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207-124
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 G-19B Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-124 50-029-21599-02-00 13692 Conductor Surface Intermediate Liner Liner 8999 80 2674 9458 1324 3196 13670 20" 13-3/8" 9-5/8" 7" 4-1/2" 9000 31 - 111 31 - 2705 29 - 9487 9342 - 10666 10494 - 13690 31 - 111 31 - 2642 29 - 7543 7433 - 8409 8284 - 8999 13569 2670 4760 5410 7500 None 5380 6870 7240 8430 10677 - 13550 4-1/2" 12.6# 13Cr80 27 - 10511 8417 - 9004 Structural 4-1/2" Baker S-3 Perm Packer 10433 8241 Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@@hilcorp.com 907-564-5026 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 0028280 27 - 8296 N/A N/A 281 Well Not Online 29637 34 0 0 1000 1850 324-436 13b. Pools active after work:Prudhoe Oil No SSSV Installed 10433, 8241 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 8:45 am, Apr 07, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.04.05 11:20:22 - 08'00' Torin Roschinger (4662) JJL 5/8/25 RBDMS JSB 041025 DSR-4/7/25 ACTIVITY DATE SUMMARY 3/31/2025 CTU#1 1.5" CT. Job Scope: Depth Log / Ext Adperf MIRU CTU. Perform Weekly BOP Test. Function test.. Cut Coil. MU NS 2-18" CTC/MHA, Pull test CTC. PT MHA 3500 - Good test. ***Continue on 4/01/25 WSR*** 4/1/2025 CTU#1 1.5" CT. Job Scope: Depth Log / Ext Adperf PT PCE 250psi low / 4000psi high. Open well = 2200psi Whp. RIH w/ HES 2-7/8" Logging Carrier & 3.25" JSN. Bullhead/Kill well with 1% KCL w/ Safelube. Keep well dead while Rih. Tagged PBTD at 13624' ctm. Logged from compression up to 10300'. Flagged Pipe at 12150'. Pooh while pumping down backside. ~ 2.2 bpm to keep hole full, plan to do continuous hole fill. Hold PJSM in regards to continuous hole fill. Break off at QTS. Break down tools. Good data (-13' Correction). OE approved correction. Corrected PBTD= 13610.52'. Correlate to PDS Coil Flag 29- July-2011. Wait on winds for gun deployment. Tagged Stripper with Connector / Pressure Tested Safety Joint-TIW / Bump Tested H2s/LEL Alarms / Verified blow out sub x-over fit to perf guns and safety joint/ verified 1/2" ball seats in firing head ***Continue on 4-2-25 WSR*** 4/2/2025 LRS CTU #1 1.5" CT Job Scope: Depth Log / Ext Adperf Maintain cont. hole fill while standing by for WS crane to be swapped out: 0.6bpm 1% slick KCL w/ SL. Crane arrived. Swap to 60/40 down ctbs maintaining 0.6 bpm cont. hole fill, no flow observed at the trip tank. Deploy 2.5" x 21 2.5" Geo Razor perf guns: ( 378' loaded) (55.58' Blank). During deployment loss rate decreased to 0.35bpm from 0.60bpm. RIH. Correct depth at blue flag. Perforate: 12,217-12,298 , 12,318- 12,461 , 12,472-12,495 - & 12,519-12650 with HES 2.5" Geo Razors, 6spf. POOH and load well with 280 bbl of 1% KCL. Flow check well and confirm no flow. Establish a loss rate of .35bpm and retrieve all guns. Bullhead well with 200 bbl of diesel. Pad operator notified of well status. RDMO. ***Conduct well control drill with day & night crew for kick while deploying/undeploying, stabbing the safety joint/dropping the bha / removing the bha*** ***Job Complete*** Daily Report of Well Operations PBU G-19B PBU G-19B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-124 50-029-21599-02-00 341J ADL 0028280 13692 8999 80 2674 9458 1324 3196 13670 20" 13-3/8" 9-5/8" 7" 4-1/2" 9000 31 - 111 31 - 2705 29 - 9487 9342 - 10666 10494 - 13690 2425 31 - 111 31 - 2642 29 - 7543 7433 - 8409 8284 - 8999 13569None 5380 6870 7240 8430 10677 - 13550 4-1/2" 12.6# 13Cr80 27 - 105118417 - 9004 4-1/2" Baker S-3 Perm Packer No SSSV Installed 10433, 8241 Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 PRUDHOE BAY 8/13/2024 PRUDHOE OIL PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.07.29 10:27:58 - 08'00' Torin Roschinger (4662) Extended Perf w CTU By Grace Christianson at 11:14 am, Jul 29, 2024 DSR-7/31/24SFD 7/30/2024MGR01AUG24 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.02 08:49:30 -08'00'08/02/24 RBDMS JSB 080224 CT Extended Adperf Well: G-19B Well Name:G-19B API Number:50-029-21599-02 Current Status:Operable producer SI – HGOR Pad:G-Pad Estimated Start Date:8/15/2024 Rig:CT Reg. Approval Req’d?10-403/10-404 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:207-124 First Call Engineer Finn Oestgaard Contact:907-350-8420 (C) Second Call Engineer:Michael Hibbert Contact:907-903-5990 (C) Current Bottom Hole Pressure:3250 psi Estimated based on Average Ivishak BHP KWF:7.2 ppg Use seawater or 1% KCL MPSP:2425 psi (BHP - .1psi/ft gas gradient + safety factor) Max Dev:95 deg At 13,288’ MD Min ID:3.725” 10,498’ MD @ XN nipple Tie In Log PDS Coil Flag 7/29/2011 Last SIWHP Estimated 2380 psi Brief Well Summary: G-19B is a horizontal Z1B rotary sidetrack drilled in 2007. The well is currently producing from a 25’ interval in the SAG and a total of 930’ of perforations in the horizontal section from Z1B. The well is currently SI for HGOR. The past 2 years it has been a cycle well showing decent cycle characteristics. The horizontal section slightly toes up resulting in these adperf intervals being 20’ deeper TVD than the deepest toe interval and closer in proximity to the HOT in the area. Objective: Perforate 378’ of net charges over a 433’ interval in Z1B. Procedure: Coiled Tubing Drift and Flag 1. MU GR/CCL in a carrier with JSN drift. RIH beyond 12,650’ (deepest shot depth) Flag pipe for perf depths and pull correlation log. a. CT was last in the well in March 2017 (90’ adperf) and did note any issues with drift or while RIH with perf guns. 2. Correlate with attached log information. a. Correct flag and send to Jeff Nelson and OE for confirmation. Coil – Extended Perforating Notes: Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. CT Extended Adperf Well: G-19B 2. Bullhead 1.2x wellbore volume ~196 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 163 bbls b. 4-1/2” Tubing – 10,511’ X .0152 bpf = 160 bbls c. 4-1/2” Liner – 166’ X 0.0152 bpf = 3 bbls 3. At surface, prepare for deployment of TCP guns. 4. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 5.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review 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. d.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 6.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 2-1/2” Millennium 6 SPF Perf Interval (tie-in depths) Lengths Total Gun Length Weight of Gun (lbs) Run #1 12,217’ – 12,298’ – gun 12,298’ – 12,318’ – blank 12,318’ – 12,461’ – gun 12,461’ – 12,472’ – blank 12,472’ – 12,495’ – gun 12,495’ – 12,519’ – blank 12,519’ – 12,650’ – gun 81’ - loaded 20’ - blank 143’ - loaded 9’ - blank 23’ – loaded 24’ - blank 131’ - loaded 433’ ~3802 lbs (8.78 ppf) 7. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 8. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 9. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 10. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 11. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 12. RDMO CTU. 13. Turn well over to Operations POP. Make up lubricator. - mgr CT Extended Adperf Well: G-19B Attachments: Wellbore Schematic Proposed Schematic Tie-In Log BOPE Schematic Standing Orders Equipment Layout Sundry Change Form CT Extended Adperf Well: G-19B Current Schematic CT Extended Adperf Well: G-19B Proposed Wellbore Schematic Proposed Perforations 12,217’ – 12,298’ (81’) 12,318’ – 12,461’ (143’) 12,472’ – 12,495’ (23’) 12,519’ – 12,650’ (131’) Total footage: (378’) CT Extended Adperf Well: G-19B Tie-in Log CT Extended Adperf Well: G-19B CT Extended Adperf Well: G-19B BOP Schematic CT Extended Adperf Well: G-19B CT Extended Adperf Well: G-19B CT Extended Adperf Well: G-19B Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED MAR 7 1 mo 1, Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations 911ut/ery0.� �p Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing EIChangeA lfyi�(ah✓J (�.�❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Reenter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 207-124 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigrephic ❑ Service ❑ 1 6. API Number: 50-029.21599-02-00 7. Property Designation (Lease Number): ADL 028280 8. Well Name and Number: PBU G -19B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 13692 feet Plugs measured None feet true vertical 8999 feet Junk measured 13569 feet Effective Depth: measured 13670 feet Packer measured 10433 feet true vertical 9000 feet Packer true vertical 8241 feet Casing: Length: Size: MD: TVD. Buret: Collapse: Structural Conductor 80 20' 31 - 111 31 - 111 Surface 2674 13-3/8" 31-2705 31-2642 4930 2670 Intermediate 9458 9-5/8" 29-9487 29-7543 6870 4760 Liner 1324 7" 9342-10666 7433-8409 7240 5410 Liner 10484 4-1/2" 10494 - 13690 8283-8999 8430 7500 Perforation Depth: Measured depth: 10677 - 13550 feet True vertical depth: 8417-9004 feet Tubing (size, grade, measured and true vertical depth) 4-1/2' 12.6# 13Cr80 27-10511 27-8295 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 10433 8241 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 248 27108 0 0 725 Subsequent to operation: 685 36546 0 0 797 14. Attachments: (required per 20 n C 25,070.25.071, a 25.201 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge, Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Oshiro, Joleen Contact Name: Oshiro, Joleen Authorized Title: EG Pad�Enggmeeerr/New Wells Delivery PE Contact Email: JOLEEN.OSHIROtalbo. WM 9/710 Authorized Signature: Date: i q Contact Phone: +1 907 564 4606 Form 10-404 Revised 04/2017 V (NLli"i�bP%MF•4� 9,BDMSL4/MAR 2 2 2019 Submit Original Only of 9B HES RELAY UNIT 046 RIH W/ 4'X 2-7/8" MAXFORCE 6 SPF, 60* PHASING. PERFORATED FROM 10,691' - 10,695' MD. RIH W/ 21'X 2-7/8" MAXFORCE 6 SPF, 60* PHASING. PERFORATED FROM 10670'-10691' MD. POOH. TIED IN USING PDS COIL FLAG 20-JUL-2011. PERF DEPTHS HAVE A 7 FOOT CORRECTION FROM MWD BAKER 10-26-19 REFERENCE LOG. 2/26/2019 ***JOB COMPLETE / DSO NOTIFIED"* TRff = 4-1/16" CNV VVE-LFEAD = CIw ACTUATOR: BAKER KB. ELEV = 67.11' BF. HEV = 40.41' KOP= 10604' Max Angle = 95° @ 132W Datum MD= 11171' Datum TVD= SSW SS 11 SAFETY NOTEAVELL ANGLE > 70- H� TBG I CEFAENTEDBABANDONED2- G-1 9B CBELOW GRADE LEAVING A MONDBORE COMPETION 2028' 9-5/8" HES ES CEMENTH2 9-518.7�ACK CSG, 47#, —LA39• r L80 HY DRL 563, D = 8.68" 13-318" CSG, 72#, L-80 BUTT, D = 12.347" 2705' 9-518- CSG, 47#, L-80 BUTT 4759' XO TO L-80 NSCC. D = 8.681" Minumum ID = 3.725" @ 10498' 4-112" HES XN NIPPLE 9-5/8-EZSVSQDEEZEPKR(09/30/07) I-1 10060' 4Ar-- TBG ST(1B (09/23/07) 9-5/8" CSG, 47#, L -BO NSOC, ID=8.681" 1-1 10595' PHiFORATIDN SlM IMRY REF LOG: ??? ANGLEAT TOP F97F: 40° @ 1067T We: Refer to Production DB for historical pert data SIZE SPF WERVAL OlWSQZ DATE 2-7/8• 6 10677 - 10702 O 0226/19 2-718" 6 11903-11993 O 03/23117 2-718" 6 12030 - 12200 O 1024107 2-718" 6 12750 - 12930 O 1024107 2-718" 6 12980 - 13220 O 10/24/07 2-718• 6 13300 - 13550 O 1024/07 3TO I 13670• I8" 13690' 13697 1 2189' 1 ESTIMATED TOP OF CEMENT 4-12-HFSX NP f)=3R15- 9. 342• H9-5/8" X 7- BKR C-2 ZXP LTP w / 11.62" PBP, ID = 6.280" 936W H 9-5/8- X 7- BKR HMC LNR HGR D = 6 9366' H7"X0PN,ID=6.276• MLLOUT WNDOW (G -19B) 9487'-9504- /F-10433- 487'-9504'10433• 7- X 4-12- BKR S-3 PKR D DATE REI/ BY COMMENTS DATE REV BY COM E NTS 0624/86 NISE ORIGINAL COMPLIE7ION 10/02/15 SJWIJMD MLLED CIBR'FISH(09/30/15) 11105196 NORD 1 CTD SDTRACK (G -19A) 03113/19 BTNJM) ADPERFS (0226/19) 1026107 WES SIDETRACK(G•19B) 06/06108 JRBIMPJ DR -G DPAFT CORRECTIONS 11/14/09 TAQ/PJC OA SAFETY NOTE 07/30/11 RLMPJC SETOBP(07/30/11) 10494' I 10b11' 0 10625' 1 14-12- HES X NP, D = 3.813" 1 w / 11.7' PBR & FLIX LOCK LNR HGP, ID = 4.440- 4-12• HES XN NP, D = 3.725• [4 *;j PRUDHOE BAY INR WELL: G -19B PBW No: 2071240 AR No: 50-029-21599-02 SLC 12, T11 R R1 3F, 1536 FSL & 2276' FV4L SP Exploration (Alaska) • ITU, - I`t1? RID 7-6?i Regg, James B (DOA) From: Herrera, Matthew F (DOA) Sent: Sunday, November 5, 2017 3:41 PM To: Regg, James B (DOA) ti ii( +� 7 Subject: RE: PBU G-Pad Deficiency Report Attachments: G-Pad WH Signs .zip Went by G-Pad and all wells in question had the well house signs replaced with ones with PTD numbers. From: Regg,James B (DOA) Sent:Thursday, November 2, 2017 8:57 AM To: Herrera, Matthew F (DOA) <matthew.herrera@alaska.gov> Subject: RE: PBU G-Pad Deficiency Report Please confirm that these well signs have been installed. Deficiency rpt attached so you know which wells. Jim Regg Supervisor, Inspections AOGCC FEB4) �1 no 333 With Ave,Suite 100scow ' Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From:AK, OPS FF Well Ops Comp Rep [mailto:AKOPSFFWeIIOpsCompRep@bp.com] Sent: Monday, September 25, 2017 8:59 AM To: Herrera, Matthew F (DOA) <matthew.herrera@alaska.gov>; Regg,James B (DOA)<jim.regg@alaska.gov> Cc:AK, OPS GC1 Field O&M TL<AKOPSGC1FieldOMTL2@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS FF Well Ops Comp Rep<AKOPSFFWellOpsComrRep@bp.com> Subject: PBU G-Pad Deficiency Report Matt and Jim, Enclosed is the completed Deficiency Report. The Well House signs have been ordered and are scheduled to ship to the Slope on Tuesday 9/26/17. Upon arrival we will schedule install. Reference the below email from our Data Controller to verify the sign orders. Please call with any questions or concerns that you may have. Vince 1 lir yx ir .S _1 ? bk..«i meq" t. t . ''''. a ' e t A x w rwx, ri r W ' COC 0a:11 ,..03 cc z _ / c (ii .cy..... .. +-� t0 I- I "� a = c „-. a) „.... 03 ►- N (0,3U) O X .0 13 W O l— r O Cl. m In (/) N .vJ 2 .Wz c CC W Q a O m V ` UJCC Z W Z cd J 0) o a n O �. : F .xy x `' «: +, ,xi .e. c ,m.�ra vwsr r.-s:«• r„ � m++x,.a✓' a.r.w'k+%�. Mp • • Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Friday, October 13, 2017 1:40 PM �y i To: Herrera, Matthew F (DOA); DOA AOGCC Prudhoe Bay IZ-6-t 101 i 3 I 1 7 Cc: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU G-Pad Deficiency Report Matt I was going through some emails and I couldn't find us fully closing out to the completion of the E-Pad wellhouse sign install from the deficiency report you initiated. Therefore, to ensure you have, please be advised that all 8 WH signs have all been installed. Lee Hulme Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony—7187 (Alternate: Vince Pokryfki) From: Herrera, Matthew F (DOA) [mailto:matthew.herrera@alaska.gov] Sent: Monday, September 25, 2017 9:01 AM To: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU G-Pad Deficiency Report Thank you Sir From:AK, OPS FF Well Ops Comp Rep [mailto:AKOPSFFWellOpsCompRep@bp.com] Sent: Monday, September 25, 2017 8:59 AM To: Herrera, Matthew F (DOA) <matthew.herrera@alaska.gov>; Regg,James B (DOA)<jim.regg@alaska.gov> Cc:AK, OPS GC1 Field O&M TL<AKOPSGC1FieldOMTL2@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS FF Well Ops Comp Rep<AKOPSFFWellOpsCompRep@bp.com> Subject: PBU G-Pad Deficiency Report Matt and Jim, Enclosed is the completed Deficiency Report. The Well House signs have been ordered and are scheduled to ship to the Slope on Tuesday 9/26/17. Upon arrival we will schedule install. Reference the below email from our Data Controller to verify the sign orders. Please call with any questions or concerns that you may have. Vince Vince Pokryfki Field Well Compliance Advisor 1 • Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Monday, September 25, 2017 8:59 AM To: Herrera, Matthew F (DOA); Regg,James B (DOA) Cc: AK, OPS GC1 Field O&M TL;AK, OPS GC1 Wellpad Lead;AK, OPS FF Well Ops Comp Rep Subject: PBU G-Pad Deficiency Report Attachments: Deficiency Report PBU G-Pad.xlsx Matt and Jim, Enclosed is the completed Deficiency Report. The Well House signs have been ordered and are scheduled to ship to the Slope on Tuesday 9/26/17. Upon arrival we will schedule install. Reference the below email from our Data Controller to verify the sign orders. Please call with any questions or concerns that you may have. Vince Vince Pokryfki Field Well Compliance Advisor BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659-5332 Cell: (907)354-1352 Harmony- 7187 Alternate:Lee Hulme From: Lastufka, Joseph N Sent: Friday, September 22, 2017 4:19 PM To: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU G-Pad Deficiency Report Ordered. Could possibly be ready on Monday. I'll keep you posted. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 1 • •WP • t t. BP Exploration AlaskaI900 E. Benson Blvd.'Room: 788DIAnchorage, AK From: AK, OPS FF Well Ops Comp Rep Sent: Friday, September 22, 2017 1:21 PM To: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Cc:AK, OPS GC1 Field O&M TL<AKOPSGC1FieIdOMTL2@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS FF Well Ops Comp Rep<AKOPSFFWellOpsCompRep@bp.com>; Cocklan- vendl, Mary E <mary.cocklan-vendl@bp.com>; Pomeroy, Glen <GIen.Pomeroy@bp.com> Subject: FW: PBU G-Pad Deficiency Report Joe, Can you please order new well house signs for the following G-Pad Wells: G-4, 5, 17, 19, 21, 23, 26, 31. Please utilize the bottom hole locations and Permit numbers found in DWF. GC1 Team, Once the signs arrive please ensure that they are installed asap as this is a "Compliance Issue"with a formal Deficiency Report submitted from the AOGCC. Thanks for the help, Vince Vince Pokryfki Field Well Compliance Advisor BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659-5332 Cell: (907)354-1352 Harmony - 7187 Alternate:Lee Hulme From: Herrera, Matthew F (DOA) [mailto:matthew.herrera@alaska.gov] Sent: Friday, September 22, 2017 11:44 AM To: Regg, James B (DOA); AK, OPS FF Well Ops Comp Rep Subject: PBU G-Pad Deficiency Report These were found during SVS testing on pad yesterday Ware genera, Petroleum Inspector 2 • • Alaska Oil & Gas Conservation Commission Matthew.herrera@alaska.gov 907-659-2714 (Slope Office) 907-448-1227(Slope Cell) 907-953-7966 (Cell) 3 • • State of Alaska Oil and Gas Conservation Commission 1( Deficiency Report iolq(17 Location: PBU G-Pad Date: 9/21/2017 PTD: Multiple Operator: BPXA Type Inspection: SVS Operator Rep: Monty Owens Inspector: Matt Herrera Position: Lead OP Op. Phone: 907-659-4084 Correct by(date): 101-417 Op. Email: AKOPSGC1WellpadLead@bp.com Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected Mutliple Wellhouse signs on the pad do not have the PTD numbers for that specific well. List of wells with deficient well house signs: PBU-04,05,17,19,21,23,26 and31 A Signs ordered on 9/22/17 and scheduled to ship to the BPXA North Slope on 9/26/17. 9/26/17 Sign install scheduled. . See email concerning the Well House sign order. (dated: 9/22/17) Attachments: Monty Owens Operator Rep Signatures: Matt Herrera AOGCC Inspector *After signing, a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention: Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification (Attention: Inspection Supervisor). Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 RECEIVE ` 207-�z 017 • 2- 320 JUN 28 2 WELL LOG TRANSMITTAL#903920317 AOGCC To: Alaska Oil and Gas Conservation Comm. June 23, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage,Alaska 99501 `. BENDER RE: Coil Flag Log: G-19B Run Date:3/21/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari,Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage,AK 99518 G-19B Digital Data(LAS),Digital Log file(Field Data) 1 CD Rom 50-029-21599-02 Coil Flag Log(Field Print) 1 Color Log 50-029-21599-02 scoop .i\JL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / A ,o..,, i ,/ vi STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Ed Other Stimulate 0 Alter Casing0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 207-124 3. Address: P.O.Box 196612 Anchorage, Development p Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21599-02-00 7. Property Designation(Lease Number): ADL 0028280 8. Well Name and Number: PRUDHOE BAY UNIT G-19B 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 IVED Total Depth: measured 13692 feet Plugs measured feet true vertical 8999 feet Junk measured 13569 feet APR 1 7 2017 Effective Depth: measured 13602 feet Packer measured 10433 feet true vertical 9002 feet Packer true vertical 8240.26 feet G CC Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"Conductor 30-110 30-110 Surface 2672 13-3/8"72#L-80 29-2701 29-2639 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: 11903-11933 feet 11933-11963 feet 11963-11993 feet 12030-12200 feet 12750-12930 feet 12980-13220 feet 13300-13550 feet True vertical depth: 9027-9026 feet feet 9026-9025 feet 9025-9024 feet 9024-9025 feet 9022-9020 feet 9019-9015 feet 9010-9004 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 27-10510 27-8295 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED I�A! I v 2,I I 1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 350 25946 16 760 748 Subsequent to operation: 965 28536 44 780 753 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development EZi Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 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 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature igPhone +1 907 564 4424 Date 4/14/17 Form 10-404 Revised 5/2015 VrL_ 57/4/`y /,7;04 BD11AS Uv At'i 1 9 2017 Submit Original Only • C.) NQ„ 000000 • I6 (re• • N Lc) N- N- U N CQ © i CO I� Nr CO CO 7 O) CO CO N CO V C) C) I,- CO CO O O I- CO CO 07 CO CO V O O O o •t O N N CO 00 00 H N C�) O (3) c CO 00 I� 00 N N O N' N N N- co 4-0• W O� A- O O O E r O (., 00C0 O) N O O M . o CO M Q = O O) CO CO V (3) (` co N N O co 'zrN A- O = QM la W • W c � O I c c w oJ co 00 O 1 M LA U J J OO J •� N� N p V •t , N • CC LL CO (Ni N CO ch o v N r. v C0 0)O I� O N C CO 0 CD LU M A- J N N CO �O W W Et H _Q Q CS)0•NUUW W CU D Q 2 C 0 Uaa_ cCct Z z0WWWWm D z z (n Z Z J J f • • Packers and SSV's Attachment PRUDHOE BAY UNIT G-19B SW Name Type MD TVD Depscription G-19B PACKER 9352.79 7440.98 7" Baker ZXP Top Packer G-19B TBG PACKER 10433 8240.26 4-1/2" Baker S-3 Perm Packer G-19B PACKER 10504.88 8291.45 5" Baker ZXP Top Packer 0 0 c' x G _c $ _ / x \ t / p \ ® x =_ E e _ �� c a to a c - ® ° 0 0) / N- I__ / 0 § x Cr § © \ / / c c © n ƒ f / § / ƒ _/ Cr) o • _ (Y) \ / \ / t co ° w �� N- / \ 0x cL --z.c e § / k % \ Zr) o Glop 0 @ / t g 6 \ c - \ \ U) �L.0 ƒ \ \ _ c » L.0 2a) ƒ ƒ � /f �_ k e3 � / k 2 ,-- co ", �� \ 3 § / \ ± \ / / 5 \ k ■ O w = n 6 _ = 9 b m ® _ @ 4 \ G r ORO c n n e cs) R p 2 O o = c ƒ \ x e ° / 2 $ x co g e m & ® e 0 - 2 m © o I m $ 1.1 CD- a) e 0) . n � / / p \ q § \\ �\ / \ \/ 0 CO in _ , § x e 't W ; \ x / \ \ § / ./ •e 2 \ o O \ b 3 / I § �_ % % @ .g I � � � ab % � t �� � � \ C �O IX _ . \ . 3 p a E / _ . \ / .E b / . R a I b y \ x t e a e % \\ ; b = 2 e >, o r - a t - e © . t t r 2 = e : ® \ o 2 . - ® c D 0 ƒ $ * 3 ƒ / I •x 11.5 c0 0.) t 3 / « 2 - % / - \ a_ • / \ U = * \ o = E _ ' x , % O = x \ ;.- a CO f ) U = x - t / 6 < [ q G < » 2- 3 2 m § a < b _c 0 _x % 7 $ 3 < b § % N.: » - - e 1 © � r n c@ � w W - n �� o ƒ / /% f » 7 f e / o k t cL© » » c . a « 2 = o o eg m e oo _® cc oma .' \ eL a \ / E \ * / o J a) I \ 0 \ \ f % \ iS E \ k £ ' E0) . = m � . . 0 0 o _ c - g 2 y O 5 = O o » .g \ r o = ® O 4 § x F$ 2 ® O * + = o / f - \ / / \ g S% / \ \ / I c b @ a \ / o I R \ 7 f 0 � 2 t O -7 I 2 v_ w E t 0 / ct o \ m O t U / EE I t 2 ¢ U L 1— < r- w w w (N \ \ \ %/ / c�_ / / / co ® ,_ c \ r m r m < TREE= 41116"CM/ • NOTE NEIL ANGLE>70°@ 11392'""4-1/2" `VELLt-EAD` OW .. CHROME TBG"'OA IS CEMENTED&ABANDONED ACTUATOR, BAKER C 1 BB_OW GRADE LEAVING A MONOBORE COMPETION KB_ELEV= 67,11' Q � BF.ELEV= 40.41' •4 ►� KOP= 10604' �4 ,C 2028' f 9-518"HES CEMENTER Max Angie=95°@ 13288' • Datum MD= 11171' 120"CONDUCTOR — 110' ,y, e Q ►• 2090' —ESTIMATE)TOP OF CEMENT Datum TVD= 8800'SS .4 ►' �4 ► 2189' f—4-1/2"I IC X NP,D=3.813" • • 9-5/8"TEE BACK CSG,47#, H 2039' • _ .4 t 4� L-80 HY DRL 563,ID=8.68" 13-3/8"CSG,72#,L-80 BUTT,D=12.347" —1 2705' I . 9342' —9-15/181".6X27."BKR C-2 ZXP LIP `// w PBR,ID 6.280" 9-5/8"CSG,471/,L-80 BUTT H 4759' XO TO L-80 NSCC,D=8.681" g r !L H 9360' 9-518"X 7"BKR MD G LNR HGR, =6.350" Minumum ID = 3.725" @ 10498' 9366' E—7"X0 PN,D=6.276" 4-1/2" HES XN NIPPLE MLLOUT WINDOW(G-19B) 9487'-9504' 9-5/8"WFPSTOCK(10/10/07) — 9487' 10403' —4-1/2 FES XNIP,D=3813" 10433' }—7"X 4-1/2"BKR S-3 PKR,D=3.870" ,b. 19-518"EZSV(10/10/07)H 9509' Nr 9-5/8"EZSV SQUE EZE PKR(09/30/07) H 10080' 111, 4-1/2"TBG STUB(09/23/07) — 10142' — , 10467' F_4-1/2"HES X NP,D=3.813" • 10494' }—7"X 5"BKR"If D"ZXP LTP 9-5/8"CSG,47#,L-80 NSCC,D=8.681" — 10595' w 1 11.7'PBR&FLEX LOCK LNR HGR,ID=4.440" PERFORATION St)vfiARY .... I 1 10498' —4-1/2"HES XN NP,D=3.725" REF LOG:??? ....I_ ANGLE AT TOP PERE:92°@ 11903' Note:Refer to FYoduction DB for historical pert data 10511' —4-112"HES WLEG,D=3.958" SIZE SFF NTE RVAL OPWSQZ CATE --IELMO TT NOT LOGGED 2-7/8" 6 11903-11993 0 03/23/17 I 10525' —5"X 4-1/2"XO,D=3.940" 1 2-7/8' 6 12030-12200 0 10/24/07 I; , 2-7/8" 6 12750-12930 0 10/24/07 2-7/8" 6 12980-13220 0 10/24/07 1 ' 2-7/8" 6 13300-13550 0 10/24/07 I• 4-1/2"TBG, 12.6#,13CR-80 VAM TOP,.0152 bpf,D=3.958" H 10511' I 1 [7"LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276" H 10666' ' PBTD H 13670' .-...... 13569'CTM —FISH 4-1/2"HES CIBP ►•�•�•44 ••••�•4 MLLED(09/30/15) • 444 4-112"TBG,12.6#,L-80 BT-M,.0152 bpf,ID=3.958" --{ 13690' !;!'21 ; 1 TD-}H 13697 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY MIT 06/24186 N18E ORIGINAL COMPLETION 10/02/15 SJW/JMD WILLED CIBP/F1SH(09/30/15) _ WELL: G-198 11/05/96 NORD 1 CTO SDTRACK(G-19A) PERMIT No: 2071240 10/26/07 NTES SIDETRACK(G-198) API No: 50-029-21599-02 06/06/08 JR13/RP/PJC DRLG DRAFT CORRECTIONS SEC 12,T11 N,R13E, 1535 FSL&2276'FWL 11/14/09 TAQ/PJC OA SAFETY NOTE 07/30/11 RLM PJC SET aBP(07/30/11) BP Exploration(Alaska) RECE1V� 7-o1 `�2( • ' ' 2,1S12_5 /Gm� APR 1 1 2017 PRINT DISTRIBUTION LIST BAKER HUGHES � Please sign and return one copy of this transmittal form to: COMPANY AoQloration Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 DATA LOGGED WELL NAME G-19B 900 E.Benson Blvd. q it2,i2011 ✓I. K. BENDEF' Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE March 28,2017 AUTHORIZED BY Paul Canizares EMAIL Paui.Canizaresta�bakerhughes.com TODAYS DATE April 10,2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BO) LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #UI- I F<IN I S #OF COPIES #OF COPIES #OF COPIES V v v 1 BP North Slope. 0 0 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 1 1 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 1 0 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 41 State of Alaska -AOGCC 0 1 1 0 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 i DNR-Division of Oil&Gas *** 0 1 1 0 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 0 0 I 0 I 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. SCANNED MAY 0 12017 Anchorage,Alaska 99508 Attn:David Itter TOTALS FOR THIS PAGE: 3 4 0 0 TOTALS FOR ALL PAGES: 0 3 4 0 0 STATE OF ALASKA ' •ALASKA OIL AND GAS CONSERVATION COMFv N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull TubingEl Operations shutdown ❑ Suspend 0 Perforate ❑ Other Stimulate 0 Alter Casing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well ❑ Other:Mill CIBP 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-124 3. Address: P.O.Box 196612 Anchorage, Development ® Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21599-02-00 7. Property Designation(Lease Number): ADL 0028280 8. Well Name and Number: PBU G-19B 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: E , ( .-... Total Depth: measured 13692 feet Plugs measured feet true vertical 8999 feet Junk measured 13569 feeti ()C.1 2 2�1a Effective Depth: measured 13602 feet Packer measured See Attachment feet true vertical 9002 feet Packer true vertical See Attachment feet a (')G CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 30-110 30-110 Surface 2672 13-3/8"72#L-80 29-2701 29-2639 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: 12030-12200 feet 12750-12930 feet 12980-13220 feet 13300-13550 feet 10280-10300 True vertical depth: 9024-9025 feet 9022-9020 feet 9019-9015 feet 9010-9004 feet 9048-9058 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr8 27-10510 27-8295 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 363 23819 8 50 699 Subsequent to operation: 350 25923 16 60 748 14.Attachments:(required per 20 AAc 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory o Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run ❑ 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 ❑ SUSP ❑ 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 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 'Yaw r estry --- Phone +1 907 564 4424 Date 10/21/15 Form 10-404 Revised 5/2015 v.TL_ 1 b/z7-// 5 . . t RBDMS UC I 1 3 2015 Submit Original Only .40 /o Pg'- - • • I Packers and SSV's Attachment PBU G-19B SW Name Type MD TVD Depscription G-19B PACKER 9352.79 7440.98 7" Baker ZXP Top Packer G-19B TBG PACKER 10433 8240.26 4-1/2" Baker S-3 Perm Packer G-19B PACKER 10504.88 8291.45 5" Baker ZXP Top Packer • 0 NQ 000000 IcocO7 ( O 04 U N O o 0 0 0 0 co M 7 O O CO N "Cr CO 'd' CO CO CO CO O) CO O O) O CO CO 0 01 6) O O O ` 6) N N co co co H O) CN O CA CO co O M N N O) N N vr- N- CO CD LO O O O O M O O N N O c,„2 O r r o CUi i i i i i e Q a) ON- M T.. O O CO CO O COCO N N O) c C N • M I— • CO a � oO � Q0 O J CO OO J (,) U J J CO = N "O N �# �# J *k N O t` ti CV CO N r r CO N U U M w a N N Cl) N (NJ CO O O) .c (N N- 't CO M CO O N- v.-- O N O) O = O CO O LC) Cr) J N N CO w w Q Q y HO U 0 0 U 0 u_ W c a a Z z � wwwwm ODHHZZj 0 O Z Z J J j- TREE= 4-1/16'CM • G19B NOTEYVELL ANGLE>70*@ 11392'—4-1/2" WELL - HEAD, OW C ME TBG OA IS CEMENTED&ABANDONED !ACTUATOR, BAKER C 88_0W GRADE LEAVING A MONO8ORE COM pErioN ;KB.ELEV= 67 11' ,,..i • I BF.ELEV= 40,411 ••• • • KOP= 10604 •4 • f 2028' -11-----9-5/8" 47ESE2 CEMENTER .. • • Max Angle=95°@ 13288'1 ay,coN3UCTOR I— 110' 't Datum MD= 11171' I 44 i. 2090' —ESTIMA TED TOP OF CEMENT • _ 'D *4atum TVD= 8800'SS] V . V I I ; 1 2189' I—F47fii•TIES X MP,ID=3.813" 9-5/8' TEBACK CSG,47#. I-- 2039' '•4 17. -------- ..4 , L-80 HY DRY_563,ID=8 68" I 13-3/8"CSG, 72#,L-80 BUTT,ID= 12.347' — 2705' I „....... A 9342' —F9---I5/8"X 7'BKR C-2 ZXPLTP lw/11.62"PI3R,ID=6.280' 9-5/8"CSG,47#, L-80 BUTT 1-- 4759' X0 TO L-80 NSCC,ID=8.681' i 1 T 9360' 1—9-5/8'X 7"BKR HMO LNR I-G11,ID=6 350" Minumum ID = 3.726" @ 10498' --------- 9366' —7"X0 PIN,ID 6.276' 4-1/2" HES XN NIPPLE I MLLOUT'WINDOW(G-1913) 9487'-9504' 9-5/8"WHPSTOOK(10/10107) I- 9487' I I [ 10403' 1—'4-1/2'1-F-S X NIP,Cs=3 813 1 I 43V`t 104.33' i---..7"X 4-112"BKR S-3R,ID PK =3.870' --t* I ,4,' : . , . .-,,.-:,-:,a,:...' :''-',..2z. AM.9-5/8'EZSV(10/10/07T— 9509' IF i 4: 9-5/8'EZSV SQUEEZE PKR(09/30/07) —1 10080' I4-1/2*TBG STUB(09(23/07) H 10142' I 1046T 1+1/2-HES X NIP,ID=3.813' if 1 I 4_3 ; 10494' h--7'X 5'BKR'F-RET ZXP LW 9-518'CSG,47#,L-80 NsCC ID=8W/ 11.7'FBR&FLEX LOCK. 681' — 10595' ; 1LNR HGR,ID=4.440' FERFORATICN SUMMARY 1 ,.51 i REF LCG:??? I-----ii:1498' ir--I 4-1/2"HES XN NIP,1-.)