460 W 148.42931694 N 70.22428931 W 148.42889575 N 70.22428939 W 148.42887202 N 70.22429359 W 148.42745008 N 70.22430361 W 148.42404520 WeIlDesign Ver SP 2.1 Bld( users) 13-03\13-03\Plan 13-03A\13-03A (P14) Generated 4/7/2009 4:09 PM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS 14(iUU.UU 13-03A Tgt 5 14678.32 14700.00 14800.00 14828.32 14900.00 15000.00 15100.00 15200.00 15300.00 Fault 15400.00 15500.00 15600.00 15700.00 yU.31 C`J./5 Cy4Z.UZ `JUl/.IL 8143 .UV I/88R0 CLL4./J J.UOR 95:00 90.00 8939.00 9013.50 8221 .13 1788.62 8302.94 50.OOR 95.84 91.00 8936.95 9011.45 8242 .71 1788.43 8324.53 50.09R 99.66 95.67 8923.46 8997.96 8341 .73 1782.69 8423.40 50.72R 100.73 97.01 8918.45 8992.95 8369 .54 1779.61 8451.10 92.19R 100.54 101.38 8905.21 8979.71 8439 .47 1768.36 8520.63 93.OOR 100.17 107.47 8887.22 8961.72 8535 .64 1743.87 8615.85 94.09R 99.68 113.54 8869.97 8944.47 8629 .21 1709.39 8708.07 95.14R 99.10 119.59 8853.64 8928.14 8719 .17 1665.29 8796.27 96.13R 98.41 125.62 8838.41 8912.91 8804 .54 1612.05 8879.49 97.05R 97.63 131.63 8824.46 8898.96 8884. 37 1550.27 8958.81 97.89R 96.76 137.61 8811.92 8886.42 8957 .79 1480.61 9027.39 98.64R 95.83 143.57 8800.95 8875.45 9024 .01 1403.84 9090.46 99.29R 94.83 149.52 8791.65 8866.15 9082.28 1320.81 9145.32 99.84R End Crv 15783.00 93.96 154.44 8785.29 8859.79 9124.16 TD / 4-1/2" Lnr 16279.34 93.96 154.44 8751.00 8825.50 9356.27 Legal Description: Northing (Yl Surface : 2054 FSL 7 FEL S14 T10N R14E UM 5932121.11 13-03A Tgt 1 : 3794 FSL 4231 FEL S18 T10N R15E UM 5934015.00 TD / BHL : 2849 FSL 959 FEL S18 T10N R15E UM 5933155.00 1247.78 9184.18 801.10 9397.86 iftUSl Easting (X1 iftUS 687206.49 693282.00 696581.00 O.VV V.JV :l~JYI IL.VJ VJJJV J.VG IY /V. LGYJVJ I! YV.YGJLI IGV 6.00 6.51 5934115.00 695462.00 N 70. 22430540 W 148.42264025 6.00 6.52 5934115.35 695483.58 N 70. 22430482 W 148.42246610 6.00 6.54 5934112.06 695582.56 N 70. 22428884 W 148.42166842 6.00 6.54 5934109.67 695610.33 N 70. 22428035 W 148.42144496 6.00 6.56 5934100.15 695680.11 N 70. 22424940 W 148.42088410 6.00 6.58 5934078.03 695775.90 N 70. 22418220 W 148.42011604 6.00 6.60 5934045.84 695868.94 N 70. 22408770 W 148.41937233 6.00 6.61 5934003.95 695958.20 N 70. 22396694 W 148.41866113 6.00 6.63 5933952.80 696042.71 N 70. 22382124 W 148.41799023 6.00 6.65 5933892.95 696121.54 N 70. 22365220 W 148.4 98 6.00 6.67 5933825.07 696193.82 N 70. 1 22346167 W 148.4 20 6.00 6.68 5933749.90 696258.77 N 70. 22325174 W 148.41 14 6.00 6.70 5933668.25 696315.66 N 70. 22302471 W 148.41584836 6.00 6.72 5933596.21 696356.33 N 70. 22282506 W 148.41553549 0.00 6.75 5933155.00 696581.00 N 70. 22160405 W 148.41381614 WeIlDesign Ver SP 2.1 Bld( users) 13-03\13-03\Plan 13-03A\13-03A (P14) Generated 4/7/2009 4:09 PM Page 3 of 3 by Schlumberger WELL FIELD STRUCTURE DS13-03A (P14) Prudhoe Bay Unit - EOA DS-13 Magr¢ik Parameters Surface Locak°n NN)2) Nasky Stale PUnas. Zane W, US Fee, Miscellaneous Model'. BGGM2008 Dip: ~.BBa° Dale: June 15. 2009 Laf: N]0139953 Nonhing'. 5932121.11 ftU5 Gnd C°nv'. +1 G212B859° Sbl: t3-03 TVD Ret. ftolary Tahle (]450Xahove MSC( Mag Dec: +22.]31° FS: 5]]126 nT Lon: W1<829226]1 Easeng. 68]206.<9 XUS Scale Fact 09999J98126 Plao. 1J-O3A (Pty) Srvy Gala: Ppil O). 