Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
206-026
7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU P2-11A Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 206-026 50-029-22923-01-00 ADL 00365548 , 0034627 17640 Conductor Surface Intermediate Liner Liner 9119 78 5705 14618 3231 665 17592 20" 9-5/8" 7" 2-3/8" 4-1/2" 9107 39 - 117 38 - 5743 36 - 14654 14396 - 17627 14412 - 15077 3099 39 - 117 38 - 4971 36 - 8937 8820 - 9116 8827 - 8973 none 3090 7020 11780 7500 none 5750 8160 11200 8430 15550 - 17350 3-1/2" 9.2# 13Cr80 34 - 144399003 - 9083 Structural 3-1/2" Baker S-3 3-1/2" TRSV SSV 14391 / 8818 2195 / 2189 Date: Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com 907.564.4061 PRUDHOE BAY 6-16-2023 Current Pools: PT MCINTYRE OIL Proposed Pools: PT MCINTYRE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.06.01 11:14:46 -08'00' By Grace Christianson at 3:33 pm, Jun 01, 2023 323-323 10-404 SFD 6/8/2023 3099 , ADL0034624 SFD MGR05JUN23 DSR-6/1/23GCW 06/09/2023 06/09/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.09 08:46:37 -08'00' RBDMS JSB 060923 Well: P2-11A PTD:206026 API:50-029-22923-01 Well Name:P2-11A API Number:50-029-22923-01 Current Status:Operable Rig:Coil Estimated Start Date:June 2023 Estimated Duration:3 days Regulatory Contact:Carrie Janowski First Call Engineer:Eric Dickerman 307-250-4013 Second Call Engineer:David Bjork 907-440-0331 Current Bottom Hole Pressure:3,979 psi @ 8,800’ TVDss 8.7 PPGE | Taken 2/25/2019 Max. Anticipated Surface Pressure:3,099 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1,990psi (Taken on 11/28/2020) Min ID:1.781” - nipple in liner top packer assembly at 14,408’ Max Angle:91.68 Deg @ 16,564’ Brief Well Summary: P2-11A is a producer at Pt. Mac in the Kuparuk formation. The well was sidetracked in April 2006 and completed with a 2-3/8” production liner. The cement top in the 2-3/8” liner was logged at approximately 15,500’md. P2-11A is supported by injector P2-34. P2-34 was on MI injection from November 2021 to December 2022, however none of the producers in the pattern observed an MI response. Objectives: The objective of this procedure is to add perforations in P2-11A targeting the area of the wellbore closest to P2- 34 and the MI that had been injected. Procedure: Coiled Tubing Notes: x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. x The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 2. Bullhead ~165 bbls (1.2x WBV) of 9.0ppg brine 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 bottom perf = 138 bbls b. 3-1/2” Tubing – 14,396’ x 0.0087 bpf = 126 bbl c. 2-3/8” Liner – (17,350’ – 14,396’) x 0.0039 bpf = 12 bbl 3. MU and RIH with logging tools. Flag pipe as appropriate per WSS for perforating. 4. POOH and freeze protect tubing as needed. Confirm good log data. 5. At surface, prepare for deployment of TCP guns. 6. Confirm well is dead. Bleed any pressure off to return tank. Kill well with 9.0 ppg brine as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man- Well: P2-11A PTD:206026 API:50-029-22923-01 watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 7.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. a.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 8. 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 *HES 1.56” guns were used to estimate for this job and calculate gun weights. Run Perf Interval Perf Length Gun Length Weight of Gun (lbs) #1 16,100’ – 16,600’500’500’2000# (4ppf) #2 15,600’ – 15,720’120’ 500’2000# (4ppf)15,721’ – 15,809’Blank – 88’ 15,810’ – 16,100’290’ 9. MU PCE. 10. RIH with perf gun #1 and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 11. After perforating, PUH and paint flag for next perf run, then continue to PUH to top of liner 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. 12. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 13. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 14. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator, thenLD gun BHA. 15. Repeat steps 5 through 14 for run #2. 16. RDMO CTU. 17. RTP or FP well. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Coil Tubing BOPE Schematic 4. Standing Orders for Open Hole Well Control during Perf Gun Deployment 5. Equipment Layout Diagram 6. Reference log 7. Sundry Change Form Well: P2-11A PTD:206026 API:50-029-22923-01 Current Wellbore Schematic Well: P2-11A PTD:206026 API:50-029-22923-01 Proposed Wellbore Schematic Well: P2-11A PTD:206026 API:50-029-22923-01 Coiled Tubing BOPs Well: P2-11A PTD:206026 API:50-029-22923-01 Standing Orders for Open Hole Well Control during Perf Gun Deployment Well: P2-11A PTD:206026 API:50-029-22923-01 Equipment Layout Diagram Well: P2-11A PTD:206026 API:50-029-22923-01 Tie in log: SLB MCNL – 19-April-2006 - Jewelry log pass Well: P2-11A PTD:206026 API:50-029-22923-01 Well: P2-11A PTD:206026 API:50-029-22923-01 Sundry change form Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION COMM! REPORT OF SUNDRY WELL OPERATI 1. Operations Performed Abandon El Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 OperationS shutdown 0 Suspend 0 Perforate El Other Stimulate ❑ Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Pull/Set Liner Top Packer I? 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-026 3. Address: P.O.Box 196612 Anchorage, Development Il Exploratory 0 - ' AK 99519-6612 Stratigraphic El Service ❑ 6. API Number: 50-029-22923-01-00 7. Property Designation(Lease Number): ADL 365548&034627 8. Well Name and Number: PBU P2-11A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PT MCINTYRE OIL ��'�� 11.Present Well Condition Summary: D Total Depth: measured 17640 feet Plugs measured None feet true vertical 9119 feet Junk measured None feet OCT 19 2017 Effective Depth: measured 17592 feet Packer measured 14391 feet true vertical 9107 feet Packer true vertical 8817 feet A®GCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" 39-117 39-117 3060 1500 Surface 5704 9-5/8" 38-5743 38-4971 5750 3090 Intermediate See Attachment 7" See Attachment See Attachment 7240/8160 5410/7020 Liner 4-1/2" 8430 7500 Liner See Attachment 2-3/8" See Attachment See Attachment Perforation Depth: Measured depth: 15550-17350 feet DEC 26217 True vertical depth: 9003-9083 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.2#13Cr80 34-14439 34-8839 Packers and SSSV(type,measured and 3-1/2"Baker S-3 Packer 14391 8817 true vertical depth) 3-1/2"OTIS TRSV SSV 2195 2189 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-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 571 447 2410 2333 - 235 Subsequent to operation: 241 291 4036 2232 438 14.Attachments:(required per 20 MC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development IZI Service 0 Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Il Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP El SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Duong,Lea Contact Name: Duong,Lea Authorized Title: Senior Petroleum Engineer �+ Contact Email: Lea.Duongi bp.com Authorized Signature: /`� Date: /QIIOII Contact Phone: +1 907 564 4840 Form 10-404 Revised 04/2017 V rL j Z/I/i7- ""' t,' "OCT� OCu 2 5 2611 Submit OriginalOnty �/�/��� Daily Report of Well Operations P2-11A ACTIVITYDATE SUMMARY T/I/O = 230/2290/400. Temp = 120*. TIFL FAILED (Eval high IAP). ALP = 2290 psi, open @ CV. IA FL @ 14330' (#7 SO, 333 bbls). SI WV, stacked well out to 2230/2420/340 in 1 hr. Grease crew serviced AL CV and lateral. Bled ALP to 500 psi. Bled IAP to P2-08 production from 2420 psi to 1080 psi in 1.5 hrs. During IA bleed, TP increased 60 psi. IA FL unchanged. Monitored for 1 hr. TP increased 40 psi, IAP increased 20 psi, IA FL unchanged. Extend monitor 1 hr. TP increased 40 psi, IAP increased 20 psi, IA FL unchanged. Extend monitor 1 hr. TP increased 30 psi, IAP increased 20 psi, IA FL unchanged. Turned well over to Ops. Final WHPs = 2400/1140/0. 7/5/2017 SV, WV= C. SSV, MV= 0. IA, OA= OTG. 16:20 ***WELL FLOWING ON ARRIVAL***(perforating) TAGGED TRSSSV @ 2163' SLM W/2.84" NO-GO CENT. THEN WITH NOGO & 128" FLAPPER CHECKER.(no issues) DRIFT TO LTP WITH 2.80" G-RING AT 14398' MD.ALL CLEAR 7/6/2017 ***CONT ON 7-7-17 WSR*** ***CONT FROM 7-6-17 WSR***(perforating) JARRED ON BKR 35KB LTP @ 14,398' MD FOR 2 HRS W/ .125 CARBON. UNABLE TO SHEAR TOOLS FROM LTP @ 14,398' MD.(jarred down for 50mins) SHEARED TOOL/TOOLSTRING FREE W/ LRS ASSIST.(see Irs log) LRS LOADED TBG W/ 150 BBLS OF CRUDE.(see Irs log) PULLED LTP FROM 14398' MD. (MISSING PART OF ONE OF THE ELEMENTS 2.5"X 1") 7/7/2017 ***CONT ON 7-8-17 WSR*** T/I/0=2292/2303/113, Temp=S/I, Assist Slickline with LTP (Gas Lift) Pumped 2 bbls meth spear followed by 150 bbls crude down tubing to free up Slickline tool. SlickLine on well upon departure. FWHP= 1800/2229/103 Valves= SLickLine 7/7/2017 well control drill CTU #9 - 1.50" Coil Job Objective: Mill Scale,AddPerf In yard welding on pipe extension. 7/7/2017 ...Continued on WSR 7-8-17 ***CONT FROM 7-7-17 WSR*** RAN 2.5" PUMP BAILER TO DEP SLV AT 14,405' MD - DID NOT RECOVER THE PIECE OF ELEMENT SET WHIDDON C-SUB ON DEP SLV AT 14,405' MD. PULLED TG-OGLV FROM ST#7 @ 14,330' MD. SET RK-OGLV IN ST#7 @ 14,330' MD AFTER 5 ATTEMPTS. PULLED 3 1/2"WHIDDON CSUB FROM DEP SLV AT 14,405' MD. 7/8/2017 ***CONT ON 7-9-17 WSR*** CTU #9 - 1.50" CT ***Cont. from WSR 7-7-17** Job Objective: Mill Scale,AddPerf Perform pipe extension in SLB yard. 7/8/2017 ...Job continued on WSR 7/9/2017... CTU #9 - 1.50" Coil Job Objective: Mill Scale,AddPerf Move CTU from SLB Yard to P2-11. Pump 1.0" drift ball. Make up 1.69" motor with 1.88" turbo scale mill and 1.69"Tem press. RIH while bleeding IA. Liquid pack well and bleeding IA. 7/9/2017 ...Job Continued on WSR 7/10/2017... Daily Report of Well Operations P2-11A ***CONT FROM 7-8-17 WSR*** DRIFTED TO DEVIATION AT 14635' SLM WITH 1.89" CENT & 1.75" SBLR-NO ISSUES, BLR EMPTY 7/9/2017 ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** CTU #9 - 1.50" Coil, Continue from WSR 7/9/2017 Job Objective: Mill Scale,ADPERF Bleeding IA down to keep gas from entering the tubing while milling. Tag small bridge from 15885-15895 and mill thorugh. Mill heavy scale from 16590-16695' and then able to drift to TD tag of 17587' CTMD. Pump gel sweep on bottom and chase out of hole. Cut pipe for Chrome Management, MU CTC, MHA, Logging tools and RIH. 7/10/2017 ...Continue on WSR 10/11/2017... CTU #9 - 1.50" Coil, Continue from WSR 7/10/2017 Job Objective: Mill Scale,ADPERF RIH with GR/CCL for Coil Flag. Log from up 17475'to 14800' and POOH. LD Logging tools and check for dat, good data, MU Perf BHA#1 with 1.56" Millenium perf gun, 6 spf x 30'. RIH and tie into flag. Perforate 16664-16694, POOH. MU Perf BHA#2 with 1.56" Millenium perf gun, 6 spf x 30' and Perforate 16632-16662, POOH. 7/11/2017 ...Job continued on WSR 7/12/2017... CTU #9 - 1.50" Coil, Continue from WSR 7/11/2017 Job Objective: Mill Scale,ADPERF POOH from perforating 16632-16662. At surface all shots fired. Stack down Lubricator, cut 100'of coil, change pack-offs, inspect chains, rehead, MU GR/CCI Logging BHA. RIH to 17480' and log up to 14800', painting a white/blue flag at 16450'. POOH. Make up Perf BHA #3 with 1.56" Millenium perf guns, 6 spf x 30' and RIH. Correct to flag and perf from 16600' to 16630' 7/12/2017 ...Job Continued on WSR 7/13/2017... CTU #9 - 1.50" Coil, Continue from WSR 7/12/2017 Job Objective: Mill Scale,ADPERF POOH from perforating 16600-16630. Make up and RIH with perf gun #4 and perforate 15780-15810. Perform weekly BOP test. Make up and RIH with 1.69" GR/CCL. 7/13/2017 ***Job Continued on 7/14/17*** CTU #9 - 1.50" Coil, Continue from WSR 7/12/2017 Job Objective: Mill Scale,ADPERF Continue RIH with logging tools. Log from 17500 to 14200. Paint green/yellow flag at 15849.8. POOH, shut the pump down at 2600' leaving the well freeze protected on top. Good data at surface, +21' correction. Made up gun #5 1.56" Millenium perf gun, 6 spf x 30' and Perforate 15750-15780, POOH. Make up gun #6 1.56" Millenium perf gun, 6 spf x 30', RIH. Corrected depth at flag and perforated 15720-15750. POOH. 7/14/2017 ***Job Continued on 7/15/17*** CTU #9 - 1.50" Coil, Continue from WSR 7/14/2017 Job Objective: Mill Scale,ADPERF Continue POOH with gun #6. LD gun #6. Trim 100' of pipe. Make up and RIH with 1.69" GR/CCL to 17,500' ctm. log up 50 fpm. Flag the coil at 15600'. Log up to 14,250' POOH pumping safelube. Good data at surface. +29' correction. Make up and RIH w/gun #7 1.56" Millenium perf gun, 6 spf x 30'. Tie into the flag to bottom shot. Shoot 15570-15600. POOH. LD gun #7 and make up/RIH with gun#8. 7/15/2017 ***Job Continued on 7/16/17*** Daily Report of Well Operations P2-11A CTU #9 - 1.50" Coil, Continue from WSR 7/15/2017 Job Objective: Mill Scale,ADPERF RIH with gun #8. Tie in at flag and perforate 15550-15570. POOH and freeze protect well with 22bb1 of 50/50. OOH with gun#8, all shots fired. RDMO. 7/16/2017 ***Job Complete*** T/I/O = 470/890/Vac. Temp = SI. IA FL (Eval TxIA comm). ALP = 0 psi, SI © casing valve. IA FL @ 470' (9 bbls). 7/18/2017 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 12:55. ***WELL S/I ON ARRIVAL***(perforating) TAG TOP OF TRSV AT 2168' SLM 8/7/2017 ***CONT ON 8-8-17 WSR*** 8/7/2017 T/I/0=700/928/101 Temp=S1 Assist SLB with B&F and load tbg. **WSR continued on 8-8- **WSR continued from 8-7-17**Assist SLB with B&F and load tbg. Pumped 2 bbls of 50/50 methanol followed by 116 bbls of crude down the tbg to assist SLB with B&F. 8/8/2017 FWHP=1510/1475/129 SLB still on well upon departure. Unit 72 taking over job. ***CONT FROM 8-8-17 WSR***(Perforating) PERFORMED FLAPPER CHECKER ON TRSV @ 2195' MD.(valve open) BRUSHED TBG W/3-1/2" BRUSH, 2.30" GAUGE RING &2-7/8" BRUSH TO DEPLOY SLV @ 14,405' MD.(coil shavings in tools) LRS PUMPED 120 BBLS OF CRUDE DOWN TBG FOR BRUSH & FLUSH.(see Irs log) LRS LOADED TBG W/ 125 BBLS OF CRUDE.(see Irs log) RAN 35 KB DRIFT & PTSA W/SEALS TO 14,048' SLM.(unable to work past, shavings in tools) BRUSHED TBG W/3-1/2" BRUSH &2.80" GAUGE RING TO 13,946' SLM.(unable to work past, shavings in tools) LRS PUMPED 125 BBLS OF CRUDE FOR BRUSH RUN.(see Irs log) ***WILL RETURN AFTER FLOWING WELL, WELL S/I ON DEPARTURE, DSO NOTIFIED 8/8/2017 OF WELL STATUS*** T/I/0=1000/980/110 Temp= shut in. Assist SlickLine (load and test) Pumped 125 bbls of 110* crude to load TBG. TxIA communication. SL could not drift. Bled gas off IA. Pumped 15 bbls of crude into the IA. Pumped 125 bbls of 180* F crude into the TBG for B&F. 8/8/2017 FWHP= 1180/880/140. SL had control of the well and DSO notified upon departure. T/I/O = 2400/2390/160. Temp = 115". WHPs (Eval T x IA). AL open @ casing valve. Ops SI well & backflowed prior to arrival (-1 hour). Inial IA FL @ 9740' (4590' above#7, S/O, too high to test properly). Ops to continue to try to displace IA overnight. FW Ps = 2400/2390/160. 8/25/2017 SV, WV= C. SSV, MV = 0. IA, OA = OTG. 1030 hrs. T/l/O = 490/2470/400. Temp = 110*. IA FL (eval TxIA). ALP = 2470 psi, open @ CV. IA FL @ 11030' (850' above#5 Dome, 256 bbls). IA FL depressed 1290' since 10:30 8/26/2017 yesterday. ****WELL S/I UPON ARRIVAL**** (Scale inhibition) DRIFTED W/2.80" CENT, 2.50" LIB, UNABLE TO PASS 13,952' SLM DRIFTED W/3-1/2" BRUSH, 2.74" G-RING TO 13,823' SLM (Unable to work past) DRIFTED W/2-1/2" S-BAILER TO DEP SLV @ 14,382' SLM / 14,405' MD (Recovered metal chunks) SET 3-1/2" SLIP STOP CATCHER @ 12,008' SLM PULLED STA#5 RK-LGLV FROM 11,864' SLM / 11,833' MD PULLED STA#3 RK-LGLV FROM 8,026' SLM /8,047' MD PULLED STA#1 RK-LGLV FROM 4,238' SLM /4,262' MD SET STA's#1, #3  RK-LGLV's 8/29/2017 ****CONT. JOB ON 8/30/17**** Daily Report of Well Operations P2-11A ****CONT. JOB FROM 8/29/17**** (Scale inhibition) PULLED 3-1/2" SLIP STOP CATCHER FROM 12,008' SLM (Empty) 8/30/2017 ****WELL LEFT /SI & PAD-OP NOTIFIED OF STATUS UPON DEPARTURE**** LRS test Unit 1, Clean out Debris left from coil. Begin WSR 9/8/17, TRAVEL, Rig up, Begin 9/8/2017 PT. continue on WSR 9/9/17 LRS test Unit 1, Clean out Debris left from coil. From WSR 9/8/17. End PT, Pop and Flow 9/9/2017 Well. Continue on WSR 9/10/17 9/10/2017 LRS Unit 70 assist LRS testers: Pumped 22 bbls crude down TBG to freeze protect. LRS test Unit 1, Clean out Debris left from coil. Continue from WSR 9/9/17. Continue to 9/10/2017 flow well mointoring for sollids, perform 8 hr test, RDMO. End WSR 9/10/17. T/1/O = SSV/2430/60. Temp = SI. IA FL (GLE request). ALP = 2460 psi, SI @ CV. IA FL @ 8550' (5780' above sta #7 SO). 9/14/2017 SV, WV, SSV = C. MV= 0. IA, OA= OTG. 23:30 ***WELL SHUT IN ON ARRIVAL*** RUN FLAPPER CHECKER TO TRSV @ 2164' SLM/2195' MD (flapper open) 9/17/2017 ***CONT. ON 09/17/17 WSR*** T/I/0=735/715/70 Temp= S/I (LRS Unit 70 -Assist Slickline: Load and Tes) MIT-T to 3000 psi Failed, unable to reach/maintain test pressure, IA tracking w/TBG. Continue on with CMIT-TxIA. CMIT-TxIA Passed to 3178/3179 Max applied pressure= 3300 psi. Target pressure= 3000 psi.Pressured up T/IA to 3260/3263 psi with 17.6 bbls 100* crude. 1st 15 min T/IA lost 60/59psi. 2nd 15 min T/IA lost 22/25 psi for a total loss of 82/84 psi in 30 min. Pumped 2 bbls crude down TBG maintaining 3000 psi while SL bled IAP in attempt to set check valve on SO. SL bled T/IA to 500 psi. 9/18/2017 ***Continued on 09-19-17 WSR*** ***CONT. FROM 09/17/17 WSR*** (scale inhibition) TAG TOP OF DEPLOYMENT SLEEVE W/2.72"x 71" DRIFT &2.50" LIB @ 14385' SLM LRS LOAD IA W/430 BBLS/CRUDE LRS LOAD TBG W/ 195 BBLS/CRUDE SET 3-1/2" HES EVO-TRIEVE @ 14383' SLM LRS ATTEMPT MIT-T TO 3000 PSI FAILED LRS CMIT-T x IA TO 3000 PSI PASSED 9/18/2017 ***CONT. ON 09/19/17 WSR*** T/I/O= 2420/2400/60. (LRS Unit 46 - Assist Slickline: Load and Test) Pumped 2 bbls 60/40, followed by 430 bbls crude down IA to load. Pumped 2 bbls 60/40, followed by 195 bbls down tbg to load. Slickline still on well at LRS departure. **Fluid packed tags hung on IAV and WV** **AFE sign hung on MV** 9/18/2017 FWHP= 1060/1053/71 ***Continued from 09-18-17 WSR*** (LRS Unit 70 -Assist Slickline: MIT-T) SL bled T/IA to 500 psi. Pumped 6.5 bbls of crude while SL ran D&D hole finder. S-line on well on departure. WV = Closed. SV, SSV, MV= Open. CV=OTG 9/19/2017 Final Whp's=600/636/65 T/I/0=400/700/0 (LRS Unit 72 -Assist Slickline: MIT-T) MIT-T PASSED to 3076 psi. Max Applied Pressure = 3300 psi. Target Pressure = 3000 psi. Pressured Tbg to 3286 psi w/2.75 bbls crude. MIT-T lost 163 psi in 1st 15 mins and 47 psi in 2nd 15 mins for a total loss of 210 psi in 30 min test. Bled Tbg to 520 psi and got back —2.5 bbls. SLine in control of well per LRS departure. IA,OA=OTG 9/19/2017 FWHP's=540/600/61 Daily Report of Well Operations P2-11A ***CONT. FROM 09/18/17 WSR*** (scale inhibition) SET 3-1/2" D&D HOLE FINDER ABOVE ST#7 @ 14292' SLM LRS PT TBG. TO 1000 PSI (holding) SET 3-1/2"WHIDDON CATCHER SUB @ 14378' SLM PULL RK-DGLV FROM ST#5 © 11883' MD PULL RK-OGLV FROM ST#7 @ 14330' MD SET RK-OGLV IN ST#5 & RK-DGLV IN ST#7 9/19/2017 ***CONT. ON 09/20/17 WSR*** ***CONT. FROM 09/19/17 WSR*** (scale inhibition) PULL EMPTY 3-1/2"WHIDDON CATCHER SUB FROM 14378' SLM PULL 3-1/2" EVO-TRIEVE FROM 14381' SLM RUN DMY 35 KB PKR DRIFT W/ DMY PTSA STINGER & SD HIGH @ 13833' SLM (unable to pass) BRUSH DEPLOYMENT SLEEVE PROFILE FROM 14385' SLM TO 14390' SLM RUN DMY PTSA STINGER & STING INTO DEPLOYMENT SLEEVE @ 14385' SLM (tattle- tales indicate full set) 9/20/2017 ***CONT. ON 09/21/17 WSR*** T/I/0=1075/940/60 Temp=Sl (LRS Unit 46 -Assist Slickline: Set Liner Top Packer) Pumped 30 bbls down tbg while slickline worked brush. Pumped 32 bbls crude down tbg to assist slickline with drifting to simulate pumping LTP into place. Pumped 14 bbls of crude down the tbg to assist slickline with setting LTP. 9/21/2017 **WSR continued on 9-22-17** ***CONT. FROM 09/20/17/WSR*** RUN DMY 35 KB PKR DRIFT & 2.50" LIB, SD HIGH @ 14072' SLM (unable to pass) LRS PUMP 30 BBLS/CRUDE FOR B&F RUN 3-1/2" BRUSH & 2.80" G. RING FROM SURFACE TO 14385' SLM RUN DMY 35 KB PKR DRIFT W/ DMY PTSA STINGER INTO DEPLOYMENT SLEEVE @ 14390' SLM (tattle-tales indicate full set) RUN DMY 35 KB PKR DRIFT 4' SPACER PUP & DMY PTSA STINGER INTO DEPLOYMENT SLEEVE @ 14390' SLM (tattle-tales indicate full set) SET 35 KB LTP W/4' PUP & NS PTSA W/ 1.781" BLANKED R PLUG INSTALLED, ***TOP OF LTP @ 14396' MD, OAL IS 13.99', 2 3/8" R-NIPPLE @ 14408' MD 9/21/2017 ***CONT. ON 09/22/17 WSR*** **WSR continued from 9-21-17** (LRS Unit 46 -Assist Slickline: Set Liner Top Packer) MIT-T PASSED to 2952 psi, Max Applied Pressure=3000 psi, Target Pressure 2500 psi, Pressured tbg to 2971 psi with .25 bbls of crude, 1st 15 min tbg lost 16 psi, 2nd 15 min tbg lost 3 psi, total loss of 19 psi in 30 min. Bled tbg down to 1500 psi. Bled back .2 bbls. Hung AFE sign on well. Slickline still on well upon departure. 