=3.725' I I. ' I ANGLE AT TOP PERE 90°@ 12030' 1 ,4111111 INbte.Refer to Production DB for historical perf data -,....4,.. --- _ 1 10511' H4-112'HES WLEG,ID=3,958" SCE SFF INTERVAL OPNISCIZ 1 DATE E HaidiD TT NOT LOGGED 2-7/8" 6 12030-12200 0 10/24/07 I - -10525'I -1r-5"X 4-1/2'XO,[5-=3.940' ; 2-7/8"I 6 12750-12930 0 10/24/07 2-7/8" 6 12980-13220 0 10/24/07 .111 k 2-7/8' 6 13300-13.550 0 10/24/07 I v•v4 ..•_•. I 4-1/2'TBG, 12.6#,13CR-80 VAM TOP,.0152 bpf,0 3.958" H 10511' I 7'LMR,26#,L-80 BTC-M, 0383 bpf,D=6276' --fair's. - F13TD — 13670' 1 .....4.4 13569' CTP;11--FISFt 4-1/2'FES CP •••• •••4 •••• mt.LED(09/30/15) 1 •••4 •,A.•,•, 4-1/2"TBG, 12.6#,L-80 BT-M, 0152 bpf,ID-=3.958" H 13690' •;•;•;•; r---fyi-- 13692----1 DATE REV BY COMPANTS---- DATE I REV BY COMMENTS 1 F'RUDFIDE BAY MIT 1 06/24/86 NI8E ORIGINAL COMPLETION 10/02/15 SJW/JACt MLLED CIBPIFISH(09/30/15) VVE_L. G-19B 11105/96 NORD I I1 CTD SDTRACK(G-19A) _ amr N2071240 10WES SIDETRACK(G-198) _ IAR No- 50-029-21599-02 06/06/08 JRB/RP/PJC DRLG DRAFT CORRECTIONS SEC 12, T11N,R13E, 1535'FSL&2276'FW. 11/14/09 TAO/PJC OA SAI-EI Y NOTE - '07/30/11 ROW PJC SET aBP(07/30/11) ---' i 13P Exploration(Alaska)k a) • • Image Project Well NistQry File Laver Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original fiile, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - ~ ~~~ Well History File Identifier 9, ., ~..v,aea iiiumiuiiiiiiu o Re,~~~eee~ iuiuui~iiuuii RE AN DIGI AL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: BY: Maria Date: /s/ Project Proofing III II')() VIII VIII BY: aria Date: /sl Scanning Preparation ~ x 30 = _w ~ a + ~~ =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: ~ ~ ~ ~(~' /s/ Production Scanning III II'III VIII II III Stage 1 Page Count from Scanned File: ~~ (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: ___,~YES NO BY: Maria Date: ` ~ !s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II II II III II I I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III II'I III 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg 20 12 Alaska Oil and Gas Conservation Commission DRUG 333 West 7 Avenue Anchorage, Alaska 99501 Q 7 1 a Subject: Corrosion Inhibitor Treatments of GPB G -Pad -19 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad G that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) G -Pad Date: 03/05/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal G-01A 1931710 50029202140100 3.0 NA 3.0 NA 10.2 5/10/2010 G-02B 2081580 50029202170200 0.5 ' NA 0.5 NA 2.6 5/10/2010 G -03A 1970700 50029202210100 0.7 NA 0.7 NA 6.0 5/27/2010 G-04B 2061400 50029202250200 0.1 NA 0.1 NA 1.7 5/10/2010 G -05 1780970 50029203510000 0.0 NA 0.0 NA 0.0 5/10/2010 G-06A 2060120 50029203580100 0.6 NA 0.6 NA 5.1 5/12/2010 G -07 1790180 50029203590000 0.5 NA 0.5 NA 3.4 5/11/2010 G -08A 2061830 50029205810100 0.1 NA 0.1 NA 0.9 5/27/2010 G-09B 2071100 50029205820200 9.0 NA 9.0 NA 69.7 5/20/2010 G -10C 2060090 50029205530300 0.9 NA 0.9 NA 8.5 3/5/2012 G -11B 2080270 50029205830200 0.0 NA 0.0 NA 0.0 5/21/2010 G -128 2031410 50029205970200 0.5 NA 0.5 NA 2.6 5/13/2010 G -13A 2001630 50029206000100 0.0 NA 0.0 NA Trace 5/12/2010 G -14B 2090680 50029206460200 0.7 NA 0.7 NA 5.1 5/22/2010 G -15B 2080650 50029206470200 26.0 4.0 0.5 7/16/2011 3.4 7/19/2011 G -16A 2090560 50029206430100 0.0 NA 0.0 NA Trace 5/22/2010 G -17A 2060760 50029206190100 21.4 _ 4.0 0.6 7/16/2011 3.4 7/19/2011 G -18A 1990320 50029206200100 71.7 14.0 1.0 7/16/2011 8.5 7/19/2011 ....--.+7 G -198 2071240 50029215990200 0.0 NA 0.0 NA Trace 5/22/2010 G -21 1951540 50029226040000 0.5 NA 0.5 NA 3.4 5/12/2010 G -238 2091440 50029216800200 0.5 NA 0.5 NA 4.3 5/11/2010 G -24A 2060820 50029216710100 0.1 NA 0.1 NA 0.9 5/11/2010 G -25B 2070860 50029216520200 5.3 NA 5.3 NA 23.8 5/28/2010 G -26B 2050480 50029216610200 2.0 NA 2.0 NA 6.8 5/11/2010 G -27A 2070310 50029216460100 0.5 NA 0.5 NA 2.6 5/30/2010 G -29B 2101410 50029216500200 2.8 NA 3.0 NA 17.0 5/13/2010 G -30C 2091510 50029216130300 1.0 NA 1.1 NA 5.1 5/30/2010 G -31B 2090310 50029216160200 0.8 NA 0.8 NA 6.0 5/21/2010 G -32A 1970010 50029216360100 0.8 NA 0.8 NA 3.4 5/21/2010 11/01/10 �""'• ° °YGP�eP NO. 5637 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD MPG -13 BCRJ -00038 X -FLOW CHECK/ISPSET RECORD 09N 5/10 1 I d4 T f 1 MPS43 AYKP -00104 SCMT 015126110 1 1 P7 -09 BCRJ -00036 PRODUCTION PROFILE s 09/12H0 1 W -37A BD88 -00048 MEM PRODUCTION PROFILE — 09111110 1 W -31A AZ2F -00064 MEM PRODUCTION PROFILE 09 /16/10 1 06 -19A AWJI.00112 MEM PRODUCTION PROFILE 09119110 1 1 12.05AL1 BAUJ -00050 MEM PRODUCTION PROFILE 09/20/10 1 1 pt -16 BCRJ -00049 INJECTION PROFILE 10106110 1 1 04 -03 BCRD-00059 PRODUCTION PROFILE 09127110 1 1 P -03A V -00065 MEM INJECTION PROFILE — 10106/10 1 t G -198 AWJI -00114 MEM PRODUCTION PROFILE 10/04/10 1 1 Y -36 15088-0058 MEM GLS 10/09/10 1 1 3- 03IJ -33 BCZ2 -00025 PRODUCTION PROFILE 09111110 1 1 L -214A BAUJ -00043 MEM INJECTION PROFILE 09/13/10 1 1 H -01A AWJI -00118 MEM PRODUCTION PROFILE 10/14/10 1 1 16 -O6B BBUO-00023 PRODUCTION PROFILE BP CORRECTION 06/08 /10 1 1 H -38 AZ2F -00068 MEM PRODUCTION PROFILE 1011 10 1 1 P244 BCRD -00063 PRODUCTION PROFILE 1 10/15/10 1 1 B -138 AYKP -00091 CH EDIT PDC -GR CMT) 07/02/10 �O 1 02 -226 IOAKA0069 OH MWD /LWD EDIT 07/07/10 2 1 W -19B BCRJ -00034 CH EDIT PDC -GR (SCMT -_ 09107110 1 1 OWDW -SE APBPMWELL RST REDO - PRINTS 09123110 t OWDW -NW BBSK -00033 RST 09124110 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 > Al l /---' -' � 4 • .~:; ~~ _ ~ ~"'P ' J. '~. 4, ~ ^~r ~~ ~f ,. ~ « >V'~ ~~ ~~ ~ ~; ~ c ,,~{c 4 s~ ~, MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\tempiTemporary Internet Files\OLK9\Microfilm_Marker.doc DATA SUBMITTAL COMPLIANCE REPORT 12/1 /2008 Permit to Drill 2071240 Well Name/No. PRUDHOE BAY UNIT G-196 Operator BP EXPLORATION (ALASKA) INC MD 13692 TVD 8999 Completion Date 1 012 6/2 0 0 7 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Log s Run: MWD DIR / GR /RES / PWD, MWDDIR / GR / ABI /RES / NEU / DE Well Log Information: log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No D Asc Directional Survey "Rpt Directional Survey C Las 15680 Induction/Resistivity ~D C Lis 16526 Induction/Resistivity ~,og Induction/Resistivity ~g Induction/Resistivity Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y! 1 Chips Received? Analysis 'f'~ Received? Comments: 25 Blu 25 Blu API No. 50-029-21599-02-00 UIC N Directional Survey L/ (data taken from Logs Portion of Master Well Data Maint Interval OH / Start -- Stop CH Received Comments -- 0 13692 Open 11/7/2007 0 13692 Open 11/7/2007 9250 13694 Open 11/9/2007 DRHB, RPM, GR, NPHI, RAM, ROP, RPS w/PDS graphics Field Data 9250 13692 Open 7/1/2008 LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RPD, j DRHO, NPHI ~ 9475 13634 Open 7/1/2008 MD Vision Service ~ 9475 13634 Open 7/1/2008 TVD Vision Service Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? N Formation Tops Y / N DATA SUBMITTAL COMPLIANCE REPORT 12/1 /2008 Permit to Drill 2071240 Well Name/No. PRUDHOE BAY UNIT G-19B MD 13692 TVD 8999 Completion Date 10/26/2007 Compliance Reviewed By: _ ______ __._ Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21599-02-00 Completion Status 1-OIL Current Status 1-OIL^~ 1~ ~ ~U,I~C N Date: J ~~.t..oce`y~ Oti/25/08 ~chlumberger NO.4750 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 140 Anchorage, AK 99501 WBiI Jeh # Len Descrintien Data, RI Cnlnr CD P1-12 11978462 STATIC PRESS & TEMP -- /"~ ,"' °'" -`' ~ O6/01/OS 1 1 X-12 11978466 PRODUCTION PROFILE ~°~ --- ~~'~ J ~' 06/04/08 1 1 G-05 12017499 PRODUCTION PROFILE j .-'' .~~% ~-'= `'~~- 'g° ,-~'' 06/12108 1 1 E-14A 12034899 SCMT f ~~`;? n ~`-~ 06/10/08 1 1 MPH-17 12066526 MEM INJ PROFILE ~,° ~ ''~=) ~ !`n f~ ~ r' ~ ~ 05/26/08 1 1 L-220 i 1975763 CH EDIT PDC GR (USIT) REVISED CD'S ONLY •* .:.- < ~y~. 04/22/08 1 L-220 40016915 OH MWD/LWD EDIT _ 7r_t•?. ~"° ~'~ 04/18/08 3 y^'-, 1f~.-~' L-221 40016787 OH MWD/LWD EDIT _ t.: <s.~- 04/03/08 3 1 01-01C 40015644 OH MWD/LWD EDIT '"' ~'~_]~- '~~~? ~'(' ~`' - =~. 08/15/07 2 1 G-196 40015844 OH MWD/LWD EDIT~+~` ~ n d ~~ 10/20/07 2 1 X-17 12057619 RST t .,_ + :~ is/' ~`~T,~).Cl ~ 05/24/08 1 1 L3-11 11966254 RST rP"~ v- ,'`'°~ f /a, ° ;~ ~. 05/01/08 1 1 Y-36 12014013 RST =<'°~ _- 'F' ( ~' ,-_ ~,°" 05/11/08 1 1 P2-37A 11216182 MCNL ~ `~"-~- ~ °-- ~'°l •'~ `_ ~ 03/17/08 1 1 05-34A 40016888 OH MWD/LWD EDIT "' <_°--_ -;~^:- c~ ° ~mf~~ 04/27/08 2 1 ra.~r+v~ env nnv~r ~.GVtaG nGV GIr ~ ~~ JIVIIYIIYLI NIYV flGl Vff IYIIYl7 VIYC I.VrT CA\. r7 1 V: BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 { ~ ~;~~ Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 40~ Anchorage, AK 99503-2a3~8 :'! ATTN: Beth ~ ~, ~~ Received by: ; ~ ~• ~~ f5 Saltmarsh, Arthur C (DOA) Page 1 of 1 From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, December 17, 2007 11:15 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU G-19B / PTD #207-124 H i Art, Please reference the following well: Wel! Name: PBU G-19B Permit #: 207-124 API #: 50-029-21599-02-00 Top Perf MD: 12030' Bottom Perf D: 13550' This well began Production on December 6, 2007 Method of Operations is: Flowing Date of Test: 12!16/07 Hours Tested: 4 24-Hour Rate /Oil-Bbl: 3,818 24-Hour Rate !Gas-Mcf: 4,446 24-Hour Rate /Water-Bbl: 90 Test Rate 1 Oil-Bbl: 636 Test Rate /Gas-Mcf: 741 Test Rate !Water-Bbl: 15 Choke Size: 95 Gas-Oil Ration: 1,165 Flow Tubing Pressure: 300 Casing Pressure: 1,050 Oil Gravity-API: 25 12ii~i2oo~ ~ ~ECI .t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM SSION NQV 3 d X007 ;- ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOkG .Alas a Od ~ Gas ~on~. Cior>7mssnn ItnP1131Y91nta 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC25.105 2oaac2s.~,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 Abar~ci~ 10/26/2007 -~' 12. Permit to Drill Number 207-124 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/11/2007 13. API Number 50-029-21599-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 10/19/2007 14. Well Name and Number: PBU G-19B 1535 FSL, 2276 FWL, SEC. 12, T11 N, R13E, UM Top of Productive Horizon: 667' FNL, 2959' FEL, SEC. 14, T11 N, R13E, UM 8. KB (ft above MSL): 67.11 Ground (ft MSL): 37.86' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 699' FSL, 1105' FEL, SEC. 11, T11N, R13E, UM 9. Plug Back Depth (MD+TVD) 13602 9002 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 657248 y- 5967883 Zone- ASP4 10. Total Depth (MD+TVD) 13692 ~ 8999 16. Property Designation: ADL 028280 TPI: x- 652061 y- 5965574 Zone- ASP4 Total Depth: x- 653886 y- 5966977 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.05 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 AAC 25.071 MWD DIR / GR /RES /PWD, MWD DIR / GR / ABI /RES / NEU /DENS / PWD L/iNAe7/r~~ ): , 9~~~MD ~.s'ya's71~ 22. CASING, LINER AND CEMENTING RECORD CASING $ET71NG QEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT• GRADE TOP BOTTOM TOP = BOTTOM SIZE CEMENTING RECORD PULLED 20" Insulated Conductor Surface 110' Surface 110' 26" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2703' Surface 2641' 17-1/2" 3808 cu ft Permafrost 9-5/8" 47# L-80 Surface 4 7' Surface 7543' 12-1/4" 575 cu ft Class'G', 780 cu ft Class'G' 7 26# L-80 9342' 10666' 7433' 409' 8-1/2" 329 cu ft Cla s'G' 4-1/2" 12.6# L-80 10494' 13690' 8284' 8999' 6-1/8" 462 cu ft Class'G' 23. Open to production or inject ion? ®Yes ^ No 24: TUBING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 10511' 10433' MD TVD MD TVD 12030' - 12200' 9024' - 9025' 12750' - 12930' 9022' - 9020' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12980' - 13220' 9019' - 9015' DEPTH INTERVAL MD AMOUNT S~ KIND OF MATERIAL USED 13300' - 13550' 9010' - 9004' Freeze Protect w/ 137 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: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCUU~TeD 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^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.Q71. None .,~ ~'~:. I;IE C. ~4 ~ ZD~~ ) /(~ - . ~~~i5 ,. Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE /'" 28. GEOL.4GIC MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD WeIlTested. ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 10665' 8408' None Shublik A 10710' 8443' Shublik B 10762' 8487' Shublik C 10780' 8503' Sadlerochit 10798' 8519' CGL /Zone 3 10983' 8699' Base CGL 11047' 8760' 23S6 /Zone 2B 11099' 8808' 25N 11134' 8837' 21 P 11279' 8944' Zone 1 B / 14N 11382' 9000' Formation at Total Depth (Name): Zone 1 B / 14N 11382' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore going is true and correct to the best of my knowledge. / / / l ~ Si ned / 9 Terrie Hubble Title Drilling Technologist Date d PBU G-196 207-124 Prepared By Name/ntumber. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Ron Phillips, 564-5913 Permit No. / A royal No. INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: G-19 Common Name: G-19 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 10/10/2007 FIT 9,496.0 (ft) 7,550.0 (ft) 10.80 (ppg) 475 (psi) 4,711 (psi) 12.01 (ppg) 10/15/2007 FIT 10,667.0 (ft) 8,408.0 (ft) 8.40 (ppg) 700 (psi) 4,369 (psi) 10.00 (ppg) U Printed: 11/2/2007 12:01:30 PM :' BP EXPLORATION Page 1 of 32 Qpeiratiolns Sumlrnary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task. Code NPT Phase Description of Operations 9/13/2007 17:00 - 00:00 7.00 MOB P PRE Stage sub on N-Pad 9/14/2007 00:00 - 04:00 I 4.00 MOB I P 04:00 - 08:00 4.00 MOB P 08:00 - 09:00 I 1.00 I MOB I P 09:00 - 09:30 0.50 MOB P 09:30 - 12:00 I 2.501 MOB I P 12:00 - 12:30 I 0.501 MOB I P 12:30 - 13:30 1.00 RIGU P 13:30 - 14:30 I 1.00 DHEOP I P 14:30 - 16:00 1.50 DHB P 16:00 - 17:00 I 1.001 DHB I P 17:00 - 18:30 I 1.501 WHSUR I P 18:30 - 22:00 I 3.501 BOPSUFiP 22:00 - 23:00 1.00 BOPSU P 23:00 - 00:00 1.00 BOPSU P 9/15/2007 100:00 - 05:00 I 5.001 BOPSUa P Move satelitte camp, truck shop, and pit module from N-Pad to G-Pad Move Rig from N-Pad to G-Pad PRE Move rig sub from N-Pad to G-Pad PRE Prepare location for rig -Remove tree scalfold, set mats for sub base, and spread herculite Spot sub and pits Berm sub and cuttings box PRE Make up service lines from pits to rig PRE PJSM with hands Inspect Derrick Raise Derrick PRE PJSM with hands Bridle down Hang Bridle lines Raise Cattle Chute Rig up Rig floor PRE Rig accepted @ 12:00 Continue Rig up and fill pits with 9.8 ppg brine PRE Pre Spud meeting with Well Site Leader, Toolpusher, Mud Man, and Crew. DECOMP Cameron pump down control lines to verify SSSV is pulled DECOMP PJSM with hands and DSM Rig up Lubricator Test Lubricator to 3,500 psi for 5 min Pull BPV Tubing static, IA - 0 psi, OA -vac DECOMP Make up TWC valve Rig up Lubricator and test to 3,500 psi for 5 min Set TWC Test TWC to 1,000 psi from above for 5 min DECOMP PJSM with hands Nipple down tree Inspect hanger threads, threads damaged Mobilize 4 1/2" test joint with donut ring DECOMP Nipple up BOPs Install riser DECOMP Rig up to test BOP DECOMP BOP test 250 psi low, 3,500 psi high AOGCC witness of test waived by Lou Grimaldi, test witnessed by Joey LeBlanc WSL and Biff Perry NTP Test #1 -Choke valves 1, 2, 3, Blind rams, Manual Kill, Dart valve DECOMP Test #2 -Choke 4,5,6, TIW, HCR Kill Test #3 -Choke 7,8,9 Test #4 -Super Choke, Manual Choke Test #5 -Choke 10, 11, 15, Upper IBOP Test #6 -Choke 12, 13, Manual IBOP Test #7 -Upper Pipe Rams (Var - 3 1/2"-6"), Choke 14 Test #8 -HCR Choke Test #9 -Manual Choke, Annular Accumulator test Pflntetl: 11/Z2007 12:01:37 PM ~ ~ BP EXPLORATION Page 2 of 32 Operations Sulrnlmary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: .Date From - To Hotars Task Code NPT Phase Description of Operations 9/15/2007 00:00 - 05:00 5.00 BOPSU P DECOMP Initial 2,980 psi Function valves - 1,750 psi Recover to 200 psi - 14 sec Full Recovery 1 min 16 sec Avg Nitrogen in 5 bottles 1,825 psi 05:00 - 05:30 0.50 BOPSU P DECOMP Rig down BOP test equipment 05:30 - 07:00 1.50 BOPSU P DECOMP PJSM with DSM and crew Rig up Lubricator with doughnut extension IA = 0 psi 07:00 - 08:30 1.50 BOPSU P DECOMP Pressure test Lubricator to 3500 psi for 5 min Pull TWC, tubing on vac. start filling the hole and RD lubricator and extension. Hole took 26 bbls to fill tubing. Check IA for pressure 0 psi on gauge, open IA to bleed tank, fluid level dropping in tubing, took 8 bbls to fluid pack IA. total 34 bbls to fill the well. 08:30 - 09:30 1.00 PULL P DECOMP Monitor well -Initial static loss rate loss rate 3 bbls/hr for first half hour, diminishing to static after 1 hour. Fill hole with 9.8 ppg brine Rig up 2 7/8" handling equipment while monitoring well 09:30 - 11:30 I 2.00 I PULL I P 11:30 - 12:00 0.50 PULL P 12:00 - 13:30 1.50 PULL P 13:30 - 16:00 I 2.501 PULL I P 16:00 - 22:00 I 6.001 PULL I P 22:00 - 00:00 I 2.001 PULL I P DECOMP Continue monitor well, Static. Pick up multi string cutter BHA DECOMP RIH with multi string cutter and tag up at 69' DECOMP Extend knives and attempt to locate collar, no collar Tag up on collapse and pick up 2' to 67' Start cut, 270 GPM @ 2,470 psi, 50 RPM @ 1,000 fUlbs Confirm cut with 700 psi decrease in pressure, POH to inspect blades Monitor well DECOMP Well flowing, shut in well 4 bbl gain in pits SICP = 50 psi Consult with town Bleed through choke in 10 psi increments monitoring for pressure build, SICP = 10 psi, no pit gains, no pressure increase. DECOMP Circulate across top of well, maintain 20 psi casing pressure Monitor IA and OA, OA dead most of the time, occasional release of pressure about every 4 hours IA building pressure, bleed gas only when IA reaches 55 psi, stop bleeding when fluid is present Approximately 63 bbls displaced in well bore, of which -30 bbls was diesel rest was gas DECOMP Circulate across top of well, maintain 20 psi casing pressure Monitor IA and OA, OA dead most of the time, occasional release of pressure about every 4 hours IA building pressure, bleed gas every 5 minutes, stop bleeding when fluid is present Approximately 85 bbls displaced in well bore, of which -45 bbls was diesel rest was gas OOA 13 3/8" x 20" appears to have dropped 3 inches since tubing was cut, 5 inches below top of flutes Pfintetl: 11/2/2007 12:01:37 PM BP EXPLORATION Page 3 of 32 Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date I From - To I Hours I .Task I Code I NPT 9/16/2007 100:00 - 03:00 I 3.001 PULL I P 03:00 - 07:30 I 4.501 PULL I P 07:30 - 08:00 ! 0.501 PULL 1 P 08:00 -08:40 I 0.671 PULL I P 08:40 - 12:45 I 4.081 PULL I P 12:45 - 13:00 I 0.251 PULL I P 13:00 - 00:00 I 11.001 PULL I P 19/17/2007 100:00 - 07:30 I 7.501 PULL I P Phase Description of Operations DECOMP Circulate across top of well, maintain 20-30 psi casing pressure Monitor IA and OA, OA dead most of the time, occasional release of pressure about every 4 hours IA building pressure, bleed gas every 5 minutes, stop bleeding when fluid is present Approximately 120 bbls displaced in well bore, of which -53 bbls was diesel rest was gas OOA 13 3/8" x 20" static, 5 inches below top of flutes 01:30 large gas bubble migrated up, had to vent IA for 29 minutes to get rid of gas in IA and loss returns while circulating across well head momentarily DECOMP Circulate across top of well, maintain 20-30 psi casing pressure Monitor IA and OA, OA dead fA building pressure, bleed gas every 10 minutes, stop bleeding when fluid is present Approximately 164 bbls displaced in well bore, of which -94 bbls was diesel rest was gas OOA 13 3/8" x 20" static, 5 inches below top of flutes 05:00 large gas bubble migrated up, had to vent IA for 20 minutes to get rid of gas in IA and loss returns again, increased pump rate to re-gain returns. DECOMP Rig up secondary kill line to IA and test secondary kill line to 3,500 psi DECOMP Pump 9.8 ppg brine down IA and take returns from the tubing, route returns through choke and gas buster Returns were straight diesel for first 23 barrels DECOMP Pump 508 bbls 9.8 ppg brine down IA and take returns from the tubing and route through choke and gas buster Maintain 20-60 psi back pressure with choke Loss a total of 30 bbls, 14 bbls to hole, 16 bbls diesel back Total cumulative losses 194 bbls, of which 110 bbls of diesel brine slurry DECOMP Shut down pumps, monitor well -well static Open Blind rams to monitor well 26 bbl gain -shut well in and line back up on choke DECOMP Started new procedure Pump 2 BPM @ 65 psi until losses stabilize and no diesel in returns Shut pumps down and allow fluid to flow back -diesel and 9.8 ppg brine U-tube, as diesel gets closer to surface gas breaks out of diesel, this forces returns to increase beyond capability of possum belly to drain Start pumps and pump until losses stabilize and no diesel in returns repeat over and over again Total losses 109 bbls, 35 bbls to the hole, 74 bbls to diesel Cumulative losses 303 bbls of which 184 bbls was diesel DECOMP Pump 2 BPM @ 65 psi until losses stabilize and no diesel in returns Shut pumps down and allow fluid to flow back -diesel and 9.8 ppg brine U-tube, as diesel gets closer to surface gas breaks out of diesel, this forces returns to increase beyond capability of possum belly to drain Printed: 11/2/2007 12:01:37 PM :~ BP EXPLORATION Page 4 of 32 Operations Summary Report Legal Well Name: G-19 ,Common Well Name: G-19 Spud Date: 6/6/1986 'Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/17/2007 00:00 - 07:30 7.50 PULL P DECOMP Start pumps and pump until losses stabilize and no diesel in returns shut down cycle seems to increasing in length, possibly means situation is improving? 6 hr losses 49.5 bbls, 11.5 bbls to the hole, 37 bbls to diesel Cumulative losses 352.5 bbls of which 221 bbls was diesel 07:30 - 11:30 4.00 PULL P DECOMP Shut well in to monitor pressure build up Minutes Tubing IA Minutes Tubing IA initial 20 40 80 68 107 9 20 50 90 69 109 20 37 65 100 70 111 30 45 77 110 73 115 40 52 87 120 75 115 50 58 96 137 76 115 60 61 100 160 84 115 70 65 104 170 84 114 Open choke and bleed back for 25 minutes Total fluid back was 20.2 bbls, of which 14.7 was diesel 11:30 - 13:30 2.00 PULL P DECOMP Shut well in and monitor pressure build up Minutes Tubing IA Minutes Tubing IA Initial 14 5 60 20 10 10 19 10 90 20 10 30 20 10 105 20 10 Determine well is not flowing, pressure are caused by small amounts of gas breaking out of migrating diesel freeze protect 13:30 - 20:45 7.25 PULL P DECOMP Pump 2 BPM @ 65 psi to circulate out diesel 4 bbls diesel per hour till 19:00 slowed '1.5 bbls diesel per hour 20:45 - 21:15 0.50 PULL P DECOMP .Shut down pumps to rig up contingency line to G-18 15 minutes after pumps down returns diminished to nothing IA pressure increased from 20 psi when pumps where shut down to 27 psi in 30 minutes 21:15 - 00:00 2.75 PULL P DECOMP Pump 2 BPM @ 65 psi to circulate out diese- 0.5 bbls diesel per hour Slowed pump rate to 1 BPM @ 30 psi to see if diesel recovery would increase Printed: 11/2/2007 12:01:37 PM BP EXPLORATION Page 5 of 32 Operations Summary.Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name; NABORS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of'Operations 9/17/2007 21:15 - 00:00 2.75 PULL P DECOMP No noticeable increase, only a trace of diesel in retums 24 hr losses 175 bbls, 79 bbls to hole and 96 bbls was diesel ~ Cumulative losses 478 bbls, 198 bbls to hole and 280 bbls was diesel 9/18/2007 00:00 - 03:00 3.00 PULL P DECOMP Pump 1 BPM @ 30 psi to circulate out diesel Avg -3 bbls diesel per hour Trace of diesel in retums for 1 hour 3 hr losses 14 bbls, 5 bbls to hole and 9 bbls of diesel recovered Cumulative losses 492 bbls, 203 bbls to hole and 289 bbls of diesel recovered 03:00 - 04:00 1.00 PULL P DECOMP Monitor returns from Gas Buster for 1 hour, no fluid back IA dropped from 2Qpsi to 10 psi after 1 hour Bleed IA to bleed trailer, short release of pressure and then dead Filf hole, took 4 strokes to get retums - 0.3 bbls Open blinds rams and monitor well 04:00 - 04:30 0.50 PULL P DECOMP Fill riserto flow line Mohitorwell for30 minutes, lost 1/2 bbl 04:30 - 08:00 3.50 PULL P DECOMP Line.up.hole fill and monitor static losses Static Ions rate Q 1:8 bblslhr 08:00 - 11:30 3.50 PULL P DECOMP Reverse cirCUlater monitor returns for diesel 2 BPM @ 65`p`si 11:30 - 13:30 2.00 PULL P DECOJuIP Monitorvuell arrd mQ~Mit'iz~,!/amco.for control line and Cameron .for Tubing hanger Static loss rate 2.25 bbls/hr RU control line spooler RU tubing handling equipment 13:30 - 14:00 0.50 PULL P DECOMP PJSM with Baker Make up Fishing Spear BHA Engage grapple in hanger Pull Hanger, 5K Ibs to unseat hanger 14:00 - 15:30 1.50 PULL P DECOMP Lay down Spear BHA Monitor well, static loss rate @ 2.25 bbls/hr Lay down hanger Cut off joint (40.18'), 1 -Control line clamp with pin, and 40' of control line 15:30 - 18:00 2.50 BOPSU P DECOMP Rig up to test BOP, upper rams and annular with 4" test joint, Blinds, and Lower rams with both 4" and 4.5" test joints. Low test pressure 250 psi, high 3,500 psi. 18:00 - 20:00 2.00 EVAL P DECOMP Monitor well, allow fluid level to drop below problematic area to run camera 20:00 - 21:30 1.50 EVAL P DECOMP PJSM with Haliburton Rig up wireline unit Run in the hole with downhole camera Identify control line and control line clamp sitting at 68' 21:30 - 23:00 1.50 FISH P DECOMP Mobilize Baker Rope Spear PJSM with hands Pickup BHA Run in hole to 75', rotate, pull out of hole Recovered 22' of control line and 1 control line clamp with pin Run in hole to 79', rotate, pull out of hole Nothing recovered rnntea: nurzuvi ~z:vi:ai rm ~~ • BP EXPLORATION Page 6 of 32 :Operations Summary.Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date ~ From - To I Hours ~ Task ~ Code ~ NPT ~ Phase Description of Operations 9/18/2007 123:00 - 00:00 I 1.00 I EVAL I P 9/19/2007 100:00 - 02:00 I 2.001 EVAL I P 02:00 - 09:30 I 7.501 EVAL I P 09:30 - 10:00 I 0.501 FISH I P 10:00 - 12:00 I 2.001 FISH ( P 12:00 - 13:00 I 1.001 FISH I P 13:00 - 21:00 I 8.001 DHB I P 21:00 - 22:30 I 1.501 DHB I P 22:30 - 00:00 I 1.501 DHB I P ~ 9/20/2007 100:00 - 00:30 I 0.501 DHB I P 00`.30 - 05:30 I 5.001 DHB I P 07:00 - 100:00 I 3.00 FD SH I P DECOMP Run in the hole with downhole camera Identified collapsed 9 5/8" casing from 69' to top of tubing stump at 75' Run inside 4 1/2" tubing, collapsed 3' from top of tubing stump DECOMP Discuss camera video results showing collapsed 9 5/8" casing with town team and plan forward Rig down Haliburton camera wireline unit DECOMP Line up on hole fill and monitor losses Static losses average 2 bbls/hr DECOMP Make up 6.25" sub on bottom of drill pipe, run in hole 6.25" tagged up at 71', 9 5/8" collapsed casing ID smaller than 6.25" Pull out of hole and lay down 6.25" sub Run in hole with drill pipe, tool joint OD = 5.25" Tag top of tubing stump at 76' Pull out of hole DECOMP Make up Spear assembly Run in hole to top of tubing stump at 76' Engage spear in fish ' Pull 50 Klbs, slack off to 30 Klbs, rotate 12 turns to the left, , joint backed out and weight dropped off to 15 Klbs, calculated tubing length -1,000' based on 15 Klbs string weight DECOMP Pull out of hole to collapsed joint of tubing Lay down 2' of cut joint and collapsed joint of tubing (14.5' of joint was collapsed) DECOMP Mobilize Schlumberger E-line PJSM -Rig up Big Mac (7.062" ID valve to test lubricator) while waiting on Schlumberger Average loss rate of 1.7 bbls/hr DECOMP PJSM with crew and Schlumberger Rig up E-line lubricator, BOP, and pack off Test to 1000 psi DECOMP Run in hole with gauge ring, junk basket, and collar locator Last collar located at 1,056' Tagged tubing stump at 1,165' Multiple attempts to enter tubing failed DECOMP Crew change for Rig and Schlumberger PJSM with new rig crew and Schlumberger Inspect rig up for E-line well control Mobilize swage and lead impression block DECOMP Pull out of hole with gauge ring junk basket Inspect bottom, no identifiable marks on bottom of junk basket Rig up lead impression block (3.5" OD), and centralizer (3.70" OD), run in hole Tag up on tubing stump at 1,165', pick up and drop 4' Pull out of hole and inspect impression block Half moon from pin of tubing in the center of lead block Pick up tapered centralizer 3.70" OD and run in hole Tag up on tubing stump at 1,165', multiple attempts to enter tubing failed Pull out of hole and rig down Schlumberger E-line DECOMP Rig up 4.5" tubing handling equipment DECOMP Run in the hole with 116' of 4.5" tubing to tag the top of 4.5" Printed: 11/2/2007 12:01:37 PM C • BP EXPLORATION Page 7 of 32 Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date From - To I Hours I Task I Code NPT 9/20/2007 107:00 - 10:00 I 3.001 FISH I P 10:00 - 12:30 I 2.501 DHB I P 12:30 - 17:30 I 5.001 DHB I P 17:30 - 18:30 I 1.001 DHB I P 18:30 - 00:00 I 5.501 DHB I P 19/21/2007 100:00 - 06:30 I 6.501 DHB I P 06:30 - 07:30 1.00 DHB I P 07:30 - 09:30 2.00 DHB P Phase. I Description of Operations DECOMP tubing stump at 1,165' while pumping down tubing at 2 BPM - 30 psi Tag top of tubing and rotate slowly 1 turn to the left, no noticeable change in weight or pressure Pick up 2', set back down on 4.5" tubing stump and rotate 1/4 tum to the right, positive indication box fell over pin on weight indicator and pressure increased to 90 psi Shut down pumps and remove pup joint to space out for wireline rig up DECOMP PJSM with Schlumberger E-line hands Rig up Big Mac (7.062" ID valve to test lubricator), E-line lubricator, BOP, and pack off, test to 1000 psi DECOMP Run in hole with 3.70" gauge ring, junk basket, and collar locator No problems passing 1,165' tubing reconnect joint or 2,070' SSSV nipple, run down to 10,228' Pull out of hole with out any problems, 1 - 12 oz cup of plastic pipe coating in junk basket DECOMP Run in hole with EZSV 3.66" OD Tag up at 192' Work multiple times but could not get past 204' Looked like EZSV was pushing something ahead of it Pull out of hole, bottom of EZSV was full of paraffin and plastic pipe coating DECOMP Run in hole with second 3.70" OD gauge ring, junk basket, and collar locator Tagged up at 204', work up and down twice and was able to get past 204' Run in hole to 10,228' without any problems Pull out of hole, stuck at 500', work junk basket down to get free, pull out of hole and inspect junk basket Junk basket full of paraffin and some plastic pipe coating Run in hole to 3,000' with 3.70" OD gauge ring, junk basket, and collar locator DECOMP Pull out of hole with 3.70" OD gauge ring, junk basket, and collar locator Junk basket full of paraffin Run in hole with 4 1/2" EZSV (3.66" OD) Start taking weight from 340' - 400', slump on wireline and wait for EZSV to fall Run in hole fine from 500' to 10,230', identify completion equipment from Sliding sleeve to the "X" Nipple Re-log pulling up from "X" Nipple to Sliding sleeve, run in hole to 10,230' Pull up to position top of EZSV at 10,210', Set top of EZSV at 10,210', Positive indication EZSV fired by decrease in tension, wait 3 minutes and stack tools on EZSV to confirm set Pull out of hole Break Schlumberger Lubricator and stand off to side Fill 4 1/2" tubing, shut down hole fill and monitor fluid levels in 4 1/2" tubing and 9 5/8" IA DECOMP Monitor well for losses, losses at 0.5 bbls/hr DECOMP Rig down Schlumberger Lubricator Printed: 11 /2/2007 12:01:37 PM Legal Well Name: G-19 Common Well Name: G-19 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 7ES Date I From - To I Hours ( Task Code ~ NPT 9/21/2007 09:30 - 14:00 I 4.501 DHB I P 14:00 - 16:00 2.00 DHB P 16:00 - 18:00 I 2.00 I RE 18:00 - 00:00 I 6.001 RE 9/22/2007 100:00 - 12:00 I 12.00 12:00 - 13:00 I 1.00 13:00 - 14:00 I 1.00 14:00 - 18:00 I 4.00 18:00 - 19:30 I 1.50 19:30 - 20:30 I 1.00 20:30 - 22:00 I 1.50 Spud Date: 6/6/1986 Start: 9/13/2007 End: Rig Release: 10/26/2007 Rig Number: Phase I Description of Operations DECOMP Monitor well for losses, losses at 0.5 bbls/hr DECOMP Pick up Baker internal multi string cutter Cut 4 1/2" tubing just above lower pipe rams, 19.5' Lay down cutter, 5.80' pup, and cut joint 13.58' DECOMP PJSM with Haliburton, Baker, and crew Rig up 2 7/8" PAC running equipment Pick up Haliburton stinger for EZSV DECOMP Run in the hole with 2 7/8" PAC drill pipe from surface to 3,000' picking up singles out of the pipeshed Stop and circulate 104 degree 9.8 brine at first HTPAC joint of drill pipe and 3,000' 1,600' 4 bbls 1 bbl/min 130 psi 3,000' 22 bbls 2 bbl/min 595 psi Paraffin in returns, dump to cuttings box DECOMP R1H with 2 7/8" HTPAC drill pipe from 3,000' to 10,142' picking up singles out of the pipeshed Stop and circulate bottoms up with 104 degree 9.8 ppg brine at 6,000' and 9,000' 6,024' 92 bbls 3 bbl/min - 2,200 psi, fluid was out of balance, U-tubing after first bottoms up, circulate bottoms up x2 9,021' 78 bbls 2 bbl/min - 1,355 psi, 3 bbUmin - 2,933 psi DECOMP Rig up to pump Wash down from 10,142' to EZSV Tag EZSV at 10,210' 2 BPM - 1,537 psi DECOMP Lay down joint of HTPAC drill pipe and space out string for cementing DECOMP Circulate 9.8 ppg brine while waiting on cement results from Lab 2 BPM - 1,537 psi 3 BPM - 3,100 psi DECOMP Rig up Schlumberger Cementers PJSM with Schlumberger, Halliburton, and crew Pressure test lines to 5,000 psi DECOMP Run in hole to 10,210', sting into EZSV past "O"ring seal but left the valve closed to test seal Seal tested good, slack off and apply 10 Klbs on stinger Switch over to Schlumberger for injection test 0.5 BPM - 1,450 psi 1.0 BPM - 2,100 psi, staging up to 1 BPM break over was at 2,600 psi Inject 43.7 bbls of 9.8 ppg brine while waiting on 14.0 ppg Squeeze Crete Cement to be batch mixed Batching started at 19:50 DECOMP Switch on the fly to start cement job Phase Vol Rate Pressure Mud Push 2.2 bbls 1 BPM 2,050 psi 14.0 PPG Squeeze Crete 14.4 bbls 1 BPM 1,360 psi Mud Push 2.0 bbls 1 BPM 1,309 psi 9.8 ppg Brine 40.5 bbls 1 BPM 1,670 psi BP EXPLORATION Page 8 of 32 Operations Sumllnary Report Nnntea: tvzizuui u:ui::ti rnn - • • BP EXPLORATION Page 9 of 32 ..Operations Summary Report Legal Well Name: G-19 'Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: ..Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date I From - To, Hours I Task I Code ~ NPT ! Phase I Description of Operations 9/22/2007 120:30 - 22:00 I 1.50 DECOMP Displacement left 1.0 bbls of cement in the 2 7/8" drill pipe and 2.0 bbls of Mud Push 22:00 - 22:30 I 0.50 22:30 - 23:30 I 1.00 23:30 - 00:00 I 0.501 RE 9/23/2007 100:00 - 12:00 I 12.00 12:00 - 12:30 0.50 12:30 - 13:30 1.00 13:30 - 18:00 I 4.501 STCTPL I P 18:00 - 21:00 I 3.00 I STCTPL I P 21:00 - 22:00 I 1.00 I STCTPL I P 22:00 - 00:00 I 2.001 STCTPL I P ~ 9/24/2007 ~ 00:00 - 02:00 ~ 2.00 ~ CLEAN ~ P 02:00 - 04:00 2.00 CLEAN P 04:00 - 10:30 6.50 CLEAN P Pressure started to climb as the cement crossed the first set of perfs, 1,200 psi to 1,670 psi Cement in place at 21:42 DECOMP Shut down pumps, 400 psi on drill pipe Pull out of EZSV, drill pipe pressure dropped to zero Allow cement in drill pipe to U-tube Pull out of hole, lay down 2 joints, both joints were dry DECOMP Hook up head pin and circulate bottoms up x2 159 bbls 9.8 ppg brine 3 BPM 3,130 psi 10 bbls of cement contaiminated brine back to surface, ph spike, weight increased to 11.0 ppg, and smelled like cement, dump to cuttings box DECOMP Rig down circulating equipment Rig up to lay down 2 7/8" HTPAC drill pipe DECOMP Pull out of hole #rom 10,150' to BHA laying down 2 7/8" PAC drill pipe Well static; no losses during trip out DECOMP Lay down cement stinger BHA DECOMP Rig down 2 7/8" handling equipment Clean and clear rig floor DECOMP Rig up Schlumberger lubricator extension, Big Mac (7.062" ID valve to test lubricator), wireline BOP, lubricator, and pack off Test lubricator to 500 / 1000 psi DECOMP Run in hole with Schlumberger Jet cutter and collar locator on E-line to 10,100' DECOMP Log down to 10,154', lost tension on wireline, pick up and get tool movement at 10,154' Top of Cement at 10,154' Log sliding sleeve going down, log sliding sleeve going up and correlate to EZSV run Position jet cutter at 10,142' Fire jet cutter, positive indication on tension that jet cutter moved down hole DECOMP Pull out of hole Lay down wireline tools Jet cutter fired DECOMP Rig up 2 7/8" PAC handling equipment Pick up 4 1/2" RTTS BHA to circulate below back off at 1,165' DECOMP Run in hole with 49 joints of 2 7/8" PAC to 1,512' DECOMP Set RTTS Packer at 1,512' Circulate Hi Vis Sweep with red dye surface to surface 138 bbls 9.8 ppg brine pumped 2 BPM @ 3444 psi 323 bbls 9.8 ppg brine pumped 4 BPM @ 2,900 psi, gas back to surface, breaking out in bell nipple, shut down pumps and monitor well, well static, returns were 9.3 ppg brine 548 bbls 9.8 ppg brine pumped 3 BPM @3,055 psi, returns back to 9.8 ppg brine, no gas 625 bbls 9.8 ppg brine pumped 4 BPM @ 3,480 psi, Red dye back to surface, dump 65 bbls red brine, dye strung out in Printed: 11/2/2007 12:01:37 PM - . • BP EXPLORATION Page 10 of 32 .Operations Summary Report (Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: 'Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date I From - To ~ Hours I Task ~ Code ~ NPT I Phase I Description of Operations 9/24/2007 04:00 - 10:30 6.50 CLEAN P 10:30 - 11:00 0.50 CLEAN P 11:00 - 13:15 2.25 CLEAN P 13:15 - 14:00 0.75 CLEAN P 14:00 - 14:30 0.50 CLEAN P 14:30 - 15:00 0.50 CLEAN P 15:00 - 17:00 2.00 CLEAN P 17:00 - 17:30 0.50 CLEAN P 17:30 - 18:15 0.75 STCTPL P 18:15 - 18:45 0.50 STCTPL P 18:45 - 19:30 0.75 STCTPL P 19:30 - 20:00 0.50 STCTPL P 20:00 - 22:00 2.00 STCTPL P 22:00 - 22:30 0.50 STCTPL P 22:30 - 00:00 1.50 BOPSU P 9/25/2007 00:00 - 00:45 00:45 - 08:30 08:30 - 09:30 09:30 - 10:00 10:00 - 10:30 10:30 - 12:00 0.751 BOPSUF{P 7.751 BOPSUaP 1.00 BOPSU P 0.50 FISH P 0.50 FISH P 1.50 FISH P DECOMP returns Calculated 680 bbls surface to surface for cut at 10,142' and dye back at 690 bbls 9.8 ppg brine in, 9.8 ppg brine out DECOMP Monitor well, well static DECOMP Circulate bottoms up 549 bbls 9.8 ppg brine 4 BPM @ 2,878 psi 9.8 ppg brine in, 9.8 ppg brine out OA = 135 psi Fluid level in 20" x 13 3/8" = 58" DECOMP Monitor well, well static DECOMP Bleed OA down to zero and monitor during test Test 9 5/8" casing to 1000 psi for 5 min, good test, OA = 100 psi DECOMP Monitor well, well static Rig down E-line equipment left on rig floor and clear off rig floor DECOMP Pull out of hole with RTTS from 1,512' laying down 2 7/8" PAC drill pipe in pipe shed DECOMP Lay down RTTS Pick up Multi string cutter DECOMP Run in hole to 217' with multi string cutter on 2 7/8" PAC drill pipe DECOMP Cut 4 1/2" tubing at 217' 17 GPM @ 1,550 psi DECOMP Pull out of hole with multi string cutter Lay down cutter DECOMP Pick up Baker Spear Assembly on 4" Drill Pipe Run in hole to 19' Spear 4 1/2" tubing Pull out of hole with fish DECOMP Lay down cut joint (28.25') with spear engaged, 3 pups, 3 joints tubing, 2nd cut joint (12.25'), 95' control line, and one control line clamp DECOMP Rig down handling equipment, clean and clear rig floor DECOMP Install test plug Change lower rams to 9 5/8" DECOMP Install 9 5/8" test joint Fill stack, choke, and test joint with water DECOMP Test BOP, Low 250 psi, High 3,500 psi #1 -Upper Rams, 4 1/2" test joint #2 -Upper Rams, 4" test joint, Choke valves 1, 2, 3, 16, Lower (BOP, Dart Valve #3 -Choke vavles 4, 5, 6, HCR Kill, Manual top drive #4 -Choke valves 7, 8, 9, Floor Valve, Manual Kill #5 -Super Choke, Manual Choke #6 -Choke valves 10, 11, 15 Witnessed by: Duncan Ferguson, Joey LeBlanc BP, Lenward Toussant and Chris Weaver NAD and Jeff Jones AOGCC. DECOMP RD test equipment. Clear rig floor. DECOMP PU Baker 5-1/2" multistring cutter. DECOMP RIH to 178' MD. DECOMP Circulate 50 bbl 8.5 ppg seawater, RU lines f/OA to cuttings Printed: 11/2/2007 12:01:37 PM :~ i ~ BP EXPLORATION Page 11 of 32 Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date I From - To I Hours I Task I Code I NPT Phase Description of Operations 9/25/2007 112.30 - 13:00 ~ 0.501 FISH I P 13:00 - 15:30 I 2.501 FISH I P 15:30 - 15:45 0.25 FISH P 15:45 - 17:00 1.25 FISH P 17:00 - 19:00 2.00 FISH P 19:00 - 21:00 2.00 FISH P 21:00 - 21:30 I 0.501 FISH P 21:30 - 22:45 1.25 FISH P 22:45 - 00:00 I 1.251 FISH I P 19/26/2007 100:00 - 01:30 I 1.501 FISH I P 01:30 - 02:30 1.00 FISH P 02:30 - 03:00 0.50 FISH P 03:00 - 06:00 3.00 FISH P 06:00 - 08:00 I 2.001 FISH I P 08:00 - 09:00 1.00 FISH P 09:00 - 10:00 1.00 FISH P 10:00 - 11:00 1.00 FISH P 11:00 - 12:00 1.00 FISH P 12:00 - 13:00 1.00 FISH P 13:00 - 15:00 2.00 FISH P 15:00 - 16:00 I 1.001 FISH I P DECOMP box. Fluid 52" below 13-3/8" x 20"fluted hanger. DECOMP Cut 9-5/8" casing at 178'. 229 gpm, 609 psi, 53 rpm, 1 K tq. DECOMP Close annular preventer. Circulate 170 gpm, 360 psi. 50 bbls 120 deg. 8.5 ppg seawater down 9-5/8" through cut at 178' in 9-5/8" up 13-3/8" annulus. Dead crude freeze protect fluid recovered at surface and sent to cuttings box. DECOMP PJSM. Rig up Little Red Hot Oil Svcs. Pump 20 bbls 100 deg F. diesel down 9-5/8" casing. Returns apparent up 9-5/8" x 13-3/8" annulus. Allow diesel to sit 30 mins. Circulate 120 deg. F 8.5 ppg seawater. 211 gpm, 410 psi. Pump 128 bbls total volume. DECOMP POH f/178' w/9-5/8" casing cutter and LD cutter. DECOMP MU 9-5/8" casing spear. RIH. Latch into 9-5/8" casing. Fluid returns noticed at 13-3/8" x 20" annulus. 10 gals. crude oil released into secondary containment herculite berm in cellar. Cleaned up w/adsorb. Notified BP non emergency spill department # 5700. Drain fluid f/BOP stack and flow ceased f/20". DECOMP Unlatch spear. POH. Monitor 13-3/8" x 20" annulus. Static. DECOMP RIH w/ 9-5/8" spear and latch casing. Back off lock down screws. Pull packoff up 7' w/25K overpull. No further upward movement possible after 7'.s Pull to 75K w/no movement. Consult w/town team. DECOMP POH. LD casing spear. DECOMP MU &RIH w/casing cutter. Cut 9-5/8" casing at 52'. 191 gpm, 820 psi, 60 rpm, 1 K tq. POH and lay down casing cutter. DECOMP MU 9-5/8" casing spear, RIH 21' and latch casing. Pull to 75K. Not free. POH and lay down spear. Prepare to rerun casing cutter. DECOMP MU &RIH w/casing cutter. Re-cut 9-5/8" casing at 52'. 190 gpm, 820 psi, 60 rpm, 1 K tq. POH and lay down casing cutter. DECOMP POH w/9-5/8" casing f/52' to surface. LD 32' of 9-5/8" casing. DECOMP MU and RIH w/9-5/8" spear, bumper sub, and two 6.5" drill collars. DECOMP Engage spear in 9-5/8" casing at 52'. Jar down w/bumper sub and free casing. Tag up 7.5' below stuck point on top of cut at 178' as expected. PU and pull back up through tight spot w/9-5/8". Work pipe up through tight spot. Pull over to 100K on indicator briefly and work pipe to surface w/spear. Casing collapsed immediately below 1st collar pulled above floor. Disengage and stand collars/spear back. DECOMP RU and LD 9.92' top cut off stub, 1 collapsed jt, 2 jts, and a 32' bottom cut off stub. Top of 9 5/8" stub at 178' DECOMP Clear floor, service top drive and rig. DECOMP Monitor well. Consult w/town team on plan forward. DECOMP RU and RIH w/BHA #13 to spear 4.5" tubing.. DECOMP Engage fish w/spear and POH w/4.5" tubing. PU = 40K. DECOMP RU to LD 4.5" tubing. DECOMP LD 28.45' top cut off stub, 22 jts of 4.5" tubing, total of 917.61' laid down. 917.61' + 217' f/previous cut =top of 4.5" tubing at 1164.61'. Note: Pin up on tubing remaining in hole. Laid down additional control line and 12 clamps. DECOMP RD tubing handling equipment. Clear rig floor. Printed: 11/2/2007 12:01:37 PM -~ ~ • $P EXPLORATION Page 12 of 32 Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 7ES Date I From - To I Hours I Task Code l NPT 9/26/2007 16:00 - 22:00 I 6.001 FISH P 22:00 - 00:00 2.00 FISH P 9/27/2007 100:00 - 03:00 I 3.00 I FISH I P 03:00 - 04:30 1.50 FISH P 04:30 - 06:00 1.50 FISH P 06:00 - 12:00 6.00 FISH P 12:00 - 16:00 4.00 FISH P 16:00 - 17:00 1.00 FISH P 17:00 - 19:30 2.50 FISH P 19:30 - 20:30 1.00 FISH P 20:30 - 21:00 I 0.501 FISH I P 21:00 - 00:00 I 3.001 FISH I P 19/28/2007 100:00 - 00:30 I 0.501 FISH I P 02:30 - 03:00 I 0.501 FISH P 03:00 - 03:30 0.50 FISH P 03:30 - 05:30 2.00 FISH P 05:30 - 06:30 1.00 FISH P 06:30 - 07:00 I 0.501 FISH I P 09:30 -109:00 1.501 FISH I P 11:00 - 12:30 I 1.501 FISH I P 13:30 - 15:00 1.501 FISH ~ N 15:00 - 16:30 1.50 FISH P 16:30 - 18:15 1.75 FISH P 18:15 -20:00 1.75 FISH P Spud Date: 6/6/1986 Start: 9/13/2007 End: Rig Release: 10/26/2007 Rig Number: Phase ~ Description of Operations DECOMP MU 10.75" swaging BHA # 15. DECOMP Work swage through tight spot in 13-3/8" f/69' to 80' several times. Use bumper subs to drive through obstruction each time. Pull up to 100K to pull back through. Trip jars as required when pulling back through tight spot. Broke hydraulic fitting on top drive. Repair line. DECOMP Work 10.75" OD swage through tight spot in 13 3/8" casing f/69' to 80'. No change in up down weight requirements to work swedge down and back through. DECOMP LD 10.75" OD swage and PU 11.50" OD swedge. DECOMP Swage tight spot between 69' and 80' w/11.25" OD swedge. DECOMP Spot tube pill across tight spot. Swedge between 69' and 82'. No change 50K overpull to bring swedge through tight spot. DECOMP PJSM. Replace IBOP damaged by jarring activities. Test lower IBOP 250/3000 psi. DECOMP Inspect derrick and top drive. DECOMP Work 11.5" swedge through tight spot between 69' and 82'. DECOMP LD 11.5" swedge and PU 12.125" swedge. 11.5" swedge still gage. DECOMP RIH to 68' w/12.125" swedge and spot tube pill around swedge. DECOMP Run 12.125" swedge and work tight spot between 69' and 82' several times. This swedge worked through more easily than past smaller swedges. RIH to 100' w/no resistance. Still 50K PU to pull swedge through tight spot. DECOMP Run 12.125" swedge through tight spot in 13-3/8" casing between 69' and 82'. DECOMP LD 12.125" swedge and BHA #17. DECOMP Clear rig floor and bring 12.125" OD dress-off shoe and washpipe assy for 9 5/8" casing to floor. DECOMP Service topdrive and rig. DECOMP Pick up 12.125" OD Dress-off shoe for 9-5/8" stub. BHA #18. DECOMP RIH BHA # 18 w/12.125" OD shoe w/11.75" washpipe and inner mill to dress top of 9-5/8" stub. DECOMP Dress top of 9-5/8" casing stub at 178' to accept temporary casing patch overshot. DECOMP POH and LD BHA # 18. DECOMP RU to run 9-5/8" temporary overshot casing patch and 9-5/8" 47# L-80 BTC casing f/178' to surface and land using lower pipe rams as temporary packoff. DECOMP Run BHA #19. 11.125" OD overshot assy. to 178'. Engage 9-5/8" and pull check w/25K over string wt. DECOMP RD casing handling equipment. RREP DECOMP (NPT not chargeable to rig.) Topdrive. Bolts sheared on top of IBOP actuator due to jarring while swaging. Replace ring and bolts. Test upper and manual IBOPs 250/3000 psi low/high pressure. DECOMP MU BHA #20. 4.5" tubing overshot assy. DECOMP RIH picking up 4" HT40 drill pipe 1 x 1 to 1165'. Engage 4.5" tubing w/overshot and grapple. Pull over string wt. 25K to 175K and pull free. DECOMP Circulate 20 bbls Safe-Solt' and 30 bbls Safe-Surf O around Printetl: 11/2/2007 12:01:37 PM • BP EXPLORATION Page 13 of 32 Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/28/2007 18:15 - 20:00 1.75 FISH P DECOMP w/9.8 ppg brine. 490 gpm, 1175 psi. Pump 781 bbls. 20:00 - 22:00 2.00 FISH P DECOMP POH. LD 4.5" tubing overshot/grapple BHA # 20. 22:00 - 00:00 2.00 FISH P DECOMP POH laying down 4.5" 12.6# L-80 Buttress tubing 1 x 1. 9/29/2007 00:00 - 05:00 5.00 FISH P DECOMP Continue POH laying down 4.5" 12.6 # L-80 Buttress tubing. Lay down 219 jts, 1 SSSV w/pups, 1 sliding sleeve w/pups, 1 cut off stub 17.08' w/clean jet cut. Retrieved 11 rubber clamps, 2 stainless steel bands and 1000' control line. 05:00 - 06:30 1.50 FISH P DECOMP RD 4.5" tubing handling equipment and clear rig floor. 06:30 - 07:30 1.00 CLEAN P DECOMP PU 8.5" bit and 9-5/8" casing scraper BHA #21. 07:30 - 14:00 6.50 CLEAN P DECOMP PU 4" drill pipe in singles from the pipe shed and RIH to 1.0138' and tag tubing stub. 180K PU 130K SO. 14:00 - 15:15 1.25 CLEAN P DECOMP CBU at 10137'. 460 gpm, 2530 psi. Pumped 623 bbls. 15:15 - 19:30 4.25 CLEAN P DECOMP Monitor well. BD topdrive. MW = 9.8 ppg. POH to BHA. 19:30 - 21:00 1.50 CLEAN P DECOMP LD BHA #21. Recover 1.5 gals scale from boot baskets. 21:00 - 23:45 2.75 DHB P DECOMP PU blank bottom perforated drill pipe pup and RIH picking up 4" drill pipe singles to 3351'. 23:45 - 00:00 0.25 DHB P DECOMP RIH hole w/drill pipe stands (/3351' to 4595'. 9/30/2007 00:00 - 02:00 2.00 DHB P DECOMP RIH w/cementing stinger and drill pipe stands f/4595' to 10142'. 02:00 - 04:30 2.50 DHB P DECOMP CBU and RU cement lines to spot balanced plug. RU Schlumberger cementing unit. 04:30 - 05:30 1.00 DHB P DECOMP PJSM w/Schlumberger, hands, TP and WSL. Test lines to 4000 psi. Pump 10 bbl water ahead of cement. Mix and pump 7.3 bbl class "G" cement at 15.8 ppg, 92 gpm 150 psi. Pump 1.25 bbl water, 84 gpm, 118 psi. Switch to rig pumps and displace with 95 bbl 9.8 ppg brine. 294 gpm, 800 psi. Under displace by 2 bbl. Cement in place at 05:15. 05:30 - 07:00 1.50 DHB P DECOMP POH 100' slowly out of cement plug to 9980'. CBU 500 gpm, 2330 psi. Noted ph spike at bottoms up. 07:00 - 14:00 7.00 DHB P DECOMP WOC for 1000 psi compressive strength. Service rig and top drive. Repair EZ torque pressure regulator. Cut and slip drilling line. Displace well to 8.5 ppg seawater while WOC. Rig housecleaning. 14:00 - 14:30 0.50 DHB P DECOMP RIH and find hard cement at 10005'. SO 10K on cement. POH to 9947' and circulate 20 bbls 8.5 ppg seawater to clear cement from stinger, 200 gpm 360 psi. PU 165K, SO 125K. BD topdrive. Monitor well. 14:30 - 19:00 4.50 DHB P DECOMP POH w/drill pipe (/9947' to surface. LD cementing stinger. 19:00 - 21:30 2.50 DHB N WAIT DECOMP Wait on Schlumberger Wireline unit to run 9-5/8" EZSV and USIT log. 21:30 - 23:30 2.00 DHB P DECOMP RU Schlumberger wireline unit. 23:30 - 00:00 0.50 DHB N SFAL DECOMP Mobilize Sclumberger mechanic f/Deadhorse to repair wireline unit hydraulic winch actuator pump system. 10/1/2007 00:00 - 00:30 0.50 DHB N SFAL DECOMP Continue repair actuator pump f/winch on wireline unit. 00:30 - 03:00 2.50 DHB P DECOMP RIH w/9-5/8" Halliburton EZSV w/bridging plug and log into place w/top at 9943'. Collar below at 9947'. Collar above at 9907'. Tag cement top at 10007'. 03:00 - 04:30 1.50 DHB P DECOMP POH w/E-line running tool. LD Schlumberger E-line setting tool. 04:30 - 06:30 2.00 EVAL P DECOMP RU USIT logging equipment and RIH. to 9943'. 06:30 - 10:00 3.50 EVAL P DECOMP USIT. Log f/9943' to 150'. 10:00 - 11:30 1.50 EVAL P DECOMP RIH to 2300' and relog to 150' to verify top of cement. 11:30 - 12:00 0.50 EVAL P DECOMP LD USIT tool. Printed: 11/2/2007 12:01:37 PM - ~ • BP EXPLORATION Page 14 of 32, Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date I From - To I Hours I Task I Code I NPT I Phase I Description of Operations 10/1/2007 12:00 - 13:30 1.50 EVAL P 13:30 - 14:30 1.00 EVAL P 14:30 - 15:00 0.50 EVAL P 15:00 - 17:45 2.75 EVAL P 17:45 - 18:30 0.75 EVAL P 18:30 - 19:30 1.00 EVAL N 19:30 - 00:00 4.50 EVAL P 10/2/2007 100:00 - 04:30 I 4.501 EVAL I P 04:30 - 05:30 1.00 EVAL P 05:30 - 06:30 1.00 FISH P 06:30 - 08:00 1.50 FISH P 08:00 - 08:30 0.50 FISH P 08:30 - 09:30 1.00 FISH P 09:30 - 10:30 1.00 FISH P 10:30 - 11:30 1.00 FISH P 11:30 - 14:30 3.00 FISH P 14:30 - 15:00 0.50 FISH P 15:00 - 19:30 4.50 FISH P 19:30 - 20:15 0.751 FISH ~P 20:15 - 21:00 0.75 BOPSU P 21:00 - 00:00 3.00 BOPSU P 10/3/2007 00:00 - 01:30 1.50 BOPSU P 01:30 - 02:00 0.50 BOPSU P 02:00 - 03:00 1.00 FISH P 03:00 - 05:00 2.00 FISH P DECOMP RU to run stringshot. DECOMP RIH and log 12' x 3 strand stringshot into place and fire across collar at 2000'. DECOMP POH and LD string shot tool. DECOMP RU Gyrodata gyro survey equipment. DECOMP Run gyro f/surface to 1000' continuous data acquisition. Gyrodata CCL failure. DFAL DECOMP POH and changeout CCL unit. DECOMP Attempt to gyro survey continuous mode f/1000' to 9943'. Gyro not able to acquire data continuously. Consult w/town team and decision made to single shot survey surface to 9943'. Per Gyrodata, run single shot survey every 50' by surveying every even 100' running in hole to 9900' (5000, 5100, 5200 etc.). PU 50' and survey ea. alternating odd 100' (5250', 5150', 5050' etc.) while POH to surface. Data acquisition OK in single shot mode. DECOMP Continue to survey w/gyro in single shot mode f/9943' to surface. Perform rig preventive maintenance and housecleaning. DECOMP RD Schlumberger wireline unit/GyroData equipment and clear rig floor. DECOMP PU Baker 9-5/8" multistring casing cutter BHA # 22 and RIH to 1980'. DECOMP RU to circulate to OA. Spot vac truck for cellar. PJSM w/Baker, crew, TP and WSL before cutting casing. DECOMP Cut casing at 1980'. 127 gpm, 310 psi, 50 rpm, 2.5K tq. Circulate 115 bbls seawater down drill pipe, through cut, and up 13-3/8" x 9-5/8" annulus. 208 gpm, 1020 psi. DECOMP Monitor well. POH to BHA. MW = 8.5 ppg seawater. DECOMP LD 9-5/8" multistring cutter. MU 9-5/8" casing spear w/packoff and stab into 9-5/8" casing at surface. DECOMP PU 9-5/8" and pull free w/string wt. 105K. Spot Hot Oil Svc. Hook up lines. PJSM. DECOMP Test lines to 3000 psi. Circulate 120 bbls heated diesel down 9-5/8" casing to 1980 and into 9-5/8" x 13-3/8" annulus via cut in 9-5/8". 5 bpm, 800 psi. Displace w/145 bbl 100 deg. 8.5 ppg seawater w/Safe Surf 0, 235 gpm, 20 psi. SD and allow diesel to soak f/30 min. in annulus. Circulate annulus clean w/219 bbls 8.5 ppg 100 deg seawater at 235 gpm, 137 psi. DECOMP Pull casing to floor w/105K PU wt. and LD spear. DECOMP Id 4 jts 9-5/8" BTC casing and casing patch overshot w/5.75' cut off stub, 50 jts. of 9-5/8" NSCC casing w/18.38' cut off stub on bottom. 10 turbolators on jts. DECOMP RD casing equipment and clear floor. DECOMP RU to test BOP. DECOMP Test BOP to 250psi/3500 psi low/high pressure. Test witnessed by Lenward Toussant NAD TP and Lowell Anderson BP WSL. AOGCC rep Lew Grimaldi waived AOGCC presence at test. DECOMP Continue BOP test. DECOMP RD test equipment and clear floor. DECOMP PU 11-3/4" washpipe/washover shoe BHA# 24. DECOMP RIH and wash down over stub and collar at 2000'. 300 gpm, Printed: 11/2/2007 12:01:37 PM -~ BP EXPLORATION Page 15 of 32 Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/3/2007 03:00 - 05:00 2.00 FISH P DECOMP 225 psi. 05:00 - 06:30 1.50 FISH P DECOMP CBU. 300 gpm, 225 psi., 50 rpm, 2K tq. PU 70K, SO 68K, ROT 70K. 06:30 - 07:00 0.50 FISH P DECOMP POH to SHA#24. MW = 8.5 ppg. 07:00 - 08:00 1.00 FISH P DECOMP Stand back collars and LD washover BHA # 24. Found 3 centralizer inside of washpipe. 08:00 - 08:30 0.50 FISH P DECOMP Clean and clear floor. 08:30 - 09:30 1.00 FISH P DECOMP PU cleanout BHA# 25 w/8.5" bit. 09:30 - 10:30 1.00 FISH P DECOMP RIH to stub at 1980'. Took 2K wt to enter 9-518" stub. RIH past stub to 2500'. PU 78K SO 78K. 10:30 - 11:30 1.00 FISH P DECOMP POH to BHA. Stand back drill collars. 11:30 - 12:00 0.50 FISH P DECOMP LD BHA # 25. 12:00 - 13:45 1.75 FISH P DECOMP PU 8" Backoff Tooi BHA #26 w/muleshoe on drill collars below backoff tool. 13:45 - 16:00 2.25 FISH P DECOMP RIH w/drill pipe filling ea. stand, 16:00 - 16:30 0.50 FISH P DECOMP RIH. Drill collars entered 9-5/8" stub. Lower anchor on back off tool would not enter 9-5/8" at 1980'. SO 10K on tools and attempt to rotate w/20 rpm, 1.5K tq. 16:30 - 16:45 0.25 FISH P DECOMP Drop ball/rod and circulate to seat in pump out sub. Blow seat out at and circulate drill pipe volume 8.5 ppg seawater. BD topdrive. 16:45 - 17:45 1.00 FISH P DECOMP Monitor well. POH to BHA. MW = 8.5 ppg. 17:45 - 19:00 1.25 FISH P DECOMP LD Backoff Tool BHA #26. Stand back 3 stands of drill collars. 19:00 - 20:15 1.25 FISH P DECOMP MU tapered mill/string mill BHA #27. 20:15 - 21:00 0.75 FISH P DECOMP RIH w/4" drill pipe to 1970'. 21:00 - 21:45 0.75 FISH P DECOMP Enter 9-5/8" w/no problem. Run mills up and back f/1980' to 1985'. 80 rpm, 1 K tq, 262 gpm, 167 psi, 75K PU, 73K SO, 75K ROT. 21:45 - 22:00 0.25 FISH P DECOMP RIH f/1980' to 2510'. No obstructions seen. 22:00 - 23:00 1.00 FISH P DECOMP POH to BHA. 23:00 - 23:30 0.50 FISH P DECOMP Stand back drill collars. LD tapered/string mill BHA #27. 23:30 - 00:00 0.50 FISH P DECOMP MU 8" Backoff Tool BHA #28. 10/4/2007 00:00 - 02:00 2.00 FISH P DECOMP RIH w/Backoff Tool BHA #28 to 1980'. 02:00 - 03:00 1.00 FISH P DECOMP Position backoff tool across collar at 2000'. Actuate backoff tool. 1st break at 2000 psi. 3/4 of a turn. Cycle tool 8 more times w/average pressure of 800 psi for a total of 5 complete rotations at the casing collar. On last actuation pressure increased to 1200 psi. Drop ball/rod to circ sub. Circulate ball to seat. Btow out seat at 1400 psi. Circulate string volume w/8.5 ppg seawater. 03:00 - 03:30 0.50 FISH P DECOMP POH w/BHA #28. 03:30 - 04:00 0.50 FISH P DECOMP LD Backoff Tool BHA #28. 04:00 - 04:30 0.50 FISH P DECOMP PU Spear BHA #29. 04:30 - 05:00 0.50 FISH P DECOMP RIH w/Spear. 05:00 - 05:30 0.50 FISH P DECOMP Engage fish w/spear. 05:30 - 06:30 1.00 FISH P DECOMP Attempt to complete backoff. Tq. = 9K. Work pipe. PU 60K, SO 60K. No rotation possible. Release spear. 06:30 - 07:30 1.00 FISH P DECOMP CBU x 2. 440 gpm, 430 psi. Monitor well. BD topdrive. 07:30 - 08:00 0.50 FISH P DECOMP POH w/Spear BHA #29. MW = 8.5 ppg. 08:00 - 08:30 0.50 FISH P DECOMP LD BHA #29. 08:30 - 10:00 1.50 FISH P DECOMP PU 11.75" Washpipe BHA #30. 10:00 - 11:30 1.50 FISH P DECOMP RIH to 1840'. Printed: 11/2/2007 12:01:37 PM BP EXPLORATION- Page 16 of 32 Opelratiolns Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/4/2007 11:30 - 12:00 0.50 FISH P DECOMP Cut and slip drilling line. 12:00 - 12:45 0.75 FISH P DECOMP Service topdrive. 12:45 - 13:00 0.25 FISH P DECOMP RIH f/1840' to 1970'. 13:00 - 14:30 1.50 FISH P DECOMP Wash over stub at 1980', past collar at 2000', tag up slightly and wash free at 2018'. Wash past collar at 2039' to 2073'. 211 gpm, 50 rpm. PU 75K, SO 70K. 14:30 - 16:00 1.50 FISH P DECOMP Circulate 180 vis sweep. Work pipe between 2025' and 2068', 460 gpm, 379 psi, PU 65K, SO 50K. POH to 1960'. RIH w/washpipe f/1960' over stump at 1980' to 2068' w/out pumps. No problems. 16:00 - 17:00 1.00 FISH P DECOMP POH to BHA. MW = 8.5 ppg. 17:00 - 19:30 2.50 FISH P DECOMP Stand back drill collars. LD 11.75" Washpipe BHA #30. 19:30 - 21:00 1.50 FISH P DECOMP PU 8" Backoff Tool BHA #31. 21:00 - 22:30 1.50 FISH P DECOMP RIH w/drill pipe to 1990' w/backoff tool lower anchor. Drill collars below backoff tool with 1/2 muleshoe at 2287'. No problem entering top of stub with 1/2 muleshoe and collars on bottom of back off BHA. 22:30 - 00:00 1.50 FISH P DECOMP Attempt to RIH f/1990' w/lower anchor of backoff tool. Lower anchor would not pass 2001'. 10/5/2007 00:00 - 00:30 0.50 FISH P DECOMP Work pipe and attempt to pass 2001' w/back off tool lower slip. PU 75K, SO 75K. Rotate slowly and attempt to pass obstruction. Torqued up when lower anchor at 2001'. PU 2' and attempt to rotate. Torqued up again. Attempt to RIH. Tag up each time at 2001' w/lower back off tool anchor. PU w/anchor to 1990' and attempt to rotate. Stilt torquing up. Pull back off tool above top of 9-5/8" into 13-3/8". Drop ball/rod to circ. sub and pump open at 1500 psi. 00:30 - 01:00 0.50 FISH P DECOMP POH to BHA. MW = 8.5 ppg. seawater. 01:00 - 01:30 0.50 FISH P DECOMP Stand back drill coNars. LD Backoff BHA #31. Junk scars on back off tool at lower anchor. 01:30 - 02:45 1.25 FISH P DECOMP PU 8.5" ODTapered Mill/String Mill BHA #32. 02:45 - 03:45 1.00 FISH P DECOMP RIH w/BHA #32 to top of 9-5/8" stub at 1980'. 03:45 - 04:30 0.75 FISH P DECOMP Enter 9-5/8" w/no problems. Run mills dry f/1980' to 2500". No obstructions. POH to collar at 2000' and work mills f/1980' to 2010'. 260 gpm, 134 psi, 50 rpm, PU 70K, SO 70K, ROT 75K. See torque to 1.9K on first pass through. Work mills through area several times. Tq .5K. Pull above collar to 1980' and run through dry to 2010'. No obstructions. 04:30 - 05:00 0.50 FISH P DECOMP POH. MW = 8.5 ppg. seawater. 05:00 - 05:30 0.50 FISH P DECOMP Stand back drill collars. LD tapered/string mill BHA #32. 05:30 - 07:00 1.50 FISH P DECOMP PU 8" Back Off Tool BHA #33. Replace damaged slip on backoff tool. 07:00 - 08:30 1.50 FISH P DECOMP RIH to 2331'. 08:30 - 10:00 1.50 FISH P DECOMP Space out Back Off Tool across collar at 2039'. Pressure up and at 2800 psi get 1 turn to left at surface. Pressure up 5 times to average 800 psi for a total of 4 turn to left at surface. Crop ball/rod to circ sub and shear out at 1600 psi. Circulate drill pipe volume. 10:00 - 11:00 1.00 FISH P DECOMP Monitor well. BD topdrive. MW = 8.5 ppg seawater. POH. 11:00 - 12:00 1.00 FISH P DECOMP Stand back drill collars. LD Back Off Tool BHA #33. 12:00 - 13:00 1.00 FISH P DECOMP PU Bowen Itco Spear BHA #34. 13:00 - 14:30 1.50 FISH P DECOMP RIH to 1980' and engage spear to stop collar in fish. 14:30 - 16:30 2.00 FISH P DECOMP POH w/fish. Printed: 11/2/2007 12:01:37 PM BP EXPLORATION Page 17 of 32 Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/5/2007 16:30 - 17:00 0.50 FISH P DECOMP PJSM w/hands and Baker. LD 21.05" cut off casing stub w/9-5/8" NSCC pin on bottom. 17:00 - 18:00 1.00 FISH P DECOMP LD Itco Spear BHA #34. 18:00 - 18:30 0.50 FISH P DECOMP PU Itco Spear BHA #35 w/new grapple f/8.681" ID. 18:30 - 20:00 1.50 FISH P DECOMP RIH to new top offish at 2000'. PU 63K, SO 67K, ROT 67K. Engage fish w/spear. Tq, up left to 10.2K to backoff fish and freewheel pipe. PU wt 59K. Suspect backoff, no bumper sub action. Screw back in and get pull over. Release spear. 20:00 - 21:30 1.50 FISH P DECOMP POH f/2000' check/torque ea. connection on trip out. 21:30 - 22:00 0.50 FISH P DECOMP No loose jt. found. LD BHA Bowen Itco Spear #35. 