2009 6000 ~ 7000 0 0 0 c N fil ~ 8000 H 9000 2000 3000 4000 5000 6000 7000 8000 9000 ._.._.._.. _.._ _.. _.._..-..-..-.. _..-..- -. .1. Crv 41100: -..-..-.._..-..-..-..-...j.-..-..-..-..-..-..-..-..~..-..-..-..-..-..-..-..- .-..-..-..-..-..-..-..- -..-..-..-..-..-..-..-.. _.. _.. _.. _.. _.._.._.._ End Crv ~ ~ .. . Crv 61100 ~ TD l4-tl2" Lnr : End Crv Target 3 End drv 7"Csg ~ -. _. _.. .. _.._.._.._ .. .. .. ' 6 BId tON00 1j-03A Tgt2 ;End Crv Fault „_;, ,_„ ,_„_„_.._.. _. ._.._..-.. _.._ -..-.. _.. _..-..-.._.._.._ _.. _.. _.. _.._.._. _. _ _.._.._.._..-...t.._..-..-.._.._.._.._.. _..~~rv..5_~.._.. _ _ ._.._.._.._.._.. _.._.._ _.. _.._.. _.._. _ .. l f iiiiiiiiiiiiiiii,iiiiiiiiiitiiiiiiiiHiiiiiiiiiiititiiiifiiiiii E, Eiii~: 'iiiiiiiiiiiiiiiiitiiifiiiifiiiiitiiiiiiiiiiii<~ii~i0'i i 'iifi iii' i;3iiSiiii;;iiiiiiiiiiiiii3iiiitii iiiiiiieiiiiii iiiiii iiiii 'tiiiiiiiifi3ii ......................... Ene crv civ finoo Crv 61100 Fault 1303A Tgt d Fault End BId Crv'fi1100 ~ End Crv Crv &100 13-03A Tgt 5 ;End Crv 13-03A Tgt 1 3-03 6000 7000 8000 9000 2000 3000 4000 5000 6000 7000 8000 9000 Vertical Section (ft) Azim = 92.39°, Scale = 1(in):1000(ft) Origin = 0 N/-S, 0 E/-V by Schlumberger WELL FIELD STRUCTURE DS13-03A (P14) Prudhoe Bay Unit - EOA DS-13 Magnelc Parameien SuM1ace Location NPDl) AlasMa SUie PNnes. Zone 04. US Faei MlscelMneous Matlel'. SGGM 3008 Dp. 80.884° Date: June tfi. 3009 Lat: NT0139.9fi3 NonM1ing: 59311]1.11 M1US GfW DOnY. X162118889° Slol- 1303 TVD Raf: ROUry TaLle (T4.50 XaEOVa MSLj Mag Dec: X12]31° FS: 5]]114 nT Lon: W1481921.8]1 Easiing: 68]]06 4911U5 Srala Fact:0999938B12fi Plan: 13-03R jP 14) SiW Dale: Api101. 1009 2000 3000 4000 5000 6000 7000 8000 9000 10000 4000 3000 n n A Z 2000 r 0 0 0 c a~ ~ 1000 0 _, 000 )00 • )00 FI[ 6 )00 )00 i ~~ Inns 2000 3000 4000 5000 6000 7000 8000 9000 10000 «< W Scale = 1(in):1000(ft) E »> Comparry: North America -ALASKA - BP Local Co=ordinate RsToerencsc Well 13-03 -Slot 03 _ _ Project: Prudhoe Bay TVD Reference; ,13-03A Plan ~ 74.50ft (Nabors XES) Reference:Site: PB DS 13 MD Reference: ' 13-03A Plan Q 74.50ft (Nabors XES) Site Error: O.OOft North Reference: True Reference Well: 13-03 Survey Calculation Method: Minimum Curvature Weil Error: O.OOft Output errors are at ! 1.00 sigma Reference YYsilbore ' Plan 13-03A Database: EDM .16 - Anc Prod - WH24P .Reference Design: .: Plan #1413-03A Offset TiID Referenc®: ° Offset Datum Rsferenca Plan #14 13-03A __ Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refen Depth Range: 6,700.00 to 16,279.34ft Scan Method: Trav. Cylinder North Survey Tool Program Date 4/7/2009 From To (it) (ft) Survey (iNellborej Tool Name Description 98.50 6,698.50 13-03 Srvy 1 Camera based MS gyro (13-~ CB-GYRO-MS Camera based gyro multishot 6,698.50 8,100.00 Plan #14 13-03A (Plan 13-03A) MWD MWD -Standard 6,698.50 10,449.00 Pian #14 13-03A (Plan 13-03A) MWD+IFR+MS MWD +IFR + Mull Station ~T7l2tJ09 4:2~~3Pti~ __-- Page 2 of 4 COMPASS 2003.16 Build 70 Company: North America -ALASKA - BP Project: 'Prudhoe Bay :Reference Site: PB DS 13 .Site Error: O.OOft :Reference Wslh 13-03 Well Error::. O.OOft Reference Welltrore Plan 13-03A .Reference Oesign: Plan #14 13-03A local Co-ordtnate Reference: Well 13-03 -Slot 03 TVD Reference: 