9/22/2017 FW H P=940/525/60 ***CONT. FROM 09/21/17 WSR*** LRS PERFORM PASSING MIT-T TO 2615 PSI PULL 1.781" R PLUG FROM INTEGRAL 1.781" R NIPPLE @ 14390' SLM 9/22/2017 ***WELL TURNED OVER TO DSO*** T/I/O = 330/2200/730. Temp = 115°. Wireless install (WOLP). Installed and pressure tested wireless pressure gauges on IA/OA. Installed temperature transmitters on S-riser and flow line. FCO complete and ready to turn over to Operations. SV = C. WV, SSV, MV= 0. IA, OA= OTG. 1700 hrs. 9/23/2017 T/I/O= 750/2175/400 Temp= Hot (LRS Unit 42 - Scale Inhibition Treatment, SIT) Road to location, Spot equipment, Inspect shower trailer, Open RAP, S/I well, ***WSR Continued on 10/12/2017 10-13-17** Daily Report of Well Operations P2-11A ***WSR Continued from 10-12-17*** T/I/O= 750/2175/400 Temp= Hot (LRS Unit 42 - Scale Inhibition Treatment, SIT) Pumped the following down the TBG: 2 bbls 60/40 meth spear 233 bbls 1% KCL w/ 15% EGMBE Pre-flush 413 bbls 1% KCI w/20% PM-9701 (Scale Inhibitor) 478 bbls 1% KCL Over-Flush/Displacement 22 bbls Diesel Freeze Protect Valve position @ departure- ,SV,WV,SSV= CLosed IA,OA= Open to gauge MV,AL= Open Notified Pad-op of well status, 10/13/2017 FWHP= 679/1776/50 TREE= 4-1/16"CIW P2-1 1 A SAS '" NOTES:**WELL ANGLE>70"@ 14695'** WELLHF,AD= 11 FMCWELL REQUIRES A SSSV***CHROME CSG,LNR& ACTUATOR= BAKER *** KB.BEV= 49.8" I BF.a.EV= KOP= 1381' Q D 2021' 9-5/8"HES ES CEMENTER Max Angle= 92 @ 16564' "CONDUCTOR ? Datum MD .... 14462' #, 2196" r 3-1/2"HES TRSV SERFS 10,D=2.813" Datum TV D= 8800'SS bpf,D=_"? GAS LFT MADS ST MD ND DEV TYPE VLV LATCH PORT DATE 9-5/8"CSG,40#,L-80,D — =8.835" —I 5743' 4 ii k1 4262 4061 47 MMG-5 DOME RK 16 08/29/17 2 5838 5024 57 IV DMY RK 0 10/26/98 7"CSG,26#,L-80 BTC-M,.0383 bpf,D ax=6.276" H 13662' c 3 8047 6013 65 MMG 5 DOME RK 16 08/29/17 4 9874 6824 64 MMG-5 DMY RK 0 01/22/99 5 11883 7709 65 IVIMG-5 SO RK 20 09/19/17 6 13274 8318 64 MMG-5 DMY RK 0 10/26/98 7"MARKER JOINT(CHROME) H 14245' —0 7 14330 8790 64 MMG 5 DMY RK 0 09/19/17 H3 Minimum ID = 1.781" @ 14408' 1` g' v2"x 4 u2"xo,D=2.ss2" R NIPPLE IN PTSA LTP ( )........ 14391' --17"x 4-1/2'BKR S-3 PKR,D=3.875" 14395' H4-1/2"X 3-1/2"XO,D=2.992" 14396' -j3-1/2"NS PTSA LNR TOP PKR w/2-3/8"R NP @ $ 14408',D=1.781"(09/21/17) 14405' H2.70"BOT DEPLOY SLV,D=1.920" 14412' H6'BKR TACK SLV,D=5.250" ' t / 14416' H3-1/2"HES X NP,D=2.813" TOP OF 4-1/2"LNR —I 14419' 6 14419' --17'X 5"BKR HMC LNR HGR,D=4.437" _ 14426' --I5"X 4-1/2"XO,D=3.958" I 14427' —13-1/2"HES XN NP,D=2.75" BEHIND CT LNR 3-1/2"TBG,9.2#,13CR NSCT,.0087 bpf,D=2.992" —{ 14438' / ‘ 14439' H3-1/2"WLEG,D=3.000" 14425' H ELMD TT LOGGED 10/30/99 7"CSG,29#,13CR NSCC,.0371 bpf,)=6.184" —I 14.654' , 4-1/2"MECHACAL HPSTOCK(03/31/06) H 15077' I 14677' H4-1/2"MARKERJONT NW w/RA TAG @ 15085' MLLOUT WINDOW(P2-11A) 15077'-15080' PE32FORATION SUMMARY REF LOG: MCN_ON 04/19/06 15400' —j TOP OF CEMENT ANGLE AT TOP PB;F: 87'@ 15550' AN Note:Refer to Production DB for historical pert data , SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 6 4;#4,1.56" 6 15550-15600 0 07/16/17 y 1.56" 6 15720-15810 0 07/14/17 1.56" 6 16600-16630 0 07/13/17 E 4 1.56" 6 16600-16800 0 04/21/06 17591' H PBTD 1.56" 6 16632-16662 0 07/11/17 .4 'fie,,,.., 1.56" 6 16664-16694 0 07/11/17 •�•�•�•�•�••2 •A 'his; AAAAAA "V:1.56" 6 16840-16960 0 04/21/06 1.56" 6 17000-17160 0 04/21/06itiSii 1.56" 6 17200-17350 0 04/21/06 2-3/8"LNR,4.6#,13CR-80 STL, --I 17367' / N .0039 bpf,D=1.995" 2-3/8"LNR,4.44#, L-80 STL, .0039 bpf,D=1.992" —I 17627' 4-1/2"LNR,12.6#,13CR NSCT,.0152 bpf,D=3.958" — 15199' DATE REV BY COMMENTS DATE REV BY COMMBVTS FONT MC INTY RE UNIT 10/28/98 INITIAL COMPLETION 10/10/17 BSEIJMD SET PTSA LTP&RNP(09/21/17) WELL: P2-11A 04/24/06 NORDIC 2 CTD SIDETRACK(P2-11A) 10/18/17 JNUJMD CORRECTION TO PERFS PERMIT No:' 060260 07/10/17 MGS/JMD GLV GO(07/08/17) AR No: 50-029-22923-01 07/19/17 JDM(JMD ADPERFS&REPBRFS SEC 11,T12N,R14E, 1'FSL&1115 RAIL 09/08/17 ZV/JMD GLV GO(08/29/17) 10/10/17 DG/JMD GLV C/O(09/19/17) BP Exploration(Alaska) • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, September 21, 2017 7:57 AM To: AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS GPMA OSM; AK, OPS GPMA Field O&M TL;AK, OPS LPC DS Ops Lead;AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Special Projects;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, OPS PCC Ops Lead; Burton, Kaity; Duong, Lea; Regg,James B (DOA);Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington,Aras J;AK, GWO Well Integrity Well Information Subject: OPERABLE: Producer P2-11A(PTD#2060260)Well barriers restored, MIT-T passed All, Producer P2-11A(PTD#2060260)was made Under Evaluation on 8/24/17 to resume diagnostics of sustained inner annulus casing pressure discovered on 7/1/17. On 9/18-9/19 fullbore performed a passing CMIT-TxIA to 3,178psi,and a passing MIT-T to 3076psi post gas lift change out.The passing pressure test confirms two competent well barriers. At this time the well is reclassified as Operable. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO gr.rr..w colpow.ao. SCANNED SEP 2 5 2097 From: AK, GWO Well In •rity Engineer Sent: Thursday, August 24, ! 7 9:02 AM To: AK, GWO Well Integrity Engin-- • AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS GPMA OSM; AK, OPS GPMA Field O&M TL; A', •PS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, GWO •'T Special Projects; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead; Burton, ' ‘ ; Duong, Lea; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integ '' • AK, OPS FF Well Ops Comp Rep; AKIMS App User; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgome Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Worthington, Aras.3 Subject: UNDER EVALUATION: Producer P2-11A (PTD# 2060260) High Inn- nnulus Pressure Over NOL 1 • S Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday,August 24, 2017 9:02 AM To: AK, GWO Well Integrity Engineer;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS GPMA OSM;AK, OPS GPMA Field O&M IL;AK, OPS LPC DS Ops Lead;AK, OPS LPC Board Operator;AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Special Projects;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, OPS PCC Ops Lead; Burton, Kaity; Duong, Lea; Regg,James B (DOA);Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington,Aras J Subject: UNDER EVALUATION: Producer P2-11A(PTD#2060260) High Inner Annulus Pressure Over NOL All, Producer P2-11A(PTD#2060260)was made not operable on 07/30/17 for having sustained inner annulus casing pressure above NOL and planned maintenance at GCI prevented further integrity diagnostics. The GC1 TAR is now complete. The well is now ready to be put on production so a warm TIFL can be completed. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1. OPS: POP Well 2. DHD: Warm TIFL 3. Well Integrity Engineer:Additional diagnostics as needed. Please respond with any questions, Matt Ross (Alternate: Josh Stephens) `)Ci Q �� Well Integrity Engineering 5`pN�E® Office 907-659-8110 Cell 907-980-0552 Harmony 4530 From: AK, G • - Integrity Engineer Sent: Sunday, July 30, r :• AM To: AK, GWO Well Integrity Engineer, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS GPMA OSM; AK, OPS GPMA Field O&M TL; AK, OPS - 'S Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Speci. • o'ects; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead; Burton, Kaity; Duong, Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity; A , •• FF Well Ops Comp Rep; AKIMS App User; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis unk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Worthington, Aras J; AK, GWO Well Integrity Well : ation Subject: NOT OPERABLE: Producer P2-11A(PTD# 2060260) High Inner Annulus Press - •ver NOL All, 1 • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday,July 16, 2017 10:16 AM To: Regg,James B (DOA);Wallace, Chris D (DOA) Cc: AK, GWO Well Integrity Engineer Subject: FW: UNDER EVALUATION: Producer P2-11A (PTD#2060260) High Inner Annulus Pressure Over NOL Attachments: P2-11A.pdf; Producer P2-11A(PTD#2060260)TIO Plot 2017-07-16.docx external-email: 0 Jim and Chris, I discovered today that you were inadvertently omitted from this notification. Producer P2-11A(PTD#2060260) exceeded IA NOL on 07/01/17. Current status: 1. DHD:Warm TIFL—Failed 7/5 2. Slickline: change out orifice gas lift valve—Completed 7/9 3. DHD: Cold TIFL—Scheduled 7/18 4. DHD(contingent):Warm TIFL Apologies for the oversight. I'll ensure you are included on all future correspondence related to this well. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) AUG 0 g 7017 0:(907)659-5102 SCANt4EU C:(907)943-0296 H:2376 From: AK, GWO Well Integrity Engineer Ser tic arndayr July 02, 2017 3:49 PM To: AK, GWO Pr..-sis Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS GPMA OSM; AK, OPS GPMA Field O&M TL; AK, OPS LPC DS Ops Lea., ; OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Special Projects; A , GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead; Burton, Kaity; Duong, Lea Cc: AK, GWO DHD Well Integrity; AK, GWO SUP - I Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Dempsey, David , '•bert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, • ' -r R; Worthington, Aras J Subject: UNDER EVALUATION: Producer P2-11A (PTD# 2060260) High -r Annulus Pressure Over NOL All, Producer P2-11A(PTD#2060260)was reported to have sustained inner annulus casing pressure a i= e NOL on 7/1/17. The pressures were reported to be TBG/IA/OA=2610/2610/100psi.At this time the well is rec . "fled as Under Evaluation and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - ~~~j Well History File Identifier Organizing (done> RESCAN ~olor !tams: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: ~..o.cea iuuiiimmiuii DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: ^ Rescan Needed III II'lII II OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~ ~ /s/ Project Proofing III IIIIII VIII II III BY: Maria Date: ~ b ~ /s/ rn Scanning Preparation _~ x 30 = _~ + ~ =TOTAL PAGES_ ,~~ (Count does not include cover sheet) BY: Maria Date: S' D /s/ Production Scanning III IIIIII VIII VIII Stage 1 Page Count from Scanned File: ~ (Count does include cov sheet) Page Count Matches Number in Scan ing Pr partition: 1/ YES NO BY: Maria Date: ~ ~-,~ O $ /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. ReScanned BY: Maria Date: Isl Comments about this file: o~a~.~,e~kee mimmiuiiuu 10!6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 SittetitE A(1G (1 8 i!(,l Mr. Jim Regg a - d a-(t Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Pa Subject: Corrosion Inhibitor Treatments of GPMA PM -2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA PM -2 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, L- 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) GPMA PM -2 Date: 04130tt2012 Corrosion Vol. of cement Final top of Cement top Corrosion inhibitor/ sealant Well Name PTD # API # Initial top of cement pumped cement off date inhibitor date ft bbls ft na gal P2 -01 1970730 50029227610000 0.3 NA 0.3 NA 1.70 6/22/2009 P2 -03 1970440 50029227490000 2.0 NA 2.0 NA 10.20 6/22/2009 P2-04 1981560 50029229070000 1.0 NA 1.0 NA 5.10 6/22/2009 P2-06 1931030 50029223880000 4.0 NA 4.0 NA 30.60 , 6/22/2009 P2 -07 1940580 50029224690000 2.0 NA 2.0 NA 13.60 6/22/2009 P2 -08A 2061690 50029228960100 0.8 NA 0.8 NA 4.30 6/21/2009 P2 -09 1980660 50029228760000 0.3 NA 0.3 NA 0.85 6/21/2009 P2 -10 1980970 50029228860000 0.3 NA 0.3 NA 1.70 6/21/2009 .---► P2 -11A 2060260 50029229230100 3.5 NA 3.5 NA 69.70 6/21/2009 P2 -12 1931150 50029223950000 Sealed conductor NA NA NA NA NA P2 -13 1970600 50029227570000 0.5 NA 0.5 NA 2.60 6/21/2009 P2 -14 1981050 50029228880000 1.5 NA 1.5 NA 10.20 6/21/2009 P2 -15A 2070320 50029224090100 Sealed conductor NA NA NA NA NA P2 -16 1931230 50029223970000 3.0 NA 3.0 NA 28.10 6/20/2009 P2 -17 1981370 50029229020000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -18 1940600 50029224710000 0.8 NA 0.8 NA 2.60 6/20/2009 P2 -19A 2070120 50029227650100 0.3 NA 0.3 NA 0.90 6/20/2009 P2 -20 1960590 50029226640000 0.5 NA 0.5 NA 2.60 6/20/2009 P2 -21 1940530 50029224670000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -22 1972490 50029228500000 1.0 NA 1.0 NA 7.70 6/20/2009 P2 -23 1940320 50029224530000 1.3 NA 1.3 NA 11.10 6/20/2009 P2 -24 1980080 50029228540000 1.5 NA 1.5 NA 10.20 6/15/2009 P2 -25 1971110 50029227760000 1.8 NA 1.8 NA 17.90 6/10/2009 P2 -27 1971250 50029227850000 1.3 NA 1.3 NA 8.50 6/10/2009 P2 -28 1950440 50029225510000 3.3 NA 3.3 NA 37.40 4/18/2012 P2 -29 1931470 50029224070000 10.3 NA 10.3 NA 71.40 6/15/2009 P2 -30 1920950 50029222890000 2.8 NA 2.8 NA 17.90 6/10/2009 P2 -31 1940360 50029224560000 2.2 NA 2.2 NA 21.30 6/20/2009 P2 -32 1951350 50029225930000 Surface casing leak NA NA NA NA NA P2 -33B 1972310 50029228120200 2.0 NA 2.0 NA 16.60 6/9/2009 P2 -34 1950660 50029225580000 1.5 NA 1.5 NA 11.50 6/9/2009 P2-35 1951790 50029226200000 1.0 NA 1.0 NA 13.60 6/9/2009 P2 -36A 2060220 50029228010100 1.1 NA 1.1 NA 6.00 6/9/2009 P2 -37A 2050570 50029225760100 2.0 NA 2.0 NA 23.00 6/9/2009 P2 -39 2111230 50029234540000 0.8 NA 0.8 NA 10.20 4/30/2012 P2-40 1972260 50029228370000 0.5 NA 0.5 NA 5.10 6/9/2009 P2-41 1952050 50029226330000 1.5 NA 1.5 NA 17.00 6/9/2009 P2-42 1931430 50029224050000 19.3 NA 19.3 NA 121.60 6/20/2009 P2 -43 2050240 50029232500000 0.8 NA 0.8 NA 6.00 6/8/2009 P2-44 1960630 50029226660000 2.3 NA 2.3 NA 23.80 6/8/2009 P2-45B 2080210 50029227690200 0.8 NA 0.8 NA 5.10 6/8/2009 P246 1931320 50029224010000 2.3 NA 2.3 NA 25.50 6/8/2009 P247 1951900 50029226280000 0.0 NA 0.0 NA NA NA P248 1921260 50029223090000 0.2 NA 0.2 NA 1.70 4/18/2012 P249 1920240 50029222520000 2.5 NA 2.5 NA 18.70 6/7/2009 P2 -50B , 1950960 50029222610200 2.0 NA 2.0 NA 23.00 6/8/2009 P2 -51 1920380 50029222620000 0.3 NA 0.3 NA 0.85 6/7/2009 P2 -52 1972010 50029228260000 3.8 NA 3.8 NA 47.60 6/7/2009 P2 -53 1960410 50029226560000 2.0 NA 2.0 NA 21.30 6/7/2009 P2 -54A 2030300 50029224700100 0.8 NA 0.8 NA 3.40 6/7/2009 P2 -55 1920820 50029222830000 4.0 NA 4.0 NA 79.90 6/22/2009 P2 -56 1951620 50029226100000 2.8 NA 2.8 NA 17.90 6/7/2009 P2 -57A 2022140 50029221830100 15.5 NA 15.5 NA 77.40 6/22/2009 P2 -58 1900080 50029220000000 Sealed conductor NA NA NA NA NA P2 -59A 1982010 50029220960100 Sealed conductor NA NA NA NA NA P2-60 1910910 50029221920000 8.3 NA 8.3 NA 56.10 3/13/2012 ~ i ~.r ,~ ,~ ~ - ,. ~~~ ~~ ~y_ ~ ~~ -~ .. _ _~ - w,.., „~ -. , . ,, .~ ~ ~ , ~;, MICROFILMED 6/30/2010 DO NOT PLACE. ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS RECEIVED- DES o ~ X010 th O 1. Operations Abandon ^ Repa^Vell Plug Perforations ^ Stimulated er f~ A1 ,~ ~ Performed: Alter Casing ^ Pull ~ing Pertorate New Pool ^ Waiver^ Time E~ ~ bas ~+~ Commi Change Approved Program ^ Operat. Shown Pertorate ^ Re-e er Suspended Well ^ Sncherage 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exp-oratory 206-0260 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-22923-01-00 8. Property Designation (Lease Nurgber) : 9. Well Name and Numt)er: ~ ~ ADLO-365548 P2-11A 10. Field/Pool(s): ~ PRUDHOE BAY FIELD / PT MCINTYRE OIL POOL 11. Present Well Condition Summary: Total Depth measured \ 17640 feet Plugs (measured) None feet true vertical ~ 9118.9 feet Junk (measured) None feet Effective Depth measured 17592 feet Packer (measured) 14391 true vertical 9107 feet (true vertical) 8817 Casing Length Size MD TVD Burst Collapse Structural Conductor 118 20" 133# H-40 40 - 118 40 - 118 Surface 5742 9-5/8" 40# L-80 38 - 5742 38 - 4970 5750 3090 Intermediate 14654 7" 26#/29# L-80/13CR 36 - 14654 36 - 8937 7240 8160 5410 7020 Production Liner 665 4-1/2" 12.6# 13CR 14412 - 15077 8827 - 8973 8430 7500 Liner 3226 2-3/8" 4.6#/4.44# 13CR/L-80 14401 - 17627 8822 - 9006 Perforation depth: Measured depth: O 16600 - 16800 O 16840 - 16960 O 17000 - 17160 O 17200 - 17350 _ True Vertical depth: 9057.78 - 9064.59 9066.17 - 9071.98 9073.75 - 9079.77 9081.26 - 9083.31 _ Tubing: (size, grade, measured and true vertical depth) 3-1/2" 9.2# 13CR SURFACE - 14438 SURFACE - 8839 Packers and SSSV (type, measured and true vertical depth) 7"x4-1/2" bkr s-3 gkr 14391 8817 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~-~, ~y~~~ ry ~ 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: 484 614 1985 406 Subsequent to operation: 487 618 1997 392 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 2/9/2010 ReoMS ~e i i ~a ~ Form 10-404 Revised 7/2009 ~- ~~ .ID n rr .? r~.3/rc ,, '' ~ Submit Original Only ~IOfi • P2-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1/26/2010T/I/0=1350/1800/0. (Acid Treatment.) Spear into IA w/ 5 bbls 60/40 meth ~ followed by 259 bbls crude. IA pressured up to 2500 psi. Pump 35 bbls crude down tbg, swap to KCL. Pump 100 bbls 1 %KCL. Swap to pre-flush. Pump 25 j bbls Pre-Flush, 54 bbls DAD Acid. Flushed acid w/ 3 bbls methanol, 58 bbls i `OverFlush. 5 bbls 1 %KCL. Continued on 1-27-10 1/27/2010Continued from 1-26-10 Acid treatment. Pumped remainder of 81 bbls 1%KCL Eflush down Tbg. Freeze protected tree w/ 5 bbls 60/40. DSO to POP. FWHP=800/1140/0 SV,WV shut. MV,SSV,IA,OA Open FLUIDS PUMPED BBLS 105 1%KCL 54 DAD ACID 6 Total rGG- n_~t~a~~ r WELLHEAD = 11 FMC ACTUATOR = BAKER C KB. ELEV = 49.8' BF. ELEV = _ KOP = 1381' Max Angle = 92° @ 16564' Datum MD = Datum TV D = 14462' 8800' SS r SAF OTES: WELL ANGLE> 70° @ 14695' ^ ~ -11 A **CHR E CSG, LNR & TBG** 2021' H 9-518" HES ES CEMENTER 2195' 3-1/2" HES TRSSSV SER. 10 NIP, ID = 2.