22:00 - 23:00 1.00 FISH P DECOMP PJSM w/hands on handling new type equipment. PU Baker Type "B" (slip type wP'j" slot w/right hand release) Spear BHA #36. 23:00 - 23:30 0.50 FISH P DECOMP RIH to 2001'. PU 69K, SO 73K, ROT 73K. Engage spear and back off 9-5/8" casing 3 turns to left. 23:30 - 00:00 0.50 FISH P DECOMP POH f/2001' to 1843'. MW = 8.5 ppg. 10/6/2007 00:00 - 00:30 0.50 FISH P DECOMP POH f/1843' to BHA. 00:30 - 01:00 0.50 FISH P DECOMP Stand back drill collars. POH w/BHA #36. No fish. 01:00 - 01:30 0.50 FISH P DECOMP Re-cock "j" on Type "B" spear. PU drill collars. RIH to 2001'. PU 69K, SO 73K, ROT 73K. Engage spear and back off 9-5/8" casing 3 more turns to left. Torque 5.5K max. See torque bleed off as expected. 01:30 - 02:30 1.00 FISH P DECOMP POH to BHA #36. 02:30 - 03:00 0.50 FISH P DECOMP LD Type "B" Spear BHA #36. Spear out of hole in released position. No fish. 03:00 - 03:30 0.50 FISH P DECOMP Service rig and topdrive. 03:30 - 04:30 1.00 FISH P DECOMP Bowen "Itco" Spear grapple damaged. Mobilize from Baker Deadhorse shop a new grapple f/Bowen Itco Spear BHA #37. 04:30 - 05:00 0.50 FISH P DECOMP PU Bowen Itco Spear BHA #37. 05:00 - 05:30 0.50 FISH P DECOMP RIH to 2001'. 05:30 - 06:00 0.50 FISH P DECOMP PU 62K, SO 67K, ROT 67K. Engage fish w/spear assy. Work pipe and torque left to 8.2K and back fish out. 06:00 - 07:00 1.00 FISH P DECOMP POH w/fish. 07:00 - 08:30 1.50 FISH P DECOMP Stand back drill collars. LD backed off joint 39.30' long w/NSCC box on bottom. Pin up downhole. LD spear BHA# 37. 08:30 - 09:00 0.50 FISH P DECOMP Clean and clear rig floor of fishing equipment. 09:00 - 10:00 1.00 CASE P DECOMP RU 9-5/8" casing handling/torque turn equipment. 10:00 - 17:30 7.50 CASE P DECOMP PJSM w/crew, TP, casing hand, WSL. RIH w/9-5/8" L-80 47# Hydril 563 casing to 70'. Torqueturn to 18000 ft/Ibs. See tight hole and work casing through collapsed area of 13-3/8" f/70' to 74'. RIH to 2026' and unable to RIH further. MU IF x Hyd 563 headpin and and rotate casing slowly through tight spot and then RIH free. 17:30 - 19:00 1.50 CASE P DECOMP Tag up at 2038'. PU 108K SO 110K. Work 10K torque down to Baker triple thread w/NSCC collar looking down. 14 turns at surface. RD torque turn equipment. Pull test to 250K. 19:00 - 21:00 2.00 CASE P DECOMP RU cement head and circulating lines. Pressure test casing from plug on top of baffle collar installed below ES cementer to surface. 2000 psi f/30 minutes and chart. Bring pressure up and shear out ES cementer at 2900 psi. Establish circulation w/210 gpm, 142 psi. 21:00 - 23:30 2.50 CASE P DECOMP PJSM w/Schlumberger, TP crew, truckdrivers, WSL. Pressure Printed: 11/2/2007 12:01:37 PM • -__ BP EXPLORATION. Page 18 of 32 Operations Summary :Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date I From - To Hours Task I Code I NPT I Phase I Description of Operations 10/6/2007 121:00 - 23:30 I 2.501 CASE I P 23:30 - 00:00 0.50 CASE P 10/7/2007 00:00 - 00:45 0.75 CASE P 00:45 - 01:45 1.00 CASE P 01:45 - 02:45 1.00 CASE P 02:45 - 17:30 14.75 CASE P 18:00 - 19:00 I 10.00 i CLEAN I P 19:00 - 20:00 1.00 CLEAN P 20:00 - 20:30 0.50 CLEAN P 20:30 - 21:30 1.00 CLEAN P 21:30 - 22:00 0.50 CLEAN P 22:00 - 00:00 I 2.00 I CLEAN I P 10/8/2007 100:00 - 03:30 I 3.501 CLEAN I P 03:30 - 05:30 I 2.001 CLEAN I P 05:30 - 11:00 I 5.501 CLEAN i P 11:00 - 13:00 I 2.001 WHSUR I P DECOMP test lines to 3000 psi. Pump 5 bbls water ahead down drill pipe w/Schlumberger. Start mixing cement at 22:00. Pump on the fly 139 bbls of 15.8 ppg Gcement w/additives at average 3 bbl/min. Red dye in 1st 10 bbls of cement. SD and drop ES Cementer closing plug. Follow w/Schlumberger pumping 10 bbls of displacement. Switch to rig pumps and displace w/139 bbts of 8.5 ppg seawater at 7 bpm average displacement rate down flow line to cuttings box. At 114 bbts displacement red dye to surface. SD. Close annular preventer. Open valve to line f/9-5/8" x 13-3/8" annulus direct to cuttings box to avoid cementing up BOP. Continue pumping displacement at 85 gpm. Bump plug on schedule. CIP 23:20. FCP = 845 psi. 23 bbls. cement weighed at 15.2 ppg back to surface. Bring pressure to 2000 psi, (see indication at floor that ES cementer closed) and hold for 5 minutes. Release pressure and check ES cementer. No bleed back. DECOMP Open annular preventer and flush stack to clear cement. DECOMP Continue to flush stack, clear and BD lines. DECOMP Use Schlumberger cementer unit charge pump to circulate 7.75 bbls of 15.8 ppg G cement down 1" x 10' pipe into 13-3/8" annulus. Good cement back at surface. Catch all returns to surface in "Katch-Can" w/Super Sucker. DECOMP RD cementing lines and Schlumberger unit. Clear/clean floor and "Katch-Can" in cellar. DECOMP WOC, 1000 psi compressive strength per Schlumberger. Bring equipment f/casing cutting operation to floor. Clean rig, service top drive. Clean cuttings box. CO brushes on top drive motor. Change out "O" rings on upper valve body on topdrive. Clean/paint and then paint/clean. DECOMP PU 9-5/8" multistring casing cutter BHA #39 w/ball on seat. DECOMP RIH to 20' below RKB. Cut 9-5/8" casing, 915 psi, 48 rpm, 3K tq. Casing cut through in 6 minutes. SD and POH and LD 23.75' cut off stub. DECOMP LD multistring cutter BHA #39. Clear floor. CO bails. DECOMP PU cleanout BHA #40. DECOMP PU 24 jts of 4" HWDP. DECOMP RIH to 1992' and wash down to cement at 2025'. 259 gpm, 243 psi. DECOMP Drill cement, plugs, ES Cementer,baffle collar/plug from 2025' to 2035'. Drop through. 259 gpm, 243 psi, 85 rpm, 1.5K tq. ROT 80K. CBU. Rotate and reciprocate pipe through cleanout area. No drag, no obstructions. DECOMP RIH to EZSV at 9941'. PU to 9933'. PU 198K, SO 135K, ROT 170K. DECOMP Circulate surface to surface w/35 bbl Hi-Vis sweep. 465 gpm, 2100 psi., 40 rpm, tq. 9.2K. Pump 671 bbls. Small amount of rubber, scale, and no metal noted across shakers. DECOMP POH f/ 9933' to surface. MW = 8.3 ppg. Stand back collars and LD BHA # 40. Found metal in boot baskets, bolts and pieces of metal f/9-5/8" centralizers. DECOMP RIH with 1/2 muleshoe, nine 6.25" drill collars, 8 stds 4" HWDP below RTTS stormpacker. 35K string wt below packer. Set stormpacker @ 35' below RKB in 9-5/8" csg. Printed: 11/2/2007 12:01:37 PM :' ~ ~ BP EXPLORATION Page 19 of 32 Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 7ES Date From = To Hours Task Code NPT 10/8/2007 13:00 - 14:00 1.00 WHSUR P 14:00 - 15:30 I 1.50 BOPSUI~P 15:30 - 19:30 4.00 WHSUR I P 19:30 - 21:30 I 2.OOI WHSURI P 23:30 - 00:00 I 0.501 BO SUR P 10/9/2007 00:00 - 01:00 1.OOI BOPSU~P 01:00 - 05:30 4.50 BOPSU P 05:30 - 06:00 0.50 BOPSUf~ P 06:00 - 08:00 2.00 DHB I P 08:00 - 09:00 I 1.00 I DHB I P 09:00 - 11:00 2.00 DHB P 11:00 - 11:30 0.50 DH8 P 11:30 - 12:00 0.50 DHB N MISC 12:00 - 12:30 0.50 DHB N MISC 12:30 - 13:00 0.50 DHB P 13:00 - 14:30 1.50 DHB N MISC 14:30 - 17:30 3.00 DHB P 17:30 - 21:30 4.00 DH8 P Spud Date: 6/6/1986 Start: 9/13/2007 End: Rig Release: 10/26/2007 Rig Number: Phase I Description of Operations DECOMP PJSM. Test casing below stormpacker to 3500 psi f/30 mins and chart. Good test. Rotate stormpacker on off tool. POH with on/off tool closing stormpacker valve in top of RTTS. LD on/off tool. DECOMP PJSM w/crew. ND BOP stack. DECOMP Split stack and cut 9-5/8" casing above old tubing spool. ND/LD old tbg. spool. Stand back BOP stack. Cut 13-3/8" casing below GL and remove old well head. RU Wachs cutter and cut 9-5/8" csg 5" above ground level per Cameron specifications. DECOMP Install Cameron Slip Lock Head w/CANH metal seals. Test well head slip lock flange to 3800 psi (80% of collapse of L-80 9-5/8") f/30 minutes. DECOMP NU adaptor and BOP stack. DECOMP PJSM and CO bottom pipe rams f/9-5/8" to 2-7/8" x 5" variables. DECOMP Continue CO f/9-5/8" rams to 2-7/8" x 5" variable lower rams. DECOMP BOP test. 250 psi low, 3500 psi high pressure. Test witnessed by NAD TP Biff Perry and Lowell Anderson BP WSL. AOGCC representative Bob Noble waived AOGCC representation at the test. DECOMP Rig down test equipment and blow down lines. DECOMP Pick up 1 joint of drill pipe and RTTS running tool Run in hole and sting into RTTS, check for pressure bellow RTTS, no pressure Release RTTS and pull out of hole, Lay down RTTS Rack back drill collars DECOMP Install wear ring PJSM with Schlumberger wireline Rig up Schlumberger wireline DECOMP Run in hole with 8 1/2" gauge ring junk basket and casing collar locater to 9,920' eline depth DECOMP Pull out of hole from 9,920' to 1,860', wire came out with a bird's nest DECOMP Work on Schlumberger Wire DECOMP Feed Bird Nested E-line over sheave and out to unit DECOMP Continue pull out of hole from 1,860' to Surface, 2 gallons of cement, rubber, rocks, and metal recovered in junk basket DECOMP Rig down E-line, un-spool 2,000' of E-line, cut bad line and re-head E-line DECOMP Rig up E-line and run in hole to 9,820' with gauge ring junk basket and casing collar locater Pull out of hole, junk basket empty Lay down junk basket DECOMP Pick up 9 5/8" EZSV and casing collar locater Run in hole to 9,700' Log up and correlate to 9 5!8" USIT log Set top of 9 5/8" EZSV at 9,523' Positive indication EZSV setting tool fired on tension, lost 700 Ibs of tension Set down on EZSV, did not move Normal up tension was 230 Ibs less after EZSV was set Pull out of hole from 9,523' to surface, lay down Casing collar Printed: 11/2/2007 12:01:37 PM t i BP EXPLORATION Page 20 of 32 Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description ofiOperations 10/9/2007 17:30 - 21:30 4.00 DHB P DECOMP locater and setting tool 21:30 - 22:00 0.50 DHB P DECOMP Rig down Schlumberger E-line 22:00 - 22:30 0.50 DHB P DECOMP Test 9 5/8" casing and 9 5/8" EZSV to 3,500 psi Record and Chart for 30 minutes 22:30 - 00:00 1.50 STWHIP P WEXIT Pick up 9 5/8" Milling/Whipstock BHA 10/10/2007 00:00 - 01:00 1.00 STWHIP P WEXIT Finish picking up Milling/Whipstock BHA 01:00 - 02:00 1.00 STWHIP P WEXIT Run in the hole to 2,066' 02:00 - 02:30 0.50 STWHIP P WEXIT Shallow hole test MWD tool, test good 450 GPM @ 865 psi 02;30 - 06:30 4.00 STWHIP P WEXIT Run in hole from 2,066' to 9,250' with milling/whipstock BHA 06:30 - 07:00 0.50 STWHIP P WEXIT Orient Whipstock to 45 degrees left of high side PUW=203K, SOW=128K 450 GPM @ 1,950 psi 07:00 - 07:30 0.50 STWHIP P WEXIT Run in hole to 9,509', tag EZSV Check orientation, 44 degrees left of high side 450 GPM @ 1,950 psi Set bottom anchor Pick up to 215K to confirm anchor set Slack off and shear brass bolt with 35KIbs Pick up to 9,486' for mud displacement 07:30 - 09:00 1.50 STWHIP P WEXIT Displace well from seawater to 10.8 ppg milling fluid Pump 35 bbls Hi Vis Spacer 450 GPM @ 1,200 psi Pump 716 bbls 10.8 ppg LSND 450 GPM @ 1,450 psi initial, 450 GPM 2 300 si final 09:00 - 15:00 6.00 STWHIP P WEXIT Mill window in 9 5/8" 47# casing with Baker generation 2 milling i ` ~~ assembly To of window = 9 48T Bottom of window = 9 5 4' 110 RPM @ 8-10 Kft/Ibs, 500 GPM @ 2,651 psi, WOB = 4-10K 275 Ibs of metal in returns 15:00 - 17:00 2.00 STWHIP P WEXIT Mill formation to 9,529' 110 RPM @ 9-10 KfUlbs, 500 GPM @ 2,651 psi, WOB 9-10K Appear to have good cement behind casing 17:00 - 18:30 1.50 STWHIP P WEXIT Circulate 1.5 bottoms up to clean hole for FIT Super Sweep surface to surface rotating and reciprocating pipe 60' Circulate 952 bbls of 10.8 ppg LSND mud 70 RPM @ 8Kft/Ibs, 500 GPM @ 2,760 psi 18:30 - 19:30 1.00 STWHIP P WEXIT Rig up to Perform FIT Perform FIT Hole depth 9,529' Shoe depth 9,496' Shoe TVD 7,550' MW 10.8 ppg Test Pressure 475 psi EMW = 12.0 Charted for 10 minutes Rig down head pin 19:30 - 00:00 4.50 STWHIP P WEXIT Pull out of hole from 9,529' to 120' with milling assembly Rack back HWDP Lay down drill collars 10/11/2007 00:00 - 01:00 1.00 STWHIP P WEXIT Lay down milling assembly Upper mill full gauge 01:00 - 02:00 1.00 STWHIP P WEXIT Pull wear ring Printed: 11/2/2007 12:01:37 PM • BP EXPLORATION Page 21 of 32 Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I ..Rig Name: NABORS 7ES Spud Date: 6/6/1986 Start: 9/13/2007 End: Rig Release: 10/26/2007 Rig Number: Date ~ From - To ~ Hours ~ Task Code NPT ~ Phase 110/11/2007 101:00 - 02:00 I 1.001 STWHIPI P 02:00 - 02:30 0.50 STWHIP P 02:30 - 05:30 3.00 STWHIP P 05:30 - 09:00 3.50 STWHIP P 09:00 - 10:30 1.50 STWHIP P 10:30 - 11:30 1.00 STWHIP P 11:30 - 12:00 I 0.501 STWHIPI P 12:00 - 00:00 12.00 DRILL P 110/12/2007 100:00 - 07:30 I 7.50 ~ DRILL I P 07:30 - 09:30 I 2.001 DRILL I P 09:30 - 12:00 I 2.501 DRILL I P 12:00 - 12:30 I 0.501 DRILL P 12:30 - 13:00 l 0.50 DRILL P Description of Operations I WEXIT Pick up BOP flushing device Flush BOP stack and well head Blow down lines WEXIT Install wear ring Service Topdrive WEXIT Pick up drilling BHA #42 Run in hole with HWDP out of derrick WEXIT Run in hole with 4" drill pipe out of derrick from 904' to 9,217' Shallow hole test MWD @ 1,354', 457 GPM @ 1,286 psi WEXIT Cut and Slip 117' of drilling line WEXIT Run in hole from 9,217' to 9,280' Start Mad Pass from 9,280' to 9,440', data used to tie in with correlation log 490 GPM @ 3,095 psi, no rotation Establish ECD baseline @ 9,440' WEXIT Run in hole from 9,440' to 9,509' with no pumps, end of gauged hole INT1 Wash to bottom from 9,509' to 9,529' Drill ahead from 9,529' to 10067', slides as needed 500 GPM @ 3,185 psi off, 3,470 psi on, CECD=11.1, AECD=11.48, MW=10.8 W06=8-15K, PUW=185K, SOW=123K, RWT=150K Torque 7.3K off, 10.3K on @ 80 RPMs back ream full stand at drilling rate going up, 70% coming down Midnight update ADT=6.75, AST=3.75, ART=3.0 INT1 Drill ahead from 10,067' to 10,667', Rotating ahead looking for TD Control drill with constant WOB for last 77' to pick top of Sag off ROP 475 GPM @ 3,422 psi off, 3,640 psi on, CECD=11.1, AECD=11.60, MW=10.8 W06=10-15K, PUW=193K, SOW=130K, RWT=153K Torque 8.OK off, 10.OK on @ 80 RPMs back ream full stand at drilling rate going up, 70% coming down ADT=5.35, AST=0.9, ART=4.45 INT1 Circulate to clean hole prior to wiper trip and confirm casing point pick First bottoms up did contain glauconite in sample, confirmed TD pick Total 1,460 bbls pumped for 2.5 bottoms up shakers clean CECD=11.1, AECD=11.4 Mud wt in 10.8 ppg, out 10.8 ppg Monitor well, well static INT1 Pull out of hole for wiper trip from 10,667' to 9,480' Very little drag but hole swabbing Pump out to avoid swabbing, 250 GPM @ 1,350 psi PUW=193K, SOW=130K INT1 Service Topdrive and Crown INT1 Run in the hole from 9,480' to 10,587' with out any problems Wash down as precaution from 10,587' to 10,667' Stage pumps up to 500 GPM @ 3,760 psi, 7.0 Kff/Ibs @ 80 RPM Pnntea: tvzizom tz:ots~rrot :' ~ ~ BP .EXPLORATION: Page 22 of 32 Operatiolns Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/12/2007 13:00 - 16:00 3.00 DRILL P INT1 Circulate to clean hole prior to trip out of hole Circulate bottoms up, followed by sweep surface to surface 40 bbl Hi Vis Sweep, 30% increase in cuttings with return of sweep Continued pumping till AECD 0.2 over CECD 500 GPM @ 3,640 psi, 7.0 Kft/Ibs @ 80 RPM CECD=11.1, AECD=11.3 MW in 10.8 ppg, out 10.8 ppg Monitor well, well static 16:00 - 17:30 1.50 DRILL P INT1 Pull out of hole from 10,667' to 9,408', no problems 17:30 - 19:00 1.50 DRILL P INT1 Circulate sweep surface to surface to clean casing Pump 808 bbls total 40 bbl Hi Vis sweep, no noticeable increase in cuttings when sweep returned 500 GPM @ 3,325 psi, Reciprocate pipe with no rotation MW in 10.8 ppg, out 10.8 ppg Monitor well, well static Pump dry job, blow down topdrive, disconnect blower hose 19:00 - 22:30 3.50 DRILL P INT1 Pull out of hole from 9,408' to 901', no problems pulling out 22:30 - 00:00 1.50 DRILL P INT1 Lay down BHA #42 from HWDP to 2nd Non Mag Drill Collar All stabilizers in gauge 10/13/2007 00:00 - 01:30 1.50 DRILL P INT1 Lay down rest of BHA #42 Bit 1-3 in gauge 01:30 - 05:00 3.50 BOPSU P INT1 Pull wear ring Install test plug Change upper rams from 3.5"x6" variables to 7" Test upper rams, 250 psi low, 3,500 psi high Pull test plug 05:00 - 06:00 1.00 CASE P LNR1 PJSM with Nabors casing, Baker, and crew Rig up to run 7" casing 06:00 - 09:30 3.50 CASE P LNR1 Run 32 joints of 7" 26# L-80 BTC-M liner Fill on the fly, top off every 10 joints Average torque 7,800 fUlbs Centralizer locked down on joints 1, 2, and every 3rd joint to 2 joints below window, 2 centralizers in lap, total 12 centralizers run 09:30 - 10:00 0.50 CASE P LNR1 Pick up Baker "C-2" ZXP Liner top PackerP'HMC" Liner Hanger assembly and run in hole 10:00 - 10:30 0.50 CASE P LNR1 Circulate one liner volume, 52 bbls 3 BPM @ 145 psi Rig down Casing running equipment 10:30 - 15:30 5.00 CASE P LNR1 Run 7" liner on 4" drill pipe out of derrick from 1,341' to 9,436' Fill every 10 stands Running speed, 1 min per stand 15:30 - 17:00 1.50 CASE P LNR1 Circulate one annular volume before entering open hole, 520 bbls Stage pumps up to 6 BPM @ 890 psi 17:00 - 18:00 1.00 CASE P LNR1 Run in hole from 9,436' to 10,635' with out any problems PUW=195, SOW=125 18:00 - 18:30 0.50 CASE P LNR1 Pick up Topdrive cement head, single, and wash to bottom from 10,635' to 10,667' 2 BPM @ 470 psi, PUW=190, SOW=130 18:30 - 19:30 1.00 CASE P LNR1 Circulate 3 open hole volumes. to condition mud for cement job, Printed: 11/2/2007 12:01:37 PM J BP EXPLORATION Page 23 of 32 Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date I From - To I Hours I Task I Code I NPT I Phase I Description of Operations 10/13/2007 118:30 - 19:30 I 1.001 CASE I P 19:30 - 21:30 I 2.001 CEMT I P 21:30 - 00:00 1 2.501 CEMT I P 110/14/2007 100:00 - 01:00 I 1.001 CEMT I P 06:00 - 09:30 3.50 BOPSUR P 09:30 - 11:00 1.50 DRILL P 11:00 - 15:00 4.00 DRILL P 15:00 - 16:00 I 1.001 DRILL 1 P 16:00 - 16:30 I 0.501 DRILL I P 16:30 - 17:30 1.00 CASE P LNR1 230 bbls Stage up to 5 BPM @ 975 psi PJSM with CH2MHill, Schlumberger, Baker, and crew LNR1 Fill lines with water and test to 4,500 psi bbls BPM PSI Phase 48.5 5.0 850 11.5 ppg Mud Push 59.0 5.0 280 15.8 ppg class G tail cement Kick dart out with 5 bbls water from Schlumberger, positive indication dart left head Displace with rig pumps, 10.8 ppg LSND mud no indication of liner wiper plug latch up Displace and bump plug at 2,260 strokes @ 1,500 psi Continue pressuring up to 4,000 psi to set liner hanger Slack off to 55 Klbs to check hanger set Bleed off pressure to check floats, no retums Floats held Rotate 20 turns to the right to release from C-2 running tool Pressure up to 1000 psi, pick up 6' to expose dogs, circulate 30 bbls at 11.5 BPM @ 3,040 psi Slow pump rate to 1 BPM, slack off to 55K hookload to set ZXP packer, positive indication of dog sub shear, repeat, rotate 15 RPM and repeat set down to 55K hookload two more times LNR1 Circulate out cement, reciprocate 6' to prevent pulling out of liner top, no rotation 8 BPM @ 1,670 psi Circulate 395 bbls, PH increased to 12.0, start dumping mud Dump 390 bbls of cement contaminated mud, PH still at 12 Cointinue circulating taking returns to the pits, treat mud in pits LNR1 Circulate bottoms up to condition contaminated mud, 540 bbls 13 8PM @ 2,740 psi PH in 10.8, out 10.8 MW 10.8 ppg in, 10.8 ppg out Monitor well, well static LNR1 Pull out of hole with C-2 running tool, Lay down running tool LNR1 Install test plug Change upper rams from 7" to 3.5"x6" variables Test upper rams, 250 psi low, 3,500 psi high Pull test plug Install Wear Ring PROD1 P/U and RIH with 6 1/8 BHA to 242' PROD1 RIH with DP from 242' to 9,304' MWD shallow hole test @ 1,179' Circulate at 220 gpm @ 814 psi Fill pipe every 30 stands PU WT=170K, SOW=110K PROD1 PJSM with hands. Service Top Drive Install blower hose Conduct H2S drill with hands PROD1 RIH from 9,304' to 10,355' PROD1 PJSM with hands RU to test liner Test liner to 3,500 psi, chart for 30 min Tested good Printed: 11/2/2007 12:01:37 PM • • BP EXPLORATION ' Page 24 of 32- Operations Summary. Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date I From = To Hours I Task I Code I NPT I Phase I Description of Operations 10/14/2007 16:30 - 17:30 1.00 CASE P 17:30 - 18:00 0.50 DRILL P 18:00 - 22:00 i 4.001 DRILL I P 22:00 - 00:00 I 2,001 DRILL I P 10/15/2007 100:00 - 02:30 I 2.501 DRILL I P 02:30 - 03:00 I 0.501 DRILL I P 03:00 - 05:00 2.00 I DRILL ~ P 05:00 - 06:00 I 1.001 EVAL I P 06:00 - 12:00 I 6.001 DRILL I P 12:.00 - 15:00 ~ 3.00 ~ DRILL ~ P 15:00 - 16:00 I 1.001 DRILL I P PROD1 RD and blow down lines PROD1 Continue to RIH from 10,355' to 10,617' Wash down 200 gpm @ 1,300 psi, 30rpm @ 11.3 Kft/Ibs Tag stringers @ 10,617' Tag cement @ 10,550' PROD1 Drill cement, Landing Collar, Float Collar and Float Shoe track to 10,657 RPM=30, Torque on bottom = 11.3K, off bottom = 10.4 223 gpm @ 1,450 psi PUW = 170K, SOW = 110K, RTW = 145K PROD1 Drop 1.76" ball, pump @ 2 bpm @ 430 psi Open CCV @ 2,250 psi Circulate 531 gpm @ 3065 psi; vo1=1,154 bbls PROD1 Displace to new 8.4 ppg Flo-Pro mud 550 GPM @ 1,440 psi Reciprocate 15', no rotation 80 bbls of water, 5 bpm @ 1,140 psi 40 bbls of Hi Vis Spacer, 7.5 bpm @ 1,450 psi 730 bbls of 8.4 ppg Flo-Pro mud, 13 bpm @ 1,950 psi Hi-Vis spacer to surface, 698 bbls Flo-Pro back to surface, 767 bbls Shut down and clean under shakers Drop ball to close CCV, pump down @ 2 BPM PUW=180K, SOW=140K, RTW=145K slow pump rates 2 bpm=380 psi, 3 bpm=480 psi for both pumps 30RPM @ 5.5 K ft/Ibs PROD1 Drilling out Float Shoe plus 20' new formation Slide 20' as per Directional Driller 250 gpm @ 1,170 psi PROD1 Circulate bottoms up for FIT Test, 570 bbls 30 rpm @ 4.7Kft/Ibs 250 gpm @ 1,100 psi PROD1 RU headpin to perform FIT Hole depth 10,687' Shoe depth 10,667' Shoe TVD 8,408' MW 8.4 ppg Test Pressure 700 psi EMW = 10.0 Charted for 10 minutes PROD1 Slide from 10,687' to 10,928' WOB=20K, PUW=180K, SOW=145K, RWT=150K 270 gpm @ 1466 psi on, 1340 psi off ADT=5.25 hrs, AST=5.08 hrs, ART=0.17 Jar hrs=139 PROD1 Slide from 10,928'to 11,013' PUW=185K, SOW=145K GPM=276, 1370 psi on, 1289 psi off ADT=1.92 hrs, AST=1.92 hrs MW=8.4 ppg Flo-Pro PROD1 Pump out of the hole from 11,013' to 10,640', no problems 280 gpm @ 1295 psi Printetl: 11/L"1007 12:01:37 PM BP EXPLORATION Page 25 of 32 Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/15/2007 15:00 - 16:00 1.00 DRILL P PROD1 BHA not making doglegs POOH to change degree motor from 1.68 to 2.0 16:00 - 17:00 1.00 DRILL P PROD1 Drop 1.76" ball, pump 2 bpm @ 440 psi 17:00 - 17:30 I 0.501 DRILL I P 17:30 - 20:30 3.00 DRILL P 20:30 - 21:30 1.00 DRILL P 21:30 - 00:00 I 2.501 DRILL I P 110/16/2007 100:00 - 01:30 I 1.501 DRILL I P 01:30 - 06:30 I 5.001 DRILL I P 06:30 - 08:00 I 1.50 DRILL P 08:00 - 08:30 0.50 DRILL P 08:30 - 19:30 I 11.001 DRILL I P 19:30 - 20:30 I 1.00 I DRILL I P 20:30 - 22:00 1.50 DRILL P Open CCV @ 2250 psi Stage pumps to 500 gpm @ 1325 psi, reciprocate pipe with no rotation Circulate 577 bbls, no increase in cuttings returns PROD1 Clear ice from derrick Monitor well -well static Remove blower hose, pump dry job PROD1 POH from 10,640' to 319' PROD1 Drop 1.76" ball and attempt to close CCV Pressure up to 2000 psi, stage in 500 psi increments up to 3500 psi, unable to circulate Drop ball to attempt to open; opened at 1700 psi, establish circulation Drop ball to close CCV, unable to circulate with CCV closed Drop ball to open CCV, established circulation Mobilize new CCV because we could not circulate when closed PROD1 Monitor well -well static Stand back CCV and jars Upload MWD Pull up to bit, attempt to drain mud motor, unable to rotate motor Break bit, 4-7 1/16th undergauage BHA was packed off from float to bit with cuttings and drilled cement PROD1 PU BHA #44 Change out 1.68 degree motor and pick up 2.0 degree motor Change out CCV and ball catcher as precautionary measure PROD1 RIH from 224' to 10,500' Shallow hole test MWD @ 1,185' 260 GPM @ 770 psi PROD1 Slip and cut 100' of drilling line. PROD1 RIH to 10,832'. PU Kelly and establish parameters: PUW = 175K ,SOW = 145K. Wash down to bottom at 11,013' with 250 GPM @ 1,070 psi. PROD1 Drill from 11,013'to 11,450'. Establish slow pump rates: Pump 1: 2 BPM at 420 psi , 3 BPM at 540 psi. Pump 2: 2 BPM at 420 psi , 3 BPM at 520 psi. PUW = 200K ,SOW = 138K , WOB = 20-30K. 280 GPM with 1,587 psi on and 1,468 psi off. AST = 7.71 hrs, ADT = 7.71 hrs, Jars = 148.68 hrs, Bit = 7.71 hrs. MW = 8.5 PP9• PROD1 Pump out of the hole from 11,450' to 10,641' - no problems. 280 GPM at 1,460 psi. PROD1 Circulate bottoms up at 280 GPM at 1,330 psi a total of 594 bbls. No increase in cuttings or change in mud noticed across the Shakers. Printed: 11/2/2007 12:01:37 PM :_ i , BP EXPLORATION Page 26 of 32 Operatiolns Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: ++ ++ Date (From - To I Hours 1 Task I Code ( NPT I Phase I Description of Operations 10/16/2007 20:30 - 22:00 1.50 DRILL P PROD1 22:00 - 22:30 0.50 DRILL P PROD1 10/17/2007 102:30 - 03:30 1.00 I DRILL ~ P I I PROD1 03:30 - 04:00 I 0.501 DRILL I P I I PROD1 04:00 - 05:00 1.00 DRILL P PROD1 05:00 - 05:30 0.50 DRILL P PROD1 05:30 - 06:00 0.50 DRILL P PROD1 06:00 - 06:30 0.50 DRILL P PROD1 06:30 - 07:30 1.00 EVAL P PROD1 07:30 - 11:00 3.50 DRILL P PROD1 11:00 - 12:00 1.00 DRILL P PROD1 12:00 - 00:00 12.001 DRILL I P I I PROD1 110/18/2007 100:00 - 01:30 1,501 EVAL I N I DFAL I PROD1 01:30 - 02:30 I 1.00 I DRILL I N I DFAL I PROD1 02:30 - 03:30 I 1.00 I DRILL I N I DFAL I PROD1 03:30 - 04:00 0.50 DRILL N DFAL PROD1 04:00 - 08:00 4.00 DRILL N DFAL PROD1 08:00 - 08:30 0.50 DRILL N DFAL PROD1 MW in = 8.5 ppg , MW out = 8.5 ppg. Monitor the well dead - OK ,well static. Drop 1.76" ball and pump at 2 BPM. Open the CCV at 2,180 psi. Pump dry job and spot outside of CCV. POOH from 10,641' to 6,629'. Continue POOH from 6,629' to 224'. Lay down BHA #44 components. Recovered 2 silver balls from Ball Catcher. Change out Motor and Bit, 3-3. PJSM with Schlumberger and crew PU/MU BHA #45 with New Motor, PDC Bit, Nukes (Density / Neutron) RIH to 101' - MU BHA components. Load source in ADN Continue MU BHA #45 components RIH to 1,250' Test MWD; MWD having trouble with signal 270 gpm @ 730 psi Blow down top drive RIH from 1,250' to shoe at 10,665' PUW=170K, SOW=140K Continue to RIH from 10,665' to 11,245' Kelly up and wash to bottom at 11,450' 100 gpm @ 580 psi Drill ahead from 11,450' to 11,787' 280 gpm @ 1,785 psi psi off = 1,580 psi rpm = 60 Torque on = 9K, off = 6.5K PUW = 195K, SOW = 138K, RTW = 162K, WOB = 15K AST = 4.83, ART = 1.73, ADT = 6.56 SPR taken at 11,787' MD, 9,029' TVD SPR: Pump 1 450 psi @ 2 bpm, 620 psi @ 3 bpm Pump 2 450 psi @ 2 bpm, 600 psi @ 3 bpm MW = 8.5+ PP9 Circulate and test function of MWD tools due to possible malfunction 240 gpm @ 1,258 psi 35 rpm POH from 11,807' to shoe @ 10,665' while pumping due to MWD failure 220 gpm @ 1,122 psi PUW=190K, SOW=135K Open CCV @ shoe with 2500 psi Circulate BU 450 gpm @ 1300 psi Monitor Well-Static Pump dry job Blow down top drive POH from 10,665 to 254' Close CCV with 2000 psi PJSM with all hands on LD of BHA and unloading nuclear Printed: 11/2/2007 12:01:37 PM :' ~ ~ BP EXPLORATION Page 27 of 32 Operatiolns Summary. Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date I From - To I Hours I Task I Code I NPT Phase I Description of Operations 10/18/2007 08:00 - 08:30 0.50 DRILL N DFAL PROD1 08:30 - 09:00 0.50 DRILL N DFAL PROD1 09:00 - 10:00 1.00 DRILL N DFAL PROD1 10:00 - 10:30 0.50 DRILL N DFAL PROD1 10:30 - 12:30 2.00 DRILL N DFAL PROD1 12:30 - 13:00 I 0.501 EVAL I N I DFAL I PROD1 13:00 - 16:00 I 3.001 DRILL I N I DFAL I PROD1 16:00 - 16:30 I 0.501 DRILL I N I DFAL I PROD1 16:30 - 00:00 I 7.501 DRILL I P I I PROD1 110/19/2007 100:00 - 01:30 I 1.501 DRILL I P I I PROD1 01:30 - 07:00 I 5.501 DRILL I N I DPRB I PROD1 07:00 - 08:30 1.50 DRILL N DPRB PROD1 08:30 - 23:30 15.00 DRILL P PROD1 23:30 - 00:00 I 0.501 DRILL I P 10/20/2007 100:00 - 04:30 I 4.501 DRILL I P PROD1 PROD1 source Stand back Drill Collars and unload source Continue to LD BHA from 101' to surface Clean and clear floor to prepare for next BHA PJSM with hands PU, MU and RIH with 6 1/8" BHA to 101' Load nuclear device Continue to RIH to 210 RIH to 1,210' and shallow test MWD 250 gpm @ 700 psi Test good Blow down top drive Continue to RIH to 10,576' Fill pipe every 30 stands Install blower hose Continue to RIH and wash down to bottom at 11,807 MD 100 gpm @ 600 psi PUW=175K, SOW=135K Drill ahead from 11,807 to 12,450' 280 gpm @ 1865 psi on, 1630 psi off RPM=80 @ Torque on=9K, off=6.5K PUW=195K, SOW=136K, ROT=160K, WOB=10K AST=2.72, ART=2.78, ADT=5.5 SPR: Pump 1 2bpm=580 psi, 3bpm=700 psi Pump 2 2bpm=575 psi, 3 spm=700 psi MW=8.6 PP9 Drill from 12,450' to 12,510' 285 gpm @ 1785 psi on, 1630 psi off RPM=80 @ 11 K torque on, 6.5K torque off PUW=197K, SOW=137K, ROT=160K, WOB=12K Encountered 500 psi pressure drop Drop in turbine RPM's at same flow rate Check surface equipment, pressure test surface equipment Pull out of hole looking for washout Found washout on bottom joint of Stand 105, washout at base of box where the hard band ends and elevators latch around joint Pumped out of hole with 115 gpm @ 750 psi RIH from 10,160' to 12,510' Drill ahead from 12,510' to 13,692' 280 gpm @ 2120 psi on, 1848 psi off RPM=80 @ torque 9K on, 7K off PUW=205K, SOW=125K, ROT=160K, WOB=10K AST=2.6 hrs, ART=3.66 hrs, ADT=6.26 hrs SPR: Pump 1 2bpm=670 psi, 3bpm=805 psi Pump 2 2bpm=650 psi, 3bpm=790 psi Monitor well -static well Backream from 13,692' to 13,538' 280 gpm @ 1780 psi 80 rpm @ 7K torque Backream from TD of 13,692'to 11,460' 290 gpm @ 1,700 psi 70 rpm @ 6.3K torque Printed: 11/2/2007 12:01:37 PM BP EXPLORATION Page 28 0# 32 Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/20/2007 00:00 - 04:30 4.50 DRILL P PROD1 PUW=195K, SOW=135K, ROT=155K 04:30 - 12:00 I 7.501 DRILL I P 12:00 - 13:15 I 1.251 DRILL I P 13:15-13:45 I( 0.50 DRILL I+P 13:45 - 14:30 I 0.751 DRILL I P 14:30 - 15:30 1.00 DRILL P 15:30 - 16:30 1.00 DRILL P 16:30 - 17:30 I 1.001 DRILL I P 17:30 - 18:00 I 0.501 DRILL I P 18:00 - 22:00 4.00 DRILL P 22:00 - 00:00 2.00 DRILL P 10/21/2007 100:00 - 02:00 I 2.001 CASE I P 02:00 - 05:00 I 3.001 CASE I P 05:00 - 06:30 I 1.501 CASE I P 06:30 - 07:30 I 1.001 CASE I P 07:30 - 13:15 5.75 CASE P 13:15 - 14:15 1.00 CASE P MAD Pass: Pull out rate of 720 ft/hr through horizontal; 1 sample per foot Pull out rate of 300 ft/hr through curves; 1 sample per 1/2 foot PROD1 Circulate from 11,460' to 10,950' Continue to MAD Pass per GEO 290 gpm @ 1,589 psi PUW=185K, SOW=140K Pull out rate of 180 fUhr PROD1 Continue to MAD Pass from 10,950' to 10,750' 280 gpm @ 1,490 psi PROD1 POH to shoe at 10,665' Circulate 3 liner volumes up, 90 bbls 40 rpm @ 4K torque 118 SPM, 285 gpm @ 1,427 psi PROD1 Drop ball and open CCV Circulate and reciprocate from 10,665' to 10,572' 550 gpm @ 1,674 psi PROD1 POH from 10,572' to bit depth of 9,580' Position CCV at TOL @ 9,342' PROD1 Reciprocate and circulate through CCV ports at TOL Rotate 10 min 10 rpm @ 4K torque 550 gpm @ 1,471 psi PROD1 Reciprocate and circulate Hi-Vis sweep at TOL Rotate 10 min while the sweep exited the CCV ports 10 rpm @ 4K torque 553 gpm @ 1,504 psi 10% cuttings increase with sweep at surface MW in = 8.6 ppg , MW out = 8.6 ppg PROD1 Monitor Well -Well Static Pump dryjob Blow down top drive PROD1 POH from 9,580' to 255' PROD1 Cycle CCV closed Blow down top drive PJSM on handling radioactive source LD BHA RUNPRD PU 4-1/2", 12.6#, L-80, IBT-M Liner Shoe Track BakerLok Joints #1-3 (2 connections) Test Floats -good RUNPRD RIH with 4-1/2", 12.6#, L-80, IBT-M Liner from 128' to 3,200' Average MU torque=3,800 ft/Ibs PUW=63K, SOW=60K RUNPRD MU liner hanger Wait for Pal Pak to set up RD all liner equipment RU 4" handling equipment RUNPRD RIH with one stand of 4" DP Circulate 1.5 liner volumes 155 gpm @ 150 psi RUNPRD RIH with liner from 3,286' to 10,667', filling every 10 stands RUNPRD Circulate at shoe, staging from 2 bpm to 6 bpm @ 620 psi Printed: 11(2/2007 12:01:37 PM • • BP EXPLORATION- Page 29 of 32 .Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date I From - To I Hours I Task Code I NPT I .Phase Description of Operations 10/21/2007 114:15 - 16:45 2.50 CASE P I I RUNPRD RIH with 4.5" liner on 4" DP from 10,667' to 13,670' 16:45 - 17:45 1.00 CASE P 17:45 - 18:30 I 0.751 CEMT I P 18:30 - 18:50 I 0.331 CEMT I P 18:50 - 19:15 0.421 CEMT I P 19:15 - 19:20 0.08 CEMT P 19:20 - 20:00 I 0.671 CEMT I P 20:00 - 20:30 0.50 CEMT I P 20:30 - 22:30 2.00 CEMT P 22:30 - 00:00 I 1.501 CEMT I P 10/22/2007 ~ 04:30 - 05:30 I 1.001 CEMT ~ P 05:30 - 08:30 3.00 CEMT P 08:30 - 09:00 0.50 CEMT P RUNPRD MU cement head Circulate for 1.5 hrs Stage pumps to 5 bpm at 940 psi PUW=190K, SOW=130K PJSM with crew, Schlumberger, Baker Tag bottom @ 13,692' Attempt to reciprocate Pull up at 25K over, no pipe movement Stop Reciprocation RUNPRD Batch cement Circulate without reciprocating 5 bpm @ 930 psi RUNPRD Pump 2 bbls water, none down drill pipe Pressure test cement lines to 4,500 psi Pump 40 bbls 10.5 ppg mud push, 4 bpm @ 860 psi 12% retums (full) RUNPRD Pump 82 bbls of 15.8 ppg cement, 5 bpm @ 1,250 psi 25% returns (full) RUNPRD Pump 5 bbls water to clean cement head, none down drill pipe Switch to rig pumps Drop dart; positive indication that dart left cement head RUNPRD Displace with 50 bbls pert pill; 732 strokes to empty pert pill pit Follow with 100 bbls 8.7 ppg Flo-Pro 5 bpm @ 470 psi 1,178 strokes to catch cement Slow pump rate to 3 bpm at 1,700 strokes to latch dart 1,784 strokes to latch dart (positive indication of latch at 2,124 psi) 2,597 strokes to bump plug 3 bpm @ 2,700 psi Cement in place @ 19:54 hrs Slack off weight to 50K Pressure up to 4,300 psi to test hanger Bleed pressure and check floats RUNPRD Shear ZXP packer with 30K Set packer with 50K, repeat with rotation RUNPRD PU and reciprocate/circulate 550 gpm @ 1,900 psi, no losses 40 bbls 10.5 ppg Mud Push and 5 bbls cement returns to surface RUNPRD Displace to 8.5 ppg seawater 543 gpm @ 2535 psi Reciprocate PUW=165K, SOW=135K RUNPRD POH from 10,512' to 2,961' Rack back 4" drill pipe in derrick RUNPRD PJSM with crew for slip and cut Slip and cut 149' of drilling line Service top drive RUNPRD POH from 2,961' to surface LD 90 joints to pipe shed RUNPRD LD liner. running tool Clean and clear rig floor Printed: 11/2/2007 12:01:37 PM Legal Well Name: G-19 Common Well Name: G-19 Event Name: REENTER+COMPLETE Start: 9/13/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Spud Date: 6!6/1986 End: Date From - To Hours Task Code NPT Phase Description of Operations 10/22/2007 09:00 - 10:00 1.00 CEMT P RUNPRD Rig up and test wellbore to 3500 psi Hold for 30 min 10:00 - 12:00 2.00 CLEAN P CLEAN Prepare floor and load pipe shed for scraper run 12:00 - 14:30 2.50 CLEAN P CLEAN Make up 7" and 9 5/8" scraper and BHA 14:30 - 18:30 4.00 CLEAN P CLEAN RIH with 4" drill pipe to 8,657' 9 5/8" scraper to approximately 7,500' 18:30 - 21:30 3.00 CLEAN P CLEAN Wash 9 5/8" casing with scraper from 7,500' to top of 7" liner 21:30 - 22:15 I 0.751 CLEAN P 22:15 - 23:15 I 1.001 CLEAN I P 23:15 - 23:30 0.25 CLEAN P 23:30 - 00:00 0.50 CLEAN P 10/23/2007 00:00 - 03:30 3.50 CLEAN P 03:30 - 06:00 2.50 CLEAN P 06:00 - 12:00 6.00 BOPSU P at approximately 9,342' 448 gpm @ 1528 psi Observed cement returns across shaker CLEAN Circulate with 2 7/8" x 4' Mule Shoe into 4.5" liner and 9 5/8" casing scraper @ 9,340' 538 gpm @ 2608 psi Pumped 288 bbls of 8.5 ppg seawater CLEAN Pump Hi-Vis sweep 50 bbls of 10.7 ppg, 300 viscosity When sweep reached top of 4.5" liner, pull up and rotate/reciprocate/circulate: Mule Shoe from 10,480' to 10,444' 9 5/8" scraper from 9,323' to 9,287' 7" scraper from 10,446' to 10,410' 540 gpm @ 2495 psi 30 rpm @ 4K torque PUW=175K, SOW=135K, ROT=155K Pumped 915 bbls with cement returns across shakers Sweep recovered, no problems MW in=8.5 ppg, MW out=8.5 ppg CLEAN Monitor well -Well static Blow down top drive CLEAN POH from 10,480' to 9,300' Rack back 4" drill pipe to derrick CLEAN POH from 9,300' to 1,185' Rack back 4" drill pipe into derrick CLEAN LD BHA CLEAN Test BOP with 4" and 4.5" test joints, low 250 psi, high 3,500 psi State of Alaska's right to witness was waived by Chuck Scheve, Test witnessed by WSL Joey LeBlanc and NTP Larry Wurdman Test #1 4" Test Joint Top Rams, Choke valves 1, 2, 3, & 16, HCR Kill, Dart Valve, Lower IBOP Test #2 4" Test Joint Bottom Rams, Choke Valves 4, 5, 6, Manual Kill, and Manual IBOP Test #3 Choke Valves 7, 8, 9, and TIW Test #4 Super Choke, Manual Choke B Test#5 Choke Valves 10, 11, & 15 Test #6 Choke Valve 14 Test #8 Manual Choke Test #9 Annular Test #10 Blind Rams, Choke Valves 12 & 13 Test #11 4.5" Test Joint Top Pipe Rams Test #12 4.5" Test Joint Top Pipe Rams Koomey Test BP EXPLORATION Page 30 of 32 Operations Summary Report Printea: ttizizoo~ tz:otsi Nnn .~ BP EXPLORATION Page 31 of 32 Operations Summary Report Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 Rig Name: NABORS 7ES Rig Number: Date From - To I Hours ~ .Task ~ Code ~ NPT Phase Description of Operations 10/23/2007 106:00 - 12:00 I 6.001 BOPSUaP 12:00 - 13:00 I 1.00 I PERFO~ P 13:00 - 19:45 6.75 PERFO P 19:45 - 00:00 4.25 PERFO P 10/24/2007 00:00 - 01:30 1.50 PERFO P 01:30 - 02:00 I 0.50 ~ PERFO~ P 02:00 - 02:30 0.50 PERFO P 02:30 - 03:45 I 1.251 PERFOBI P 04:15 - 00:30 1 6.25 PERFO~ P 10:30 - 11:30 1.00 PERFO P 11:30 - 14:30 3.00 PERFO P 14:30 - 16:30 2.00 PERFO P 16:30 - 22:00 5.50 PERFO P 22:00 - 22:30 I 0.50 ~ PERFO~ P 22:30 - 23:00 0.50 BOPSU P 23:00 - 00:00 I 1.00 110/25/2007 00:00-01:30 1.50 01:30 - 17:00 15.50 17:00 - 21:00 I 4.00 21:00 - 22:30 I 1.501 RU 22:30 - 23:30 I 1.00 I RU 23:30 - 00:00 0.50 RU 10/26/2007 00:00 - 03:30 3.50 RU CLEAN Bleed down from 3,000 psi to 1,500 psi Pressure up 200 psi - 15 sec Pressure up to 3,000 psi - 1 min 40 sec Average 5 bottles nitrogen 1,850 psi OTHCMP PJSM with Schlumberger and Crew Rig up to run Perf Guns OTHCMP Pickup 48 - 2 7/8" PJ2906 6 SPF guns, 13 Blanks, 2 firing heads, Hydraulic Disconnect, and 70 joints of 2 7/8" PAC drill pipe to 3209'. OTHCMP RIH w/4" stands from derrick f/3209' to 11459'. OTHCMP RIH f/11459' and tag up on landing collar at 13602'. PU 180K, SO 130K. PU 52' and spaceout guns w/bottom shot at 13550' and toa shot at 12030'. OTHCMP PJSM w/Schlumberger, WSL, all hands, NAD tourpusher. Perform dry practice run w/pumps per Schlumberger. OTHCMP Perform E-Fire firing sequence per Schlumberger. E-fire did not accept commands. Wait on hydraulic delay backup firing heads. Saw both HDF heads fire on shot detector and felt at . floor. Fluid dropped 7-8 ft. OTHCMP POH to top of 4.5" liner at 10496', standing back 32 drill pipe stands. MW = 8.5 ppg seawater. Well took 7 bbls of fluid. OTHCMP Monitor well. Static. BD top drive. OTHCMP Pump dry job. POH laying down drill pipe 1 x 1 f/10496'. to 3500'. MW = 8.5 ppg seawater. Total losses = 23 bbls. while pullin pipe. OTHCMP RIH w/stands f/derrick to 7000'. OTHCMP POH w/drill pipe f/7000' to top of PAC at 3212'. OTHCMP POH laying down 54 jts of 2-7/8" PAC drill pipe. OTHCMP PJSM. LD 842' of pert guns, 16 jts. PAC drill pipe, 210' of pert guns. All shots Fred. OTHCMP RD 2-7/8" PAC drill pipe and pert gun handling equipment. Clear and clean floor. RUNCMP Pull wear bushing and make tubing hanger dummy run. RKB to tubing lock down screws verified at 27.25'. RUNCMP RU to run 4.5" 12.60# 13Cr Vam Top completion w/torque turn and compensator. RUNCMP Continue RU/test torque turn equipment. Load pipeshed. RUNCMP Run 4.5" 12.6# 13Cr Vam Top completion f/surface to 10492'. Baker-Lok all threads in tail pipe from packer to muleshoe. Torque average = 4460 ft/Ibs. PU 135K, SO 99K. RUNCMP Wash down to 10516' and tag up. PU several times to 10490' and rotate 1/4 turn and wash back to 10516' to verify tag up on bottom of extension sleeve. No indications of circulating into liner top above 10516'. Tag up at again at 10516' and pump at 182 gpm, 224 psi. PU slowly w/same parameters and at 10504' saw drop of 25 psi to 199 psi. RUNCMP Space out and land tubing hanger -27.25' RKB w/WLEG at 10511'. Run in lock down screws to gland nuts w/200 fUlbs torque. Re-torque all lock down screws to 400 ft/Ibs torque. SFAL RUNCMP Thaw hard lines and frozen gooseneck running into cuttings box. RUNCMP RU to reverse circulate. RUNCMP Continue reverse circulating 200 bbls untreated seawater, Printed: 11/2/2007 12:01:37 PM :~ ~ ~ BP EXPLORATION Page 32 of 32 Operations Summalry Report ,Legal Well Name: G-19 Common Well Name: G-19 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 9/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/26/2007 ,Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/26/2007 00:00 - 03:30 3.50 RUNCO RUNCMP followed by 400 bbls corrosion inhibited seawater. 126 gpm 35 psi. 03:30 - 05:00 1.50 RUNCO RUNCMP RU Hot Oil Svc and reverse circulate w/137 bbls 60 deg F diesel freeze protect fluid down annulus. Shut down. 05:00 - 06:00 1.00 RUNCO RUNCMP Shut in annulus. RU Hot Oil Svc to tubing and bullhead 33 bbls of 60 deg F diesel freeze protect fluid down tubing. 06:00 - 10:00 4.00 RUNCO RUNCMP Drop ball and rod to RHC plug. Set packer and test tubing at 3500 si w/chart for 30 minutes. Bleed tubing pressure o 0 psi. Pressure annulus to 500 psi and test w/chart f/30 minutes. Bleed off all pressure. Leave ball an ro in place. 10:00 - 12:00 2.00 BOPSU P RUNCMP MU and set TWC and test from top to 1000 psi. Install VR plugs. 12:00 - 13:30 1.50 BOPSU P RUNCMP PJSM ND and stand back BOP stack. 13:30 - 16:00 2.50 WHSUR P RUNCMP NU tree. Test andaptor, tree and pack-off to 5000 psi ~ w/diesel. Install VR plugs. 16:00 - 18:00 2.00 WHSUR P RUNCMP Install valves and gauges on tree. Secure well, release rig f/G-19B at 18:00. Printed: 11/2/2007 12:01:37 PM by G-19B Su Client: BP Exploration Alaskz Field: Prudhoe Bay Unit - WOA Structure 1 Slot: GPAD / G-19 Well: G-19 Borehole: G-19B UWIIAPgt: 500292159901 Survey Name 1 Date: G196 /October 21, 2007 Tort 1 AHD 1 DDI 1 ERD ratio: 313.073° / 8442.71 ft / 6.603 / 0.93! Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Fee Location LatlLong: N 70.31898429, W 148.7252101: Location Grid NIE YIX: N 5967883.000 ftUS, E 657248.000 ftU: Grid Convergence Angle: +1.20034195° Grid Scale Factor: 0.9999280 Reuort schlumberger ,. survey 1 DLS computation Method: Minimum curvature I Lubinslc Vertical Section Azimuth: 55.000° Vertical Section Origin: N 0.000 ft, E 0.000 fl 7VD Reference Datum: Rotary Table ND Reference Elevation: 67.11 ft relative to MSL Base Flange Level Elevation: 37.18 ft relative to MSL Magnetic Declination: 23.551 ° Total Field Strength: 57658.187 nT Magnetic Dip: 80.924° Declination Date: October 15, 2007 Magnetic Declination Model: BGGM 2007 North Reference: TNe North • Total Corc Mag North •> True North: +23.551 ° Comments Measured Inclination Azimuth Sub•Sea TYD ND Vertical Along Hole Closure NS EW DLS Northing Easting Latkude Longitude Depth Section Departure ft d d ft k ft ft ft ft ft de 100 ft ftUS ftUS x\10 AA ~]AOA~I~1!\ \A/ A10 ~~fL~\AI\A ~° Klt V.UU V.UU V.UU -~r.l l U.VU U.UU U.VU U.VU V.VV V.VV V.VV J.7Vl VUJ.VV VJl LYV.VV 1\ IV.J IpAV'fG.7 YY 110.l LJL IV IJ WRP 28.68 0.00 0.00 -38.43 28.68 0.00 0.00 0.00 0.00 0.00 0.00 5967883.00 657248.00 N 70.31898429 W 148.72521013 GYD CT CMS 100.00 0.26 198.04 32.89 100.00 -0.13 0.16 0.16 -0.15 -0.05 0.36 5967882.85 657247.95 N 70.31898387 W 148.72521053 200.00 0.37 197.17 132.89 200.00 -0.57 0.71 0.71 -0.68 -0.22 0.11 5967882.32 657247.80 N 70.31898244 W 148.72521187 300.00 0.51 195.91 232.89 300.00 -1.17 1.48 1.48 -1.41 -0.43 0.14 5967881.58 657247.60 N 70.31898043 W 148.72521364 400.00 0.54 194.68 332.88 399.99 -1.87 2.40 2.40 -2.30 -0.67 0.03 5967880.69 657247.37 N 70.31887801 W 148.72521559 500.00 0.57 185.55 432.88 499.99 -2.55 3.36 3.36 -3.25 -0.84 0.09 5967879.73 657247.23 N 70.31897541 W 148.72521695 600.00 0.48 186.63 532.87 599.98 -3.16 4.28 4.27 -4.16 -0.94 0.09 5967878.82 657247.15 N 70.31897292 W 148.72521773 700.00 0.45 176.21 632.87 699.98 -3.64 5.09 5.06 -4.97 -0.96 0.09 5967878.01 657247.14 N 70.31897072 W 148.72521791 800.00 0.61 168.48 732.86 799.97 -4.05 6.01 5.94 -5.88 -0.83 0.17 5967877.10 657247.29 N 70.31896822 W 148.72521684 900.00 0.29 157.38 832.86 899.97 -4.32 6.79 6.67 -6.64 -0.62 0.33 5967876.35 657247.51 N 70.31896616 W 148.72521519 1000.00 0.32 160.10 932.86 999.97 -4.45 7.33 7.15 -7.13 -0.43 0.03 5967875.86 657247.72 N 70.31896480 W 148.72521 1100.00 0.34 162.81 1032.86 1099.97 -4.61 7.90 7.68 -7.68 -0.25 0.03 5967875.32 657247.91 N 70.31896331 W 148.72521 1200.00 0.34 161.95 1132.86 1199.97 -4.79 8.50 8.25 -8.24 -0.07 0.01 5967874.76 657248.10 N 70.31896177 W 148.72521069 1300.00 0.33 161.10 1232.85 1299.96 -4.95 9.08 8.80 -8.80 0.12 0.01 5967874.21 657248.30 N 70.31896025 W 148.72520919 1400.00 0.16 145.71 1332.85 1399.96 -5.03 9.51 9.19 -9.19 0.29 0.18 5967873.82 657248.48 N 70.31895919 W 148.72520780 1500.00 0.23 174.06 1432.85 1499.96 -5.13 9.84 9.51 -9.50 0.39 0.12 5967873.51 657248.59 N 70.31895833 W 14B.72520699 1600.00 0.27 255.47 1532.85 1599.96 -5.45 10.21 9.76 -9.76 0.18 0.33 5967873.25 657248.38 N 70.31895762 W 148.72520867 1700.00 0.90 237.95 1632.85 1699.96 -6.46 11.22 10.26 -10.24 -0.71 0.65 5967872.75 657247.50 N 70.31895632 W 148.72521592 1800.00 2.15 222.71 1732.81 1799.92 -9.07 13.87 12.32 -12.03 -2.65 1.30 5967870.92 657245.60 N 70.31885142 W 148.72523163 1900.00 4.13 213.90 1832.66 1899.77 -14.27 19.34 17.44 -16.40 -5.93 2.03 5967866.48 657242.4! N 70.31893949 W 148.72525822 2000.00 8.45 236.14 1932.04 1999.15 -24.98 30.17 27.37 -23.49 -14.05 4.88 5967859.23 657234.45 N 70.31892013 W 148.72532400 2100.00 12.47 241.09 2030.36 2097.47 -43.07 48.31 44.19 -32.80 -29.61 4.12 5967849.59 657219.09 N 70.31889467 W 148.72545011 2200.00 16.15 240.86 2127.24 2194.35 -67.65 73.02 68.04 -44.80 -51.21 3.68 5967837.14 657197.74 N 70.31886190 W 148.72562523 SurveyEditor Ver SP 2.1 Bld( doc40x_100) G-19\G-19\G-1961G-19B Generated 11/2/2007 3:58 PM Page 1 of 6 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude ~ + Depth Section Departure ft d d k ft k ft k k k d 1100 k ftUS kUS LSUU.UU ZV.U6 Z4U.Z3 ZZZZ.Zr ZZO`J.3b -`JiSAr -IU4.Uy aa.or -ov.va -ra.[o o.ai ayoroti.c~ oar ~r i.uc rv ra.oioocu~c vv wo.rcaoyywa 2400.00 24.40 241.05 2314.82 2381.93 -136.21 141.92 136.21 -78.62 -111.23 4.35 5967802.08 657138.44 N 70.31876952 W 148.72611173 2500.00 29.56 242.56 2403.91 2471.02 -181.23 187.27 181.30 -99.99 -151.23 5.20 5967779.87 657098.91 N 70.31871111 W 148.72643589 2600.00 33.71 243.65 2489.03 2556.14 -233.14 239.70 233.46 -123.69 -198.01 4.19 5967755.20 657052.64 N 70.31864637 W 148.72681505 2700.00 35.96 244.19 257i.f0 2638.2f -289.57 296.82 290.34 -148.79 -249.31 2.27 5967729.03 657001.88 N 70.31857779 W 148.72723089 2800.00 37.10 244.88 2651.46 2718.57 -348.27 356.34 349.64 -174.38 -303.05 1.21 5967702.32 656948.69 N 70.31850788 W 148.72766648 2900.00 39.01 242.66 2730.20 2797.31 -409.18 417.98 411.17 -201.64 -358.33 2.35 5967673.91 656894.00 N 70.31843340 W 148.72811447 3000.00 41.27 242.13 2806.64 2873.75 -473.11 482.44 475.60 -231.52 -415.45 2.29 5967642.85 656837.53 N 70.31835177 W 148.72857743 3100.00 42.89 243.69 2880.86 2947.97 -539.48 549.45 542.57 -262.02 -475.11 1.93 5967611.10 656778.52 N 70.31826843 W 148.72906102 3200.00 44.42 243.09 2953.21 3020.32 -607.77 618.48 611.55 -292.94 -536.83 1.59 5967578.90 656717.47 N 70.31818394 W 148.72956122 3300.00 44.74 242.88 3024.44 3091.55 -677.28 688.67 681.72 -324.83 -599.36 0.35 5967545.71 656655.62 N 70.31809682 W 148.73006803 3400.00 44.46 242.84 3095.64 3162.75 -746.83 758.89 751.92 -356.86 -661.84 0.28 5967512.38 656593.83 N 70.31800931 W 148.7305 3500.00 44.22 243.41 3167.16 3234.27 -816.02 828.78 821.79 -388.45 -724.18 0.47 5967479.49 656532.17 N 70.31792298 W 148.731079 3600.00 44.29 243.10 3238.79 3305.90 -885.09 898.56 891.55 -419.86 -786.50 0.23 5967446.79 656470.52 N 70.31783716 W 148.73158479 3700.00 44.27 243.28 3310.38 3377.49 -954.19 968.38 967.35 -451.35 -848.81 0.13 5967414.01 656408.89 N 70.31775112 W 148.73208981 3800.00 44.58 243.69 3381.80 3448.91 -1023.42 1038.38 1031.33 -482.59 -911.45 0.42 5967381.46 656346.93 N 70.31766573 W 148.73259743 3900.00 44.61 243.60 3453.01 3520.12 -1092.83 1108.59 1101.51 -513.76 -974.36 0.07 5967348.98 656284.69 N 70.31758056 W 148.73310730 4000.00 44.60 244.04 3524.20 3591.31 -1162.22 1178.81 1171.71 -544.74 -1037.38 0.31 5967316.69 656222.34 N 70.31749590 W 148.73361802 4100.00 44.54 243.18 3595.44 3662.55 -1231.61 1248.98 1241.87 -575.94 -1100.24 0.61 5967284.19 656160.14 N 70.31741066 W 148.73412749 4200.00 44.47 243.51 3666.76 3733.87 -1300.96 1319.08 1311.95 -607.38 -1162.89 0.24 5967251.44 656098.17 N 70.31732473 W 148.73463520 4300.00 44.20 243.41 3738.29 3805.40 -1370.09 1388.97 1381.83 -638.61 -1225.41 0.28 5967218.91 656036.33 N 70.31723939 W 148.73514188 4400.00 44.24 243.75 3809.95 3877.06 -1439.05 1458.71 1451.56 -669.64 -1287.87 0.24 5967186.58 655974.54 N 70.31715459 W 148.73564805 4500.00 43.92 243.52 3881.79 3948.90 -1507.83 1528.27 1521.11 -700.53 -1350.20 0.36 5967154.39 655912.87 N 70.31707016 W 148.73615318 4600.00 43.46 243.73 3954.10 4021.21 -1576.12 1597.35 1590.18 -731.22 -1412.08 0.48 5967122.42 655851.65 N 70.31698630 W 148.73665469 4700.00 43.46 243.74 4026.69 4093.80 -1644.11 1666.13 1658.95 -761.66 -1473.77 0.01 5967090.69 655790.62 N 70.31690311 W 148.73715457 4800.00 43.05 244.19 4099.52 4166.63 -1711.79 1734.66 1727.46 -791.74 -1535.34 0.51 5967059.34 655729.70 N 70.31682090 W 148.73765353 4900.00 42.91 244.21 4172.68 4239.79 -1779.09 1802.83 1795.61 -821.41 -1596.71 0.14 5967028.39 655668.96 N 70.31673981 W 148.73815093 5000.00 42.61 244.35 4246.10 4313.21 -1846.10 1870.73 1863.48 -850.87 -1657.88 0.31 5966997.65 655608.43 N 70.31665928 W 148.73864661 5100.00 42.65 244.76 4319.67 4386.78 -1912.88 1938.45 1931.17 -879.97 -1719.04 0.28 5966967.28 655547.90 N 70.31657975 W 148.73914221 5200.00 42.64 244.72 4393.23 4460.34 -1979.65 2006.20 1998.89 -908.88 -1780.30 0.03 5966937.10 655487.26 N 70.31650073 W 148.7396 5300.00 42.52 245.30 4466.86 4533.97 -2046.28 2073.86 2066.50 -937.46 -1841.63 0.41 5966907.24 655426.55 N 70.31642260 W 148.7401 5400.00 42.76 245.48 4540.42 4607.53 -2112.91 2141.60 2134.19 -965.67 -1903.22 0.27 5966877.75 655365.57 N 70.31634550 W 148.74063473 5500.00 43.02 245.31 4613.69 4680.80 -2179.85 2209.66 2202.19 -994.01 -1965.10 0.28 5966848.12 655304.30 N 70.31626804 W 148.74113617 5600.00 43.69 246.59 4686.40 4753.51 -2247.25 2278.31 2270.76 -1021.98 -2027.79 1.11 5966818.84 655242.21 N 70.31619157 W 148.74164419 5700.00 43.79 246.67 4758.65 4825.76 -2314.97 2347.45 2339.79 -1049.41 -2091.25 0.11 5966790.10 655179.34 N 70.3f611660 W 148.74215849 5800.00 43.50 246.76 4831.01 4898.12 -2382.55 2416.46 2408.69 -1076.69 -2154.65 0.30 5966761.49 655116.53 N 70.31604202 W 148.74267222 5900.00 43.87 246.90 4903.33 4970.44 -2450.15 2485.53 2477.64 -1103.86 -2218.15 0.38 5966733.00 655053.62 N 70.31596772 W 148.74318677 6000.00 44.20 246.78 4975.22 5042.33 -2518.18 2555.04 2547.04 -1131.20 -2282.06 0.34 5966704.33 654990.31 N 70.31589299 W 148.74370463 6100.00 44.91 247.85 5046.48 5113.59 -2586.73 2625.20 2617.05 -1158.26 -2346.79 1.03 5966675.93 654926.16 N 70.31581902 W 148.74422916 6200.00 44.98 247.82 5117.26 5184.37 -2655.60 2695.84 2687.52 -1184.91 -2412.21 0.07 5966647.91 654861.32 N 70.31574616 W 148.74475930 6300.00 45.18 248.53 5187.87 5254.98 -2724.55 2766.65 2758.13 -1211.23 -2477.94 0.54 5966620.22 654796.15 N 70.31587418 W 148.74529195 SurveyEditor Ver SP 2.1 Bld( doc40x_100) G-19\G-19\G-196\G-198 Generated 11/2/2007 3:58 PM Page 2 of 6 .; Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude ~ Depth Section Departure ft de de ft ft ft k ft ft ft de 100 ft ftUS ftUS 6400.00 45.65 249.34 5258.07 5325.18 -2793.67 2837.87 2829.09 -1236.83 -2544.41 0.74 5966593.24 654730.25 N 70.31560419 W 148.74583049 6500.00 45.64 250.14 5327.98 5395.09 -2862.82 2909.37 2900.25 -1261.59 -2611.48 0.57 5966567.08 654663.71 N 70.31553649 W 148.74637403 6600.00 45.82 250.75 5397.78 5464.89 -2931.84 2980.98 2971.44 -1285.55 -2678.96 0.47 5966541.71 654596.76 N 70.31547095 W 148.74692079 6700.00 45.76 251.92 5467.51 5534.62 -3000.62 3052.66 3042.60 -1308.49 -2746.86 0.84 5966517.35 654529.35 N 70.31540822 W 148.74747105 6800.00 45.85 250.38 5537.22 5604.33 -3069.48 3124.35 3113.83 -1331.66 -2814.71 1.11 5966492.77 654462.01 N 70.31534486 W 148.74802082 6900.00 45.65 250.42 5607.00 5674.11 -3138.54 3195.98 3185.11 -1355.69 -2882.19 0.20 5966467.34 654395.05 N 70.31527915 W 148.74856761 7000.00 45.43 250.19 5677.04 5744.15 -3207.39 3267.36 3256.16 -1379.74 -2949.39 0.27 5966441.88 654328.38 N 70.31521337 W 148.74911212 7100.00 45.27 250.48 5747.32 5814.43 -3275.99 3338.50 3326.99 -1403.68 -3016.38 0.26 5966416.55 654261.91 N 70.31514789 W 148.74965494 7200.00 45.30 250.46 5817.68 5884.79 -3344.48 3409.56 3397.74 -1427.44 -3083.36 0.03 5966391.40 654195.45 N 70.31508292 W 148.75019761 7300.00 44.99 250.62 5888.27 5955.32 -3412.78 3480.45 3468.33 -1451.05 -3150.19 0.33 5966366.39 654129.12 N 70.31501832 W 148.75073920 7400.00 44.81 250.51 5959.04 6026.15 -3480.78 3551.04 3538.62 -1474.54 -3216.76 0.20 5966341.51 654063.07 N 70.31495408 W 148.7512 7500.00 44.39 250.49 6030.25 6097.36 -3548.44 3621.25 3608.56 -1497.98 -3282.95 0.42 5966316.69 653997.39 7 N 70.31488997 W 148.75181 7600.00 44.04 250.68 6101.92 6169.03 -3615.61 3690.99 3678.02 -1521.16 -3348.72 0.37 5966292.14 653932.13 N 70.31482656 W 148.752347 7700.00 43.62 250.71 6174.06 6241.17 -3682.28 3760.24 3747.00 -1544.05 -3414.08 0.42 5966267.88 653867.27 N 70.31476394 W 148.75287734 7800.00 43.31 251.19 6246.64 6313.75 -3748.42 3829.03 3815.50 -1566.51 -3479.10 0.45 5966244.08 653802.74 N 70.31470251 W 148.75340419 7900.00 42.75 251.17 6319.74 6386.85 -3813.96 3897.27 3883.44 -1588.52 -3543.69 0.56 5966220.72 653738.63 N 70.31464229 W 148.75392753 8000.00 42.39 251.67 6393.38 6460.49 -3878.85 3964.91 3950.78 -1610.08 -3607.81 0.49 5966197.82 653674.97 N 70.31458332 W 148.75444708 8100.00 42.09 251.74 6467.42 6534.53 -3943.23 4032.14 4017.67 -1631.18 -3671.64 0.30 5966175.39 653611.61 N 70.31452558 W 148.75496423 8200.00 43.13 251.72 6541.01 6608.12 -4008.07 4099.84 4085.04 -1652.40 -3735.92 1.04 5966152.83 653547.79 N 70.31446752 W 148.75548511 8300.00 44.11 251.52 6613.41 6680.52 -4074.17 4168.82 4153.72 -1674.16 -3801.39 0.99 5966129.71 653482.79 N 70.31440800 W 148.75601555 8400.00 44.92 251.65 6684.71 6751.82 -4141.36 4238.93 4223.52 -1696.30 -3867.91 0.82 5966106.17 653416.76 N 70.31434740 W 148.75655451 8500.00 45.41 251.41 6755.22 6822.33 -4209.35 4309.85 4294.15 -1718.77 -3935.17 0.52 5966082.31 653349.99 N 70.31428593 W 148.75709947 8600.00 45.70 251.58 6825.24 6892.35 -4277.80 4381.24 4365.27 -1741.43 -4002.87 0.31 5966058.24 653282.78 N 70.31422393 W 148.75764800 8700.00 45.10 251.72 6895.46 6962.57 -4346.02 4452.44 4436.18 -1763.84 -4070.45 0.61 5966034.41 653215.69 N 70.31416259 W 148.75819556 8800.00 44.25 251.68 6966.57 7033.68 -4413.36 4522.75 4506.21 -1785.92 -4137.20 0.85 5966010.94 653149.42 N 70.31410218 W 148.75873640 8900.00 43.65 251.52 7038.56 7105.67 -4479.87 4592.15 4575.36 -1807.83 -4203.06 0.61 5965987.66 653084.04 N 70.31404223 W 148.75926996 9000.00 42.98 251.52 7111.32 7178.43 -4545.64 4660.75 4643.73 -1829.57 -4268.12 0.67 5965964.56 653019.45 N 70.31398273 W 148.75979710 9100.00 42.40 251.40 7184.82 7251.93 -4610.66 4728.56 4711.31 -1851.13 -4332.41 0.59 5965941.66 652955.64 N 70.31392373 W 148.76031793 9200.00 41.53 251.75 7259.18 7326.29 -4674.75 4795.42 4777.95 -1872.27 -4395.84 0.90 5965919.20 652892.66 N 70.31386589 W 148.7608 9300.00 41.32 251.60 7334.16 7401.27 -4738.13 4861.59 4843.89 -1893.07 -4458.65 0.23 5965897.09 652830.31 3 N 70.31380896 W 148.761 Tie-In Stuvey 9400.00 40.93 251.74 7409.49 7476.60 -4801.14 4927.36 4909.45 -1913.75 -4521.09 0.40 5965875.11 652768.33 N 70.31375235 W 148.76184661 Top Window (Blind) 9487.00 40.58 251.45 7475.39 7542.50 -4855.57 4984.15 4966.07 -1931.68 -4574.98 0.46 5965856.05 652714.83 N 70.31370327 W 148.76228322 Base Window (Blind)\ 9504.00 42.07 249.33 7488.16 7555.27 -4866.39 4995.38 4977.27 -1935.45 -4585.55 12.03 5965852.06 652704.34 N 70.31369295 W 148.76236887 Inc+Trend 9535.89 39.50 247.00 7512.30 7579.41 -4886.67 5016.20 4998.09 -1943.19 -4604.88 9.37 5965843.92 652685.17 N 70.31367179 W 148.76252552 Inc+Trend 9630.20 42.42 241.06 7583.54 7650.65 -4947.68 5077.99 5059.76 -1970.32 -4660.36 5.16 5965815.64 652630.27 N 70.31359758 W 148.76297497 MWD+IFR+MS 9684.76 46.38 236.22 7622.53 7689.64 -4985.74 5116.14 5097.48 -1990.22 -4692.91 9.55 5965795.07 652598.16 N 70.31354317 W 148.76323856 9726.73 46.58 235.55 7651.43 7718.54 -5016.17 5146.58 5127.35 -2007.29 -4718.10 1.25 5965777.47 652573.33 N 70.31349649 W 148.76344265 9822.67 43.07 234.06 7719.47 7786.58 -5083.79 5214.20 5193.48 -2046.24 -4773.37 3.82 5965737.38 652518.89 N 70.31338999 W 148.76389034 9918.82 42.31 235.08 7790.14 7857.25 -5148.98 5279.39 5257.20 -2084.03 -4826.49 1.07 5965698.48 652466.58 N 70.31328664 W 148.76432056 10015.13 41.06 237.25 7862.07 7929.18 -5213.01 5343.43 5320.19 -2119.70 -4879.68 1.98 5965661.71 652414.16 N 70.31318910 W 148.76475136 SurveyEditor Ver SP 2.1 Bld( doc40x_100) G-19\G-19\G-19B\G-198 Generated 11/2/2007 3:58 PM Page 3 of 6 ~~ '; Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure k de de k ft ft ft ft ft ft d 1100 ft kUS ftUS 7UlUy.y3 4L7/ L3/.4L /`J33.4`J 6UVU.OV -DLID.L-J O4VD./I O3o ~./3 -G ~A3.3A W.73G.~o V.~r :J.7VJVGVAI VJLJVL.YV IY /V.J IJVJI V~ YY IYV.I VJ 1lV1J 10205.56 41.04 237.05 8005.55 8072.66 -5338.12 5468.64 5443.81 -2187.37 -4985.02 0.29 5965591.85 652310.26 N 70.31300404 W 148.76560465 10301.61 41.19 237.09 8077.91 8145.02 -5401.24 5531.80 5506.16 -2221.71 -5038.04 0.16 5965556.42 652257.98 N 70.31291014 W 148.76603403 10397..39 44.90 238.06 8147.90 8215.01 -5466.53 5597.17 5570.79 -2256.74 -5093.22 3.93 5965520.24 652203.55 N 70.31281434 W 148.76648099 10492.71 44.50 238.11 8215.65 8282.76 -5533.48 5664.21 5637.19 -2292.18 -5150.13 0.42 5965483.61 652147.39 N 70.31271740 W 148.76694196 10524.08 44.09 238.02 8238.10 8305.21 -5555.36 5686.12 5658.89 -2303.77 -5168.72 1.32 5965471.64 652129.05 N 70.31268571 W 148.76709254 10604.32 43.62 238.36 8295.96 8363.07 -5610.87 5741.71 5713.98 -2333.07 -5215.97 0.66 5965441.35 652082.43 N 70.31260556 W 148.76747519 10686.01 39.89 240.91 8356.90 8424.01 -5665.07 5796.10 5768.03 -2360.60 -5262.87 5.02 5965412.85 652036.13 N 70.31253027 W 148.76785506 10717.46 35.49 242.41 8381.78 8448.89 -5684.17 5815.32 5787.20 -2369.74 -5279.78 14.29 5965403.36 652019.41 N 70.31250527 W 148.76799205 10749.84 30.77 243.28 8408.89 8476.00 -5701.69 5833.01 5804.87 -2377.82 -5295.52 14.65 5965394.95 652003.85 N 70.31248316 W 148.76811953 10781.02 25.60 243.10 8436.36 8503.47 -5716.27 5847.74 5819.58 -2384.46 -5308.66 16.58 5965388.04 651990.85 N 70.31246500 W 148.76822596 10813.62 20.68 243.90 8466.33 8533.44 -5728.93 5860.54 5832.37 -2390.18 -5320.11 15.12 5965382.08 651979.51 N 70.31244935 W 148.76831 10845.85 15.90 246.70 8496.92 8564.03 -5738.89 5870.65 5842.48 -2394.43 -5329.28 15.08 5965377.64 651970.43 N 70.31243771 W 148.7683 10876.34 11.43 253.37 8526.54 8593.65 -5745.85 5877.85 5849.66 -2396.95 -5336.02 15.52 5965374.98 651963.76 N 70.31243082 W 148.768447 10908.50 8.86 277.60 8558.21 8625.32 -5750.70 5883.43 5854.92 -2397.54 -5341.53 15.32 5965374.28 651958.26 N 70.31242921 W 148.76849227 10942.53 9.92 300.40 8591.80 8658.91 -5753.85 5888.91 5858.85 -2395.71 -5346.66 11.28 5965376.00 651953.09 N 70.31243420 W 148.76853383 10972.30 11.29 318.95 8621.07 8688.18 -5755.22 5894.35 5861.19 -2392.21 -5350.78 12.29 5965379.41 651948.89 N 70.31244375 W 148.76856729 11004.72 13.19 335.17 8652.76 8719.87 -5754.90 5901.17 5862.17 -2386.46 -5354.42 12.06 5965385.08 651945.14 N 70.31245946 W 148.76859681 11037.02 18.05 346.94 8683.86 8750.97 -5752.38 5909.84 5861.28 -2378.23 -5357.10 17.89 5965393.25 651942.28 N 70.31248192 W 148.76861857 11068.84 23.99 356.33 8713.56 8780.67 -5747.17 5921.23 5858.11 -2366.96 -5358.63 21.40 5965404.49 651940.52 N 70.31251271 W 148.76863104 11100.32 29.46 6.25 8741.68 8808.79 -5738.73 5935.35 5852.03 -2352.86 -5358.20 22.37 5965418.59 651940.66 N 70.31255123 W 148.76862760 11132.02 33.99 14.66 8768.65 8835.76 -5726.82 5951.99 5842.65 -2336.52 -5355.11 19.94 5965434.99 651943.41 N 70.31259587 W 148.76860262 11162.73 37.99 23.16 8793.51 8860.62 -5712.23 5970.02 5830.45 -2319.51 -5349.21 20.81 5965452.12 651948.95 N 70.31264236 W 148.76855495 11194.95 42.43 31.61 8818.13 8885.24 -5693.81 5990.79 5814.33 -2301.11 -5339.60 21.81 5965470.71 651958.17 N 70.31269263 W 148.76847719 11227.77 45.68 39.95 8841.73 8908.84 -5672.29 6013.59 5794.78 -2282.66 -5326.24 20.24 5965489.44 651971.13 N 70.31274306 W 148.76836907 11258.48 45.59 43.22 8863.21 8930.32 -5650.94 6035.54 5774.93 -2266.25 -5311.68 7.62 5965506.15 651985.35 N 70.31278794 W 148.76825112 11288.91 48.73 49.11 8883.91 8951.02 -5628.91 6057.84 5754.07 -2250.83 -5295.58 17.54 5965521.90 652001.12 N 70.31283009 W 148.76812075 11322.35 55.59 51.54 8904.41 8971.52 -5602.60 6084.23 5728.79 -2234.00 -5275.25 21.30 5965539.15 652021.09 N 70.31287611 W 148.76795613 11354.35 62.37 53.09 8920.89 8988.00 -5575.23 6111.64 5702.28 -2217.26 -5253.55 21.59 5965556.35 652042.43 N 70.31292189 W 148.76778041 11385.40 68.73 54.83 8933.74 9000.85 -5546.98 6139.89 5674.78 -2200.65 -5230.70 21.11 5965573.43 652064.93 N 70.31296731 W 148.767595 11399.45 71.61 55.31 8938.50 9005.61 -5533.76 6153.10 5661.86 -2193.08 -5219.87 20.75 5965581.22 652075.60 N 70.31298801 W 148.7675 11442.31 79.13 59.68 8949.33 9016.44 -5492.38 6194.54 5621.02 -2170.84 -5184.91 20.12 5965604.19 652110.08 N 70.31304883 W 148.76722449 11470.68 81.36 57.46 8954.13 9021.24 -5464.47 6222.50 5593.39 -2156.26 -5161.06 11.01 5965619.26 652133.62 N 70.31308871 W 148.76703128 11503.21 83.30 55.28 8958.48 9025.59 -5432.25 6254.74 5561.75 -2138.41 -5134.22 8.93 5965637.67 652160.08 N 70.31313753 W 148.76681389 11536.50 85.57 54.48 8961.70 9028.81 -5399.12 6287.87 5529.41 -2119.35 -5107.12 7.23 5965657.30 652186.77 N 70.31318965 W 148.76659441 11565.24 88.49 59.24 8963.19 9030.30 -5370.44 6316.57 5501.21 -2103.66 -5083.10 19.41 5965673.48 652210.46 N 70.31323254 W 148.76639982 11598.06 89.93 58.67 8963.65 9030.76 -5337.70 6349.38 5468.76 -2086.74 -5054.98 4.72 5965690.99 652238.21 N 70.31327883 W 148.76617209 11630.68 90.61 58.95 8963.49 9030.60 -5305.16 6382.00 5436.52 -2069.85 -5027.08 2.25 5965708.46 652265.75 N 70.31332503 W 148.76594606 11662.00 90.72 58.06 8963.13 9030.24 -5273.90 6413.32 5405.60 -2053.49 -5000.37 2.86 5965725.37 652292.11 N 70.31336978 W 148.76572976 11694.50 90.41 59.87 8962.81 9029.92 -5241.48 6445.82 5373.48 -2036.73 -4972.53 5.65 5965742.71 652319.59 N 70.31341560 W 148.76550421 11727.33 90.31 58.79 8962.60 9029.71 -5208.74 6478.65 5341.01 -2019.99 -4944.29 3.30 5965760.04 652347.47 N 70.31346140 W 148.76527549 SurveyEditor Ver SP 2.1 Bld( doc4Ox_1OO) G-19\G-19\G-19B\G-196 Generated 11/2/2007 3:58 PM Page 4 of 6 i ~ ~ _ Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longkude ~ ~ Depth Section Departure ft d d k k k ft k k k de 100 ft ftUS ftUS 1175U.Z3 yU.74 5y."Ltf tSyGZ.51 `JUZ`J.OZ -51tf5.