13-03A Plan (~ 74.50ft {Nabors XES) MD Reference: 13-03A Plan ~ 74.50ft {Nabors XE5) North Reference: True Survey Calculation Method:.. Minimum Curvature Output errors are at 1.00 sigma Database: EDM .16 - Anc Prod - WH24P Offset TVD Reference: 'Offset Datum Summary Reference Offset Cet>tre to No~Go Albwabb Measured Measured Centre Dlstancs Deviation Warning Sits Name' Depth Depth Distance (ft) from Plan Offset Well - Wellbore -Design - (~) (ft) (~ _ {ft) PBDS01 01-18 - 01-18 - 01-18 15,580.07 11,590.00 154.83 227.05 -57.50 FAIL -Major Risk PBDS12 --12=T2 =-12=T7=12=12 73;231:'16 -'IU,'105:00- ?006 _ _ _-=5Q4:5~ I7sk- 12-12 - 12-12A - 12-12A 14,900.00 9,705.00 1,126.78 381.37 791.35 Pass -Major Risk 12-17 - 12-17 -12-17 11,793.83 10,930.00 1,007.86 947.78 87.79 Pass -Major Risk 12-19 -12-19 - 12-19 12,299.90 10,935.00 1,291.24 948.72 426.57 Pass -Major Risk 12-20 -12-20 -12-20 14,293.81 10,275.00 1,282.12 378.59 931.91 Pass -Major Risk --120= 92=20~ t2=20A --_ ---- - -t#~13:9o- ~0~4sUtY ~fs4:$0 - ----357.78 -~08~82 Pass=-Major Risk-- 12-20 -12-20A -12-20A wp10 13,938.88 10,535.00 844.21 357.90 488.42 Pass -Major Risk 12-21 -12-21 -12-21 15,431.43 9,230.00 1,578.58 524.34 1,090.80 Pass - Major Risk ___ __ 12-37 -12-37 - 12-37 15,232.44 9,240.00 947.09 252.59 714.24 Pass -Major Risk Plan 12-37 -Plan 12-37 -Plan #6 12 37 15,228.81 9,245.00 940.11 265.65 694.39 Pass -Major Risk Pian 12-37 -Plan 12-37P81 - Pfan #6 12-37PB1 15,228.81 9,245.00 940.11 265.70 694.38 Pass -Major Risk PBDS13 13=04-= 43=61 = 13=01 -----__ ----- - ----. _ 13-02 -13-02 -13-02 __-- -___ __- - 6,700.00 ------ _ 7,260.00 __ -- 1,546.22 467.57 --- _ 1,264.62 -E3utof rang Pass -Major Risk 13-02A -13-02A - 13-02A 6,700.00 7,265.00 1,551.45 467.41 1,271.02 Pass -Major Risk 13-02B - 13-028 - 13-026 12,854.04 14,050.00 745.37 589.42 161.12 Pass -Major Risk 13-02BL1 - 13-02BL1 - 13-02BL1 6,700.00 6,955.00 975.47 415.81 662.41 Pass -Major Risk --#3-02BRB1--13-026PB1 13-02BP;r' ~ '54636 - -- -4658 ~264.~'~ Pass-MajorRislF 13-02BPB2 -13-02BP62 - 13-02BPB2 6,700.00 7,265.00 1,551.60 467.41 1,271.22 Pass -Major Risk 13-02BP63 - 13-02BPB3 - 13-026P63 10,462.13 11,745.00 1,116.79 534.41 62726 Pass -Major Risk -13-03 -13-63 - 13-63 6,813.29 6,815.00 4.83 334.60 -32 .59 FAIL -Major Risk 13-04 -13-04 -13-04 Out of range -~3-D5~3415--.13_!05 - ~nR~~O 7~4nnn ~_,gg5.56_-_ _-__58f~n a 1,1x2.38 _-Pass--Major 13-06 -13-06 -13-06 Out of range 13-O6A - 13-06A - 13-06A Out of range 13-06APB1 - 13-06AP61 - 13-06AP61 Out of range 13-066 -13-068 - 13-068 10,689.19 11,099.68 1,595.87 1,291.54 327.64 Pass -Major Risk 13-09 - P~~~A~Q~A_w~01 --------____. _Qut9f r~?~ge___--_ - 13-10 -13-10A - 13-10A Wp 2 6,700.00 7,275.00 1,329.51 40324 959.13 Pass -Major Risk 13-21 - 13-21 - 13-21 14,278.11 12,795.00 1,579.36 2,017.40 -429.95 FAIL -Major Risk - - 2~ .66-- -----55 . -Pass-MajorRisk 'i dT772~d~ 4~2533PM --- - __ ___ ____ _ -. -_-- Page 3 of 4- -- - - - - -- -COMPASS 2003.16 Build 70 From kop to TD Scan interval 100 ft Scale 1:100 01-18, 12-12, and 13-21 Risk 1:200 7 90 180 Project: Prudhoe Bay Site: PB DS 13 Well: 13-03 Wellbore: Plan 13-03A Design: Plan #14 13-03A Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [100 ft/in] AS- BUIlT ~t+ •- ~9's' 1 ~•~u~ a. Fox f~~ ti ass - s ~ •~ _'.