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATGH PORT DATE 1 42fi2 4061 47 MMG-5 DOME RK 20 09!17100 2 5838 5024 57 MMG-5 DMY RK 0 10/26/98 3 8047 6013 65 MMG-5 DOME RK 20 09/17100 4 9874 6824 64 MMG-5 DMY RK 0 01/22/99 5 11883 7709 65 MMG-5 DMY RK 0 09/17/00 6 13274 8318 64 MMG-5 DMY RK 0 10/26!98 7 14330 8790 61 MMG-5 SO RK 16 09/17100 9-5/8" CSG, 40#, L-80, ID = 8.835" ~--~ 5743, Minimum ID =1.812" @ 14401' BK KB LINER T4P PACKER 7" CSG, 26#, L-80 BTC-M, .0383 bpf, ID = 6.276" --r 7" MARKER JOINT ( 14245' 14389' -{3-y2" x 4-y2" xO, ID = 2.992" 14391 7" X 4-112" BKR S-3 PKR, ID = 3.875" 14395' - 4-112" X 3-1/2" XO, ID = 2.992 14398' BKR SERIES"35" LTP (11/21/09}, ID=1.812" 14405' BOT DEPLOY SLV, ID = 1.920 BKR 6' TIEBACK SLV, ID = 5.250" ~ 14412' TOP OF 4-1/2" LNR -~ 14419' 3-112" TBG, 9.2#, 13CR, .0087 bpf, ID = 2.992" ~--~ 14438' 7" CSG, 29#, 13CR NSCC, .0371 bpf,ID = 6.184" ~--( 14654' MECHANICAL WHIPSTOCK (03/31/06} 15077' RA TAG 15085' PERFORATION SUMMARY REF LOG: MCNL ON 04/19/06 ANGLE AT TOP PERF: 88° @ 14915' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 14915 - 14975 O 04!17100 2-1/2" 4 15000 - 15088 O 10!25/98 2-1/2" 6 15000 - 15088 O 11/05/99 1.56" 6 16600 - 16800 O 04121/06 1.56" 6 16840 - 16960 O 04121(06 1.56" 6 17000 - 17160 O 04/21 /06 1.56" 6 17200 - 17350 O 04/21/06 4-1/2" LNR, 12.6#, 13CR, .0152 bpf, ID = 3.958" ~--~ 15199' 14416' 3-1(2" HES X NIP, ID = 2.813" (BEHIND PIPE) 14419' 7" X 5" BKR HMC LNR HGR, ID = 4.437" 14426' S" X 4-1/2" XO, ID = 3.958" 14427' 3-1/2" HES XN NIP, ID = 2.75" (BEHIND PIPE) 14439' -~3-1/2" WLEG, ID = 3.000" 14425' -~MD TT LOGGED 10/30(99 14676' 4-112" MARKERJOINT MILLOUT WINDOW (P2-11A) 15077' - 15080' ---r 1 ~-ti TOP OF CEMENT PBTD I 2-3/8" LNR, 4.6#, 13CR-80 STL, 17367' .0039 bpf, ID = 1.995" 2-3/8" LNR, 4.44#, L-80 STL, .0039 bpf, ID = 1.995" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/28198 ORIGINAL COMPLETION 09/20/08 ?/SV MIN ID CORRECTION 04124/08 NORDIC 2 CTD SIDETRACK (P2-11A) 07125!09 RLW/PJC PERF CORRECTION {04!21!06) 07103/07 JLC/PJC DRLG DRAFT CORRECTIONS 11/27/09 JCM/SV RESET LTP (11/21109) 11/21/07 RWLlPJC DRAWING CORRECTONS 05110!08 JAF/TLH ORIGINAL COMPLETION 09/06!08 KDC/ PJC SET lTP (08/31/08) POINT MCINTY RE UNIT WELL: P2-11A PERMIT No: 1060260 API No: 50-029-22923-01 SEC 11 T12N R14E 4147.16 FEL 857.43 FNL BP Exploration (Alaska) • ~ INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. ' Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: P2-11A & P2-11APB1 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary Corrected API number. This Data replaces all previously delivered digital data. LAC Job#: 1108858 ~~ - ~~ ~ i ~~iGi G ~."x:~~~~~~`~~.~ ~ i ~ ~~, ~ <~ ~~D~ ~ ~ ~~~~~rr Sent by: Catrina Guirlry Date: 08/20/~ ~ s~, ;,` -, _ ~~ ~ Received b F ~~ 1%~ ~~ y:. ~ ~; Date: ~ ., _ `~ 'U ~-___. ~ _ . ~ . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ~P~ BAICER ~ i1U6NE5 ~m~ ~t~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 r _ 4 Ct--- DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060260 Well Name/No. PRUDHOE BAY UN PTM P2-11A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22923-01-00 MD 17640 TVD 9119 Completion Date 4/2/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATI ON Types Electric or Other Logs Run: GR / ROP /PRESS / RES, MGR / CNL /CCL, MGR /CCL / SCMT (data taken from Logs Portio n of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ype Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 15862 17640 Open 5/15/2006 Electronic Transfer ~.ED Asc Directional Survey 15075 16450 Open 5/15/2006 PB 1 Electronic Transfer ~~~g Cement Evaluation 5 Col 1 14000 17558 Case 5/8/2006 CBUMEM/GR/CCUSCMT ~' 20-APR-2006 ~ Directional Survey 15862 17640 Open 5/11/2006 wR pt Directional Survey 15075 16450 Open 5/11/2006 PB 1 og Pressure Blu 1 14000 14400 Case 7/25/2006 Jewelry Log, Static Log, PRES, TEMP, GR, CCL 27- / ~ ' Apr-2006 ~D C Lis 15121 ~I Fiduction/Resistivity 1 14546 17640 Open 5/14/2007 LIS Veri, GR, ROP w/Graphics TXT, META, ~pt 15121 LIS Verification 1 14546 17640 Open 5/14/2007 LIS Veri, GR, ROP ~ w/Graphics TXT, META, i~Log 15121 Induction/Resistivity 25 Blu 15087 17640 Open 5/14/2007 Multi Propagation, Resisviity, GR 15-Apr-2006; I ~og 1511 Gamma Ray 25 Blu 15087 17640 Open 5/14/2007 MD GR 15-Apr-2006 j ~og 15121 Gamma Ray 25 Blu 15087 17640 Open 5/14/2007 TVD GR 15-Apr-2006 IiED C Lis ~~ 15122 Induction/Resistivity 1 15054 16450 Open 5/14/2007 P61 LIS Veri, GR, ROP w/Graphics TXT, META, ~D C Lis 15122vC.IS Verification 1 15054 16450 Open 5/14/2007 PB1 LIS Veri, GR, ROP w/Graphics TXT, META, ) ~,0~ V 15122 Gamma Ray 25 Blu 15087 16450 Open 5/14/2007 P61 MD GR 5-Apr-2006 ~ 'Log 15122 Gamma Ray 25 Blu 15087 16450 Open 5/14!2007 PB1 TVD GR 5-Apr-2006 ~og 15122 Induction/Resistivity 25 Blu 15087 16450 Open 5/14/2007 PB1 MD GR 5-Apr-2006 (~- C Lis 15480~utron 14186 17575 Case 10/3/2007 GR, MCNL w/PDF graphics i DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060260 Well Name/No. PRUDHOE BAY UN PTM P2-11A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22923-01-00 M9 17640 TVD 9119 Completion Date 4/2/2006 p~ _ _ Log 15480 eutron C Las 15629 ~xrUuction/Resistivity C Las 15630 'induction/Resistivity Well Cores/Samples Information: Name ADDITIONAL INFORM/~ION Well Cored? Y N Chips Received? '~T1~ Analysis Received? Comments: Daily History Received? ~ N Formation Tops ICJ N Compliance Reviewed By: __ Completion Status 1-OIL Current Status 1-OIL UIC N 25 Blu 14200 17595 Open 10/3/2007 MCNL, GR, CCL, CNL 19- Apr-2006 14547 17640 Open 10/26/2007 LAS, ATR, RPM, GR, w/PDF graphics 15505 16450 Open 10/26/2007 PB1 LAS, ATR, RPM, GR, w/PDF graphics Sample Interval Set Start Stop Sent Received Number Comments Date: ~a Date 10-12-2007 Transmittal Number:92914 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have anv 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: 02-126 ab~a-- cs~r_ ~'_~S_6l~- __ 02-16C ~=rQF6.~ __~~s-_~~.~____....___.. -_ 02-1_6CP61 a0 '~-0$~__~_t56!9 ___ - - 04-01 A , ~p~-- a35 --~ t5'L~.C~----~---- 15-16B_ ~'~Olv_.- ~~---i_~68.L 15-1613P61._ ~~-Q~-3 t.!; (~_____ 15-16BPB2_ ~n~~ n~~ L.~c?3 -.~.., 18-27Ds7Q~-133 ~~2_`L----___.._ 18-27DP61_._..20~_l~~ _.!_~~~-_.-----_.__-------- A-42A___ ~-l3r~ l5~a6._ _ __ _ _-, _.. G-24A i~64= O_1ta?_- T~~ ___ G-24APB1 aU(o.-fl~-a....1~(Ao?~---__.__.___.___.-.. P2-11APB1 _2C~Co--c~-c~-_lo,.~.1`~b3.Q...____~.._.. P2-36A _.~i.~ -..Qa-a__15~3/-._ _...___ P2-37A aO,S--OS~-.._..1 _. _ ~~(o3a P2-37APB1.:.~:Q.S- ~.DS'~.._~.-3~--~0~-..~..~__ - A u~aprn_ Za~_~3_y_- - - - -.._ Z-102 ~d ~4P=' _ Z-102PB Please Sign and Return one copy of this transmittal. ~ _~ ,~ ;j~~~, 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 09/28/07 NO.4440 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite aoo Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well _Ini. 8 1 .... ne~...:..a:..., n..a.. e: n~:~- nn 15-06A 11661158 MCNL #r C 06/21/07 1 F-26B 11216200 MCNL ~l ~/ ~ 06/06106 1 P2-11A 11285926 MCNL ~ 04/19/06 1 1 C-316 11745223 MCNL ~~./ 05/31/07 1 1 E-03A 11628773 MCNL ~ .C/ 05/09/07 1 1 K-12A 11745224 MCNL Q ~ ~, 06/02/07 1 1 18-10B 11485771 MCNL 4 / </~-(0 11/08/06 1 1 C-08B 11209599 MCNL --~j ~ ~ ~ $L 04/22/06 1 1 D-30B 11628774 MCNL L '~ 05/10/07 1 1 rLGM~G Nvn:\v\\LCV~aC RCMGr' 1 Oi JWIVII\b AI\U RC 1 URIYInIb VIVO IrVYT tAlfl'7 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~ ~ ~ ~m ~~~ ~: 900 E. Benson Blvd. ~ ~-`~ ~ F~ ~~ ~~ k - Anchorage, Alaska 99508 Date Delivered: ~~~' ~~ ~ ~~~~~~ ,~.~... r`..9 ., Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: I 1 U C~ Transmittal Form INTEQ BAKER _ _ NUGHES Anchorage GEOScience Center - _ ~_- a~:... y~~.v I 1 ~ To: AOGCC 333 West 7t" Ave, Suite 100 Anchorage, Alaska ._- ~, ~r . `Y1 `~~x ,, 99501 ~~'' ~ ~..~ ~~ _ ` `` ~` Attention: Christine Mahnken m~~~~ .~ ~i ~C.)~ ~ i ~ X418: (>Critiid~9~~`g,~eE Reference: P2-llA _ ~'f ' ~'~4'"~`~ Contains the following: 1 LDWG Compact Disc (Includes Graphic~Lnagefiles) 1 LDWG lister summary l blueline - GR Directional'Measured Depth L,og 1 blueline - MPR/Directional TVD Log 1 blueline - MPR/Directional Measured Depth Log LAC Job#: 1108858 Sent By: Deepa J glekar Date: May 09, 2007 ~- ~W~ Received By: y_N ( Date: ~ %~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 ~~~ _ ~~~ Direct: (907) 267-6612 FAX: (907) 267-6623 .fit t J~/~ i ~' --- ', i J ~~ ...~ 'L -- ~_ y- _ _ ~` I , ~t T _ _.:._ _ i _ r'~~ ~ :~ I - -~ _ _, ~I I --: • Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken BAKER ~~_W_~ HUGHES = Anchorage GEOScience Center - ---- ~..~.., ~b_N ~1 . I 6~Is~iY .%. ~e- c0U1 Reference: P2-11APB1 t~~~c~':+~`~~ Contains the following: 1 LDWG Compact Disc (Includes GraphicIrriagefiles) 1 LDWG lister summary 1 blueline - GR Directional Measured Depth Log l blueline - MPRIDirectional TVD Log ; 1 blueline - MPR/Directional Measured Depth Log I ~ LAC Job#: 1108858 ice= r_-_~._,_„~-~-___._._.______.~. _.....:.. ~~_.._'__ ___:._:_._.. .___:_ _....~__ ._. ,.._;. __ ...... .:,'".. _.. :~ Sent By: Deepa Jogl kar Date: May 09, 2007 Received By: y_- Date: ~ °~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska ~~~ ..--(~~ (~ 99518 Direct: (907) 267-6612 ~'1 ~ (~~ FAX: (907) 267-6623 7i ii _ ;~ i j! __ ~- I --. ;: ~ ~` 4 . ~ I -{ ~ C P~ I --_ ti .. _, - j----.: ..~ _~ < - - _i a Y ~~~. -- -- i ~i - ~---- - o~n slos S~6b~rger N0.3880 Alaska Data 8: Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 / Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503-2838 ~~j ~ ~ ~~ tiv Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Loa Description Date BL Color CD 5-1 11211420 L 0 7-08 5 E R FIL 061 4/06 1 P2-11A 11221564 JEWELRY/STATIC SURVEY 04!27/06 1 13-08A 11217266 INJECTION PROFILE 07/12106 1 P2-01 11223106 STATIC PRESSUREIJEWELRY 03!25106 1 L5-08 11217256 PROD PROFILE W/GHOST 8 DEFT 06106/06 1 16-04A 11217245 PROD PROFILE W/DEFT 05/08/06 1 05-40 11223123 LDL 07/07/O6 1 17-09 11211412 PROD PROFILE W/DEFT 8 GHOST 06/26/06 1 MRC-07 N/A SENSA/MEMORY GLS 04/22106 1 04-18 1121584 USIT 06/27106 1 L-51 11212873 USIT 06128/06 1 04-31 11217264 USIT 07107/06 1 D-14A 11217265 USIT 07!09106 1 PSI-07 10703937 MDT 10/13/03 1 02-166 11209601 MCNL 04/25/06 1 1 L2}18A 11217234 MCNL 04/06!06 1 1 L5-09 11212847 MCNL 04125/06 1 1 2-26A 11216205 MCNL 07/05/06 1 1 12-01 11072866 RST 07/06/05 1 1 E-17A 10928602 MCNL (Prints sent 1124/05) 10/30/04 1 Alaska Data & Consulting Services PeVotechnical Data Center LR2-1 2525 Gambeil Street, Suite aoo 900 E. Benson Blvd. Anchorage, AK 99503-2838 Anchorage, Alaska 99508 ATTN: Beth .7 STATE OF ALASKA ~ ALAS~IL AND GAS CONSERVATION CONI1~iiISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ®Oil Q Gas Q Plugged ^ Abandoned Q Suspended Q WAG zoaAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 4/24/2006 12. Permit to Drill Number 206-026 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 4/1/2006 13. API Number 50-029-22923-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 4/15/2006 14. Well Name and Number: PBU P2-11A 1 FSL, 1115 FWL, SEC. 11, T12N, R14E, UM Top of Productive Horizon: 1097' FNL, 317' FWL, SEC. 18, T12N, R15E, UM g, KB Elevation (ft): 49.8' 15. Field /Pool(s): Prudhoe Bay Field /Point Mclntyr Pool Total Depth: 434' FSL, 2475' FWL, SEC. 07, T12N, R15E, UM 9. Plug Back Depth (MD+TVD) 17592 + 9107 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 681351 y- 5998580 Zone- ASP4 10. Total Depth (MD+TVD) 17640 + 9119 Ft 16. Property Designation: ADL 365548 TPI: x- 691137 y- 5997725 Zone- ASP4 Total Depth: x- 693256 Y- 5999312 Zone- ASP4 11. Depth where SSSV set 2195' MD 17. Land Use Permit: Thi k f P f t 18. Directional Survey ®Yes Q No 19. Water depth, if offshore N/A MSL ness o erma ros 20. c 1800' (Approx.) 21. Logs Run: GR / ROP /PRESS / RES, MGR / CNL /CCL, MGR /CCL / SCMT ASING, INER AND EMENTING ECORD CASING ETTING EPTH MD ETTING EPTH TVD HOLE OUNT SIZE WT. PER FT. GRADE Op OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 133# H-40 40' 118' 40' 118' 30" Driven 9-5/8" 40# L-80 38' 5742' 38' 4970' 12-1/4" 1295 sx PF'E', 470 sx Class 'G' 7" 26# / 29# L-80 / 13Cr 36' 14654' 36' 8937' 8-3/4" 290 sx Class 'G' 4-1/2" 12.6# 13Cr 14412' 15077' 8827' 8973' 8-3/4" 120 sx Class 'G' 2-3/8" 4.6# / 4.44# 13Cr / L-80 14401' 17627' 8822' 9006' 3" 101 sx Class 'G' 23. Perforations open to Production (MD +TVD of Top and, " ' 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 1.56" Gun Diameter, 6 spf 3-1/2", 9.2#, 13Cr 14439' 14391' MD TVD MD TVD 16000' - 16800' 9031' - 9065' 16840' - 16960' 9066' - 9072' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 17000' - 17160' 9074' - 9080' 17200' 17350' 9081' 9083' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED - - 5900' Freeze Protected w/ 51 Bbls of Diesel 26. PRODUCTION TEST Date First Production: April 28, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 5/9/2006 Hours Tested $ PRODUCTION FOR TEST PERIOD • OIL-BBL 992 GAS-MCF 769 WATER-BBL 26 CHOKE SIZE 60 GAS-OIL RATIO 775 Flow Tubing Press. 74 Casing Pressure 2,311 CALCULATED 24-HOUR RATE OIL-BBL 2,977 GAS-MCF 2,306 WATER-BBL 78 OIL GRAVITY-API (CORK) 27. CORE DATA Br9ef description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit c ships; if none, state "none". Y f 4 None ~ (.TI ~ca~°J ,%~~~. `°~`~ f~t)MS BFI f~a~ ~ ~ coos ~ bbl ~ ~w ~~~ Form 10-407 Revised 12/2003 I I ~ ~ ~N~IED ON REVERSE SIDE G 28. GEOLOGIC MARKS 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kuparuk 14710' 8957' None LC3 14710' 8957' LC2 14823' 8965' LC3 16402' 9061' LC2 17055' 9076' Kuparuk 17380' 9083' Kuparuk 17443' 9086' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date ~5~~8 b PBU P2-11 A 206-026 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. ~riuinq engineer: Barbara Las/ey, 564-5126 INSTRUCTIONS GeNertn~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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). Irene 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces bn 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: True vertical thickness. 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: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only • • SP EXPLORATION:. Page 1 of 24 Operations Summary Report Legal Well Name: P2-11 Common WeII Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date- From - To Hours Task Code NPT Phase Description of Operations 3/28/2006 06:00 - 06:30 0.50 MOB P PRE Wait on crew change and security to begin move off of DS 7. 06:30 - 07:00 0.50 MOB P PRE Pre rig move safety meeting with rig crew, TP, TL, WSL and 07:105 -104:00 6.75 MOB p I PRE PRE 14:00 - 22:00 I 8.001 MOB I P I I PRE 22:00 - 23:00 I 1.001 MOB I P I I PRE 23:00 - 00:00 I 1.001 MOB I P I I PRE 3/29/2006 00:00 - 02:00 2.00 BOPSU~ P PRE 02:00 - 06:20 4.33 BOPSU P PRE 06:20 - 07:10 0.83 BOPSUF~ P PRE 07:10 - 08:00 0.83 BOPSU~j P PRE 08:00 - 08:45 I 0.751 CLEAN I P I I WEXIT 09:00 -100:00 10.00 CLEAN P WEXIT 10:00 - 12:30 2.50 CLEAN P WEXIT 12:30 - 14:30 I 2.001 CLEAN I N I SFAL I WEXIT 14:30 - 15:45 1.25 CLEAN P 15:45 - 17:00 1.25 CLEAN P 17:00 - 17:10 17:10 - 17:30 17:30 - 19:00 19:00 - 20:00 20:00 - 21:30 21:30 - 23:30 0.171 CLEAN I P 0.33 CLEAN P 1.50 CLEAN P 1.00 CLEAN P 1.50 CLEAN P 2.00 CLEAN P 23:30 - 00:00 3/30/2006 00:00 - 03:00 03:00 - 04:00 0.501 CLEAN P 3.00 CLEAN P 1.00 CLEAN P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT security. Discuss route of move, proceedures, hazards and mitigations. Jack up rig and prepare for move to PM2. Begin rig move. Depart DS 7 headed down oxbow road toward Pt. Mac #2. Stage rig on PT Mac #2 pad. Wait for well to be loaded and killed with LRS pumping unit. Injection rate at 3000 psi was 1.5 bpm. 220 bbls total were pumped during well kill. ISITP: 1650 psi. Final SITP: 220 psi. PJSM with crew and DSM. Shut in adjacent flowing wells. Spot herculite and rig mats around tree. MI and spot rig over well. Accept rig at 2300 hrs on 3/28/2006 Install berm around cellar. Seal cellar bottom. Spot cuttings box and misc equipment. Spot camps. Complete prep work in cellar. NU BOPS and riser. Test BOP equipment. Witness waived by AOGCC. SD operations for crew change and pre tour meeting. Continue with BOP test. Test completed ok at 08:00. Witness waived by AOGCC, Jeff Jones. Rig up hydraulic control lines from rig ESD controls to adjacent wells 10 and 12 with the assistance of pad operator and DSM. Also check that our rig accumulator panel is capable of 5000-5500 psi to ensure that SSSV will remain open. PJSM Re: Stabbing pipe and reheading. Pull pipe over and stab in injector. Build BHI CTC and UOC. Meg line. Line failed insulation check. Check out cable and associated eq. Found damaged Jupiter plug in reel house. Change out for replacement plug. Check line again. Checks ok. Pump 15 bbls methanol, follow by 9.6 ppg brine from pits. Load coil with fluid. Taking returns to tiger tank. Pumping at a low rate to avoid damaging cable umbilical. Pre spud meeting followed by weekly safety meeting. Meetings held on tour while circulating to load coil with fluid, and off the critical path. Continue circulating to the pits while blowing down the hardline to the tiger tank. Rig up BHA #1 to RIH with a nozzle and kill/cleanout well. RIH with BHA #1:2.25" JSN-Stinger bar-X/O-UOC-CTC. Taking gas cut returns to tiger tank. Hold TL mtg and weekly safety mtg in Ops cab while RIH. COntinue to RIH. Shut in well and allow WHP to build. Circ well at 1.98 bpm @ 3570 psi. Hold 250 psi WHP. Get several btms up. Take gas bubbles outside. Begin displacement to 9.6 flo pro. Displace well to 9.6 flo pro while pulling out of hole. At surface. Get off well. Unstab coil. MU Baker dummy WS Printed: 5/1/2006 1:31:22 PM • • BP EXPLORATION Page 2 of 24 Operations Summary Report Legal Well Name: P2-11 Common Well Name: P2-11 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date I From. - To ~ Hours Task ) Code I NPT Spud Date: Start: 3/28/2006 End: 4/24/2006 Rig Release: 4/24/2006 Rig Number: .Phase 3/30/2006 103:00 - 04:00 I 1.001 CLEAN I P 04:00 - 06:00 I 2.00 CLEAN P 06:00 - 07:35 1.58 CLEAN P 07:35 - 09:45 I 2.171 CLEAN I P 09:45 - 10:30 I 0.751 CLEAN I P WEXIT WEXIT WEXIT WEXIT WEXIT 10:30 - 12:30 I 2.001 CLEAN I N I SFAL I WEXIT 12:30 - 14:55 I 2.421 CLEAN I N I SFAL I WEXIT 14:55 - 15:30 I 0.581 CLEAN I N I SFAL I WEXIT 15:30 - 18:15 I 2.75) CLEAN I P I I WEXIT 18:15 - 19:00 I 0.751 CLEAN I P I I WEXIT 19:00 - 19:45 0.75 STWHIP P WEXIT 19:45 - 23:00 3.25 STWHIP P WEXIT 23:00 - 00:00 1.00 STWHIP P WEXIT 3/31/2006 00:00 - 00:30 0.50 STWHIP P WEXIT 00:30 - 01:00 0.50 STWHIP P WEXIT 03:45-05:00 I 1.25~STWHIPIP I (WEXIT 06:105 - 08:15 I 2.001 STWHIP P I WEXIT 08:15 - 09:30 1.25 STWHIP P Description of Operations on Inteq MWD tools. Stab coil. Test mwd tools. Get on well. Run in hole. Crew changeout and pre tour TL meeting. Held on tour, but off the critical path while we RIH. Pumps at 0.5 bpm. Log tie in pass over GR charecter at 14625', and down to 15156'. Started taking wt at 15156'. Note - Service coil cleanout made to 15144', CTM. GR tie in ok, but not great. Significant shift from PDC log due to the presence of Barium scale. Pumps at 0.5 bpm. Log tie in pass down for CCL to confirm we are on depth. Log from above tubing tail to 15156'. Set down at 14123', picked up and fell right thru. This is probably the XN nipple at 14127'. BHI CCL log is bad, and we can't confirm our tie in at the tubing tail. There may be a problem with the GR log generated previously. Take the time to attempt to sort out the problem. It is very important, especially with the radioactive scale in this well that we get a tie in log we can have confidence in. Allow MWD and DD to sort out the problem. BHI MWD hand unable to resolve issue. Can not get a CCL log, and have concerns about the validity of the GR log. MWD hand suspects a software problem and needs to consult with people in Houston. Yo-yo'd and circulated at max rate while BHI figures out software. Went up and down 5 times thin XN nipple while pumping at full rate. Didn't see any hangups, but did get a low but significant amount of additional fine material out of the hole. BHI confirms problem is a software problem. CCL is definatly bad. Suggests that GR should be ok due to its slower logging speed. Make an additional logging repeat pass with GR to confirm that it agrees with first log. The repeat logging pass confirms that the BHI GR data is repeatable. POOH to pick up the whipstock. At surface. Flow check well. Hold TL mtg and PJSM to discuss BHA. Get off well. Unstab coil. LD dummy WS. MU Baker WS on Inteq mwd tools. Stab coil. Test mwd. Get on well. Run in hole. Log gr tie in from 14550' to 14650'. Subtract 10'. Log second down pass from 15080' to 15090'. RIH to 15089.1'. PU to up to 30k# string wt. Orient to low side TF. Close EDC and pressure coil to 1500 psi. Pressure to 2000 psi. Press to 2500 psi. Tol sheared and coil pressure dropped to 1650 psi. WS top: 15077'. WS btm: 15089'. POOH circulating at min rate. Stop at 150'. Flow check. Get off well. Continue to POOH and inspect coil for wear. LD BAker setting tool. MU window milling assembly. Stab coil. Test mwd. Get on well. Run in hole. Crew change and pre tour technical limits meeting. Log tie in pass over GR charecter at 14600'. Make -22' correction. Printed: 5/1/2006 1:31:22 PM • • 8P EXPLORATION Page 3 of 24 Operations Summary Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 .Rig Name: NORDIC 2 Rig Number: Date. From - To Hours Task Code NPT Phase Description of Operations 3/31/2006 09:30 - 17:30 8.00 STWHIP P WEXIT Dry tag at top of whipstock. Pick up, kick pumps on tag at 15076.6'. Begin milling window. Apparently through casing. 