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209-053
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 07-14C Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-053 50-029-20339-03-00 13056 Conductor Surface Intermediate Liner Liner 8985 80 2635 4975 6712 2467 12590 20" 13-3/8" 9-5/8" 7" 4-1/2 9002 29 - 109 28 - 2663 26 - 5001 3995 - 10707 10589 - 13056 29 - 109 28 - 2663 25 - 4687 3924 - 8464 8358 - 8985 12700 520 2670 4760 5410 7500 12590 1530 5380 6870 7240 8430 11750 - 12968 4-1/2" 12.6# 13Cr80 23 - 10581 9026 - 8986 Structural 4-1/2" Baker S-3 Perm , 10462 , 8245 8245 10462 8245 Bo York Operations Manager Jerry Lau Jerry.Lau@hicorp.com (907) 564-5280 PRUDHOE BAY / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028309 23 - 8351 334 491 42171 38043 427 611 0 976 996 324-370 13b. Pools active after work:PRUDHOE OIL No SSSV 10462 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:43 pm, Dec 02, 2024 Digitally signed by David Bjork (3888) DN: cn=David Bjork (3888) Date: 2024.12.02 13:52:46 - 09'00' David Bjork (3888) WCB 2-11-2025 DSR-12/16/24 RBDMS JSB 120424 ACTIVITYDATE SUMMARY 10/29/2024 SLB CTU #8, 1.75" Coil, 0.156" WT. Job Objective: Mill XN, mill CIBP Mobilize CTU 8 from DS06. MIRU CTU 8 ***Continue on WSR 10/30/24*** 10/30/2024 SLB CTU #8, 1.75" Coil, 0.156" WT. Job Objective: Mill XN, mill CIBP Continue RU CTU 8. MU BOT 3.71" venturi/burnshoe milling assembly. Fnc Test BOPs. SSV not Full open / put heat and grease crew service. Kill Well. RIH. Had a few issues getting passed ~12192' with burn shoe, kept stalling, had one 10k overpull. Eventually got by with no issue. Tagged again at 12210', Decision to POOH and swap for a 6 blade junk mill. MU BOT milling assembly and 3.7" 6 bladed junk mill. RIH. Tag 12218 CTMD. Made minimal progress and hung up a few times. POOH to swap to logging tools. ***Job in Progress*** 10/31/2024 SLB CTU #8, 1.75" Coil, 0.156" WT. Job Objective: Mill XN, mill CIBP, Ext AdPerf ***Job continued from 10/30/24*** Continue POOH. Mill rounded on the outer 1/2" edge.MU BOT MHA. HES memory gamma/CCL tool with SLB 3.25" JSN. RIH to 12300' with no issues, Paint a white flag at 12,190' and log up to 11,500'. Good data (-19' correction). PT safety joint, spot in TCP/Crane. Load well w/KCL. PU/MU & RIH 215' of 2-7/8" MaxForce Guns, 6 spf, 60 deg phase. ***Job in Progress*** 11/1/2024 SLB CTU #8, 1.75" Coil, 0.156" WT. Job Objective: Mill XN, mill CIBP, Ext AdPerf ***Job continued from 10/31/24*** Continue RIH w/ 215' of 2-7/8" MaxForce Guns, 6 spf, 60 deg phase. Tie into Coil Flag. Spot guns on depth. Perferate interval from 12,005' to 12,220'. Wait on winds to rig down. Sustained winds above 30 mph preventing crane work to get guns out of the hole. ***Job in Progress*** 11/2/2024 SLB CTU #8, 1.75" Coil, 0.156" WT. Job Objective: Mill XN, mill CIBP, Ext AdPerf ***Job continued from 11/01/24*** Continue Wait on winds to Un-deploy . Sustained winds above 30 mph preventing crane work to get guns out of the hole. Snow removal in front of the well. Spot Boom truck, Load & Kill well. Establish loss rate. Start continuous hole fill at .6 bpm with no returns at surface. PJSM for Gun Un-deployment. ***Job in Progress*** 11/3/2024 SLB CTU #8, 1.75" Coil, 0.156" WT. Job Objective: Mill XN, mill CIBP, Ext AdPerf ***Job continued from 11/02/24*** Continue Monitoring well on. Flow check. No Flow Establish loss rate. Start continuous hole fill w/0.6 bpm with no returns to surface. Break lubricator and install table. Break firing head. Ball recovered. Pull & LD 2-7/8" Perf guns. FP Well. RD scaffold. RDMO ***Job Ended *** Daily Report of Well Operations PBU 07-14C g Perferate interval from 12,005' to 12,220'. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 07-14C Mill Plug & Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-053 50-029-20339-03-00 ADL 0028309 13058 Conductor Surface Intermediate Production Liner 8985 80 2635 4975 6712 12590 20" 13-3/8" 9-5/8" 7" 9002 29 - 109 28 - 2663 26 - 5001 3995 - 10707 2470 29 - 109 28 - 2663 25 - 4687 3924 - 8464 12700 520 2670 4760 5410 12590 1530 5380 6870 7240 11750 - 12968 4-1/2" 13Cr80 23 - 105819026 - 8986 Structural 4-1/2" Baker S-3 Perm No SSSV 10462 8245 Date: Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY 7-20-2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:52 am, Jun 27, 2024 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.06.26 14:49:36 - 08'00' Eric Dickerman (4002) 324-370 10-404 SFD 7/11/2024 DSR-7/8/24MGR28JUN24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.11 15:06:23 -08'00'07/11/24 RBDMS JSB 071624 07-14C Plug Mill and EAP PTD:209-053 API: 500292033903 Well Name:07-14C API Number:500292033903 Current Status:Operable producer Rig:Coil Estimated Start Date:7/31/24 Estimated Duration:2days Regulatory Contact:Carrie Janowski 564-5179 Permit to Drill Number 209-053 First Call Engineer:Jerry Lau (907) 564-5280 (O)(907) 360-6233 (M) Second Call Engineer:Dave Bjork (907) 564-4672 (O)(907) 440-0331 (M) Current Bottom Hole Pressure:3,225 psi @ 8,800’ TVD 7.1 PPGE |Recent DS07 Average Max. Expected BHP:3,350 psi @ 8,800’ TVD 7.4 PPGE | Average Ivishak BHP Max. Anticipated Surface Pressure:2,470 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2,390 psi (Taken on 5/16/24) Min ID 3.725” ID @ 10,569’ X Nip Max Angle:99° Deg @ 12,002’ MD Tie In Log:SLB JEWELRY_05JUL2014 Brief Well Summary: 07-14C was drilled in 2008 and has been a strong producer with 100% ontime during this time. The GOR of the well started climbing in 2014. The toe perforations are the closest perfs to the GOC and were thought to be the likely culprit of the high gas rate. A PPROF was run in 7/14 that showed 55% of the gas contribution with 66.7% oil from the toe. A KB choker packer with orifice was set following the PPROF results to choke back the gas from the toe. As a result of the orifice set 20 MMSCF of gas was choked back along with 100 bopd which made the well competitive. The well started to gas out and reach MGOR so on 08/17 a plug was set to shut off the gas that was coming through the orifice. We will now reopen the toe perf interval by milling a plug and fishing a packer w/orifice then add 215’ of Z2A perfs. Objective: CT to mill CIBP, Fish KB PKR w/orifice, Add 215’ of Z2A perfs Procedure: Coiled Tubing Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. x The well will be killed and monitored before making up the initial perfs guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. Mill 4-1/2” CIBP @ 12,590’ 2. Fish 4-1/2” KB PKR w/orifice. Attempt to Recover. If unable, attempt to push to PBTD. 3. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 07-14C Plug Mill and EAP PTD:209-053 API: 500292033903 4. Load well with 1% KCL/SW down TBG. Max tubing pressure 2500 psi. This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS. a. Wellbore volume to top perf = 179 bbls i. 4-1/2” Tubing – 10582’ X 0.0152 bpf = 161 bbls ii. 4-1/2” Liner – 1168’ X 0.0152 bpf = 18 bbls b. 13Cr80 TBG from surface to 10,582 MD 5. MU and RIH with logging tools and drift BHA: 3-1/8” dmy gun & nozzle. 6. Flag pipe as appropriate per WSS for adperf. 7. POOH and freeze protect tubing as needed. 8. Confirm good log data. 9. At surface, prepare for deployment of TCP guns. 10. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 11.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. a.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 12.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Only 1 run, which will be 215’ of loaded guns (no blanks). Perf Schedule Use 2-7/8” Maxforce guns or similar Perf Interval (RUN 1) Perf Length Gun Length Weight of Gun (lbs) 12.41 lbs/ft 12005 - 12220 215’215’2668 13. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 14. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 15. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 16. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 17. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 18. RDMO CTU. 19. RTP or FP well. 07-14C Plug Mill and EAP PTD:209-053 API: 500292033903 Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Coil Tubing BOPE Schematic 4. Standing Orders for Open Hole Well Control during Perf Gun Deployment 5. Equipment Layout Diagram 6. Tie In Log 7. Sundry Change Form 07-14C Plug Mill and EAP PTD:209-053 API: 500292033903 Current Wellbore Schematic 07-14C Plug Mill and EAP PTD:209-053 API: 500292033903 Proposed Wellbore Schematic 07-14C Plug Mill and EAP PTD:209-053 API: 500292033903 Coiled Tubing BOPs 07-14C Plug Mill and EAP PTD:209-053 API: 500292033903 Standing Orders for Open Hole Well Control during Perf Gun Deployment 07-14C Plug Mill and EAP PTD:209-053 API: 500292033903 Equipment Layout Diagram 07-14C Plug Mill and EAP PTD:209-053 API: 500292033903 Tie In:SLB JEWELRY_05JUL2014 07-14C Plug Mill and EAP PTD:209-053 API: 500292033903 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Operations Manager Date Operations Engineer Date • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Rednll 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other. .-c/.--c/3f) id' 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 209-053 3. Address: P.O.Box 196612 Anchorage, Development ® Exploratory 0 AK 99519-6612 Stratigraphic ❑ service ❑ 6. API Number. 50-029-20339-03-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number. PBU 07-14C 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: RECEIVED Total Depth: measured 13058 feet Plugs measured 12590 feet true vertical 8985 feet Junk measured 12700 feet SEP 1 3 2017 Effective Depth: measured 12590 feet Packer measured 10462 feet true vertical 9002 feet Packer true vertical 8246 feet , ,O () Casing: Length:, Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 29-109 29-109 1530 520 Surface 2635 13-3/8"72#L-80 28-2663 28-2663 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11750-11850 feet 12230-12400 feet 12690-12968 feet True vertical depth: 9026-9032 feet feet 9003-9002 feet 8991-8986 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 23-10581 23-8351 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): pTreatment descriptions including volumes used and final pressure: SCNOVB �"Z 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 490 36929 551 850 929 Subsequent to operation: Shut-In 0 392 14.Attachments:(required per 20 AAC 25.070.25.071,s 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development ® Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 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 N/A Authorized Name: Vohra,Prachi Contact Name: Vohra,Prachi Authorized Title: Production Engr Contact Email: Prachi.Vohra©bp.com Authorized Signature: C e'c - Date: g/t 2, /i', Contact Phone: +1 9075644677 Form 10-404 Revised 04/2017 (ATL /0 `6 / l7-" tall,7 [R R D S w C( ) 7 ', 7017 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED SEP 1 3 2017 RE: BP Exploration (Alaska), Inc. AOGCC Report of Sundry Well Operations Summary September 12, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug for Well PBU 07-14C, PTD # 209-053. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • 0) Q,o000000 • NO N CO O O C in N in N- ti U . M COQ) P ct COQ) M • Cn 0) OD N m ODCOf- 0D0D O Ch 01 00 V OD T- O CO 0 CO CO Ul 111 N N Nr 000 OUD MD OMD 0 1 1 1 1 1 1 1 H M tt NT CD O CO O N U1 M N N N N M 01 N co 00 CO 0002 E 01 W � COM000 = N N LO 0 4-! U Q Nr ;Cr coOo co co in co N N N N M N N _ C W 0 aCD0 CO OCO00 °0U C1 JO � °pco 4t � N N (Ni CCoo RI1O d a0 N - U NM -O`o � f� T- C3) O 4 4 a.$OM � NN- C CO CO CN N- L° O J N N NCO CD W a)O — — C0 0 O W W W N U U 00 u_ ce cc receZ ZWWWW U cn Z Z J J H ` • • II Packers and SSV's Attachment PBU 07-14C SW Name Type MD ND Depscription 07-14C PACKER 4006.61 3933.82 7" Baker ZXP Packer 07-14C TBG PACKER 10461.77 8245.65 4-1/2" Baker S-3 Perm Packer 07-14C PACKER 10583.72 8353.64 5" Baker ZXP Top Packer 0 • m ! us a)" b 0 - Ota) as 2 •• ° t - m o.f k a v._ o » » $ , 02 = j _1 V • 5 @ E 0 < ■ 5 v 2 0 k ° ■ of b / a / fib / ' i 2 2 iiio m• V o o � 1 II mL ° ~CL R � 0 O g Uea Co � ° 6 � 0 � � t § » CO u) % K \ 2 2 E @ as a &meq � Eo 0 E • ƒ 2 2 4 2 § § Lo c E \ l 2 . . mo22 � 2 \ Ci) n. � DUk / � = � � k � 5 & P lo . 0 2 22 ƒ 22 ° 7 m E o = g g =CO § = 6 / / CO � a � � ■ / � � 2 NI- 't a 2 - - - 2 k / qas @ ° �! i LL o a a ■ ■ m re @ 2 G -a 7= .a m s:2 t k R k E , § ' 1 _1 a) 2 t4 qa £ @a) ? $ 13 [ 2 ....0 f q Z ■ CU 2f \ 2 �� 0_ E ® - : w ® O e o Olio = w 2 a a u- - k o / � / k / � cid W � c ULii -J k 1.-: _1- c _ o � . co / 00 \ - � ) Q COLT_ _O * DO Dk / § § 2bt � 2 O o : ƒ kO 2 | O $ 7 O . & < ¥ * 0�_ d \ 2 co CO ce) CVU ,.- co < , • , ----110 TREE= CIW ! SAFETY NOTES: WELL ANGLE>70°@ 11 42 3'. WELLHEAD= GRAY 07-14C ***4-1/2"CHROME TBG***OR1G WELL,07-1 4A& ACTUATOR= BAKER CI 07-14B NOT SHOWN BELOW WHIPSTOCK*** KB.ELEV= 64 I i BF ELEV= KOP= 5001' i 2223' H4-1/2" -IF..S X NE3,ID=3.813' Max Angle= 99'@ 12002' Datum MD= 7 Datum TVD= 7 =N. — 2323'&2452'H9-5/8"FO COLLARS ...m - k GAS LFT MANDRELS 13-3/8"CSG,724,L80,D= 12.347' H 2665' 1-4 i ST MD TVD DEV TY PE V L V I LATCH FORT DATE 1 E I 2 3803 3756 27 1 T MING 000.4E1 RK 1 16 108/11/09; i 1 i 690515907 65 KBG2 SO BK ! 20 108/11/091 Minimum ID = 3.725" @ 10569" 14-1/2" HES XN NIPPLE 1 i , 3995' I—9-5/8"X 7"ZXP LTP w/TIEBACK SLV,13=6.290" 11 g..4 •• ,f4, 4018' 1-119-5)8'X 7'BKR FLEXLOCK LM HGR,ID=6 320' 1 44 14 *, 4' 4 .4 *A, ; 9-5/8'VVI-IFSTCCK(07/17/09) I-H 5001' • ft y MLLOUT WNDOW(07-14C)5001'-5018' j 9-5/8'CSG,47#,L-80/S-95,ID=8.681* —I 10524' HA 10431' 1.—4-1/2"HES X NP,ID-=3.813' i` 10462' —7'X 4-1/7'S-3 PKR,0=3.870' i -404 44 ii-1 - = - 11 10496' , 4-1/2 HES X NP,ID 3.813 , 11 , 10569' JH4-1/2"1E....,XN NIP,ID=3.725" i 1 10573' 1—%7"X 5'ZXP HR13 ZXP LIP w/TIEBACK lh SLV,ID=4 460' 10582' H4-1/2"VVLEG,ID=3.958" , 6 ' 4-1/2"TBG, 12.6#,13-CR VAM TOP,.0152 bpf,ID=3.958" 1058T low 10590' —7'X 5"BKR FLE<LOCK LNR/13R, 13=4.450' ' I ..„ 4Il,,... ID=4.450" 17"LNR,26#,L-80 BTC-M,.0383 bpi,ID=6.276" — 1070T 1 10599' H5'X 4-1/2'XO,ID=3.930" r------ FE:RFORATION SUMMARY REF LOG SLB MWD on 08/01/09 ANGLE AT TOP FERE 83°@ 11750' li Note Refer to Production GB for historical perf data I ; SIZE I SPF INTERVAL Opn/Sqz SI-POT I SOZ 12-7/8* 6 11750-11850 0 08/03/09 1 111 12590' I-4-1/2"BKRCISP(08/14/17) I 12-7/8" 6 I „To.— 12700' HRSI-t 4-1/2"KB PKR w/ORIFEE 1 8" 6 12690- 12968 C 08/03/09 ' * I1 1 j PBTD —I 12969' i i,14 444/A 4-1/2'LNR, 12.6#,L-80 IT-M,.0152 bpf,ID=3.958" --I 13056' ,i,•' DATE REV BY 1 COMMENTS 1 DATE I RB/BY COMWITS PRUDHOE BAY 1141 06/03/79 OPIGINAL COMPLETION f 08/15/171MSS/JMD PULLED PKR&PUSHED FISH DH WELL: 07-14C I 1 08/01/98 ISIDETRACK(07-14A) I 08/15/17 MSS/JAC SET CEP(08/14/17) FERMI No 2090530 11/22/03 CJS/TL SIDETRACK(07-148)(10/20/03) AR No: 50-029-20339-03-00 08/05/09 IV7ESi!SIDETRACK(07-14C) . , SEC 33, T11N,R14E,511'Ft,L&314'FEL +----- I 1 08/09/09 TLH .CFILG HO CORRECTIONS I 05/26/10-GS/JIAD;DIRLG DRAFT CORRECTIONS I 1 i I BP Exploration(Alaska) — 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. ~C ~ ~ - ~ ~~ Well History File Identifier Organizing (done) RES N Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: ^ Two-sided III IIIIIIIIIII IIII DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: ae.~~~~d,a iiiimiuiuuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Date: ^ Other:: /s/ ~. Project Proofing II I I I II II I I I I (I (I I BY: Maria Date: /s/ Scanning Preparation ~ x 30 = Vd + ~ =TOTAL PAGES~_ (Count does not include cover sheet) t/t/I ~~ BY: Maria ~ ~ Date: ~~ /s/ r r Production Scanning """"""" " "' Stage 1 Page Count from Scanned File: ~ (Count does include cover heet) Page Count Matches Number in Scanning Pre~~piia~ration: YES NO BY: Maria Date: ~ ~.. ~ V /s/ Stage ? 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 I) II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III II IIII III IIII III 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 8/27/2010 Permit to Drill 2090530 Well Name/No. PRUDHOE BAY UNIT 07-14C Operator BP EXPLORATION (ALASKIy INC API No. 50-029-20339-03-00 MD 13058. TVD 8985 Completion Date 8/5/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR /RES, GR /RES / NEU / AZI DENS Well Log Information: Log/ Electr Data Digital Dataset (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / ly -meairrmc ~~un~uCi dame va.cuc ~.~~..~a ~w ~aai~ .~wM .. ED C Lis 18465 Induction/Resistivity 4731 13038 Open 9/1/2009 LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RPD, DRHO, NPHI, TRPM Plus Graphics Log Induction/Resistivity 25 Blu 4749 13058 Open 9/1/2009 MD Vision Service 1-Aug- 2009 g Induction/Resistivity 25 Blu 4749 13058 Open 9/1/2009 TVD Vision Service 1-Aug- 2009 'Nell Cores/Samples Information: Name ADDITIONAL INFOR~ON Well Cored? Y N Chips Received? 'PTR~ Analysis ~- Received? Daily History Received? Y'1/ N Formation Tops X%" Sample Interval Set Start Stop Sent Received Number Comments • • Comments: DATA SUBMITTAL COMPLIANCE REPORT 8/27/2010 Permit to Drill 2090530 Well Name/No. PRUDHOE BAY UNIT 07-14C Operator BP EXPLORATION ~ALASKIy INC MD 13058 ND 8985 Completion Date 8/5/2009 Completion Status 1-OIL Current Status 1-OIL Compliance Reviewed By: Date: API No. 50-029-20339-03-00 UIC N _~ ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 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 ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 8/5/2009 / 12. Permit to Drill Number 209-053 -~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/18/2009 / 13. API Number 50-029-20339-03-00 ~ 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 7/31/2009 ~ 14. Well Name and Number: PBU 07-14C .% FNL, 314 FEL, SEC. 33, T11 N, R14E, UM 511 Top of Productive Horizon: 110' FNL, 2719' FEL, SEC. 33, T11 N, R14E, UM 8. KB (ft above MSL): 5 ~ lD Ground (ft MSL): ~~9 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1919' FNL, 2289' FEL, SEC. 33, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 12969' 8986' Oil Pool , 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 675869 y- 5950406 Zone- ASP4 10. Total Depth (MD+TVD) 13058' 8985' 16. Property Designation: ADL 028309 / TPI: x- 673455 y- 5950752 Zone- ASP4 th: x- 673~'°~- 5948953 Zone- ASP4 Total De 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: p 18. Directional Survey s ^ No Submit ele tr ni n rin inf rmati n er 20 AA 25.5 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 AA~ 25.071): ~/ GR /RES, GR /RES / NEU / AZI DENS ~.~ :ys~i;+~sv '7 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTHTVD :,...HOLE AMOUNT WT. PERFT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING'RECORD PULLED 20" 94# H-4 Surf ce 71' S rface 71' 30" 24 sx Arctic - / " 72 rf 2 2 17-1/ " x Ar i II - /8" 47# ~-ao i soo-ss Surfa 1' S rf ce 4688' 12-1 /4" 1 sx lass ' ' 7" 26# L-8 995' 10707' 3 24' 8465' 8-1/2" 297 x Lit Crete 169 sx Cla s'G' 23. Open to production or inject ion? ®Yes ^ No 24. TuI;wG Rl=_coRD If Yes, list each i (MD+TVD of To & Bottom Pe nterval open rforation Size and Number): SIZE DEPTH .SET MD PACKER .SET MD ; p 2-7/8" Gun Diameter 6 spf 4-1/2", 12.6#, 13Cr 10582' 10462' , MD TVD MD TVD 11750' - 11850' 9028' - 9032' 12400' 9003' 9002' 12230' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. - - 12690' - 12968' 8991' - 8986' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected w/152 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: 8/30/2009 HOUrS Tested: $ PRODUCTION FOR TEST PERIOD OIL-BBL: 618 GAS-MCF: 4,945 WATER-BBL: 487 CHOKE SIZE: 83 GAS-OIL RATIO: 8,000 Flow Tubing Press. 141 CaSing Press: 1,300 CALCULATED 24-HouRRArE~ OIL-BBL: 1,854 GAS-MCF: 14,835 WATER-BBL: .1,461 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. W~7C~"IFL~TIQCt: None VER FIEQ ~1 -, R Form 10-407 Revised 02/2007 CoNnNUeD ON REVERS ` ~'~ ~ ~~~~ ~~~~~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD 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. West Sak 6636' 5790' None Colville Mudstone 7381' 6127' Top HRZ 9764' 7643' Miluveach 9975' 7827' Kingak 10083' 7919' Sag River 10708' 8466' Shublik 10743' 8498' Ivishak /Zone 4 10814' 8561' Ivishak /Zone 3 11033' 8731' Ivishak /Zone 2 11134' 8806' Formation at Total Depth (Name): Ivishak /Zone 2 11134' 8806' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg g is true and correct to the best of my knowledge. ~ Q~_ r, /9~ l~ ~ - ~ / ' ` ~ ` v~ Signed Terrie Hubble Title Drilling Technologist Date PBU 07-14C 209-053 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A royal NO. Drilling Engineer: Garret Staudinger, .564-4242 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). 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. ITEM 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 BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: 07-14 Common Name: 07-14 Test Date Test Type 7/18/2009 LOT 7/26/2009 FIT Test Depth (TMD) Test Depth (TVD) AMW 5,023.0 (ft) 4,706.0 (ft) 9.00 (ppg) 10,730.0 (ft) 8,464.0 (ft) 8.50 (ppg) Surface Pressure Leak Off Pressure (BHP) EMW 1,170 (psi) _ 3,370 (psi) ~ 13.79 (ppg) 1,100 (psi) 4,837 (psi) 11.00 (ppg) Printed: 8/17/2009 10:17:53 AM ~~ BP EXPLORATION Operations Summary Report Legal Well Name: 07-14 Common Well Name: 07-14 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 7ES Date From - To Hours ' Task Code NPT Page 1 of 13 ~ Spud Date: 5/17/1979 Start: 7/15/2009 End: 8/5/2009 Rig Release: 8/5/2009 Rig Number: i Phase Description of Operations _....- - 7/15/2009 00:00 - 03:30 3.50 RIGU P PRE MIRU Nabors 7ES. Rig accepted at 00:00 on July 15, 2009. Rig up derrick equipment: Make up Hydraulic loop to TopDrive, connect kelly hose, unpin and hang bridle lines, and pin blocks to TopDrive. 03:30 - 07:00 3.50 RIGU P PRE RU and pressure test OA with diesel to 2000 psi for 10 minutes - good test. 1st 5 min -lost 80 psi, 2nd 5 min -lost 20 psi. Bleed off OA. RU and pressure test IA to 1000 psi -failed. Lost 300 psi in 6 minutes. Bleed off IA. Clean derrick, install floor mats, pick up handling equipment. (Off critical path) 07:00 - 08:30 1.50 RIGU P PRE RU DSM lubricator, pressure test lubricator to 1000 psi -good test. Pull BPV. RD DSM. 08:30 - 11:00 2.50 RIGU P PRE Reverse circulate 51 bbls diesel freeze protect out of tubing ' with seawater at 250 gpm with 560 psi. Line up on tubing and circulate 96 bbls diesel freeze protect out of IA at 250 gpm with I 400 psi. 11:00 - 13:00 2.00 BOPSU P PRE RU DSM lubricator and install BPV. Test below to 1000 psi - ~! good test. Cameron dry rod in test dart and test above to 3500 ~ psi for 10 min -good test. 13:00 - 16:00 3.00 BOPSU P PRE ND tree and adapter flange. 16:00 - 19:30 3.50 BOPSU P PRE NU BOP. 19:30 - 21:00 1.50 BOPSU P PRE Pick up test handling tools. RU test equipment for testing BOPE. 21:00 - 00:00 3.00 BOPSU P PRE Test BOP equipment with 4" and 5 1/2" test joints to 250 psi / 3500 psi. Each test held for 5 minutes. Chuck Sheive of AOGCC waived witness of test. Test witnessed by Toolpusher Lenward Toussant, WSLs Travis Peltier and Carrie Williams. Note: Pre-spud meeting held with Clint Pettit's crew during change out. 7/16/2009 00:00 - 02:00 2.00 BOPSU P PRE Finish testing BOPE with 4" and 5 1/2" test jts. 02:00 - 03:00 1.00 BOPSU P PRE RD BOP test equipment. 03:00 - 04:00 1.00 BOPSU P DECOMP PU DSM Lubricator and test to 500 psi -good test. Use dry rod to pull the test dart from back pressure valve. Test dart fell from T bar while lifting to the rig floor. 04:00 - 05:30 1.50 BOPSU N SFAL DECOMP Wait for Baker Rep to bring magnet out to fish test dart off the BPV. 05:00 - 05:30 0.50 FISH N SFAL DECOMP Make up magnet to jt of 4" DP. RIH and retrieve test dart. 05:30 - 06:00 0.50 BOPSU P DECOMP RU DSM Lubricator and extension. Pull BPV. Rig Down DSM. 06:00 - 06:30 0.50 PULL P DECOMP PU Spear BHA: 2 7/8" Bullnose, Packoff Assembly, and 5 1/2" Shoulder Type Spear with 4.8 Nominal Grapple. Total length = 10'. 