`JU 65U1.55 5370.325 -ZUUC.ZU -4yZ4.00 [.[0 5;105//Y.[J o5[3oo.a5 rv /us~a~-yso[ VV 140./0011043 11786.43 90.41 57.00 8962.34 9029.45 -5149.76 6537.75 5282.70 -1989.10 -4893.91 6.34 5965791.97 652397.19 N 70.31354587 W 148.76486740 11818.25 90.51 56.71 8962.08 9029.19 -5117.96 6569.57 5251.47 -1971.70 -4867.27 0.96 5965809.92 652423.46 N 70.31359345 W 148.76465161 11852.17 91.61 57.39 8961.46 9028.57 -5084.06 6603.48 5218.17 -1953.25 -4838.81 3.81 5965828.96 652451.52 N 70.31364389 W 148.76442109 11885.96 92.23 57.58 8960.32 9027.43 -5050.32 6637.25 5184.97 -1935.10 -4810.34 1.92 5965847.70 652479.61 N 70.31369353 W 148.76419042 11920.36 91.99 58.00 8959.06 9026.17 -5015.99 6671.63 5151.15 -1916.78 -4781.25 1.41 5965866.63 652508.30 N 70.31374364 W 148.76395482 11951.26 91.95 58.22 8958.00 9025.11 -4985.15 6702.51 5120.75 -1900.46 -4755.03 0.72 5965883.49 652534.17 N 70.31378826 W 148.76374243 11982.48 91.03 58.44 8957.18 9024.29 -4954.00 6733.72 5090.01 -1884.08 -4728.47 3.03 5965900.43 652560.39 N 70.31383307 W 148.76352727 12015.45 90.20 56.41 8956.83 9023.94 -4921.06 6766.69 5057.63 -1866.33 -4700.69 6.65 5965918.75 652587.79 N 70.31388160 W 148.76330224 12045.95 90.27 56.81 8956.70 9023.81 -4890.57 6797.19 5027.77 -1849.54 -4675.22 1.33 5965936.07 652612.89 N 70.31392750 W 148.76309597 12074.59 89.93 56.05 8956.65 9023.76 -4861.94 6825.83 4999.76 -1833.71 -4651.36 2.91 5965952.40 652636.42 N 70.31397081 W 148.76290267 12107.76 89.38 55.16 8956.85 9023.96 -4828.77 6859.00 4967.43 -1814.97 -4623.99 3.15 5965971.70 652663.39 N 70.31402204 W 148.7626 12141.99 88.59 54.32 8957.46 9024.57 -4794.55 6893.22 4934.21 -1795.21 -4596.04 3.37 5965992.04 652690.91 8 N 70.31407606 W 148.7624 12172.43 89.21 54.32 8958.04 9025.15 -4764.12 6923.65 4904.73 -1777.46 -4571.32 2.04 5966010.30 652715.25 N 70.31412460 W 148.762254 12205.72 90.31 53.90 8958.18 9025.29 -4730.83 6956.94 4872.53 -1757.95 -4544.35 3.54 5966030.38 652741.80 N 70.31417796 W 148.76203592 12238.74 90.61 53.90 8957.92 9025.03 -4697.82 6989.96 4840.63 -1738.49 -4517.67 0.91 5966050.39 652768.07 N 70.31423115 W 148.76181982 12270.29 90.68 53.65 8957.56 9024.67 -4666.28 7021.51 4810.19 -1719.85 -4492.22 0.82 5966069.56 652793.12 N 70.31428212 W 148.76161367 12303.28 90.31 52.24 8957.28 9024.39 -4633.31 7054.50 4778.51 -1699.97 -4465.90 4.42 5966089.98 652819.02 N 70.31433647 W 148.76140043 12333.98 90.17 51.71 8957.15 9024.26 -4602.66 7085.20 4749.19 -1681.06 -4441.72 1.79 5966109.39 652842.80 N 70.31438818 W 148.76120454 12364.16 90.03 51.08 8957.10 9024.21 -4572.54 7115.38 4720.47 -1662.23 -4418.13 2.14 5966128.71 652865.98 N 70.31443966 W 148.76101351 12397.01 89.86 51.16 8957.13 9024.24 -4539.76 7148.23 4689.29 -1641.61 -4392.56 0.57 5966149.86 652891.12 N 70.31449603 W 148.76080638 12429.05 89.41 50.69 8957.33 9024.44 -4507.80 7180.27 4658.93 -1621.41 -4367.69 2.03 5966170.57 652915.56 N 70.31455124 W 148.76060491 12461.65 89.76 50.99 8957.57 9024.68 -4475.29 7212.87 4628.08 -1600.83 -4342.41 1.41 5966191.68 652940.40 N 70.31460752 W 148.76040017 12495.17 90.27 50.60 8957.56 9024.67 -4441.86 7246.39 4596.40 -1579.64 -4316.43 1.92 5966213.41 652965.92 N 70.31466545 W 148.76018978 12526.38 91.20 51.28 8957.16 9024.27 -4410.73 7277.59 4566.89 -1559.98 -4292.20 3.69 5966233.57 652989.73 N 70.31471921 W 148.75999350 12558.07 91.68 50.71 8956.36 9023.47 -4379.13 7309.27 4536.96 -1540.04 -4267.58 2.35 5966254.02 653013.93 N 70.31477372 W 148.75979409 12590.30 91.13 49.58 8955.57 9022.68 -4347.03 7341.49 4506.70 -1519.39 -4242.85 3.90 5966275.18 653038.22 N 70.31483016 W 148.75959374 12620.25 91.09 49.27 8954.99 9022.10 -4317.22 7371.44 4478.73 -1499.91 -4220.11 1.04 5966295.13 653060.55 N 70.31488341 W 148.75940951 12652.43 90.82 48.55 8954.46 9021.57 -4285.23 7403.61 4448.82 -1478.77 -4195.86 2.39 5966316.78 653084.35 N 70.31494122 W 148.75921309 12687.15 89.52 48.85 8954.35 9021.46 -4250.72 7438.33 4416.62 -1455.85 -4169.77 3.84 5966340.23 653109.95 N 70.31500386 W 148.75900 12715.42 89.83 48.38 8954.51 9021.62 -4222.63 7466.60 4390.45 -1437.16 -4148.56 1.99 5966359.36 653130.76 N 70.31505495 W 148.75883 12746.75 90.10 48.47 8954.53 9021.64 -4191.50 7497.93 4361.51 -1416.37 -4125.13 0.91 5966380.64 653153.75 N 70.31511178 W 148.75864017 12778.40 90.31 48.35 8954.42 9021.53 -4160.06 7529.58 4332.32 -1395.36 -4101.45 0.76 5966402.14 653176.98 N 70.31516921 W 148.75844843 12809.02 90.92 48.84 8954.09 9021.20 -4129.63 7560.20 4304.07 -1375.11 -4078.49 2.56 5966422.86 653199.51 N 70.31522457 W 148.75826241 12841.10 90.82 48.31 8953.60 9020.71 -4097.76 7592.28 4274.52 -1353.89 -4054.44 1.68 5966444.58 653223.11 N 70.31528258 W 148.75806759 12874.43 89.96 48.86 8953.38 9020.49 -4064.64 7625.61 4243.84 -1331.84 -4029.44 3.06 5966467.15 653247.64 N 70.31534285 W 148.75786513 12907.33 89.83 48.45 8953.44 9020.55 -4031.94 7658.51 4213.59 -1310.11 -4004.74 1.31 5966489.39 653271.87 N 70.31540226 W 148.75766505 12938.67 90.89 49.31 8953.24 9020.35 -4000.78 7689.84 4184.76 -1289.50 -3981.14 4.36 5966510.49 653295.04 N 70.31545860 W 148.75747382 12971.80 92.47 50.75 8952.27 9019.38 -3967.79 7722.96 4154.08 -1268.23 -3955.76 6.45 5966532.28 653319.97 N 70.31551675 W 148.75726824 13002.16 92.74 50.56 8950.89 9018.00 -3937.55 7753.29 4125.89 -1249.00 -3932.30 1.09 5966552.00 653343.01 N 70.31556931 W 148.75707825 13033.60 92.26 50.56 8949.52 9016.63 -3906.23 7784.70 4096.75 -1229.04 -3908.05 1.53 5966572.45 653366.85 N 70.31562386 W 148.75688174 SurveyEditor Ver SP 2.1 Bld( doc40x_100) G-19\G-19\G-196\G-196 Generated 11/2/2007 3:58 PM Page 5 of 6 r-. r Comments Measured Inclination Azimuth Sub-SeaTVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude ~ ~ Longitude Depth Section Departure ft de de ft ft ft k ft ft ft d It00ft ftUS ftUS 1suUa.tss yU./`J bL.54 ts`J4ts.bb aul~.r/ -:Sts/4.Utl /tS7U.yL 4UOt).t)y -7LUy.VI -3tsaL.bL r.oo oaooaas.vi 13096.80 89.79 52.19 8948.50 9015.61 -3843.14 7847.88 4037.67 -1190.10 -3858.29 3.42 5966612.43 13128.34 90.03 52.96 8948.55 9015.66 -3811.63 7879.42 4008.10 -1170.93 -3833.24 2.56 5966632.12 13161.37 90.13 52.82 8948.51 9015.62 -3776.62 7912.45 3977.10 -1151.01 -3806.90 0.52 5966652.59 13193.60 90.41 52.52 8948.36 9015.47 -3746.42 7944.68 3946.93 -1131.46 -3781.27 1.27 5966672.66 13224.99 91.30 53.60 8947.89 9015.00 -3715.05 7976.07 3917.50 -1112.60 -3756.19 4.46 5966692.05 13257.60 94.53 53.80 8946.23 9013.34 -3682.50 8008.63 3886.88 -1093.32 -3729.95 9.92 5966711.87 13287.89 94.66 53.60 8943.80 9010.91 -3652.31 8038.83 3858.52 -1075.45 -3705.61 0.79 5966730.25 13319.10 93.63 52.67 8941.55 9008.66 -3621.20 8069.95 3829.41 -1056.77 -3680.71 4.44 5966749.44 13352.28 91.68 52.72 8940.01 9007.12 -3588.08 8103.10 3798.55 -1036.69 -3654.35 5.88 5966770.07 13384.54 90.31 53.94 8939.45 9006.56 -3555.84 8135.35 3768.42 -1017.42 -3628.48 5.69 5966789.87 13416.71 90.48 53.69 8939.23 9006.34 -3523.68 8167.52 3738.31 -998.43 -3602.51 0.94 5966809.40 13449.49 90.89 53.91 8938.84 9005.95 -3490.91 8200.30 3707.67 -979.07 -3576.06 1.42 5966829.31 13481.81 91.23 54.66 8938.24 9005.35 -3458.60 8232.61 3677.40 -960.21 -3549.82 2.55 5966848.72 13514.06 91.51 54.05 8937.47 9004.58 -3426.36 8264.85 3647.22 -941.42 -3523.62 2.08 5966868.05 13547.10 91.44 53.19 8936.62 9003.73 -3393.34 8297.88 3616.49 -921.83 -3497.03 2.61 5966888.19 13579.23 91.88 54.76 8935.69 9002.80 -3361.23 8330.00 3586.58 -902.94 -3471.06 5.07 5966907.62 13607.50 91.68 53.57 8934.81 9001.92 -3332.98 8358.26 3560.26 -886.40 -3448.15 4.27 5966924.63 Last Survey 13635.17 91.99 53.69 8933.92 9001.03 -3305.33 8385.91 3534.63 -870.00 -3425.88 1.20 5966941.49 TD (Projected) 13692.00 91.99 53.69 8931.95 8999.06 -3248.55 8442.71 3482.05 -836.37 -3380.12 0.00 5966976.08 Survey Type: Definitive Survey NOTES: GYD CT CMS - (Gyrodata -cont. casing mis - Gyrodata multishot surveys with continuous toll (RGS-CT) in casing. OD 13-3/e" or less. INC+TREND - (Inclinometer + known azi trend - Incltnatlon only surveys in near-vertical hole-where formation dip and experience enables direction of drfft to be predicted. Replaces ex-BP "Inclinometer (azimuth in known quadrant)" model. MWD + IFR + MS - (In-field referenced MWD with mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Les~al Descriution: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 1534 FSL 3004 FEL S12 T11N R13E UM 5967883.00 657246.00 BHL : 697 FSL 1104 FEL S11 T11N R13E U M 5966976.08 653886.39 oo~ayi.oo rv rus~aorooL vv ~~-o.r~oorroo 653415.77 N 70.31573032 W 148.75647868 653440.41 N 70.31578272 W 148.75627577 653466.32 N 70.31583720 W 148.75606238 653491.53 N 70.31589063 W 148.75585476 653516.22 N 70.31594219 W 148.75565154 653542.05 N 70.31599489 W 148.75543893 653566.00 N 70.31604376 W 148.75524180 653590.51 N 70.31609481 W 148.75504004 653616.44 N 70.31614972 W 148.75482647 653641.90 N 70.31620237 W 148.75461688 653667.46 N 70.31625429 W 148.75440 653693.50 N 70.31630721 W 148.75419 653719.33 N 70.31635878 W 148.75397968 653745.13 N 70.31641015 W 148.75376741 653771.30 N 70.31646370 W 148.75355197 653796.87 N 70.31651533 W 148.75334154 653819.43 N 70.31656056 W 148.75315595 653841.34 N 70.31660539 W 148.75297553 653886.39 N 70.31669732 W 148.75260473 i SurveyEditor Ver SP 2.1 Bld( doc40x_100) G-19\G-19\G-196\G-19B Generated 11/2!2007 3:58 PM Page 6 of 6 = 4" CAMERON WELLHEAD= MCEVOY ACTUATOR = AXELSON KB. ELEV = 87.11' BF. ELEV = 37.18' KOP = 10,604' Max Angle = 94.5 Datum MD = Datum TV D = 8800 13-3/8" CSG, 72#, I L-80, D = 12.347" G-19B ` DRLG DRAFT 2,028' HES ES Cementer / 9-5/8", 47#, L-80, HydrN 563 2,090' Top of Cement 9 5/8" x 13 3/8" 2,189' 4-1/2" X LANDING NO', D = 3.813" 2,705 13-3/8", 72#, L-80, ID=12.347" 9,342 9-5/8" X 7" Baker HMC liner hanger, ZXP Inr top packer 9-5/8" Window a a87'-9 Soo' EZSV w/ Wropstodc ontop 9509' QSV CIBP 9943' Top Of Cement 10007' QSV Squeeze PKR 10163' Tubing cut 10142' &5/8"x4-1/2"TIWPKR 10183' Set QSV 10210' TOP OF 2-7/8" LNR 10247' TOP OF 7" LNR 10340' 4-1/2" TBG, 12.8#, L-80, X3.958" 10291' ID = 8.681" 10S9S' 7" LNR, 26#, L-80, ID = 8.278" 11253' 2-7/8" LNR, 8.18#, L-80, X2.441" .12758' Minumum ID = 3.725" @ 10498' 4-1/2" XN NIPPLE 10,403 41/2"'X' Landing N~ple, ID=3.813" 10433' 7" X 4-1/2" Baker S-3 PKR 10,467 4 112" 'X' Landing Nipple, ID = 3.813" 10,498 4 112" 'XN' Landing N~ple, ID = 3.725" 10,510 ~ ~ 4 1/2",12.8#, 13G-80, VamTop 10,493 H7 X 4-1/2" Baker HMC liner hanger, ZXP Inr top I I I packer w / TBS 10667' 7" , 26#, L-80, BTGM liner PERFORATION SUMMARY RFC LOG: ???? ON MM/DD/YY ANGLE AT TOP PERF: 80° @ 12030' Note: Refer to Production DB for historical perf data SIZE SPF IME~/AL OPNISQZ DATE 2-7/8" 6 12030 - 12200 O 10/24/07 2-7/8" 6 12750 - 12930 O 10/24/07 2-7/8" 8 12980 - 13220 O 10/24107 2-7/8" 6 13300 - 13550 O 10/24/07 13602' Baker Land'mg collar 13690' 4-1/2" , 12.8#, L-80, IBT-M LNR DATE REV BY COMU6+lTS DATE REV BY COMMENTS 08129/86 ORIGINAL COMPLETION 11/04/99 CTD SIDETRACK COMPL 10/26/07 N7E3 SIDETRACK (G"19B) 10/31/07 /TLH CORRECTIONS PRUDHOE BAY llNff WELL: Cr196 PERMff No: 2071240 API No: 50-029-21599-02 SEC 12, T11N, R73E, 1534' FSL & 3004' FEL BP Exploration (Abaka) G '~ ~/ i ~. Client .................... 6P Alaska Field ..................... Prudhoe-Bay well.. .................. G-196 API number ................ 50-029-21599-02 Engineer .................. Wayne Hart COUNTY :................... 7-ES STATE :.................... Alaska ----- Survey calculation m Method for positions.....: Method for DLS............ ----- Depth reference ---- Permanent datum........... Depth reference........... BF above permanent.......: KB above permanent.......: DF above permanent.......: ethods------------ Minimum curvature Mason & Taylor Mean Sea Level Drill Pipe Tally 37.18 ft N/A 67.11 ft G-19B_Final_Surveys.txt SCHLUMBERGER survey report 21-Oct-2007 16:51:31 ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance spud date... ............ 9-oct-07 Last survey date.......... 20-Oct-07 Total accepted surveys...: 207 MD of first survey........ 0.00 ft MD of last survey........: 13692.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2007 Magnetic date. ...... ... 09-oct-2007 Magnetic field strength..: 57657.91 GAMA Magnetic dec (+E/W-).....: 23.56 degrees Magnetic dip .............. 80.92 degrees ----- vertical section origin---------------- Latitude (+N/S-).......... 0.00 ft Departure (+E/w-)......... 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).......... 0.00 ft Departure (+E/w-)......... 0.00 ft Azimuth from vsect origin to target: 248.57 degrees [(c)2007 IDEAL ID12_OC_l3]0 survey Reference G ............... H . ............. Dip ............. of G............ of H. .......... of Dip.......... ~~~ ~~~ ~ 7 At~ek~~~~+ ~ grrima~i~tt Anch~rag~ Criteria --------- 1002.68 meal 57658.00 GAMA 80.92 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Ma~netic dec (+E/W-).....: 23.55 degrees Grid convergence (+E/w-).: 0.00 degrees Total az corr (+E/w-).... 23.55 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .. 2=Sag Corrected Inclination M=schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction Page 1 ORIGI~~^,L SCHLUMBERGER Survey Report G-196_Final_Surveys.txt 21-Oct-2007 16:51:31 Page 2 of 8 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- vertical ------- ------- Displ --------- --------- Displ ------- ------- Total -------- -------- At ----- ----- DLS ----- ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/5- +E/w- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (ft) --------- (ft) ------- (deg) -------- 100f) ----- type ----- (deg) ------ --- 1 -------- 0.00 ------ 0.00 ------- 0.00 ------ 0.00 -------- 0.00 -------- 0.00 ------- 0.00 --------- 0.00 ------- 0.00 -------- 0.00 ----- 0.00 ----- TIP ------ None 2 28.68 0.00 0.00 28.68 28.68 0.00 0.00 0.00 0.00 0.00 0.00 BP_UNKNOwN 3 100.00 0.26 198.04 71.32 100.00 0.10 -0.15 -0.05 0.16 198.04 0.36 BP_UNKNOWN 4 200.00 0.37 197.17 100.00 200.00 0.45 -0.68 -0.22 0.71 197.65 0.11 BP_GYD CT CMS 5 300.00 0.51 195.91 100.00 300.00 0.92 -1.41 -0.43 1.48 197.02 0.14 BP_GYD CT CMS 6 400.00 0.54 194.68 100.00 399.99 1.47 -2.30 -0.67 2.40 196.35 0.03 BP_GYD CT CMS 7 500.00 0.57 185.55 100.00 499.99 1.97 -3.25 -0.84 3.36 194.53 0.09 BP_GYD CT CMS 8 600.00 0.48 186.63 100.00 599.98 2.39 -4.16 -0.94 4.27 192.71 0.09 BP_GYD CT CM5 9 700.00 0.45 176.21 100.00 699.98 2.71 -4.97 -0.96 5.06 190.95 0.09 BP_GYD CT CM5 10 800.00 0.61 168.48 100.00 799.97 2.92 -5.88 -0.83 5.94 188.02 0.17 BP_GYD CT CM5 11 900.00 0.29 157.38 100.00 899.97 3.01 -6.64 -0.62 6.67 185.38 0.33 BP_GYD CT CMS 12 1000.00 0.32 160.10 100.00 999.97 3.01 -7.13 -0.43 7.15 183.47 0.03 BP_GYD CT CM5 13 1100.00 0.34 162.81 100.00 1099.97 3.04 -7.68 -0.25 7.68 181.86 0.03 BP_GYD CT CMS 14 1200.00 0.34 161.95 100.00 1199.97 3.08 -8.24 -0.07 8.25 180.49 0.01 BP_GYD CT CMS 15 1300.00 0.33 161.10 100.00 1299.96 3.11 -8.80 0.12 8.80 179.25 0.01 BP_GYD CT CMS 16 1400.00 0.16 145.71 100.00 1399.96 3.09 -9.19 0.29 9.19 178.21 0.18 BP_GYD CT CMS 17 1500.00 0.23 174.06 100.00 1499.96 3.11 -9.50 0.39 9.51 177.67 0.12 BP_GYD CT CM5 18 1600.00 0.27 255.47 100.00 1599.96 3.40 -9.76 0.18 9.76 178.95 0.33 BP_GYD CT CM5 19 1700.00 0.90 237.95 100.00 1699.96 4.41 -10.24 -0.71 10.26 183.99 0.65 BP_GYD CT CMS 20 1800.00 2.15 222.71 100.00 1799.92 6.87 -12.03 -2.65 12.32 192.43 1.30 BP_GYD CT CMS 21 1900.00 4.13 213.90 100.00 1899.77 11.52 -16.40 -5.93 17.44 199.89 2.03 BP_GYD CT CM5 22 2000.00 8.45 236.14 100.00 1999.15 21.66 -23.49 -14,05 27.37 210.89 4.88 BP_GYD CT CMS 23 2100.00 12.47 241.09 100.00 2097.47 39.55 -32.80 -29.61 44.19 222.07 4.12 BP_GYD CT CMS 24 2200.00 16.15 240.86 100.00 2194.35 64.04 -44.80 -51.21 68.04 228.82 3.68 BP_GYD CT CMS 25 2300.00 20.06 240.23 100.00 2289.38 94.80 -60.09 -78.26 98.67 232.48 3.91 BP_GYD CT CMS 26 2400.00 24.40 241.05 100.00 2381.93 132.27 -78.62 -111.23 136.21 234.75 4.35 BP_GYD CT CMS 27 2500.00 29.56 242.56 100.00 2471.02 177.31 -99.99 -151.23 181.30 236.53 5.20 BP_GYD CT CMS 28 2600.00 33.71 243.65 100.00 2556.14 229.51 -123.69 -198.01 233.46 238.01 4.19 BP_GYD CT CM5 29 2700.00 35.96 244.19 100.00 2638.21 286.44 -148.79 -249.31 290.34 239.17 2.27 BP_GYD CT CMS 30 2800.00 37.10 244.88 100.00 2718.57 345.81 -174.38 -303.05 349.64 240.08 1.21 BP_GYD CT CMS [(c)2007 IDEAL ID12_OC_13]o SCHLUMBERGER Survey Report 21-Oct-2007 16:51:31 Page 3 of 8 Page 2 LJ G-19B_Final_Surveys.txt --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ------- ------- Displ --------- --------- Displ ------- ------- Total -------- -------- At ----- ----- DLS ----- ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/S- +E/w- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (ft) --------- (ft) ------- (deg) -------- 100f) ----- type ----- (deg) ------ --- 31 -------- 2900.00 ------ 39.01 ------- 242.66 ------ 100.00 -------- 2797.31 -------- 407.23 ------- -201.64 --------- -358.33 ------- 411.17 -------- 240.63 ----- 2.35 ----- BP_GYD --- CT --- CMS 32 3000.00 41.27 242.13 100.00 2873.75 471.31 -231.52 -415.45 475.60 240.87 2.29 BP_GYD CT CMS 33 3100.00 42.89 243.69 100.00 2947.97 538.00 -262.02 -475.11 542.57 241.12 1.93 BP_GYD CT CMS 34 3200.00 44.42 243.09 100.00 3020.32 606.74 -292.94 -536.83 611.55 241.38 1.59 BP_GYD CT CMS 35 3300.00 44.74 242.88 100.00 3091.55 676.60 -324.83 -599.36 681.72 241.54 0.35 BP_GYD CT CMS 36 3400.00 44.46 242.84 100.00 3162.75 746.47 -356.86 -661.84 751.92 241.67 0.28 BP_GYD CT CMS 37 3500.00 44.22 243.41 100.00 3234.27 816.04 -388.45 -724.18 821.79 241.79 0.47 BP_GYD CT CMS 38 3600.00 44.29 243.10 100.00 3305.90 885.53 -419.86 -786.50 891.55 241.91 0.23 BP_GYD CT CMS 39 3700.00 44.27 243.28 100.00 3377.49 955.04 -451.35 -848.81 961.35 242.00 0.13 BP_GYD CT CMS 40 3800.00 44.58 243.69 100.00 3448.91 1024.76 -482.59 -911.45 1031.33 242.10 0.42 BP_GYD CT CMS 41 3900.00 44.61 243.60 100.00 3520.12 1094.71 -513.76 -974.36 1101.51 242.20 0.07 BP_GYD CT CMS 42 4000.00 44.60 244.04 100.00 3591.31 1164.69 -544.74 -1037.38 1171.71 242.30 0.31 BP_GYD CT CMS 43 4100.00 44.54 243.18 100.00 3662.55 1234.60 -575.93 -1100.24 1241.87 242.37 0.61 BP_GYD CT CMS 44 4200.00 44.47 243.51 100.00 3733.87 1304.41 -607.38 -1162.89 1311.95 242.42 0.24 BP_GYD CT CMS 45 4300.00 44.20 243.41 100.00 3805.40 1374.02 -638.61 -1225.41 1381.83 242.47 0.28 BP_GYD CT CMS 46 4400.00 44.24 243.75 100.00 3877.06 1443.49 -669.64 -1287.87 1451.56 242.53 0.24 BP_GYD CT CMS 47 4500.00 43.92 243.52 100.00 3948.90 1512.80 -700.53 -1350.20 1521.11 242.58 0.36 BP_GYD CT CMS 48 4600.00 43.46 243.73 100.00 4021.21 1581.62 -731.22 -1412.08 1590.18 242.62 0.48 BP_GYD CT CMS 49 4700.00 43.46 243.74 100.00 4093.80 1650.16 -761.66 -1473.77 1658.95 242.67 0.01 BP_GYD CT CMS 50 4800.00 43.05 244.19 100.00 4166.63 1718.46 -791.74 -1535.34 1727.46 242.72 0.51 BP_GYD CT CMS 51 4900.00 42.91 244.21 100.00 4239.79 1786.44 -821.41 -1596.71 1795.61 242.78 0.14 BP_GYD CT CMS 52 5000.00 42.61 244.35 100.00 4313.21 1854.14 -850.87 -1657.88 1863.48 242.83 0.31 BP_GYD CT CMS 53 5100.00 42.65 244.76 100.00 4386.78 1921.70 -879.97 -1719.04 1931.17 242.89 0.28 BP_GYD CT CMS 54 5200.00 42.64 244.72 100.00 4460.34 1989.29 -908.88 -1780.30 1998.89 242.95 0.03 BP_GYD CT CMS 55 5300.00 42.52 245.30 100.00 4533.97 2056.82 -937.46 -1841.63 2066.50 243.02 0.41 BP_GYD CT CMS 56 5400.00 42.76 245.48 100.00 4607.53 2124.46 -965.67 -1903.22 2134.19 243.10 0.27 BP_GYD CT CMS 57 5500.00 43.02 245.31 100.00 4680.80 2192.41 -994.01 -1965.10 2202.19 243.17 0.28 BP_GYD CT CMS 58 5600.00 43.69 246.59 100.00 4753.51 2260.99 -1021.98 -2027.79 2270.76 243.25 l.ll BP_GYD CT CMS 59 5700.00 43.79 246.67 100.00 4825.76 2330.09 -1049.41 -2091.25 2339.79 243.35 0.11 BP_GYD CT CMS 60 5800.00 43.50 246.76 100.00 4898.12 2399.07 -1076.69 -2154.65 2408.69 243.45 0.30 BP_GYD CT CMS [(c)2007 IDEAL ID12_OC_13]~ SCHLUMBERGER Survey Report 21-Oct-2007 16:51:31 Page 4 of 8 Page 3 • G-196_Final_Surveys.txt Seq Measured Incl Azimuth Course TVD vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/5- +E/w- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (ft) --------- (ft) ------- (deg) -------- 100f) ----- type ----- (deg) ------ --- 61 -------- 5900.00 ------ 43.87 ------- 246.90 ------ 100.00 -------- 4970.44 -------- 2468.11 ------- -1103.86 --------- -2218.15 ------- 2477.64 -------- 243.54 ----- 0.38 ----- BP_GYD --- CT --- CMS 62 6000.00 44.20 246.78 100.00 5042.33 2537.59 -1131.20 -2282.06 2547.04 243.63 0.34 BP_GYD CT CMS 63 6100.00 44.91 247.85 100.00 5113.59 2607.73 -1158.26 -2346.79 2617.05 243.73 1.03 BP_GYD CT CMS 64 6200.00 44.98 247.82 100.00 5184.37 2678.36 -1184.91 -2412.21 2687.52 243.84 0.07 BP_GYD CT CMS 65 6300.00 45.18 248.53 100.00 5254.98 2749.17 -1211.23 -2477.94 2758.13 243.95 0.54 BP_GYD CT CMS 66 6400.00 45.65 249.34 100.00 5325.18 2820.39 -1236.83 -2544.41 2829.09 244.08 0.74 BP_GYD CT CMS 67 6500.00 45.64 250.14 100.00 5395.09 2891.88 -1261.59 -2611.48 2900.25 244.22 0.57 BP_GYD CT CMS 68 6600.00 45.82 250.75 100.00 5464.89 2963.44 -1285.55 -2678.96 2971.44 244.37 0.47 BP_GYD CT • CMS 69 6700.00 45.76 251.92 100.00 5534.62 3035.04 -1308.49 -2746.86 3042.60 244.53 0.84 BP_GYD CT CMS 70 6800.00 45.85 250.38 100.00 5604.33 3106.66 -1331.66 -2814.71 3113.83 244.68 l.ll BP_GYD CT CMS 71 6900.00 45.65 250.42 100.00 5674.11 3178.25 -1355.69 -2882.19 3185.11 244.81 0.20 BP_GYD CT CMS 72 7000.00 45.4 3 250.19 100.00 5744.15 3249.59 -1379.74 -2949.39 3256.16 244.93 0.27 BP_GYD CT CMS 73 7100.00 45.27 250.48 100.00 5814.43 3320.70 -1403.68 -3016.38 3326.99 245.05 0.26 BP_GYD CT CMS 74 7200.00 45.30 250.46 100.00 5884.79 3391.72 -1427.44 -3083.35 3397.74 245.16 0.03 BP_GYD CT CMS 75 7300.00 44.99 250.62 100.00 5955.32 3462.57 -1451.05 -3150.19 3468.33 245.27 0.33 BP_GYD CT CMS 76 7400.00 44.81 250.51 100.00 6026.15 3533.11 -1474.54 -3216.76 3538.62 245.37 0.20 BP_GYD CT CMS 77 7500.00 44.39 250.49 100.00 6097.36 3603.29 -1497.98 -3282.95 3608.56 245.47 0.42 BP_GYD CT CMS 78 7600.00 44.04 250.68 100.00 6169.03 3672.98 -1521.16 -3348.72 3678.02 245.57 0.37 BP_GYD CT CMS 79 7700.00 43.62 250.71 100.00 6241.17 3742.18 -1544.05 -3414.07 3747.00 245.66 0.42 BP_GYD CT CMS 80 7800.00 43.31 251.19 100.00 6313.75 3810.92 -1566.51 -3479.10 3815.50 245.76 0.45 BP_GYD CT CMS 81 7900.00 42.75 251.17 100.00 6386.85 3879.08 -1588.52 -3543.69 3883.44 245.85 0.56 BP_GYD CT CMS 82 8000.00 42.39 251.67 100.00 6460.49 3946.65 -1610.08 -3607.81 3950.78 245.95 0.49 BP_GYD CT CMS 83 8100.00 42.09 251.74 100.00 6534.53 4013.77 -1631.18 -3671.64 4017.67 246.05 0.30 BP_GYD CT CMS 84 8200.00 43.13 251.72 100.00 6608.12 4081.37 -1652.40 -3735.92 4085.04 246.14 1.04 BP_GYD CT CMS • 85 8300.00 44.11 251.52 100.00 6680.51 4150.25 -1674.16 -3801.39 4153.72 246.23 0.99 BP_GYD CT CMS 86 8400.00 44.92 251.65 100.00 6751.82 4220.27 -1696.30 -3867.91 4223.52 246.32 0.82 BP_GYD CT CMS 87 8500.00 45.41 251.41 100.00 6822.33 4291.09 -1718.77 -3935.17 4294.15 246.41 0.52 BP_GYD CT CMS 88 8600.00 45.70 251.58 100.00 6892.35 4362.39 -1741.43 -4002.87 4365.26 246.49 0.31 BP_GYD CT CMS 89 8700.00 45.10 251.72 100.00 6962.56 4433.48 -1763.84 -4070.45 4436.18 246.57 0.61 BP_GYD CT CMS 90 8800.00 44.25 251.68 100.00 7033.67 4503.69 -1785.92 -4137.20 4506.21 246.65 0.85 BP_GYD CT CMS [(c)2007 IDEAL ID12_OC_13]0 SCHLUMBERGER Survey Report 21-Oct-2007 16:51:31 Page 5 of 8 Page 4 G-196_Final_Surveys.txt Seq Measured Incl Azimuth Course TVD vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/w- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (ft) --------- (ft) ------- (deg) -------- 100f) ----- type (deg) ----- ------ --- 91 -------- 8900.00 ------ 43.65 ------- 251.52 ------ 100.00 -------- 7105.67 -------- 4572.99 ------- -1807.83 --------- -4203.06 ------- 4575.36 -------- 246.73 ----- 0.61 ----- ------ BP_GYD CT CMS 92 9000.00 42.98 251.52 100.00 7178.43 4641.50 -1829.57 -4268.12 4643.73 246.80 0.67 BP_GYD CT CMS 93 9100.00 42.40 251.40 100.00 7251.93 4709.22 -1851.13 -4332.40 4711.31 246.86 0.59 BP_GYD CT CMS 94 9200.00 41.53 251.75 100.00 7326.28 4775.99 -1872.27 -4395.84 4777.95 246.93 0.90 BP_GYD CT CMS 95 9300.00 41.32 251.60 100.00 7401.27 4842.06 -1893.07 -4458.65 4843.89 246.99 0.23 BP_GYD CT CMS 96 9400.00 40.93 251.74 100.00 7476.59 4907.73 -1913.75 -4521.08 4909.45 247.06 0.40 BP_GYD CT CMS 97 9487.00 40.58 251.45 87.00 7542.50 4964.45 -1931.68 -4574.98 4966.07 247.11 0.46 BP_BLIND 98 9504.00 42.07. 249.33 17.00 7555.26 4975.67 -1935.45 -4585.55 4977.27 247.12 12.03 BP_INC+TREND 99 9535.89 39.50 247.00 31.89 7579.41 4996.50 -1943.19 -4604.88 4998.09 247.12 9.37 BP_INC+TREND 100 9630.20 42.42 241.06 94.31 7650.65 5058.05 -1970.32 -4660.36 5059.76 247.08 5.16 BP_INC+TREND 101 9684.76 46.38 236.22 54.56 7689.63 5095.61 -1990.22 -4692.91 5097.48 247.02 9.55 BP_MWD+IFR+MS 102 9726.73 46.58 235.55 41.97 7718.54 5125.30 -2007.29 -4718.10 5127.35 246.95 1.25 BP_MWD+IFR+MS 103 9822.67 43.07 234.06 95.94 7786.57 5190.99 -2046.24 -4773.37 5193.48 246.80 3.82 BP_MWD+IFR+MS 104 9918.82 42.31 235.08 96.15 7857.25 5254.24 -2084.03 -4826.49 5257.20 246.65 1.07 BP_MWD+IFR+MS 105 10015.13 41.06 237.25 96.31 7929.17 5316.78 -2119.70 -4879.68 5320.19 246.52 1.98 BP_MWD+IFR+MS 106 10109.93 41.17 237.42 94.80 8000.60 5377.93 -2153.35 -4932.16 5381.73 246.41 0.17 BP_MWD+IFR+MS 107 10205.56 41.04 237.05 95.63 8072.65 5439.57 -2187.37 -4985.02 5443.81 246.31 0.29 BP_MWD+IFR+MS 108 10301.61 41.19 237.09 96.05 8145.02 5501.46 -2221.71 -5038.04 5506.16 246.20 0.16 BP_MWD+IFR+MS 109 10397.39 44.90 238.06 95.78 8215.00 5565.63 -2256.74 -5093.22 5570.79 246.10 3.93 BP_MWD+IFR+MS 110 10492.71 44.50 238.11 95.32 8282.76 5631.56 -2292.18 -5150.13 5637.19 246.01 0.42 BP_MWD+IFR+MS 111 10524.08 44.09 238.02 31.37 8305.21 5653.10 -2303.77 -5168.72 5658.89 245.98 1.32 BP_MWD+IFR+MS 112 10604.32 43.62 238.36 80.24 8363.07 5707.78 -2333.07 -5215.97 5713.98 245.90 0.66 BP_MWD+IFR+MS 113 10686.01 39.89 240.91 81.69 8424.00 5761.50 -2360.60 -5262.87 5768.03 245.84 5.02 BP_INC+TREND 114 10717.46 35.49 242.41 31.45 8448.89 5780.58 -2369.74 -5279.78 5787.20 245.83 14.29 BP_MWD+IFR+MS 115 10749.84 30.77 243.28 32.38 8475.99 5798.18 -2377.82 -5295.52 5804.87 245.82 14.65 BP_MWD+IFR+MS 116 10781.02 25.60 243.10 31.18 8503.47 5812.84 -2384.46 -5308.66 5819.58 245.81 16.58 BP_MWD+IFR+MS 117 10813.62 20.68 243.90 32.60 8533.44 5825.59 -2390.18 -5320.11 5832.37 245.81 15.12 BP_MWD+IFR+MS 118 10845.85 15.90 246.70 32.23 8564.03 5835.68 -2394.43 -5329.28 5842.48 245.81 15.08 BP_MWD+IFR+MS 119 10876.34 11.43 253.37 30.49 8593.65 5842.87 -2396.95 -5336.02 5849.66 245.81 15.52 BP_MWD+IFR+MS 120 10908.50 8.86 277.60 32.16 8625.32 5848.22 -2397.54 -5341.53 5854.92 245.83 15.32 BP_MWD+IFR+MS [(c)2007 IDEAL ID12_OC_13]o SCHLUMBERGER Survey Report 21-Oct-2007 16:51:31 Page 6 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool • Page 5 G-196_Final_Surveys.txt # depth angle angle length depth section +N/S- +E/w- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (ft) --------- (ft) ------- (deg) -------- 100f) ----- type (deg) ----- ------ --- 121 -------- 10942.53 ------ 9.92 ------- 300.40 ------ 34.03 -------- 8658.90 -------- 5852.32 ------- -2395.71 --------- -5346.66 ------- 5858.85 -------- 245.86 ----- 11.28 ----- ------ BP_MWD+IFR+MS 122 10972.30 11.29 318.95 29.77 8688.17 5854.89 -2392.21 -5350.79 5861.19 245.91 12.29 BP_MWD+IFR+MS 123 11004.72 13.19 335.17 32.42 8719.86 5856.17 -2386.46 -5354.42 5862.17 245.98 12.06 BP_MWD+IFR+MS 124 11037.02 18.05 346.94 32.30 8750.97 5855.66 -2378.23 -5357.10 5861.28 246.06 17.89 BP_MWD+IFR+MS 125 11068.84 23.99 356.33 31.82 8780.67 5852.97 -2366.96 -5358.63 5858.11 246.17 21.40 BP_MWD+IFR+MS 126 11100.32 29.46 6.25 31.48 8808.79 5847.41 -2352.86 -5358.20 5852.03 246.29 22.37 BP_MWD+IFR+MS 127 11132.02 33.99 14.66 31.70 8835.76 5838.56 -2336.52 -5355.11 5842.65 246.43 19.94 BP_MWD+IFR+MS 128 11162.73 37.99 23.16 30.71 8860.62 5826.86 -2319.51 -5349.21 5830.45 246.56 20.81 BP_MWD+IFR+MS 129 11194.95 42.43 31.61 32.22 8885.23 5811.19 -2301.11 -5339.60 5814.33 246.69 21.81 BP_MWD+IFR+MS 130 11227.77 45.68 39.95 32.82 8908.84 5792.02 -2282.66 -5326.25 5794.78 246.80 20.24 BP_MWD+IFR+MS 131 11258.48 45.59 43.22 30.71 8930.31 5772.46 -2266.25 -5311.68 5774.93 246.89 7.62 BP_MWD+IFR+MS 132 11288.91 48.73 49.11 30.43 8951.01 5751.84 -2250.83 -5295.58 5754.08 246.97 17.54 BP_MWD+IFR+MS 133 11322.35 55.59 51.54 33.44 8971.52 5726.77 -2234.00 -5275.25 5728.79 247.05 21.30 BP_MWD+IFR+MS 134 11354.35 62.37 53.09 32.00 8988.00 5700.45 -2217.26 -5253.55 5702.29 247.12 21.59 BP_MWD+IFR+MS 135 11385.40 68.73 54.83 31.05 9000.84 5673.11 -2200.65 -5230.70 5674.78 247.18 21.11 BP_MWD+IFR+MS 136 11399.45 71.61 55.31 14.05 9005.61 5660.26 -2193.08 -5219.87 5661.86 247.21 20.75 BP_MWD+IFR+MS 137 11442.31 79.13 59.68 42.86 9016.43 5619.60 -2170.84 -5184.92 5621.02 247.28 20.12 BP_MWD+IFR+MS 138 11470.68 81.36 57.46 28.37 9021.24 5592.07 -2156.26 -5161.06 5593.39 247.33 11.01 BP_MWD+IFR+MS 139 11503.21 83.30 55.28 32.53 9025.58 5560.56 -2138.41 -5134.22 5561.75 247.39 8.93 BP_MWD+IFR+MS 140 11536.50 85.57 54.48 33.29 9028.81 5528.37 -2119.35 -5107.12 5529.41 247.46 7.23 BP_MWD+IFR+MS 141 11565.24 88.49 59.24 28.74 9030.30 5500.28 -2103.66 -5083.10 5501.21 247.52 19.41 BP_MWD+IFR+MS 142 11598.06 89.93 58.67 32.82 9030.75 5467.93 -2086.74 -5054.98 5468.76 247.57 4.72 BP_MWD+IFR+MS 143 11630.68 90.61 58.95 32.62 9030.60 5435.78 -2069.85 -5027.08 5436.52 247.62 2.25 BP_MWD+IFR+MS 144 11662.00 90.72 58.06 31.32 9030.23 5404.94 -2053.49 -5000.38 5405.60 247.67 2.86 BP_MWD+IFR+MS 145 11694.50 90.41 59.87 32.50 9029.91 5372.90 -2036.73 -4972.53 5373.48 247.73 5.65 BP_MWD+IFR+MS 146 11727.33 90.31 58.79 32.83 9029.71 5340.50 -2019.99 -4944.29 5341.01 247.78 3.30 BP_MWD+IFR+MS 147 11750.23 90.14 59.28 22.90 9029.62 5317.92 -2008.20 -4924.66 5318.38 247.82 2.26 BP_MWD+IFR+MS 148 11786.43 90.41 57.00 36.20 9029.44 5282.32 -1989.10 -4893.91 5282.70 247.88 6.34 BP_MWD+IFR+MS 149 11818.25 90.51 56.71 31.82 9029.19 5251.16 -1971.70 -4867.27 5251.47 247.95 0.96 BP_MWD+IFR+MS 150 11852.17 91.61 57.39 33.92 9028.56 5217.93 -1953.25 -4838.81 5218.17 248.02 3.81 BP_MWD+IFR+MS [(c)2007 IDEAL ID12_OC_13]o SCHLUMBERGER survey Report 21-oct-2007 16:51:31 --- -------- ------ ------- ------ -------- -------- ---------------- ------ --- -------- ------ ------- ------ -------- -------- ---------------- ------ Seq Measured Incl Azimuth Course TvD vertical Displ Displ Total # depth angle angle length depth section +N/5- +E/W- displ Page 7 of 8 ----- ----- ----- ------ ----- ----- ----- ------ At DLS Srvy Tool Azim (deg/ tool Corr Page 6 G-196_Final_Surveys.txt - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (ft) --------- (ft) ------- (deg) -------- 100f) ----- type (deg) ----- ------ --- 151 -------- 11885.96 ------ 92.23 ------- 57.58 ------ 33.79 -------- 9027.43 -------- 5184.79 ------- -1935.10 --------- -4810.34 ------- 5184.97 -------- 248.09 ----- 1.92 ----- ------ BP_MWD+IFR+MS 152 11920.36 91.99 58.00 34.40 9026.16 5151.02 -1916.78 -4781.25 5151.15 248.15 1.41 BP_MWD+IFR+MS 153 11951.26 91.95 58.22 30.90 9025.10 5120.65 -1900.46 -4755.03 5120.75 248.21 0.72 BP_MWD+IFR+MS 154 11982.48 91.03 58.44 31.22 9024.29 5089.94 -1884.08 -4728.47 5090.01 248.28 3.03 BP_MWD+IFR+MS 155 12015.45 90.20 56.41 32.97 9023.93 5057.59 -1866.33 -4700.69 5057.63 248.35 6.65 BP_MWD+IFR+MS 156 12045.95 90.27 56.81 30.50 9023.81 5027.76 -1849.54 -4675.22 5027.77 248.42 1.33 BP_MWD+IFR+MS 157 12074.59 89.93 56.05 28.64 9023.76 4999.76 -1833.71 -4651.36 4999.76 248.48 2.91 BP_MWD+IFR+MS 158 12107.76 89.38 55.16 33.17 9023.96 4967.43 -1814.97 -4623.99 4967.43 248.57 3.15 BP_MWD+IFR+MS 159 12141.99 88.59 54.32 34.23 9024.57 4934.20 -1795.21 -4596.04 4934.21 248.66 3.37 BP_MWD+IFR+MS 160 12172.43 89.21 54.32 30.44 9025.15 4904.70 -1777.46 -4571.32 4904.73 248.75 2.04 BP_MWD+IFR+MS 161 12205.72 90.31 53.90 33.29 9025.29 4872.47 -1757.95 -4544.35 4872.53 248.85 3.54 BP_MWD+IFR+MS 162 12238.74 90.61 53.90 33.02 9025.03 4840.53 -1738.49 -4517.68 4840.63 248.95 0.91 BP_MWD+IFR+Ms 163 12270.29 90.68 53.65 31.55 9024.67 4810.02 -1719.85 -4492.23 4810.19 249.05 0.82 BP_MWD+IFR+MS 164 12303.28 90.31 52.24 32.99 9024.38 4778.26 -1699.97 -4465.90 4778.51 249.16 4.42 BP_MWD+IFR+MS 165 12333.98 90.17 51.71 30.70 9024.26 4748.83 -1681.06 -4441.72 4749.19 249.27 1.79 BP_MWD+IFR+MS 166 12364.16 90.03 51.08 30.18 9024.20 4720.00 -1662.23 -4418.13 4720.48 249.38 2.14 BP_MWD+IFR+MS 167 12397.01 89.86 51.16 32.85 9024.23 4688.66 -1641.61 -4392.56 4689.29 249.51 0.57 BP_MWD+IFR+MS 168 12429.05 89.41 50.69 32.04 9024.44 4658.13 -1621.41 -4367.69 4658.93 249.63 2.03 BP_MWD+IFR+MS 169 12461.65 89.76 50.99 32.60 9024.67 4627.08 -1600.83 -4342.41 4628.08 249.76 1.41 BP_MWD+IFR+MS 170 12495.17 90.27 50.60 33.52 9024.67 4595.16 -1579.64 -4316.44 4596.40 249.90 1.92 BP_MWD+IFR+MS 171 12526.38 91.20 51.28 31.21 9024.27 4565.42 -1559.97 -4292.20 4566.90 250.03 3.69 BP_MWD+IFR+MS 172 12558.07 91.68 50.71 31.69 9023.47 4535.22 -1540.04 -4267.59 4536.96 250.16 2.35 BP_MWD+IFR+MS 173 12590.30 91.13 49.58 32.23 9022.68 4504.65 -1519.39 -4242.85. 