17:30 - 19:45 2.25 STWHIP P WEXIT Drill 10' of rat hole. 4130 psi @ 1.32 in/out. Make two up and down ream passes. Dry drift. Window smooth. 19:45 - 23:45 4.00 STWHIP P WEXIT Pull out of hole. Stop and try to get UTIM working. Concerned about coil life management in chrome tbg. Unable to cut coil due to length required for proposed TD. Stop at 100'. Get off well. Inspect 100' coil above connector. Pipe wear is minimal. 23:45 - 00:00 0.25 STWHIP P WEXIT Unstab coil. LD BHA. 4/1/2006 00:00 - 01:00 1.00 DRILL P PROD1 Continue to LD milling BHA. Pick up orienter. Make up HYC bi-center bit. Stab coil. Test mwd. Get on well. 01:00 - 04:15 3.25 DRILL P PROD1 Run in hole. 04:15 - 04:45 0.50 DRILL P PROD1 Log gr tie in from 14,580'. Subtract 34.5' correction. 04:45 - 05:00 0.25 DRILL P PROD1 Run in hole to window. Pass through window smoothly. 05:00 - 06:00 1.00 DRILL P PROD1 Drill ahead from 15095'. 4200 psi fs at 1.55 bpm in/ 1.4 out. 06:00 - 08:30 2.50 DRILL P PROD1 Drill ahead from 15099'. PVT=402 bbls. Drilling at 1.40/1.26/3933 psi. IAP=454 psi, OAP=229 psi. WOB=670 lbs. BHP=5647 psi. Drilling slow at first, but improved after 10'. Out micro motion is not reading correctly. 2 hours into the tour PVT = 403 bbls. No fluid losses occuring. 08:30 - 11:55 3.42 DRILL P PROD1 Stop at 15150'. Make wiper up to window, then back to TD to clean hole. POOH open EDC above window and POOH pumping at full rate to clean hole. No problems at the window. 11:55 - 12:05 0.17 DRILL P PROD1 PJSM with rig hands, BHI, BHI visitors and WSL. Discuss hazards and plan forward for BHA swap. 12:05 - 14:30 2.42 DRILL P PROD1 Break off injector at 100'. POH inspecting coil visually and with SWS UTIM. No problems found. Blow down BHA. Lay down bit and motor. Lay down MWD tool. Hook up rib steer motor on catwalk and check it electrically. Pick up rib steer BHA. 14:30 - 17:45 3.25 DRILL P PROD1 RIH with BHA #6, Rib Steer motor plus Res tool. Running a new Hycalog bit. 17:45 - 19:00 1.25 DRILL P PROD1 Log tie in pass down from 14580'. 19:00 - 20:15 1.25 DRILL N DFAL PROD1 Experiencing software problems with coil track. Reciprocate in liner while working on problem. 20:15 - 20:45 0.50 DRILL N DPRB PROD1 Unable to work through window with ribsteer BHA. Make several attempts at different speeds and circulating at min rate. Set down with the bit at 15085' each time. 20:45 - 00:00 3.25 DRILL N DPRB PROD1 Pull out of hole for orienter, string reamer, and window mill. 4/2/2006 00:00 - 01:15 1.25 DRILL N DPRB PROD1 LD ribsteer tools. MU 0.8 deg Inteq motor with orienter, string reamer, and diamond speed mill. Stab coil. Test mwd. Get on well. 01:15 - 04:30 3.25 DRILL N DPRB PROD1 Run in hole. 05:30 - 06:00 0.50 DRILL N DPRB PROD1 Log gr tie in from 14,580'. Subtract 47' correction. Log RA tag to verify depth. 06:00 - 07:00 1.00 DRILL N DPRB PROD1 Hold pre tour TLM meeting with rig crew, Geo, MWD, TP, WSL. 07:00 - 07:30 0.50 DRILL N DPRB PROD1 Begin reaming window. Plan to make a reaming pass every 30 degrees completely around the clock. Note -Window mills were 2.73" when recovered from initial window milling. Rib steer BHA is 2.68" OD at the wear rig 7' behind the bid. The diameter as measured at the ribs was 2.71". The ribs have some sacraficial hard facing on them. Printed: 5/1/2006 1:31:22 PM • • BP EXPLORATION Page 4 of 24 Operations Summary Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/2/2006 07:00 - 07:30 0.50 DRILL N DPRB PROD1 While this milling run was made the BHI engineer ground down the hard facing on the ribs to be less than 2.68". 07:30 - 08:45 1.25 DRILL N DPRB PROD1 BHI lost communication with the BHA. Troubleshoot problem. 08:45 - 12:30 I 3.751 DRILL I N I DPRB I PROD1 12:30 - 15:45 I 3.251 DRILL I N I DPRB I PROD1 BHI found a damaged Jupiter connection where their cable enters into the Schlumberger collecter. This is a repeat failure. The SWS Cell leader will be contacted to investigate a better solution. The Jupiter connection was repaired, and the BHI BHA is now working again. Resume milling window area. Getting a small amount of motor work during passes thru window. Get 30 Ibs motor work when TF is low side, getting 100 Ibs motor work when TF is high side, which is 180 degrees out from the whipstock setting angle. Continue reaming window every 30 degrees of TF. POOH pumping at full rate to pick up rib steer BHA again. Never saw any real significant amount of motor work while milling. Note - CTD Cell leader, Eloy Muniz examined the Jupiter plug problem on the collector and has formulated a plan. The SWS crew will attempt to repair when we are OOH. 15:45 - 17:50 2.08 DRILL N DPRB PROD1 PJSM while flow checking well. Discuss plan forward, hazards, and mitigations. Check well for flow. No flow observed. Break off lubricator. Lay down BHA. Check out rib steer BHA on catwalk. Make up rig steer BHA. 17:50 - 20:45 I 2.921 DRILL I N I DPRB I PROD1 20:45 - 21:30 0.75 DRILL N DPRB PROD1 21:30 - 00:00 2.50 DRILL P PROD1 4/3/2006 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 00:45 0.25 DRILL P PROD1 00:45 - 05:30 4.75 DRILL P PROD1 05:30 - 06:00 0.50 DRILL P PROD1 06:00 - 09:00 3.00 DRILL P PROD1 Note -Mills were recovered with no additional wear. Whipstock mill gauged 2.73" go, 2.72" no-go. String reamer gauged 2.73" go, 2.74" no-go. RIH with BHA #8: Hycalog DS100 (Full Round Cutters, TREX)-Rib Steer Motor-RES-GR-DPS-EDC-OC-CTC. Log gr tie in from 14,580'. Subtract 5' correction. Run in hole. Through window with a few bobbles. Tag btm at 15150'. Drill ahead from 15150'. 3850 psi fs at 1.36 in/out. 200-300 dpsi. DHWOB: 2.5-3.5k#. Initial ROP: 60 fph. Rib steer appears to be working....so far so good. BHP/EDC: 5664/12.22 ppg. IA/OA/PVT: 4171198/425 bbls. Pump hi-vis sweeps every hour to aid hole cleaning. Drill ahead from 15,270'. Pump hi vis sweeps every hour. Wiper trip to window. Hole smooth. Drill ahead from 15,300'. 3950 psi fs at 1.37 bpm in/out. Software glitch in mwd system. Shut down tool and re-start. Re-boot surface systems. Resume drilling. Wiper trip to the window. Resume drilling. PVT=427 bbls. IAP=570 psi, OAP=420 psi. 1.39/1.44/4450 psi. In density=9.53 ppg, out density=9.49 ppg. ROP=65 fph. Free spin 4150 psi at 1.3 bpm. Pumping 20 bbl high vis sweeps 1 per hour to assist in hole cleaning. 09:00 - 09:40 0.67 DRILL P PROD1 Wiper trip to shoe. Slight drag as we picked up off bottom. PU at 32 klbs. Wiper at 28 klbs. PVT=427 bbls. Called for swap Printed: 5/1/2006 1:31:22 PM ;~ • BP EXPLORATION Page 5;of 24- Opelrations Summary Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date From =To Hours :Task Code NPT Phase Description of Qperations 4/3/2006 09:00 - 09:40 0.67 DRILL P PROD1 to new mud. Currently using a used system. 09:40 - 10:20 0.67 DRILL P PROD1 Resume drilling ahead. Free spin 3280 psi at 1.3 bpm. Drilling at 1.27/1.48/4550 psi. Need to pick up to reboot CCAT. Pickup 50', then can't run down. Pickups clean each time. Nothing on DHWOB sensor. Make short wiper trip up hole. Returns are good. Ribs are retracted. Attempt to open and close ribs. RIH ok. 10:20 - 11:15 0.92 DRILL P PROD1 Stall, Pickup and can't run back in. Nothing on DHWOB sensor. Ribs are closed. Either we have junk beside us, or some sort of problem with the BHA. Wiper to the window. Smooth, no problems. Jog 100' below the window. Pull up thru the window. Draggy pulling thru the window with a 4000 Ib overpull. Pull up hole 100'. Run back down hole in liner. No problems observed. Pumps to minimum. Run thru the window clean. Run back to bottom clean. RIH weight at the window =8500 Ibs with pumps on. 11:15 - 14:00 2.75 DRILL P PROD1 Resume drilling. Taking new mud off the vac truck. ROP=80 fph. 12:30 - 12:45 0.25 DRILL P PROD1 Had a stall, picked up and couldn't run back to bottom. Try several time, can't go down. Rib steer is closed. Pull up to 15450', then can run in ok. 12:45 - 14:00 1.25 DRILL P PROD1 Drill ahead. 14:00 - 14:40 0.67 DRILL P PROD1 Wiper trip to the window. Clean PU off bottom at 29 klbs. Clean to 15110'. Clean back to bottom. 14:40 - 17:40 3.00 DRILL P PROD1 Back on bottom. Free spin = 3990 psi at 1.25 bpm. Drilling at 1.25/1.25/4130 psi. Still taking on new mud from Vac truck. 17:40 - 18:45 1.08 DRILL P PROD1 Wiper trip to window. Hole smooth. 18:45 - 21:15 2.50 DRILL P PROD1 Drill ahead from 15,950'. ROP: 50-65 fph. Smooth drilling. 21:15 - 22:30 1.25 DRILL P PROD1 Wiper trip to to 500' above window (into 60 deg hole angle section). Pump hi-vis sweep. 22:30 - 22:45 0.25 DRILL P PROD1 Log gr tie in across RA tag. Add 11' correction. 22:45 - 23:15 0.50 DRILL P PROD1 Run in hole. 23:15 - 00:00 0.75 DRILL P PROD1 Drill ahead from 16,100'. On a hard spot ?. Difricult to get drilling again. Had several stalls and pick ups before drilling resumed. 4/4/2006 00:00 - 03:00 3.00 DRILL P PROD1 Drill ahead from 16,105'. 3950 psi at 1.28 bpm in/out. 300-450 dpsi. DHWOB: 3-4k#. ROP: 40-60 fph. BHP/ECD: 5879/12.6 ppg IA/OA/PVT:568/404/384 bbls. 03:00 - 04:15 1.25 DRILL P PROD1 Wiper trip to window. Pump hi vis sweep timed as bit nears window. Hole smooth. 04:15 - 05:30 1.25 DRILL P PROD1 Drill ahead from 16,250'. Get stuck at 16279'. Appears to be differential. Shut down pumps and rest hole. Came free after 5 minutes. Short trip to 16220'. Get stuck again. Rest hole. 05:30 - 06:00 0.50 DRILL P PROD1 Got free. Make wiper to window. 06:00 - 07:00 1.00 DRILL P PROD1 Crew change and pretour meeting. Held off the critical path while we short trip. Held in Ops cabin. 07:00 - 07:20 0.33 DRILL P PROD1 Log tie in pass down over RA tag. Make +6.5' correction. 07:20 - 07:55 0.58 DRILL P PROD1 Run back in hole to resume drilling. 07:55 - 10:25 2.50 DRILL P PROD1 Back to bottom. No problems running in the hole. Resume drilling. 10:25 - 12:00 1.58 DRILL P PROD1 16385'. Drilling along, took a stall, and started having losses. Possibly crossed a sub seismic fault. Drilling at 1.28/0.88/4435 psi. PVT=369 bbls. Continue drilling ahead. Printed: 5/1/2006 1:31:22 PM BP EXPLORATION Page 6 of 24 Operations Summary Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: .:Date From - To Hours Task Code NPT Phase Description of Operations 4/4/2006 12:00 - 15:45 3.75 DRILL P PROD1 Make long wiper trip to window, then up to 13000' inside tubing. Pump at full rate on way OOH. No problems in open hole. 15:45 - 18:45 3.00 DRILL P PROD1 Back on-bottom. Losses persist: 1.27/0.97/4500 psi. PVT=261 bbls. Drilling @ -60 fpm. Pumps kicked out a few times due to high circulating pressure (pump kick-out set @ 4850psi). 18:45 - 19:55 1.17 DRILL N SFAL PROD1 BHI PC lockup. Wiper (200') while reboot PVT 221 See drastic increase in GR w/ associated decrease in all resistivity curves starting at 16385' 19:55 - 22:00 2.08 DRILL P PROD1 Resume drilling from 16423' 1.26/1.18/4500/120L w/ 100-200 psi dill w/ 2k wob at 13.05 ECD w/ very erratic and slow penetration rate. Some minor overpulls. Determine this is the Kalubik. Drill to 16450' while wo vac trucks for mud swap, but find out that possible fire at GC2 delayed trucks so cancel-will swap when back at TD with sidetrack assy 22:00 - 23:00 1.00 DRILL P PROD1 Wiper to window was clean. Relax ribs. Had minor overpulls before window. RBIH to 15125' and had some wt loss spots. Circ thru bit 1.0 bpm while pull thru window w/ minor overpull PVT 204 23:00 - 00:00 1.00 DRILL P PROD1 Open EDC. POOH 1.47/4000 Weekly crew safety mtg 4/5/2006 00:00 - 02:15 2.25 DRILL P PR001 Finish POOH 1.46/3300 PVT 140 Check last 100' of CT and found flat spots and 0.125" external wall loss max Function test pipe rams (weekly test) 02:15 - 02:45 0.50 DRILL P PROD1 LD drilling BHA Finish function test of stack components 02:45 - 06:10 3.42 DRILL P PROD1 Cut off CTC. Clamp a-line to stub. Stab back on. Reverse slack back at 2.0/4000. Cut off a total of 24' CT. Replace packoff. Install CTC and PT 30k. Head up BHI and meg test 46 ohms. PT CTC at 3900 psi 06:10 - 06:45 0.58 DRILL P PROD1 Circ to warm CT while conduct TL/safety mtg 06:45 - 07:15 0.50 STKOH P PROD1 Open up to well; fluid level @ surface. MU 1.5 bend motor & R60 w/ brass cap &RIH. Start taking on new mud to pits. 07:15 - 11:20 4.08 STKOH P PROD1 RIH & tie in to RA tag; -6' correction. Continue RIH. 12:00 - 15:25 3.42 STKOH P PROD1 Start troughing @ 15,945' 180 TF; 1.3/0.9/4200 psi. PVT 390 bbls. Trough to 15,965' X 2. 15:25 - 18:25 3.00 STKOH P PROD1 Start time drilling @ 15,965'. 1.3/0.9/4280 psi. PVT 327 bbls. Get to 15971' and won't take wt 18:25 - 22:25 4.00 STKOH P PROD1 Restart troughing down from 15945-15965' and perform thrice at 1.33/0.88/4600/175L at 10'/hr. Also, swap to fresh mud. After finish swap to new mud had 1.34/0.98/3920/175L PVT 366 22:25 - 00:00 1.58 STKOH P PROD1 Park at 15965' for 20 min then start time drill schedule 1.34/1.0/3830/175L 4/6/2006 00:00 - 01:30 1.50 STKOH P PROD1 Continue time drill from 15967'. By 15972' it is obvious that we are not making new hole 01:30 - 02:10 0.67 STKOH P PROD1 Wiper in hole to setdown at 16440' and spud into Kalubik several times just in case brass cap is not fully removed. Wiper back to new KOP PVT 304 02:10 - 05:30 3.33 STKOH P PROD1 Restart troughing area 15960-15980' at 20'/hr and repeat twice after one stackout 1.35/1.27/4170/170L (higher return rate and CTP due to stirring up cuttings in Kalubik which partially Printed: 5/1/2006 1:31:22 PM BP EXPLORATION Page 7 of 24' Operatiolns Sumlmary Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Qperations 4/6/2006 02:10 - 05:30 3.33 STKOH P PROD1 plugged losses at fault) PVT 301 05:30 - 08:45 3.25 STKOH P PROD1 Park at 15980' for 20 min and then begin time drill schedule 1.34/0.94/3934/170L. Losses resumed at prior rate after almost 3 hours of nearly full returns. Still no ledge developed. POOH & discuss options with town. 10:45 - 12:30 1.75 STKOH P PROD1 Hold PJSM/risk assessment for load & strap 2 3/8" pipe in pipe shed. Perform same. Continue OOH. Inspect last 100' of pipe OOH. 12:30 - 14:00 1.50 STKOH P PROD1 LD BHA. Hold PJSM: picking up liner. Start In hole w/ liner; Kick drill w/ 6 joints in the hole: went well aside from TIW valve wrench in doghouse. Re-located wrench on the floor w/ driller. MU bullnose shoe, 17 jts solid 2 3/8" L-80 w/ cementralizers, liner top billet, & GS spear. 14:00 - 14:45 0.75 STKOH P PROD1 MU BHI BHA; stab on injector &RIH. SSSV pressure 5K. 17:50 - 18:20 0.50 STKOH P PROD1 Tie in to RA tag. Correction -3.5; continue in hole thru open hole and was clean. 18:50 - 19:00 0.17 STKOH P PROD1 Took a couple of tries to get to bottom. Close EDC, bring pump on at 1.05/3950 psi. PUH 31k and left liner w/ shoe at 16450' and top of billet located @ 15,890'. 19:00 - 22:45 3.75 STKOH P PROD1 POOH thru open hole, clean. POOH for sidetrack assy 22:45 - 00:00 1.25 STKOH P PROD1 Check last 100' of CT for wear. LD WS setting assy and load out tools. MU sidetrack assy 4/7/2006 00:00 - 03:10 3.17 STKOH P PROD1 RIH w/ BHA #11 circ thru EDC 0.33/1430 03:10 - 03:30 0.33 STKOH P PROD1 Log tie-in down to RA tag at 15088', corr -7'. Close EDC 03:30 - 04:20 0.83 STKOH P PROD1 Wiper to billet 1.36/3900. Tag at min rate at 15888'. PUH 31 k, start pump. RIH to 15887' and park PVT 482 04:20 - 06:20 2.00 STKOH P PROD1 Time drill from top of billet 1.36/1.16/3850/90L w! 0 dill, 0 wob w/ 12.47 ECD and w! 9.7k surface str wt. After 1 hr (one btms up) start seeing aluminum at shaker. 06:20 - 07:00 0.67 STKOH P PROD1 Drill past AI billet to 15,915' MD; start backreaming; 1.37/1.22/3800 PVT 475 bbls. 07:00 - 08:30 1.50 STKOH P PROD1 Back ream 30 R/L of KO toolface; looks good. 08:30 - 13:15 4.75 STKOH P PROD1 POOH; LD motor & mill. PU rib-steer assy. 13:15 - 14:00 0.75 DRILL N PROD1 Some trouble getting rib-steer to actuate; C/O rib-steer assy for spare: function test OK; continue MU. 14:00 - 18:00 4.00 DRILL P PROD1 Stab injector; RIH; SSSV panel pressure 5200 psi 18:00 - 18:30 0.50 DRILL P PROD1 Tie in to RA tag correction -6.5' correction. 18:30 - 19:10 0.67 DRILL P PROD1 Wiper to billet. Attempt to go by billet w/o pump and set down at 15988' 19:10 - 19:40 0.50 DRILL P PROD1 Ream by billet at red rate of 0.75/2600 at 1-2'/min to 15900'. Incr pump to 1.3/1.17/3750 while ream to TD at 1-2'/min tagged at 15915' 19:40 - 21:40 2.00 DRILL P PROD1 Backream at full rate to 15875' w/ stall at 15882'. RIH at 0.4/2100 thru billet area on third try at 20'/min. Backream again and stall at 15881'. RIH thru billet area on third try. Backream up to tite spot at 15881-882' (up depth) and spend one hr backreaming until clean. RBIH at red rate and was clean Lessons Learned-need to KO billet at 120-160 (R or L) to utilize gravity assist for cleaning up 2.73" OD hole w/ RS (essentially a straight motor) and bi bit 21:40 - 22:10 0.50 DRILL P PROD1 Backream from 15900' and had stall at 15884'. Spend 15 min and cleaned this area up. Backream one more time to 15875' Printed: 5/1/2006 1:31:22 PM BP EXPLORATION Page 8 of 24 Operations Summary Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/7/2006 21:40 - 22:10 0.50 DRILL P PROD1 and billet was clean. RIH w/ pump 1.3/1.19/3750 and was clean thru sidetrack area 22:10 - 00:00 1.83 DRILL P PROD1 Drill from 15915' 1.30/1.20/3750 w/ rib steer at 20-45'/hr w/ 100-200 psi dill, 2.3k wob at 12.25 ECD Drill to 15980' 4/8/2006 00:00 - 01:00 1.00 DRILL P PROD1 Drill from 15980-16000' 01:00 - 02:15 1.25 DRILL P PROD1 Wiper to window 1.3/3700 was clean by billet at 20'/min. Pull thru window and wiper to 14950', clean. Wiper back to TD. Slow down before billet to 6'/min and had no MW or wt loss PVT 481 02:15 - 07:00 4.75 DRILL P PROD1 Drill from 16000' 1.25/1.12/3800 w/ 200-300 psi dill 2-3k wob w/ 12.15 ECD at 84 deg 30-40'/hr 07:00 - 10:35 3.58 DRILL P PROD1 Drill to 16,144' 1.35/1.25 Wiper to 14,000' hole looks clean, window clean. Tie in: correction +6'. Wiper back to TD -slow down before billet to 6'/min and had very little MW or wt Toss. 09:00 - 10:30 1.50 DRILL P PROD1 Drill ahead from 16,144' 1.43/1.32/4060 w/ 200-300 psi dill 2-3k wob w/ 12.42 ECD 45'/hr. PVT 483 10:30 - 13:00 2.50 DRILL N STUC PROD1 Drill to 16,188'; stacking some weight, PU and stuck @ 16,150'. CBU. Looks like differential sticking; get crude tanker on the way (2 hours out due to no loaded tankers). Relax technique used. SD pumps for 15 minutes at a time & PU to -50K, stack out, kick on pumps. Tried a few times & got free; pulled a max of 58K. 13:00 - 14:10 1.17 DRILL P PROD1 Wiper to window; wiper back to bottom, resume drilling. 