06:30 - 07:00 0.50 PULL P DECOMP RIH and spear 13 5/8" x 5 1/2" tbg hgr. Unseat hanger with 265k, PUW 115k. 07:00 - 08:30 1.50 PULL P DECOMP Circulate 50 bbl Safe-Surf-O pill at 305 gpm with 420 psi. 08:30 - 15:30 7.00 PULL P DECOMP LD hanger. Pull and LD 5 1/2" 17# -80 8rd AB Mod plastic coated tubing from 5596'. Recovered 4 Stainless steal bands, 26 metal clamps, 131 jts, 1 20' pup jt, 2 GLMs, 1 SSSV, and 21.87' cut jt. Rig down 5 1/2" handling equipment. Outside of tubing shows no sign of corrosion. Inside of tubing shows moderate pitting. Some of the pin ends are missing Pnntetl: S/t72009 10:7 7:55 Ann ~S 1 ~~ BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: 07-14 Common Well Name: 07-14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 7/15/2009 End: 8/5/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2009 Rig Name: NABOBS 7ES Rig Number: NPT Phase Description of Operations Date From - To Hours Task Code ;, 7/16/2009 08:30 - 15:30 7.00 PULL P DECOMP threads. Cut jt is slightly flaired. While LD tbg lost 5 bbls. 15:30 - 16:00 0.50 PULL P DECOMP Rig down 5 1/2" handling equipment. 16:00 - 17:00 1.00 PULL P DECOMP Test new derrick desend system with 200 Ibs -good test. Total descend time 18 sec. 17:00 - 17:30 0.50 BOPSU P DECOMP RU BOP test equipment. 17:30 - 19:00 1.50 BOPSU N SFAL DECOMP Test Bottom 2 7/8" x 5" variable rams -test failed. 19:00 - 20:00 1.00 BOPSU N SFAL DECOMP Change out bottom set of variables to 4" rams. 20:00 - 21:00 1.00 BOPSU P DECOMP Test 4" rams to 250 psi low and 3500 psi high for 5 min each - good test. 21:00 - 22:00 1.00 BOPSU P DECOMP RD BOP test equipment. Pull test plug. Install wear ring. 22:00 - 00:00 2.00 CLEAN P DECOMP PU Clean out BHA: 8 1/2" Used bit, 8 1/2" Upper string mill, 9 jts 6 1/2" DC, 12 jts 4" HWDP. Total length = 647'. 7/17/2009 00:00 - 00:30 0.50 CLEAN P DECOMP RIH with Clean out BHA from 647' to 740' picking up 4" DP. 00:30 - 02:00 1.50 CLEAN N SFAL DECOMP Troubleshoot problem with pipe skate. Change out bad switch on the upper ramp controls. 02:00 - 05:30 3.50 CLEAN P DECOMP Continue to RIH from 930' to 5536' picking up 4" DP. Rotate at 10 rpms through FO collars at 2323' and 2452' with no problems. 05:30 - 06:30 1.00 CLEAN P DECOMP CBU at 550 gpm with 2080 psi for a total of 323 bbls while reciprocating pipe. Monitor well -static. 06:30 - 08:30 2.00 CLEAN P DECOMP POH from 5536' to 647', stand back 4"DP, 4" HWDP, and 6 1/2" DCs. Monitor well -static. 08:30 - 09:30 1.00 CLEAN P DECOMP LD Clean out BHA. All components in full gauge. Clean and clear rig floor. 09:30 - 11:00 1.50 DHB P DECOMP Rig up Schlumberger E line unit. Pick up Halliburton 9 5/8" EZSV bridge plug. 11:00 - 13:00 2.00 DHB P DECOMP RIH with bridge plug and set at 5023' (top element). 13:00 - 14:00 1.00 DHB P DECOMP POH with E - Llne. Rig down Schlumberger unit. 14:00 - 14:30 0.50 DHB P DECOMP Rig up and test EZSV bridge plug x 9 5/8" csg to 3500 psi for charted 10 min - no bleed off -good test. Rig down test equipment. 14:30 - 17:00 2.50 STWHIP P WEXIT Make up 9 5/8" Whipstock and Milling BHA with Bottom Trip Anchor, Baker Gen II 9 5/8" whipstock slide, 8 1/2" window mill, 8 3/8" lower string mill, 2 - 8 1/2" upper string mills, float sub, 1 jt 5" HWDP, MWD, UBHO, 9 jts 6 1/2" DCs, and 12 jt 4" HWDP. Total lenght 740'. 17:00 - 20:30 3.50 STWHIP P WEXIT RIH with Whipstock and Milling BHA from 740' to 1205' and perform shallow hole test on MWD at 500 gpm with 895 psi - good test. Continue to RIH from 1205' to 5001'. 20:30 - 21:00 0.50 STWHIP P WEXIT Orient Whipstock 112 degrees left of high side. Tag top of EZSV at 5023' and SO 15k to set bottom trip anchor. PU to confirm set. Shear mills from slide with 50k down weight. 21:00 - 22:00 1.00 STWHIP P WEXIT Displace the well by pumping 100 bbls water, 50 bbls spacer pill with Flowzan, and chase with 9.0 ppg LSND milling fluid at 400 m with 830 si. 22:00 - 00:00 2.00 STWHIP P WEXIT Mill 8 1/2" window in 9 5/8" casing with following parameters: WOB 2-5k, 400 gpm with 870 psi, 4k ft-Ibs torque on bottom at !, ~ ~~ 75 rpm. PUW 125k, SOW 115k, and ROT 120k. Top of window at 5001'. 7/18/2009 00:00 - 02:30 2.50 STWHIP P WEXIT Continue to Mill 8 1/2" window in 9 5/8" casing with following parameters: WOB 2-5 k, 400 gpm with 870 psi, 7k ft-Ibs tq on, 4k ft-bls tq off, on bottom at 70 rpm. PUW 125k, SOW 115k, rnnieo: ai i nzvaa i v. i i as rave BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: 07-14 Common Well Name: 07-14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 7/15/2009 End: 8/5/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2009 Rig Name: NABOBS 7ES Rig Number: i Date From - To ' Hours Task ~ Code NPT Phase Description of Operations 7/18/2009 00:00 - 02:30 2.50 STWHIP P WEXIT and ROT 120k. Drill new hole to 5058'. Work mills through window with and without rotation, no problems. Total metal recovered approximately 360 lbs. 02:30 - 03:30 1.00 STWHIP P WEXIT Circulate 1 1/2 Bottoms Up at 400 gpm with 830 psi. 03:30 - 04:30 1.00 STWHIP P WEXIT Pull back into 9 5/8" csg window at 4955' to perform LOT. Rig up test equipment. Achieve LOT of 13.7 ooa EMW with 9.0 mu i .Rig down test equipment. 04:30 - 06:30 2.00 STWHIP P WEXIT Monitor well -static. POH from 4955' to 717' standing back 4" HWDP and 4" DP in derrick. 06:30 - 08:30 2.00 STWHIP P WEXIT LD Whipstock BHA. Two upper string mills in full gauge. 08:30 - 09:00 0.50 STWHIP P WEXIT Clean and clear rig floor. 09:00 - 09:30 0.50 STWHIP P WEXIT Service the Top Drive. 09:30 - 12:00 2.50 STWHIP P WEXIT Make u 8 1/2" Drillin BHA: RSX616M bit, Xceed BSS, ARC6, MWD, 3 jts 7 1/4" NM DCs to 715'. 12:00 - 14:00 2.00 STWHIP P WEXIT RIH with 8 1/2" BHA from 715' to 2115' picking up 4" DP from pipe shed. 14:00 - 14:30 0.50 STWHIP P WEXIT POH from 2115' to 715' standing back 4" DP. 14:30 - 17:30 3.00 STWHIP P WEXIT RIH with 8 1/2" Drilling BHA from 715' to 4638' picking up 4" DP from pipe shed. Continue to RIH from 4638' to 4780' with 4" DP from derrick. Ghost reamer at 3938'. 17:30 - 19:00 1.50 STWHIP P WEXIT Mad Pass from 4780' to 5058' without pumping. 19:00 - 00:00 5.00 DRILL P INT1 Control drill from 5058' to 5068' at 10'/hr. From 5068' to 5098' at 30'/hr. From 5098' to 5115' at 50/hr at 550 gpm with 1620 psi, PUW 125k, SOW 105k, ROT wt 112k, 5k ft-Ibs tq on, 4k ft-Ibs off, 80 rpm. ADT 2.93 hrs. 7/19/2009 00:00 - 08:00 00 8 DRILL P INTi Attem t to sidetrack with rotora st era I b n I . from 5115' to 5145' at 50' / hr with 550 gpm with 1620 psi, PUW 125k, SOW 105k, ROT wt 112k, WOB 1- 5k, 5k ft-Ibs tq on, 4k ft-Ibs off, 80 rpm. Slow down to 10' / hr for 50' with tool face on low side. Continue to control drill 25' / hr from 5145' to 5265', then increase WOB to 5 - 10k. 08:00 - 10:30 2.50 DRILL P INTi At 5346' monitor well -flowing. After 6 bbl pit gain, shut in and monitor ressure: SIDPP 80 si SICP 60 si. Make notifications to BP Field Superintendant Alan Madsen, AOGCC, FS3 and DS 7 Operators, BP Safety rep Allen Graff. 10:30 - 12:00 1.50 DRILL P INTi Circulate kick out usin the wei ht and wait method. Weight up mud system from 9.0 ppg to 9.4 ppg. Circulate following the DP reduction schedule with initial circulating pressure of 350 psi and final circulating pressure of 280 psi. 12:00 - 13:00 1.00 DRILL P INT1 Open choke and annular preventer and monitor well -static. Turn pumps on to 550 gpm and return flow increased an additional 7% beyond expected. Shut down and monitor well - slight flow. 13:00 - 13:30 0.50 DRILL P INT1 CBU at 550 gpm with 1862 psi, while monitoring for gas and flow increase -observed neither. Monitor well -slight flow. 13:30 - 00:00 10.50 DRILL P INTi Continue to drill ahead in 8 1/2" hole from 5346' to 6045' WOB 10-15k, 550 gpm, 2095 psi on, 2025 psi off, 6.5k fUlbs torque on, 4.5k ft/Ibs torque off, PUW 140k, SOW 112k, ROT Wt 120k, 140 rpm. Weight up mud system while drilling ahead from 9.4 to 9.6 .Monitor we I w ile n ing a ea an at connections -static. Pump Nut Plug sweeps as needed for bit balling. 7/20/2009 00:00 - 08:00 8.00 DRILL P INT1 Drill ahead in 8 1/2" hole from 6045' to 6480'. Pump Nut Plug BP EXPLORATION Page 4 of 13 Operations Summary Report Legal Well Name: 07-14 Common Well Name: 07-14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 7/15/2009 End: 8/5/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2009 Rig Name: NABOBS 7ES Rig Number: i Date From - To Hours Task Code NPT Phase Description of Operations - 7/20/2009 00:00 - 08:00 8.00 DRILL P INT1 sweeps as needed for bit balling. WOB 10-15k, 550 gpm, 2095 psi on, 2025 psi off, 6.5k fUlbs torque on, 4.5k fUlbs torque off, PUW 140k, SOW 112k, ROT Wt 120k, 140 rpm. MW in and out 9.6 ppg. Cal ECD 10.07 ppg, Act ECD 10.22 PPg• ADT 6.15 hr. 08:00 - 11:00 11:00 - 12:00 12:00 - 12:30 12:30 - 15:00 3.00 1.00 0.50 2.50 DRILL DRILL DRILL DRILL P P P P INT1 INTi INT1 INT1 Stick slip problems limiting BOP. from 6480' to 5000', PUW 145k, SOW 120k. Monitor well at window -static. Pump dry job and contine to POH to 208'. LD RSS BHA. Bit grade 2-4-BT-A-X-I-WT-PR. Rig up BOP test equipment. Test BOP equipment that was used in well control situation. Use 4" test joint to test annular preventer to 250 psi low and 2500 psi high. Test HCR choke, and valves 2,3,4,7,10,12,14, & 15 on choke manifold to 250 psi low and 3500 psi high. Rig down test equipment. Test witnessed by WSL Mike Dinger, Tool pusher Larry Wurderman. 15:00 - 15:30 0.50 DRILL P INT1 Rig down test equipment. 15:30 - 17:00 1.50 DRILL P INTi Make u 8 1/2" Drillin BHA : DTX619M bit, XP Motor 1.5 deg, ~ DC, Float. Total BHA = 717'. ARC6, MWD, 3 jts 7 1/2" NM Shallow test MWD at 460 gpm with 760 psi -good test. 17:00 - 19:00 2.00 DRILL P INTi RIH from 717' to 4925'. Ghost Reamer at 3938'. 19:00 - 19:30 0.50 DRILL P INTi Cut and slip drill line. 19:30 - 20:00 0.50 DRILL P INTi Service Top Drive and Crown. 20:00 - 21:00 1.00 DRILL P INTi Continue to RIH from 4925' to 6445'. Wash to bottom at 6480' with no fill, no problems, and no problems going through window. Establish ECD baseline 10.34 ppg. 21:00 - 00:00 3.00 DRILL P INT1 Drill ahead in 8 1/2" hole from 6480' to 6665'. 7/21/2009 100:00 - 12:00 I 12.001 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P WOB 6-10k, 550 gpm with 2500 psi, 2500 psi on, 2250 psi off, 7.5 k fUlb on, 6 k fUlb off, PUW 135k, SOW 108k, ROT Wt 120k, 80 rpm. MW in and out 9.6 ppg. Cal ECD 10.33 ppg, Act ECD 10.28 PPg• AST 1.82 hrs, ART .10, ADT 1.92. INT1 Drill ahead in 8 1/2" hole from 6665' to 7287'. WOB 15k, 565 gpm with 2510 psi on, 2350 psi off, 7 k fUlb on, 5 k fUlb off, PUW 140k, SOW 110k, ROT Wt 125k, 60 rpm. MW in and out 9.6 ppg. Cal ECD 10.12 ppg, Act ECD 10.16 PPg• AST 8.25 hrs, ART .53 hr, ADT 8.78 hrs. INTi Drill ahead in 8 1/2" hole from 7287' to 8587'. WOB 10-15k, 565 gpm with 3455 psi on, 3125 psi off, 9 k fUlb on, 6.5 k fUlb off, PUW 165k, SOW 115k, ROT Wt 125k, 100 rpm. MW in and out 9.7 ppg. Cal ECD 10.13 ppg, Act ECD 10.83 PPg• AST 6.47 hrs, ART .2.73 hr, ADT 9.2 hrs. Pnntetl: 8/17/2009 10:17:59 AM BP EXPLORATION Page 5 of 13 Operations Summary Report Legal Well Name: 07-14 Common Well Name: 07-14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 7/15/2009 End: 8/5/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To ', Hours Task j Code NPT Phase Description of Operations 7/22/2009 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ P 12:00 - 00:00 12.001 DRILL ~ P 17/23/2009 100:00 - 07:00 7.00 I DRILL ~ P 07:00 - 08:00 I 1.001 DRILL I P 08:00 - 11:00 I 3.00 DRILL P 11:00 - 11:30 0.50 DRILL P 11:30 - 13:30 2.00 DRILL P 13:30 - 17:30 I 4.001 DRILL I P 17:30 - 23:00 I 5.501 DRILL I P INT1 Drill ahead in 8 1/2" hole from 8587" to 9450'. While drilling from 8958' to 9143', ghost reamer hanging upon •-~ outside of 9 5/8" csg. Ghost reamer at bottom of window at 5018' to 5203' torque spikes 7 k -12 k. WOB 15k, 565 gpm with 3830 psi on, 3620 psi off, 10 k ft/Ib on, 7 k fUlb off, PUW 195k, SOW 125k, ROT Wt 135k, 100 rpm. MW in and out 10.2 ppg. Cal ECD 10.22 ppg, Act ECD 10.66 PPg• AST 6.03 hrs, ART 2.65 hr, ADT 8.68 hrs. Raise mud wt from 9.6 ppg to 10.2 ppg at 10:00 before entering THRZ. INTi Drill ahead in 8 1/2" hole from 9450' to 10294'. WOB 5-10k, 550 gpm with 4020 psi on, 3760 psi off, 14 k ft/Ib on, 12 k ft/Ib off, PUW 220k, SOW 120k, ROT Wt 150k, 100 rpm. MW in and out 10.2 ppg. Cal ECD 10.69 ppg, Act ECD 11.24 PPg• AST 5.78 hrs, ART 3.40 hr, ADT 9.18 hrs. INTi Drill ahead in 8 1/2" hole from 10294' to TD at 10709' at top of PU - 235k, SO - 125k, ROT - 150k. WOB - 10k to 15k. RPM - 100, TO - 13k off / 14k on. Pump at 525 gpm at 3810 psi off / 4010 psi on. MW - 10.2 ppg in & out. Calculated ECD 10.69 ppg, Actual ECD 11.20 ppg. INT1 Circulate bottoms up 2x. While circulating, recover Sag River samples for geological confirmation and weight up mud to 10.4 Circulate at 530 gpm at 3968 psi, 100 RPM. INT1 Short trip from 10709' to 10198', overpull 35k. Back ream from 10198' to 9722'. PU - 230k, SO - 125k, ROT - 150k. Pump at 520 gpm, 3800 psi. Calculated ECD - 10.88 ppg. ECD spikes up to 12.13 ppg. INT1 RIH from 9722' to 10709'. No tight spots encountered. INTi Circulate until ECD's are 0.3 ppg over calculated. Circulate at 510 gpm, 3850 psi, 100 RPM. Calculated ECD - 10.88 ppg, Actual ECD - 11.18 ppg. INTi POH from 10709' to 7825'. Swabbing and 45k overpulls encountered from 9684' to 8933'. 40k overpulls encountered at 8435', 8255'. Swabbing and 50k overpulls from 8220' to 7825' INT1 Pump out of hole from 7825' to 7755' at 240 gpm, 1140 psi. Printetl: N/1 //LUUy lU:l /:~y AM BP EXPLORATION Page 6 of 13 Operations Summary Report Legal Well Name: 07-14 Common Well Name: 07-14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 7/15/2009 End: 8/5/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2009 Rig Name: NABOBS 7ES Rig Number: ~ ! Code NPT Phase Description of Operations Date From - To Hours Task ', 7/23/2009 17:30 - 23:00 5.50 DRILL P INTi Backream out of hole from 7755' to 6823'. Pump at 500 gpm, 3250 psi, 60 RPM. Pump out of hole from 6823' to 5977' at 500 gpm, 2675 psi. Cuttings blinding off screens from 7755' to 7450', clearing up for the remainder of backreaming operations. Actual ECD - 11.82 ppg with occasional spikes to 12.5 ppg at the start of backreaming. ECD's dropped to 11.17 ppg by the end of backreaming. Calculated ECD - 10.89 ppg. 23:00 - 23:30 0.50 DRILL P INT1 POH from 5977' to 5000'. 23:30 - 00:00 0.50 DRILL P INT1 Circulate bottoms up - no increase in cuttings. Circulate at 550 gpm, 2636 psi, 100 RPM. Calculated ECD - 10.89 ppg, Actual ECD - 11.07 ppg. 7/24/2009 00:00 - 00:30 0.50 DRILL P INT1 Monitor well -static. Pump dry job. Drop 2 1/4" rabbit. 00:30 - 02:00 1.50 DRILL P INT1 POH from 5000' to 717'. 02:00 - 04:00 2.00 DRILL P LNR1 LD 8-1/2" drillin BHA (BHA #5) from 717'. All components in gauge. Bit grade: 1-1-CT-G-X-I-No-TD. Clean and clear rig floor. 04:00 - 05:30 1.50 BOPSU P LNR1 Chan a out u er BOP rams to 7" from 3-1/2" x 6" VBR. 05:30 - 06:30 1.00 BOPSU P LNR1 RU and test upper BOP rams with 7" test joint to 250 psi low / 3500 psi high -good test. RD test equipment. 06:30 - 07:30 1.00 CASE P LNR1 Rig up 7" casing handling equipment. 07:30 - 15:00 7.50 CASE P LNR1 RIH with 7" 26# L-80 BTC-M shoe track. Fill pipe, test floats - good test. Continue to RIH with 7" csg to 5000'. MU liner to average 8500 fUlbs torque. 15:00 - 17:00 2.00 CASE P LNR1 Stage pumps to 5 bpm and circulate 1 1/2X liner volume. 3 bpm 356 psi 4 bpm 419 psi 5 bpm 580 psi PUW 133k, SOW 120k 17:00 - 19:00 2.00 CASE P LNR1 Continue to RIH with 7" liner from 5000' to 6679'. 19:00 - 20:30 1.50 CASE P LNR1 Make up 7 x 9 5/8" Flex-Lock Hanger and ZXP liner top packer (19.84' long with 10.97' PBR), PUW 175k, SOW 125k. 20:30 - 22:00 1.50 CASE P LNR1 Stage pumps up to 5 bpm and circulate 11/2X liner volume. 3 bpm 500 psi 4 bpm 550 psi 5 bpm 530 psi PUW 175k, SOW 133k 22:00 - 00:00 2.00 CASE P LNR1 Continue to RIH with 7" liner on 4" DP from 6679' to 9255'. 7/25/2009 00:00 - 00:30 0.50 CASE P LNRi Continue to RIH with 7" liner on 4" DP from 9255' to THRZ at 9732', PUW 225k, SOW 105k. 00:30 - 04:00 3.50 CASE P LNR1 Fill pipe and attempt to stage pumps up to 5 bpm to CBU. While sta in um s u ackin off at 2 b m. Lost 40 bbls to formation. Pull out 1 stand. Attempt to pull out of slips, 65k over ull to et free. Work pipe and establish circulation at 3 b m with 880 si 4 b~ m with 920 si. xcessive amoun o fine sand across shakers at bottoms u , 4000 units of as, mud wt cut to 9.8 Continue to circulate until shakers clean up. 04:00 - 07:00 3.00 CASE P LNR1 Continue to RIH from 9732' to 10670'. From 10670' to 10709' work through tight hole and pack off. Establish circuation of Printed: 8/17/2009 10:17:59 AM ~ ~ BP EXPLORATION Page 7 of 13 Operations Summary Report Legal Well Name: 07-14 Common Well Name: 07-14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 7/15/2009 End: 8/5/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/5/2009 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 7/25/2009 04:00 - 07:00 3.00 CASE P LNR1 3.5 bpm with 875 psi. 07:00 - 08:00 1.00 CEMT P LNR1 MU cement head and RIH. 08:00 - 10:00 2.00 CEMT P LNR1 Stage pumps up to 5 bpm and circulate to condition mud for cement job at 5 bpm with 890 psi. PJSM on cement job while circulating. 10:00 - 13:00 3.00 CEMT P LNR1 -Pump 10 bbls 11.0 ppg MudPush, pressure test lines to 4500 psi. -Pump remaining 40 bbls of 11.0 ppg Mudpush -Pump 176 bbls 11.0 ppg LiteCrete Lead cement (295 sks, 3.33 tuft / sk yield) -Pump 35.1 bbls 15.8 ppg Class G Tail cement (158 sks, 1.16 cut s yield -Drop dart, chase with 10 bbls water and displace with 279 bbls of 10.4 ppg LSND with rig pumps per CADE pumping schedule. -Plug bumped with 2600 psi. Set liner hanger. Test float„- holdin . -CIP at 12:50. Lost 45 bbls while pumping cement. 13:00 - 14:00 1.00 CEMT P LNR1 Set ZXP liner top packer and release runnin tool with chlumberger pumps at 4400 psi. Pick up and confirm release from liner hanger. Circulate at 400 gpm with 870 psi, PUW 85k, SOW 82k. Cement back at surface 18 bbls. 14:00 - 17:30 3.50 CEMT P LNRi LD cement head. Monitor well -Static. POH from 3950' to 43' stand back 4" DP. LD liner hanger /packer running tool. 17:30 - 18:00 0.50 WHSUR P LNRi Rig up to test 9 5/8" csg x 7" liner. Pump 3 bbls to pressure up to 1500 si for charted 10{min - ood test. Lost 0 psi in 10 min. Rig down test equipment. 18:00 - 00:00 6.00 WHSUR P LNR1 Nipple down BOP and stand back on pedestal. Nipple down tbg spool. Change out 13 3/8" x 9 5/8" packoff, with no problems. Nipple up Gray New Standard tbg spool. 7/26/2009 00:00 - 00:30 0.50 WHSUR P LNR1 Test 13 3/8" x 9 5/8" Pack off and Gray new standard tbg spool to 5000 psi for 30 min -good test. 00:30 - 04:00 3.50 BOPSU P LNR1 Nipple up BOP. Change top rams to 3 1/2" x 6" variables, and bottom rams to 2 7/8" x 5" variables. 04:00 - 04:30 0.50 BOPSU P LNR1 Rig up BOP test equipment. 04:30 - 08:00 3.50 BOPSU P LNR1 Test BOP a ui ment with 2 7/8" and 4 1/2" test joints to 250 psi low, 3500 psi high, 2500 psi high for annular preventer. All tests pass. Witness of test waived by AOGCC rep Lou Grimaldi. Test witnessed by BP WSL Duncan Ferguson and NAD Toolpusher Chris Weaver. 08:00 - 08:30 0.50 BOPSU P LNR1 Rig down BOP test equipment. 08:30 - 09:00 0.50 BOPSU P LNR1 Rig up to test 9 5/8" and 7" liner. 09:00 - 10:00 1.00 CASE P LNRi Test 9 5/8" csg and 7" liner to 3500 psi for charted 30 min - 1st 15 minutes -lost 20 psi, 2nd 15 minutes -lost 10 psi. 10:00 - 12:00 2.00 DRILL P PROD1 PU 6 1/8" Drilling BHA: XR20D bit, 1.5 degree mtr, MWD, ADN with radio active source, pump out sub. Total length = 279'. 12:00 - 18:30 6.50 DRILL P PRODi RIH with BHA picking up DP from 279' to 2566'. Continue to RIH with stands from 2566' to 10450'. Shallow test Printed: 8/17/2009 10:17:59 AM BP EXPLORATION Page 8 of 13 Operations Summary Report Legal Well Name: 07-14 Common Well Name: 07-14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 7/15/2009 End: 8/5/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/5/2009 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code, NPT I Phase Description of Operations 7/26/2009 12:00 - 18:30 6.50 DRILL P PROD1 MWD at 1042'. 18:30 - 20:30 2.00 DRILL P PROD1 Wash down from 10450' to 10622' at 196 gpm with 1982 psi. Ta u and drill lu s landin collar and cement,from 10622' to 10697' 206 gpm with 1815 psi, WOB 10k, PUW 280k, SOW 100k, 11 k ft/Ib tq, 35 rpm. Found plugs on depth at 10622'. 20:30 - 23:00 2.50 DRILL P PROD1 Pump 70 bbls of freshwater and 50 bbl Hi Vis Steel Lube spacer. Displace the well to 8.5 ppg FloPro at 250 gpm with 1600 psi, PUW 185k, SOW 135k, ROT wt 150k, 5k fUlb tq, 40 rpm. 23:00 - 23:30 0.50 DRILL P PROD1 Drill out remainin float a ui meat and 23' of new hole from 10697' to 10730' at 247 gpm with 1780 psi on, 1600 psi off, PUW 185k, SOW 135k, ROT wt 150k, 5k ft/Ib tq on and off, 40 rpm. 23:30 - 00:00 0.50 DRILL P PROD1 Pull back into shoe. Perform FIT at 10696' and = 8464 tvd to EMW of 11.0 with 1100 si. Hold test for charted 10 min - good test. Lost 0 psi in 10 minutes. 7/27/2009 00:00 - 12:00 12.00 DRILL P PROD1 Drill in 6 1/8" production hole from 10730' to 11311'. 260 gpm with 1991 psi on, 1875 psi off, PUW 195k, SOW 130k, ROT wt 150k, 7k fUlb tq on and 6k ft/Ib tq off, 80 rpm. AST 5.52, ART 2.78, ADT 8.30 MW in and out 8.5 ppg. 12:00 - 00:00 12.00 DRILL P PROD1 Drill in 6 1/8" production hole from 11311' to 11833'. 250 gpm with 2080 psi on, 1855 psi off, PUW 210k, SOW 127k, ROT wt 155k, 6k Wlb tq on and off, 40 rpm. AST 2.73, ART 5.80, ADT 8.53 MW in and out 8.5 ppg. 7/28/2009 00:00 - 05:30 5.50 DRILL P PROD1 Drill in 6 1/8" production hole from 11833' to 12025'. 250 gpm with 2080 psi on, 1855 psi off, PUW 210k, SOW 127k, ROT wt 155k, 6k fUlb tq on and off, 40 rpm. MW in and out 8.5 ppg. 05:30 - 10:30 5.00 DRILL P PRODi MAD pass from 12025' to 11900' at 300 fph. 10:30 - 15:00 4.50 DRILL P PRODi P OH, racking back stands from 11,900' MD to BHA. 15:00 - 22:00 7.00 DRILL P PRODi La down BHA #6• pumpout sub, flex collars, Impulse and ADN MWD tools, 1.5deg motor and Smith XR20D ODIGVPS. Bit grade 3-8-BT-G-F-4/16-WT-PR. MU new bit Smith XR20DOD1 DV and change mud motor. RIH with BHA #7; new Smith R20 OD1 GVPS bit, 1.5deg mud motor, stabilizer, flex collars, Impulse MWD tool, pumpout sub and jars. 22:00 - 23:00 1.00 DRILL P PROD1 Cut and slip 136' drilling line. Service top drive, blocks and crown. 23:00 - 00:00 1.00 DRILL P PRODi RIH w/ BHA #7 on 4" DP from surface to hole 11,920' MD. 7/29/2009 00:00 - 05:00 5.00 DRILL N DFAL PROD1 Connect top drive to start washing /reaming to bottom. Expecting under gauge hole. Encountered abnormally high pressure while attem tin to um 3900 si ~ 70 m . Pick u work pipe unable to rotate. POH one stand with pumps on and off to determine cause of problem- no problems reciprocating or rotating with 4000 psi and 45 GPM. Worked tight spot at 11,925'. Ream to 12,020' no excessive torque but 4000 psi and 45 GPM. Pump and rotate, pull out 5 stands- flow rate gradually Panted: 8/17/2009 70:17:59 AM BP EXPLORATION Page 9 of 13 Operations Summary Report Legal Well Name: 07-14 Common Well Name: 07-14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 7/15/2009 End: 8/5/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To I Hours Task i Code NPT Phase Description of Operations 7/29/2009 00:00 - 05:00 5.00 DRILL N DFAL PROD1 increasing to 250gpm, pressure 3900psi. Work pipe to further assess the situation. Wash and ream to 12,025'. 250 GPM, 2700 psi, 5K torque. Ta bottom unable to drill with 18K WOB. No Delta pressure. Bit not drilling. Decision made to POOH to inspect BHA. 05:00 - 10:30 5.50 DRILL N DFAL PROD1 Open circ sub and pump dry job; POOH to evaluate BHA problems. 225k up, 125k down, 150k rotating; no overpulls while POOH. 10:30 - 12:30 2.00 DRILL N DFAL PROD1 LD BHA #7' mud motor damaged and partially clogged with rubber stator material. Bit damaged from cone interference. Change out for new mud motor and new bit; pick up BHA #8; pump-out sub, flex collars, Impulse MWD tool, 1.5deg mud motor and 6-1/8" Smith XR20D ODIGVPS tricone bit. 12:30 - 18:00 5.50 DRILL N DFAL PROD1 RIH w/ BHA #8 from surface to -11,835' MD. Turn pumps on periodically to check for normal pressure and any undergauge; none encountered, pump parameters normal. 18:00 - 19:00 1.00 DRILL P PRODi Pump and rotate down last three stands to tag upon bottom hole. Slight tight hole encountered -70ft off bottom (200psi pressure differential), but worked through with no problems. Continue to bottom and tag up ~ 12,025' MD. 19:00 - 00:00 5.00 DRILL P PROD1 -1 r duction hole with BHA #8 from 12,025' MD to 12,275' MD. 210k up, 125k down, 150k rotating. 