~ CERTIFICATE OF SURVEYOR 1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED ANO LICENSED TO PRACTICE LAND SURVEYING iN tHE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATtON SURVEY MADE BY ME OR UNDER MY SUPERVISION, ANO ALL DIMENSIONS ANO OTHER DETAILS ARE CORRECT. 7- 2~- 7B DAT E ~~~~x SURVEYOR V WELl~ o.1 SAT. 70° 13~ 12.265" Y 5 932 354.81 LONG. 148° 29 24.106 X 687 15 1.26 ~ WELt Nat LAT. t0° 13~ i l . l 06~ Y 5 932 237.63 LOAG. 148°29 23.391 X 687 178.80 WELL No.3 LAT. TO° 13~ 09.954° LONG. 148° 29 22.671 ' V WELL No.4 LAT. 70° 13; 08.801 LONG. 148° 29 21.939 Y 5932 121.11 X 687 206.49 Y 5 932 004.57 X 687 234.61 COORDINATES ARE ALASKA STATE PLANE ZONE 4. • EXISTING CONDUCTOR ARCO No. HVL No. I ~ RICHFIELD CO. ~ AS-BUILT DRILL SITE No.13 WELLS 1 THRU 4 LOCATED IN PROTRACTED SECTION 13814,TION,RI4E,UM. PREPARED BY ~ HEWITT V. LOUNSBURY 8 ASSOC. '23 W 6fn AVE., ANCHORAGE, ALASKA I GATE JULY 1978 SCALE ~ CMKD. BY P•C• FIEID 8K. U~~~ Alaska Department of Natural ~ources Land Administration System . Page 1 of~ C `::?;,Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural ResOU1'Ces ~ ~m 4LL~ Alaska DNR Case Summary File Type: ADL File Number: 28330 ~ Printable Case File Summary See Township, Range, Section and Acreage? ~ New search ,-- ~-, t!~ Yes t? No LAS Menu I Case Abstract I Case Detail I Land Abstract ,, File: ADL 28330 '"'_ Search for Status. Plat Updates As of 04/22/2009 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: 08/19/1965 Total Acres: 2512.000 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: O1 ON Range: 015E Section: 17 Section Acres: 640 Plats Meridian: U Township: OION Range: 015E Section: 18 Section Acres: 615 Meridian: U Township: Ol ON Range: 015E Section: 19 Section Acres: 617 Meridian: U Township: OION Range: 015E Section: 20 Section Acres: 640 Legal Description OS-28-1965 * * *SALE NOTICE LEGAL DESCRIPTION* Cl -1-160 TION-RISE-UM 17,18,19, 20 2512.00 U- 3- 7 End of Case Summary Search. Last updated on 04/22/2009. httn.//dnr.alaska.~ov/nroiects/las/Case Summarv.cfm?FileType=ADL&FileNumber=2833... 4/22/2009 Alaska Department of Natural ~ources Land Administration System • Page 1 of~ll >a Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins /Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28315 ~ Printable Case File Summary See Township, Range, Section and Acreage? New Search ~' Yes ~~~~ No LAS Menu ~ Case Abstract ~ Case. Detail ~ Land Abstract Case Type. 784 O[L & GAS LEASE COMP D File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Offrce of Primary Responsibility: DOG DN OIL AND GAS File: ADL 28315 r " Search for_Status Plat Updates As of 04/22/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 NR Unit: 780 OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASS IGNMENT APPROVED Meridian: U Township: O1 ON Range: 014E Section: 13 Section Acres: 640 Search Plats Meridian: U Township: O l ON Range: 014E Section: 14 Section Acres: 640 Meridian: U Township: O l ON Range: 014E Section: 23 Section Acres: 640 Meridian: U Township: O1 ON Range: 014E Section: 24 Section Acres: 640 Legal Description 0.5-28-1965 * * * SALE NOTICE LEGAL DESCRIPTION C14-137 TION, R14E, UM 13, 14, 23, 24 2560.00 End of Case Summary Last updated on 04/22/2009. httn://dnr.alaska.gov/nroiects/las/Case Summarv.cfm?FileTvpe=ADL&FileNumber=2831... 