14:10 - 17:30 3.33 DRILL P PROD1 Drill 10' and start stacking weight again -just like last time; work the hole here a bit and cleaned up; drill ahead 1.38/1.28/4100 w/ 200-300 psi dill, 3-5K WOB 40-50'/hr. Hard streak @ 16,220' - 16,230'. PVT 465; Difficulty getting weight to bit continues, work hole near TD frequently to get weight on the bit. 17:30 - 18:30 1.00 DRILL P PROD1 Drilling break; 50-70'/hr; 1.30/1.23/4090 w/ 200-300 psi dill; 3-4 K WOB PVT 473 Drill to 16323' and start stacking with signs of differential and having some overpulls 18:30 - 18:50 0.33 DRILL P PROD1 Slow wiper to try and improve hole conditons 18:50 - 19:20 0.50 DRILL N STUC PROD1 While backreaming, had overpull w/o MW at 16230' (100' off btm). Stop PUH and park. Relax ribs and tried to go back down w/o success. Stuck BHA w/ bit at 16230' w/ stretch 16212-16236' w/ 54k max up and -8k down. Try it a couple times while fin circ sample to surface and not .. . 19:20 - 21:10 1.83 DRILL N STUC PROD1 SD pump and bleed off CTP w/ CT at neg wt. WO DHP to stabilize at 4600 psi. Try after 30 min and no success. Circ to warm CT. Repeat w/o success w/ DHP 4530 psi. Circ to warm CT. Bleed off CTP, activate ribs to push HS and wait 30 min and attempt to move pipe w/o success. WO crude transport, but no drivers available 21:10 - 22:50 1.67 DRILL N STUC PROD1 CBU thru bit 1.44/1.38/4400 while pump 40 bbl hi-vis pill. Recip occasionally w/o success. Losses starting to incr? 22:50 - 00:00 1.17 DRILL N PROD1 Pump 20 bbls 8.6# Flovis pill down CT at 1.41/0.91/3850. SD pump w/ 10 bbls out bit and bleed off CTP Found a driver for crude truck, but truck is being serviced .. . 4/9/2006 00:00 - 00:40 0.67 DRILL N STUC PROD1 After 20 min w/ pump SD, begin to work pipe w/ 54k max and -7k min. Still immobile at 16230' bit. Open EDC and circ. SD pump, close EDC and wait. Recip w/o success Printed: 5/1/2006 1:31:22 PM BP EXPLORATION Page 9 of 24 Opelratiolns Sumllnalry Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date From.- To Hours Task Code NPT Phase Description of Operations 4/9/2006 00:40 - 01:00 0.33 DRILL N PROD1 Circ thru bit 1.4/1.0/4000 Safety mtg re: pump dead crude 01:00 - 02:25 1.42 DRILL N STUC PROD1 RU crude tanker. Take off 10 bbls crude followed by mud 1.0/0.81/4340. Displ 5 bbls out bit, then SD pump and wait 20 min. CTP increased when crude at bit so suspect trash from truck 02:25 - 03:15 0.83 DRILL N STUC PROD1 Work CT w/o pump to 60k, -8k w/ no movement. Pace cycles to maximize CT life. Pump 2 more bbls after 40 min to warm CT. SD pump and wait. Cycle pipe some more w/o success and concentrating on the down mode. Injector trips at -9k, but keep hammering down. Looks like we gained a foot so cycled up and broke free at 54.7k 03:15 - 03:55 0.67 DRILL N PROD1 PUH w/ no more overpulls. Attempt to pump, but could only get 0.5 bpm at 4000 psi. Pressure is high and variable @ 4000-4500 psi at 0.4 bpm and are now suspecting methanol in crude, but crude is fully displaced from CT, muse, muse. Pull thru billet area, clean at 0.4/0.15/4150 psi 03:55 - 05:00 1.08 DRILL N PROD1 Pull thru window w/ minor overpull. Park at 15040'. Check FS at 0.5/3940. Open EDC and check 0.5/3540 which is 400 psi press drop over BHA, normal. Mud 'looks' okay. Bypass filter in reelhouse and perform other checks to eliminate surface restrictions. Assume trash at CTC. POOH to check BHA 05:00 - 07:40 2.67 DRILL P PROD1 At 12000', saw signs of restriction disipating. Keep increasing pump rate and finally dislodged all the trash. Now at 1.54/4100 which is normal. Continue trip to check BHA and change bit. At 10400' or 46 bbls of returns from TD, got interface (clabbered) then crude w/ mud back at 8.75 ppg. Dump 90 bbls to cuttings box of which most was clabbered 07:40 - 09:10 1.50 DRILL P PROD1 Inspect last 100' of CT for wear - OK; LD rib steer & pump through CTC - OK -some clabbered mud cleaned out; Function test rib steer - OK; PU rib steer & new bit, stab injector &RIH. SSSV panel pressure 4800 psi. 09:10 - 13:00 3.83 DRILL P PROD1 Tie in to RA tag; continue in hole to --15,500' then started losing returns 1.41/0.56/4200 psi. May be more clabbered up mud circulated into the backside driving the circulation pressure up and returns into the formation. Continue circulate losing returns & PU to window. 13:00 - 15:10 2.17 DRILL N PROD1 Returns down to 1.2/0.25/3000; continue OOH to break-up the clabbered up mud coming north; take rate down to 0.9/.23; PVT 312 & no vac trucks currently available to get more mud. Returns dropped to zero briefly then @ 11,000' start getting returns again 0.9/0.25: clabbered up mud returns to surface - divert 15 bbls clabbered mud to cuttings tank. 15:10 - 17:20 2.17 DRILL N PROD1 Pull to 8300'; finally break over to 1:1 returns. Mud cleaned up. Start RBIH. Mud Engineer says we can thin the clabbered mud by lowering the Ph; will hold off on that while we're getting good mud back to the pits. RIH 0.911.08/2500 psi, 85 fpm PVT 274 Lesson learned-citric acid breaks this clabbered mud. Normally when crude is pumped due to dill sticking it is circa OOH at a high rate before POH so the clabbered phenomenon is not seen. Consider pretreating displacement mud w/ citric acid Printed: 5/1/2006 1:31:22 PM BP EXPLORATION Page 10 of 24 Operations Sulmmalry Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Dat~ From. -To Hours 'Task Code NPT Phase Description of Operations 4/9/2006' 17:20 - 18:35 1.25 DRILL P PROD1 Back on bottom & drilling: 1.3/1.1/4300 psi; 500 psi of mw 2-3k WOB 50-60'/hr PVT 299. Drill to 16399' and getting sticky. Can't get back down at 16363' 18:35 - 19:10 0.58 DRILL P PROD1 200' wiper. Wiper up hole w/ overpulls to 42k from 16280-230'. ', Wiper in hole was clean. Resistivity later showed the fault 14390' ', 19:10 - 20:45 1.58 DRILL P PROD1 Dnll from 16399' 1.35/1.18/3950 at 40'/hr steady to 16441' ~, 20:45 - 22:00 1.25 DRILL P PROD1 Start stacking at 16441'. Pick up and was sticky w/ overpulls to 47k (w/ ribs relaxed) to 16160'. Continue wiper to window which was clean. Wiper back in hole was clean to TD tagged at 16438' PVT 290 ', 22:00 - 00:00 2.00 DRILL P PROD1 Drill from 16438' 1.34/1.15/3940 w/ 200-400 psi dill, 2-3k wob ', w/ 12.48 ECD at 40-60'/hr at 88 deg. At 16450' adjust TF to ', start sli climb. Also, start fresh 9.4# Flopro (lightened MW by ', 0.2#/gal to see if dill sticking is less of a problem. Also, incr LSRV back to 30k. Drill to 16500' After new mud back to ', surface 1.5/1.32/3700 and penetration rate increased to 50-70'/hr w/ less differential. 4/10/2086 00:00 - 02:30 2.50 DRILL P PROD1 Drill from 16500' to 16600' 1.56/1.37/3500 at 91 deg w/ 300-600 psi dill and 2-4k wob at 11.5 ECD at avg 60'/hr when drilling. Do three 200' wipers. Drilling break at 16540'. Drill to ', 16580' and having trouble w/ ribs function (building angle, need to drop) 200' wiper. Drill to 16600' and still can't get tool to ', drop angle PVT 318 02:30 - 03:15 0.75 DRILL P PROD1 Wiper to/thru window was clean PVT 314 ', 03:15 - 06:15 3.00 DRILL N DFAL PROD1 Open EDC. POOH to check function of rib steer tool ', 06:15 - 08:20 2.08 DRILL N DFAL PROD1 Check well for flow. POOH checking last 100' of CT: some flat ', spots: 6'-8' & 60' from CTC; 1.947" OD was minimum flat spot ', - 1.940" is published minimum. Will defer cutting CT off until next BOP test (due Wed). LD rib-steer, checked out OK on ', surface. PU 0.8 deg bent motor to drop angle. RIH. SSSV ', panel pressure 4650 psi. ', 08:20 - 13:35 5.25 DRILL N PROD1 TIH & Tie in: -T correction. wiper to TD: all clean. 13:35 - 14:45 1.17 DRILL P PROD1 Tag TD 20' deep; drill ahead to 16,655' then decide to PU and ', mad pass to confirm tie-in (resistivity character higher up) & ', Mad pass to TD to confirm log. 14:45 - 17:00 2.25 DRILL P PROD1 Drill to 16,289' 1.48/1.37 PVT 312; start stacking weight & stuck briefly @ 16,670' work pipe free; wiper trip to window to clean up the hole: looks good. 17:00 - 17:50 0.83 DRILL P PROD1 Drill to 16,700' -projected inclination @ bit is 85 degrees. ', 17:50 - 18:40 0.83 DRILL P PROD1 Wiper to/thru window, clean 18:40 - 22:00 3.33 DRILL P PROD1 Open EDC. POOH for rib steer assy ', 22:00 - 22:45 0.75 DRILL P PROD1 Tag up, chk for flow. LD drilling BHA 22:45 - 00:00 1.25 DRILL P PROD1 Reverse slack back. RU cutter and cut off 165' CT plus 5' eline and dispose 4/11/2006 00:00 - 02:30 2.50 DRILL P PROD1 Install CTC. PT 35k. Head up BHI. Meg line 45.4 ohms. PT CTC 4000 psi, inner reel valve to 4000 psi. Set injector back Carlisle delivered rebuilt rib steer motor ', 02:30 - 11:00 8.50 BOPSU P PROD1 Bi-weekly ROPE test witnessed by WSL. Blind/shears leaked - ', Rubbers damaged; replace seals & test again. 11:00 - 12:00 1.00 BOPSU P PROD1 Finished BOP test i Printed: 5/1/2006 1:31:22 PM ~` BP EXPLORATION Page 11 of 24 Operation Summary Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date from - To Hours Task. Code NPT Phase Description of Operations 4/11/2006 12:00 - 12:15 0.25 DRILL P PROD1 PJSM on PU drilling BHA 12:15 - 14:20 2.08 DRILL P PROD1 PU BHI Rib Tool, found short in tools string. Investiaged, changed out Flow sub and lower quick connect 14:20 - 17:40 3.33 DRILL P PROD1 RIH with BHI Rib tool Stopped at 12,700 ft and open EDC to cir at higher flow rate Op = 1.5 bpm at 3,430 psi 17:40 - 17:55 0.25 DRILL P PROD1 Tie at 120 fph logging down from 15095 ft. -3' correction 17:55 - 18:50 0.92 DRILL P PROD1 Continue RIH. No problem going past AI billett. Tag btm at 16700'. 18:50 - 20:15 1.42 DRILL P PROD1 Drill ahead f/ 16700' after some intial stalls with new bit 1.35/1.35 3775fs, 12.11 ECD, 350-450 mw, TF 180, 53001bs CTW 38001bs WOB 50'/hr We expected to see 85degs on bottom from last BHA, actual was 86.5degs. Having problems dropping angle. 16729' PU and reset Hyd Power Control from 1.Oamp to max of 1.6amps giving maximum steering force to RibSteer tool. Resume drilling. At 16744' still unable to drop hole angle. 20:15 - 00:00 3.75 DRILL N DFAL PROD1 Pick-up hole while confiring with town BHI engineers for other possible surface adjustments to downhole tools. Only suggestion is to lighten up on WOB resulting in less ROP. We are within 2' of the predicted TKUP base and NBI is 89deg. This is too close to continue drilling without predictable results. TOH for .8 motor and CoilTrac hyd. orienter. PU wt 35-31 k Pit vol 300bb1s 4/12/2006 00:00 - 00:15 0.25 DRILL N DFAL PROD1 Continue TOH. Hold PJSM to review BHA handling precautions. 00:15 - 00:45 0.50 DRILL N DFAL PROD1 LD BHA. 00:45 - 02:00 1.25 DRILL N DFAL PROD1 Inspect RibSteer tool. Review computer data with town. Tool tests good. Accepts commands and ribs fuction well. Could possibly be formation hardness or any combination of drilling parameters that prevents ribs from exerting enough lateral force to drill in desired direction. 02:00 - 03:00 1.00 DRILL N PROD1 PU BHA #16 with 0.8 deg motor and RR bit #9. 03:00 - 06:45 3.75 DRILL N PROD1 RIH. Close EDC at 15,000 ft 06:45 - 07:08 0.38 DRILL N PROD1 Tie-in logging from from 15,095 ft to 15,135 ft (corrected -5.5 ft) 07:08 - 07:50 0.70 DRILL N PROD1 RIH 07:50 - 08:45 0.92 DRILL P PROD1 Tagged bottom. Oriented TF to 180 deg. Took awhile to get it to drill, stacking with bit stalling Drilling lateral at 180 TF to 105R Op = 1.45/1.44 bpm at a CTP 4000 / 4500 psi CT Wts/WOB = 2700 Ibf / 3.12 Ibf Vp = 356 bbls at 08:30 hrs ROP's 55 to 76 fph Resistivity curve coming together. Projected hole at 86 deg Turned TF to 105 R 08:45 - 09:25 0.67 DRILL N DPRB PROD1 PUH to let Geologist make dip calculation and became differential stuck 5 ft off bottom. Work CT up to 56k and cycling pumps to try and get free. Called for dead crude for assistance. 09:25 - 10:45 1.33 DRILL N DPRB PROD1 Worked free, PUH and put dead crude on hold PUH to sweep hole to 15,764 ft RIH at reduced Op and 20 fpm 10:45 - 11:50 1.08 DRILL P PROD1 Tagged bottom at 16,792 ft. Oriented TF 90R deg. Drilling lateral at 90R TF Printed: 5/1/2006 1:31:22 PM • BP EXPLORATfON Page 12 of 24 Operations Summalry Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/12/2006 10:45 - 11:50 1.08 DRILL P PROD1 Op = 1.45/1.44 bpm at a CTP 4000 / 4300 psi CT Wts/WOB = 2500 Ibf / 2.6 Ibf Vp = 358 bbls at 10:50 hrs ROP's 70 fph; EDC = 12.14 ppg 11:50 - 12:16 0.43 DRILL P PROD1 Drilled to 16,851 ft..PU, RIH and became differential stuck again.at 16,787 ft. Work stuck pipe and ordered dead crude. Pulled free 12:16 - 13:00 0.73 DRILL P PROD1 Wiper trip after pulling free after 45 minutes and 50 ft of new hole drilled Pulled up 16,743 ft, pulled tight again, worked through. PUH to 16,415 ft RIH 13:00 - 13:38 0.63 DRILL P PROD1 Tagged bottom at 16,851 ft. TF @ 105 to180 R deg. Drilling lateral at 105R TF Op = 1.45/1.44 bpm at a CTP 4000 / 4300 psi CT Wts/WOB = 2k-2.51bf / 2.4 Ibf Vp = 351 bbls at 13:00 hrs ROP's 60-70 fph; EDC = 12.12 ppg IA / OA =547 / 410 psi Drilling with a 180deg the NBI is flat lining at 87.5 deg. Checked the internal and external offsets (OK) 13:38 - 15:03 1.42 DRILL P PROD1 Started stacking, PU and after drilling 40 ft pulled tight coming off bottom Wiper trip. At 15,063 ft open EDC. Increased Op to 1.8 bpm at 4,300psi PUH to 14,000 ft 15:03 - 15:22 0.32 DRILL P PROD1 RIH at 80 fpm, Cutting transport increased while RIH Closed EDC at 15,070 ft and Run past the WS 15:22 - 15:45 0.38 DRILL P PROD1 Log tie-in from 15,095 ft down.(+ 8 ft) 15:45 - 16:45 1.00 DRILL P PROD1 RIH 16:45 - 17:30 0.75 DRILL P PROD1 Tagged bottom at 16,889 ft. TF @ 120 to180 R deg. Drilling lateral at 120R TF Op = 1.45/1.44 bpm at a CTP 4000 / 4300 psi CT Wts/WOB = 2k-2.51bf / 2.4 Ibf Vp = 342 bbls at 13:00 hrs ROP's 60-70 fph; EDC = 12.12 ppg IA / OA =562 / 442 psi Pump pressured dropped, signs of stacking at 16,945 ft 17:30 - 19:15 1.75 DRILL P PROD1 Wiper trip to clean up solids after drilling 57 ft of new hole 19:15 - 21:15 2.00 DRILL P PROD1 Continue drilling ahead f/ 16945' 150R TF 1.35/1.31 bpm 3900psi fs 200-300psi mw 11.91 ECD, Pit Vol 336 @ 2010hr IA/550 OA//450 Drilled to 16972' when motor work dropped off. Pick off btm no problems. Unable to work back to bottom without stacking 2-3' off bottom. Make a 200' wiper trip. Tag bottom continue drilling ahead. 1.39/1.35 3900psi/4330psi CT Wts/WOB 1000 (SLB) 2K (BHI) ROP= 80-90'/hr TF 145R Seeing some angle drop tendencey at 17025' brought TF to 85R. Drilled to 17027' and pressure dropped off. PU 35K pulled to 16825'. RIH stacked and stuck. 21:15 - 21:45 0.50 DRILL P PROD1 Pulled free at 56k. Pulling irradict to 16740' Trip to 16500' Printed: 5/1/2006 1:31:22 PM BP EXPLORATION Page 13' of 24 Operations Summary.:Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date from - To Hours Task Code NPT Phase Description of Operations 4/12/2006 21:45 - 22:20 0.58 DRILL P PROD1 Continue drilling ahead f/ 17027'. Pit vol 332bb1s 2k wob 80'/hr. Drilled to 17072 and seeing pressure drop and stacking. 22:20 - 23:50 1.50 DRILL P PROD1 Wiper back 300' RIH still stacking. Wiper trip to window. Open ECD. Continue to 14000' pumping at 1.8bpm. RIH 90'/min to window. 23:50 - 00:00 0.17 DRILL P PROD1 Log tie-in -3' correction. 4/13/2006 00:00 - 01:00 1.00 DRILL P PROD1 Finished wiper trip. 01:00 - 05:10 4.17 DRILL P PROD1 Drill ahead f/ 17072' good weight transfer after wiper trip. 1.38/1.35 3900psi Free-spin 4-500psi motor work CTW 35001bs. w/ WOB 2000 (BHI) 4800 (SLB) ROP=60-70'/hr 150R TF Pit vo1=322bb1s Drilled to 17098' lost motorwork. PU 200' and work back down. Drill ahead to 17,138 ft and smae happened. Able to PU again and return to drilling. Drilled to 17164' briefly lost MW, pu and took off drilling again 60-70'/hr CTW -1k WOB by BHI steady 2k Pit vol @ 03:45hr= 317bb1s Drilled to 17,230 ft with minor stacking problems. Clean pick-up. 29-30k 05:10 - 07:10 2.00 DRILL P PROD1 Wiper trip to TT, Pulled through WS and open EDC Increased Op to 1.7 bpm and PUH to TT RIH at 80 fpm 07:10 - 07:20 0.17 DRILL P PROD1 Tie-in from 15,095 ft to 15,135 ft Correction +14 ft 07:20 - 08:30 1.17 DRILL P PROD1 RIH 08:30 - 09:00 0.50 DRILL P PROD1 Tagged bottom. Oriented TF to 90L deg. Drilling lateral and building hole angle up to 89 deg using 90L to 10L TF Op = 1.36/1.34 bpm at a CTP 3900 / 4420 psi CT Wts/WOB = 2212 Ibf / 2.00 Ibf Vp = 305 bbls at 08:30 hrs After short trip the injector wt is 2k to 3k Good 09:00 - 11:30 2.50 DRILL P PROD1 Stacking, 200 ft wiper trip PUH to 16,950 ft and turned around and was unable to go down. PUH to base of WS. 11:30 - 11:45 0.25 DRILL P PROD1 Tagged bottom. Oriented TF to 90L deg. Drilling lateral and building hole angle up to 89 deg using 90L to 10L TF Op = 1.36/1.34 bpm at a CTP 3900/4420 psi CT Wts/WOB = 2212 Ibf / 2.00 Ibf Vp = 297bb1s at 11:30 hrs Drilled to 17,280 ft and started to stack again 11:45 - 12:01 0.27 DRILL P PROD1 PUH short wiper to 16,900 ft RIH 30k up and 9k down 12:01 - 12:50 0.82 DRILL P PROD1 Drilling lateral and 90L to 140E TF Build to 90 and then turned TF down to 140E to level out. Qp = 1.33/1.30 bpm at a CTP 3900 / 4300 psi CT Wts/WOB = 1.8k to 1.9k Ibf / 1.52 Ibf Vp = 293 bbls at 12:00 hrs 12:50 - 14:47 1.95 DRILL P PROD1 Wiper trip to pump MI's EP Lube Test Started Steel Lube EP down CT (2 drums in 20 bbls) Open EDC at 15,040 ft Circulated EP tube around. CT wt before 28k up and 9 k down. No chsange after pumping 22 bbl (4500 ft) of EP Lube around. 14:47 - 15:00 0.22 DRILL P PROD1 Closed EDC and RIH to tie-in at 15,095 ft 15:00 - 15:15 0.25 DRILL P PROD1 Tie-in at RA marker Printed: 5/1/2006 1:31:22 PM BP EXPLORATION Page 14 of 24 Operations Suimmary Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name:. NORDIC 2 Rig Number: Date From - To Hours Task Code . NPT Phase Description ofOperations 4/13/2006 15:00 - 15:15 0,25 DRILL P PROD1 Corrected + 9.5 ft 15:15 - 16:10 0.92 DRILL P PROD1 RIH. Started mud swap while RIH at 16,000 ft 16:10 - 18:00 1.83 DRILL P PROD1 Drilling lateral and 90L to 140E TF Op = 1.33/1.30 bpm at a CTP 3500 / 3800 psi Lost 600 psi CTP following mud swap CT Wts / WOB = 0.81bf / 2.5 Ibf Drilled into something hard at 17,345 ft, possible siderite 18:00 - 00:00 6.00 DRILL P PROD1 Continue drilling ahead f/ 17357' 1.44/1.40 3760/4340 ECD=11.83ppg Still drilling on hard streak w/ 3k WOB Slow drilling on confirmed siderite. Good wt transfer and WOB. Rotate TF 180 no help. Reduced pump rate to 1.O6bpm 2740fs 200-300mw slowly started drilling 2-3'/hr 4/14/2006 00:00 - 01:30 1.50 DRILL P PROD1 Continued drilling ahead slowly f/ 17362'. 90L TF 1.06/1.00 2750fs / 2-300 mw. Finally broke through siderite stringer. Pit vol 347bb1s 01:30 - 04:20 2.83 DRILL P PROD1 Drill ahead f/ 17375' 1.43 / 1.41 3700fs 2-300 mw ECD= 11.90 2-3k wob 15-25'/hr. Looks as if we may have skimmed the bottom of the Kalubik shale. At 17415' dropped TF to 160E for a planned 86deg to drill back down through siderite. Will then maintain 88 degs. 04:20 - 05:30 1.17 DRILL P PROD1 Drilling ahead f/ 17441' 1.44/1.39. 