1850psi on, 1750psi off C~ 252gpm and 20k WOB. Torque = 7k on, 6k off. 1.4hrs sliding, 2.32hrs rotating, 3.72hrs total drilling time. 7/30/2009 00:00 - 10:30 10.50 DRILL P PROD1 PJSM. Drill 6-1/8" production hole from 12,275' to 12,534' MD, 9003' TVD. 215k up, 125k down and 150k rotating. 1815psi off, 1965psi on, with 25k WOB and 260gpm. Torque: 6k off, 8k on. 3.27hrs sliding, 4.10hrs rotating, 7.37hrs total drilling time. Unable to et desired res onse from BHA; discuss with town, decision made to POOH for new BHA. 10:30 - 16:00 5.50 DRILL P PROD1 POOH from 12,534' MD to BHA, racking back stands of 4" DP. 215k up, 125k down. MW in and out = 8.7ppg. 16:00 - 18:30 2.50 DRILL P PROD1 LD BHA #8; no a arent motor dama a tricone bit shows evidence of erosion along outer edge but no damage or wear to inserts. Change motor bend from 1.5deg to 1.83deg. PU BHA #9; 6-1/8" XR20D ODIGVPS tricone bit, 1.83deg mud motor, change out for new Impulse MWD tools, flex collars, pump-out sub and jars. 18:30 - 00:00 5.50 DRILL P PROD1 RIH w/ BHA #9 from surface to 12,534' MD. PU 9 jts of 4" DP in order to reach new projected TD ~ 12,975' MD. Slowed down C«2 4000' MD for 7" liner top; took 2k Ibs before passing through liner top. 7/31/2009 00:00 - 12:00 12.00 DRILL P PROD1 PJSM. Drill ahead from 12,534' MD to 12,632' MD w/ BHA #9; mud motor a~$3r7eg. 220k up, 120k down, 150k rotating. 1950psi on, 1873psi off ~ 257gpm and 20k WOB. Torque: 7k on, 7k off. Experiencing difficulty building angle and making progress through shaley formation. 7.22hrs sliding, 1.38hrs rotating, 9.1 hrs total drilling time for the night tour. Pnntea: wi iizuua iu:i roa r~nn ~ ~ BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: 07-14 Common Well Name: 07-14 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 7ES Date From - To Hours Task Code ~ NPT 7/31/2009 ~ 12:00 - 00:00 12.00 DRILL P 18/1/2009 100:00 - 01:30 1.501 DRILL P 01:30 - 05:30 1 4.00 DRILL P 05:30 - 08:00 I 2.501 DRILL I P 08:00 - 11:30 3.501 DRILL ~ P 11:30 - 13:00 1 1.501 CASE I P 13:00 - 17:00 4.00 CASE P 17:00 - 17:30 0.50 ~ CASE ~ P 17:30 - 23:00 5.501 CASE P 23:00 - 00:00 1.00 I CASE P 18/2/2009 100:00 - 02:00 2.001 CASE ~ P 02:00 - 04:00 2.00 CEMT P 04:00 - 06:00 2.00 CEMT P Spud Date: 5/17/1979 Start: 7/15/2009 End: 8/5/2009 I Rig Release: 8/5/2009 Rig Number: Phase ~~ Description of Operations PROD1 PJSM. Drill 6-1/8" production hole from 12,632' MD to interval TD ~ 13,058' MD, 8985' TVD. 225k up, 123k down, 150k rotating. 1870psi off, 2020psi on C~3 260gpm and 25k WOB. Torque: 8k on, 7.5k off. 1.17hrs sliding, 7.83hrs rotating, 9.Ohrs total drilling time for the day tour. footage is -80' past end of pay to allow for rathole and optimum perforating options. PROD1 PJSM. Circulate x1 BU while reciprocating pipe 90'. Monitor well; MW in and out = 8.7ppg. PROD1 POOH racking back stands of 4" DP from 13,058' MD to 10,705' MD. Stop pulling once inside 7" liner shoe at 10,705' MD and drop dart. Pump dart down at 250gpm while rotating pipe -60rpm. Shift pump-out sub; -1600psi before, 900psi after. Drop 2.25" drift and pump dry job. Continue to POOH to 7885' MD. PROD1 Stop POOH and monitor well; static. Secure well for planned safety stand-down. BOP-certified hand monitoring well at all times while stand-down is taking place. PROD1 Continue to POOH from 7885' MD to surface; rack back all DP. LD 6-1/8" drilling BHA #9; flex collars, pump-out sub, 1.83deg mud motor and tricone bit. Bit grade; 1-1-ER-A-E-I-CT-TD. RUNPRD PJSM w/ Baker and Nabors casing hands. RU to run 4.5" 12.6# L-80 IBT-M production liner from surface to TD ~ 13,058' MD. RU casing tongs, stabbing board. RUNPRD Run 4.5" roduction liner from surface to 2451' MD; total of 58 joints. Torque connections to 32001b-ft as per casing hand; utilize stabbing board for making connections. MU liner hanger and ZXP liner top packer. Pour Pal-Mix and allow to set for 30 minutes before continuing to run liner. PU one stand of DP and RIH; liner wt 54k up, 52k down. RUNPRD Circulate 1.5x liner volume before continuing into the hole on DP. RUNPRD RIH w/ 4.5" production liner and 4" DP from 2451' to 10,697' MD. 175k up, 125k down. Slow down when going into 7" liner top with 4.5" liner shoe, and again when top of production liner reaches 7" liner top. RUNPRD Circulate 1.5x liner and DP volume before continuing into openhole. Stage pumps up to 5bpm, 787psi. No losses while circulating. RUNPRD PJSM. Continue into open hole with 4.5" 12.6# L-80 IBT-M production liner on 4" DP. Tag up at 13,058' MD. RUNPRD Circulate and reci rocate 4.5" liner in re for cement 'ob. RUNPRD PJSM w/ SLB cementers. Cement 4.5", 12.6# L-80 IBT-M production liner as follows: Start batching cement C~ 03:45hrs; done batching cement C~3 04:15hrs. 04:24 Pump 4.6bb1 10.5ppg MudPush, test lines to 4500psi; good. 04:33 Pump 16.2bb1 10.5ppg MudPush away. Start pumping 15.8 ppg, Class G w/ Latex, 15.8ppg cement. PIII1tBtl: W17/"LUUy lU:l /:Sy AM ~ ~ BP EXPLORATION Page 11 of 13 Operations Summary Report Legal Well Name: 07-14 Common Well Name: 07-14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 7/15/2009 End: 8/5/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To '; Hours Task Code NPT Phase Description of Operations 8/2/2009 04:00 - 06:00 2.00 CEMT P RUNPRD 04:42 20bbls cement away ~ 5.1 bpm, WHP = 501 psi 04:46 40bb1 cement away, 5.1 bpm, 342psi 04:53 60bb1 cement away, 5.1 bpm, 352psi 04:54 65.2bb1 cement away, 2.3bpm, 141 psi Full returns while pumping cement. 65.2bb1 cement pumped total; isolate SLB and displace with rig pumps 05:03 Drop plug; kick out with 45bbls 8.5ppg perf pill; tattletale indicated that plug dropped. Reciprocate pipe in 5' strokes; reciprocate until 125.9bbls displaced, then stop pipe movement. 05:03 Start displacement 05:10 52bbls displaced, 5bpm, 154psi 05:15 73bbls displaced, 5bpm, 480psi 05:20 95bbls displaced, 5bpm, 1295psi Slow pumps from 5.Obpm to 3.Obpm in anticipation for plug latch. 05:23 Plug latched in liner top; 105bb1s displaced, 3bpm. 05:25 111 bbls displaced, 4bpm, 2100psi 05:27 123bb1s displaced, 3bpm, 1585psi 05:30 131 bbls displaced, 3bpm, 1653psi 05:32 136bb1s displaced, 3bpm, 1715psi Plug bumped ~ 05:34 142bb1s displaced, 3bpm, 2768psi Returns dropped slightly while displacing, however, remained good throughout job. CIP ~ 05:34hrs Cement job volume: 65.2 bbls 15.8ppg Class G w/ Latex cement pumped; 288sxs ~ 1.17cufUsx t I b m ontinue to ressure u to 3500 si and hold to ensure liner han er set then continue to ressure u to 4200 si to neutralize usher and release han er setting tool. Bleed off pressure and check floats; okay. PU to verify tool release; good. Continue to 'dogs out' PU and slack off to set ZXP liner top packer. PU again and repeat slack off with rotation to ensure packer set. Liner top ~ 10,573' MD_._ 06:00 - 06:30 0.50 CEMT P RUNPRD Pull out of liner top and circulate at max rate to clean; 500gpm, 2200psi. 25bb1 cement contaminated mud and 8bbls good , cement returned to surface. 06:30 - 07:00 0.50 CEMT P RUNPRD LD cement head and DP single. 07:00 - 08:00 1.00 CEMT P RUNPRD Circulate wellbore over to clean 8.5ppg seawater ~ 550gpm, 2900psi. Reciprocate pipe in 40' strokes while swapping over. 08:00 - 09:00 1.00 CEMT P RUNPRD Cut and slip 116' of drilling line; service top drive, blocks and crown. Adjust brakes. 09:00 - 14:30 5.50 CEMT P RUNPRD POOH w/ 4" DP from 10,589' MD to 2097' MD (rack back rnntea: un iieuua i u: i i:oa iam BP EXPLORATION Operations Summary Report Legal Well Name: 07-14 Page 12 of 13 Common Well Name: 07-14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 7/15/2009 End: 8/5/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task j Code ! NPT ', Phase Description of Operations 8/2/2009 09:00 - 14:30 5.50 CEMT P RUNPRD 114stands, LD excess DP). Break out and lay down liner running tool; dog sub shear confirmed. Clean and clear rig floor of third party tools. 14:30 - 17:00 2.50 PERFO P OTHCMP PJSM w/ SLB perforating crew. RU to run 2-7/8" PowerJet Omega pert guns; bring handling equipment to the rig floor. PU two pert guns in derrick. 17:00 - 17:30 0.50 PERFO P OTHCMP Production liner cement reached appropriate compressive strength;~ressure up to test 4.5 liner. Pressure up to 3500psi and hold for 30min; chart test; ood. 0 min = 3500psi 15min = 3500psi 30min = 3500psi 17:30 - 21:30 4.00 PERFO P OTHCMP MU 2-7/8" PowerJet Omega pert guns, 6 shots per foot, 60deg phasing, as per SLB TCP specialist. RIH w/ pert assy on 2-7/8" FQX tbg from surface to 2513' MD. Total of three sets of live guns run; 548' total to be perforated. 21:30 - 00:00 2.50 PERFO P OTHCMP Change out handling equipment. Continue to RIH w/ pert gun and FOX tbg assembly from 2513' to 6238' MD. 95k up, 90k down. 8/3/2009 00:00 - 03:00 3.00 PERFO P OTHCMP PJSM. Continue to RIH w/ pert gun and 2-7/8" FOX tbg assy from 6238' to 12,968' MD. Tag up lightly on PBTD, and PU to up wt (188k). 03:00 - 04:00 1.00 PERFO P OTHCMP PJSM w/ SLB TCP specialists. Circulate out any air in guns and calibrate pumps. Initiate firing sequence. Guns fire ~ 03:31 hrs and 03:32hrs. Good indication at surface that guns fired; lost 2bbls initially. Perforations: 11,750' - 11,850' (100ft) 12,230' - 12,400' (170ft) 12,690' - 12,968' (278ft) 04:00 - 05:00 1.00 PERFO P OTHCMP Pull 13 stands of DP so bottom gun is above top-most shot C 11,750' MD. Circulate bottoms-up C~ 480gpm, 3500psi, and montior well for losses. 2.6bbls lost during circulation. 05:00 - 13:00 8.00 PERFO P OTHCMP POOH, LD joints of 4" DP from 11,715' to 7097' MD. RIH with remainder of DP and come out laying down all DP. 13:00 - 19:30 6.50 PERFO P OTHCMP Change out handling equipment. LD 2-7/8" FOX tubing from 2514' to 1270'MD. PJSM w/ TCP pert specialists; LD perf guns and remainder of FOX tubing from 1270' to surface. All shots fired. 19:30 - 23:30 4.00 BUNCO P RUNCMP RU completion running equipment; pull wear busing, RU compensator, torque-turn equipment and double-stack tongs. Make dummy run w/ tubing hanger; 4.909" MCA thread; 16 RH turns to MU. 23:30 - 00:00 0.50 BUNCO RUNCMP PJSM w/ Nabors casing and Baker hands. Run 4.5" 12.6# 13Cr VamTo completion from surface to 105' MD; Bakerlok all connections below Baker S-3 production packer. Torque all connections to 4440ft1bs MU torque. 8/4/2009 00:00 - 10:30 10.50 BUNCO P RUNCMP PJSM. RIH w/ 4.5" 12.6# 13Cr VamTop completion from 105' to 10,584' MD. Torque-turn all connections w/ 4440ft1bs. Utilize stabbing board and guide shoe for making connections; JetLube Seal Guard on all connections; Bakerlok all connections below the Baker production packer. 10:30 - 12:00 1.50 BUNCO P RUNCMP PU 3 space-out pups (3.91', 9.83' and 19.76') to position Pflntetl: 8/17/2009 10:1 /:S9 AM • BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: 07-14 Common Well Name: 07-14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 7/15/2009 End: 8/5/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2009 Rig Name: NABOBS 7ES Rig Number: t F T D H T k C NPT ~ h d f O a e rom - o ours as o e P ase. Description o perations 8/4/2009 10:30 - 12:00 1.50 BUNCO RUNCMP WLEG 5' inside PBR. Land tubing hanger in wellhead; RILDS as per Cameron hand. 12:00 - 15:00 3.00 BUNCO RUNCMP Reverse circulate and spot corrosion inhibited brine. Pump 144bb1 clean 8.5ppg seawater, 134bb1 corrosion inhibited 8.5ppg seawater, 214bb1s clean 8.5ppg seawater. Corrosion inhibited fluid placed between GLM#2 and production packer. Pump C~ 121 gpm, 170psi. 15:00 - 17:00 2.00 BUNCO RUNCMP - Dro ball and rod and allow to fall to RHC plug C~ 10,569' MD. Pressure up and set S-3 production packer as per Baker hand. Hold pressure and test tubing to 3500psi for 30 minutes, chart test; ood. Bleed tubin to 1500psi and pressure test IA to 3500psi for 30 minutes, chart test; good. Bleed off IA. Bleed down tubing, and pressure IA back up to 3500psi to shear DCR; valve sheared at 2250psi. Pump 2bbl each way to confirm circulation ability. Tubing test: Omin = 3500psi 15min = 3500psi 30min= 3500psi IA test: Omin = 3500psi 15min = 3500psi 30min = 3500psi 17:00 - 17:30 0.50 BUNCO P RUNCMP Install TWC w/ drv rod and test from below to 1000psi; good. 17:30 - 19:30 2.00 BOPSU P RUNCMP _ ND BOPs. 19:30 - 23:30 4.00 WHSUR P RUNCMP NU adapter flange and tree. PT flange and tree to 5000psi. RU DSM and test lubricator to 500psi; pull TWC with lubricator. 23:30 - 00:00 0.50 WHSUR P RUNCMP RU LRHOS and test connections. 8/5/2009 00:00 - 01:30 1.50 WHSUR P RUNCMP PJSM. Pump 152bb1s to freeze protect IA/tubing from surface to 2200' MD. Pump down the annulus w LRH an a ow diesel to U-tube throug tree. 01:30 - 02:30 1.00 WHSUR P RUNCMP Rig up DSM. Run in BPV. Test with LRS from below, with diesel, to 1000 psi. Rig down D M. 02:30 - 06:00 3.50 WHSUR P RUNCMP Rig down LRS. Secure well. Rig down pits and sub. Install valves and gauges. Move pits away from sub. Rig down and disconnect portable buildings. Prepare to lower derrick, move sub away from well and from 07-14C to 01-18A. Rig release at 06:00 hours. Printed: 8/17/2009 10:17:59 AM ~ ~~ T,~., DS07-14C Su Report Date: 1-Aug-09 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - EOA Structure /Slot: DS-07 / 07-14 Well: 07-14 Borehole: 07.14C UWVAPI#: 500292033903 Survey Name /Date: 07-14C / Aug 1, 2009 Tort /AHD / DDI / ERD ratio: 396.875° / 7251.34 ft / 6.619 / 0.803 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 701612.434, W 148 34 39.412 Location Grid NIE Y/X: N 5950406.370 ftUS, E 675869.480 ftUS Grid Convergence Angle: +1.33891540° Grid Scale Factor: 0.99993514 Total Corr Mag North -> True North: +22.619° Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub-Sea TVD TVD Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True North True Narth tt de de n n n n tt tt tt de 00 tt ftUS ttUS Nro~ectea-up 0. UU U.W U.UU -bb. 1l) U.UU U.W U.UU U.UU U.UU U.UU U.UU b`JbU4Utl.J/ b/bt3by.4t5 N /U lb 1Z.4a4 W 14t5 a43`J.41Z WRP 33 .26 0.00 0.00 -22. 00 33. 26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 CB GYRO MS 91 .26 0.00 0.00 36. 00 91. 26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 191 .26 0.00 0.00 136. 00 191. 26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 291 .26 0.00 0.00 236. 00 291. 26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 391 .26 0.00 0.00 336. 00 391. 26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 491 .26 0.00 0.00 436. 00 491. 26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 591 .26 0.00 0.00 536. 00 591. 26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 691 .26 0.00 0.00 636. 00 691 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 791 .26 0.00 0.00 736. 00 791 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 891 .26 0.00 0.00 836. 00 891 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 991 .26 0.00 0.00 936. 00 991 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39. 1091 .26 0.00 0.00 1036. 00 1091 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39. 1191 .26 0.00 0.00 1136. 00 1191 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 1291 .26 0.00 0.00 1236. 00 1291 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 1391 .26 0.00 0.00 1336. 00 1391 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 1491 .26 0.00 0.00 1436. 00 1491 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 1591 .26 0.00 0.00 1536. 00 1591 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 1691 .26 0.00 0.00 1636 .00 1691 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 1791 .26 0.00 0.00 1736 .00 1791 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 1891 .26 0.00 0.00 1836 .00 1891 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 1991 .26 0.00 0.00 1936 .00 1991 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 2091 .26 0.00 0.00 2036 .00 2091 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 2191 .26 0.00 0.00 2136 .00 2191 .26 0.00 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 2291 .26 0.50 149.00 2236 .00 2291 .26 -0.29 0.44 0.44 -0.37 0.22 0.50 5950406.00 675869.71 N 70 16 12.430 W 148 34 39.405 Report Schlumberger Vertical Section Azimuth: 17.300° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 55.26 tt relative to MSL Sea Bed /Ground Level Elevation: 26.56 ft relative to MSL Magnetic Declination: 22.619° Total Field Strength: 57669.076 nT Magnetic Dip: 80.921 ° Declination Date: July 27, 2009 Magnetic Declination Model: BGGM 2009 North Reference: True North • SurveyEditor Ver SP 2.1 Bld( users) 07-14\07-14\07-14C\07-14C Generated 8/18/2009 12:02 PM Page 1 of 5 Comments Measured Inclination Azimuth SulrSea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de n n ft ft ft n n de 00 tt ftUS ttUS L3yl.Cb V.UU V.UV L33b.VV Gay I.CO -U.JO V.O/ V. O/ -V./V V.wV v.VV aaavwv~.vv v/nova. ~:~ iv iv iv ic.wcv vv iwc/ aw aa.aaa 2491.26 0.00 0.00 2436.00 249126 -0.58 0.87 0. 87 -0.75 0.45 0.00 5950405.63 675869.95 N 70 16 12.426 W 148 34 39.399 2591.26 0.50 140.00 2536.00 2591.26 -0.82 1.31 1. 31 -1.08 0.73 0.50 5950405.31 675870.23 N 7016 12.423 W 148 34 39.390 2691.26 0.00 0.00 2635.99 2691.25 -1.05 1.75 1. 74 -1.42 1.01 0.50 5950404.98 675870.52 N 70 16 12.420 W 148 34 39.382 2791.26 1.00 14.00 2735.99 2791.25 -0.18 2.62 1. 35 -0.57 1.22 1.00 5950405.83 675870.71 N 70 16 12.428 W 148 34 39.376 2891.26 6.50 7.00 2835.74 2891.00 6.26 9.15 6. 27 5.90 2.12 5.51 5950412.32 675871.46 N 70 16 12.492 W 148 34 39.350 2991.26 11.00 29.00 2934.57 2989.83 21.19 24.19 21. 22 19.87 7.44 5.53 5950426.41 675876.46 N 70 16 12.629 W 148 34 39.195 3091.26 12.50 28.50 3032.48 3087.74 41.15 44.55 41. 48 37.73 17.23 1.50 5950444.49 675885.82 N 70 16 12.805 W 148 34 38.910 3191.26 15.00 16.50 3129.62 3184.88 64.71 68.24 65. 10 59.66 26.07 3.78 5950466.61 675894.15 N 70 16 13.020 W 148 34 38.653 3291.26 18.00 18.00 3225.49 3280.75 93.11 96.63 93. 38 86.76 34.53 3.03 5950493.91 675901.97 N 70 16 13.287 W 148 34 38.407 3391.26 18.00 23.50 3320.61 3375.87 123.92 127.51 124. 25 115.63 45.46 1.70 5950523.02 675912.23 N 70 16 13.571 W 148 34 38.088 3491.26 20.00 25.00 3415.15 3470.41 156.23 160.07 156. 77 145.30 58.85 2.06 5950553.00 675924.92 N 70 16 13.863 W 148 34 37.6 3591.26 22.50 24.00 3508.35 3563.61 192.19 196.31 192. 98 178.29 73.86 2.53 5950586.32 675939.15 N 70 16 14.187 W 148 34 37. 3691.26 24.25 25.50 3600.14 3655.40 231.52 235.98 232. 63 214.30 90.49 1.85 5950622.72 675954.93 N 70 16 14.541 W 148 34 36. 3791.26 26.50 28.00 3690.49 3745.75 273.77 278.82 275. 38 252.54 109.81 2.49 5950661.39 675973.35 N 7016 14.917 W 148 34 36.215 3891.26 29.00 26.00 3778.98 3834.24 319.67 325.38 321. 86 294.04 130.91 2.67 5950703.37 675993.48 N 70 16 15.326 W 148 34 35.601 3991.26 31.25 25.00 3865.47 3920.73 369.34 375.56 372. 03 339.34 152.50 2.31 5950749.16 676014.00 N 70 16 15.771 W 148 34 34.972 4091.26 34.00 27.00 3949.69 4004.95 422.61 429.47 425. 91 387.77 176.16 2.95 5950798.12 676036.52 N 70 16 16.247 W 148 34 34.283 4191.26 35.50 28.00 4031.85 4087.11 478.71 486.46 482. 83 438.32 202.49 1.60 5950849.27 676061.66 N 70 16 16.745 W 148 34 33.517 4291.26 39.50 26.50 4111.17 4166.43 538.66 547.33 543. 65 492.44 230.32 4.10 5950904.03 676088.22 N 70 16 17.277 W 148 34 32.706 4391.26 42.50 24.50 4186.63 4241.89 603.58 612.92 609. 24 551.66 258.53 3.27 5950963.88 676115.03 N 70 16 17.859 W 148 34 31.885 4491.26 43.50 21.00 4259.78 4315.04 671.46 681.11 677. 36 614.54 284.88 2.59 5951027.36 676139.90 N 70 16 18.478 W 148 34 31.118 4591.26 43.00 17.00 4332.63 4387.89 739.91 749.61 745. 52 679.30 307.19 2.79 5951092.61 676160.69 N 70 16 19.115 W 148 34 30.468 4691.26 43.50 18.00 4405.47 4460.73 808.43 818.13 813. 59 744.64 327.79 0.85 5951158.42 676179.76 N 70 16 19.757 W 148 34 29.868 4791.26 42.50 17.00 4478.60 4533.86 876.63 886.33 881 .42 809.68 348.30 1.21 5951223.91 676198.75 N 70 16 20.397 W 148 34 29.271 4891.26 43.00 16.50 4552.04 4607.30 944.50 954.21 948 .89 874.68 367.87 0.60 5951289.35 676216.78 N 70 16 21.036 W 148 34 28.702 Tie-In Survey 4991.26 42.50 17.00 4625.47 4680.73 1012.38 1022.09 1016 .41 939.68 387.43 0.60 5951354.78 676234.82 N 70 16 21.675 W 148 34 28.132 TOW (Blind) 5001.00 42.57 16.93 4632.64 4687.90 1018.96 1028.67 1022 .97 945.98 389.35 0.87 5951361.12 676236.59 N 70 16 21.737 W 148 34 28.076 BOW (Blind) 5018.00 42.00 14.00 4645.22 4700.48 1030.39 1040.11 1034 .32 957.00 392.40 12.07 5951372.21 676239.39 N 70 16 21.846 W 148 34 27.987 Blind 5058.00 42.00 17.00 4674.95 4730.21 1057.14 1066.87 1060 .90 982.78 399.55 5.02 5951398.15 676245.93 N 70 16 22.099 W 148 34 27.779 ~ Inc+Trend 5085.10 42.31 16.50 4695.04 4750.30 1075.33 1085.06 1079 .01 1000.20 404.79 1.69 5951415.69 676250.76 N 70 16 22.271 W 148 34 27. 5115.95 42.17 16.60 4717.88 4773.14 1096.06 1105.80 1099 .65 1020.08 410.70 0.50 5951435.70 676256.21 N 70 16 22.466 W 148 34 27.454 5148.98 42.25 16.80 4742.35 4797.61 1118.25 1127.99 1121 .75 1041.33 417.08 0.47 5951457.10 676262.08 N 70 16 22.675 W 148 34 27.269 5244.17 40.97 17.00 4813.52 4868.78 1181.46 1191.20 1184 .74 1101.81 435.45 1.35 5951517.98 676279.04 N 70 16 23.270 W 148 34 26.734 5339.34 41.69 5.00 4885.09 4940.35 1243.68 1253.92 1246 .33 1163.28 447.35 8.35 5951579.71 676289.50 N 70 16 23.874 W 148 34 26.387 5434.93 41.43 353.00 4956.74 5012.00 1303.66 1317.20 1305 .11 1226.44 446.26 8.32 5951642.82 676286.94 N 70 16 24.496 W 148 34 26.418 MWD+IFR+MS 5530.70 41.15 341.34 5028.80 5084.06 1358.13 1380.27 1358 .45 1287.83 432.30 8.03 5951703.87 676271.54 N 70 16 25.099 W 148 34 26.825 5626.54 41.90 335.55 5100.58 5155.84 1407.55 1443.78 1407 .58 1346.86 408.96 4.08 5951762.33 676246.83 N 70 16 25.680 W 148 34 27.505 5721.87 44.18 329.38 5170.28 5225.54 1453.58 1508.81 1454 .66 1404.46 378.84 5.02 5951819.21 676215.38 N 70 16 26.246 W 148 34 28.381 5817.75 45.54 320.87 5238.31 5293.57 1494.93 1576.37 1498 .92 1459.81 340.20 6.42 5951873.63 676175.45 N 70 16 26.791 W 148 34 29.506 5913.07 47.64 316.37 5303.83 5359.09 1530.87 1645.60 1540 .11 1511.71 294.41 4.08 5951924.44 676128.47 N 70 16 27.301 W 148 34 30.839 6009.95 51.45 313.21 5366.68 5421.94 1564.83 1719.29 1582 .21 1563.58 242.07 4.65 5951975.07 676074.94 N 70 16 27.811 W 148 34 32.363 6105.73 52.02 312.46 5426.00 5481.26 159725 1794.50 1625 .49 1614.71 186.93 0.86 5952024.89 676018.62 N 70 16 28.314 W 148 34 33.969 6198.23 51.98 312.93 5482.95 5538.21 1628.50 1867.39 1669 .47 1664.13 133.35 0.40 5952073.05 675963.91 N 70 16 28.800 W 148 34 35.529 SurveyEditor Ver SP 2.1 Bld( users) 07-14\07-14\07-14C\07-14C Generated 8/18/2009 12:02 PM Page 2 of 5 Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub-Sea TVD TVD Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de ft tt ft ft tt tt ft de 00 ft ftUS ftUS bLyl.bb b:S.b`J 31L./tl 553`J.4U 55`J4.bb IbbU. S/ I`J41./I 1/Ib.bV I/14.b23 /b.25/ I./3 b`JbCILC.31 b/5`JU25.Lb IV /U Ib C`J. L`Ji5 VV 1425 343/.115 6382.56 53.00 312.55 5593.79 5649.05 1691. 82 2014.67 1764.31 1764.13 25.22 0.68 5952170.49 675853.48 N 70 16 29. 784 W 148 34 38.677 6473.77 53.69 311.76 5648.24 5703.50 1722. 57 2087.84 1813.46 1813.23 -29.02 1.03 5952218.31 675798.10 N 70 16 30. 267 W 148 34 40.257 6569.98 58.96 305.60 5701.60 5756.86 1751. 60 2167.85 1865.36 1863.11 -91.54 7.64 5952266.71 675734.44 N 70 16 30. 757 W 148 34 42.077 6665.87 62.11 301.26 5748.78 5804.04 1774. 74 2251.32 1915.84 1909.04 -161.21 5.13 5952311.00 675663.72 N 70 16 31. 209 W 148 34 44.106 6759.72 64.83 297.16 5790.71 5845.97 1792. 03 2335.27 1964.02 1949.97 -234.48 4.87 5952350.20 675589.51 N 7016 31. 612 W 148 34 46.239 6853.76 65.19 293.45 5830.45 5885.71 1803. 89 2420.50 2010.67 1986.39 -311.53 3.60 5952384.81 675511.65 N 7016 31. 970 W 148 34 48.483 6945.96 65.36 287.31 5869.04 5924.30 1808. 38 2504.23 2052.92 2015.54 -389.98 6.05 5952412.11 675432.54 N 70 16 32. 256 W 148 34 50.767 7039.56 65.10 279.93 5908.30 5963.56 1802. 94 2589.20 2089.66 2035.54 -472.50 7.16 5952430.17 675349.58 N 70 16 32. 453 W 148 34 53.170 7128.79 63.60 275.81 5946.94 6002.20 1789. 78 2669.63 2119.74 2046.56 -552.15 4.49 5952439.34 675269.70 N 70 16 32. 561 W 148 34 55.489 7225.01 61.16 270.55 5991.57 6046.83 1769. 04 2754.87 2148.03 2051.34 -637.22 5.47 5952442.12 675184.54 N 70 16 32. 608 W 148 34 57.967 7317.04 58.75 265.20 6037.67 6092.93 1742. 60 2834.51 2170.22 2048.43 -716.79 5.67 5952437.35 675105.08 N 70 16 32. 580 W 148 35 0~ 7409.74 57.06 259.94 6086.95 6142.21 1709. 