4/22/2009 TRANSMITTAL LETTER CHECKLIST WELL NAME ~/~'~ /3-0~3~9 PTD# v~OgU~~ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~•E't,/D.~,/OE~Ay POOL: PiG~I/.D.4~~~' /~~Jy ©/G 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 WELL HERMIT CHECKLIST Field 8 Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 13.03A Program DEV Well bore seg ^ PTD#:2090480 Company BP EXPLORATION~ALASKAa INC Initial ClasslType DEV 1 P END GeoArea 890 Unit 11650 ONOff Shore ~_ Annular Disposal ^ Administration 1 Pe[mitfeeatkached-- --------- - - - - --- ---- - NA- -- -- -- ---- ----- -- - - - ---- - ' 2 Leese numberaPRroRriate--- ---- -- --- - - --- -Yes - --- - -- - - - - -- ----- - -- - - -- - -- - - 3 Unique well-name andnumbet-- -- - - - - - -Yes------ - -- - -- - -- - ---- ----- -- - --- -- -- 4 Well located in a_definedpool--- ---- - -- -- -- ---- -Yes---- -- - - - - - ---- ---- - - -- - -- - ~ 5 Well located Properdtstancefromdnlli[tgpnit_baundary-__-___-_-- ___ ____--Yes--_---- -------------------------------------------- - -- - -- - 6 Well locatedP[oRflrdistanGe-f[amotherwells-------------------- ----------Yes------- ------------------------.--------------------- -- -- - --- - 7 Sufficient acreageayailableindtillingunit---------------------- ---_-._--Yes------_ 2569 acres.-______-__-________-_____-_-----.---_.------------------ 8 Ifdeviated, is-wellboreplatinciuded - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - 9 OpstakoronlyaltectedPartY.-- -- -- --- - - - -- --- Yes -- - - -- --- - ------ ---- --- ---- -- - ---- - 10 Operatorhas-appropriate_bondinforce-__--_--__--_____-_ ____-----Yes------- BlanketBond#6194.193•---------------------------------------------------- 11 Pe[miteanbeissuedwiihoutGOnserva1i9n9rder--------------.-- ------.--Yes~------ ------------------------------------------ -- -------- ---- Appr Date 12 Permit-eanbeisSUedwiihoutadmiriisirative_approval-------------- ----------Yes--.-- --------.------------------------------------ -- -- --- - --- 13 Can permit beaRRrovedbeforel5-daywait--------------------- ------_--Yes------- -----------------------------,------------- ---- -- -- -- ACS 4!2212009 14 Well locatedwHhinareaandstrataauthorizedby-InjectionOrdsr#(put_IQ#in_ comments)-(For-NA________ _____________________________________-_______--__--___.__-_______ 15 All wells within114_mileateaof[eyiewidentified(FOrservicewe!!only)-__-- --______ NA________ __________________________________________--__--__-_._--_________-- 16 Pte•Rroducedinjector:durationofpreproduotionless_than-3monihs_(FarseNicewellon__ly}_-NA________ _______-__-___.-__--__--__--__---------------------------------- 17 NoncoAven, gas conforms to AS31,05.03Q(j.1,A),(j.2.A-D} - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ - -- _ 18 Conductotstring_ptovided_--_________--_.______----- _ ---------NA_______ Conductorset_in DS 13-03(17$-0$2).______________-____--__----------------- Engineering 19 Surface casing.protectsallknovm_USDWS_____________________ _________ NA__-___- NOaquifers,AIQ46,cone!usion5,_-___-_______--_____--__-___---_-_------_ _--- ~ 20 CMT_votadequate_tecirculateonconductor&surfcsg______________ __________ NA-_--____ Surfacecasingsetin_DS13-03.