100E TF NBI 86.1deg 1-2k wob. Pit vol= 346b1s 05:30 - 06:50 1.33 DRILL P PROD1 Wiper trip to window. PU wt 29-31k 06:50 - 08:30 1.67 DRILL P PROD1 With bit at 15,146 ft started to pul{ tight with top of BHA at base of WS. Worked through using several techniques and after 1 hrs finally worked BHA into WS area. Circulated lots of solids over shaker during the period. Worked to where the area was clean, reduced Qp, PUH past WS. Open EDC and pumped at 1.8 bpm awhile working CT up to TT. Rlh and Baker cleaned up. 08:30 - 08:45 0.25 DRILL P PROD1 Closed EDC, RIH to tie-in. Tied in from 15,095 ft to 15,145 ft Corrected +7 ft 08:45 - 10:15 1.50 DRILL P PROD1 RIH to 16,000 ft and found part of injector roller bearing on the rig floor. SD and inspected both chains. Replaced 1 bearing on inside chain 10:15 - 10:36 0.35 DRILL P PROD1 RIH and set down at 17,375 ft. Worked through trouble area to17, 420 ft. Backed reamed twice and clean. 10:36 - 11:00 0.40 DRILL P PROD1 RIH and tagged bottom at 14,468 ft. 11:00 - 16:00 5.00 DRILL P PROD1 Drilling lateral and dropping hole angle to look for OlW contact TF adjusted at 100E 140E and 160 L Drilling in siderite cap Op = 1.36/1.34 bpm at a CTP 3800 / 4150 psi CTWts/WOB=-2k to-5klbf/1.5to2.31bf Vp = 305 bbls at 11:00 hrs Drilling slow in siderite cap. Tried several things and was unable to get it to drill. Getting good WOB and hole angle is coming down, but slow or no pentration rate in 5 hrs. 16:00 - 21:10 5.17 DRILL P PROD1 POOH for bit change. RIH to 200' pumping max rate to flush tbg. POH to 50'. Unstab injector. Inspect last 50' of coil for wear. Found flat owrn spot 6' up from CTC. Nomial thickness .156" worn area .131" decide to cut 100' coil. Printed: 5/1/2006 1:31:22 PM $P EXPLORATION. Page 15 of 24 .Operations Summary Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date From.- To Hours Task Code NPT Phase Description of Operations 4/14/2006 21:10 - 22:00 0.83 DRILL P PROD1 Setback injector. LD BHA. Bit had 1 compact on nose broken badly. One gauge compact broken. Erosional wear every where. Inspect motor, it's good. MU new Hycolog bit. 22:00 - 22:15 0.25 DRILL P PROD1 PJSM on the rig floor to review coil cutting procedures and hazards. Discuss hazards for dressing end of coil and the requirements for double eye protection during the dressing procedures. 22:15 - 22:35 0.33 DRILL P PROD1 Cut 100' of coil. Flush with FW, drain and dispose off rig floor. 22:35 - 00:00 1.42 DRILL P PROD1 Dress end of coil. Install Kendal CTC. Pull test to 25K. Install BHI's UOC meg test. PT to 3500psi. 4/15/2006 00:00 - 00:40 0.67 DRILL P PROD1 PU BHA #17 stab-on injector. 00:40 - 04:05 3.42 DRILL P PROD1 Test tools and RIH 04:05 - 04:35 0.50 DRILL P PROD1 Log tie-in -8.5' 04:35 - 06:00 1.42 DRILL P PROD1 Continue RIH to bottom. Had to W/R between 17,430 ft to 17,450 ft. couple of times 06:00 - 09:30 3.50 DRILL P PROD1 Drilling lateral and dropping hole angle to look for O/W contact TF adjusted at 130E Op = 1.3681.36 bpm at a CTP 3900 / 4150 psi CTWts/WOB=-2k to-3klbf/1.5to2.31bf Vp = 279 bbls at 06:00 hrs ROP PU with new bit from 15 fph to 45 fph. Averaged 25 fph drilling this interal. Seen small amount of shale in Geo 17,500 ft samples. 09:30 - 12:00 2.50 DRILL P PROD1 After stacking, conducted wiper trip to base of WS. Pulled ratty at 17,533 ft and pulled clean 17,399 ft. Rest of hole clean. 12:00 - 13:20 1.33 DRILL P PROD1 Drilling lateral TF adjusted at 120E Res log shows a drop below 8 ohms m Op = 1.3681.36 bpm at a CTP 3900 / 4150 psi CT Wts / WOB = -1.5 k Ibf / 1.5 Ibf ROP = 40-50 fph Vp = 279 bbls at 12:00 hrs 13:20 - 14:15 0.92 DRILL P PROD1 Short wiper trip. 14:15 - 14:55 0.67 DRILL P PROD1 Drilling lateral TF adjusted at 120E Res Tool is dropping below 8 ohms-m Op = 1.3681.36 bpm at a CTP 3900 / 4150 psi CT Wts / WOB = -1.5 k Ibf / 1.5 Ibf ROP = 40-50 fph Increased to 70 fph at 17,632 ft MD/ 9,069 ft TVD Vp = 273 bbls at 14:00 hrs Started to lose fluid at 17,633 ft Op = 1.43 / 0.87 bpm Resisitivity log made a dip at 17,612 ft MD / 9062.85 ft TVD TD Well 14:55 - 16:35 1.67 DRILL P PROD1 PUH, Op = 1.29/ 0.79 bpm out rate improving as PUH. At WS, tossing 0.27 bpm Ordered 290 bbl new mud to finish well 16:35 - 16:50 0.25 DRILL P PROD1 Tie-in RA marker at 15,085 ft Op = 1.29 / 1.02 bpm Vp = 210 bbl Corrected +8.5 ft 16:50 - 17:45 0.92 DRILL P PROD1 PUH to conduct MAD pass, Open EDC to circulated well clean. Op 1.67 / 1.1 bpm. Lossing 0.3 bpm. PUH to 14,400 ft and RIH to 15,500 ft. PUH to 14,580 ft to conduct MAD Pass. Close EDC Panted: 5/1/2006 1:31:22 PM • BP EXPLORATION Page 16 of 24` Operations Summary Report Legal Weil Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/15/2006 17:45 - 00:00 6.25 DRILL P PROD1 RIH at 300 fph running MAD Pass pumping at min rates .72/.62 2500 12.00 EDC pit vol at midnight 281 bbls 4/16/2006 00:00 - 04:20 4.33 DRILL P PROD1 Continue MAD Pass logging f/ 16450' at 300'/hr. Pumping at min rates .72/.62 Pit Vol at 0230hr = 275bb1s Slight momentary mw at 17380' then dropped off. Took weight at 17410. Set down at 17439'. Popped thru on it's own. Tagged TD at 17640' 04:20 - 09:05 4.75 DRILL P PROD1 POOH Pit vol 251 bbls PU wt 33.5k. Lossing 0.3 bpm while POOH. At surface, RIH to 200 ft to flush out solids at surface. Close EDC PUH, tagged up. Monitored well, OK 09:05 - 09:20 0.25 DRILL P PROD1 Held PJSM on BHA handling 09:20 - 10:00 0.67 DRILL P PROD1 LD BHA 10:00 - 10:45 0.75 CASE P RUNPRD PU nozzle w/ blind sub. Closed MV & SV. Stab on well head Make ready to pickle and blow down CT 10:45 - 11:15 0.50 CASE P RUNPRD PJSM covering mixing issues. Covered MSDS Sheets on Bleach and SLB's A261 Corrosion inihibitor. Delveloped procedures, pump schedule and defined PPE for job. 11:15 - 12:00 0.75 CASE P RUNPRD Mix up Bleach as per PJSM directions. Cir and mix with agitator. 12:00 - 12:30 0.50 CASE P RUNPRD Held PJSM on Pickling and blow down of CT. Cover all MSDS sheets and discussed pump schedule and hazards assoicated with this job. 12:30 - 14:00 1.50 CASE P RUNPRD Circulating pickle fluid into CT Pumped 12 bbl bleach Pumped 64 bbl fresh water Pumped 5 bbl MEOH Puped 15 bbl water w/ corrosion inhibitor Pumped 2 bbl's behind Inhibitor Pumped 5 bbl MEOH SD pump 14:00 - 15:55 1.92 CASE P RUNPRD PJSM on pumping N2 and displacing CT to TT PT to 3500 psi. Purging fluid out of CT w/ N2 Bleed CTP down 15:55 - 16:30 0.58 CASE P RUNPRD Unstabbed injector and RU CT cutter. Cut 3-20 ft sections of CT for Lisburne UBD project 16:30 - 16:45 0.25 CASE P RUNPRD RU to pull CT across pipe shed for reel swap Open well and filled hole, slight vacume. Clsed SV 16:45 - 18:00 1.25 CASE P RUNPRD PJSM Pull CT across pipe shed. Secured at reel 18:00 - 18:30 0.50 CASE P RUNPRD Crew changeout and discuss operations. PJSM assign job tasks and SIMOPS operations/hazards. 18:30 - 19:00 0.50 CASE P RUNPRD RU to run 2-3/8" liner and same time breakout inner hardline on coil reel. 19:00 - 00:00 5.00 CASE P RUNPRD MU 2-3/8" shoe track and PU 7jts L-80 and 80jts 13Cr liner. Drift with 1.895" drift while picking up. Make-up torque 600ft/Ibs useing Faras tongs. After MU drifting each connection with 1.87" BTT drift on 2jts of 1" CSH tbg. Same time hoist a-free 2" coil reel and MU inner reel hardline. Install internal grapple with wireline back to injector. 4/17/2006 00:00 - 01:30 1.50 CASE P RUNPRD Finish running 2-3/8" liner. MU BTT CTLRT equipment. 01:30 - 06:00 4.50 CASE P RUNPRD Hang injector on the blocks. MU coil pull cable to winch. Printed: 5!1!2006 1:31:22 PM S BP EXPLORATION Page 17 of 24 Operations Summary Report ' Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/17/2006 01:30 - 06:00 4.50 CASE P RUNPRD PJSM review procedures with crews involved. Pull coil to injector and secure. Install clamp-on dart catcher. Pump 5 bbls methanol followed by 5 bbls water spacer. Reset totalizer then on to Flo-Pro. Pumped 54 bbls and seen bump in pressure. Checked for dart but not there. Kept pumping never did see dart but finally stopped at 68 bbls away and it was in catch. Never seen anything to indicate it landed. So pumping another dart... 06:00 - 07:30 1.50 CASE N RUNPRD Waited on Pad Ops gas sniffer Nodic's failed 07:30 - 08:30 1.00 CASE P RUNPRD Welded on 1.60" ID CTC, Pulled test to 40k and PT Installed BOT dart catcher 08:30 - 09:45 1.25 CASE P RUNPRD Installed new Wiper Dart and displaced CT at 1.72 bpm and 3,600 psi Red Op to 1.00 bpm and 2,256 psi Dart hit at 65.3 bbl which equates to 23,592 ft 2" CT Sheared dart catcher, SD and make ready to pump it again. 09:45 - 10:30 0.75 CASE N SFAL RUNPRD Pump conformation dart with used dart Qp = 1.06 bpm at 2,300 psi with 9.4ppg Flo-Pro. Vol = 65.3 bbl Lct = 23,592 ft 10:30 - 12:30 2.00 CASE N SFAL RUNPRD Review operational options with town engineer and SLB. Nordis 1 laydown 2" reel has 14,670 ft on. CT too short for this job. RU to cut off 5,000 ft of CT on present 23,592 ft reel. Order metal dumpster from t)eadhorse. Load out BHI Rib Steer tool. RD SLB Slickline. Removed BOT Deployment Sleeve and circulated liner at 3,221 ft to monitor well paramters. 12:30 - 15:45 3.25 CASE N SFAL RUNPRD Cut 4,490 ft 2" CT in 10 ft intervals Len (CT) = 19,102 ft 15:45 - 17:00 1.25 CASE N SFAL RUNPRD RD cutter and dress CT for weld-on connector. GBR welded on CTC Pull tested to 40k PT to 4000 psi 17:00 - 17:45 0.75 CASE P RUNPRD Insert dart and launch Displaced dart at 1.7 bpm. CTP 3025 psi, Lost 580 psi friction. Dart landed at 53.1 bbl (19,184 ft) 17:45 - 18:00 0.25 CASE P RUNPRD Crew change. PJSM install PJ and deployment sleeve.. 18:00 - 18:15 0.25 CASE P RUNPRD MU injector to liner. 18:15 - 22:15 4.00 CASE P RUNPRD RIH pumping min rate 0.16bpm 2100psi .Not seeing any returns. 22:15 - 00:00 1.75 CASE P RUNPRD Weight check at 15000' 36K Continue RIH dwn wt 66001bs/ at 39'/min clear window with shoe track. RIH first setdown at 16092'. PU tight 54k RIH fast 115'/min work past continue RIH fast started into negitive weights at 16400' gradually pushing at -8k and came to stop at 17070'. PU several times 30-50' RIH and couldn't start to even push it. PU to 16600' RIH neg 7k CTW stopped at 16820' PU 16790' RIH 60'/min smooth w/ neg 1-2k neg 3-4k at 17150' ratty now a 17225 w/ neg 5-6k tripped out at 17308'. PU 44k to 17245' RIH 60'/min ratty going neg 5-6k trippped at 17348'. PU to 17305' RIH stopped 348' PU to 250' RIH 40'/min make it to 367 work it to 17382.7' Work this area for 15 min. Circ 0.20 for 15 min. Still have not seen any retums. 4/18/2006 00:00 - 01:00 1.00 CASE P RUNPRD Work liner down to 17416' circ keeping CTP <2300psi for 10min. Try working some more but not going further. 01:00 - 02:50 1.83 CASE P RUNPRD Close choke line. Pressure up annulus 300-500psi. Work liner at 17416'. Run hard into 17416' 6 times and finally went Printed: 5/1!2006 1:31:22 PM BP EXPLORATION Page 18 of 24 Operations Sumlmary Report - Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name:. NORDIC 2 Rig Number: Date From: - To Hours Task Cade NPT Phase Description of Operations 4/18/2006 01:00 - 02:50 1.83 CASE P RUNPRD through. Continue working to bottom 17631.5' (uncorrected) Work this depth but seems to be bottom. PU wt 50K off bottom. Check rates/pressures for ball drop. 1.0/3040psi no returns 1.58/3633psi no returns. Figuring that most of the pressure we are seeing is coil friction pressure tried to move liner while pumping 1.5bpm to induce circulation. PU wt 48K got stretch out of coil. At 17610' seen liner drop off. No reduction in pump pressure to indicate seal assembly came out of deployment sleeve. Stack back down on liner. Filled backside across top took <1 bbl to fill. 02:50 - 03:40 0.83 CASE P RUNPRD Load and launch .625" ball. Talked to town engineer about no returns. Plan forward after putting ball on seat is to displace coil with 9.4ppg brine (on location) and then bullhead annulus with same. Making the assumption that being out of the openhole for +/-36hrs the FloPro mud has developed high gel strengths making it hard to regain any circulation. Ball sheared at 4212psi after pumping 48.8bbls. Pick-up confirm liner released. up wt 31 k at 17609'. 03:40 - 06:15 2.58 CASE P RUNPRD Displace coil and liner with 70bbls 9.4ppg brine at 1.55bpm 3263psi returns +/- <0.10bpm. Never any better after pumping 70 bbls. Swap to annulus pump at 0.25bpm 2275psi. At 27bbls in .59/2355. Pumped 69 bbl down annulus which equals to the annular volume to the deployment sleeve. Pressure inc rapidly, like shut a valve, slowed pump down and pressure still climbing. SD and lined out to cir down CT and gained 1:1 cir to the pits. Fixed a HP union seal. PT lines to 4500 psi. OK 06:15 - 07:15 1.00 CASE P RUNPRD Circulate down CT. Qp = 0.80 / 0.74 bpm CTP = 1223 psi. SD and lined out to rev cir. Q = 0.55 bpm at 1,340 psi stable Qp = 0.75 bpm @ 1,447 psi; no cir; P steady Qp = 1.25 bpm @ pressured up and gained no circulation. Pumped 11 bbl. Pumped a total 80 bbl down annulus SD and pressure fell 2,150 psi.112 psi in 1 mina dropping slowly 07:15 - 10:15 3.00 CASE P RUNPRD Cir down CT. Increasing Op to 1.5 bpm and at 1.0 bpm the started tossing some returns. Op = 1.531 1.14 bpm. Looks like what I would expect from loss and cir pressures. After 20 bbl's pumped O p = 1.53 / 1.05 bpm at 3125 psi. (consistence) With 90 bbl pumped down CT, (Annular volume equates to 84 bbl's) flo-pro at shaker, divert to cutting box. Diverted 54 bbl to cutting box. Looks like its all together. Circulate well and cleanup waste fluid from rig and TT and conducting SLB cementer crew change After pumping 260 bbl pumped the flowrates are at 1.54 / 0.92 bpm 3256 psi 10:15 - 14:00 3.75 CASE P RUNPRD Pumping red dye in 1-1/2 ppb bio water. SLB making crew change. Op = 1.54 / 0.95 bpm at 3115 psi. No red dye seen at the Printed: 5/1/2006 1:31:22 PM BP EXPLORATION Page 19 of 24 Operations Summary Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/18/2006 10:15 - 14:00 3.75 CASE P RUNPRD deployment sleeve bottoms. Waiting on 9.4 ppg brine from MIDF. With 90 bbl pumped up annulus seen red bizan at shaker. It channeled up the open hole annulus. 14:00 - 14:45 0.75 CEMT P RUNPRD Loading pits with 9.4ppg brine. O = 0.41/0.36 bpm at 530 psi 14:45 - 15:10 0.42 CEMT P RUNPRD Held PJSM on cements ops. Talked about HAZARDS assoicated with pumping cement, dart installation and cement cleanup. 15:10 - 15:45 0.58 CEMT P RUNPRD SLB primed up and batch mixing 15.8ppg cement. Cement at Density at 15:40 hrs Pumped 1.8 bbl water, PT to 5000 psi (OK) 15:45 - 17:15 1.50 CEMT P RUNPRD Pumped 20.9 bbl 15.8ppg cement at 1.4 bpm. SD cleaned up cement line and drop dart. Launched dart, displacing cement with 30 bbl 1.5 ppb Biozan. switched to 9.4 ppg brine, O = 1.56 / 0.70 bpm. CTP=3,267 psi. Reduced Op to 1.2 / 0.69 bpm, CT dart seated at 53.3 bbl and LWP sheared at 5,550 psi. Pumped 12.1 bbl at 1.1 /0.25 bpm at 2,400 psi. LWP seated in LC with 65.4 bbl behine. Final circulation O/P 1.03/0.18 bpm at 2,400 psi. Circulated a total of 8.9 bbl up annulus. Volume to top of fault is 4.3 bbl. Bumped LWP at 3,300 psi and released pressure and floats held. Put 200 psi on CT unstung from deployment sleeve. Cement in place at 17:07 hrs 17:15 - 21:00 3.75 CEMT P RUNPRD POOH replacing CT voidage. LD BTT CTLRT 21:00 - 00:00 3.00 EVAL P LOWER1 PU Cleanout BHA #18 4/19/2006 00:00 - 01:00 1.00 EVAL P LOWERI Check injector chains. Replace 1 roller bearing. 01:00 - 03:15 2.25 EVAL P LOWER1 MU injector. RIH. At 0300hrs SLB called reporting Cmt compressive strength at 1400/psi Entered liner top +/- 14415' no cement 0.74/0.74 2970psi. RIH to 14444'. PU wt check 28.8k 03:15 - 05:10 1.92 EVAL P LOWER1 RIH 0.74/0.86 3000psi 29'/min 13.6K clean all the way to tag at 17600'. 05:10 - 09:15 4.08 EVAL P LOWER1 TOH. Cement at 1600 psi at 14,000ft while POOH. Will test later Some trace of cement to surface. 09:15 - 10:00 0.75 EVAL P LOWER1 Make ready to stand back CSH. Dropped 1/2" ball and open CS P = 3200 psi at 3/4 bpm 10:00 - 10:20 0.33 EVAL P LOWER1 Safety meeting and identified HAZARDS on working CSH and standing it in derrick 10:20 - 13:00 2.67 EVAL P LOWER1 POOH standing back CSH. SLB is conducting chain inspection on injector 13:00 - 13:30 0.50 EVAL P LOWER1 Held PJSM concern RA Source and hazards 13:30 - 16:30 3.00 EVAL P LOWER1 PU SLB's MCNL BHA 16:30 - 16:55 0.42 EVAL P LOWER1 Installed MHA and stabbed injector Set counter to 3,305.5 ft 16:55 - 18:50 1.92 EVAL P LOWERI RIH and confirm loggers depth encoder reading 18:50 - 20:50 2.00 EVAL P LOWER1 Start fogging MCNL from 14200' at 30'/min. Log to tag at 17608.2' 20:50 - 21:50 1.00 EVAL P LOWER1 Pull to 17558' and paint yellow flag. Log MCNL to 14400' at 60'/min 21:50 - 23:25 1.58 EVAL P LOWER1 TOH to BHA #19 PJSM: review hazards associated with handling 1" CSH 23:25 - 00:00 0.58 EVAL P LOWER1 Stand back CSH tbg 4/20/2006 00:00 - 01:15 1.25 EVAL P LOWER1 Finish standing back 1" CSH. 01:15 - 01:30 0.25 EVAL P LOWER1 Review with SLB precautions while handling source material from MCNL. Printed: 5/1/2006 1:31:22 PM BP EXPLORATION` Page 20 of 24 Operatioins SuIlnlmary Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date From.- To Hours Task Code NPT Phase Description ofiOperations 4/20/2006 01:30 - 02:15 0.75 EVAL P LOWER1 LD SLB logging tools. Preliminary results show good CCL data but CNL data has questionable data sections. TOL 14405' PBTD 17595' 02:15 - 03:00 0.75 EVAL P LOWER1 PT liner lap. Pressure up to 2000psi bled down to 1350 in 5 min checking for surface leaks. Repressure to 2000psi and double block everything leading back to pump. No surface leaks. 5 min 1370psi 10 min 1146psi 15 min 977psi 20 min 849psi 25 min 747psi 30 min 650psi Bleed remaining pressure off. 03:00 - 04:50 1.83 EVAL P LOWER1 PU SLB CBL logging tools. RIH w/ 1"CSH from derrick. 04:50 - 06:00 1.17 EVAL P LOWER1 Make up injector 06:00 - 07:10 1.17 EVAL P LOWER1 RIH w/ SCMT to 14,200 ft 07:10 - 10:50 3.67 EVAL P LOWER1 Log down w/ SCMT / GR at 15 fpm down 10:50 - 12:45 1.92 EVAL P LOWER1 PUH logging at 30 fpm with SCMT 12:45 - 15:00 2.25 EVAL P LOWER1 RIH to lay in pert pill 15:00 - 16:15 1.25 EVAL P LOWER1 POOH laying in pert pill 16:15 - 18:15 2.00 EVAL P LOWER1 POOH to run pert guns. tagup with BHA. 18:15 - 18:25 0.17 EVAL P LOWER1 PJSM review plan forward and CSH handling and inspection of coil. 18:25 - 20:30 2.08 EVAL P LOWERI Pop off injector. Inspect last 100' of 2" coil for wear patterns from chrome tbg. Set back injector. Stand back 41 std CSH UD 24 jts. LD SWS CBL tools. 20:30 - 23:45 3.25 EVAL P LOWER1 Remove excess tubulars from pipe shed while waiting for results on CBL. Load in 36 1.56" pert guns. CBL results show good cement bond up to at least 16000'. Good bond around 16400' fault zone. 23:45 - 00:00 0.25 EVAL P LOWERI PJSM w/ SLB pert crews. Discuss procedures and hazards with handling the pert guns. 4/21/2006 00:00 - 02:00 2.00 PERFO P LOWER1 PU 771' (630' net) of 1.56" 6 spf pert guns. 02:00 - 03:00 1.00 PERFO P LOWER1 RIH with 42 stds of 1" CSH from derrick. 03:00 --06:15 3.25 PERFO P LOWER1 PU injector and RIH with pert guns. Weight check at window 33K. Tagged at 17,613 ft MD (down). PU 36.5k at 17,603 ft MD, Corrected to 17,590.50 corrected to MCNL dated 4/19/2006. 06:15 - 06:40 0.42 PERFO P LOWER1 PUH to shooting depth of 17,350 ft. Dropped 1/2 ball, launched 06:40 - 08:03 1.38 PERFO P LOWER1 Pump 18 bbl behind ball and then switch to 9.4 brine Vp = 387/ (382 strap) bbls. Red Op to 0.2 bpm at 1,300 psi to land ball Ball on seat at 53.8 bbl. RIH PUH and pert on the fly at 4812 psi Perforated using 1.56" 6spf 1606 PJ guns: 16,600,ft to 16,800ft 16,840 ft to 16,960 ft 17,000 ft to 17,160 ft 17,200 ft to 17,350 ft 08:03 - 12:00 3.95 PERFO P LOWER1 PUH flilling hole. Stopped at 14,000 ft and checked flow. 12:00 - 12:30 0.50 PERFO P LOWER1 OOH, monitor well, OK PJSM, Unstab CTl and make ready to Printed: 5/1/2006 1:31:22 PM • BP EXPLORATION Page 21 of 24 Operations Summary Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Gode NPT .Phase Description of Operations 4/21/2006 12:00 - 12:30 0.50 PERFO P LOWER1 pull 1"CSH 12:30 - 14:45 2.25 PERFO P LOWER1 POOH standing CSH back in derrick 14:45 - 15:00 0.25 PERFO P LOWER1 THA/PJSM on pert gun handling and associated hazards 15:00 - 17:20 2.33 PERFO P LOWER1 RU to pull 36 guns out of hole and lay down. All shots fired. 