80 2913.02 2187.72 2038.31 -794.62 5.14 5952425.42 675027.51 N 70 16 32. 480 W 148 35 2. 7502.03 57.90 253.84 6136.59 6191.85 1670. 42 2990.82 2200.13 2020.66 -870.35 5.65 5952406.00 674952.22 N 70 16 32. 306 W 148 35 4.755 7595.34 59.52 247.42 6185.09 6240.35 1622. 81 3070.53 2206.98 1994.19 -945.50 6.13 5952377.80 674877.71 N 70 16 32. 046 W 148 35 6.943 7690.83 57.72 241.43 6234.85 6290.11 1567. 42 3152.03 2208.23 1959.06 -1018.99 5.68 5952340.96 674805.06 N 7016 31. 700 W 148 35 9.083 7785.93 55.11 236.00 6287.48 6342.74 1508. 08 3231.23 2204.45 1918.00 -1086.68 5.49 5952298.33 674738.35 N 70 16 31. 296 W 148 35 11.054 7882.26 54.69 234.29 6342.87 6398.13 1445. 85 3310.04 2198.55 1872.96 -1151.35 1.52 5952251.80 674674.76 N 70 16 30. 853 W 148 35 12.936 7977.89 54.16 233.17 6398.50 6453.76 1383. 27 3387.82 2193.56 1826.95 -1214.06 1.10 5952204.34 674613.14 N 70 16 30. 401 W 148 35 14.762 8070.50 53.86 233.30 6452.93 6508.19 1322. 60 3462.76 2190.71 1782.10 -1274.09 0.34 5952158.10 674554.18 N 70 16 29. 960 W 148 35 16.510 8163.70 53.17 231.71 6508.35 6563.61 1261. 38 3537.69 2189.47 1736.50 -1333.54 1.56 5952111.12 674495.82 N 70 16 29. 511 W 148 35 18.241 8256.54 54.57 232.72 6563.09 6618.35 1199. 90 3612.67 2190.41 1690.56 -1392.81 1.75 5952063.81 674437.65 N 70 16 29. 059 W 148 35 19.966 8354.05 58.46 238.25 6616.90 6672.16 1136. 08 3693.96 2199.03 1644.59 -1459.81 6.19 5952016.29 674371.74 N 70 16 28. 607 W 148 35 21.917 8449.49 60.67 245.89 6665.30 6720.56 1077. 77 3776.21 2219.94 1606.15 -1532.46 7.28 5951976.17 674300.01 N 70 16 28. 229 W 148 35 24.032 8543.77 60.21 245.75 6711.81 6767.07 1023. 45 3858.22 2248.61 1572.56 -1607.27 0.50 5951940.84 674226.01 N 70 16 27 .898 W 148 35 26.210 8636.26 59.42 244.83 6758.31 6813.57 969. 95 3938.17 2278.38 1539.14 -1679.90 1.21 5951905.74 674154.19 N 70 16 27 .569 W 148 35 28.324 8730.60 57.27 244.02 6807.82 6863.08 915. 32 4018.47 2309.58 1504.48 -1752.33 2.39 5951869.40 674082.59 N 70 16 27 .228 W 148 35 30.433 8823.27 54.55 240.86 6859.77 6915.03 861. 23 4095.20 2339.17 1469.01 -1820.37 4.07 5951832.35 674015.41 N 70 16 26 .879 W 148 35 32.414 8916.87 51.82 237.94 6915.86 6971.12 805. 67 4170.12 2366.48 1430.91 -1884.86 3.84 5951792.75 673951.82 N 70 16 26 .504 W 148 35 34.291 9010.41 47.50 236.48 6976.40 7031.66 751. 01 4241.40 2391.83 1392.33 -1944,80 4.77 5951752.79 673892.81 N 70 16 26 .125 W 148 35 36~ 9102.97 43.53 234.95 7041.24 7096.50 699. 30 4307.42 2415.35 1355.17 -1999.36 4.45 5951714.36 673839.13 N 70 16 25 .759 W 148 35 37. 9194.33 39.39 230.16 7109.71 7164.97 650. 01 4367.88 2435.23 1318.50 -2047.41 5.71 5951676.59 673791.96 N 70 16 25 .398 W 148 35 39.023 9285.95 35.30 226.22 7182.55 7237.81 602. 39 4423.43 2450.66 1281.54 -2088.87 5.17 5951638.67 673751.38 N 70 16 25 .035 W 148 35 40.230 9377.71 32.01 223.24 7258.92 7314.18 557. 30 4474.27 2462.82 1245.47 -2124.68 4.01 5951601.78 673716.42 N 70 16 24 .680 W 148 35 41.273 9469.53 31.52 219.22 7337.00 7392.26 513 .14 4522.59 2472.38 1209.14 -2156.53 2.37 5951564.72 673685.43 N 70 16 24 .323 W 148 35 42.200 9563.80 32.46 211.96 7416.98 7472.24 465 .79 4572.48 2478.32 1168.57 -2185.52 4.20 5951523.48 673657.40 N 70 16 23 .924 W 148 35 43.043 9659.33 31.29 207.87 7498.11 7553.37 416 .60 4622.91 2480.43 1124.89 -2210.69 2.57 5951479.22 673633.26 N 70 16 23 .494 W 148 35 43.776 9754.70 30.69 204.65 7579.87 7635.13 368 .11 4672.01 2480.32 1080.87 -2232.42 1.85 5951434.71 673612.57 N 70 16 23 .061 W 148 35 44.408 9849.57 28.75 204.71 7662.26 7717.52 321 .47 4719.04 2479.81 1038.13 -2252.06 2.05 5951391.53 673593.93 N 70 16 22 .640 W 148 35 44.979 9945.18 29.61 201.96 7745.74 7801.00 275 .12 4765.65 2479.09 995.34 -2270.50 1.67 5951348.32 673576.49 N 70 16 22 .219 W 148 35 45.516 10039.99 31.24 202.44 7827.49 7882.75 227 .28 4813.66 2478.32 950.89 -2288.65 1.74 5951303.46 673559.39 N 70 16 21 .782 W 148 35 46.044 10135.40 32.33 201.79 7908.59 7963.85 177 .21 4863.91 2478.44 904.33 -2307.56 1.20 5951256.48 673541.57 N 70 16 21 .324 W 148 35 46.594 10231.00 30.71 202.78 7990.08 8045.34 127 .42 4913.89 2479.70 858.08 -2326.50 1.78 5951209.80 673523.72 N 70 16 20 .869 W 148 35 47.145 SurveyEditor Ver SP 2.1 Bld( users) 07-14\07-14\07-14C\07-14C Generated 8/1 8/2009 1 2:02 PM Page 3 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North it de de tt tt ft n n n ft de 00 ft ttUS ftUS 10325.64 Z9.t14 2U3.4y tSU/1.152 251L/.UtS 10421.19 29.35 202.82 8154.90 8210.16 10516.75 27.81 201.90 8238.81 8294.07 10612.79 26.04 202.10 8324.44 8379.70 10646.13 25.53 201.68 8354.46 8409.72 7" Cc3 10709'md 10714.89 24.34 201.68 8416.81 8472.07 10745.15 25.21 197.64 8444.29 8499.55 10776.49 27.42 191.67 8472.38 8527.64 10808.65 28.95 185.92 8500.73 8555.99 10838.98 31.63 181.28 8526.92 8582.18 10869.04 34.41 177.99 8552.13 8607.39 10900.97 38.37 175.44 8577.83 8633.09 10931.38 41.92 174.91 8601.07 8656.33 10962.59 42.65 174.20 8624.16 8679.42 10994.24 42.51 173.03 8647.47 8702.73 11022.72 42.59 173.02 8668.45 8723.71 11054.58 42.40 172.90 8691.94 8747.20 11085.53 42.36 172.60 8714.80 8770.06 11114.93 42.45 171.79 8736.51 8791.77 11145.62 42.32 172.13 8759.18 8814.44 11176.35 45.71 170.45 8781.28 8836.54 11205.96 48.03 169.62 8801.52 8856.78 11237.48 50.82 169.19 8822.02 8877.28 11267.89 53.90 168.19 8840.59 8895.85 11297.28 57.02 168.04 8857.25 8912.51 11328.83 59.87 168.73 8873.76 8929.02 11359.92 62.08 170.00 8888.84 8944.10 11391.40 66.04 168.43 8902.61 8957.87 11423.19 69.61 168.50 8914.61 8969.87 11455.19 73.08 168.94 8924.84 8980.10 11486.89 76.46 166.12 8933.17 8988.43 11518.88 79.60 166.00 8939.80 8995.06 11550.82 82.60 166.45 8944.74 9000.00 11581.55 82.58 165.87 8948.71 9003.97 11613.63 82.35 165.53 8952.91 9008.17 11645.31 82.29 166.19 8957.15 9012.41 11709.34 82.31 166.31 8965.73 9020.99 11771.78 83.13 166.49 8973.64 9028.90 11806.12 88.60 166.23 8976.11 9031.37 11837.38 89.60 165.57 8976.60 9031.86 11868.38 89.71 166.43 8976.79 9032.05 11899.65 95.50 167.49 8975.37 9030.63 11931.82 98.43 168.11 8971.47 9026.73 /y.yb 4yb1.t5U 'L4252.bt5 33.01 5008.79 2486.31 -12.52 5054.50 2490.16 -55.86 5097.99 2494.32 -70.32 5112.49 2495.84 -99.22 5141.48 2499.04 -111.88 5154.16 2500.08 -125.74 5168.04 2500.08 -140.75 5183.22 2498.62 -155.59 5198.51 2495.86 -171.19 5214.88 2491.91 -188.91 5233.82 2486.53 -207.07 5253.43 2480.61 -226.43 5274.42 2474.22 -246.04 5295.84 2467.53 -263.60 5315.10 2461.47 -283.21 5336.62 2454.84 -302.18 5357.48 2448.50 -320.14 5377.31 2442.44 -338.83 5398.00 2436.19 -358.02 5419.34 2429.66 -377.22 5440.95 2422.79 -398.38 5464.89 2415.12 -419.51 5488.97 2407.34 -440.65 5513.17 2399.51 -464.18 5540.06 2391.19 -488.20 5567.24 2383.51 -513.16 5595.54 2375.73 -538.95 5624.98 2367.61 -565.57 5655.29 2359.73 -592.11 5685.87 2351.53 -618.86 5717.16 2342.75 -645.88 5748.71 2334.38 -671.97 5779.19 2326.64 -699.05 5810.99 2318.71 -725.84 5842.39 2311.37 -780.20 5905.84 2298.21 -833.35 5967.78 2287.14 -862.71 6002.01 2281.69 -889.39 6033.27 2276.92 -915.88 6064.27 2272.64 -942.83 6095.49 2269.28 -970.61 6127.42 2266.75 2514.21 -'L:345.L5 U.yy 5y517bb. bV b/JbVb.Vl IV /V lb 2U. 4.Si5 VV 1425 J5 4/.byU 770.82 -2363.80 0.62 5951121. 70 673488.47 N 70 16 20. 011 W 148 35 48.230 728.55 -2381.20 1.68 5951079. 03 673472.07 N 70 16 19. 595 W 148 35 48.736 688.23 -2397.49 1.85 5951038. 35 673456.72 N 70 16 19. 199 W 148 35 49.210 674.77 -2402.90 1.62 5951024. 77 673451.63 N 70 16 19. 066 W 148 35 49.368 647.83 -2413.61 1.73 5950997. 59 673441.56 N 70 16 18. 801 W 148 35 49.679 635.90 -2417.86 6.29 5950985. 56 673437.58 N 7016 18. 684 W 148 35 49.803 622.46 -2421.35 10.99 5950972. 05 673434.41 N 70 16 18. 552 W 148 35 49.904 607.47 -2423.65 9.69 5950957. 00 673432.46 N 70 16 18. 404 W 148 35 49.971 592.21 -2424.58 11.73 5950941. 73 673431.88 N 70 1618. 254 W 148 35 49.998 575.84 -2424.46 11.00 5950925. 36 673432.39 N 70 16 18. 093 W 148 35 49.994 556.93 -2423.36 13.27 5950906. 49 673433.94 N 70 16 17. 907 W 148 35 49.9 537.40 -2421.70 11.73 5950887. 00 673436.04 N 7016 17. 715 W 148 35 49. 516.50 -2419.71 2.80 5950866. 15 673438.52 N 70 16 17. 510 W 148 35 49.856 495.21 -2417.33 2.54 5950844. 94 673441.40 N 70 16 17. 300 W 148 35 49.786 476.10 -2414.99 0.28 5950825. 88 673444.19 N 70 16 17. 112 W 148 35 49.718 454.74 -2412.35 0.65 5950804. 59 673447.32 N 70 16 16. 902 W 148 35 49.641 434.04 -2409.72 0.67 5950783. 96 673450.44 N 70 16 16. 699 W 148 35 49.564 414.40 -2407.03 1.88 5950764. 39 673453.59 N 7016 16. 506 W 148 35 49.485 393.91 -2404.13 0.86 5950743. 98 673456.96 N 70 16 16. 304 W 148 35 49.401 372.81 -2400.89 11.67 5950722. 96 673460.69 N 70 16 16. 097 W 148 35 49.306 351.53 -2397.15 8.10 5950701. 78 673464.93 N 70 16 15. 887 W 148 35 49.197 328.00 -2392.75 8.91 5950678. 36 673469.88 N 70 16 15. 656 W 148 35 49.069 304.39 -2388.02 10.46 5950654. 87 673475.16 N 7016 15. 424 W 148 35 48.931 280.71 -2383.03 10.62 5950631 .30 673480.70 N 70 16 15. 191 W 148 35 48.786 254.38 -2377.62 9.22 5950605 .11 673486.72 N 70 16 14. 932 W 148 35 48.628 227.66 -2372.61 7.96 5950578 .52 673492.36 N 70 16 14. 669 W 148 35 48.482 199.86 -2367.31 13.35 5950550 .85 673498.31 N 70 16 14. 396 W 148 35 48.327 171.02 -2361.42 11.23 5950522 .16 673504.86 N 70 16 14 .112 W 148 35 48.156 141.29 -2355.49 10.92 5950492 .58 673511.48 N 70 16 13 .820 W 148 35 47. 111.43 -2348.89 13.69 5950462 .88 673518.79 N 70 16 13 .526 W 148 35 ~ 47. 81.07 -2341.35 9.82 5950432 .70 673527.03 N 70 16 13 .227 W 148 35 47.570 50.42 -2333.84 9.50 5950402 .24 673535.26 N 70 16 12 .926 W 148 35 47.351 20.83 -2326.55 1.87 5950372 .84 673543.24 N 70 16 12 .635 W 148 35 47.139 -9.99 -2318.69 1.27 5950342 .21 673551.81 N 70 16 12 .332 W 148 35 46.910 -40.43 -2311.02 2.07 5950311 .96 673560.19 N 70 16 12 .033 W 148 35 46.686 -102.06 -2295.94 0.19 5950250 .70 673576.71 N 7016 11 .426 W 148 35 46.247 -162.26 -2281.38 1.34 5950190 .86 673592.67 N 70 16 10 .834 W 148 35 45.822 -195.54 -2273.30 15.95 5950157 .79 673601.52 N 70 16 10 .507 W 148 35 45.587 -225.85 -2265.69 3.83 5950127 .66 673609.84 N 70 16 10 .209 W 148 35 45.365 -255.93 -2258.19 2.80 5950097 .77 673618.04 N 70 16 9 .913 W 148 35 45.147 -286.35 -2251.14 18.82 5950067 .52 673625.79 N 70 16 9 .614 W 148 35 44.941 -317.55 -2244.39 9.31 5950036 .48 673633.27 N 70 16 9 .307 W 148 35 44.744 SurveyEditor Ver SP 2.1 Bld( users) 07-14\07-14\07-14C\07-14C Generated 8/1 8/2009 1 2:02 PM Page 4 of 5 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude ~pffi True Section Departure True North True North ft de de ft ft ft ft n ft ft de 100 ft ftUS ftUS llyr51.4b yt5 .425 1bb.Vb tSyb4.l/ yVly.43 -1U13.U3 bl/b.bl LCb3.lL -3bb.4V -LL3:S. 4L 4.Uy b`J4yytSiS.`J'1 li/Sb45 .:i5 12002.02 98 .62 168.40 8961. 11 9016.37 -1030.64 6196.85 2261.97 -385.24 -2228. 93 11.27 5949969.19 673650 .31 12033.31 98 .50 167.92 8956. 46 9011.72 -1057.66 6227.80 2261.09 -415.52 -2222. 58 1.56 5949939.06 673657 .37 12064.91 94 .64 167.29 8952. 84 9008.10 -1084.93 6259.18 2260.31 -446.17 -2215. 84 12.37 5949908.57 673664 .82 12097.17 92 .03 167.89 8950. 96 9006.22 -1112.89 6291.38 2259.97 -477.62 -2208. 92 8.30 5949877.30 673672 .47 12128.36 90.97 168.22 8950.15 9005.41 -1140.10 6322 .56 2260.32 -508.13 -2202. 47 3.56 5949846.95 673679 .63 12160.66 91.24 167.36 8949. 53 9004.79 -1168. 20 6354 ,86 2260.99 -539.69 -2195. 64 2.79 5949815.56 673687 .20 12256.02 92.34 166.58 8946. 55 9001.81 -1250. 47 6450 .17 2264.30 -632.55 -2174. 15 1.41 5949723.24 673710 .85 12291.12 90.73 167.50 8945. 61 9000.87 -1280. 78 6485 .26 2266.56 -666.74 -2166. 28 5.28 5949689.24 673719 .52 12320.32 88.72 166.22 8945. 75 9001.01 -1305. 95 6514 .45 2268.77 -695.17 -2159. 64 8.16 5949660.97 673726 .81 12351.09 88.91 166.18 8946. 38 9001.64 -1332. 29 6545 .22 2271.15 -725.05 -2152. 30 0.63 5949631.28 673734 .85 12383.09 89.25 166.66 8946. 90 9002.16 -1359. 75 6577 .21 2274.18 -756.15 -2144. 79 1.84 5949600.36 673743 .09 12414.59 89.42 166.86 8947. 26 9002.52 -1386. 88 6608 .71 2277.79 -786.81 -2137. 58 0.83 5949569.88 673751 .01 12446.89 89.84 164.67 8947. 47 9002.73 -1414. 41 6641 .01 2281.37 -818.12 -2129. 64 6.90 5949538.77 673759 .68 12478.27 89.08 165.10 8947. 77 9003.03 -1440. 90 6672 .39 2284.81 -848.41 -2121. 45 2.78 5949508.68 673768 .57 12511. 66 88.96 166.33 8948.34 9003.60 -1469.33 6705.77 12539. 90 90.55 165.71 8948. 46 9003.72 -1493.47 6734.01 12575. 36 93.36 165.96 8947. 25 9002.51 -1523.69 6769.45 12606. 86 95.56 166.76 8944. 80 9000.06 -1550.63 6800.85 12638. 67 96.53 165.95 8941. 45 8996.71 -1577.76 6832.48 12670. 83 96.52 165.80 8937. 79 8993.05 -1605.02 6864.44 12702. 80 95.65 166.56 8934. 41 8989.67 -1632.24 6896.22 12734. 79 90.88 165.38 8932. 58 8987.84 -1659.51 6928.15 12766. 05 90.00 163.96 8932. 34 8987.60 -1685.83 6959.41 12830. 04 90.00 164.69 8932. 34 8987.60 -1739.51 7023.40 2289.42 -880.76 -2113.22 2293.83 -908.16 -2106.39 2299.74 -942.52 -2097.72 2305.69 -973.04 -2090.32 2312.11 -1003.78 -2082.85 2318.75 -1034.76 -2075.06 2325.94 -1065.63 -2067.46 2333.45 -1096.61 -2059.72 2340.53 -1126.76 -2051.46 2355.86 -1188.36 -2034.17 IV /U lEi tS.t3:i/ W 14k5 :S5 44.4"L5 N 70 16 8.642 W 148 35 44.294 N 70 16 8.344 W 148 35 44.109 N 70 16 8.042 W 148 35 43.912 N 70 16 7.733 W 148 35 43.710 N 70 16 7.433 W 148 35 43.522 N 70 16 7.123 W 148 35 43.323 N 70 16 6.210 W 148 35 42.697 N 70 16 5.873 W 148 35 42.468 N 70 16 5.594 W 148 35 42.274 N 7016 5.300 W 148 35 42.060 N 70 16 4.994 W 148 35 41.841 N 7016 4.692 W 148 35 41:~ N 70 16 4.385 W 148 35 41. N 70 16 4.087 W 148 35 41.161 3.70 5949476.53 673777.56 N 70 16 3.769 W 148 35 40.921 6.04 5949449.30 673785.02 N 70 16 3.499 W 148 35 40.723 7.96 5949415.16 673794.49 N 70 16 3.161 W 148 35 40.470 7.43 5949384.82 673802.61 N 70 16 2.861 W 148 35 40.254 3.96 5949354.27 673810.79 N 70 16 2.559 W 148 35 40.037 0.46 5949323.47 3.60 5949292.79 15.36 5949262.01 5.34 5949232.07 1.14 5949170.88 673819.31 673827.62 673836.08 673845.05 673863.77 673892.00 673916.22 673932.20 N 70 16 2.254 W 148 35 39.809 N 70 16 1.950 W 148 35 39.588 N 70 16 1.646 W 148 35 39.363 N 70 16 1.349 W 148 35 39.122 N 70 16 0.744 W 148 35 38.618 N 70 15 59.829 W 148 35 37.859 N 70 15 59.077 W 148 35 37.205 N 70 15 58.590 W 148 35 36.773 12926.63 90.72 164.00 8931.74 8987.00 -1820.56 7119.99 2382.10 -1281.37 -2008.11 1.03 5949078.52 Last Survey 13006.36 91.03 163.30 8930.52 8985.78 -1886.92 7199.71 2405.55 -1357.86 -1985.66 0.96 5949002.57 TD (Projected) 13058.00 91.03 163.30 8929.59 8984.85 -1929.73 7251.34 2421.72 -1407.32 -1970.83 0.00 5948953.48 Survey Type: Definitive Survey NOTES: CB Gyro MS - (Camera-based gyro multishot --Traditional optically referenced gyro surveys run on wireline -including "level rotor" gyros and Sperry-Sun SU3. Replaces ex-BP "PGMS" model. ) Inc+Trend - (Inclinometer + known azi trend --Inclination only surveys in near-vertical hole-where formation dip and experience enables direction of drift to be predicted. Replaces ex-BP "Inclinometer (azimuth in known quadrant)" model. ) MWD + IFR + MS - (In-field 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) IftUSI Easting (X) IftUSI Surface : 4768 FSL 314 FEL S33 Ti 1 N R14E UM 5950406.37 675869.48 BHL : 3360 FSL 2288 FEL S33 T11 N R14E UM 5948953.48 673932.20 SurveyEditor Ver SP 2.1 Bld( users) 07-14\07-14\07-14C\07-14C Generated 8/18/2009 12:02 PM Page 5 of 5 TREE= 41/8" 5000 Carbon WELLHEAD= GRAY ACTUATOR = KB. ELEV = 55.3' BF. ELEV = 25.7 KOP = 5001' Max Angle - 98.6/12002' Datum MD = 13058' Datum TV D = 8985' I9-5/8" FO COLLARS ~~ 2323.1 13-3/8" CSG, 72#, L80, ID = 12.347" Minimum ID = 3.725" ~ 10569' 4-1/2" XN NIPPLE 07-14 2222' ~-j41/2" X NIPPLE C`-,A S I IFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 3803 6905 3756 5907 27 65 MMG KBG2 SHEA DMY RKP BK 0 0 08/04!09 08/09/09 3995' H T' Hanger /Liner Top Packer 9-5/8" Whipstock ~ 5001' 9-5/8" ¢SV 5023' 5-1 /2" Jet Cut I-I 5600' Tobin Danger lifting threads are . PERFORATION SUMMARY REF LOG: SPERRY ElNR - GR ON 10/14103?? ANGLE AT TOP PERF: 83 @ 11750' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 11750 - 11850 O 08/03/09 2-7/8" 6 12230 - 12400 O 08/03/09 2-7/8" 6 12690 - 12968 O 08/03/09 10431' 4-1 /2" OTIS X NIP, ID = 3.813" 10462' 7" x 41 /2" S-3 PKR 10496' 4-1/2" OT1S X NIP, ID = 3.813" 10569' 4-1 /2" OTIS XN NIP, ID = 3.725" 10582' 41/2", 12.6#, 13-CR, .0152 bpf, ID = 3.958" 10573' 41/2" Hanger / LTP, ID = 4.45" 10599' S" X 41 /2" XO, ID = 3.93" 10707' 7", 26#, L-80, BTCM, 0.0383 bpf, ID = 6.276" PBTD ~-I 12969' ~~ 13056' 4-1/2", 12.6#, L-80, .0152 bpf, ID=3.958" 'fir DATE REV BY COMMENTS DATE REV BY COMMENTS 06/03!79 ORIGINAL COMPLETION 08/01/98 SIDETRACK{07-14A) 11/22/03 CJSlrLH SIDETRACK(07-148)(10/20/03 08!05/08 N7ES SIDETRACK (07-14C) 08/09/09 TLH DRLG HO CORRECTIONS PRUDHOE BAY UNff WELL: 07-14C PERMfT No: 2031420 APINo_ 50-029-20339-03 SEC 33, T11 N, R14E, 511.07' FEL & 313.93' FNL BP Exploration (Alaska) ~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 AT1N: Beth Date BL oei2sios N0.5342 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Color CD Well Job # Log Description C~ 07-14C 09AKA0145 OH MWD/LWD EDIT - 08/01/09 2 1 01-10 ANHY-00104 RST G (~ 08/11/09 1 1 01-29 B6JE-00009 RST - 08/12/09 1 1 ti PLEASE ACKNOWLEDGE RECEIPT 8Y SIGNING AND RETURNING VNt DOPY tAGR I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~-~ ~' ~ $ SEAN PARNELL, GOVERNOR ~).~ "` J ALASSA OII, A1~TD rirA~S ~ 333 W. 7th AVENUE, SUITE 100 COI~TSERQA'I`IO1~T COI~IMISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Robert Tirpack Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-14C BP Exploration (Alaska) Inc. Permit No: 209-053 Surface Location: 511' FNL, 314' FEL, SEC.33, T11N, R14E, UM Bottomhole Location: 1919' FNL, 2288' FEL, SEC. 33, T11N, R14E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit supersedes permit 209-053 previously issued to revise the bottom-hole location of this well This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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). Sincerely, Cathy . Foerster. Commissioner DATED this ~~ day of August, 2009 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/ o encl. STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 Revised 08/03/09, Change BHL -580' 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 well is proposed for: ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 07-14C 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13058' TVD 8985' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028309 Oil Pool FEL, SEC. 33, T11 N, R14E, UM 511 FNL, 314 Top of Productive Horizon: T11 N R14E UM 2632' FEL SEC. 33 542' FNL 8. Land Use Permit: 13. Approximate Spud Date: July 18, 2009 , , , , , Total Depth: 1919' FNL, 2288' FEL, SEC. 33, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 25,250' 4b. Location of Well (State Base Plane Coordinates): Surface: x-675869 y-5950406 Zone-ASP4 10. KB Elevation (Height above GL): 55.6' feet 15. Distance to Nearest Well Within Pool: 930' 16. Deviated Wells: Kickoff Depth: 5000 feet Maximum Hole An le: 99 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3240 Surface: 2360 18. a in Pr r m: ecifi t'o n To - in De th - Bott m u nti f m n .f. or Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-8 BTC-M 722' 4000' 3930' 10722' 8505' 313 sx LiteCrete 168 sx Class'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1903' 10572' 8375' 13058' 8985' 288 sx Class'G' 19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 12500' Total Depth TVD (ft): Plugs (measured): 8978' None Effective Depth MD (ft): 12468' Effective Depth TVD (ft): 8975' Junk (measured): None Casing Length Size Cement Volume MD TVD Conductor /Structural 71' 20" 243 s Ar i e 71' 71' Surface 2665' 13-3/8" 4200 sx Arcticset II 2665' 2 65' Intermediate 10362' - /8" 12 0 sx Class 'G' 1 362' 8573' Pr i n Liner 2652' 3-1/2" x 3-3/16" x 2-7/8" 147 sx Class'G' 9848' - 12500' 8210' - 8978' Perforation Depth MD (ft): 10950' - 12465' Perforation Depth TVD (ft): 8960' - 8975' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: - Date: 22. I hereby certify that the foregoing is true and correct. Contact Garret Staudinger, 564-4242 Printed Name Robert Tirpack Title Engineering Team Leader Prepared By Name/Number: Si nature .~ Phone 564-4166 Date ,~' Terrie Hubble, 564-4628 .Commission Use Onl Permit To Drill Number: 209-053 API Number. 50-029-20339-03-00 Permit A proval See cover letter for Date: .~ I 0 other r uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^ xes ~No Mud Log Req'd: ^Xes ~No HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other. APPROVED BY THE COMMISSION Date 8 -~(,Z ,COMMISSIONER Form 10-401 Revised 12/2005 Sub ~t In Duplicate 0 R G ~ ~ 01 ~r/~ i Well Name: 07-14C Drill and Complete Plan Summary T e of Well service / roducer / in'ector : Producer Surface Location: X=675869.48' Y=5950406.37' As-Built 4768' FSL, 314' FEL, T11 N, R14E, Sec. 33 Target Locations: X=673552.97' Y=5950322.22' Z=9005.5' 07-14C T t 1 4738' FSL, 2632' FEL, T11 N, R14E, Sec. 33 Bottom Hole Location: X =673932.20' Y =5948953.48' Z=8984.85' 3360' FSL, 2288' FEL, T11 N, R14E, Sec. 33 Adam Van Holland Geolo ist 564-4477 Alice Kaminski Prod. En ineer 564-5676 Garret Staudin er Drillin En ineer 564-4242 API NUMBER: TBD Ri Nabors 7ES Estimated Start Date: 7/15/2009 Operatin Days to complete: 23.6 MD: 13058' TVD: 8985' RT/GL: 28.5'/26.8' RTE: 55.3' Well Design: Ivishak Zone 2B Producer 4 ~/z" tbg, 12.6# 13-CR-80 , 7" x 4-~h" packer, 4'/z" L-80 12.6# Liner Ob'ective: Horizontal Producer in Ivishak Zone 26 Directional Plan: Version: Schlumber er P4 KOP: 5000' MD, build 4/100 Maximum Hole An le: 90° Close Approach Wells: Nearest well within Pool: No close approach wells 930' to 07-04A Distance to Nearest Property Line• 25,250' to Unit Boundary S Surface and Anti-collision: Surface Shut in Wells: No wells are required for surface shut-in prior to rig moving on well Close Approach Shut-in Wells: All wells pass Close Approach Anti-Collision Scan 07-14C Permit Application Page 1 • Logging Program: f~J Intermediate Interval Drilling, MWD: GR/Resistivity Open Hole: None Cased Hole: None Production Interval Drilling, MWD: GR, RES, NEU, Azimuthal Density Open Hole: None Cased Hole: None Mud Program: Whi stock Millin Mud Pro erties Density Plastic Yield Point API Fluid MBT (ppg) Viscosity (Ib/100ft2) Loss pH c mis/30min 8.8 15-22 30-40 6 -8 9.0 - 9.5 < 20 8 1/2: Intermediate Hole: LSND Mud Density Plastic Yield Point API Fluid MBT Interval (ppg) Viscosity (Ib/100ft) Loss pH c mis/30min 5000 - 9523 8.8 - 9.2 12 -18 18 -24 < 6.0 9.0 - 10 < 20 9523 -TD TSGR 10.2 16-20 25 - 30 < 6.0 9 - 10 < 20 6 1/8" Production Hole: Flo-Pro Mud Density Plastic Y t API Interval (ppg) Viscosity lb/tl Oftn ( ) Fluid Loss pH MBT c ml/30 min Production 8.5 8 - 15 24 - 30 6 -8 9 - 9.5 < 6 Casin ubin Pro ram: Hole Size Csg/ Tb O.D. WUFt Grade Connection Length Top MDlTVD Btm MD/TVD RTE 8 1 /2" 7" 26 L-80 BTC-M 6722' 4000' / 3930' 10722' / 8505' 6 1 /8" 4 1 /2" 12.6 L-80 I BT-M 2486' 10572' / 8375' 13058' / 8985' Tubin 4'/z" 12.6 13CR-80 VamTo 10572' GL 10572' / 8375' Integrit Testin Test Point Depth Test Type 9 5/ "Surface Casin 20' - 50' in o en hole from window FIT 12.5 Test Point Depth Test Type 7" Intermediate Casin 20' - 50' from 7" shoe FIT 11.0 07-14C Permit Application Page 2 Cement Calculations: Casin Size Intermediate - 7" 26 ppf L-80 BTC-M -Single Stage Basis Lead: Open hole volume. + 40% excess + 1000' liner lap + 200' MD above liner. TOC is TOL Tail: O en hole volume + 40% excess TOC at 1000' above 7" shoe. Wash None S acer 50 bbls of MudPush II wei hted to 10.6 Lead 186 bbls 313 sks 11.0 LiteCRETE cement - 3.33 ft /sk Tail 35 bbls 168 sks 15.8 Class G -1.16 cuft/sk Temp BHST =190° F Casin Size Production Casin - 4 1/2" 12.6 f L-80 IBT-M -Sin le Sta e Basis Tail: O en hole volume + 40% excess + 150' liner la + 200' MD above. liner. TOC at TOL. Wash None 3 acer 30 bbls of MudPush II wei hted to 12.0 Tail 59.5 bbls 245 sks 15.8 Class G w/latex -1.16 Temo BHST = 200° F 07-14C Permit Application Page 3 • Formation Markers (Based on SOR): Est. Formation To s Uncertain Commercial Hydrocarbon Bearin Est. Pore Press. Formation (TVDss) (eet) (Yes/No) (Psi) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells SV3 -3290 40' no SV2 -3511 40' no SVl -3918 40' no UG4 -4448 40' no KOP -4635 UG3 -4693 40' no UGl -5123 40' no WS2 -5735 40' no WSl -5940 40' no CM3 -6123 40' no CM2 -6620 40' no CM1 -7125 40' no THRZ -7592 40' no BHRZ/TJE -7750 40' no TJD -8013 40' no TJC -8090 40' no TJB -8257 40' no TJA -8358 40' no TSGR -8453 20' es TSHU -8484 20' no TSAD -8556 20' es TCGL -8742 20' es BCGL -8813 20' es -3240 si 23SB -8868 20' es 22TS -8925 20' es 22N -8957 20' no 21TS -8972 20' es HOT -8970 20' es TZ1B -9042 20' es BSAD -9113 20' es 07-14C Permit Application Page 4 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Annular preventer will be tested to 2500 psi. Rams will be tested to 3500 psi. The BOP test frequency during the Decomplete will be on a 7 day period, and 14 days during the D&C operations. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • Annular Preventer • Rams • Planned completion fluid: 3240 psi C«~ 8800' TVD, 7.1 ppg EMW (at BCGL, -11,199' MD) 2360 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) 250 / 2500 psi 250 / 3500 psi 8.6 ppg seawater / 6.8 ppg diesel Kick Tolerance /Integrity Testing Summary Table Casing and Interval Casing Test Pressure Maximum Influx Volume Mud Weight Exp Pore Press LOT / FIT 95/$" Casing 3500 psi 67.9 BBLS 10.2 8.8 12.5ppg 8-1/2" (assuming FIT Intermediate 10.8 ppg Interval EMV FIT 7" Casing and 3500 psi Infinite 8.5 7.2 11.Oppg 6-1/8" (assuming at FIT Production least 8.8 ppg Interval EMV FIT 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 disposal 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 and 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 I liquids will be directed to Pad 3. 07-14C Permit Application Page 5 i • 07-14C -Drill and Complete Procedure Summary A. Current Well Status: 1. MIT - OA passed 2000 psi on 9/24/08 2. MIT - IA failed on 4/16/08. Establish LLR rate of 4.7 BPM C~ 1250 psi 3. PPPOT-T & PPPOT-IC passed on 3/30/2008 4. Downhole camera was run on 5/31/2008 and showed collapsed tubing at 9587' MD. Confirmed TxIA communication. 5. Could not get 2" jet swirl nozzle or LDL toolstring (1.6875" OD) past collapsed tubing point. B. Pre-Riq Work: 1. F: Fluid pack the tubing and inner annulus w/ seawater/diesel. 2. E: RU, run STP log in parent well from 9,500' to surface. 3. F: P & A the perforations in the 07-14B wellbore with cement from 12,468' MD up to 9,300' MD. Install tree saver to prevent cement from getting into tree/BPV profile. Ensure that IA and tubing are fluid packed. Perform infectivity test. Bullhead cement from surface into perforations and chase with foam ball. a. CEMENT CALCULATIONS i. 1446' of 2-7/8", 6.16# liner: .0058 bbls/ft = 8.4 bbls ii. 1174' of 3-3/16", 6.2# liner: .0076 bbls/ft = 8.9 bbls iii. 250' of 3.80" cement sheath: .0140 bbls/ft = 3.5 bbls iv. 300' of 9-5/8" csg w/ 5-1 /2" tbg .0671 bbls/ft = 20.2 bbls TOTAL (with 10 bbls excess) = 51 bbls Note: Do not use aggregate in slurry as ID of collapsed tubing is unknown. A squeeze can be done if possible, but it is not necessary to achieve a squeeze pressure. Target TOC at 9,300' MD. 4. S: WOC. Drift for Jet Cutter. Tag Top of cement plug. 5. F: CMIT - T x IA to 2,500 psi for 30 minutes. 6. F: MIT - OA to 2,000 psi for 30 minutes. 7. E: Jet cut the 5-1/2" tubing in the middle of a full joint at 5600' MD. 8. F: CMIT - T x IA to 2,500 psi for 30 minutes. 9. F: Circulate the well to seawater. Freeze protect the IA and tubing with diesel to 2,200'. 10. D: Bleed all casing and annulus pressures to zero psi. 11. W: Function all tubing and casing LDS. Repair and replace as necessary. PPPOT - IC and PPPOT - T. 12. V: Set a BPV. Remove well house and flow line. Level the pad as needed. Provide total well preparation cost on the handover form. C. Riq Operations: 1. MIRU. 2. Pull BPV. Circulate out freeze protection with 9.0 ppg brine and condition fluid as needed. Set a TWC-and test from below to 2000 psi and above to 3500 psi. 3. Nipple down tree. Nipple up and test BOPE to 3500 psi. Pull TWC. 4. RU and pull the 5-1/2", 17#, L-80, 8 rd A-B Modified plastic coated tubing from the pre-rig jet cut at 5600' MD (steam wellhead prior to pulling hanger). Spool up the control line and count metal Hydril control line clamps (26 listed on tally) and stainless steel bands (5 listed on tally). Test the lower set of pipe rams. 5. PU 4" drillpipe and 9-5/8" clean-out assembly and clean-out well to the top of the tubing stub 5600' MD. Note: Do not run 9-5/8" casing scrapers due to the 9-5/8" FO collars at 2323' and 2452'. 6. With E-line, run a 9-5/8" EZSV for 47# casing. Set the EZSV at 5020' MD. Rig down E-line. 7. Pressure test the EZSV to 3500 psi for 10 minutes. 8. PU 9-5/8" whipstock, bottom trip anchor and 8.5" window milling assembly (to include full gauge string mills). 9. Hang weight of 9-5/8" whipstock assembly and set storm packer just below the wellhead. 10. Remove the existing Gray Gen 2 Tubing Spool. Change out the 9-5/8" pack-offs per Cameron. Install the New Standard Tubing Spool. 07-14C Permit Application Page 6 • i 11. RIH to the top of the EZSV. Orient and set the whipstock. Swap the well. over to 9.0 ppg fresh water LSND milling fluid. 12. Mill a window in the 9-5/8" casing from 5000' MD' plus 20' of formation from mid-window. 13. Perform an FIT to 12.5 ppg (a minimum FIT of 10.8 ppg is required to satisfy kick tolerance requirments). POOH for drilling BHA. 14. MU an 8-1/2" drilling BHA with DIR/GR/RES/PWD and ghost reamer behind the bit. RIH. Kick off and drill 8-1/2" intermediate interval to 7" casing point at the top of the Sag River. NOTE: The mud will need to be weighted up with spike fluid. Plan for one weight-up with the spike fluid to 10.2 ppg over several circulations prior to drilling the HRZ and Kingak shale. 15. Change to 7" casing rams and test. 16. Run and cement a 7", 26#, L-80, BTC-M drilling liner throughout the 8-1/2" hole and back into the 9- 5/8". Set TOL to cover cretaceous (cretaceous top at top SV1). Displace cement with mud and set hanger /liner top packer. POOH. 17. MU a 6-1/8" BHA with DIR/GR/RES/DEN/NEU and RIH to the 7" landing collar. Pressure test liner and casing to 3500 psi for 30 min. Drill out the shoe plus 20' of formation while swapping over to new Flo-Pro drilling fluid. Perform an FIT to 11.0 ppg. 18. Drill ahead per plan to the base of the conglomerates. POOH for bit and BHA change. 19. MU a 6-1/8" BHA with DIR/GR/RES/DEN/NEU and RIH. Verify with town geo to MAD pass build interval. Drill ahead the Ivishak Z2 horizontal per plan to TD. 20. CBU, short trip, circulate until clean and spot a liner running pill. MAD Pass where required. POOH. 21. Run and cement a 4-1 /2", 12.6#, L-80, IBT-M liner from TD to 150' inside the 7" shoe. Set the liner top packer. 22. Run on DP --600' of 2-7/8" 2906 PJ HMX, 6 spf perf guns and shoot over balanced. Fire guns, POOH. LD remaining DP 23. RU and run 4-1/2", 12.6#, 13Cr-80, Vam Top completion, tying into the 4-1/2" liner top. 24. Reverse circulate to spot corrosion inhibited seawater. 25. Drop ball and rod. Set packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. Shear DCK valve. 26. Set and test a TWC. 27. ND BOPE. NU and test the tree to 5,000 psi. Pull TWC. 28. Freeze protect the well with diesel to 2200' MD. Set a BPV 29. RDMO. D. Post-Rig Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from `XN' nipple below the new production packer. 2. Install gas lift valves. 3. Install wellhouse and flowlines. (S-Riser work will be required.) 07-14C Permit Application Page 7 • • Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE 1. Directional Control: Ensure that directional control is maintained and to not fall behind the planned curve. Important to stay on plan in the intermediate section to avoid approaching a Kingak fault to the east. II. Lost Circulation: Overall risk of significant lost circulation is considered low for this well due to no anticipated fault crossings. DS 7 wells have not encountered a lot of LC issues in the past. Follow the recommended drilling practices, and the lost circulation decision tree. III. Kick Tolerance /integrity Testing: The 9 5/8" casing most likely will not have cement behind casing at the window depth. The 9-5/8" casing shoe was cemented with a 50 bbls tack job. The 9-5/8" x 13-3/8" annulus was cemented through the FO collars. Casing will be tested to 3500 psi before drilling out. An FIT to 12.5 will be performed after drilling 20-50' of new formation after milling out the 9 /$" casing. The 7" liner will be cemented to the TOL. A FIT to 11.0 will be performed after drilling 20-50' of new formation after drilling out 7" casing shoe Kick Tolerance /Integrity Testing Summary Table Casing and Interval Casing Test Pressure Maximum Influx Volume Mud Weight Exp Pore Press LOT / FIT 95/8" Casing and 3500 psi 67.9 BBLS 10.2 8.8 12.5ppg 8-1 /2" (assuming FIT Intermediate 10.8 ppg Interval EMV FIT 7" Casing and 3500 psi Infinite 8.5 7.2 11.Oppg 6-1/8" (assuming at FIT Production least 8.8 ppg Interval EMV FIT IV. Hydrogen Sulfide DS 7 is not an H2S site. Most wells on DS 7 are typically <30 ppm H2S levels. Standard H2S precautions will be followed at all times. H2S Summa Table WeII Name H S Level m Date of Readin #1 Closest SHL Well H2S Level 07-29D n/a n/a #2 Closest SHL Well H2S Level 07-28AL1 28 1/4/2008 #1 Closest BHL Well H2S Level 07-03A 16 4/10/2008 #2 Closest BHL Well H2S Level 07-04A 16 4/17/2008 Max. Recorded H2S on Pad/Facilit 07-13A 150 7/21/1993 V. Faults No fault crossings are expected. There is a low risk of lost circulation for this well. VI. Anti-Collision Issues All wells have passed the major risk scan. Reference the Anti-collision report in the directional plan for a full list of offset well paths. CONSULT THE DS 7 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 07-14C Permit Application Page 8 by ~" _ _ _ _ _ ..... _ Schlumberger V~V / --1 ~Ftr JUfV@~/ Re(JVft Report Date: August 3, 2009 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 17.300° Field: Prudhoe Bay Unit - EOA Vertical Section Origin: N 0.000 ft, E 0.000 ft SVucture 1 Slot: DS-07 107-14 ND Reference Datum: Rotary Table Well: 07-14 ND Reference Elevation: 55.26 ft relative to MSL Borehole: 07-14C Sea Bed 1 Ground Level Elevation: 26.56 ft relative to MSL UWIIAPI#: 500292033903 Magnetic Declination: 22.619° Survey Name 1 Date: 07-14C /July 27, 2009 Total Field Strength: 57669.076 nT Tort 1 AHD I DDI 1 ERD ratio: 396.875° 17251.34 ft / 6.619 10.803 Magnetic Dip: 80.921 ° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: July 27, 2009 location LaULong: N 701612.434, W 148 34 39.412 Magnetic Declination Madel: BGGM 2009 Location Grid NIE YIX: N 5950406.370 ftUS, E 675869.480 ftUS North Reference: True North Grid Convergence Angle: +1.33891540° Total Corc Mag North •> True North: +22.619° Grid Scale Factor: 0.99993514 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Trus Section Departure True North True North ft de de ft ft ft ft 8 ft ft de 1100 ft ftUS ftUS Yro1@C[ed-Up u.uu u.vu v.uu -ao.co v.uv v.vu WRP 33.26 0.00 0.00 -22.00 33.26 0.00 SCI DRILNG 6/11/79 g1.26 0.00 0.00 36.00 91.26 0.00 1150GYM3-121 GYRO 191.26 0.00 0.00 136.00 191.26 0.00 291.26 0.00 0.00 236.00 291.26 0.00 391.26 0.00 0.00 336.00 391.26 0.00 491.26 0.00 0.00 436.00 491.26 0.00 591.26 0.00 0.00 536.00 591.26 0.00 691.26 0.00 0.00 636.00 691.26 0.00 791.26 0.00 0.00 736.00 791.26 0.00 891.26 0.00 0.00 836.00 891.26 0.00 991.26 0.00 0.00 936.00 991.26 0.00 1091.26 0.00 0.00 1036.00 1091.26 0.00 1191.26 0.00 0.00 1136.00 1191.26 0.00 1291.26 0.00 0.00 1236.00 1291.26 0.00 1391.26 0.00 0.00 1336.00 1391.26 0.00 1491.26 0.00 0.00 1436.00 1491.26 0.00 1591.26 0.00 0.00 1536.00 1591.26 0.00 1691.26 0.00 0.00 1636.00 1691.26 0.00 1791.26 0.00 0.00 1736.00 1791.26 0.00 1891.26 0.00 0.00 1836.00 1891.26 0.00 1991.26 0.00 0.00 1936.00 1991.26 0.00 2091.26 0.00 0.00 2036.00 2091.26 0.00 2191.26 0.00 0.00 2136.00 2191.26 0.00 2291.26 0.50 149.00 2236.00 2291.26 -0.29 ~.~~ ~.~~ .,.~., ~.,,~ ,..,,,. ,.~.,.,~,,...,.. ................ .. ... ... .~.-.,,. .. ,-..,,,T.,.,.~,~ 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434. W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 3~ 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 3 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.00 0.00 0.00 0.00 0.00 5950406.37 675869.48 N 70 16 12.434 W 148 34 39.412 0.44 0.44 -0.37 0.22 0.50 5950406.00 675869.71 N 70 16 12.430 W 148 34 39.405 SurveyEditor Ver SP 2.1 Bld( users) 07-14\07-14\07-14C\07-14C Generated 8/3/2009 10:44 AM Page 1 of 5 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 1100 ft ftUS ftUS 2391.26 0.00 0.00 2336.00 2391.26 -0.58 0.87 0.87 -0.75 0.45 0.50 5950405.63 675869.95 N 70 16 12.426 W 148 34 39.399 2491.26 0.00 0.00 2436.00 2491.26 -0.58 0.87 0.87 -0.75 0.45 0.00 5950405.63 675869.95 N 70 16 12.426 W 148 34 39.399 2591.26 0.50 140.00 2536.00 2591.26 -0.82 1.31 1.31 -1.08 0.73 0.50 5950405.31 675870.23 N 70 16 12.423 W 148 34 39.390 2691.26 0.00 0.00 2635.99 2691.25 -1.05 1.75 1.74 -1.42 1.01 0.50 5950404.98 675870.52 N 70 16 12.420 W 148 34 39.382 2791.26 1.00 14.00 2735.99 2791.25 -0.18 2.62 1.35 -0.57 1.22 1.00 5950405.83 675870.71 N 70 16 12.428 W 148 34 39.376 2891.26 6.50 7.00 2835.74 2891.00 6.26 9.15 6.27 5.90 2.12 5.51 5950412.32 675871.46 N 70 16 12.492 W 148 34 39.350 2991.26 11.00 29.00 2934.57 2989.83 21.19 24.19 21.22 19.87 7.44 5.53 5950426.41 675876.46 N 70 16 12.629 W 148 34 39.195 3091.26 12.50 28.50 3032.48 3087.74 41.15 44.55 41.48 37.73 17.23 1.50 5950444.49 675885.82 N 70 16 12.805 W 148 34 38.910 3191.26 15.00 16.50 3129.62 3184.88 64.71 68.24 65.10 59.66 26.07 3.78 5950466.61 675894.15 N 70 16 13.020 W 148 34 38.653 3291.26 18.00 18.00 3225.49 3280.75 93.11 96.63 93.38 86.76 34.53 3.03 5950493.91 675901.97 N 70 16 13.287 W 148 34 38.407 3391.26 18.00 23.50 3320.61 3375.87 123.92 127.51 124.25 115.63 45.46 1.70 5950523.02 675912.23 N 70 16 13.571 W 148 34 3 3491.26 20.00 25.00 3415.15 3470.41 156.23 160.07 156.77 145.30 58.85 2.06 5950553.00 675924.92 N 70 16 13.863 W 148 34 3 3591.26 22.50 24.00 3508.35 3563.61 192.19 196.31 192.98 178.29 73.86 2.53 5950586.32 675939.15 N 70 16 14.187 W 148 34 37. 1 3691.26 24.25 25.50 3600.14 3655.40 231.52 235.98 232.63 214.30 90.49 1.85 5950622.72 675954.93 N 70 16 14.541 W 148 34 36.777 3791.26 26.50 28.00 3690.49 3745.75 273.77 278.82 275.38 252.54 109.81 2.49 5950661.39 675973.35 N 70 16 14.917 W 148 34 36.215 3891.26 29.00 26.00 3778.98 3834.24 319.67 325.38 321.86 294.04 130.91 2.67 5950703.37 675993.48 N 70 16 15.326 W 148 34 35.601 3991.26 31.25 25.00 3865.47 3920.73 369.34 375.56 372.03 339.34 152.50 2.31 5950749.16 676014.00 N 70 16 15.771 W 148 34 34.972 4091.26 34.00 27.00 3949.69 4004.95 422.61 429.47 425.91 387.77 176.16 2.95 5950798.12 676036.52 N 70 16 16.247 W 148 34 34.283 4191.26 35.50 28.00 4031.85 4087.11 478.71 486.46 482.83 438.32 202.49 1.60 5950849.27 676061.66 N 70 16 16.745 W 148 34 33.517 4291.26 39.50 26.50 4111.17 4166.43 538.66 547.33 543.65 492.44 230.32 4.10 5950904.03 676088.22 N 70 16 17.277 W 148 34 32.706 4391.26 42.50 24.50 4186.63 4241.89 603.58 612.92 609.24 551.66 258.53 3.27 5950963.88 676115.03 N 70 16 17.859 W 148 34 31.885 4491.26 43.50 21.00 4259.78 4315.04 671.46 681.11 677.36 614.54 284.88 2.59 5951027.36 676139.90 N 70 16 18.478 W 148 34 31.118 4591.26 43.00 17.00 4332.63 4387.89 739.91 749.61 745.52 679.30 307.19 2.79 5951092.61 676160.69 N 70 16 19.115 W 148 34 30.468 4691.26 43.50 18.00 4405.47 4460.73 808.43 818.13 813.59 744.64 327.79 0.85 5951158.42 676179.76 N 70 16 19.757 W 148 34 29.868 4791.26 42.50 17.00 4478.60 4533.86 876.63 886.33 881.42 809.68 348.30 1.21 5951223.91 676198.75 N 70 16 20.397 W 148 34 29.271 4891.26 43.00 16.50 4552.04 4607.30 944.50 954.21 948.89 874.68 367.87 0.60 5951289.35 676216.78 N 70 16 21.036 W 148 34 28.702 Tie-In Survey 4991.26 42.50 17.00 4625.47 4680.73 1012.38 1022.09 1016.41 939.68 387.43 0.60 5951354.78 676234.82 N 70 16 21.675 W 148 34 28.132 TOW (Blind) 5001.00 42.57 16.93 4632.64 4687.90 1018.96 1028.67 1022.97 945.98 389.35 0.87 5951361.12 676236.59 N 70 16 21.737 W 148 34 28.076 BOW (Blind) 5018.00 42.00 14.00 4645.22 4700.48 1030.39 1040.11 1034.32 957.00 392.40 12.07 5951372.21 676239.39 N 70 16 21.846 W 148 34 27 7 Blind 5058.00 42.00 17.00 4674.95 4730.21 1057.14 1066.87 1060.90 982.78 399.55 5.02 5951398.15 676245.93 N 70 16 22.099 W 148 34 2 Inc+Trend 5085.10 42.31 16.50 4695.04 4750.30 1075.33 1085.06 1079.01 1000.20 404.79 1.69 5951415.69 676250.76 N 70 16 22.271 W 148 34 27.626 5115.95 42.17 16.60 4717.88 4773.14 1096.06 1105.80 1099.65 1020.08 410.70 0.50 5951435.70 676256.21 N 70 16 22.466 W 148 34 27.454 5148.98 42.25 16.80 4742.35 4797.61 1118.25 1127.99 1121.75 1041.33 417.08 0.47 5951457.10 676262.08 N 70 16 22.675 W 148 34 27.269 5244.17 40.97 17.00 4813.52 4868.78 1181.46 1191.20 1184.74 1101.81 435.45 1.35 5951517.98 676279.04 N 70 16 23.270 W 148 34 26.734 5339.34 41.69 5.00 4885.09 4940.35 1243.68 1253.92 1246.33 1163.28 447.35 8.35 5951579.71 676289.50 N 70 16 23.874 W 148 34 26.387 5434.93 41.43 353.00 4956.74 5012.00 1303.66 1317.20 1305.11 1226.44 446.26 8.32 5951642.82 676286.94 N 70 16 24.496 W 148 34 26.418 MWD+IFR+MS 5530.70 41.15 341.34 5028.80 5084.06 1358.13 1380.27 1358.45 1287.83 432.30 8.03 5951703.87 676271.54 N 70 16 25.099 W 148 34 26.825 5626.54 41.90 335.55 5100.58 5155.84 1407.55 1443.78 1407.58 1346.86 408.96 4.08 5951762.33 676246.83 N 70 16 25.680 W 148 34 27.505 5721.87 44.18 329.38 5170.28 5225.54 1453.58 1508.81 1454.66 1404.46 378.84 5.02 5951819.21 676215.38 N 70 16 26.246 W 148 34 28.381 5817.75 45.54 320.87 5238.31 5293.57 1494.93 1576.37 1498.92 1459.81 340.20 6.42 5951873.63 676175.45 N 70 16 26.791 W 148 34 29.506 5913.07 47.64 316.37 5303.83 5359.09 1530.87 1645.60 1540.11 1511.71 294.41 4.08 5951924.44 676128.47 N 70 16 27.301 W 148 34 30.839 6009.95 51.45 313.21 5366.68 5421.94 1564.83 1719.29 1582.21 1563.58 242.07 4.65 5951975.07 676074.94 N 70 16 27.811 W 148 34 32.363 SurveyEditor Ver SP 2.1 Bld( users) 07-14\07-14\07-14C\07-14C Generated 8/3/2009 10:44 AM Page 2 of 5 Comments Measured Inclination Azimuth Sub•Sea ND ND 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 til ua. is 6198.23 6291.56 6382.56 6473.77 6569.98 6665.87 6759.72 6853.76 6945.96 7039.56 7128.79 7225.01 7317.04 7409.74 7502.03 7595.34 7690.83 7785.93 7882.26 7977.89 8070.50 8163.70 8256.54 8354.05 8449.49 8543.77 8636.26 8730.60 8823.27 8916.87 9010.41 9102.97 SZ.UZ 51.98 53.59 53.00 53.69 58.96 62.11 64.83 65.19 65.36 65.10 63.60 61.16 58.75 57.06 57.90 59.52 57.72 55.11 54.69 54.16 53.86 53.17 54.57 58.46 60.67 60.21 59.42 57.27 54.55 51.82 47.50 43.53 3"I Z.4U 312.93 312.78 312.55 311.76 305.60 301.26 297.16 293.45 287.31 279.93 275.81 270.55 265.20 259.94 253.84 247.42 241.43 236.00 234.29 233.17 233.30 231.71 232.72 238.25 245.89 245.75 244.83 244.02 240.86 237.94 236.48 234.95 9194.33 39.39 230.16 9285.95 35.30 226.22 9377.71 32.01 223.24 9469.53 31.52 219.22 9563.80 32.46 211.96 9659.33 31.29 207.87 9754.70 30.69 204.65 9849.57 28.75 204.71 9945.18 29.61 201.96 10039.99 31.24 202.44 94ZU. V U 5482.95 5539.40 5593.79 5648.24 5701.60 5748.78 5790.71 5830.45 5869.04 5908.30 5946.94 5991.57 6037.67 6086.95 6136.59 6185.09 6234.85 6287.48 6342.87 6398.50 6452.93 6508.35 6563.09 6616.90 6665.30 6711.81 6758.31 6807.82 6859.77 6915.86 6976.40 7041.24 7109.71 7182.55 7258.92 7337.00 7416.98 0401.L0 l~`J/.LO I /`J4.OU IOLO.Yy IO IY.I l 5538.21 1628.50 1867.39 1669.47 1664.13 5594.66 1660.57 1941.71 1716.50 1714.68 5649.05 1691.82 2014.67 1764.31 1764.13 5703.50 1722.57 2087.84 1813.46 1813.23 5756.86 1751.60 2167.85 1865.36 1863.11 5804.04 1774.74 2251.32 1915.84 1909.04 5845.97 1792.03 2335.27 1964.02 1949.97 5885.71 5924.30 5963.56 6002.20 6046.83 6092.93 6142.21 6191.85 6240.35 6290.11 6342.74 6398.13 6453.76 6508.19 6563.61 6618.35 6672.16 6720.56 6767.07 6813.57 6863.08 6915.03 6971.12 7031.66 7096.50 7164.97 7237.81 7314.18 7392.26 7472.24 1803.89 2420.50 2010.67 1986.39 1808.38 2504.23 2052.92 2015.54 1802.94 2589.20 2089.66 2035.54 1789.78 2669.63 2119.74 2046.56 1769.04 2754.87 2148.03 2051.34 1742.60 1709.80 1670.42 1622.81 1567.42 1508.08 1445.85 1383.27 1322.60 1261.38 1199.90 1136.08 1077.77 1023.45 969.95 915.32 861.23 805.67 751.01 699.30 650.01 602.39 557.30 513.14 465.79 2834.51 2913.02 2990.82 3070.53 3152.03 3231.23 3310.04 3387.82 3462.76 3537.69 3612.67 3693.96 3776.21 3858.22 3938.17 4018.47 4095.20 4170.12 4241.40 4307.42 4367.88 4423.43 4474.27 4522.59 4572.48 7498.11 7553. 37 416.60 4622. 91 7579. 87 7635. 13 368.11 4672. 01 7662. 26 7717. 52 321.47 4719. 04 7745. 74 7801. 00 275.12 4765. 65 7827. 49 7882 .75 227.28 4813. 66 2170.22 2187.72 2200.13 2206.98 2208.23 2204.45 2198.55 2193.56 2190.71 2189.47 2190.41 2199.03 2219.94 2248.61 2278.38 2309.58 2339.17 2366.48 2391.83 2415.35 2435.23 2450.66 2462.82 2472.38 2478.32 2480.43 2480.32 2479.81 2479.09 2478.32 IOO.~J 133.35 78.87 25.22 -29.02 -91.54 -161.21 -234.48 -311.53 -389.98 -472.50 -552.15 -637.22 2048.43 -716.79 2038.31 -794.62 2020.66 -870.35 1994.19 -945.50 1959.06 -1018.99 1918.00 -1086.68 1872.96 -1151.35 1826.95 -1214.06 1782.10 -1274.09 1736.50 -1333.54 1690.56 -1392.81 1644.59 -1459.81 1606.15 -1532.46 1572.56 -1607.27 1539.14 -1679.90 1504.48 -1752.33 1469.01 -1820.37 1430.91 -1884.86 1392.33 -1944.80 1355.17 -1999.36 1318.50 -2047.41 1281.54 -2088.87 1245.47 -2124.68 1209.14 -2156.53 1168.57 -2185.52 1124.89 -2210.69 1080.87 -2232.42 1038.13 -2252.06 995.34 -2270.50 950.89 -2288.65 U.00 VSVL VLY.O-/ O/OV IO.OL IV !V IV LO.J IY YV IYp JY JJ..7V.7 0.40 5952073.05 675963.91 N 70 16 28.800 W 148 34 35.529 1.73 5952122.31 675908.26 N 70 16 29.298 W 148 34 37.115 0.68 5952170.49 675853.48 N 70 16 29.784 W 148 34 38.677 1.03 5952218.31 675798.10 N 70 16 30.267 W 148 34 40.257 7.64 5952266.71 675734.44 N 70 16 30.757 W 148 34 42.077 5.13 5952311.00 675663.72 N 70 16 31.209 W 148 34 44.106 4.87 5952350.20 675589.51 N 70 16 31.612 W 148 34 46.239 3.60 5952384.81 675511.65 N 70 16 31.970 W 148 34 48.483 6.05 5952412.11 675432.54 N 70 16 32.256 W 148 34 50.767 7.16 5952430.17 675349.58 N 70 16 32.453 W 148 34 53.170 4.49 5952439.34 675269.70 N 70 16 32.561 W 148 34 5~ 5.47 5952442.12 675184.54 N 70 16 32.608 W 148 34 5 5.67 5952437.35 675105.08 N 70 16 32.580 W 148 35 0.283 5.14 5952425.42 675027.51 N 70 16 32.480 W 148 35 2.550 5.65 5952406.00 674952.22 N 70 16 32.306 W 148 35 4.755 6.13 5952377.80 674877.71 N 70 16 32.046 W 148 35 6.943 5.68 5952340.96 674805.06 N 70 16 31.700 W 148 35 9.083 5.49 5952298.33 674738.35 N 70 16 31.296 W 148 35 11.054 1.52 5952251.80 674674.76 N 70 16 30.853 W 148 35 12.936 1.10 5952204.34 674613.14 N 70 16 30.401 W 148 35 14.762 0.34 5952158.10 674554.18 N 70 16 29.960 W 148 35 16.510 1.56 5952111.12 674495.82 N 70 16 29.511 W 148 35 18.241 1.75 5952063.81 674437.65 N 70 16 29.059 W 148 35 19.966 6.19 5952016.29 674371.74 N 70 16 28.607 W 148 35 21.917 7.28 5951976.17 674300.01 N 70 16 28.229 W 148 35 24.032 0.50 5951940.84 674226.01 N 70 16 27.898 W 148 35 26.210 1.21 5951905.74 674154.19 N 70 16 27.569 W 148 35 28.324 2.39 5951869.40 674082.59 N 70 16 27.228 W 148 35 3 4.07 5951832.35 674015.41 N 70 16 26.879 W 148 35 3 3.84 5951792.75 673951.82 N 70 16 26.504 W 148 35 3 . 4.77 5951752.79 673892.81 N 70 16 26.125 W 148 35 36.036 4.45 5951714.36 673839.13 N 70 16 25.759 W 148 35 37.625 5.71 5951676.59 673791.96 N 70 16 25.398 W 148 35 39.023 5.17 5951638.67 673751.38 N 70 16 25.035 W 148 35 40.230 4.01 5951601.78 673716.42 N 70 16 24.680 W 148 35 41.273 2.37 5951564.72 673685.43 N 70 16 24.323 W 148 35 42.200 4.20 5951523.48 673657.40 N 70 16 23.924 W 148 35 43.043 2.57 5951479.22 673633.26 N 70 16 23.494 W 148 35 43.776 1.85 5951434.71 673612.57 N 70 16 23.061 W 148 35 44.408 2.05 5951391.53 673593.93 N 70 16 22.640 W 148 35 44.979 1.67 5951348.32 673576.49 N 70 16 22.219 W 148 35 45.516 1.74 5951303.46 673559.39 N 70 16 21.782 W 148 35 46.044 SurveyEditor Ver SP 2.1 Bld( users) 07-14\07-14\07-14C\07-14C Generated 8/3/2009 10:44 AM Page 3 of 5 Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Tnre Section Departure True North True North ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS 7" @ 10709'md 10135.40 10231.00 10325.64 10421.19 10516.75 10612.79 10646.13 10714.89 10745.15 10776.49 10808.65 10838.98 10869.04 10900.97 10931.38 10962.59 10994.24 11022.72 11054.58 11085.53 11114.93 11145.62 11176.35 11205.96 11237.48 11267.89 11297.28 11328.83 11359.92 11391.40 11423.19 11455.19 11486.89 11518.88 11550.82 11581.55 11613.63 11645.31 11709.34 11771.78 11806.12 11837.38 32. 