4506.70 250.30 3.90 BP_MWD+IFR+MS 174 12620.25 91.09 49.27 29.95 9022.10 4476.36 -1499.91 -4220.11 4478.73 250.43 1.04 BP_MWD+IFR+MS 175 12652.43 90.82 48.55 32.18 9021.56 4446.06 -1478.76 -4195.86 4448.82 250.59 2.39 BP_MWD+IFR+MS 176 12687.15 89.52 48.85 34.72 9021.46 4413.41 -1455.85 -4169.77 4416.62 250.75 3.84 BP_MWD+IFR+MS 177 12715.42 89.83 48.38 28.27 9021.62 4386.84 -1437.16 -4148.56 4390.45 250.89 1.99 BP_MWD+IFR+MS 178 12746.75 90.10 48.47 31.33 9021.64 4357.43 -1416.37 -4125.13 4361.51 251.05 0.91 BP_MWD+IFR+MS 179 12778.40 90.31 48.35 31.65 9021.53 4327.71 -1395.36 -4101.46 4332.32 251.21 0.76 BP_MWD+IFR+MS 180 12809.02 90.92 48.84 30.62 9021.20 4298.94 -1375.11 -4078.49 4304.07 251.37 2.56 BP_MWD+IFR+MS [(c)2007 IDEAL ID12_OC_13]o SCHLUMBERGER Survey Report 21-oct-2007 16:51:31 Page 8 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD vertical Displ Displ Total At DLS srvy Tool # depth angle angle length depth section +N/5- +E/w- displ ,4zim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) Page 7 ~~ --- -------- ------ ------- ------ ------- G-19B_Final - -------- _Surveys.txt ---------------- ------ --- 181 -------- 12841.10 ------ 90.82 ------- 48.31 ------ 32.08 ------- 9020.71 - -------- 4268.80 ------ -1353.89 ---------- -4054.44 ------ 4274.52 182 12874.43 89.96 48.86 33.33 9020.48 4237.47 -1331.84 -4029.44 4243.85 183 12907.33 89.83 48.45 32.90 9020.54 4206.54 -1310.11 -4004.75 4213.59 184 12938.67 90.89 49.31 31.34 9020.35 4177.04 -1289.50 -3981.14 4184.76 185 12971.80 92.47 50.75 33.13 9019.38 4145.64 -1268.23 -3955.76 4154.09 186 13002.16 92.74 50.56 30.36 9018.00 4116.78 -1249.00 -3932.30 4125.90 187 13033.60 92.26 50.56 31.44 9016.62 4086.91 -1229.04 -3908.05 4096.75 188 13065.83 90.79 52.54 32.23 9015.77 4056.11 -1209.01 -3882.8 2 4066.69 189 13096.80 89.79 52.19 30.97 9015.61 4026.37 -1190.10 -3858.29 4037.67 190 13128.34 90.03 52.96 31.54 9015.66 3996.05 -1170.93 -3833.24 4008.10 191 13161.37 90.13 52.82 33.03 9015.61 3964.25 -1151.00 -3806.90 3977.10 192 13193.60 90.41 52.52 32.23 9015.46 3933.25 -1131.46 -3781.28 3946.93 193 13224.99 91.30 53.60 31.39 9014.99 3903.01 -1112.60 -3756.19 3917.50 194 13257.60 94.53 53.80 32.61 9013.33 3871.54 -1093.32 -3729.95 3886.88 195 13287.89 94.66 53.60 30.29 9010.91 3842.35 -1075.45 -3705.61 3858.52 196 13319.10 93.63 52.67 31.21 9008.65 3812.35 -1056.77 -3680.71 3829.41 197 13352.28 91.68 52.72 33.18 9007.11 3780.47 -1036.68 -3654.35 3798.55 198 13384.54 90.31 53.94 32.26 9006.55 3749.35 -1017.42 -3628.48 3768.42 199 13416.71 90.48 53.69 32.17 9006.33 3718.24 -998.43 -3602.51 3738.31 200 13449.49 90.89 53.91 32.78 9005.94 3686.55 -979.07 -3576.06 3707.67 201 13481.81 91.23 54.66 32.32 9005.34 3655.23 -960.21 -3549.83 3677.40 202 13514.06 91.51 54.05 32.25 9004.57 3623.98 -941.42 -3523.63 3647.22 203 13547.10 91.44 53.19 33.04 9003.72 3592.07 -921.83 -3497.04 3616.49 204 13579.23 91.88 54.76 32.13 9002.79 3560.99 -902.94 -3471.06 3586.58 205 13607.50 91.68 53.57 28.27 9001.91 3533.62 -886.40 -3448.15 3560.26 206 13635.17 91.99 53.69 27.67 9001.03 3506.90 -870.00 -3425.89 3534.63 207 13692.00 91.99 53.69 56.83 8999.05 3452.01 -836.37 -3380.12 3482.05 [(c)2007 IDEAL ID12_OC_13] ------- ------- 251.53 ----- ----- 1.68 ----- ------ ----- ------ BP_MWD+IFR+MS 251.71 3.06 BP_MWD+IFR+MS 251.89 1.31 BP_MWD+IFR+MS 252.05 4.36 BP_MWD+IFR+MS 252.22 6.45 BP_MWD+IFR+MS 252.38 1.09 BP_MWD+IFR+MS 252.54 1.53 BP_MWD+IFR+MS 252.70 7.65 BP_MWD+IFR+MS 252.86 3.42 BP_MWD+IFR+MS 253.01 2.56 BP_MWD+IFR+MS 253.18 0.52 BP_MWD+IFR+MS 253.34 1.27 BP_MWD+IFR+MS 253.50 4.46 BP_MWD+IFR+MS 253.66 9.92 BP_MWD+IFR+MS 253.82 0.79 BP_MWD+IFR+MS 253.98 4.44 BP_MWD+IFR+MS 254.16 5.88 BP_MWD+IFR+MS 254.34 5.69 BP_MWD+IFR+MS 254.51 0.94 BP_MWD+IFR+MS 254.69 1.42 BP_MWD+IFR+MS 254.86 2.55 BP_MWD+IFR+MS 255.04 2.08 BP_MWD+IFR+MS 255.23 2.61 BP_MWD+IFR+MS 255.42 5.07 BP_MWD+IFR+MS 255.58 4.27 BP_MWD+IFR+MS 255.75 1.20 BP_MWD+IFR+MS 256.10 0.00 Projected_TD Page 8 Date I 1-09-2007 Transmittal Number:92919 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Douglas Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: ~-'=-_k G.-09B..__~~'}......l-t.~.~'~ .tSl~~-Pa._-- r_ ion ~,.~ _ t~Ll ~ rte! 5: c'~? Please`~ign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 !/ Schlumberger Customer Well No Installation/Rig ~~v o ~ zoos Drilling & Measurements AIB~k~ (~~~ ~ ~~~ C005, Cummiss~or>! MWD/LWD Log Product Delivery ApGMOr3~6 BP Exploration (Alaska) Inc. G-19B Nabors 7ES Dispatched To: Date Dispatched Dispatched By: Christine Mahnken 1-0 ct-07 Franklin Medina Data No Of Prints No of Floppies Surveys 2 1 Received By: V Wvw Please sign and return to: Drilling & Measurements LWD Division p p u v ~~ ~~„~ 2525 Gambell Street, Suite 400 1~ Anchorage, Alaska 99501 fclarke3C~?slb.com Fax:907-561-8317 LWU Log Uellvery VZ.1, U3-Uti-Uti ORIGINAL a~?-r~.ti Maunder, Thomas E (DOA From: Hobbs, Greg S (ANC) [Greg.Hobbs@bp.com] Sent: Tuesday, October 02, 2007 9:01 PM To: Maunder, Thomas E (DOA) ~ Subject: RE: G-19A c~~ ~ ~ ~~°~ The 13 3/8" was collapsed and barely passed a 9 5/8" collar. We pulled 100,000 over to get the first collar through, then were able to fish the rest out. We then swaged out the 13 3/8" with a 10 3/4, 11 1/4 and 12 i/8" swage respectively to get the 11 3/4 washover shoe through to the top of the 9 5/8" stub. We then tied back with a patch successfully and fished the rest of the tubing and laid the abandonment plug and set a CIBP above the packer. We are now tying back the 9 5/8" from about 2050' per the original sundry. All in all the well was a mess. Ali the damage was caused by ice on the casing, the tubing was pressure. I have a presentation that I am putting together that I will send to you. I am heading to the slope tommorrow, but will catch up with you! Greg From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov~ Sent: Tue 10/2/2007 1:06 PM To: Hobbs, Greg S {ANC) Subject: RE: G-19A Based on what you relate,. it appears that you were successfully able to deal with the collapsed 13-3/8". If you can describe what was found, I'd appreciate. Regards, Tom Maunder, PE AOGCC From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs@bp.com] Sent: Monday, October Ol, 2007 1:13 PM To: Maunder, Thomas E (DOA) Cc: Nigh, Jim Subject: RE: DS 14-18B Tom- Jim is out, I will take a look and follow up- G-19 has an abandonment plug above the oid production packer now, and we are working on doing the 9 5/8" tieback at this time- 1 RE: G-19 Progress Page 1 of 4 Maunder, Thomas E (DOA) From: Hobbs, Greg S (ANC) [Greg.Hobbs@bp.com] Sent: Monday, September 24, 2007 3:54 PM To: Maunder, Thomas E (DOA) Cc: NSU, ADW Drlg Rig 7 ES Subject: RE: G-19 Progress ~~ ~1--\~ `--~ j~c G~~~ ~ ~~ -~~ Thanks for the quick turnaround Tom, this helps Duncan firm up his plans forward. Also to clarify, we will weld a wellhead on the well if a 7" tieback is required for any 9 5/8" corrosion right now. If we do not need a 7" tieback at this time, we will use a Cameron Sliplock wellhead with Primary and Back-up metal seals. The same seal has been used to hang casing in in Arctic conditions in Russia with no issues. The metal seals allow it to have the Arctic rating we require. Cameron has successfully tested it in their Anchorage shop, and it passes their engineering requirements. Greg From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, September 24, 2007 3:42 PM To: Hobbs, Greg S (ANC) Cc: Jim Regg Subject: RE: G-19 Progress Greg, The further information answers my questions. It is important to know the behavior of the well since the cement was placed through the retainer. It appears that you have demonstrated that the remaining "structure" of this wounded well is competent to allow you to safely proceed with the repairs. Employing the 9-5/8" rams as you plan appears to be appropriate. Thanks for the update. Call or message with any questions. Tom Maunder, PE AOGCC From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs@bp.com] Sent: Monday, September 24, 2007 3:26 PM To: Maunder, Thomas E (DOA) Cc: NSU, ADW Drlg Rig 7 ES Subject: RE: G-19 Progress Tom- After discussion this morning, with the well not losing at all since laying the cement, and following the IA circulation with 9.8 brine, we decided to test the well to 1000 psi and monitor the OA. The abandoned perforations and the production packer held 1000 psi for 10 minutes, losing 10 psi initially, then flatlining. The OA only pressured up to 100 psi and went back to zero as the pressure was bled off the well. The bradenhead of the well has a leak (screwed on the 13-3/8") that has held 500 psi in the past and failed at 1000 psi. We have not re-tested this as it is a known leak. We did not want to exacerbate it. We wanted to test the barriers down the hole to support their integrity to better support moving forward with our current plan, keeping the well full of 9.8 brine while we abandon the production packer and re-build the 9 5/8" to weld a new wellhead to it and eliminate the 13 3/8" casing string from the picture. Hope that helps- 10/3/2007 RE: G-19 Progress • ~ Page 2 of 4 Greg From: Maunder, Thomas E (DOA) [mailto:tom.maunder@aiaska.gov] Sent: Monday, September 24, 2007 2:40 PM To: Hobbs, Greg S (ANC) Subject: RE: G-19 Progress Greg, It appears that the perforations have been successfully plugged. Your plan doesn't sound unreasonable. A couple of questions ... 1. Is your OA sound? Holding the 9-5/8"joint as you plan leaves that annulus exposed to any wellbore pressure. 2. Has the well bore been pressure tested at any time? I look forward to your reply. Tom Maunder, PE AOGCC From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs@bp.com] Sent: Monday, September 24, 2007 2:32 PM To: Maunder, Thomas E (DOA) Cc: NSU, ADW Drlg Rig 7 ES Subject: RE: G-19 Progress Tom, Over the weekend, cement was placed below the EZSV with no issues and a bit of pressuring up as it entered the perforations. We came out of the EZSV and layed ~60' of cement on it, circulated the drillpipe clean and came out of the hole. We then ran a-line and tagged cement at 10152' MD (58' on cement on the EZSV) and cut the tubing at 10142' MD. We ran in with a 4.5" RTTS to 1500' to get below the back-off point in the 4.5" tubing and circulated the well to 9.8 brine through the cut at 10142' MD. Plan forward is to cut the 4.5" tubing at 200' and pull it out of the hole. Duncan would like to change the lower set of pipe rams to 9 5/8" rams and test them during the BOP test. We want to use this set of rams to space out and hold the section of 9 5/8" casing that we run back in the well to replace what is currently damaged. This eliminates breaking the stack to set slips on this temporary piece of 9 5/8" in the well. The remainder of the 4.5" tubing will then be pulled out of the well with the upper set of VBR's that will be tested for the tubing and 4" drillpipe, the annular and the blind rams. After pulling the tubing, we will lay a 100' cement plug on top of the production packer to abandon the current production interval once and for all. We will then proceed with re-building the well with new 9 5/8" casing from 2100' to surface per the sundry. Just keeping you up to date. If you have any comments or questions, feel free to get back with me! Greg 10/3/2007 RE: G-19 Progress • • Page 3 of 4 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Saturday, September 22, 2007 12:16 PM To: Hobbs, Greg S (ANC) Cc: Regg, James B (DOA) Subject: RE: G-19 Progress Greg, Good news on the progress. I have spoken with Jim Regg and we agree that your request to go beyond 7 days on the BOP test is appropriate. Plan to test when you have the upper portion 0200') of the 4-9/2" tubing removed from the well and the BOP is clear. A copy of this message should be available at the rig. Call or message with any questions. Tom Maunder, PE AOGCC From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs@bp.com] Sent: Sat 9/22/2007 8:33 AM To: Maunder, Thomas E (DOA) Subject: RE: G-19 Progress Good Morning Tom- As of 7:45 this morning, they are running the 2 7/8" PAC pipe to the plug, and are about ready to space out and pump cement. Regarding the extension of the BOP test, the blinds and bottom pipe rams were tested last Tuesday. The test of the full stack minus the bottom rams was last Saturday. With our 4 1/2" tubing in the stack that is currently allowing access deep in the well, we will not be able to test at midnight tonight. Our plan forward of cutting the 4 1/2" tubing above the packer at 10183' and 200' is to complete all work within the 4 1/2" tubing while we have that conduit. We want to minimize control line junk above the tubing fish in the well while we re-gain access through the 9 5/8" casing to finish the abandonment of the reservoir above the production packer. Hope that helps, and we appreciate the help! Greg From: Maunder, Thomas E (D maunder@alaska.gov">mailtoaom.maunder@alaska.gov] Sent: Fri 9/21 /2007 1:42 PM To: Hobbs, Greg S (ANC) Subject: RE: G-19 Progress Good news Greg. I hadn't seen tubing mashed that flat before. Now to find out if the 13-318" is not deformed. Tom From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs@bp.com] Sent: Friday, September 21, 2007 10:25 AM To: Maunder, Thomas E (DOA) Subject: G-19 Progress 10/3/2007 RE: G-19 Progress • ~ Page 4 of 4 Tom, Got an EZSV set in the 4 1/2" tailpipe last night, and are progressing forward with a cement abandonment of the perforations under the EZSV. Greg 10/3/2007 a ~ a a a SARAH PAUN, GOVERNOR ~i/~a-7~ O~ ~i`L ~S 333 W. 7th AVENUE, SUITE 100 COH-SIriRVA~IOIQ COAlMiSSIOlY ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Senior Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G-19B BP Exploration Alaska Inc. Permit No: 207-124 Surface Location: 1535' FSL, 2276' FWL, SEC. 12, T11N, R13E, UM Bottomhole Location: 612' FSL, 1050' FEL, SEC. 11, T11N, R13E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the 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). incerely an . Seamount Commissioner DATED this2~ day of September, 2007 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~'IO~~ ~ ALASKA ~f'~ AND GAS CONSERVATION COMMISS~ ~ ~ ~ ~ p ®6 ~OO~ ~:A " 3\ PERMIT TO DRILL ~~,~~ C,~ ~~~ Cis Cons. CQmmssan 20 AAC 25.005 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 propose or. ^ 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 G-19B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13612 TVD 9027 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1535' FSL 2276' FWL SEC 12 T11N R13E UM 7. Property Designation: ADL 028280 Pool , , , , . , Top of Productive Horizon: 577' FNL, 2811' FEL, SEC. 14, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: September 16, 2007 Total Depth: 612' FSL, 1050' FEL, SEC. 11, T11N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 13,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-657248 y-5967883 Zone-ASP4 10. KB Elevation Plan (Height above GL): 68.91 feet 15. Distance to Nearest Well Within Pool: 400' 16. Deviated Wells: Kickoff Depth: 10000 feet Maximum Hole An le: 90.5 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3848 Surface: 3007 18. Gasin Pr ram: ' S oificatio ns To -'Settin De t -Bo ttom uanti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data N/A 9-5/8" 47# L-80 dril 563 2152' Surface Surface 2152' 2146' 713 cu ft Class'G' 8-1/2" 7" 26# L-80 BTC-M 548' 10100' 7997' 10648' 8409' See Below -1/2" 7" 26# L-80 TC-II 2 0' 9850' 7803' 1 100' 7997' 218 cu ft Cla s'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3114' 10498' 8297' 13612' 9027' 438 cu ft Class'G' 9. PRESE NT WELCCONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 12758 Total Depth TVD (ft): 9008 Plugs (measured): None Effective Depth MD (ft): 12691 Effective Depth TVD (ft): 9007 Junk (measured): 12480 Casing , Length Size Cement Volume MD'- TVD Conductor /Structural 110' 20" 8 cu ds Concrete 110' 110' Surface 2703' 13-3/8" 3808 cu ft Permafrost 2703' 2641' Intermediate 10595' 9-5/8" 575 c ft Class 'G' 10595' 8387' Prod ction Liner 912' 7" 448 cu ft Class'G' 10341' - 11253' 8188' - 8869' Liner 2511' 2-7/8" 129 cu ft Class 'G' 10247' - 12758' 8114' - 9008' Perforation Depth MD (ft): 11355' - 12642' Perforation Depth TVD (ft): 8924' - 9007' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Piot ^ Shaltow 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 foregoipg is true and correct. Contact Ron Philips, 564-5913 Printed Name Greg Ho Title Senior Drilling Engineer ~ ,.` Prepared By Name/Number: Si nature Phone 564-4191 Date ~~~~~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: O ~?~JSb API Number: 50-029-21599-02-00 Permit A proval See cover letter for Date: • O~ other re uirements Conditions of Approval: 1 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: ^ Yes ~No Mud Log Req'd: Yes ~No ~,r~, HZS Measures: [~ Yes ^ No Directional Survey Req'd: Yes ^ No Other: 3SO~ eS~ ~30~ '-~ts~ . _ Dat APPROVED BY T COMMIn STONER Form 10~40'~ Revised ~/20fd5t s ; ~ ~ • . ~~ //e~yJim~~~ Cate U NG a_ 2~~ • • Well Name: G-196 Planned Well Summary Well Horz. Target Ivishak Well G-19B Type Sidetrack Objective Zone 1 B Producer AFE Number PBD4P2487 API Number: 50-029-21599-03 Surface Northin Eastin Offsets TRS Location 5,967,883 657,248 1,535' FSL / 2,276 FWL 11 N, 13E, 12 Target Northin Eastin TVD Offsets TRS Location 5,965,667 652,207 -9,033 4,703'FSL / 2,468'FWL 11 N, 13E, 14 Bottom Northin Eastin TVD Offsets TRS Location 5,966,891 653,942 -9,027' 612' FSL / 4,229' FWL 11 N, 13E, 11 Planned TD: 13,612' MD / 9,027' TVD S ud Date: 9/16/07 Ri Nabors 7ES DirectlOnal - Schlumberaer (P9) GL: 40.41' RKB: 68.91' Maximum Hole An le: 90.5° in the tanned horizontal roduction section Close Approach Wells: All wells except the D-07A, G-11 A and G21 pass major risk close approach criteria. The center to center distances are 739', 1,085' and 470'. All three will be re-gyroed and should pass a major risk close approach criteria. If these wells still fail anti-collision issues then the tolerable collision risk worksheet will be com leted. Surve Pro ram: MWD Standard / IFR / MS Nearest Property Line: 13,000 to the Unit boundary to the North Nearest Well within Pool: G-16 is 400' awa from tanned well. G-196 Drilling Program Page 2 • Formation Markers G-19B (Based on Dir P9) Estimated Formation Tops Estimated Pore Press Formation TVDss TVD rkb @ 68.91' MD rkb 68.91' (Psi / EMW ppg) TJD 7,846 7,915 9,993 TJC 8,045 8,114 10,254 TJB 8,167 8,236 10,416 TSGR 8,340 8,409 10,648 TSAD 8,447 8,516 10,779 TCGL 8,620 8,689 10,959 BCGL 8,680 8,749 11,020 23S6 8,731 8,800 11,072 22TS 8,790 8,859 11,136 3188psi/6.9ppg 21 TS 8,840 8,909 11,195 TZ1 B 8,926 8,995 11,328 HOT 8,964 9,033 11,481 Casinq/Tubinq Proaram Hole Size Csg / Tbg O.D. WUFt Grade Conn Length Top MD /TVD rkb Bottom MD / TVDrkb 12-1/4" 9-5/8" 47# L-80 Hydril 563 2,152' Surface 2,152' / 2,146' 8-1/2" 7" 26# L-80 BTC-M 548' 10,100'/7,997' 10,648' / 8,409' 8-1/2" 7" 26# L-80 TC-II 250' 9,850' / 7,803' 10,100' / 7,997' 6-1/8" 4-1/2" 12.6# L-80 IBT Mod 3,114' 10,498'/8,297' 13,612' / 9,027' Tubin 4-1/2" 12.6# 13CR-80 Vam To 10,498' Surface 10,498' / 8,297' Mud Proaram Hole Section / o eration: Mill window in the 9-5/8" casin KOP in Kin ak J T e Densit PV YP MBT API FL H LSND 10.8 15-25 22-30 <15 5-7 9 - 10 Hole Section / o eration: Drillin 6-1/8" roduction hole to TD 13,612' MD T e Densit PV YP LSRV API FL H MBT Flo-Pro SF 8.4-8.5 8 - 12 22 - 28 >20,000 6 - 8 9.0 - 9.5 <3 Loaaina Proaram Hole Section: Required Sensors /Service 9-5/8" C&P: USIT/GR run to find TOC for cut and pull (2,152') and condition of casing to KOP 10,000' 8-1/2" intermediate: MWD Dir/GR/Res/PWD 6-1/8" roduction: MWD Dir/GR/ABI/Res/Neu/Dens/PWD G-19B Drilling Program Page 3 .7 Cement Program • Casin Strin 9-5/8", 47#, L-80, H dril 563 Cut and ull Slurry Design Basis: Tail slurry: 2,152' of 9-5/8" x 13-3/8" annulus up to surface. Tail Slur : Slur T e 15.8 Class `G' liner slur ry Mix method Batch mix Slur Volume 127 bbls /713 cf / 615 sx Class `G'/ 15.8 / 1.16 cf/sk. Casin Strin 7", 26#, L-80, BTC-M x TC-II Drillin liner Slurry Design Basis: Tail slurry: 648' of 7" x 8-1/2" annulus with 40% excess, plus ~80' of 7", 26#, shoe tract. Plus 150' of 7" x 9-5/8" annulus. Also 200' on top of liner hanger between drill i e and 9-5/8". Mud Push II: 50 bbls at 12 Tail Slur : Slur T e 15.8 Class `G' liner slur ry Mix method Batch mix Slur Volume 39 bbls / 218 cf / 187 sx Class `G'/ 15.8 / 1.17 cf/sk. Casin Strin 4-1/2", 12.6#, L-80, IBT-M Production liner Slurry Design Basis: Tail slurry: 2,964' of 4-1/2" x 6;1/8" annulus with 40% excess, plus ~80' of 4- 1/2 , 26#, shoe tract. Plus 150 of 4-1/2 x 7 annulus. Also 200 on top of liner han er between drill i e and 7". Mud Push II: 40 bbls at 10.5 Tail Slur : Slur T e 15.8 Class `G' liner slur ry Mix method Batch mix Slur Volume 78 bbls / 438 cf / 374 sx Class `G'/ 15.8 / 1.17 cf/sk. Surface and Anti-Collision Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. Wells G-18 is the closest well at 114' to the North. Close Approach Shut-in Wells: All wells pass major risk close approach criteria except D-07A, G-21 and G-11A. All three collision issues are in the production zone. The D-07A is at 11,100' MD, the G-21 is at 11,654' MD and the G-11A is at 13,455'. Their respective center to center are 739', 470' and 1,085'. All three wells should pass major anti-collision when re-gyroed. If they fail major anti-collision and pass minor anti-collision 1/200, the tolerable collision risk sheet will be completed. It maybe required to shut-in these wells prior to drilling the production section of G-196. Hydrogen Sulfide G-pad is not designated as an HZS site. Standard Operating Procedures for H2S precautions should still be followed at all times. Date of Well Name H2S Level Readin #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data (H2S alarms from rigs, etc.) G-18A No Data G-17 No Data G-21 No Data D-07A 20 m 8/6/05 G-02A 25 m 6/11/06 G-196 Drilling Program Page 4 C Faults There are only two planned fault crossings, both are small and in the production section. Fault #1 is at 12,700' MD with an estimated throw of i5' down to the South East and fault #2 is at 11,700' MD with an estimated throw of 10' down to the West. A number of faults are located in the near vicinity of the proposed well. The coordinates for these faults will be provided in the directional plan details. The risk of fault and fracture associated lost circulation is considered low. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams, blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: Well Interval: 8-1/2" intermediate interval to TSGR Maximum antici ated BHP: 3,848 si at 8,409' tvd Maximum surface ressure: 3,007 si based u on BHP and a full column of as from TD (~ 0.10 si/ft Calculated kick tolerance: Infinite with 12 EMW FIT Planned BOPE test ressure: 250 si low / 3,500 si hi h - 14 da test c cle Drillin o erations Well Interval: 6-1/8" horizontal roduction interval in Ivishak Zone 1 B Maximum antici ated BHP: 3,241 si at 9,033' tvd Maximum surface pressure: 2,338 pSl (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: Infinite with 10.0 EMW FIT Planned BOPE test ressure: 250 si low / 3,500 si hi h - 14 da test c cle Drillin o erations Planned com letion fluid: 8.8 seawater / 7.1 Diesel BOPE and drilling fluid system schematics are currently on file with the AOGCC. Disposal Annular No annular injection in this well. In~ection: Cuttings Cuttings generated from drilling operations are to be hauled to the Grind and Inject Handlin station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 for Handlin injection. All Class I wastes are to be hauled to Pad 3 for dis osal. G-19B Drilling Program Page 5 • • Drilling Hazards and Contin~ encies POST THIS NOTICE IN THE DOGHOUSE Well Control A 10.8 ppg mud weight is required to kick off in the Kingak D formation. The Ivishak is expected to be under pressured at 6.9ppg EMW. II. Lost Circulation/Breathing The risk of fault and fracture associated lost circulation is considered medium to low. Follow the LCM decision tree if losses occur in the intermediate section. Swap to seawater if losses are encountered in the production hole after consulting with the ODE. III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for the intermediate hole section is infite with 10.8 ppg mud, 12.0 ppg FIT, and an 8.3 ppg pore pressure at the top of the Sag River. This FIT should prove up adequate formation strength for expected ECD's. B. The Kick Tolerance for the production hole section is infinite with 8.5 ppg mud, 10.0 ppg FIT, and an 6.9 ppg pore pressure. This FIT should prove up adequate formation strength for expected ECD's. C. Integrity Testing Test Point Test De th Test a EMW Ib/ al 9-5/8" KOP 20-ft from the 9-5/8" KOP FIT 12.0 minimum 7" shoe 20-ft from the 7" shoe FIT 10.0 minimum IV. Stuck Pipe A. Pipe sticking tendency is possible if the HRZ shale give problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. B. Monitor cuttings closely and adjust mud weight accordingly to avoid destabilization. C. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide G-Pad is not designated as an H2S site. The maximum H2S reading on G-Pad is 25 ppm. Standard Operating Procedures for H2S precautions should still be followed at all times. VII. Faults There are only two planned fault crossings, both are small and in the production section. Fault #1 is at 12,700' MD with an estimated throw of 15' down to the South East and fault #2 is at 11,700' MD with an estimated throw of 10' down to the West. A number of faults are located in the near vicinity of the proposed well. The coordinates for these faults will be provided in the directional plan details. The risk of fault and fracture associated lost circulation is considered low. VIII. Anti-Collision Issues Close Approach Shut-in Wells: All wells pass major risk close approach criteria except D-07A, G-21 and G-11A. All three collision issues are in the production zone. The D-07A is at 11,100' MD, the G-21 is at 11,654' MD and the G-11A is at 13,455'. Their respective center to center are 739', 470' and 1,085'. All three wells should pass major anti-collision when re-gyroed. If they fail major anti-collision and pass minor anti-collision 1/200, the tolerable collision risk sheet will be completed. It maybe required to shut-in these wells prior to drilling the production section of G-19B. Consult the G-Pad Data sheet for Additional information. G-196 Drilling Program Page 6 • • G-19B Operations Summary Pre-Rip Work: 1. Bleed casing and annulus pressures to zero. 2. Cycle all LDS, repair or replace as needed. 3. Kill well with 9.8ppg brine. Freeze protect well with diesel. 4. Jet cut tubing at 37' with a-line. 5. Set a BPV and test to 1000 psi from tubing annulus (or maximum allowable up to 1000 psi). 6. Secure the well. Level the pad as necessary. Rig Operations: 1. MI/RU Nabors rig 7ES. Pull BPV. 2. Set and re-test TWC to 1,000 psi. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull TWC. 4. Fish tubing hanger and cut stub. 5. RIH with wash-over pipe/outside cutter. Wash-over tubing stub 90' to swallow collapsed pipe. 6. Cut tubing below collapse and POOH with fish. 7. RIH with overshot on 5" drillpipe. Latch tubing stub. 8. Attempt to pull 4-'/z" tubing from the SBR at 10,168' (80% Yield = 231,000 Ibsf). 