17:20 - 18:25 1.08 PERFO P LOWERI RD TCP handling equipment from rig floor RU to run KB Packer 18:25 - 19:15 0.83 PERFO P LOWER1 PU Baker KB packer assembly w/ 2jts 1-1/4" CSH 19:15 - 23:00 3.75 PERFO P LOWER1 MU injector RIH at min rate of 0.30bpm/280psi to 14300' Up wt 31 K RIH wo pump tag at 14421' RIH to 14428 and stack out 10K. Check reel for ball drop position -good. PU bring on pump to 0.33/300 RIH pressure increase at 14422. PU RIH wo pump and repeat same depths. PU and repeat again. Enter TOL at 14421-2' no-go bottoms out at 14427.8 to 14428.3'. Pressure up to 400psi. PU and pressure drop at 14420.9' PU to 14401' Launch .625" aluminum ball. Up wt 31-32K 23:00 - 00:00 1.00 PERFO P LOWER1 Circulate ball down on seat at 0.78 bpm 750psi 4/22/2006 00:00 - 00:30 0.50 ZONISO LOWERI Continue pumping .625" aluminum ball. On seat at 51.6bbls away. RIH to 14428' to stackout depth. PU to 14423'. Pressure up to 2000psi to set slips and energize seal assembly. Set down 10k down. Slowly bleed off pressure. 00:30 - 03:00 2.50 ZONISO LOWER1 Pressure test annulus to 2000psi. Bled down to 1250 after 10min. Check for surface leaks. Pressure back up 2000psi and close in double block everything on surface. Bled off to 1240 after 12 min. Coil pressure rising slowly so seals must not be set. Bleed off pressure. stackout to -2k. Pressure up again. Close Kill HCR. Continues to leak as prior test. Bleed down. Tried again same results. Bleed off pu to neutral wt. Re test -same. Bleed off replace wellhead transducer with gauge and retest. Same results. Call town discuss. Have not sheared off packer yet so can pull to release packer and TOH. Tool designed to release 15k over sting wt which is 32K PU to release. Appears slips never set on intial setting pressure of 2000psi. Picking up with just string wt of 32k. No overpull Okay going to try this all over again. Pull to 144417 free. RIH see entering TOL at 14426.1' stacking out at 14431.1 Pull to 14424' 25k. Pressure up on coil to 2200psi and hold (shear release set at 2500psi) 5min. Set down 10k 144428.6' bleed off CP CTW 15.7 setdown another 10k 5.3k Pumping down annulus. PT to 2000psi. Still same problem bled down to 1120psi after 10min. Bleed off all pressure. PU to release packer. Up wt 34k. Not seeing the additional 15k we should see if the slips had set. Something wrong with packer. Could try to increase the setting pressures but run the risk of shearing the release. need to TOH and check packer. 03:00 - 06:00 3.00 ZONISO N LOWER1 TOH 60'/min. With ball on seat filling hole across top. 06:00 - 06:50 0.83 ZONISO N LOWER1 PUH and LD BOT KB Packer BHA Bottom 3 seal on seal assy are damaged and the running tool looks fine while the packer slips did not engage tubing. 06:50 - 07:30 0.67 ZONISO N LOWER1 Load out KB packer to have rebuilt. RU to RIH with 1" CSH to Printed: 5/1/2006 1:31:22 PM • BP EXPLORATION Page 22 of 24 Qperatiolns Sumllnary Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date from - To Hours Task .Code NPT Phase Description of Operations 4/22/2006 06:50 - 07:30 0.67 ZONISO N LOWERI LD 07:30 - 11:20 3.83 ZONISO N LOWER1 RIH with 41 stands 1" CSH to LD. LD Same. BOT found lots of scal and deris in the running tool of the KB Pkr. The seal assy was scared up and new o-rings installed. 11:20 - 12:45 1.42 ZONISO N LOWER1 PU Injector, cut off CTC and 100 ft CT (CT Management in Cr tubing) Installed Kendell CTC and pull tested to 32k, PT tp 3500 psi 12:45 - 13:30 0.75 ZONISO N LOWER1 PU BOT PBR Polishing 2.24" BHA 13:30 - 16:10 2.67 ZONISO N LOWER1 RIH Computer locked up at 9,700 ft Rebotted. RIH and tagged PBR at 14440.5 uncorrected 16:10 - 18:45 2.58 ZONISO N LOWER1 Reaming out PBR at 1.6 bpm at 2,550 psi. Flowrates at 1.59 / 1.58 bpm Mill 5.68 ft max to No/Go. Washed down to 14,438.6 ft CTP. CTP climbed 250 psi, No/Gon on the top of PBR PU , CTW = 27.5k at 1.6 bpm. Ream again down to 14,439.4 ft PU to 14,429 ft and wash /ream down again. Started 10 bbl 2ppb Bio pill down CT. Washed down to 14,441 ft at 1.6 bpm and 3,098 psi, Wash down again to ensure the No / Go at the top of PBR. 500 psi pressure spike at 14,441 ft. PUH, clean. SD pump and launched 5/8" ball to open CS with 10 bbl biozan. Washed down again to 14,441 ft. ball hit at 48.1 bbls Pressure up to 4500 and tripped pumps. Reset to 4800psi pressue up again and tripped. Reset to 5000psi. Circ sub sheared at 4950psi. 18:45 - 22:15 3.50 ZONISO N LOWER1 TOH Hold PJSM/THA for swapping BHA's and changing injector pack-off. 22:15 - 23:00 0.75 ZONISO N LOWER1 LD motor and mill assembly. No-Go appears to have touched the Deployment Sleeve top as designed. PU re-drressed KB packer assembly and setting tool. Changed out injector pack-off. 23:00 - 0.00 ZONISO N LOWERI RIH 4/23/2006 00:00 - 02:00 2.00 ZONISO N LOWER1 Finish RIH w/ KB packer. Weight check at 14400' 33k. 02:00 - 03:35 1.58 ZONISO N LOWER1 RIH slowly appeared to enter PBR at 14421' continued to take weight rather than "slip" into PBR as seen on previous packer run. Had 10k setdown wt at 14427'. PU full wt back at 14417.4' pull to 14400 to load and launch ball 0.90/900psi ball on seat at Vt= 51.2bbls RIH to 14427 with 10k setdown wt on packer. PU see 33k put wt at 14416.8' pu to 14414.5' Pressure up to 2200psi to set pkr slips. Vt = 51.6bbls slack off 10k to 18k bleed off CT pressure slack off another 10k to 8k depth 14423' Appears that slips have set. 03:35 - 04:25 0.83 ZONISO N LOWERI Line up to pump down annulus. PT liner lap 03:40 2080psi 03:55 2051 psi 04:10 2040 psi Good test. Bleed down. Line up on coil. Pressure up to 3050psi and shear piston in setting tool. PU didn't want to release. Work pipe. Pump down coil 1.0/1250psi PU then came free. 04:25 - 07:15 2.83 ZONISO N LOWER1 TOH. Conducting PJSM on handling KB BHA. While PUH slowley with hydraulic/reel pressure dialed down to 550 /600psi and ready to bump up at 38' the slimhole CTC, MDA and 1 jt of Printed: 5/1/2006 1:31:22 PM BP EXPLORATION. Page 23 of 24 ©pera#ions Summary Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task. Code NPT Phase Description of Operations 4/23/2006 04:25 - 07:15 2.83 ZONISO N LOWER1 1-1/4" CSH pulled through the injector and we stopped it with Kendell CTC just past the guide arch. Joint 1-1/4" CSH across the chains 07:15 - 07:45 0.50 ZONISO N LOWER1 Held THA/PJSM on way forward to pull the CT back in the hole using a wench line on the pipe shed roof to pull back in the hole in small increments. 07:45 - 08:15 .0.50 ZONISO N LOWER1 RU wrench, sling and clamp on CT above pipe shed. Using chain pressure, pulled CT in the hole and secured in chains. 08:15 - 08:30 0.25 ZONISO N LOWER1 RD clamp and slings 08:30 - 09:00 0.50 ZONISO N LOWER1 Unstab injector and stand back to circulate. Pulled out 1 bent joint of 1-1 /4" CSH and lay down. Loaded out BOT's equipment. 09:00 - 09:30 0.50 ZONISO N LOWER1 Cut off CTC and installed new non slimhole CTC Pull 2.2" OD CTC to 35k. Pulled up to packoff at 10k. 09:30 - 10:20 0.83 ZONISO N LOWER1 Held Post job incident review and planned way forward. 10:20 - 11:15 0.92 ZONISO N LOWER1 Installed mechanical counter. PU FP nozzle and extension BHA 11:15 - 12:20 1.08 WHSUR N POST RIH to FP wellbore at 5900 ft Pumped 51 bbl of diesel down CT 12:20 - 13:20 1.00 WHSUR N POST POOH FP well taking returns through choke PUH at 107 fpm while pumping at 1.17 bpm keeping returns at 0.71 bpm. WHP increasing at 3,500 ft along with out flowrate. Take returns to TT density at 8.5 ppg 6.73ppg diesel at MM. SWI 13:20 - 13:45 0.42 WHSUR N POST OOH, SWI Final WHP = 384 psi Bleed pressure off, blow down surface lines RD jetting nozzle BHA 13:45 - 14:30 0.75 WHSUR N POST RU DSM and set BPV. WHP = 10 psi RD DSM and load out. Cleaning pits 14:30 - 15:15 0.75 WHSUR N POST Held operational and PJSM on conducting the CT shear with cable inside the CT. 15:15 - 18:15 3.00 WHSUR N POST Fill stack with 9.4ppg brine. Placed 25 ft 5/16" monocable in CT from the bottom Installed nozzle and placed injector over wellhead Stab on well and RIH 19.9 ft PU to 18.4 ft Rebuild Nordic's test pump and tested Set bottom 2" combi's pull test to 4k 7 sec voical Sheared CT in 2 sec, lost 4k string wt. PT below blind shears. PT to 250 psi and test failed on low side PU on CT and unstabbed. PU and cable still) attached. Blow down stack to look at cable. Opened blinds and pulled a-line from stack. It was cut in half. Pictures were taken and will be e-mailed to town. Apparently a few strands rode up between shears and the PT failed because of that. 18:15 - 19:00 0.75 WHSUR N POST After an extensive crew changeout lined up to retest the blinds. Test good @ 250psi/5min and 3500psi/5min. 19:00 - 20:10 1.17 WHSUR N POST Mix 15bb1 pumpable corrision inhibitor in pit#4. Put 60 bbls FW in pit#5. Spot truck with bleach another with methanol. Line-up to Tiger Tank 20:10 - 20:20 0.17 WHSUR N POST PJSM again to be sure everyone is on same page for the Printed: 5/1/2006 1:31:22 PM BP EXPLORATION Page 24 of 24 Operations Summalry Report Legal Well Name: P2-11 Common Well Name: P2-11 Spud Date: Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/24/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/24/2006 Rig Name: NORDIC 2 Rig Number: Date from - To Hours Task Code NPT Phase Description of Operations 4/23/2006 20:10 - 20:20 0.17 WHSUR N POST pumping sequence. Discuss hazards associated with the fluids being pumped. 20:20 - 21:25 1.08 WHSUR N POST Stab injector on well. RIH 6' Open pipe/slip combi's to drop held pipe during cut test. Pump the following: 15 bbls bleach 60 bbls freshwater 15 bbls corrision inhibitor 10 bbls methanol 4 bbl freshwater to flush rig pumps 21:25 - 21:35 0.17 WHSUR N POST PJSM with SLB N2 crews and rig crews. Review job hazards and procedures. 21:35 - 00:00 2.42 WHSUR N POST Fluids lined up to Tiger Tank. PT N2 lines to 2500psi. Come on line with N2 1500SCFM for 20 min. Bleed down coil Same time vac out all fluids in rig pits, Tiger Tank and cuttings tank. Removed hardline inside reel. 4/24/2006 00:00 - 00:10 0.17 WHSUR P POST PJSM review operations and hazards for installation of internal coil grapple and winding coil back from injector to reel, 00:10 - 01:15 1.08 WHSUR P POST Unstab injector from well. Dress end of coil. Install internal grapple and pull test, retighten. Pull coil to reel and secure. Secure injector for rig move. Spot truck to receive reel. 01:15 - 01:25 0.17 WHSUR P POST PJSMITHA review operations and hazards for loweing reel to truck. 01:25 - 02:00 0.58 WHSUR P POST Open Bombay doors and lower reel. 02:00 - 03:00 1.00 BOPSU P POST Remove blind/Shear ram doors. Remove inspect and rebuild. Take pictures. Reinstall rams. 03:00 - 06:00 3.00 BOPSU P POST ND BOPE. Install tree cap. Pressure test to 5000k. RIG RELEASED AT 06:00 HRS 4/24/2006 Move to S-103 Printed: 5/1/2006 1:31:22 PM ,,,,. b ~ BP Alaska • BAff R~ p Baker Hughes INTEQ Survey Report 1NTE~G S Q Company: BP Amoco Date: 5/7(2006 Time: 11:47:29 Page: 1 Field: Point McIntyre Co-ordinate(NE) Reference: Well: P2-11, True North Site: Pt Mac 2 Vertical (TVD) Reference: P2-11 49.8 Well: P2-11 Section (VS) Reference: Well (O.OON,O.OOE,SO.OOAzi) Wellpath: P2-11AP61 Survey Calculation Method: Minimum Curvature Db: OraGe Field: Point McIntyre North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Pt Mac 2 TR-12-14 UNITED STATES :North Slope Site Position: Northing: 5995140.76 ft Latitude: 70 23 32.530 N From: Map Easting: 674873.98 ft Longitude: 148 34 37.934 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: P2-11 Slot Name: 11 P2-11 Well Position: +N/-S 3286.65 ft Northing: 5998579.63 ft Latitude: 70 24 4.825 N +E/-W 6555.67 ft Easting : 681350.56 ft Longitude: 148 31 25.868 W Position Uncertainty: 0.00 ft Wellpath: P2-11AP61 Drilled From: P2-11 Tie-on Depth: 15075.14 ft Current Datum: P2-11 Height 49.80 ft Above System Datum: Mean Sea Level Magnetic Data: 2/3/2006 Declination: 24.74 deg Field Strength: 57616 nT Mag Dip Angle: 80.97 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 38.40 0.00 0.00 80.00 Survey Program for Definitive Wellpath Date: 2/3/2006 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 100.00 5442.00 Survey #1 Gyro GC MS (100.00-5 GCT-MS Schlumberger GCT multishot 5481.05 14630.39 Survey #2 MWD (5481.05-15007.4 MWD MWD -Standard 14642.00 15075.14 Survey #1 MWD (14642.00-15153. MWD MWD -Standard 15078.00 16450.00 MWD (15078.00-16450.00) MWD MWD -Standard Annotation MD TVD ft ft 15075.14 8973.41 TIP 15078.00 8973.43 KOP 16450.00 9035.88 TD Survey: MWD Start Date: 4/4/2006 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path r BP Alaska ~ s~R ~ by Baker Hughes INTEQ Survey Report INTE~G~S Q Company: BP Amoco Date: 5!7/2006 Tiroe: 11:47:29 Page: 2 Field: Point McIntyre Co-ordinate(NE) Reference: Well: P2-11, True North Site: Pt Mac 2 Vertical (TVD) Reference: P2-11 49.8 Well: P2-11 Section (VS) Reference: Well (O.OON,O.OOE,80.OOAzi) Wellpath: P2-11AP61 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD ft Incl deg Azim deg TVD ft Sys TVD ft N/S ft E/W ft 15075.14 89.82 22.12 8973.41 8923.61 -977.38 10069.17 15078.00 89.31 21.65 8973.43 8923.63 -974.72 10070.24 15078.00 89.31 21.65 8973.43 8923.63 -974.72 10070.24 15095.00 85.59 22.30 8974.19 8924.39 -958.98 10076.59 15128.36 86.30 23.60 8976.55 8926.75 -928.33 10089.57 15159.33 86.79 24.80 8978.41 8928.61 -900.14 10102.24 15190.76 86.60 26.00 8980.22 8930.42 -871.79 10115.70 15220.91 86.32 27.73 8982.09 8932.29 -844.95 10129.30 15251.54 85.27 26.31 8984.33 8934.53 -817.74 10143.17 15284.81 85.74 25.10 8986.94 8937.14 -787.85 10157.56 15318.05 86.38 25.33 8989.22 8939.42 -757.85 10171.69 15349.74 86.81 26.56 8991.11 8941.31 -729.41 10185.53 15380.11 86.23 26.95 8992.95 8943.15 -702.34 10199.17 15412.82 86.54 26.80 8995.01 8945.21 -673.22 10213.93 15442.86 86.50 27.38 8996.83 8947.03 -646.52 10227.59 15476.56 86.91 26.85 8998.77 8948.97 -616.58 10242.92 15506.75 87.34 29.05 9000.29 8950.49 -589.94 10257.05 15536.83 86.66 29.20 9001.86 8952.06 -563.70 10271.67 15567.97 86.85 30.32 9003.62 8953.82 -536.71 10287.10 15597.19 86.48 30.56 9005.32 8955.52 -511.57 10301.88 15644.69 87.03 30.60 9008.01 8958.21 -470.74 10326.01 15675.49 86.88 32.09 9009.65 8959.85 -444.47 10342.01 15704.93 87.10 33.65 9011.19 8961.39 -419.78 10357.96 15735.55 87.16 34.96 9012.73 8962.93 -394.52 10375.20 15767.73 87.40 36.48 9014.25 8964.45 -368.42 10393.96 15799.55 86.91 36.97 9015.83 8966.03 -342.95 10412.97 15830.66 86.92 37.83 9017.51 8967.71 -318.27 10431.84 15862.54 87.13 39.37 9019.16 8969.36 -293.39 10451.70 15891.21 87.19 40.74 9020.58 8970.78 -271.47 10470.12 15920.74 86.60 42.06 9022.18 8972.38 -249.35 10489.62 15950.06 86.45 42.96 9023.96 8974.16 -227.78 10509.40 15980.13 86.98 43.53 9025.68 8975.88 -205.91 10529.97 16010.59 86.61 43.53 9027.39 8977.59 -183.86 10550.91 16040.55 87.10 45.10 9029.03 8979.23 -162.46 10571.81 16073.69 87.03 47.28 9030.73 8980.93 -139.55 10595.69 16100.64 86.95 47.90 9032.14 8982.34 -121.40 10615.56 16132.69 86.79 48.74 9033.89 8984.09 -100.12 10639.47 16171.60 87.99 51.37 9035.66 8985.86 -75.17 10669.26 16201.44 88.51 51.36 9036.58 8986.78 -56.54 10692.56 16230.81 88.79 52.02 9037.27 8987.47 -38.34 10715.60 16261.08 89.31 53.43 9037.77 8987.97 -20.01 10739.68 16291.98 90.20 54.07 9037.90 8988.10 -1.74 10764.60 16320.52 90.81 54.66 9037.65 8987.85 14.89 10787.80 16352.16 90.90 55.32 9037.18 8987.38 33.04 10813.71 16380.77 90.35 56.41 9036.87 8987.07 49.09 10837.39 16410.30 90.94 58.04 9036.53 8986.73 65.07 10862.21 16450.00 90.94 58.04 9035.88 8986.08 86.08 10895.89 MapN MapE ft ft 5997846.96 691439.86 5997849.64 691440.86 5997849.64 691440.86 5997865.54 691446.83 5997896.48 691459.05 5997924.98 691471.04 5997953.64 691483.80 5997980.80 691496.74 5998008.34 691509.96 5998038.56 691523.61 5998068.90 691537.01 5998097.67 691550.15 5998125.06 691563.13 5998154.52 691577.18 5998181.54 691590.18 5998211.85 691604.78 5998238.81 691618.26 5998265.40 691632.24 5998292.75 691647.01 5998318.25 691661.18 5998359.65 691684.30 5998386.30 691699.66 5998411.37 691715.01 5998437.04 691731.63 5998463.58 691749.75 5998489.51 691768.13 5998514.63 691786.39 5998539.99 691805.64 5998562.34 691823.53 5998584.93 691842.49 5998606.97 691861.73 5998629.33 691881.76 5998651.88 691902.17 5998673.78 691922.54 5998697.27 691945.85 5998715.89 691965.28 5998737.75 691988.65 5998763.41 692017.83 5998782.59 692040.67 5998801.35 692063.26 5998820.26 692086.89 5998839.12 692111.36 5998856.31 692134.14 5998875.08 692159.60 5998891.70 692182.88 5998908.28 692207.31 5998930.11 692240.47 VS DLS Tool ft deg/100ft 9746.48 0.00 MWD 9747.99 24.25 MWD 9747.99 0.00 MWD 9756.98 22.21 MWD 9775.08 4.43 MWD 9792.46 4.18 MWD 9810.63 3.86 MWD 9828.69 5.80 MWD 9847.08 5.76 MWD 9866.44 3.89 MWD 9885.56 2.05 MWD 9904.13 4.11 MWD 9922.27 2.30 MWD 9941.86 1.05 MWD 9959.94 1.93 MWD 9980.24 1.99 MWD 9998.78 7.42 MWD 10017.74 2.31 MWD 10037.62 3.64 MWD 10056.54 1.51 MWD 10087.39 1.16 MWD 10107.71 4.86 MWD 10127.71 5.34 MWD 10149.07 4.28 MWD 10172.08 4.78 MWD 10195.22 2.18 MWD 10218.09 2.76 MWD 10241.97 4.87 MWD 10263.92 4.78 MWD 10286.96 4.89 MWD 10310.18 3.11 MWD 10334.24 2.59 MWD 10358.69 1.21 MWD 10382.99 5.48 MWD 10410.49 6.57 MWD 10433.21 2.32 MWD 10460.44 2.66 MWD 10494.12 7.42 MWD 10520.30 1.74 MWD 10546.15 2.44 MWD 10573.05 4.96 MWD 10600.76 3.55 MWD 10626.49 2.97 MWD 10655.16 2.11 MWD 10681.27 4.27 MWD 10708.49 5.87 MWD 10745.31 0.00 MWD b ~ ~P Alaska p Baker Hughes INTEQ Survey Report w ~i.~ s~~s ~, . ~ ...t Company: BP Amoco Date: 5/7/2006 Time: 11:49:44 Page: 1 Field: Point McIntyre Co-ordinate(NE) Reference: Well: P2-11, True North Site: Pt Mac 2 Vertical (TVD) Reference: P2-11 49.8 WeUc P2-11 Section (VS) Reference: Well (O.OON,O.OOE,80.OOAzi) Wellpath: P2-11A Survey Calculation Metbod: Minimum Curvature Db: Oracte Field: Point McIntyre North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2005 ~ - _ - Site: Pt Mac 2 ----- TR-12-14 UNITED STATES :North Slope Site Position: Northing: 5995140.76 ft Latitude: 70 23 32.530 N From: Map Easting: 674873.98 ft Longitude: 148 34 37.934 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: P2-11 Slot Name: 11 P2-11 Well Position: +N/-S 3286.65 ft Northing: 5998579.63 ft Latitude: 70 24 4.825 N +E/-W 6555.67 ft Easting : 681350.56 ft Longitude: 148 31 25.868 W Position Uncertainty: 0.00 ft Wellpath: P2-11A Drilled From: P2-11AP61 Tie-on Depth: 15862.54 ft Current Datum: P2-11 Height 49.80 ft Above System Datum: Mean Sea Level Magnetic Data: 4/8/2006 Declination: 24.67 deg Field Strength: 57617 nT Mag Dip Angle: 80.97 deg Vertical Section: Depth From (TVD) +N/-S +E!-W Direction ft ft ft deg 38.40 0.00 0.00 80.00 Survey Program for Definitive Wellpath Date: 4/17/2006 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 100.00 5442.00 Survey #1 Gyro GC MS (100.00-5 GYD-GC-MS Gyrodata gyrocompassing m/s 14642.00 15153.32 Survey #1 MWD (14642.00-15153. MWD MWD -Standard 15887.00 17640.00 MWD (15887.00-17640.00) MWD MWD -Standard Annotation MD TVD ft ft 15862.54 9019.16 TIP 15887.00 9020.38 KOP 17640.00 9118.90 TD Survey: MWD Start Date: 4!8/2006 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path b ~ BP Alaska ~ s P Baker Hughes INTEQ Survey Report 1NTEQ Company: BP Amoco Date: 5/7/2006 Time: 11:49:44 Page: . 