33 201. 79 7908 .59 7963. 85 177 .21 30. 71 202. 78 7990 .08 8045. 34 127 .42 29. 84 203. 49 8071 .82 8127. 08 79 .95 29. 35 202. 82 8154 .90 8210. 16 33 .01 27. 81 201. 90 8238 .81 8294. 07 -12 .52 26. 04 202. 10 8324 .44 8379. 70 -55 .86 25. 53 201. 68 8354 .46 8409. 72 -70 .32 24. 34 201. 68 8416 .81 8472. 07 -99 .22 25. 21 197. 64 8444 .29 8499. 55 -111 .88 27. 42 191. 67 8472 .38 8527. 64 -125 .74 28. 95 185. 92 8500 .73 8555. 99 -140 .75 31. 63 181. 28 8526 .92 8582. 18 -155 .59 34. 41 177. 99 8552 .13 8607. 39 -171 .19 38. 37 175. 44 8577 .83 8633. 09 -188 .91 41. 92 174. 91 8601 .07 8656. 33 -207 .07 42. 65 174. 20 8624 .16 8679. 42 -226 .43 42. 51 173. 03 8647 .47 8702. 73 -246 .04 42. 59 173 .02 8668 .45 8723. 71 -263 .60 42. 40 172 .90 8691 .94 8747. 20 -283 .21 42. 36 172 .60 8714 .80 8770. 06 -302 .18 42.45 42.32 45.71 48.03 50.82 53.90 57.02 59.87 62.08 66.04 69.61 73.08 76.46 79.60 82.60 82.58 82.35 82.29 82.31 83.13 88.60 89.60 171.79 172.13 170.45 169.62 169.19 168.19 168.04 168.73 170.00 168.43 168.50 168.94 166.12 166.00 166.45 165.87 165.53 166.19 166.31 166.49 166.23 165.57 8736.51 8759.18 8781.28 8801.52 8822.02 8840.59 8857.25 8873.76 8888.84 8902.61 8914.61 8924.84 8933.17 8939.80 8944.74 8948.71 8952.91 8957.15 8965.73 8973.64 8976.11 8976.60 8791.77 8814.44 8836.54 8856.78 8877.28 8895.85 8912.51 8929.02 8944.10 8957.87 8969.87 8980.10 8988.43 8995.06 9000.00 9003.97 9008.17 9012.41 9020.99 9028.90 9031.37 9031.86 -320.14 -338.83 -358.02 -377.22 -398.38 -419.51 -440.65 -464.18 -488.20 -513.16 -538.95 -565.57 -592.11 -618.86 -645.88 -671.97 -699.05 -725.84 -780.20 -833.35 -862.71 -889.39 4863.91 4913.89 4961.60 5008.79 5054.50 5097.99 5112.49 5141.48 5154.16 5168.04 5183.22 5198.51 5214.88 5233.82 5253.43 5274.42 5295.84 5315.10 5336.62 5357.48 5377.31 5398.00 5419.34 5440.95 5464.89 5488.97 5513.17 5540.06 5567.24 5595.54 5624.98 5655.29 5685.87 5717.16 5748.71 5779.19 5810.99 5842.39 5905.84 5967.78 6002.01 6033.27 2478.44 2479.70 2482.56 2486.31 2490.16 2494.32 2495.84 2499.04 2500.08 2500.08 2498.62 2495.86 2491.91 2486.53 2480.61 2474.22 2467.53 2461.47 2454.84 2448.50 2442.44 2436.19 2429.66 2422.79 2415.12 2407.34 2399.51 2391.19 2383.51 2375.73 2367.61 2359.73 2351.53 2342.75 2334.38 2326.64 2318.71 2311.37 2298.21 2287.14 2281.69 2276.92 904.33 -2307.56 858.08 -2326.50 814.21 -2345.25 770.82 -2363.80 728.55 -2381.20 688.23 -2397.49 674.77 -2402.90 647.83 -2413.61 635.90 -2417.86 622.46 -2421.35 607.47 -2423.65 592.21 -2424.58 575.84 -2424.46 556.93 -2423.36 537.40 -2421.70 516.50 -2419.71 495.21 -2417.33 476.10 -2414.99 454.74 -2412.35 434.04 -2409.72 414.40 -2407.03 393.91 -2404.13 372.81 -2400.89 351.53 -2397.15 328.00 -2392.75 304.39 -2388.02 280.71 -2383.03 254.38 -2377.62 227.66 -2372.61 199.86 -2367.31 171.02 -2361.42 141.29 -2355.49 111.43 -2348.89 81.07 -2341.35 50.42 -2333.84 20.83 -2326.55 -9.99 -2318.69 -40.43 -2311.02 -102.06 -2295.94 -162.26 -2281.38 -195.54 -2273.30 -225.85 -2265.69 1.20 5951256.48 673541.57 N 70 16 21.324 W 148 35 46.594 1.78 5951209.80 673523.72 N 70 16 20.869 W 148 35 47.145 0.99 5951165.50 673506.01 N 70 16 20.438 W 148 35 47.690 0.62 5951121.70 673488.47 N 70 16 20.011 W 148 35 48.230 1.68 5951079.03 673472.07 N 70 16 19.595 W 148 35 48.736 1.85 5951038.35 673456.72 N 70 16 19.199 W 148 35 49.210 1.62 5951024.77 673451.63 N 70 16 19.066 W 148 35 49.368 1.73 5950997.59 673441.56 N 70 16 18.801 W 148 35 49.679 6.29 5950985.56 673437.58 N 70 16 18.684 W 148 35 49.803 10.99 5950972,05 673434.41 N 70 16 18.552 W 148 35 49.904 9.69 5950957.00 673432.46 N 70 16 18.404 W 148 35 4~ 11.73 5950941.73 673431.88 N 70 16 18.254 W 148 35 4 11.00 5950925.36 673432.39 N 70 16 18.093 W 148 35 49.9 4 13.27 5950906.49 673433.94 N 70 16 17.907 W 148 35 49.962 11.73 5950887.00 673436.04 N 70 16 17.715 W 148 35 49.914 2.80 5950866.15 673438.52 N 70 16 17.510 W 148 35 49.856 2.54 5950844.94 673441.40 N 70 16 17.300 W 148 35 49.786 0.28 5950825.88 673444.19 N 70 16 17.112 W 148 35 49.718 0.65 5950804.59 673447.32 N 70 16 16.902 W 148 35 49.641 0.67 5950783.96 673450.44 N 70 16 16.699 W 148 35 49.564 1.88 5950764.39 673453.59 N 70 16 16.506 W 148 35 49.485 0.86 5950743.98 673456.96 N 70 16 16.304 W 148 35 49.401 11.67 5950722.96 673460.69 N 70 16 16.097 W 148 35 49.306 8.10 5950701.78 673464.93 N 70 16 15.887 W 148 35 49.197 8.91 5950678.36 673469.88 N 70 16 15.656 W 148 35 49.069 10.46 5950654.87 673475.16 N 70 16 15.424 W 148 35 48.931 10.62 5950631.30 673480.70 N 70 16 15.191 W 148 35 48.786 9.22 5950605.11 673486.72 N 70 16 14.932 W 148 35 48.628 7.96 5950578.52 673492.36 N 70 16 14.669 W 148 35 4 13.35 5950550.85 673498.31 N 70 16 14.396 W 148 35 4 11.23 5950522.16 673504.86 N 70 16 14.112 W 148 35 48.156 10.92 5950492.58 673511.48 N 70 16 13.820 W 148 35 47.983 13.69 5950462.88 673518.79 N 70 16 13.526 W 148 35 47.790 9.82 5950432.70 673527.03 N 70 16 13.227 W 148 35 47.570 9.50 5950402.24 673535.26 N 70 16 12.926 W 148 35 47.351 1.87 5950372.84 673543.24 N 70 16 12.635 W 148 35 47.139 1.27 5950342.21 673551.81 N 70 16 12.332 W 148 35 46.910 2.07 5950311.96 673560.19 N 70 16 12.033 W 148 35 46.686 0.19 5950250.70 673576.71 N 70 16 11.426 W 148 35 46.247 1.34 5950190.86 673592.67 N 70 16 10.834 W 148 35 45.822 15.95 5950157.79 673601.52 N 70 16 10.507 W 148 35 45.587 3.83 5950127.66 673609.84 N 70 16 10.209 W 148 35 45.365 SurveyEditor Ver SP 2.1 Bld( users) 07-14\07-14\07-14C\07-14C Generated 8/3/2009 10:44 AM Page 4 of 5 Comments Measured Inclination Azimuth Sub-Sea TVD T\~D Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North R de de R R R R R (R (R de 1100 R RUS RUS i _i ana .Ja aa. i _i i on. 9J 11899 .65 95. 50 167. 49 11931 .82 98. 43 168. 11 11981 .45 98. 48 166. 06 12002 .02 98. 62 168. 40 12033 .31 98. 50 167. 92 12064 .91 94. 64 167. 29 12097 .17 92. 03 167. 89 12128.36 90.97 168.22 12160.66 91.24 167.36 12256.02 92.34 186.58 12291.12 90.73 167.50 12320.32 88.72 166.22 12351.09 88.91 166.18 12383.09 89.25 166.66 12414.59 89.42 166.86 12446.89 89.84 164.67 12478.27 89.08 165.10 12511.66 88.96 166.33 12539.90 90.55 165.71 12575.36 93.36 165.96 12606.86 95.56 166.76 12638.67 96.53 165.95 12670.83 96.52 165.80 12702.80 95.65 166.56 12734.79 90.88 165.38 12766.05 90.00 163.96 12830.04 90.00 164.69 12926.63 90.72 164.00 aa/n./a auac.~a -alo.aa ovo9.u LL/L.09 -LVV..7J -LLVO.Iy 8975.37 9030.63 -942.83 6095.49 2269.28 -286.35 -2251.14 8971.47 9026.73 -970.61 6127.42 2266.75 -317.55 -2244.39 8964.17 9019.43 -1013.03 6176.51 2263.12 8961.11 9016.37 -1030.64 6196.85 2261.97 8956.46 9011.72 -1057.66 6227.80 2261.09 8952.84 9008.10 -1084.93 6259.18 2260.31 8950.96 9006.22 -1112.89 6291.38 2259.97 8950.15 8949.53 8946.55 8945.61 8945.75 8946.38 8946.90 8947.26 8947.47 8947.77 8948.34 8948.46 8947.25 8944.80 8941.45 8937.79 8934.41 8932.58 8932.34 8932.34 8931.74 Last Survey 13006.36 91.03 163.30 8930.52 TD (Projected) 13058.00 91.03 163.30 8929.59 Legal Description: Surface : 4768 FSL 314 FEL S33 T11 N R14E UM BHL : 3360 FSL 2288 FEL S33 T11 N R14E UM 9005.41 -1140.10 6322.56 2260.32 9004.79 -1168.20 6354.86 2260.99 9001.81 -1250.47 6450.17 2264.30 9000.87 -1280.78 6485.26 2266.56 9001.01 -1305.95 6514.45 2268.77 -365.40 -2233.42 -385.24 -2228.93 -415.52 -2222.58 -446.17 -2215.84 -477.62 -2208.92 -508.13 -2202.47 -539.69 -2195.64 -632.55 -2174.15 -666.74 -2166.28 -695.17 -2159.64 c.ou oaawa/.// 18.82 5950067.52 9.31 5950036.48 4.09 5949988.91 11.27 5949969.19 1.56 5949939.06 12.37 5949908.57 8.30 5949877.30 3.56 5949846.95 2.79 5949815.56 1.41 5949723.24 5.28 5949689.24 8.16 5949660.97 9001. 64 -1332 .29 6545. 22 2271 .15 -725. 05 -2152. 30 0.63 5949631 .28 9002. 16 -1359 .75 6577. 21 2274 .18 -756. 15 -2144. 79 1.84 5949600 .36 9002. 52 -1386 .88 6608. 71 2277 .79 -786. 81 -2137. 58 0.83 5949569 .88 9002. 73 -1414 .41 6641. 01 2281 .37 -818. 12 -2129. 64 6.90 5949538 .77 9003. 03 -1440 .90 6672. 39 2284 .81 -848. 41 -2121. 45 2.78 5949508 .68 9003.60 -1469.33 6705.77 9003.72 -1493.47 6734.01 9002.51 -1523.69 6769.45 9000.06 -1550.63 6800.85 8996.71 -1577.76 6832.48 8993.05 -1605.02 6864.44 8989.67 -1632.24 6896.22 8987.84 -1659.51 6928.15 8987.60 -1685.83 6959.41 8987.60 -1739.51 7023.40 8987.00 -1820.56 7119.99 8985.78 -1886.92 7199.71 8984.85 -1929.73 7251.34 Northing IY- tftUSl 5950406.37 5948953.48 2289.42 -880.76 -2113.22 2293.83 -908.16 -2106.39 2299.74 -942.52 -2097.72 2305.69 -973.04 -2090.32 2312.11 -1003.78 -2082.85 2318.75 -1034.76 -2075.06 2325.94 -1065.63 -2067.46 2333.45 -1096.61 -2059.72 2340.53 -1126.76 -2051.46 2355.86 -1188.36 -2034.17 2382.10 -1281.37 -2008.11 2405.55 -1357.86 -1985.66 2421.72 -1407.32 -1970.83 Eastins~ 1X1 fftUS 675869.48 673932.20 3.70 5949476.53 6.04 5949449.30 7.96 5949415.16 7.43 5949384.82 3.96 5949354.27 0.46 5949323.47 3.60 5949292.79 15.36 5949262.01 5.34 5949232.07 1.14 5949170.88 1.03 5949078.52 0.96 5949002,57 0.00 5948953.48 O/JO IO.U9 IV /V 10 `7..71J VV 190 JV 9.7.19/ 673625.79 N 70 16 9.614 W 148 35 44.941 673633.27 N 70 16 9.307 W 148 35 44.744 673645.35 N 70 16 8.837 W 148 35 44.425 673650.31 N 70 16 8.642 W 148 35 44.294 673657.37 N 70 16 8.344 W 148 35 44.109 673664.82 N 70 16 8.042 W 148 35 43.912 673672.47 N 70 16 7.733 W 148 35 43.710 673679.63 N 70 16 7.433 W 148 35 43.522 673687.20 N 70 16 7.123 W 148 35 43.323 673710.85 N 70 16 6.210 W 148 35 42.697 673719.52 N 70 16 5.873 W 148 35 4 673726.81 N 70 16 5.594 W 148 35 4 673734.85 N 70 16 5.300 W 148 35 42.060 673743.09 N 70 16 4.994 W 148 35 41.841 673751.01 N 70 16 4.692 W 148 35 41.631 673759.68 N 70 16 4.385 W 148 35 41.400 673768.57 N 70 16 4.087 W 148 35 41.161 673777.56 N 70 16 3.769 W 148 35 40.921 673785.02 N 70 16 3.499 W 148 35 40.723 673794.49 N 70 16 3.161 W 148 35 40.470 673802.61 N 70 16 2.861 W 148 35 40.254 673810.79 N 70 16 2.559 W 148 35 40.037 673819.31 673827.62 673836.08 673845.05 673863.77 673892.00 673916.22 673932.20 N 70 16 2.254 W 148 35 39.809 N 70 16 1.950 W 148 35 39.588 N 70 16 1.646 W 148 35 39.363 N 70 16 1.349 W 148 35 39.122 N 70 16 0.744 W 148 35 38.618 N 70 15 59.829 W 148 35 3793 N 70 15 59.077 W 148 35 N 70 15 58.590 W 148 35 3 . SurveyEditor Ver SP 2.1 Bld( users) 07-14\07-14\07-14C\07-14C Generated 8/3/2009 10:44 AM Page 5 of 5 ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME P,~S ~ O~ /~G' PTD# 070 OS3 ~' ~/S.SI.IE~ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~.~//JL,iOE''_ .9y POOL: ~,E'l~.D•~D~ ./~AS~ OiG 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(fj, 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 throu h tar et 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 iM1~"~,i. P~RNiIT C C~{,~~~{' eField & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 _ ____ Well Name: PRUDHOE BAY UNIT 07-14C __Program DEV ___ __ _ Well bore seg ^ a_v~.. PTD#:2090530 Company BP EXPLORATIO_N_ A( LASKA) INC __ _ Initial ClasslType _ DEV l 1-OIL GeoArea 890 _. __ _ _. Unit 11650- _ On/Off Shore On _ _ Annular Disposal ^ Administration '1 Permit fee attached NA_ i2 Lease number appropriate Yes 3 Unique well_name and number Yes ~_ s-Or1 • Yes Prudhoe Bau Oil Pool 4 Well located m a_defined pool - j5 Well located properdistance_from_drilling unit_boundary_ - _ _ Yes _ _ 6 Well located propertlistance_from4therwells _ Yes 17 Sufficient acreage available m drilling unit. Yes 25.60 acres. ~8 If tleviaied, is_we_Ilbore plat_included _ Yes _ _ 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Blanket Bond # 6194193. '11 Permit can be issued without conservation order_ _ _ _ Yes - _ _ _ - - _ Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15-day wait_ Yes ACS 81412009 14 Well located within area and strata authorized by Injection Order # (put 10# i_n_comments)_(For N_A - 15 All wells within 1!4 milearea of review identified (For service well only) _ NA_ 1116 Pre-produced injector: duration ofpre-production less than_ 3 months (For_service well_ only) NA 17 Nonconven, gas conforms to AS31,05,030(j.1.A),Q,2.A-D) NA - -_ 18 Conductor siring provided NA Conductor set_in DS 07.14 (178-081)._ Engineering 19 Surface casing. protects all known. USDWs NA No aquifers, AIO 46, conclusion 5. 1,20 CMT. vol. adeguate_to circulate on conductor & surf csg N_A Surface casing set in_ DS 07-14_. ',21 CMT vol_adeguate_totte-inlong string to surf csg N_A_ - Production-casing set in DS 07-14. X22 CMT_will cover all known productive horizons Yes ~i23 Casing designs adequate for C, T, B & permafrost_ Yes '24 Adequate tankage or reserve pit Yes - Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal well(s). - ' 25 If a re-drill, has a 10-403 for abandonment been approved Yes - 309-159 1 126 Adequate wellbore separationproposed- - Yes Proximity analysis perfomed. Traveling_cylinderpaih_calculated. '27 If_diverter required, does it meet regulations. y- _ . _ 28 Drilling fluid program schematic & equip list adequate Yes _ Maximum expected formation pressure 7,1 EMW in zone.. MW planned up_to 10.2 ppg in HRZ and 8.5 ppg_in zon Appr Date GLS 8!6/2009 29 . BOPEs, do They meet regulation Yes 30 BOPE press rating appropnate; test to_(put prig in comments) Yes MASP calculated at 2360 psi. 3500_psi BOP testplannetl, X31 Choke manifold complies wlAPI RP-53 (May 84) Yes 32 Work will occur without operation shutdown Yes 133 Is presence of H2S gas_probable Yes H2S is reported ai DS 7. Mud shoul_d_preclude H2S on rig, _R_ig hassensorsand alarms. 34 Mechanical condition of wells within A0R verified (Forservice well only) _ _ NA _ _ _ _ _ _ _ _ 35 Permit_can be issued wlo hydrogen sulfide measures No Max level H2S on Patl was 150ppm (7121193).- Geology 36 Data presented on potential overpressure zones NA Appr Date I'i37 Seismic analysis of shallow gas zones _ NA ACS 8!412009 38 Seabed condition survey (ifoff-shore) _ NA_ b e in place will alread NA BOP stack X39 Contaci_name/phone for weekly.progressreports_[exploratoryonly] Yes - GarretStaudinger-564-4242. Geologic Engineering Publi Permit BHL changed 580' (8!3!09), Permit re-issued ACS. Commissioner: Date: Com r.: ~ ate Commis ' ate DTS 5/21/2009 5l21/200~ 07-14C TD Extension ~ Page 1 of 2 Maunder, Thomas E ~©QA~ From:: Rebol, Amanda [reboa2~BP.com] Sent:. Saturday,. August 01, 2409 t:15 AM To: NSU, ADW Drlg Rig 7 ES; Staudinger, Garret; Tirpaek, Robert B; pawson, Bob S (PRA); Maunder, Thomas E (p4A) Subject; RE: 47,140 (209-053) Tp Extension C>~entlerrtcn. ~~}~c~at~; on ~ri~lit~g t~tx ~-~~tio~t~ ~~t~ ~7~~4~ ~tg~rd' ~`niittin~: W'e TD'd t ~cil te~ni~ht ar~~un~ midnight (~ ei~rk:30, a~ ~re~iCted~ at l x,058' MIJ. ~9~7' TAD. This ctcl~t#~ i~ ~~ fast the ~r~~~.t-aut<~rized °1'D ~f ~2,`9'~~i" 1Utl). ;~°s Pm~ iou~~ discos~ed, t subrrtit a revised petit ~i~r the ~e1~ first Ding Md~da~y ~norning> l~lldil tC ,~'Y'a1.1 Amanda r~mai:~a ~~ n~'~c Nig}rt W53,, Nabors ~~,` {?~??-E~S~- KR;3 720- X3:3-t?3.72 from: Maunder, Ttwmas E (QC?A) [mattto:tom,rnaunderCaZataska.gov] Sent: Thursday, 7uly 30, 2009 5:05 PM To: Staudinger, Garret Gc: Ttrpactc, Robert B~ t~awson, t3ob S (PttA); NSU, AQW prtg Rig ~ ES subject: RE: 07-toe (209-OS3) TD F~ctenston Garrett eti al, discussed, the permit wiN need to be reiss~-ad to driii more than 499' additional. After hours/weekend rc~ntacts tzar a ~att~r like his ~hoi,td b+e ~v~ided. 1 t~nz~w I vvc~'t ap ~ gang welt tap ettei 1 t~rtenly It t rnpt to alt ease et the Carr~rriissioners. It appears dritli~g lacyor+d +~g9° i~ ur~t~rtain, taut in the rrst t v~aat will happen and it wil- be at G dark30, t suggest that it is apprffipriate ~ nfcarm us in a return rn ge that y~ru could drill more than 4~~' end l apprise the ~6mmissior~ers of that during ntarrrral business hours tamorrow. if drilling eds 499' actditionai, then ~ t~ew ~Tp applit~an wilt tea be by Tuescia~, tl; driNirag is he v~ith td~an d99' additic~~al drilled than tl~ trotter is rrv~t, l Ic~cak fcarwgrd to your reply. Torn Maunder, From; Skaudtnger, Garret [mailto:Garret.Staudinger@bp.com] Sent: Thursday, .duly 30, 20f?9 4:05 PM To: Maunder,. Thomas E (pOA) Cc: Tirpaek, Robert B; pawson, Bob ~ (PRA); NSIi, ApW prig Rig 7 ES Subject: 07-140 Tp Extension Team, 8/412009 07-14C TD Extension Page 2 of 2 I wanted to keep you in the loop of the drilling operations on 07-14C. We are currently drilling 6-1/8" production hole in Ivishak Zone 2. Our originally planned TD was at 12,475' MD from Schlumberger directional plan 4. While drilling, we did not find as much oil as anticipated in lower Zone 2, so we inverted and targeted sands in upper Zone 2. This caused us to spend more time in shale than originally anticipated. We are currently at 12,534' MD and have tripped to surface to pick up new bit and motor to finish drilling the hole section. The asset has not yet achieved their minimum pert objectives. We currently plan to extend TD to 499' beyond originally planned TD. The new TD is at 12974' MD. In the unlikely event that we will request extending TD beyond this point, we will seek State approval prior to drilling past 12,974'. What are the after hour /weekend contact numbers for me to call to request approval in the event that we need to extend TD beyond 499'? Please let me know if you have any questions. Thanks, Garret Garret Staudinger Operations Drilling Engineer BP Exploration Alaska, Inc. Work: (907) 564-4242 Cell: (907) 440-6892 8/4/2009 • ~ Page 1 of 1 Maunder, Thomas ~ (D©A) From: Maunder, Thomas E (DOA) Sent: Tuesday, July 21, 2Q09 9:14 AM To; DOA AOGCC Prudhoe Bay Subject. FW,: DS Q7-14C (209053) July 19 Kick All, F#ere is the respon frorr~ B~: W 3~1 h it~je d abut 8MM tsbls of produ w r in the last year. F~~aarfo+retions a~ shown t+~ ben rly 1000' # send so ~r as ! n tell, floe lures ere at t 2500' apart at ~+~ lcl~ depth.. Tdt~t From. Reltier Brandon [rrtallto:Brandon.Peftier@bp.com] Sen#t Monday, July 20, 2009 5:21 PM To; Maunder, Thomas ~ (DOA) Cc: Tirpack, Robert B Staudnger, Garret ~bj~®ct: FHV:; QS Q?-14C (2A9-053} )u!y 19 Kiek Tom I am filling in for Garret today. The answers to your questions are below: 1. A rding to the !l plan, It was Intend exit the sing ~ 5 '. ~9Vh is the a 1 window's The actual window is from 5001' - 6018'. 2. Whai 1~1T valcre w aohieved2 A LOT of 13.7ppg EMW was achieved.. 3. This is an urn l event, whit meat haslis lacing de erdir-g the possible ol: tl'te hyd n~ The gas is likely from the Ugnu coal seams that were drilled. 4. 'Was any liquid en2 There were no signs of oil or produced water, however it is possible that there may be over pressure in this interval from Cretaceous injection of produced water. t_etus know if you have any further questions. Thank you. Brandon Reltier BF Exploration (Alaska), Inc. Operations Drilling Engineer GFB Rotary Drilling (907) 564-5912 (Direct) (907) 7487838 (Mobile) Brandon . Peltier~bp, com ?/2 ~ 12QQ9 • Page 1 of 1 Maunder, Tharna~ E (C1Q/~) iFrom: Maunder, Thomas E (DOA) Sent: Monday, July 2f?, 2QQ9 7:36 AM To: 'Staudinger, Garret' Gc; Tirpack, Robert B; aCtA AC-GCC Prudhoe Bay Subject: QS D7-14C (2fl9-Q53) July 19 Kick Attachments: 7-19 kick.doc From: Seheve, Charles M (DOA) Sen#: Monday, July 2fl, 20©9 6;46 AM T~: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: FlIV: The Ugnu flowing with 9 lib mud in hole??? From; E?inger, Michael E [mailto:Michael.Qinr}er~albp.com] Sent: Sunday, July 19, 2089 8:04 PM Ta: OOA AOGCC Prudhoe say subject; Chuek, here is a summary of what occurred today. If you have any questions, give me a Bail. Mike ginger 659-4835 7/2 ~ /2009 • DS7-14C (209-053) Kick in UGNU 3 At 8:00 AM on 7-19-09 the Driller noticed the flow percentage increase from 36% to 47% while drilling ahead in the Ugnu at 5346' MD, 4930' TVD. The pumps were shut down and the well was monitored. The well was flowing with gas breaking out of the mud and the well was shut in after a 6 bbl pit gain. Pressures were allowed to stabilize with SIDPP 80 psi, and SICP 60 psi. The wait and weight method was used to circulate out the influx. The mud system was weighted up from its origina19.0 ppg to 9.4 ppg. The well was circulated with 9.4 ppg following the DP reduction schedule w/ ICP of 350 psi and a FCP of 280 psi. (surface to bit) 280 psi was maintained on the DP for the remainder of the circulation. After the circulation, the choke was opened and the well was monitored in the pits. A slight trickle of fluid was observed at the pits. The annular preventer was opened and the well was monitored. No flow was observed while monitoring the well and drilling commenced. The Driller brought the pumps up to drilling rate and noticed the flow line percentage jump 7%. Once again the pumps were shut down and the well was monitored with a slight flow going down the flow line. B/LJ was circulated and the well monitored throughout for gas/ flow line percentage increase. Neither were observed. The well was monitored after circulating B/U and the well was still flowing slightly. Drilling commenced and the MW was raised to 9.6 ppg while drilling ahead. The well was monitored closely while drilling ahead and at connections and no other signs of an influx were observed. Mike Dinger WSL 7-ES Robert Tirpack Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 SARAH PALIN, GOVERNOR R- 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, 07-14C Well BP Exploration (Alaska) Inc. Permit No: 209-053 Surface Location: 511' FNL, 314' FEL, SEC. 33, Tl 1N, R14E, UM Bottomhole Location: 141..2' FNL, 2416' FEL, SEC. 33, T11N, R14E, UM Dear Tirpack 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 Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms anal. 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). Sincerely, ~%~~-- Cathy oerster ~' Commissioner DATED this ~sday of May, 2009 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. ~ STATE OF ALASKA A~ OIL AND GAS CONSERVATION COM~SION PERMIT TO DRILL 20 AAC 25.005 .~~ f~9 ~;~~~s ~ h~ ~a~ 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 well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 07-14C 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12476' TVD 9006' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028309 Oil Pool FEL, SEC. 33, T11 N, R14E, UM 511 FNL, 314 Top of Productive Horizon: T11N R14E UM 542' FNL 2632' FEL SEC. 33 8. Land Use Permit: 13. Approximate Spud Date: July 1, 2009 , , , , , Total Depth: 1412' FNL, 2416' FEL, SEC. 33, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 25,250' 4b. Location of Well (State Base Plane Coordinates): Surface: x-675869 y-5950406 Zone-ASP4 10. KB Elevation Plan (Height above GL): 50, ~ feet 15. Distance to Nearest Well Within Pool: 930' 16. Deviated Wells: Kickoff Depth: 5000 feet Maximum Hole An le: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3240 Surface: 2360 1 'n 'P r m: r~catio ns T - e in h -Bottom n' o m c.f: o Hole Casin Wei ht Grade Cou tin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-8 BTC-M 722' 4 0' 39 10722' 505' 31 sx Lite rete 168 x Class' ' 6-1/8" 4-1/2" 12.6# L-8 IBT-M 1903' 10572' 837 ' 1247 ' 9005' 24 sx Cla s'G' 19. PRESE Total Depth MD (ft): Total Depth T 12500' 8978' NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) VD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): None 12468' 8975'- None Casing Length Size Cement Volume MD TVD Conductor /Structural 71' x Ar i 7 ' 71' Surface 2 65' 13- / " 42 x Arcticset II 266 ' 2665' Intermediate 1 362' - / " 1 x lass'G' n~ - 103 2' 573' Pr i Liner 2652' 3-1/2" x 3-3/16" x 2-7/8" 147 sx Class'G' `' ` 9848' - 12500' 8210' - 7 ' Perforation Depth MD (ft): 10950' - 12465' Perforation Depth TVp`( ° 8960' - 8975' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Dritling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Dritling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Garret Staudinger, 564-4242 Printed Name Robert Tirpack Title Engineering Team Leader / Prepared By Name/Number. Si nature ..~, Phone 564-4166 Date ydk~ ~' Terrie Hubble, 56a-4628 Commission Use Onl Permit To Drill umber:o?0905..