-_____--_____.-___-__--__--._____-______-__._-_ 21 CMT_voladequate_t9tie-in long string tos#~rf_csg__________________ __________ NA_--_____ Production_easingsetin-D$1303.______-__-_______-_________--__--__-__---__-_- 22 CMT_will cover all knownproductivehorizons- - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ' 23 Cesing designs adequate for C~?, B &_pe[mafrost - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequatelankage_ornserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - Rig equipped wish steel pits, No reserve pit planned._ All waste to aARroved disRosalwell(s). - _ _ _ - _ _ - - _ - 25 Ifa_ra-dill,has_a10-403 for abandonment been approved____________ _________ Yes___--__ 309-14$-___--__________________-_________-_____-_------------------ 26 Adequake wellbore separationp[opgsed _ _ _ _ - _ _ _ . - _ - - _ - _ _ _ _ - Yes _ _ _ _ Proximity-analysis performed, T[aveling cylinder path calculated, _ _ _ _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 ffdiverterrequired,doesitmeetregulations_____-______-__-.__- _________ NA-__-___- BQPStaok_willalready-be in place___________________--._--____-___-__________ 28 program schematic & equip list adequate_ - - _ _ - - - - - Drilling iluid - - - - - - - - - - Yes _ _ _ - - Maximum expected formation pressure 9,0_EMW in Sag and 7.2 EMW in zone. MW planned 1t).8 &-up to 9.t) ppg Appr Date TEM 4!2312009 29 _ BQPts, do They meetregulatien - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 30 BOPS-press rating approp[iate; test to_(put psig in comments)- - _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - _ _ . MASP calculated at 3172 psi._ 3$00_psi_BQP testptanned. _ _ _ _ _ _ _ _ _ _ _ _ . = _ _ _ _ : _ _ _ _ _ _ - - _ _ _ _ . - 31 Choke-manifoldcomplieswlAPI_RP-53(Msy$4)__________________ __________Yes______- __ 32 Work will 9ccur with9ut operation shutdown- - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 !s presence-of ~f2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - - _ _ _ _ _ H2$ is present at DS 13, _Mud should_preclude H2S on rig. -Rig hassensors.and ela[ms: - - _ _ _ _ _ _ - - _ _ - _ _ 34 Mechanical-condition of wellswiihinAORverified(For-setvicewell only)___ ___________ NA-_______ _--_--__--__--_---______-_______-___-_-__-__--__--__--___-____._- - --- 35 Pemjit_canbeissuedwlohydrogen_suifidemeaslares______________ ---- ___________No-_______ MaxlevelH2Son-Pad was300ppmonwell13-02A,_---_____.-__--___________________ Geology 36 Data_ptesentedo4Rotentialoverprassurezones---------------- ----------- NA-------- ------------------------------------------ - - -- Appr Date 37 Seismic analysis.ofsha)IOwgasz9nes---- - ----- --- -- -- -~- --- -- -- - ---- ---- --- - -- -- - -- --- --- ACS 412212009 38 Seabed conditionsunrey_(ifoff-shore}---------------------- .---------- I~A__--_- --_----------------------------------- - -- -- - ---- - -- 39 ContactnamelphonefotWeeldY-P-rog[essreports-Iexploratory4nly]----- -----------Yes.----- -AbbyWarren-564,572Q•---_-----------------------------------.------------ Geologic Commissioner: Date: Engineering Daie Public Co issioner: Com ner Daie ' ~~~~v `~ z~-a~ C~G..Zf~d~ ~J