9. RU wireline. Punch tubing in the first full joint above the SBR TBG seal assy at 10,183'. 10. Circulate well to seawater. 11. RIH with jet cutter and cut tubing at ± 10,173'. 12. Recover tubing fish. 13. RIH with EZSV squeeze packer on DP and set at 10,163'. 14. Pump 18.5 bbls of cmt to fill tbg/csg, squeeze 24.2 bbls into perfs, unsting from packer and lay 7.3 bbls (100') on top of squeeze packer. POOH. 15. RIH w/ 8-'/z" gauge ring /junk basket to top of cement 10,063'. 16. RIH with HES EZSV bridge plug on E-line and set at 10,022' md, as required to avoid cutting a casing collar while milling the window. POH. R/D E-line. 17. Run USIT in 95/8" casing from surface csg shoe 02,705' up to surface, run in corrosion and cement mode. POOH. R/D E-line. 18. String shot 95/8" casing at back off point (2,152' or where USIT indicates TOC) to ease break out. RD a-line. 19. Change out to 9-%" rams, and test doors. 20. MU a Baker 9 b/8' cutting assembly. RIH picking up DP. Cut the 9 5/8" casing per Baker representative instructions. Cut ~4' above the string shot casing collar. POOH, VD assembly. 21. BOLDS, RU/MU casing spear assembly, and unseat the 95/8". Circulate the Arctic Pack from the annulus with warm diesel followed by seawater and detergent sweeps. Pull the 9-5/8" casing from the cut. 22. MU Wash over assembly, and 13 3/s' casing scraper. 23. RIH, Clean out the 13 3/e" casing, and the 9-5/8" casing stub, POOH, UD the assembly. 24. RU BKR back-off assembly, RIH, and back off the 9 8/8' casing joint. POOH, UD assembly. 25. MU casing spear assembly, RIH, recover cut stub. POOH. 26. MU 9-5/" ES Cementer on screw in sub and RIH w/ new 9 5/8", Hydril 563 casing. 27. Nipple down BOPE. 28. Weld on 9-5/8" FMC starting head. 29. Nipple up and test BOPE. ~~~ 30. Shear open ES cementer and cement 9 8/8" x 13 '/8" annulus w/ 126 bbls class G 15.8ppg cement with Latex (2,152'of133/8"x95/a". ~j~~ 31. PU 4" DP and mill tooth bit. Make clean out run through the ES Cementer. 32. Pressure-test the 9-5/8" casing to 3,500 psi for 30 minutes. Record test. 33. Change BOP rams back to VBR's and test. ~ 34. P/U and RIH with 95/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on EZSV bridge plug. Shear off of whip stock. 35. Displace the well to 10.8 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 36. Mill window in 9-8/8" casing at ± 10,000' MD, plus approxmat~~Or beyon mi e o wm ow- Circulate well bore clean. 37. Pull up into 95/8" casing and conduct an FIT to 12.0 ppg EMW. POOH. ~ 38. M/U 8-~h" Dir/GR/Res assembly. RIH, kick off and drill the 8-'h" intermediate section to the top of the /~`~ ~ Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. ~ ,~,~. ~~`~ G-19B Drilling Program Page 7 • • 39. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. 40. Test the 9 5/8" casing X 7" liner to 3,500psi for 30 minutes. Record the test. 41. M/U 6 1/8" Dir/GR/Res/ABI assembly. RIH to the landing collar. 42. Drill out the 7" liner float equipment and cement to the shoe. 43. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 44. Drill out the 7" shoe plus drill ~20' new formation; pull up into the shoe and conduct an FIT to 10.0 ppg EMW. Drill ahead to horizontal landing point. POOH for bit / BHA change. PU Neu/Den. 45. RIH, drill horizontal section to planned TD, short trip as necessary. 46. Circulate, short trip, spot liner running pill, POOH. 47. Run and cement a 4-~h", 12.6#, L-80 solid production liner. POOH VD all drill pipe. 48. RIH with 2-'/z" pert guns and perforate ±800'. 49. R/U and run 4-~h", 12.6#, L-80 completion tubing. Land the tubing RILDS. 50. Reverse circulate seawater and corrosion inhibitor. Drop the ball and rod, set the packer. 51. Individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 52. Pressure up on annulus to shear the DCK valve. Confirm two-way circulation. 53. Set a TWC and test to 1000 psi. 54. Nipple down the BOPE. Nipple up the tree and test to S,OOOpsi. 55. Pull TWC. Reverse in sufficient diesel to freeze protect to 2,200' TVD. U-tube. 56. Install BPV and test. Secure well. RDMO. Post-Rig Operations: 1. MI / RU slick line. 2. Pull the ball and rod / RHC plug from landing nipple below the production packer. 3. Install well house and instrumentation. G-19B Drilling Program Page 8 TREE= ~ 4" CAMERON WELLHEAD= _ _ McEVOY ACTUATOR=~ -__._ _ AXELSO N ti _ KB. ELEV = _ _ __~ 67.06' BF. ELEV = v~ ~ 40.41' KOP = _ _ ~ ~~ 2000' Max Angle = Datum MD =-~~ _ ~ 95 ~ 11622' ~~-~~~~~11250' Datum TV D =~~ 8800' SS ~ G-19A 13-3/8" CSG, 72#, L-80, ID = 12.347" I-I 2705' Minumum ID = 2.37" @ 10247' 2-7/8" LINER TOP, PIN ID TOP OF 2-7/8" LNR ~-i 10247' I4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 10291' TOP OF 7" LNR 10340' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10595' 12480' I~ FISH -POSSIBLE JUNK MILLOLfT WINDOW 11253' - 11259' TOP OF WHIPSTOCK ~ 11250' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" PERFORA TION SUMMA RY REF LOG: MWD GR ON 01 /02/99 ANGLEATTOPPERF:62° ~ 11355' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL OPN/SQZ DATE 2 6 11355 - 11375 O 02/13/02 2 6 11513 - 11535 O 02/13/02 2 6 11535 - 11560 O 02!13/02 2 4 11619 - 11830 O 11 /04/99 2 4 11880 - 11970 O 11 /04199 2 4 12005 - 12045 O 11 /04199 2 4 12170 - 12400 O 11/04/99 2 4 12440 - 12529 O 11/04/99 2 4 12584 - 12642 O 11/04/99 12687' I-~ MILLED CIBP (617/03) I ~ SAFETY : 70° ~ 11491' AND 90° ~ 11588'. POSSIBL BSTRUCTION IN LINER ~ 12480' (SEE 6/25/03 AWGRs) 2070' 4-1/2" SSSV OTIS LANDING NIP, ID = 3.813" 10107' I~ 4-1/2" OTIS XA SLIDING SLV, ID = 3.813" 10168' I-i sBR TBG SEAL Asst 10183' -1 9-5/8" X 4-1/2" HBBPTMJ PKR, ID = 4.75" 10225' 4-1 /2" OTIS X NIP, ID = 3.813" 10247' 2-7/8" BKR DEPLOY MENT S UB, ID = 3.000" 10258' 4-1/2" OTIS XN NIP, ID = 3.725" 10291' 4-1/2"TUBING TA IL 10302' ELMD TT LOGGED 05/06/90 PBTD H 12691' 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" I--I 12758' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/29/86 ORIGINAL COMPLETION 12105/OS CJA/PAG TNV PACKER CORRECTION 11(04!99 CTDSIDETRACKCOMPL 02/01/02 RN/TP CORRECTIONS 02/17/02 JAF/TLH ADD PERFS 06!07/03 DBM(TLH MILL CIBP 06/25/03 SRB/KK FISH PRUDHOE BAY UNIT WELL: G-19A PERMff No: 1991030 API No: 50-029-21599-01 SEC 12, T11 N, R13E, 3744' SNL &3003' WEL BP Exploration (Alaska) TREE= ~ 4" CAMERON WELLHEAD= McEVOY ACT UA TOR = ~ AXELSON _~ __M _ _ KB. ELEV = ~ 67.06' BF. ELEV = __ KOP =_ _ ~ 40.41' ~_ _ _ 2000' __ Max Angle = ~_~ ~ _ ~95 ~ i 1622' ^~ Datum MD = __ Datum TV D = _ 11250' ~ 8800' SS G -1 A p re -rig SAFETY : TxIA communication. Occasional crude to su ace thru fluted suit csg hgr 3T Pre-rig tubing cut i, 42' Collapsed tubing (< 1.5" restriction) 2070' 4-1/2" SSSV OTIS LANDING NIP, ID= 3.813" 13-318" CSG, 72#, L-80, ID = 12.347" I-i 2705' Minumum ID = 2.37" ~ 10247' 2-718" LINER TOP, PIN ID TOP OF 2-7/8" LNR I-I 10247' I4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 10291' TOP OF 7" LNR 10340' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10595' I I 10107' -i 4-112" OTIS XA SLIDING SLV, ID = 3.813" 10168' SBR TBG SEAL ASSY 10183' ~-j 9-518" X 4-112" HBBPTMJ PKR, ID = 4.75" 10226' 4-1/2" OTIS X NIP, ID = 3.813" 10247' 2-7/8" BKR DEPLOY MENT S UB, ID = 3.000" 10258' 4-1/2" OTIS XN NIP, ID = 3.725" 10291' 4-1/2" TUBING TAIL 10302' ELMD TT LOGGED 05/06/90 MILLOUT WINDOW 11253' - 11259' TOPOFWHIPSTOCK ~ 11250' 7" LNR, 26#, L-80, .0383 bpf. ID = 6.276" -r 11253' PERFORAl10N SUMMARY REF LOG: MWD GR ON 01 /02/99 ANGLEATTOPPERF:62° ~ 11355' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL OPNJSOZ DATE 2 6 11355 - 11375 O 02/13/02 2 6 11513 - 11535 O 02/13/02 2 6 11535 - 11560 O 02/13/02 2 4 11619 - 11830 O 11/04/99 2 4 11880 - 11970 O 11/04/99 2 4 12005 - 12045 O 11 /04199 2 4 12170 - 12400 O 11 /04/99 2 4 12440 - 12529 0 11 /04/99 2 4 12584 - 12642 O 11 /04/99 12480' I~ FISH -POSSIBLE JUNK (6/26103) I ~ 12687' I-I MILLED CIBP (6/7/03) ~ ~ PBTD H 12691' 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" ~--~ 12758' DATE REV BY COMMENTS DATE REV BY COMMENTS 08129/86 ORIGINAL COMPLETION 12/05/05 CJA/PAG TMJ PACKER CORRECTION 11104!99 CTD SIDETRACK COMPL 07/20/07 RLP Pre-Rig Cut X37' 02/01/02 RN/TP CORRECl10NS 02/17/02 JAF/TLH ADD PERFS 06/07/03 DBM/TLH MILL CIBP 06/25/03 SRBJKK FISH PRUDHOE BAY UNIT WELL: G-19A PERMIT No: 1991030 API No: 50-029-21599-01 SEC 12, T11 N, R13E, 3744' SNL & 3003' WEL BP Exploration (Alaska) TREF = 4" CAMERON yVELLHEAD= McEVOY ACTUATOR = AXELSON KB. E1EV = 66.36' BF. E1EV = 40.41' KOP = _ 9950 Max Angle = M~ ____ _.__._._ Datum MD = DatumND= i G-19~ Proposed • 2,152 HES ES Cementer/ 9-5/8", L-80, Hydril 563 2,200 4-112" X LANDING NIP, ID = 3.813" 2,705 13-3/8", 72#, L-80, ID=12.347" 9,850 9-S/8" X 7" Baker HMC liner hanger, ZXP Inr top packer 10,100 7",26#, TGII x-over BTGM LNR 9-518" Window 10000'-10019' EZSV CIBP 10022' Top Of Cement 10063' EZSV Squeeze PKR 10163' Tubing cut 10173' 9-5/8'k4-1/2" TIWPKR 10183' TOP OF2-7/8" LNR 10247' TOP OF 7" LNR 10340' 4-1/2" TBG, 12.6#, L-80,ID=3.958" 10291' 9-518", 47#, L-80, ID = 8.681" 10595' 7" LNR, 26#, L-80, ID = 6.276" 11253' 2-7/8" LNR, 6.16#, L-SO,ID=2.441" 12758' 10,424 41/2"'X' Landing Nipple, ID=3.813" 10444' 7" X 4-112" Baker S-3 PKR 10,464 4 1/2"'X' landing Nipple, ID= 3.813" 10,484 4 112" 'XN' Landing Nipple, ID = 3.725" 10,498 41/2",12.6#, 13Cr-80, VamTop 10,498 7" X 4-112" Baker HMC liner hanger, ZXP Inr top packer w / TBS 10848' 7" , 26#, L-80, BTGM liner 13612' 4-1/2" , 12.6#, L-80,IBT-M, LNR DATE REV BY COMMENTS DATE REV BY CCMAMENTS 10/03/06 PGS Proposed Compl. (Wp02) 05/08/07 RLP Updated 07/01/07 RLP Proposed Compl. (Wp09) PRUDHOE BAY UNtr WELL: G-19B PERMff No: API No: 50-029-2159.9-02 SEC 12, 711 N, R13E, 3744' SNL & 3003' WEL BP Exploration (Alaska) by G-19B (P9 Report Date: June 27, 2007 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure I Slot: WeN: G-PAD I G-19 ~~'~~ G-19 Borehole: ~~ Plan G-19B ~e ~ UWIIAPI#: r 500292159907 Survey Name I Date: G-196 (P9) I June 27, 2007 Tort I AHD 1 DDI 1 ERD ratio: 241.173° 18326.23 ft / 6.481 10.922 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location Latllong: N 70.31898429, W 148.72521013 Location Grid NIE YIX: N 5967883.000 ftUS, E 657248.000 ftUS Grid Convergence Angle: +1.20034195° Grid Scale Factor: 0.99992809 Schlumberger osal Survey 1 DLS Computation Method: Minimum Curvature I Lubinski Vertical Section Azimuth: 60.600° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 68.91 ft relative to MSL Sea Bed 1 Ground Level Elevation: 40.41 ft relative to MSL Magnetic Declination: 23.663° Total Field Strength: 57653.258 nT Magnetic Dip: 80.922° Declination Date: August 01, 2007 Magnetic Declination Model: BGGM 2007 North Reference: True North Total Corr Mag North -> True North: +23.663° Comments Measured Inclination Azimuth Subsea TVD TVD Vertical NS EW Gravity DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty n de de n n n n ft de de 100 n Index nUS nUS I ie-In survey TJD Top Whipstock Base Whipstock KOP Crv 4/100 TJC End Crv TJB TSAG 7" Csg Pt Crv 15/100 TSAD aavl.ao Ja.n/ L~+.~u !//4. la 9993. 03 38.61 254.77 7846. 00 10000. 00 38.60 254.79 7851 .44 10016. 00 40.41 253.78 7863. 79 10028. 00 40.41 253.78 7872 .93 10100. 00 40.33 249.34 7927. 79 10200. 00 40.51 243.17 8003 .95 10254. 07 40.74 239.87 8045. 00 10300. 00 41.01 237.09 8079 .73 10387 .04 41.70 231.92 8145 .09 10416. 39 41. 70 231. 92 8167.00 10634. 68 41. 70 231. 92 8329.99 10648 .09 41 .70 231 .92 8340.00 10648. 10 41. 70 231. 92 8340.01 10668 .09 41 .70 231 .92 8354.93 10700 .00 37 .08 229 .95 8379.59 10750 .00 29 .93 225 .83 8421.26 10779. 12 25. 84 222. 50 8447.00 10800 .00 22 .97 219 .46 8466.01 10850 .00 16 .48 208 .20 8513.07 10900 .00 11 .25 185 .20 8561.63 10950 .00 9 .65 143 .81 8610.87 /C4J.OJ -oloa.// -lalaua walu.lc 7914.91 -5224.01 -1830.13 -4965.02 7920.35 -5228.22 -1831.27 -4969.21 7932.70 -5238.11 -1834.03 -4979.01 7941.84 -5245.69 -1836.20 -4986.48 7996.70 -5291.45 -1850.95 -5030.69 8072.86 -5355.90 -1877.03 -5089.98 8113.91 -5391.10 -1893.82 -5120.92 8148.64 -5421.12 -1909.53 -5146.53 8214.00 -5478.26 -1942.91 -5193.31 8235.91 -5497.56 -1954.95 -5208.67 8398.90 -5641.11 -2044.50 -5322.98 8408.91 -5649.92 -2050.00 -5330.00 8408.92 -5649.93 -2050.01 -5330.01 8423.84 -5663.07 -2058.20 -5340.47 8448.50 -5683.03 -2070.95 -5356.20 8490.17 -5709.94 -2089.36 -5376.71 8515.91 -5723.01 -2099.11 -5386.22 8534.92 -5731.14 -2105.61 -5391.88 8581.98 -5746.24 -2119.42 -5401.45 8630.54 -5755.01 -2130.54 -5405.24 8679.78 -5757.29 -2138.79 -5403.21 I IU./ IR 110.50R 20.00E 93.22E 89.83E 85.14E 82.63E 80.53E 165.59E 164.06E 160.61 L 157.67E 154.90E 144.28E 121.91 L 81.15E U.BV V./U .7.7V.7~V.7.VJ VJLJ!l.J4 IV /V.J I4VL IJ4 VY 140.l 04`77~OL 0.20 5.70 5965949.40 652322.78 N 70.31398003 W 148.76544443 0.20 5.70 5965948.18 652318.61 N 70.31397691 W 148.76547841 12.00 5.71 5965945.21 652308.87 N 70.31396935 W 148.76555779 0.00 5.71 5965942.89 652301.45 N 70.31396340 W 148.76561830 4.00 5.73 5965927.22 652257.55 N 70.31392304 W 148. 76597655 4.00 5.76 5965899 .90 652198.83 N 70.31385166 W 148. 76645683 4.00 5.77 5965882. 47 652168.26 N 70.31380575 W 148. 76670743 4.00 5.79 5965866 .23 652142.98 N 70.31376278 W 148. 76691489 4.00 5.81 5965831 .87 652096.91 N 70.31367150 W 148. 76729378 0.00 5.81 5965819. 52 652081.80 N 70.31363858 W 148. 7674 0.00 5.82 5965727. 60 651969.41 N 70.31339372 W 148. 1 7683 0.00 5.82 5965721 .95 651962.50 N 70.31337868 W 148. 7684 0.00 5.82 5965721. 95 651962.50 N 70.31337866 W 148. 76840090 0.00 5.82 5965713 .53 651952.21 N 70.31335624 W 148. 76848565 15.00 5.85 5965700 .46 651936.75 N 70.31332140 W 148. 76861304 15.00 5.88 5965681 .62 651916.63 N 70.31327105 W 148. 76877915 15.00 5.90 5965671. 68 651907.33 N 70.31324441 W 148. 76885609 15.00 5.91 5965665 .06 651901.81 N 70.31322663 W 148. 76890197 15.00 5.94 5965651 .06 651892.53 N 70.31318890 W 148. 76897939 15.00 5.97 5965639 .87 651888.97 N 70.31315851 W 148. 76901010 15.00 5.99 5965631 .66 651891.18 N 70.31313598 W 148. 76899357 WeIlDesign Ver SP 2.1 Bld( doc40x_100) G-19\G-19\Plan G-196\G-19B (P9) Generated 6/27/2007 10:56 AM Page 1 of 2 Comments Measured Inclination Azimuth Subsea ND ND Vertical NS EW Gravity DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face pifficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS tno Lrv 1 Vyby.l3 `J.`JD TCGL / TZ3 10959.27 9.95 BCGL / TZ2 11020.18 9.95 Crv 18.6/100 23S8 22TS 21 TS TZ18 HOT Tgt 1 /Crv 10/100 End Crv Fault Crossing Crv 10/100 Tgt 2 End Crv Fault Crossing TD / 4-1 /2" Lnr 11025.31 11050.00 11072.45 11100.00 11135.87 11150.00 11194.89 11200.00 11250.00 11300.00 11327.77 11350.00 11400.00 11450.00 11480.87 11483.32 11500.00 11550.00 11600.00 11650.00 11650.50 11730.00 12187.91 12200.00 12231.14 12232.90 12570.00 13611.70 9.95 12.80 16.09 20.57 26.74 29.22 37.24 38.16 47.23 56.35 61.43 65.51 74.69 83.87 89.55 l 3b.yb 135.96 135.96 135.96 117.47 107.12 99.12 92.72 90.91 86.64 86.25 83.16 80.86 79.79 79.01 77.41 75.94 75.07 Ob 1 `J.Ob 8620.00 8680.00 8685.05 8709.26 8731.00 8757.15 8790.00 8802.48 8840.00 8844.04 8880.76 8911.66 8926.00 8935.93 8952.93 8962.22 8963.99 25b025.// -b/O/.UU -L~13`J.`J/ -b4VL.Ll 8688.91 -5756.99 -2139.99 -5402.19 8748.91 -5754.33 -2147.55 -5394.88 8753.96 -5754.11 -2148.19 -5394.26 8778.17 -5752.08 -2150.99 -5390.35 8799.91 -5748.57 -2153.05 -5385.17 8826.06 -5742.16 -2154.94 -5376.74 8858.91 -5730.38 -2156.33 -5362.44 8871.39 -5724.71 -2156.53 -5355.81 8908.91 -5703.00 -2155.91 -5331.25 8912.95 -5700.19 -2155.72 -5328.13 8949.67 -5669.25 -2152.51 -5294.42 8980.57 -5632.70 -2147.01 -5255.57 8994.91 -5610.32 -2143.01 -5232.14 9004.84 -5591.50 -2139.35 -5212.60 9021.84 -5546.73 -2129.73 -5166.63 9031.13 -5499.58 -2118.41 -5118.88 9032.90 -5469.81 -2110.70 -5089.06 9032.91 -5467.44 9032.90 -5451.22 9032.78 -5402.03 9032.53 -5352.26 9032.13 -5302.28 9032.12 -5301.77 9031.38 -5222.34 9027.11 -4764.83 9027.01 -4752.75 9026.91 -4721.74 9026.91 -4719.99 9026.91 -4385.24 9026.91 -3350.82 -2110.07 -2105.52 -2089.11 -2068.65 -2044.29 -2044.03 -2002.24 -1761.57 -1755.11 -1737.49 -1736.45 -1537.47 -922.60 -5086.69 -5070.64 -5023.43 -4977.83 -4934.18 -4933.75 -4866.12 -4476.59 -4466.37 -4440.70 -4439.27 -4167.16 -3326.30 -- Ib.VV O.UU JyObbJU.bU OJ IO~L.LU IV lU.J IJ IJL/W VV I~iO.l OO~Ob40 -- 0.00 6.00 5965630.48 651892.22 N 70.31313270 W 148.76898532 --- 0.00 6.00 5965623.07 651899.69 N 70.31311204 W 148.76892599 61.33E 0.00 6.00 5965622.45 651900.32 N 70.31311030 W 148.76892099 43.19E 18.60 6.01 5965619.73 651904.29 N 70.31310267 W 148.76888929 33.16E 18.60 6.03 5965617.78 651909.51 N 70.31309704 W 148.76884730 25.56E 18.60 6.04 5965616.06 651917.98 N 70.31309189 W 148.76877894 19.69E 18.60 6.06 5965614.98 651932.30 N 70.31308814 W 148.76866307 18.09E 18.60 6.07 5965614.91 651938.93 N 70.31308759 W 148.76860940 14.51E 18.60 6.09 5965616.05 651963.47 N 70.31308934 W 148.76841037 14.20E 18.60 6.10 5965616.31 651966.58 N 70.31308987 W 148.76838511 11.92E 18.60 6.12 5965620.22 652000.22 N 70.31309869 W 148.76811 10.49E 18.60 6.15 5965626.53 652038.94 N 70.31311380 W 148.76779 9.94E 18.60 6.16 5965631.02 652062.28 N 70.31312478 W 148.76760733 9.59E 18.60 6.17 5965635.09 652081.74 N 70.31313481 W 148.76744900 9.04E 18.60 6.20 5965645.67 652127.49 N 70.31316117 W 148.76707657 8.77E 18.60 6.22 5965657.99 652174.99 N 70.31319218 W 148.76668971 8.72E 18.60 6.24 5965666.32 652204.65 N 70.31321331 W 148.76644806 88.14E 18.60 6.24 5965667.00 652207.00 N 70.31321504 W 148.76642890 88.14E 10.00 6.24 5965671.89 652222.95 N 70.31322750 W 148.76629888 88.15E 10.00 6.26 5965689.28 652269.80 N 70.31327242 W 148.76591639 88.18E 10.00 6.27 5965710.69 652314.97 N 70.31332840 W 148.76554696 88.22E 10.00 6.29 5965735.95 652358.09 N 70.31339501 W 148.76519340 -- 10.00 6.29 5965736.22 652358.51 N 70.31339573 W 148.76518993 --- 0.00 6.30 5965779.41 652425.24 N 70.31351000 W 148.76464215 97.09E 0.00 6.34 5966028.18 652809.62 N 70.31416818 W 148.76148676 97.10E 10.00 6.35 5966034.85 652819.70 N 70.31418585 W 148.76140399 90.00E 10.00 6.36 5966053.00 652845.00 N 70.31423401 W 148.76119603 --- 10.00 6.36 5966054.07 652846.40 N 70.31423685 W 148.761 --- 0.00 6.39 5966258.69 653114.26 1 N 70.31478087 W 148.7589 -- 0.00 6.48 5966891.00 653942.00 N 70.31646182 W 148.75216 90.00 75.00 8964.00 90.05 73.33 8963.99 90.22 68.34 8963.87 90.38 63.34 8963.62 90.53 58.34 8963.22 90.53 58.29 8963.21 90.53 58.29 8962.47 90.53 58.29 8958.20 90.39 57.09 8958.10 90.00 54.00 8958.00 90.00 53.82 8958.00 90.00 53.82 8958.00 90.00 53.82 8958.00 WeIlDesign Ver SP 2.1 Bld( doc40x_100) G-19\G-19\Plan G-196\G-196 (P9) Generated 6/27/2007 10:56 AM Page 2 of 2 by Schlumberger 'NELL fIELU STRUCTURE G-19B (P9) Prudhoe Bay Unit - WOA G-PAD Fbgneuo Peraloulnr~ Surlxe LO,:alnn NADl/ Ma.ka Sla{o PNnu+. 2unr ~~ U Mla,:uNaII,Y)11~ Mwlel. BGGM 2001 Dip NC 922" Oa{e ~I 100i LaL 9 ~ u ~ ,or uiiv 'tUCYt~ Slw „u Np RO' ~ .ni,. vlnal...~M~Li Mrvy Doc -2]bfil' LS .,lloi W1a54B 101155 Ca- 4 Pay t•IB iP,~i .V Daul r -6400 -6000 -5600 -5200 -4800 -4400 -4000 -3600 -3200 7600 6000 O 0 v C ii 6400 0) N U H 6600 9200 G-19 . , .... ...... ...... ...r.. ~ Tie•In Survey Top Whipstock Basa Whipstock KOP Crv 4/700 ._.._.._ _._..-..-..-..-..-..-..- -.-..-..-..-..-..-..-..- -.. _.._.._.._.._.. ~D ._..-..-..-..-..-.._ _.._.. _.. _.._.._.._.._ -..-..-..-..-..-..-..- .-..-..-..-.. _.. _.._.._ .. _.._.._.._.._.. _.. _.._ ............... i..................................;...................................i......................... .......i..................................i..................................-i..................................j..................................i.................................. y ._.. _.._ _ ._..-..-..-..-..-..-.._.j. .-..-..-..-..-..-..-End'Crv .._..- ~..-..-. -........-..-......... .........-..-..-..-..- -..-..-..-..-..-..-..- .-..-..-.............. ..-..-..-..-..-..-..-..- ._.._.._ ~ ._.,-..-..-..-..-..-.._.~_.._.._.._.._.._.._.._,._~,_,_ ~_._.._.._..-..y.-..-.....-..-..-..-..-.y..-.._.._.._.._.._..-..-..i..-..-..-..-.....-..-.. .q...-..-..-..-.._.._.._..-.~-..-..-..-..-..-..-..-.. _.. 7" Csg Pt Crv 15/100 TSAG TSAD End Crv .-..-.. ._..-..-..-..-..-..... .~_ •-'YC' Ili. .._.. _.._..-..-..-..-..-..-...~.-..-..-..-..-..-........:..-..-..-..-..-..-..-..- .*. -..-..-..-..-..-..-.. .-..-..-..-..-..-.._..-.j-..-.._.._.._.._.._.._.._i. .-..... .............-..-..-.. .i- .- CAL%T ,Crv 18.6N 00. .......... .................-.....i. -..-..-..-..-..-..-..- .i.. -..-..-..-..-..-..-.. ._..-.._.._.._.._.._..-.i-..-..-.....-..-..-..-..- .._..-..-..r..-.._.._.._.._.._.._.. ~_.._.._.._. _.._.._<._.._.. ?~t.1L&=.?s!144._._.._.._.._.._.._.._.._.o.._..-.._.._..-..-..-..-...._.._.._.._.._.._.._.._.,~.._.._.._.._.._.._.._.._._.._.._.._.._.._.._,._.._. ~2T?i End Cry Fault Crossing Crv 10110 : Tgt 2 End Crv : FauH Crossing TD 14112" Lnr .._.._..-..i..-..-..-..-..-..-.. -.i_..-..-..-....._.. ...._:._.._.. .-..-..-.. .. -..-. .-..-..-..-..-..-..- _..-........-..- -..-..-..-..-........ .-..-..-..-..-..-..-.. ..-.._.._. _.._.._.. 21TS ~. _.. _,. _,.y.._........... ~ ~-..-..-.-..-..-.. ..-.. ........,..............,.r. ... ,.-..-..............~ .-......................Q...-..-..-..-..-..-..-..-.j-..-..-..-..-. ..-..-..-1. -19 ...............:..................................:.................................. ..................................j..................................:...................................;..................................i..................................i.................................. ;. -6400 -6000 -5600 -5200 -4800 -4400 -4000 Vertical Section (ft) Azim = 60.6°, Scale = 1(in):400(ft) Origin = 0 N/-S, 0 E/-V 7600 6000 6400 6600 9200 -3600 -3200 by Schlumberger wE« G-196 (P9) F,E~o Prudhoe Bay Unit - WOA srA~~ r~R~ G-PAD Mayi~eu~P~r + u.x.a <~u un r.,;[._ ~~~. ~..~~IW..., c~.i~n 5fna iv.e n..i~. A1o~u 6~~M tfXl~ pV tl09YL' Date. Puyu~t u~ 1 / ~ ~ . .... ~ i _~ ~ ~ 'o ~- ND Rai o .rv Try ~~ nn S' ~W, ire M~~ R Mag Oer. ~2i fio3" FS 5l6S]3 nT W 2 Cap ~ Fn -t.56 if'v~ ~rvy Da= -800 ~ -1200 n Z `o 0 v c -1600 a~ m U V V v -2000 -2400 6000 -5600 -5200 -4800 -4400 -4000 -3600 -3200 -2800 6000 -5600 -5200 -4800 -4400 -4000 -3600 -3200 -2800 «< W Scale=1(in):400(ft) E »> 800 1200 1600 2000 2400 BP Alaska Anticollision Report r t;ompanye BP Amoco ~ Date: 6!27/2007 Time: 11104:51 Paged. 1 ', Field: Prudhoe Bay. Reference Site: PB G Pad Co-ordinate(NE) Reference: WeIL G-19, True North Reference Well: G-19 Vertical (TVD) Reference: - G-19B Plan 68.9 '. Reference Wellpath: Plan G-19B Dlr: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are >t~Qli'Boeells in thisRltildlpal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Range: 10000.00 to 13611.70 ft Scan Method: Trav Cylinder North Maximum Radius:10000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 6/21/2007 Validated: No Version: 7 ', Planned From To Survey Toolcode Tool Name ', ft ft _-- - -- - 101.85 9901.85 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot ', 9901.85 10200.00 Planned: Plan #9 V2 BLIND Blind drilling 10200.00 10980.00 Planned: Plan #9 V2 MWD+IFR+MS MWD +IFR + Multi Station ', 10980.00 13611.70 Planned: Plan #9 V2 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in __ - - -- - -_ J - -- _ __ ---- -- ----_ 2706.50 2644.14 13.375 17.500 13 3/8" _ - 10000.00 7920.35 9.625 12.250 9 5/8" 10648.09 8408.91 7.000 8.500 7" 13611.70 9026.91 4.500 6.125 4 1 /2" Summary <-------- ---- DffseYWellpath -- -----s Reference Offset Ctr-Ctr No-Co Allowable Site Well Wellpath MD MD' Distance Area Deviation ft ft ft ft ft PB D Pad D-07 D-07 V2 12231.14 12445.00 962.33 1598.65 -636.33 PB D Pad D-07 D-07A V1 11116.46 12705.00 767.92 1164.39 -396.47 PB D Pad D-07 Plan 2, D-076 VO Plan: 11170.41 12105.00 1176.501122.55 53.95 PB D Pad D-28A D-28A V1 11650.50 11859.34 1129.20 902.41 226.78 PB D Pad D-28AL1 D-28AL1 V1 11616.73 11741.34 1229.37 904.98 324.39 PB G Pad G-10 G-10 V5 PB G Pad G-10 G-106 V2 PB G Pad G-11A G-11A V1 PB G Pad G-11 G-11 V1 PB G Pad G-15A G-15A V1 PB G Pad G-15 G-15 V1 PB G Pad G-16 G-16 V1 PB G Pad G-17 G-17 V7 PB G Pad G-17 G-17A V16 PB G Pad G-18A G-18A V3 PB G Pad G-18APB1 G-18APB1 V2 PB G Pad G-18 G-18 V1 PB G Pad G-19 G-19 V1 PB G Pad G-19 G-19A V2 PB G Pad G-21 G-21 V1 PB G Pad G-21 PB1 G-21 P61 V1 13335.99 10670.00 1109.531388.21 -278.67 12147.12 11485.00 1541.611809.29 -267.68 13611.15 11185.00 1776.131219.92 556.21 10440.31 10450.00 68.981638.97 -1569.99 11639.04 12758.00 183.981779.69 -1595.72 11653.55 13359.00 470.451084.47 -614.02 12274.96 12672.00 628.691042.33 -413.64 Warning FAIL: Major Risk FAIL: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range FAIL: Major Risk FAIL: Major Risk Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range FAIL: Major Risk FAIL: Major Risk FAIL: Major Risk FAIL: Major Risk • BP Alaska Anticollision Report - - Company: BP Amoco Date: 6!27/2007 Time: 11:10:35 Paget. 1 Fietd: Prudhoe Bay Reference Site: PB G Pad Co-ordinate(NE) Reference: WeII; G-19, True North '; Reference Welt: G-19 Vertical (TVD) Reference:. G-196 Plan 68.9 ' Reference Wellpath: Plan G-196 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are ff.NPli'Haeells in thisRtildlpal Plan & PLANNED PROGRAM ', Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse ', Depth Range: 10000.00 to 13611.70 ft Scan Method: Trav Cylinder North ', Maximum Radius:10000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath ---- Date: 6121/2007 Validated: No Version: 7 Planned From To Survey Toolcode Tool Name ft ft 101.85 9901.85 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot ', 9901.85 10200.00 Planned: Plan #9 V2 BLIND Blind drilling 10200.00 10980.00 Planned: Plan #9 V2 MWD+IFR+MS MWD +IFR + Multi Station ', 10980.00 13611.70 Planned: Plan #9 V2 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 2706.50 2644.14 13.375 17.500 13 3/8" 10000.00 7920.35 9.625 12.250 9 5/8" 10648.09 8408.91 7.000 8.500 7" 13611.70 9026.91 4.500 6.125 41/2" Summary -------- ----.Offset Wellpath ---- ------> Reference Offset ` Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area. Deviation.- Warning.. ft ft ft ft ft PB D Pad D-07 D-07 V2 12231.14 12445.00 962.33 0.00 962.33 Pass: Minor 11200 PB D Pad D-07 D-07A V1 11100.00 12905.00 738.92 0.00 738.92 Pass: Minor 1/200 ', PB D Pad D-07 Plan 2, D-07B VO Plan: 11170.41 12105.00 1176.501122.55 53.95 Pass: Major Risk ', PB D Pad D-28A D-28A V1 11650.50 11859.34 1129.20 902.41 226.78 Pass: Major Risk PB D Pad D-28AL1 D-28AL1 V1 11616.73 11741.34 1229.37 904.98 324.39 Pass: Major Risk PB G Pad G-10 G-10 V5 Out of range PB G Pad G-10 G-10B V2 Out of range ', PB G Pad G-11A G-11A V1 13454.98 10470.00 1085.41 0.00 1085.41 Pass: Minor 1/200 ', PB G Pad G-11 G-11 V1 12526.62 10930.00 1473.10 0.00 1473.10 Pass: Minor 1/200 PB G Pad G-15A G-15A V1 13611.15 11185.00 1776.131219.92 556.21 Pass: Major Risk PB G Pad G-15 G-15 V1 Out of range PB G Pad G-16 G-16 V1 Out of range ', PB G Pad G-17 G-17 V7 Out of range PB G Pad G-17 G-17A V16 Out of range PB G Pad G-18A G-18A V3 Out of range PB G Pad G-18AP61 G-18AP61 V2 Out of range PB G Pad G-18 G-18 V1 Out of range PB G Pad G-19 G-19 V1 10001.85 10000.00 0.00 0.91 -0.91 FAIL: NOERRORS PB G Pad G-19 G-19A V2 10001.85 10000.00 0.00 0.91 -0.91 FAIL: NOERRORS PB G Pad G-21 G-21 V1 11653.55 13359.00 470.45 0.00 470.45 Pass: Minor 1/200 PB G Pad G-21PB1 G-21PB1 V1 12274.96 12672.00 628.69 0.00 628.68 Pass: Minor 11200 • • FieldPrudhoe Bay SitePB G Pad We11:G-19 WellpathElan G-19B -940 900 600 300 0 2 300 600 900 940 n 0 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre t Alaska Department of Natural l~urces Land Administration System ~ Page 1 of ~' .: ~ { ., ,.,r.~ .,~.,:.~ I- ;; ~ ~ <.;'er`s S~aich State Cabins t+i~tura SaDUE't~5 sa base Summary File Type A~~__ _i File Number: 28280 ~ ~ Printable Case File_Summary See Township, Range, Section and Acreage? ~` Yes ~' No New Search [_AS Menu I Case Abstract ~ Case Detail ~ Land Abstract ti File: ~DL 2428(1 ''t`'~` Search for Status Plat Updates A of 09i 12/007 CZrslo~rtc r: 00010?377 BP E~iPLURATION (ALAS1ir1) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 78~ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISS/APPRV/ACTV/ RUTH Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Offcegf Primary Responsibility: DOG DIV OIL ANDGAS Last I~°ansaction Date: 12/04/2006 Case Sz+btype: S NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED lleridic~n: ~ T~nri~~hr~>: 01 lti~ R~rn~c~: 0] ~l: ,Scctiorl: 01 Seclin~t.-lcre~s: 6~0 Search Plats lc~r~rdi~rn.~ l_! Tuirnshij~: 01 I N Ran~re.~ 0l i L ,S`ectiuit: 02 S~c~ctiur7 _ a~~rc.~~: 6~0 l~~rrcliun.~ U %~najzshlJ>: O1 l N Rath>~~.~ 0131; S'c'c<<~,n.~ I 1 ,ti~c~~7ir,j7 Acj•c~.c: 6 ~0 llet~rdran.~ (1l ~nvn.~hii~: 01 I N Ran;~e: 013E S~ Ilion: I ? Sec~tinn Acres: Ei=I0 Lc al Descriptii~n OS-28-196 * * * SALE NOTICE LEGAL DESCRIPTION Cl ~- 91 TIIN, R13E, UM 1, 2, 11, 12 2, 560.00 07-07-1987 * * * LISBURNE PARTICIPATING AREA DESCRIPTION T. I 1 N., R.13 E., U.M. SECTION 1: ALL 640 ACRES SECTION 12: ALL 640 ACRES http://www.dnr. state. ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumbei =28280&... 9/ 12/2007 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~l/. ~e9L~ PTD# o~~~~i~~~ Development Service Exploratory Stratigraphic Test ^Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -~~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing exception... assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for !name of well) until after ~Compan~Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ,SCompany Name) must contact the Commission to obtain advance approval of such water well testing ro ram. 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' ~ c. ~~ n~ m. ? a a' o' , L, o' L~ a~ a c' °~ . ar I °~ y, ~ ~, - ° c ~ a d , w Z a~~ , , p ~, E. ° 3, °, •~ ~m •- a~ fl. d a ~ L' ~, • w, N. 3 -- 3 O Z ° m c, a, ;a . c `~ m `~ m, d 'm ° d °?. ~ 3 •3, a m ~, 16, a, E, ~ o . ~ . a~, ~, ~ ~ y 'v °-~ c 3; :: y, m m , , , , M y, L ~ ~ ar o o q ° 4 ~~ ~ ~ 3' `~~ o, o' 3 ~ ~~ ~ . _ >i `°' a~ °' c w ° O Q a' ' , a c, »_, , y , , a, a~, fl a, a , .. ~, o , . o . ar u i~ ~ m o - rn c , a y a~ o 4 H ~' o 14' ~' ` a ' a ~° n , v. o. ~, , ~, o ° , c, ~ o, o, ~ o, c Y, o ° ~ ' o, y, , o~ o' ~, ° o' ~ ' ' , ~ t/) ~ Q ' , °, '~ y, c ' . otf ~ L' n a r d d, d f6; ~ d N 01 N' N fl. y, `~~ y d d c ~, N, U ' o a ~ ~ ~ d 6 - /3 a N ~ O) rn ~ "~ ~ ' N' Of C, U. $• f0' ~ . _~ 'a, y. O O• O O' y' G L, a v. (6 E, o, ° c o, ~°' 3' t/1, 4 o~ m ~ m «, ~~ y. i c. m ( f6 c, of °' °' , y Y, p ui .°' • m 'a' _, p ~ c' I N, a' o, 'y' d O N J _. r ~~ c' ~ d d N. N U >i Vj N. Q N• ~ 3. c t a, O ~, '._, c. Q 6 ' N. c. ~ ~ N. ~, ~ d ~, w~ O ~, ~, y. N. >„ ~ ~, LL Q. 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