~ API Number: 50-029-20339-03-00 Permit Approval See cover letter for 3 2i c~ her it en Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed me~th/ane, gas hydrates, or gas contained shales: 3~~eS ~ rp,~ ~ c,~- Samples Req'd: ^ yes tl~J No Mud Log Req'd: ^ Yes C~No a SOO Qs'~ M~ rat ~"~~l ty GPh~1~(-~S'~ HZS Measures: Yes ^ No Directional Survey Req'd: (Yes ^ No Other: APPROVED BY THE COMMISSION Date 5 -2 - ,COMMISSIONER Form 10-401 Revised 12/2005 ~ Sub In uplicate V~~ ~'W ! ` 9,.. Well Name: 07-14C Drill and Complete Plan Summary T e of Welt service / roducer / in'ector : Producer Surface Location: X=675869.48' Y=5950406.37' As-Built 4768' FSL, 314' FEL, T11 N, R14E, Sec. 33 Target Locations: X=673552.97' Y=5950322.22' Z=9005.5' 07-14C T t 1 4738' FSL, 2632' FEL, T11 N, R14E, Sec. 33 Bottom Hole Location: X =673791.22' Y =5949457.61' Z=9005.5' 3868' FSL, 2416' FEL, T11 N, R14E, Sec. 33 Adam Van Holland Geolo ist 564-4477 Alice Kaminski Prod. En ineer 564-5676 Garret Staudin er Drillin En ineer 564-4242 API NUMBER: TBD Ri Nabors 7ES Estimated Start Date: 7/1/2009 Operating Days to complete: 23.6 MD: 12475' TVD: 9005' RT/GL: 28.5'/22' RTE: 50.5' Well Design: Ivishak Zone 2B Producer 4'/z" tbg, 12.6# 13-CR-80 , 7" x 4-~/z" packer, 4'h" L-80 12.6# Liner Ob'ective: Horizontal Producer in Ivishak Zone 26 Directional Plan: Version: Schlumberger P4 KOP: 5000' MD, build 4/100 Maximum Hole An le: 90° Close Approach Wells: Nearest well within Pool: No close approach wells 930' to 07-04A Distance to Nearest Property Line: 25,250' to Unit Boundary S Surface and Anti-collision: Surface Shut in Wells: No wells are required for surface shut-in prior to rig moving on well Close Approach Shut-in Wells: All wells pass Close Approach Anti-Collision Scan 07-14C Permit Application Page 1 Lo in Pro ram: Intermediate Interval Drilling, MWD: GR/Resistivity Open Hole: None Cased Hole: None Production Interval Drilling, MWD: GR, RES, NEU, Azimuthal Density Open Hole: None Cased Hole: None Mud Program: Whipstock Milling Mud Properties Density Plastic Yield Point API Fluid MBT (ppg) Viscosity (Ib/100ft2) Loss pH c mis/30min 8.8 15-22 30-40 6 -8 9.0 - 9.5 < 20 8 1/2: Intermediate Hole: LSND Mud Density Plastic Yield Pomt API Fluid MBT Interval (ppg) Viscosity (Ib/100ft) Loss pH c mis/30min 5000 - 9523 8.8 - 9.2 12 -18 18 -24 < 6.0 9.0 - 10 < 20 9523 -TD TSGR 10.2 16-20 25 - 30 < 6.0 9 - 10 < 20 6 1/8" Production Hole: Flo-Pro Mud Plastic API Interval Density Viscosity Ylb/1d Ottnt ( ) Fluid Loss pH MBT (ppg) c ml/30 min Production 8.5 8 - 15 24 - 30 6 -8 9 - 9.5 < 6 Casing/Tubing Program: Hole Size Csg/ Tb O.D. Wt/Ft Grade Connection Length Top MDlTVD Btm MD/TVD RTE 8 1 /2" 7" 26 L-80 BTC-M 6722' 4000' / 3930' 10722' / 8505' 6 1 /8" 4 1 /2" 12.6 L-80 I BT-M 1903' 10572' / 8375' 12475' / 9005' Tubin 4'h" 12.6 13CR-80 VamTo 10572' GL 10572' / 8375' Integrit Testin Test Point Depth Test Type 9 5/ "Surface Casin 20' - 50' in o en hole from window FIT 12.5 Test Point Depth Test Type 7" Intermediate Casin 20' - 50' from 7" shoe FIT 11.0 07-14C Permit Application Page 2 r • Cement Calculations: Casin Size Intermediate - 7" 26 ppf L-80 BTC-M -Sin le Sta e Basis Lead: Open hole volume + 40% excess + 1000' liner lap + 200' MD above liner. TOC is TOL Tail: O en hole volume + 40% excess TOC at 1000' above 7" shoe. Wash None S acer 50 bbls of MudPush II wei hted to 10.6 Lead 186 bbls 313 sks 11.0 LiteCRETE cement - 3.33 ft /sk Tail 35 bbls 168 sks 15.8 Class G -1.16 cuft/sk Temn BHST = 190° F Casin Size Production Casin - 4 1/2" 12.6 f L-8016T-M -Sin le Sta e Basis Tail: O en hole volume + 40% excess + 150' liner la + 200' MD above liner. TOC at TOL. Wash None S acer 30 bbls of MudPush II wei hted to 12.0 Tail 51 bbls 245 sks 15.8 Class G w/latex -1.16 ft /sk Temo BHST = 200° F 07-14C Permit Application Page 3 Formation Markers (Based on SOR): ~J Est. Formation To s Uncertain Commercial Hydrocarbon Bearin Est. Pore Press. Formation (TVDss) (eet) (Yes/No) (Psi) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells SV3 -3290 40' no SV2 -3511 40' no SVl -3918 40' no UG4 -4448 40' no KOP -4635 UG3 -4693 40' no UGl -5123 40' no WS2 -5735 40' no WSl -5940 40' no CM3 -6123 40' no CM2 -6620 40' no CMl -7125 40' no THRZ -7592 40' no BHRZ/TJE -7750 40' no TJD -8013 40' no TJC -8090 40' no TJB -8257 40' no TJA -8358 40' no TSGR -8453 20' es TSHU -8484 20' no TSAD -8556 20' es TCGL -8742 20' es BCGL -8813 20' es -3240 si 23SB -8868 20' es 22TS -8925 20' es 22N -8957 20' no 21TS -8972 20' es HOT -8970 20' es TZ1B -9042 20' es BSAD -9113 20' es 07-14C Permit Application Page 4 ~ ~ Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Annular preventer will be tested to 2500 psi. Rams will be tested to 3500 psi. The BOP test frequency during the Decomplete will be on a 7 day period, and 14 days during the D&C operations. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- • Maximum anticipated BHP: 3240 psi C~ 8800' TVD, 7.1 ppg EMW (at BCGL, 11,199' MD) • Maximum surface pressure: 2360 psi @ surface (based on BHP and a full column of gas from TD C~3 0.10 psi/ft) • Planned BOP test pressure: • Annular Preventer • Rams • Planned completion fluid: 250 / 2500 psi 250 / 3500 psi 8.6 ppg seawater / 6.8 ppg diesel Kick Tolerance / Integrity Testinst Summary Table Casing and Interval Casing Test Pressure Maximum Influx Volume Mud Weight Exp Pore Press LOT / FIT 95/8" Casing 3500 psi 67.9 BBLS 10.2 8.8 12.5ppg 8-1/2" (assuming FIT Intermediate 10.8 ppg Interval EMV FIT 7" Casing and 3500 psi Infinite 8.5 7.2 11.Oppg 6-1/8" (assuming at FIT Production least 8.8 ppg Interval EMV FIT 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 disposal 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 and 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 I liquids will be directed to Pad 3. 07-14C Permit Application Page 5 07-14C -Drill and Complete Procedure Summary A. Current Well Status: 1. MIT - OA passed 2000 psi on 9/24/08 2. MIT - IA failed on 4/16/08. Establish LLR rate of 4.7 BPM @ 1250 psi 3. PPPOT-T & PPPOT-IC passed on 3/30/2008 4. Downhole camera was run on 5/31/2008 and showed collapsed tubing at 9587' MD. Confirmed TxIA communication. 5. Could not get 2" jet swirl nozzle or LDL toolstring (1.6875" OD) past collapsed tubing point. B. Pre-Riq Work: 1. F: Fluid pack the tubing and inner annulus w/ seawater/diesel. 2. E: RU, run STP log in parent well from 9,500' to surface. 3. F: P & A the perforations in the 07-146 wellbore with cement from 12,468' MD up to 9,300' MD. Install tree saver to prevent cement from getting into tree/BPV profile. Ensure that IA and tubing are fluid packed. Perform infectivity test. Bullhead cement from surface into perforations and chase with foam ball. a. CEMENT CALCULATIONS i. 1446' of 2-7/8", 6.16# liner: .0058 bbls/ft = 8.4 bbls ii. 1174' of 3-3/16", 6.2# liner: .0076 bbls/ft = 8.9 bbls iii. 250' of 3.80" cement sheath: .0140 bbls/ft = 3.5 bbls iv. 300' of 9-5/8" csg w/ 5-1 /2" tbg .0671 bbls/ft = 20.2 bbls TOTAL (with 10 bbls excess) = 51 bbls Note: Do not use aggregate in slurry as ID of collapsed tubing is unknown. A squeeze can be done if possible, but it is not necessary to achieve a squeeze pressure. Target TOC at 9,300' MD. 4. S: WOC. Drift for Jet Cutter. Tag Top of cement plug. 5. F: CMIT - T x IA to 2,500 psi for 30 minutes. 6. F: MIT - OA to 2,000 psi for 30 minutes. 7. E: Jet cut the 5-1/2" tubing in the middle of a full joint at 5600' MD. 8. F: CMIT - T x IA to 2,500 psi for 30 minutes. 9. F: Circulate the well to seawater. Freeze protect the IA and tubing with diesel to 2,200'. 10. D: Bleed all casing and annulus pressures to zero psi. 11. W: Function all tubing and casing LDS. Repair and replace as necessary. PPPOT - IC and PPPOT - T. 12. V: Set a BPV. Remove well house and flow line. Level the pad as needed. Provide total well preparation cost on the handover form. C. Riq Operations: 1. MIRU. 2. Pull BPV. Circulate out freeze protection with 9.0 ppg brine and condition fluid as needed. Set a TWC and test from below to 2000 psi and above to 3500 psi. 3. Nipple down tree. Nipple up and test BOPE to 3500 psi. Pull TWC. 4. RU and pull the 5-1/2", 17#, L-80, 8 rd A-B Modified plastic coated tubing from the pre-rig jet cut at 5600' MD (steam wellhead prior to pulling hanger). Spool up the control line and count metal Hydril control line clamps (26 listed on tally) and stainless steel bands (5 listed on tally). Test the lower set of pipe rams. 5. PU 4" drillpipe and 9-5/8" clean-out assembly and clean-out well to the top of the tubing stub 5600' MD. Note: Do not run 9-5/8" casing scrapers due to the 9-5/8" FO collars at 2323' and 2452'. 6. With E-line, run a 9-5/8" EZSV for 47# casing. Set the EZSV at 5020' MD. Rig down E-line. 7. Pressure test the EZSV to 3500 psi for 10 minutes. 8. PU 9-5/8" whipstock, bottom trip anchor and 8.5" window milling assembly (to include full gauge string mills). 9. Hang weight of 9-5/8" whipstock assembly and set storm packer just below the wellhead. 10. Remove the existing Gray Gen 2 Tubing Spool. Change out the 9-5/8" pack-offs per Cameron. Install the New Standard Tubing Spool. 07-14C Permit Application Page 6 • ~ ~~_ ~~ 11. RIH to the top of the EZSV. Orient and set the whipstock. Swap the well over to 9.0 ppg fresh water LSND milling fluid. 12. Mill a window in the 9-5/8" casing from 5000' MD' plus 20' of formation from mid-window. 13. Perform an FIT to 12.5 ppg (a minimum FIT of 10.8 ppg is required to satisfy kick tolerance requirments). POOH for drilling BHA. 14. MU an 8-1/2" drilling BHA with DIR/GR/RES/PWD and ghost reamer behind the bit. RIH. Kick off and drill 8-1/2" intermediate interval to 7" casing point at the top of the Sag River. ~ h~`7 NOTE: The mud will need to be weighted up with spike fluid. Plan for one weight-up with '~ the spike fluid to 10.2 ppg over several circulations prior to drilling the HRZ and Kingak ~~~ shale. 15. Change to 7" casing rams and test. 16. Run and cement a 7", 26#, L-80, BTC-M drilling liner throughout the 8-1/2" hole and back into the 9- 5/8". Set TOL to cover cretaceous (cretaceous top at top SV1). Displace cement with mud and set hanger /liner top packer. POOH. 17. MU a 6-1/8" BHA with DIR/GR/RES/DEN/NEU and RIH to the 7" landing collar. Pressure test liner and casing to 3500 psi for 30 min. Drill out the shoe plus 20' of formation while swapping over to new Flo-Pro drilling fluid. Perform an FIT to 11.0 ppg. 18. Drill ahead per plan to the base of the conglomerates. POOH for bit and BHA change. 19. MU a 6-1/8" BHA with DIR/GR/RES/DEN/NEU and RIH. Verify with town geo to MAD pass build interval. Drill ahead the Ivishak Z2 horizontal per plan to TD. 20. CBU, short trip, circulate until clean and spot a liner running pill. MAD Pass where required. POOH. 21. Run and cement a 4-1/2", 12.6#, L-80, IBT-M liner from TD to 150' inside the 7" shoe. Set the liner top packer. 22. Run on DP 600' of 2-7/8" 2906 PJ HMX, 6 spf perf guns and shoot over balanced. Fire guns, POOH. LD remaining DP 23. RU and run 4-1/2", 12.6#, 13Cr-80, Vam Top completion, tying into the 4-1/2" liner top. 24. Reverse circulate to spot corrosion inhibited seawater. 25. Drop ball and rod. Set packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. Shear DCK valve. 26. Set and test a TWC. 27. ND BOPE. NU and test the tree to 5,000 psi. Pull TWC. 28. Freeze protect the well with diesel to 2200' MD. Set a BPV 29. RDMO. D. Post-Rig Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from `XN' nipple below the new production packer. 2. Install gas lift valves. 3. Install wellhouse and flowlines. (S-Riser work will be required.) 07-14C Permit Application Page 7 • Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE Directional Control: Ensure that directional control is maintained and to not fall behind the planned curve. Important to stay on plan in the intermediate section to avoid approaching a Kingak fault to the east. II. Lost Circulation: Overall risk of significant lost circulation is considered low for this well due to no anticipated fault crossings. DS 7 wells have not encountered a lot of LC issues in the past. Follow the recommended drilling practices, and the lost circulation decision tree. III. Kick Tolerance /Integrity Testing: The 9 5/a' casing most likely will not have cement behind casing at the window depth. The 9-5/8" casing shoe was cemented with a 50 bbls tack job. The 9-5/8" x 13-3/8" annulus was cemented through the FO collars. Casing will be tested to 3500 psi before drilling out. An FIT to 12.5 will be performed after drilling 20-50' of new formation after milling out the 9 /$" casing. The 7" liner will be cemented to the TOL. A FIT to 11.0 will be performed after drilling 20-50' of new formation after drilling out 7" casing shoe Kick Tolerance /Integrity Testing Summary Table Casing and Interval Casing Test Pressure Maximum Influx .Volume Mud Weight Exp Pore Press LOT / FIT 95/$" Casing and 3500 psi 67.9 BBLS 10.2 8.8 12.5ppg 8-1/2" (assuming FIT Intermediate 10.8 ppg Interval EMV FIT 7" Casing and 3500 psi Infinite 8.5 7.2 11.Oppg 6-1/8" (assuming at FIT Production least 8.8 ppg Interval EMV FIT IV. Hydrogen Sulfide DS 7 is not an H2S site. Most wells on DS 7 are typically <30 ppm H2S levels. Standard H2S precautions will be followed at all times. H2S Summa Table Well N me H S Level m Date of R adin #1 Closest SHL Well H2S Level 07-29D n/a n/a #2 Closest SHL Well H2S Level 07-28AL1 28 1/4/2008 #1 Closest BHL Well H2S Level 07-03A 16 4/10/2008 #2 Closest BHL Well H2S Level 07-04A 16 4/17/2008 Max. Recorded H2S on Pad/Facilit 07-13A 150 7/21/1993 V. Faults No fault crossings are expected. There is a low risk of lost circulation for this well. VI. Anti-Collision Issues All wells have passed the major risk scan. Reference the Anti-collision report in the directional plan for a full list of offset well paths. CONSULT THE DS 7 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 07-14C Permit Application Page 8 t= ~rwr vr~v~ .LHEAD = GRAY • UATOR = AXELSON ELEV = 64' ELEV = '= 10360' Angle = 95 @ 11429 im MD = 10705' im TV D = 8800' SS 9-518" FO COLLARS 2323' 8 2452' 13-318" CSG, 72#, L80, ID = 12.347" 2~5' Minimum ID = 2.377" ~ 11040" 2-7/8" STL PIN CONNECTION 07-14B C COLLAPSED TBG (REF VIDEO LOG 05/31/08) ~~ 9587' CMT SHEATH, ID = 3.80" 9600'-9850' 5-112" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~-{ 9797' 4-1 /z' TBG-NPC, 12.6#, N-80, .0152 bpf, ID = 3.958" H 9913' PERFORATION SUMMARY ~~ REF LOG: SPERRY EWR - GR ON 10/14/03 ', ANGLE AT TOP PERF: 88 Q 10950' '', Note: Refer to FYoduction DB for h~torical pert data SIZE SPF INTERVAL OpNSgz DATE '' 2" 4 10950 - 11400 O 10!20/03 2" 4 11445 - 11480 O 10/20/03 2" 4 11640 - 11825 O 10/20/03 7' 4 11890 - 12140 O 10/20/03 7' 4 12295 - 12465 O 10/20/03 SA NOTES: COLLAPSED TBG ~ 9587' (REF VI OG 05/31/081 2256' J~5-1/2 OTIS ROM SSSV NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2903 2903 7 OTIS DMY T2 0 03/29/08 2 5186 4826 43 OTIS DMY RM 0 09/18/04 3 7033 6139 45 OTIS DMY T2 0 03/x/08 4 8147 6993 38 OTIS DRAY RA 0 08/19/03 5 8829 7494 45 OTIS DMY RA 0 08/19/03 8902 7545 46 OTIS DMY RA 0 08/19/03 7 9365 7868 45 OTIS DMY RA 0 08!19/03 8 9443 7923 45 OTIS DMY RA 0 08!19103 9 9587 8025 45 OTIS DMY RA 0 08/19/03 10 9658 8076 45 OTIS DMY T2 0 08/19/03 9520' 5-112" OTIS SLIDING SLV 9732' H~-1/r' OTIS N NIP, ID = 4.455" (IN CMT SHEATH) 9772' 5-1 /2" BOT PBR A SSY 9798' 9-5/8" X 5-112" BKR SAB PKR 9809' 6-5/8" X 4-1/2" XO (MILL OUT EXTENSION) 9$48' 3-1/2" BKR DEPLOY SLV, ID = 3.00" 9858' 3-1/2" X NIP, ID = 2.813" 9869' 3-112" X 3-3/16" XO, ID = 2.786" 9870' 4-112" CAM DB-6 LAND NIP, ID = 3.813" (BEHIND CT LNR) 1 10120' ~--TOP OF CEMENT (RAMP) MpLLOUT CMT WINDOW (07-14B) 10360' - 10363' 110?.2' HXO`ID=2.440" 9-5/8" CSG, 47#, L-80/S-95, ID = 8.681" ~ 10524' 2-7/8" LNR, 6.5#, L-80, ID = 2.441" 11881' 3-3/16" LNR, 6.2#, L-8Q .0076 bpf, ID = 2.805" ~-1 11022' ~~ PBTD 12468' 2-718" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" 12500' OATE REV BY COMMENTS DATE REV BY COMMENTS 06/03/79 ORIGINAL COMPLETION 09/14/07 KSBIfLH GLV GO 08/01/98 SIDETRACK(07-14A} 04~1/OS DAV/SV GLV GO 11/22/03 CJS/TLH SIDETRACK(07-148)(10120/03) 06/25/08 RLM/PJC COLLAPS®TBG (05131/08) 10/243 MH/TLH GLV GO 09/18/04 GJBITLP GLV GO 08/D4/07 DTRlSV GLV GO PRUDHOE BAY UNIT WELL: 07-14B PERMIT No: 82031420 API No: 50-029-20339-02 SEC 33, T11 N, R14E, 511.07' FEL & 313.93' FNL BP Exploration (Alaska) TREE _ GRAY GEN 2 ~ ~ ~ ~ e ~ O ~ _ 14 C WELLHEAD = GRAY ACTUATOR =_ AXELSON KB. ELEV = 64' BF. ELEV = ~ KOP = 5000' Max Angle = ~ 90 @ 11578 Datum MD =_ 10705' Datum TV D = 8800' SS I9-518" FO COLLARS I-j 2323' & 2452' 13-318" CSG, 72#, L80, ID = 12.347" 2665' Minimum ID = 2.377" c~ 11040" 2-7/8" STL PIN CONNECTION 9-5/8" Whipstock ~~ 5000' 9-518" ¢SV 5020' ~ 5-112" Jet Cut 5600' ESTIMATED TOC 9300' 5-1/2" OTIS SLIDING SLV 9520' PSED TBG (REF V IDEO LOG 05/31108) 9587' CMT SHEATH, ID = 3.80" 9600'-9850' 5-1 /2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 9-5/8" X 5-112" BKR SAB PACKER 6-5/8" X4-1/2" XO (MILL OUT EXTENSION) 3-1 /2" BAKER DEPLOY SLEEVE, ID = 3.00" 4-1/2" TBG-NPC, 12.6#, N-80, .0152 bpf, ID = 3.958" ~ 9797' ~ 9798' 1 9848' ~ 9913' PERFORATION SUMMARY REF LOG: SPERRY E1NR - GR ON 10/14/03 ANGLE AT TOP PERF: 88 @ 10950' Note: Refer to Roduction DB for historical pert data SIZE SPF INTERVAL OpNSgz DATE 2" 4 10950 - 11400 O 10/20/03 SA NOTES: COLLAPSED TBG ~ 9587' (REF VII~LOG 05/311081 2200 4-1/2" X NIPPLE (SAS I IFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 1 2903 2903 - OTIS DMY T2 0 03/29/Q8 2 5186 4826 43 OTIS DMY RM 0 09/18/04 3 7033 6139 45 OTIS DMY T2 0 03/29!08 4 8147 6993 38 OTIS DMY RA 0 08!19/03 4000' 7" Hanger /Liner Top Packer 10432' I4-1/7' OTIS X NIP, ID = 3.813" 10462' T' x 4-1/2" S-3 PKR 10492' 4-1 /2" OTIS X NIP, ID = 3.813" 10562' 4-112" OTIS XN NIP, ID = 3.725" 10572' 4-1/2", 12.6#, 13-CR, .0152 bpf, ID = 3.958" 10572' 4-1/2" Hanger / LTP 10722' T', 26#, L-80, BTCM, 0.0383 bpf, ID = 6.276" PBTD 12395' 12475' ~-I4-1/2", 12.6#, L-80, .0152 bpf, ID=3.958" 9-5/8" CSG, 47#, L-80/S-95, ID = 8.681" I-+ 10524' ~ Ll 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.805" 11022' 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 06/03!79 ORIGINAL COMPLETION 09/14/07 KSB/TLH GLV C/O 08/01/98 SIDETRACK~07-14A) 04/01/08 DAV/SV GLV C/O 11122/03 CJSlTLH SIDETRACK (07-146)(10/20/03) 06125/08 RLM/PJC COLLAPSED TBG (05/31108) 10/24/03 MH/TLH GLV C/O 04/09/09 GJS 07-14C PROPOSAL 09/18/04 GJB/TLP GLV C!O 08/04/07 DTR/SV GLV C/O PRUDHOE BAY UNIT WELL: 07-146 PERMff No: "2031420 API No: 50-029-20339-02 SEC 33, T11 N, R14E, 511.07' FEL & 313.93' FNL BP Exploration (Alaska) by DS07-74C (P4) Proposal Schlumberger Report Date: Aplil 16, 2009 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - EOA Structure I Slot: Well: DS-07 / 07-14 ~~ I'~ 07.14 Borehole: Plan 07-14C ~e~ ~i UWIIAPIff: 500292033903 Survey Name 1 Date: 07-14C (P4) I April 16, 2009 Tort 1 AHD 1 DDI 1 ERD ratio: 273.521 ° / 6720.67 ft / 6.406 10.746 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaVLong: N 70.27012048, W 148.57761433 Location Grid NIE YIX: N 5950406.370 ftUS, E 675869.480 ftUS Grid Convergence Angle: +1.33891540° Grid Scale Factor: 0.99993514 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 233.510° Vertiwl Section Origin: N 0.000 ft, E 0.000 ft ~~ TVD Reference Datum: Rotary Table TVD Reference Elevation: 50.50 ft relative to MSL Sea Bed I Ground Level Elevation: 22.00 ft relative to MSL Magnetic Declination: 22.645° Total Field Strength: 57718.463 nT Magnetic Dip: 80.909° Declination Date: August Ot, 2009 Magnetic Declination Model: BGGM 2008 North Reference: True North Total Corr Mag North -> True North: +22.645° • 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 1100 ft Index ftUS ftUS Tie-In Survey 49S6.bU 4"G.bU 1/.UU 4t5Yb.4/ 46/b.y/ -if/U.Zy y3y.6S 315/.43 34. 4tfL U.t)U 4.i5U ~yb13b4./tl b/UY34.tlZ N /V. L/LdC/O`J VV 14if. D/44i511V Top Whipstock 5000.00 42.57 16.93 4635.42 4685.92 -877.62 948.41 390.09 65. 00E 0.60 4.81 5951363.57 676237.28 N 70. 27271144 W 148. 57445956 Base Whipstock 5016.00 43.41 14.40 4647.12 4697.62 -886.23 958.91 393.03 --- 12.00 4.83 5951374.14 676239.97 N 70. 27274013 W 148. 57443575 Crv 4/100 5029.00 43.41 14.40 4656.57 4707.07 -893.16 967.56 395.25 89. 00E 0.00 4.83 5951382.84 676241.99 N 70. 27276377 W 148. 57441778 UG3 5036.48 43.41 13.96 4662.00 4712.50 -897.14 972.55 396.51 88. 68E 4.00 4.84 5951387.85 676243.14 N 70.27277739 W 148. 57440760 5100.00 43.53 10.27 4708.10 4758.60 -929.91 1015.26 405.68 86. 01 L 4.00 4.87 5951430.76 676251.31 N 70. 27289407 W 148. 57433341 5200.00 43.95 4.52 4780.38 4830.88 -977.79 1083.77 414.57 81. 85E 4.00 4.93 5951499.46 676258.58 N 70. 27308123 W 148. 57426156 5300.00 44.66 358.88 4851.97 4902.47 -1020.93 1153.53 416.62 77. 81 L 4.00 4.98 5951569.24 676259.00 N 70. 27327182 W 148. 57424494 5350.00 45.12 356.12 4887.39 4937.89 -1040.65 1188.78 415.08 75. 86E 4.00 5.01 5951604.44 676256.64 N 70. 27336811 W 148. 57425738 5400.00 45.64 353.41 4922.52 4973.02 -1059.11 1224.21 411.83 73. 95E 4.00 5.03 5951639.79 676252.56 N 70. 27346491 W 148 .5744 5500.00 46.87 348.14 4991.69 5042.19 -1092.15 1295.46 400.22 70. 30E 4.00 5.08 5951710.74 676239.30 N 70. 27365956 W 148 .5743 8 5600.00 48.33 343.10 5059.15 5109.65 -1119.89 1366.93 381.85 66. 90E 4.00 5.12 5951781.76 676219.27 N 70. 27385482 W 148 .57452599 UG1 5683.62 49.71 339.06 5114.00 5164.50 -1138.91 1426.62 361.37 64. 25E 4.00 5.16 5951840.95 676197.39 N 70.27401788 W 148. 57469165 5700.00 50.00 338.29 5124.56 5175.06 -1142.19 1438.28 356.82 63. 76E 4.00 5.17 5951852.50 676192.57 N 70. 27404974 W 148 .57472846 5729.00 50.52 336.94 5143.10 5193.60 -1147.62 1458.90 348.32 95. 00E 4.00 5.18 5951872.91 676183.60 N 70. 27410606 W 148 .57479713 5800.00 50.33 333.27 5188.34 5238.84 -1158.62 1508.52 325.30 92. 66E 4.00 5.21 5951921.98 676159.42 N 70. 27424164 W 148 .57498337 5900.00 50.26 328.07 5252.25 5302.75 -1168.20 1575.55 287.63 89. 33E 4.00 5.25 5951988.10 676120.20 N 70. 27442476 W 148 .57528797 6000.00 50.42 322.87 5316.10 5366.60 -1170.82 1638.93 244.02 86. 02E 4.00 5.29 5952050.45 676075.12 N 70. 27459792 W 148 .57564070 6050.00 50.59 320.29 5347.91 5398.41 -1169.53 1669.16 220.05 84. 38E 4.00 5.31 5952080.10 676050.45 N 70. 27468050 W 148. 57583458 6100.00 50.81 317.72 5379.58 5430.08 -1166.49 1698.36 194.67 82. 75E 4.00 5.33 5952108.70 676024.40 N 70. 27476027 W 148 .57603984 6200.00 51.43 312.65 5442.37 5492.87 -1155.21 1753.54 139.82 79. 56E 4.00 5.37 5952162.58 675968.28 N 70. 27491102 W 148 .57648344 6300.00 52.26 307.67 5504.17 5554.67 -1137.04 1804.20 79.74 76. 49E 4.00 5.40 5952211.82 675907.04 N 70. 27504944 W 148 .57696934 WeIlDesign Ver SP 2.1 Bld( users) 07-14\07-14\Plan 07-14C\07-14C (P4) Generated 4/16/2009 10:02 AM Page 1 of 3 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Mag I 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 b4VV .UU 03.Zy 3VZ.ifZ OOb4.by Ob10."I `J -111Z.U/ "ItlOU.II "14./3 /S .OOL 4.UU 0.44 OyOZZOb.Iy b/OC4U.yt5 N/U.Z/01/4150 VV14t7 .0//4JOlt5 6429 .00 53.63 301.43 5581.95 5632.45 -1103.57 1862.50 -5.00 94 .00E 4.00 5.45 5952268.12 675820.96 N 70.27520870 W 148 .57765478 6500 .00 53.48 297.91 5624.14 5674.64 -1080.50 1890.77 -54.61 91 .91 L 4.00 5.47 5952295.22 675770.71 N 70.27528593 W 148 .57805606 6600 .00 53.46 292.93 5683.68 5734.18 -1042.68 1925.24 -127.15 88 .94E 4.00 5.50 5952327.98 675697.39 N 70.27538010 W 148 .57864276 6700 .00 53.63 287.96 5743.13 5793.63 -998.82 1953.32 -202.48 85. 99E 4.00 5.53 5952354.29 675621.43 N 70.27545680 W 148 .57925202 WS2 6716. 66 53.68 287.14 5753.00 5803.50 -990.94 1957.36 -215.27 85. 50E 4.00 5.54 5952358.04 675608.55 N 70.27546785 W 148. 57935549 6750. 00 53.80 285.49 5772.72 5823.22 -974.69 1964.91 -241.07 84. 52E 4.00 5.55 5952364.98 675582.58 N 70.27548848 W 148. 57956419 6800 .00 54.01 283.03 5802.18 5852.68 -949.13 1974.86 -280.22 83. 07E 4.00 5.56 5952374.01 675543.21 N 70.27551565 W 148 .57988088 6900 .00 54.60 278.15 5860.55 5911.05 -893.84 1989.77 -360.01 80. 23E 4.00 5.59 5952387.05 675463.10 N 70.27555637 W 148 .5805 7 7000 .00 55.37 273.36 5917.96 5968.46 -833.24 1997.96 -441.46 77. 48E 4.00 5.62 5952393.34 675381.49 N 70.27557875 W 148 .581 WS1 7074. 63 56.07 269.85 5960.00 6010.50 -784.72 1999.68 -503.08 75. 50E 4.00 5.64 5952393.62 675319.85 N 70.27558344 W 148. 5816 7100 .00 56.33 268.67 5974.12 6024.62 -767.61 1999.41 -524.16 74. 84E 4.00 5.65 5952392.85 675298.78 N 70.27558269 W 148 .58185397 7129 .00 56.64 267.33 5990.13 6040.63 -747.68 1998.56 -548.32 94. 12E 4.00 5.66 5952391.44 675274.65 N 70.27558037 W 148 .58204941 7200. 00 56.48 263.93 6029.27 6079.77 -697.51 1994.05 -607.38 92. 25E 4.00 5.68 5952385.55 675215.71 N 70.27556803 W 148 .58252710 7300 .00 56.41 259.13 6084.56 6135.06 -623.98 1981.78 -689.77 89. 60E 4.00 5.70 5952371.36 675133.64 N 70.27553449 W 148 .58319349 CM3 7384. 02 56.50 255.10 6131.00 6181.50 -559.83 1966.17 -758.02 87. 37E 4.00 5.73 5952354.16 675065.78 N 70.27549182 W 148. 58374549 7400. 00 56.54 254.33 6139.81 6190.31 -547.40 1962.66 -770.87 86. 95E 4.00 5.73 5952350.35 675053.01 N 70.27548222 W 148 .58384945 7500. 00 56.84 249.56 6194.76 6245.26 -468.16 1936.76 -850.29 84. 32E 4.00 5.76 5952322.61 674974.23 N 70.27541146 W 148 .58449177 End Crv 7595. 33 57.30 245.05 6246.60 6297.10 -390.49 1905.90 -924.07 --- 4.00 5.78 5952290.03 674901.19 N 70.27532711 W 148 .58508853 CM2 8343. 87 57.30 245.05 6651.00 6701.50 226.68 1640.19 -1495.18 --- 0.00 5.87 5952011.07 674336.48 N 70.27460096 W 148. 58970741 Crv 4/100 8719 .97 57:30 245.05 6854.20 6904.70 536.77 1506.68 -1782.14 146. 66E 0.00 5.92 5951870.90 674052.74 N 70.27423606 W 148 .59202808 8800. 00 54.64 242.89 6898.98 6949.48 601.98 1477.60 -1841.73 145. 45E 4.00 5.93 5951840.44 673993.85 N 70.27415658 W 148 .59251000 8900. 00 51.38 239.99 6959.14 7009.64 681.06 1439.47 -1911.89 143. 71 L 4.00 5.95 5951800.68 673924.61 N 70.27405235 W 148 .59307734 9000 .00 48.20 236.82 7023.70 7074.20 757.12 1399.51 -1976.94 141. 66E 4.00 5.97 5951759.21 673860.51 N 70.27394315 W 148 .59360338 9100 .00 45.11 233.31 7092.34 7142.84 829.78 1357.93 -2036.57 139. 25E 4.00 5.99 5951716.25 673801.88 N 70.27382950 W 148 .59408555 9200 .00 42.15 229.42 7164.73 7215.23 898.70 1314.92 -2090.48 136. 43E 4.00 6.01 5951672.00 673748.98 N 70.27371197 W 148 .59452151 CM1 9251. 04 40.69 227.27 _ 7203.00 7253.50 932.33 1292.49 -2115.71 134. 82E 4.00 6.02 5951648.99 673724.29 N 70.27365067 W 148. 59472550 9300 .00 39.33 225.07 7240.50 7291.00 963.54 1270.70 -2138.42 133. 14E 4.00 6.02 5951626.68 673702.09 N 70.27359113 W 148 .594 9400 .00 36.69 220.19 7319.31 7369.81 1023.98 1225.48 -2180.15 129. 28E 4.00 6.04 5951580.50 673661.43 N 70.27346756 W 148 .59524652 9500 .00 34.28 214.69 7400.75 7451.25 1079.73 1179.49 -2215.47 124. 80E 4.00 6.05 5951533.69 673627.20 N 70.27334187 W 148 .59553204 9600 .00 32.14 208.50 7484.43 7534.93 1130.52 1132.93 -2244.20 119. 63E 4.00. 6.07 5951486.48 673599.57 N 70.27321467 W 148 .59576430 9700 .00 30.34 201.61 7569.95 7620.45 1176.09 1086.05 -2266.21 113. 73E 4.00 6.08 5951439.10 673578.66 N 70.27308657 W 148 .59594218 End Crv 9722 .00 30.00 200.00 7588.97 7639.47 1185.39 1075.72 -2270.14 --- 4.00 6.08 5951428.68 673574.98 N 70.27305833 W 148 .59597392 THRZ 9723. 19 30.00 200.00 7590.00 7640.50 1185.89 1075.16 -2270.34 -- 0.00 6.08 5951428.12 673574.79 N 70.27305681 W 148. 59597556 TJD 10225. 48 30.00 200.00 8025.00 8075.50 1395.29 839.16 -2356.24 --- 0.00 6.10 5951190.19 673494.43 N 70.27241200 W 148. 59666965 TJC 10299. 38 30.00 200.00 8089.00 8139.50 1426.10 804.44 -2368.88 --- 0.00 6.11 5951155.18 673482.61 N 70.27231713 W 148. 59677177 TJB 10495. 68 30.00 200.00 8259.00 8309.50 1507.94 712.21 -2402.45 --- 0.00 6.11 5951062.20 673451.21 N 70.27206514 W 148. 59704301 TJA 10608. 84 30.00 200.00 8357.00 8407.50 1555.11 659.04 -2421.80 -- 0.00 6.12 5951008.60 673433.11 N 70.27191987 W 148. 59719937 TSAG 10704. 67 30.00 200.00 8439.99 8490.49 1595.06 614.01 -2438.19 -- 0.00 6.12 5950963.21 673417.78 N 70.27179685 W 148. 59733178 10722 .00 30.00 200.00 8455.00 8505.50 1602.29 605.87 -2441.15 --- 0.00 6.12 5950955.00 673415.00 N 70.27177460 W 148 .59735572 WeIlDesign Ver SP 2.1 Bld( users) 07-14\07-14\Plan 07-14C\07-14C (P4) Generated 4/16/2009 10:02 AM Page 2 of 3 Comments Measured Inclination Azimuth SutrSea 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 1100 ft Index ftUS ftUS /~~c;$g IU/LL.UI 1V.VV LVU.VV d4VV.V/ 0~7U.7..7/ IOVL.Cy VUV.00 -LYY1./V °- V.VV V.IL J.7JV.7JV.yy V/JYIV.VV IY/V.L/I//Y:JV YY /YV.V.7/JVU/Y Bld 10/100 10727.00 30.00 200.00 8459.33 8509 .83 1604.37 603.52 -2442.00 67 .31E 0.00 6.12 5950952. 63 673414.20 N 70 .27176818 W 148.59736263 TSHU 10755.66 31.21 194.89 8484.00 8534. 50 1616.15 589.61 -2446.36 62. 92E 10.00 6.13 5950938. 62 673410.17 N 70. 27173017 W 148.59739785 10800.00 33.44 187.72 8521.48 8571 .98 1633.65 566.39 -2450.96 56 .85E 10.00 6.14 5950915. 30 673406.12 N 70 .27166674 W 148.59743494 TSAD 10845.66 36.11 181.22 8559.00 8609. 50 1650.66 540.46 -2452.94 51. 51E 10.00 6.15 5950889. 33 673404.75 N 70. 27159589 W 148.59745086 10900.00 39.69 174.56 8601.89 8652 .39 1669.42 507.15 -2451.63 46 .25E 10.00 6.17 5950856. 07 673406.83 N 70 .27150490 W 148.59744022 End Bld 10991.00 46.37 165.48 8668.43 8718 .93 1696.78 446.22 -2440.59 --- 10.00 6.19 5950795. 41 673419.29 N 70 .27133844 W 148.59735080 TCGL 11096.18 46.37 165.48 8741.00 8791. 50 1725.26 372.52 -2421.50 -- 0.00 6.20 5950722. 18 673440.10 N 70. 27113711 W 148.59719622 BCGL 11199.08 46.37 165.48 8812.00 8862. 50 1753.12 300.41 -2402.82 -- 0.00 6.20 5950650. 54 673460.45 N 70. 27094014 W 148.5970 9 Crv 11.5/100 11215.22 46.37 165.48 8823.14 8873 .64 1757.50 289.10 -2399.89 HS 0.00 6.20 5950639. 30 673463.65 N 70 .27090924 W 148.597 23S8 (1228) 11282.53 54.45 165.53 8866.00 8916. 50 1776.91 238.92 -2386.92 HS 12.00 6.22 5950589. 44 673477.79 N 70. 27077216 W 148.5969 4 11300.00 56.55 165.55 8875.89 8926 .39 1782.31 224.98 -2383.33 HS 12.00 6.23 5950575. 59 673481.71 N 70 .27073409 W 148.59688714 11400.00 68.54 165.61 8921.91 8972 .41 1815.59 139.20 -2361.27 HS 12.00 6.26 5950490. 35 673505.76 N 70 .27049976 W 148.59670854 22TS 11405.79 69.24 165.61 8924.00 8974. 50 1817.62 133.96 -2359.92 HS 12.00 6.26 5950485. 15 673507.23 N 70. 27048546 W 148.59669766 11500.00 80.54 165.66 8948.51 8999 .01 1851.82 46.00 -2337.40 HS 12.00 6.29 5950397. 74 673531.80 N 70 .27024516 W 148.59651529 Target 1 11578.79 90.00 165.70 8955.00 9005 .50 1881.42 -30.00 -2318.00 90. OOR 12.00 6.31 5950322. 22 673552.97 N 70 .27003755 W 148.59635824 End Crv 11580.74 90.00 165.93 8955.00 9005 .50 1882.16 -31.88 -2317.52 --- 12.00 6.31 5950320. 35 673553.49 N 70 .27003241 W 148.59635438 TD / 4-1/2" Lnr 12475.69 90.00 165.93 8955.00 9005 .50 2223.53 -900.00 -2100.00 --- 0.00 6.41 5949457. 61 673791.22 N 70 .26766094 W 148.59459347 Leaal Descriotion: Northina (Yl fftUSl Eastina (Xl fftUSl Surface : 4768 FSL 314 FEL S33 T11 N R14E UM 5950406.37 675869.48 Target 1 : 4738 FSL 2632 FEL S33 T11 N R14E UM 5950322.22 673552.97 TD / BHL : 3868 FSL 2416 FEL S33 T11 N R14E UM 5949457.61 673791.22 WeIlDesign Ver SP 2.1 Bld( users) 07-14\07-14\Plan 07-14C\07-14C (P4) Generated 4/16/2009 10:02 AM Page 3 of 3 . by Schlumberger WELL DS07-14C (P4) FIELD Prudhoe Bay Unit - EOA BTRDDTURE DS-07 Ma9na0c Paramelen MaCel: BGGM 2008 DID_ &0909' Dale my b.2009 Gu~ace Localbn NNJ2] Nasky State Planes. Zone 04. DS Feet Lal'. N>01fi 13434 No~bing: 595060637Itt1S GnJ COnv: •133691560° Mhcellaneous Sbt: 0]-14 TVD Ref'. Roiary Table (50.50 M1above MBL) Mag Dec. .2264]° FS'. 5]]18.3 nT Lon: W148 36 39 413 Easing: 6]5869.68Itt15 Scale Fact: 0.9999351363 Plan. 0]~16C (P4) Srvy Date'. Apn116. 2009 Tie-In SI T p Whipstt ase Whip: .._.Gcv: 4800 ....... 5600 8400 O 0 c II -800 °-' m <n 9000 07-14 ~ Zia .._.._.._.. -1200 -600 0 600 7-14C (P4) ~.._.._. ~B .._.._..T.~_.._.._..-.._.._.._.._.._.._.._..-.._.._.._.._..-.._.._..~.._.._.._.._.._.._ ..~..i,..,.. ~ ,.+.81dQY14Y0~+.+v..,~..w......,.,w..w•.,i......w.ww~.~w~.~«.r~..i,.v.,..w,..,w+w... .- _..~ H~.. _.._.._. _j._.._.. _.. _.._.._.. _.._..y. _.._. ~.._..-.._.._.._•.~. _.._.._.._.._. _ Crv 71.51100 ,_.._..~.._.._.._.._..-..-..-.._..F.._.._.. _.._.. _.._ .- _.._.._.._.._.._ .Gt.._ _.._.._.._.._. .. .. .. ... . 7-S4C P4 Target 1 End Crv TD 14112" Lnr -1200 -600 0 600 Vertical Section (ft) Azim = 170°, Scale = 1(in):600(ft~ Origin = 0 N/-S, 0 E/-V .................................................................:.................................. ~.................................. ............................ 5600 6400 I ...........................:...................................................i..................................i..................................i............................~ 6400 C cA 7200 I '.._.._.._.._.._.._ _ ._.._.._..-.._.._.._.. -.._.._.._.._.._.._..-?..-.._.._.._.._. _.._.._..-.._.._..-.._..;.._.._.._..-.._.._.._1 7200 o r H End Crv 8000 ........................... i .................................. i.......................................................... ......... i.................................. .......................... 8000 ._.._.._.._.._.._ ._.._.._.._.._..-.._..- .._.._.._.._.._.._.._.._ -.._.._.._.._.._.._.._. _. _SA. .._.._.._.._ _ -.._.._.._.._.._.._ Crv 17.51100 8800 ? : _ 8800 ._.._.._..~..~ . ~~~~.~..~..~..~. ~..~ ~.._.i- .~..~~ ~..~..~..~ ~.. _.~_.._.._.._.._.._.._. _.._ ~ k T71SL..=.. .~~ _..~..~~ _.._..~.._ - _ - - 7-14C (P4) Target 1 Entl Crv TD 14.1/2" Lnr -800 0 800 1600 2400 Vertical Section (ft) Azim = 233.51°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V 8400 9000 by Schlumberger WELL FIELD STRUCTURE DS07-14C (P4) Prudhoe Bay Unit - EOA DS-07 Magnetic Parameters SuNace Loralun NND2) AlasMa Stela Planes, Zone 04, US Feel Miscellareous Motlel: BGGM 1008 DID: 80809° Dale. Pugwl0l. ]009 LaL. N]016 12434 NonbNg: 595040fi 3]flU5 Grit Gwrv: X133891540° Sbl: 0]-14 TVD Ret: Rotary Table (50.50flabove MSL) Meg Deo. ~21.6a5° FS'. 5]]18.5 nT Lon'. W1483d 39411 Easeng'. fi]8Bfi94811US Scala Fah: 0.9999351363 Plan'. 0]-14C (P4) Srvy Dale. April 16, 1009 -3000 -2400 -1800 -1200 -600 0 600 1800 n 1200 A A Z a= 0 O C 600 N t0 U V v v 0 -600 ........ i .................................. ¢..................................i....................... crv atoo End Crn ........:............TnC~......... ~............................,.....:................. Bld 101100 End Bld Crv 17.51100 .............................................................................1................. Target 1 End Crv To 1 avZ° Lnr ~-tac (Pa> End ~-ta ;. ~ .............. .............. i..... ........................ N crv anoo ~ E Base Whipstock Tdp Whipstock Ti~ln Survey i .......... i ..................................:...................................i .................................. i .............................. 1800 1200 600 0 -600 •I • 3000 -2400 -1800 -1200 -600 0 600 c« W Scale = 1(in):600(ft) E »> -- - xp oration A al s~ _ -- ~n~~io~epor~ Comparry: North America -ALASKA - BP LocaFCo-ordi Reference: Well 07-14 Project; .Prudhoe Bay TVD Reteror~e: 07-14C Plan ~ 50.50ft (Nabors TES) R~tsnnce Sib: PB DS 07 MD Referonce: 07-14C Plan ®50.SOft (Nabors 7E3) $ke Error: O.OOft North Reference: True 'Retenenc~ Welb , 07-14 Survey Calcula8on Methork Min~num Curvature Well"Errs': ' ! O.OOft Output errae are at 1.00 sgma Referierrce YVeiibore ' Plan OT-14C Datet-aee: EDM .16 - Anc Prod - WH24P Refafance lJ~ign: 'Plan #4 07-14C OffsefTilD Refierence: ` ;Offset Datum Refei+en~, Plan #4 07-14C Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refen Depth Range: 5,000.00 to 12,475.69ft Scan Method: Trav. Cylinder North Survey Tool Program Date 4!16/2009 From To {fU (R) Survey (We~oro) Tool Neme Descrfp~iorr 86.50 4,986.50 1 : Camera based gyro muldsho (07-14) CB-GYRO-MS Camera based gyro multistwt 4,986.50 6,400.00 Plan #4 07-14C {Plan 07-14C) MWD MWD -Standard 4,986.50 10,722.00 Plan #4 07-14C (Plan 07-14C) MWD+IFR+MS MWD +IFR + Multi Station - - - 4Tf672(T09 TOOT= Page 2 of 4 COMPASS 2003.16 Build 70 ---- ---__.B -xp oratfon7~las~ - - -- Kn~ico~on~2e~o-_r~ __ Compsrry: Nortl~ America -ALASKA - BP Local Co-a~r+see Referonice: Well 07-14 _ Project:..: Prudhoe Bay TVD Reference: 07-14C Plan ~ SO.SOft (Plabors 7ES) Referents 81te: ' PB DS 07 MD Reference: ! 07-14C Plan (cj; 50.50ft (Natwrs 7ES) Site Error: O.OOft trforth Rehronce: 'True Referonce Welk ' 07-14 Surrey CakulaNon [MelFtod: Minanum Curvature Well Error: O.OOft output errors aro at 1.00 sigma !Referonce 11Vellbore : Plan 07-14C Database: EDM .16 - Anc Prod - WH24P Reference Dsslgrc Plan #4 07-14C Offset TVD Rsferonce: ` 'Offset Datum Summary Reterer~e offset Centro to No-~3o Alflawabte Nesaured fMeasurod Cemre Dlatar~ce Devistbn warning Ska Name ' ~+ astance (R) from Plen oMsaE WeN - Welt~ors - Design _ C8) _ Cn) Cif _ _ (~) Pa os o7 __ -07= - - - rr,998.J2 9;8ta~ -1;189.82- --2o4:5A 9s22~ Pass-MajorR;sk- 07-03 - 07-03A - 07-03A 12,041.91 9,695.00 1,189.85 204.55 995.28 Pass -Major Risk 07-03 - 07-03AP61 - 07-03AP61 12,041 .91 9,695.00 1.189.85 ~ _204.18 995.65 Pass=Major Risk - _ __ 07-04 - 07-04 - 07-04 _ _ Out of range 07-04A - 07-04A - 07-04A 11,989.02 9,938.00 547.21 226.14 627.75 Pass -Major Risk 07-09 - 07-09 - 07-09 9,764.17 8,730.00 663.67 191.65 476.92 Pass -Major Risk 07-13 - 07-13 - 07-13 8,412.54 7,055.00 1,321.23 174.81 1,172.14 Pass -Major Risk 07-13 - 07-13A - 07-13A 8,413.55 7,045.00 1,321.29 174.82 1,172.14 Pass -Major Risk __ __ 07-13 - 07-13B - 07-13B 8,413.55 7,045.00 1,321.29 174.82 1,172.14 Pass -Major Risk 07-13 - 07-138 -Plan #6 8,413.55 7,045.00 1,321.29 174.93 1,172.03 Pass -Major Risk 14-~7-~ - ~ ~ _ --- ~, 3599-- 1-5©-.90 -- 5,- - - 7 SQ - _ 145?~ - -137.65 FAlL---Ma. . ---- 07-14 - 07-14A - 07-14A 5,135.99 5,150.00 7.58 145.61 -137.54 FAIL -Major Risk 07-14 - 07-146 - 07-146 5,135.99 5,150.00 7.58 145.61 -137.54 FAIL -Major Risk - 46PBi = 07=146PB1- ____-5;1.35:95 ---5~T50:00 -_ _T.58 __,4561- ='f37:54 FAIL-= alor is _-_. 07-27 - 07-27 - 07-27 5,000.00 5,240.00 506.14 183.33 370.55 Pass -Major Risk - - OZ-28-Q7-2A _ _ _ 2,220.32 6 3~n.00 _ - ].,285.07 _ __172.4D 1.,1.14.Q'L_ Pass - Major__Risk- 07-28 - 07-28A - 07-28A 7,219.22 6,285.00 1,284.98 172.33 1,.114.01 Pass -Major Risk 07-28 - 07-28AL1 - 07-28AL1 7,219.22 6,285.00 1,284.98 172.33 1,114.01 Pass -Major Risk 07-28 - 07-28AL1 -Plan #4 7,219.22 6,285.00 1,284.98 172.23 1.,114.11 Pass -Major Risk 07-28 -Plan 6, 07-28B -Plan 6 7,219.22 6,285.00 1,284.98 172.16 1,114.18 Pass -Major Risk 07-29 - 07-2907-29 __ 6 480.79 6,135.00 _- 630.66 _._ __152.34 _.494.69 Pass - Ma'oJ r Risk 07-29 - 07-29A - 07-29A 6,480.79 6,135.00 630.66 152.45 494.58 Pass -Major Risk 07-29 - 07-29AP61 - 07-29AP61 6,480.79 6,135.00 630.66 152.34 494.69 Pass -Major Risk -296 = 0~2~~ 6;480:79 - ^.~ , 3~ ao --- 63~6fr- _ -1T2:45 -494.5? -Pass -Major Risl~ 07-29 - 07-296 -Plan #11 6,480.79 6,135.00 630.66 152.45 494.58 Pass -Major Risk 07-29 - 07-296P61 - 07-296P61 6,480.79 6,135.00 630.66 152.34 - 494.69 Pass -Major Risk _ -- - -- - 07-29 - 07-29C - 07-29C 6,481.95 _ 6,125.00 630.66 152.34 494.69 Pass -Major Risk 07-29 - 07-29D - 07-29D 6,481.95 6,125.00 630.66 152.33 494.69 Pass -Major Risk 07-30 - 07-30 - 07-30 8,089.81 7,025.00 579.70 189.16 392.10 Pass -Major Risk 07-30 - 07-30A - 07-30A 8,089.81 7,025.00 579.70 189.16 392.10 Pass -Major Risk 07-30 - 07-30A -Plan #5 8,089.81 7,025.00 579.70 189.27 391.99 Pass -Major Risk __. 07=30 = 07=306-= 07=30 X689:81 7~02~00-- -379:T~ ___ ~5~1~-- X92:1 ~ - -P ss = Major i~ a 07-32 - 07-32 - 07-32 5,000.00 5,495.00 939.66 194.17 847.94 Pass -Major Risk --07-32 - 07-3~A - OZ-32A_ __- _ 5-000.00 5,4Q5 nn -__ 939.66 .__~_94_>Z ---847_.9~. _PassMajocRisk 07-32 - 07-32AP61 - 07-32APB1 5,000.00 5,495.00 939.66 194.17 847.94 Pass -Major Risk 07-32 - 07-32B - 07-32B 5,000.00 5,495.00 939.66 194.17 847.94 Pass -Major Risk .7-32 = tT7-026 =Plan #2-- - - - _ _-- 5;000:00- --6495:00 939:66 . 109 -$48:02 "Pa~~MajofRis 07-32 - 07-32PB1 - 07-32PB1 5,000.00 5,495.00 939.66 194.21 847.92 Pass -Major Risk 07-35 - 07-35 - 07-35 10 787.39 12.415.00 928.66_ 300.55 655.09 Pass_Major Risk _ 07-37 - 07-37 - 07-37 8,743.41 8,025.00 352.65 237.73 177.09 Pass -Major Risk d11 fi7200Sf0~1:2~ - Page 3 of 4 COMPASS 2003.16 8uiid 70 ~~ Project: Prudhoe Bay - -- ----- Site: PB DS 07 Well: 07-14 Wellbore: Plan 07-14C Design: Plan #4 07-14C From kop to TD Scan interval 100 ft -- - - - - Scale 1:100 0 350 330 30 30 2 20 300 BO 1 07-37!07-37 / t ( 87 11 5 07-7 4x07-1 270 87 59 90 55 56 58 56 57 1 t 2qp 120 2 300 210 _ _. - 150 - __ _ - - _ _ - - - - - - - - _ 350 180 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [100 ft/in] Alaska Department of Natura esources Land Administration System Page 1 of Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources ~® Alaska DNR Case Summary File Type: ADS File Number: 28309 ~ Printable Case File Summary See Township, Range, Section and Acreage? New Search ~ Yes ~) No LAS Menu. ~ _Case Abstract ~ _C_ ase Detail ~ Land_Abstract File: ADL 28309 ''''! Search_for_Status_Plat Updates As of 04/29/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Tyne: 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: 2560.000 Date Initiated.• 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subt}~pe: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 014E Section: 27 Section Acres: 640 Search Plats Meridian: U Township: O11N Range: 014E Section: 28 Section Acres: 640 Meridian: U Township: 011N Range: 014E Section: 33 Section Acres: 640 Meridian: U Township: O11N Range: 014E Section: 34 Section Acres: 640 Legal Description OS-28-1965 ***SALE NOTICE LEGAL DESCRIPTION*** C14-13011N14E UM 27,28,33,342560.00 U- 3- 7 12-01-1986 ***LISBURNE PARTICIPATING AREA *** T. 11N,R. 14E., U.M. SECTION 27: ALL 640 ACRES http://dnr. alaska.gov/proj ects/las/Case_Summary.cfin?FileType=ADL&FileNumbei-283 0... 4/29/2009 • TRANSMITTAL LETTER CHECKLIST WELL NAME /~~G/ 4 s?- /~C PTD# v~494S'~ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: f~.eG/~~/4~' lSA1~ POOL: ~,Eud~/D~'_~,Q~/ ~/G Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS W~.I. (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(fj, 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 throu h tar et 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 ro ram. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pooi PRUDHOE BAY, PRUDHOE OIL •640150 Well Name: PRUDNOE BAY UNIT 07.140 Program DEV Well bore seg ^~ PTD#:2090530 Company BP EXPLORATION (ALASKA/ INC tnitial ClasslType DEV! PEND ~eoArea 890 Unit 11650 OnlOff Shore 9n_ Annular Disposal ^ Administraflon 1 Permit_feeattached---_-_--_----------------------------------- NA-- ---_----- 2 1.easenumbflrappropriate --- ---- -- -- - ------- - Yes ------- - -- - ------ -- - --- -- -- -- -------- 3 Uni-quaurelLnameandnumbe(-- ---------- --- -- -- -------- Yes. ----- --- -- ------ ------ -- -- - -- --- 4 VYelllocatedina_det'irledppol- --------- - --- -- -- --- Yes- - PrudhoeBauOilPpol. - _ - ------ ---------- - --- ------ - 5 Nlelllocatedproperdistanpe_f[om_dri)lingunit-boundary---------------------- Yes- --.-------------------------------------------------------------------- 6 Welllocatedp[operdistanpef(om2therwQlls------------------------------ Yes- ------------------------------------ ------- 7 Suffipientepreageayailableindrillinqunit-------------------------------- Y_es- ------258QaGres.----------------- 8 tfdeviated~is_welippreplattncluded-------- --_ -- -- - -------- Yes --------------- -- ----- --- - -- ----------- -- - - -- - 9 Operetoronlyaff_ectedpadY------- -------- - ----- --- - - Yes- - --- -- -- -- - - - -- -- -------- -- --- - 10 Ope(ato[hasappr9priatebondin_f4rpe------------------------------- Yes- ------Blanketl}ond#6194193•---------------.------------------------------------- 11 Permit-cenbe issued withoutconservatipnorder---_----------------------- Yes- ------------------------------------------------------------------------- Appr Date 12 Pe(mitcenbeissuedwithoutadmirtist(ativeapproYal------------------------ Yes- ----------------.--.---------------------------------------------------- 13 Canpemjitbeapprovedbefprel5-deY-u/air---- - - ----- -- - ------ Yes- - --- -- -- - - ----------------- ----- -- -- - --- --- ACS 412912009 t4 UYeIIlocatedwhhinareaaRdstrataeuthprizedky-InJectipnprder#(put_IQ#in_comments)_(Fpr_ NA__ __--_------.--_--------------------_-_------------------------------- 15 Ahweps_wkhin114_mi(eateaof(eviewidentifiiQd(Forservicewellpnly)--------------- NA-- --.----------------.--------------------------------------------------- 16 Pre-producedinleptoe.dura6onofprep(oducti9nless_tban3manths_(Fprserviceweltpnly?-- JVA- -----------------.--------------------------------------------------- 17 NOnGOnYen: gas cpnformsto A831,D5.03Q(I1.A):(L2,A•D) - - - - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 Conductor st(iRg-P7pvided - - - - - - - - - - - - - - _ - - - - - - - - - NA - - - - - - - Cpnduptpr set-in DS 07.14 (17$-0$1).- - - - ... - - - - - - - - - - - - - - - - - - Engineering 19 Surfacecasing_prot@ctsallknpwnU3DWS_---------_------_-__--_--_- NA_- ----__NOaquifers,AIQ48,conclusion5________________---------------------------_-- 20 C-MT-vpladequate_tppi[c~rieteon_cprlduptpr8,&urf_csg___________________--_- NA_- ---_-Surfap~spasingset)n_D$07-14.-_______-__--__-___-____.------_------_--_____.. 21 CMT_vpladequate_kptie•inlongstringtosurfS~q-------------------------- NA-- ------Product~n_casingselinD$07.14,---------------------------------------------- 22 CMT_willooyerailknownprpduotivehon~o4s--- - - - -- -- -- Y~ ------ -- -- -- ------ - - - ---- --- ------ --- 23 GesingdesgnsadequatefQ(C,TB&.permafrost---- - - -- - - - Yes -- - - -- -- - ----- ---------- -- - ---- -- - - 24 Adequate tankage_or reserve pii - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - Yes - - _ - - - -Rig equipped with steel pits, No reserve pit planned.. All waste-tp approved disposal well(s), - - - _ - - _ - - - _ - - 25 Ifa_re-d(ill,has-a10.403forab&ndpnment4een approved---------.---------- Yes- ------309,159---------------------------.-------------------------------- 26 Adequate wellpore separationproppsed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - _ - . - -Proximity analysis perfpmed. _Traveting_cylinder_path calculated. - . - . - - - - _ - - - - - - _ - - - _ - - _ - - _ - - 27 Ifdive[terregsrited,doesit_meetrQgulatiprls------------------------------- NA-- ------~QPStapkwillalready_beinplace:------------------------.---------------------- Appr Date 28 Dntling f)uld:prpgram schematic-& equip list adequate- - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - - - -Maximum expepied fo[maiipn pressure 7,1_EMW in-zone,- MW_planned_up tp 1Q.2 ppg_in HRZ and $.5 ppg.in Zpn- TEM 5/20!2009 29 BOPES,dot#leymeetregulati9n- -------- - - - - ------- - Yes- ------ -- ----- ---------- - ----------- -- ----- ---- ~/ 30 t3OPE-press (acing appropriate; test to_(put prig in cpmments)- - - - - - - - - - - - - - - - - - Yes - _ _ _ _ _ _ _ .. _ _ _ _ _ _ - _ _ _ _ _ _ _ . _ _ _ - - - _ - MASP palculaiad_at 2360 psi, 3@00_psi_EQP testptanned, lA~,~- 31 Choke_manifpldpomplieswlAPfRP-53(May$4)---------------------------- Yes- _ _ _ _ _ _ _ ---_---___- 32 Wod<willppeurwithputoperaiionshutdown_______---------------------- Yes- ----------------------------------------------------------------------- 33 is Rresenpe_ of H2S gas-prpbable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - - - _ - - H2$ is repoded at P$ 7: Mud should_preclude H2$ pn rig. _Rig has sensprs and alarms.- _ _ - - . - _ . - - _ - . - 34 Mechenical_cpnditionofwyellswithinAORverified(_F9[seNicewsllpnly)-------------- NA-- ------------------------------------------------------------------------ 35 Permit,cenbeissuedwlohyd(ogen-sulfide measures-_-_--__--____---_---_ No-_ -___-_Maxlev_efH2$pn_Padwa8150ppm-(7121193)._--_-_-____--------------- _--_ Geology 36 Data_ptesQntedpnpotential9verpre&sr~r®zpnes---------------------------- NA-- -------------- Appr Date 37 S~~nicanalysis_pfshailpwgaszpoes---- - ---- - -- --- ~-- --- --- - - - -- -- - ------ -- -- - - - - -------- - ACS 412912009 38 Seabedcpnditionsurvey_(ifpftshore}---------------------------_----- NA__ -__-___-___________-_____---_---_---__-_--__-----_-------- 39 Coptapinamelphanefotweekly_progress[epprts_{exploratorypnlya_______________ Yes- -----_Gar(etStaudinger-564.4242,-__--___________-__--_-------_------_------..__ Geologic Camm' sinner: ~ ~' ' Engineering Public Date: Commissioner: Date Commissioner Data J J ~ 5~ 1Q p~ S d o ~ CJ