2 Field: Point McIntyre Co-ordinate(NE) Reference: Well: P2-11, True North Site: Pt Mac 2 Vertical (TVD) Reference: P2-11 49.8 Well: P2- 11 Section (VS) Reference: Well (O.OON,O. OOE,80.OOAzi) Wellpath: P2- 11A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Iucl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 15862.54 87.13 39.37 9019.16 8969.36 -293.39 10451.70 5998539.99 691805.64 10241.97 0.00 MWD 15887.00 87.18 40.54 9020.38 8970.58 -274.66 10467.39 5998559.09 691820.87 10260.67 4.78 MWD 15920.96 84.38 36.56 9022.88 8973.08 -248.19 10488.49 5998586.07 691841.32 10286.05 14.30 MWD 15951.66 83.87 32.80 9026.02 8976.22 -223.08 10505.86 5998611.59 691858.08 10307.52 12.30 MWD 15981.69 84.00 34.05 9029.19 8979.39 -198.16 10522.31 5998636.90 691873.92 10328.04 4.16 MWD 16010.27 84.49 35.31 9032.06 8982.26 -174.77 10538.49 5998660.67 691889.53 10348.04 4.71 MWD 16041.29 84.49 34.85 9035.04 8985.24 -149.50 10556.24 5998686.36 691906.65 10369.90 1.48 MWD 16070.27 84.43 35.57 9037.84 8988.04 -125.94 10572.87 5998710.32 691922.70 10390.37 2.48 MWD 16102.37 84.53 37.30 9040.92 8991.12 -100.23 10591.84 5998736.48 691941.05 10413.52 5.37 MWD 16130.32 84.89 38.01 9043.50 8993.70 -78.20 10608.84 5998758.92 691957.51 10434.09 2.84 MWD 16161.76 84.94 39.56 9046.29 8996.49 -53.79 10628.46 5998783.79 691976.53 10457.65 4.91 MWD 16194.04 85.12 41.23 9049.08 8999.28 -29.30 10649.30 5998808.78 691996.77 10482.43 5.18 MWD 16221.67 85.33 43.81 9051.38 9001.58 -9.01 10667.91 5998829.52 692014.87 10504.27 9.34 MWD 16250.19 85.41 40.88 9053.69 9003.89 12.00 10687.05 5998850.98 692033.50 10526.78 10.24 MWD 16280.48 86.14 40.38 9055.92 9006.12 34.93 10706.72 5998874.38 692052.61 10550.13 2.92 MWD 16310.98 87.04 42.49 9057.73 9007.93 57.75 10726.87 5998897.68 692072.20 10573.93 7.51 MWD 16340.93 87.96 42.88 9059.04 9009.24 79.75 10747.16 5998920.16 692091.94 10597.73 3.34 MWD 16370.34 88,36 44.03 9059.98 9010.18 101.08 10767.37 5998941.98 692111.63 10621.35 4.14 MWD 16400.26 88.82 44.33 9060.72 9010.92 122.54 10788.22 5998963.93 692131.95 10645.60 1.84 MWD 16430.39 89.59 44.76 9061.14 9011.34 144.01 10809.35 5998985.91 692152.55 10670.14 2.93 MWD 16460.77 90.66 45.29 9061.07 9011.27 165.48 10830.84 5999007.89 692173.52 10695.03 3.93 MWD 16490.09 91.43 45.83 9060.54 9010.74 186.00 10851.77 5999028.92 692193.94 10719.21 3.21 MWD 16531.18 91.18 48.23 9059.60 9009.80 214.00 10881.83 5999057.64 692223.31 10753.67 5.87 MWD 16564.05 91.68 49.36 9058.78 9008.98 235.65 10906.55 5999079.87 692247.49 10781.77 3.76 MWD 16598.20 91.52 49.93 9057.83 9008.03 257.75 10932.56 5999102.60 692272.96 10811.23 1.73 MWD 16633.09 89,31 52.27 9057.57 9007.77 279.66 10959.71 5999125.16 692299.57 10841.77 9.22 MWD 16663.50 86.69 54.89 9058.64 9008.84 297.70 10984.16 5999143.79 692323.57 10868.98 12.18 MWD 16697.34 86.93 56.24 9060.52 9010.72 316.80 11012.03 5999163.56 692350.97 10899.74 4.05 MWD 16727.08 88.17 58.67 9061.79 9011.99 332.79 11037.07 5999180.15 692375.61 10927.18 9.17 MWD 16765.95 87.77 60.60 9063.17 9013.37 352.42 11070.59 5999200.59 692408.64 10963.60 5.07 MWD 16800.23 87.46 62.41 9064.59 9014.79 368.76 11100.69 5999217.65 692438.33 10996.08 5.35 MWD 16829.86 87.92 66.62 9065.79 9015.99 381.50 11127.41 5999231.03 692464.73 11024.60 14.28 MWD 16867.91 87.40 69.10 9067.34 9017.54 395.83 11162.62 5999246.21 692499.59 11061.77 6.65 MWD 16898.61 86.75 71.28 9068.91 9019.11 406.22 11191.46 5999257.30 692528.17 11091.98 7.40 MWD 16930.03 87.00 75.21 9070.62 9020.82 415.26 11221.50 5999267.06 692557.97 11123.13 12.51 MWD 16960.67 87.80 78.67 9072.01 9022.21 422.17 11251.31 5999274.70 692587.61 11153.69 11.58 MWD 16993.01 87.25 82.48 9073.41 9023.61 427.46 11283.18 5999280.76 692619.33 11185.99 11.89 MWD 17022.11 86.60 85.04 9074.97 9025.17 430.62 11312.06 5999284.62 692648.13 11214.98 9.06 MWD 17050.53 89.49 88.02 9075.94 9026.14 432.34 11340.41 5999287.02 692676.42 11243.20 14.60 MWD 17085.07 88.54 91.52 9076.54 9026.74 432.48 11374.94 5999288.00 692710.94 11277.22 10.50 MWD 17113.64 86.97 94.60 9077.65 9027.85 430.96 11403.44 5999287.17 692739.47 11305.03 12.09 MWD 17150.06 87.65 99.79 9079.37 9029.57 426.40 11439.52 5999283.49 692775.65 11339.77 14.36 MWD 17182.36 88.05 102.84 9080.58 9030.78 420.07 11471.17 5999277.93 692807.43 11369.84 9.52 MWD 17212.72 87.19 103.01 9081.84 9032.04 413.28 11500.73 5999271.87 692837.15 11397.78 2.89 MWD 17243.57 87.68 100.19 9083.22 9033.42 407.09 11530.92 5999266.40 692867.48 11426.43 9.27 MWD 17279.05 90.45 96.98 9083.80 9034.00 401.79 11565.99 5999261.96 692902.66 11460.05 11.95 MWD 17311.37 90.72 94.65 9083.47 9033.67 398.52 11598.14 5999259.47 692934.88 11491.14 7.26 MWD 17342.06 89.89 92.81 9083.30 9033.50 396.52 11628.76 5999258.22 692965.54 11520.95 6.58 MWD 17370.56 90.02 88.86 9083.33 9033.53 396.11 11657.25 5999258.49 692994.03 11548.94 13.87 MWD 17402.39 89.28 86.14 9083.52 9033.72 397.49 11689.05 5999260.65 693025.78 11580.49 8.86 MWD 17430.27 86.02 84.65 9084.66 9034.86 399.73 11716.81 5999263.56 693053.48 11608.22 12.85 MWD 17463.40 86.73 82.44 9086.76 9036.96 403.45 11749.66 5999268.07 693086.23 11641.22 6.99 MWD 17493.54 83.91 80.98 9089.22 9039.42 407.78 11779.38 5999273.12 693115.84 11671.24 10.53 MWD b ~ BP Alaska ~ s p Baker Hughes INTEQ Survey Report 1NTE ~ Q Company: BP Amoco Date: 5/7/2006 Time: 11:49:44 Page: 3 Field: Point McIntyre Co-0rdinate(NE) Reference: Well: P2-11, True North Site: Pt Mac 2 Vertical (1'VD) Reference: P2-11 49.8 Well: P2-11 Section (VS) Reference: Well (O.OON,O.OOE,80.OOAzi) Wellpath: P2-11A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MspE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 17524.38 81.50 81.07 9093.13 9043.33 412.55 11809.60 5999278.63 693145.93 11701.82 7.82 MWD 17554.47 78.57 79.98 9098.34 9048.54 417.43 11838.83 5999284.21 693175.03 11731.45 10.37 MWD 17585.05 75.55 78.57 9105.19 9055.39 422.97 11868.10 5999290.46 693204.16 11761.25 10.85 MWD 17640.00 75.55 78.57 9118.90 9069.10 433.51 11920.26 5999302.27 693256.04 11814.44 0.00 MWD TREE = 4-1116" 5M CHROME ~NELLHEAD = CIW ACTUATOR = BAKER C KB. ELEV = BF. ELEV = 49.8' _ __ KOP = Max Angle = Datum MD = 1.381' 91 @ 14784' 14462' Datum TV D = 8800' SS ~ P2-11A l'®t'ti ®R~..G D AST I E(1' NOTES: HORIZONTAL WELL 2195' t-~ TRSSSV, HES SERIES 10, ID = 2.81" GAS LIFT MANDRELS 9-5/8" CSG, 40#, L-80, ID = 8.835" ~ 5741' Minimum ID = 2.75" @ 14427 3-1 i2" HES XN NIPPLE 7" CSG, 26#, L-80, ID = 6.276" ~~ 13662' TOP OF BOT KB Backer I 1440(}° TOP OF 2-3i8" 13cr80 LNR 14405' TOP OF 4-1/2" LNR 14419' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4262 4061 50 MMG-5 RK 2 5838 5024 57 MMG-5 RK 3 8047 6013 64 MMG-5 RK 4 9874 6824 64 MMG-5 RK 5 11883 7709 62 MMG-5 RK 6 13274 8318 64 MMG-5 RK 7 14330 8790 63 MMG-5 RK 14391' I-{ 7" X 4-112" BAKER S-3 PKR, ID = 3.875" 14416' ~~ 3-1/2" HES X NIP, ID = 2.813" 14427' (-~ 3-1l2" HES XN NIP, ID = 2.75" 3-1/2" TBG, 9.2#, 13CR, 0.0087 bpf, ID = 2.992" I-i 14438' 7" CSG, 29#, 13CR, ID = 6.184" ~~ 14654' PERFORATION SUMMARY Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 6 16000 - 16800 O 04/21!06 1.56" 6 16840 - 16960 O 04/21/06 1.56" 6 17000 - 17160 O 04/21/06 1.56" 6 17200 - 17350 O 04/21/06 PBTD 15157' 4-1/2" LNR, 12.6#, 13CR, 0.0152 bpf, ID = 3.958" 15199' 14438' --f 3-1/2" WLEG, ID = 3.000" 14425' ELMD TT LOGGED 10/30/99 15460° Top of Cement t'3 O C'~ O O 2-3/8" 13Cr80 ! L-80 cemented liner 17593' pbtd 35080' Mechanical Whipstock DATE REV BY COMMENTS DATE REV BY COMMEMS 70/28/98 ORIGINAL COMPLETION 04/24/06 NORDIC SIDETRACK 12/21/98 MILL TIGHT COLLARS POST 12/21/98 RIG. (LAST RUN 2.805" MILL) POINT MCINTYRE UNIT WELL: PZ-11 PERMfr No: x1981920 API No: 50-029-22923-01 SEC 11 T12N R14E4147.16 FEL 857.43 FNL BP Exploration (Alaska) o ~~ r~ '~ ~..~° u~ ~ ~ f~ ~ P; ~~ ~~ ~ f,~ FRANK H. MURKOWSKI, GOVERNOR l ~T~+ ~--~~~t~~BiA ®IlL ~~.~~I) cG~A~5T C®1`~~~~~Jll®~ C®1TJl1~Jli~-7~~/1't ,~ ANCHORAGE, ALASKA 9950-3539 ,~` PHONE (907) 27g-1433 Barb Lasley FAx (907) 27sasa2 CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, PBU P2-1 lA BP Exploration (Alaska), Inc. Permit No: 206-026 Surface Location: 1' FSL, 1115' FWL, SEC. 11, T12N, R14E, UM Bottomhole Location: 4706' FNL, 3760' FWL, SEC. 18, T12N, R15E, UM Dear Mr. Lasley: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) X59-3607 (pager). / t DATED this ~a day of February, 2006 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS, AND GAS CONSERVATION COMMI~I PERMIT TO DRILL 20 AAC 25.005 FEB 1 4 2006 Alaska Oil & Gas Cons. Commission 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class D Exploratory ~ ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is pro ~~@ ^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 P2-11A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 19000 TVp 9060ss 12. Field /Pool(s): Prudhoe Bay Field /Point 4a. Location of Well (Governmental Section): Surtace: 1' FSL 1115' FWL 11 SEC T12N R14E UM 7. Property Designation: ADL 365548 McIntyre Pool , , , . , , Top of Productive Horizon: 1103' FNL, 317' FWL, SEC. 18, T12N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: / March 15, 2006 Total Depth: 4706' FNL, 3760' FWL, SEC. 18, T12N, R15E, UM 9. Acres in Property: 3601 14. Distance to Nearest Property: 4167' 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 681351 - 5998580 Zone- ASP4 10. KB Elevation (Height above GL): 49.8 feet 15. Distance to Nearest Well Within Pool: 1400' 16. Deviated Wells: Kickoff Depth: 15100 feet Maximum Hole Angle: 91 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4250 Surface: 3410 ~ 18. Casin Pr ram: S ications T - Settin De th -B ottom ~uanti of Cemen cf. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# 13Cr / L-8 ST-L 4580' 14420' 8781' 19000' 9060' Slotted; Bonzai w/ 102 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed f or Redrill and Re-entry Operations) Total Depth MD (ft): 15203 Total Depth TVD (ft): 8991 Plugs (measured): None Effective Depth MD (ft): 15157 Effective Depth ND (ft): 8983 Junk (measured): None Casing Len h Size Cement Volume MD TVD Conductor /Structural 78' 20" Driven 118' 118' Surtace 5704' 9-5/8" 1295 sx PF'E', 470 sx Class 'G' 5742' 4970' Intermediate 14618' 7" 90 sx Class 'G' 14654' 8937' i Liner 787' 4-1/2" 120 sx Class 'G' 14412' - 15199' 8827' - 8991' Perforation Depth MD (ft): 14915' - 15140' Perforation Depth TVD (ft): 8966' - 8979' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Barbara Lasley, 564-5126 Printed Name Barb Lastey Title CT Drilling Engineer Prepared By Name/Number. Si nature Phone 564-5126 Date ~ p (, Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: - per'.-- API Number: 50- 029-22923-01-00 Permit Approval Date: jlS~ OG~ See cover letter for other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gash ates or gas contained shales: Samples Req'd: ^ Yes No Mud Log Req'd: ^ Yes ~No _ HZS Measures: es ~"Q ' e n I Survey Req'd: Yes ^ No Other. ~ ~C ~'~ (?jD (~ ~ 'f 'D 4000 `p ~i, , ~ ~,D~ PP D BY THE COMMISSION Date ~ FFF~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~ R ~ ~ ~ N ~ ~ 1,,,~ `„~/ / ~ Submit In Duplicate ~ • by To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Bazbaza M. Lasley, CTD Engineer Date: Februazy 10, 2006 Re: Point McIntyre P2-1 lA CTD Sidetrack Permit to Drill The sidetrack, P2-11A, is scheduled to be drilled by Nordic 2 during the last week of March. The plan calls for a slimhole, extended reach lateral with Banzai completion (solid/cemented contingency) to the Kuparuk reservoir. Pre- Rig Work Summary: Note: Do not put the well back on production after coil cleanouts are made. The well should remain SI until after the 5T is completed. 1. AC-LDS; AC-PPPOT-IC, AC-PPPOT-T. a. Note: All of the previous tests passed 2/11/05, problems are not anticipated. 2. Drift /Clean out tubing with 2.80" mill and motor to the top of the XN at 14427' a. Do not mill out XN. POH b. Pick up a Baker 2-5/8" underreamer with 3.75" blades. c. Underream liner to 15,150' POH. d. Make up a dummy whipstock BHA and run to 15150' MD. 3. Set XN plug in nipple. ff slickline cannot set the plug, set an 1BP just above XN using a-line. 4. MTI'-T, IA, and OA. Do not proceed if the MIT-T or IA fails. Further evaluation work may have to be performed 5. Pull plug. 6. Install accumulator for TRSSSV. 7. Bleed gas lift and production flowlines down to zero and blind flange 8. Remove wellhouse, level pad w(.S to - 401 gp~r~~a~ . Rie Work• o ~14~ 1. MIl2U and test BOPE to 250 psi low an psi high. 2. Mill 2.74" window at 15,100' and 10' of enhole. 3. Swap the well to 9.6 ppg Flo-Pro. 4. Dri113" OH with resistivity at minimum DLS. Target TD is 19,000' MD. 5. Run 2 3/8" 13Cr solid/slotted liner Banzai completion leaving TOL at 14,420' MD. 6. Pump primary cement job for Banzai completion to TOL, 21 bbl of 15.8 ppg expansive liner cement is planned. 7. Cleanout run to mill baffle plate and float. 8. Conduct MCNL/GR/CCL log 9. Test liner lap to 2000 psi. ~' 10. Freeze protect well, RDMO Post-Rig Work 1. Install well house. Hook up flow line. 2. Completion planned for ~ 1000' of slotted liner.- 3. SBHPS post initial cleanup. C7 Mud Program: • Well kill: 9.6 pp nn • Milling/drilling 9.6 pg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • 2 3/8" 13Cr solid liner - 14420'MD to 17000'MD • 2 3/8" L-80 slo 'net - 17000' to 19000' MD • A minimum 21 is 15.8 ppg expansive cement will be used for liner cementing. Casin finer Information OD Grade Wei ht Burst Colla se 9-5/8" L-80 40# 5750 si 3090 si 7" 13Cr 29# 8160 si 7020 si 4-1/2" 13Cr 12.6# 8431 si 7500 si 2-3/8" 13Cr / L-80 4.6 # 11,200 si 11,780 si / 3" O n hole Well Control: • BOP diagram is attached. ~~~ • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to si. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 90.69 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to neazest property - 4167' ft. to the east • Distance to neazest well within pool - 1400' ft to P2-34 injector Logging • MWD directional, Gamma Ray, LWD, and Resistivity will be run over all of the open hole section. • A cased hole GR/CCL/CNL log will be run. Hazards • The maximum recorded H2S level on P2 pad i 4 pm in well p2-60 on 09/21/2004. • Lost circulation risk is low. Reservoir Pressure • Res. press. is estimated to be 4 5 si at 8800'ss (9.3 ppg EMW). Maximum surface pressure wi as (0.10 psi/ft) to surface is 3410 psi. ~ Barbara M. Lasley f/f tilling Engineer 564-5126 CC: Well File Sondra Stewman/Terrie Hubble TREE = 4-1 /16' 5M CHROME W~LHEAD= FMC ACTUATOR = BAKER C KB. ELEV = 49.8' BF. ELEV = KOP = 1381' Max Angle = 91 ~ 14784' Datum MD= 14462' Dstum ND = 8800' SS 9-5/8' CSG, 40#, L-80, D = 8.835' 5741' Minimum ID = 2.75" ~ 14427' 3-1/2" HES XN NIPPLE 7" CSG, 26#, L-80, D = 6.276` 13681 SAFETY NOTES: HORtZOM'AL 1NELL ••CFROMECSG, LNR & TBG•' TRSSSV, HES SERFS 10, ID = 2.81' re c i cr iun~ R ST MD ND DEV TYPE VLV LATCH PORT DATE 1 4262 4061 50 MWK'-5 Flt 2 5838 5024 57 MMG-5 RK 3 8047 6013 64 ATAG-5 RK 4 9874 6824 64 AMIG-5 RK 5 11883 7709 62 AMIG-5 RK 6 13274 8318 64 MuIG-5 RK 7 14330 8790 63 ATAG-5 RK ~ 7' X 4-1/2' BAKER S-3 PKR, D= 3.875' ~ 3-1/2" HES X NP, D = 2.813' I TOP OF 4-1 /2' LNR I I 3-1/2" TBG, 9.2#, 13CR, .0087 bpf, D = 2.992" 7' CSG, 29#, 13CR, D = 6.184' H 14654' PERFORATION SUATAARY R~ LOG:SPERRY LWD ON 10/20/98 A NGLE AT TOP PERF: 89 ~ 14915' Note: Refer to Production DB for historical pert data S¢E SPF MVTERVAL NSgz DATE 2' 6 14915 - 14975 O 04/17/00 2-3/4' 4 15000 - 15088 O 10/25/98 2-1/2' 6 15000-15036 O 11/05/99 2-1 /2' 6 15036 - 15088 O 11/04/99 2' 6 15100 - 15140 O 05/30/00 ~ PBTD ~--i 15157' 4-1/2' LNR, 12.6#, 13CR, .0152 bpf, D = 3.958' 15199' 14427' H 3-1/2" HES XN NP, ID = 2.75" 14438' 3-1/2' WLEG, ID=3.000' 14425' ELAAD TT LOGGED 10/30!99 DATE REV BY OOMtAiBVTS DATE REV BY (X)NNBJTS 10/28/98 ORIGIfW4L COMPLETION 12/21/98 MLL TiGHT00LLARS POST 12/21/98 RIG. (LAST FtIJN 2.805" HALL) 09/15/01 RN/TP CORRECTIONS 10/18/05 WFYPJC PERF CORRECTONS 11/05/05 CANTER WH CORFECTDN P2-11 POM AACf~fiYRE UNIT WELL: P2-11 PERMIT No: ti 981920 API No: 50-029-22923-00 SEC 11 T12N R74E 4147.16 FEL 857.43 FNL BP Exploration (Alaska) TRFF = 4-1 /1 fi' FM C".HRnMF WEILHEAD= CM! ACTUATOR= BAKERC KB. ELEV = 49.8' BF. l1EV = KOP = 1381' Max Angle = 91 ~ 14784' Datum MD= 14462' DatumTVD= 8800'SS 9-5/8' CSG, 40#, L-80, D = 8.835' Minimum ID = 2.75" ~ 14427 3-1 /2" HES XN NIPPLE P 2 -11 A / ~ SAFETY NOTES: FIORQDNTAL WELL Proposed CTD Sidetrack 7' CSG, 26#, L-B0, D = 6.276' I ""t 13662' TOPOF4-1/2' LNR 14419' Top of Cement 14420' TOP OF2-3/8"13cr80LNR 14420' 3-1 /2' TBG, 9.2#, 13CR, 0.0087 bpf , D = 2.992' 14438' T CSG, 29#, 13CR, D = 6.184' 14654' PERFORATDN SUMMARY REF LOG:SPERRY LWD ON 10/20/98 ANGLE AT TOP PERF: 89 ®14915' Note: Refer to Roduction DB for historical pert data SQE SPF fNTERVAL Opn/Sgz DATE 2-1/2' 6 14915 - 14975 O 04/17/00 2-3/4' 4 15000 - 15088 O 10/25/98 2-1/2' 6 15000 - 15036 O 11/05/99 2-1/2' 6 15036 - 15088 O 11/04/99 2-1 /2' 6 15100 - 15140 O 05/30/00 = 3.958' I ~ I TRSSSV, HES SERFS 10, D = 2.81' t;AS I IFT MAtJI~RFI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4262 4061 50 MMG-5 RK 2 5838 5024 57 MMG-5 RK 3 8047 6013 64 MMG-5 RK 4 9874 6824 64 MMG-5 RK 5 11883 7709 62 MMG-5 RK 6 13274 8318 64 MMG-5 RK 7 14330 8790 63 MMG-5 RK 14391' H 7'X4-1 /2' BAKER S-3 PKR, D = 3.875' 14416' 3-1 /2' HES X NP, ID = 2.813' 3-1/2' HES XN NIP, ID = 2.75' 3-1/2' WLEG, ID=3.000' l3MD TT LOGGED 10/30/99 IBOItomOf cement 2-3/8" 13Cr80 cemented/sbtted liner ~6Y00~ 15100' Mechanical Whipstock t QOOO ' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/28/98 ORIGNAL COMPLETION 09/15/01 RN/TP CORRECTDNS 12/21/98 MLL TIGHT COLLARS FOST 12/21/98 RIG. (LAST RLIN 2.805' MLL) 10/30/00 SIS-Isl CONVERT®TOCANVAS 02/21/01 SIS-ND FNAL POINT MCNTY RE UNfT WELL: P2-11 PERMR No: 1981920 API No: 50-029-22923-00 S~ 11 T12N R14E 4147.16 FEL 857.43 FNL BP Exploration (Alaska) ~i%~ by BP Alaska s Baker Hughes INTEQ Planning Report JiNTEQ Company: BP Amoco Date: .2/9/2006 Time: 20:23:17. Page: 1 Field; Point McIntyre Co-ordinate(NE) Reference: WeIL P2-11, True North Site: Pt Mac 2 Vertical ('f VD) Reference: P2-11 49.8 Well: P2-11 Sectios(VS)Refereacec Well,(O.OON,O.OpE,96.34Azi) Weilpsth: PIan7, P2-11A Survey Crtlcahtiou Method: Minimum Curvature 1)b: Orade Field: Point McIntyre North Sbpe UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Pt Mac 2 TR-12-14 UNITED STATES :North Slope Site Position: Northing: 5995140.76 ft Latitude: 70 23 32.530 N From: Map Easting: 674873.98 ft Longitude: 148 34 37.934 W Position Uncertainty: 0.00 ft .North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: P2-11 Slot Name: 11 P2-11 Well Position: +N/-S 3286.65 ft Northing: 5998579.63 ft Latitude: 70 24 4.825 N +E/-W 6555.67 ft Easting : 681350.56 ft Longitude: 148 31 25.868 W Position Uncertainty: 0.00 ft Wellpath: PIan7, P2-11A DrWed From: P2-11 Tie-0n Depth: 15075.14 ft Current Datum: P2-11 Height 49.80 ft Above System Datum: Mean Sea Level Magnetic Data: 2/3/2006 Declination: 24.74 deg Field Strength: 57616 nT Mag Dip Angie: 80.97 deg Vertical Section: Depth From (TVD) +N/-S +FJ-W Direction ft ft ft deg 38.40 0.00 0.00 96.34 Plan: Plan #7 Date Composed: 2/3!2006 Version: 6 Principal: Yes Tied-to: From: Definitive Path Targets Map Map. <-- Latitude -> ~. Longitude -> Name Description TVD +N/~ +E/-W Northing; Fasting' Deg Mlo Sec Deg Min Sec Dip. ' Dir. ft ft ft ft ft P2-11A Polygon 49.80 -993.76 9796.85 5997823.97 691168.02 70 23 54.988 N 148 26 38.883 W -Polygon 1 49.80 -993.76 9796.85 5997823.97 691168.02 70 23 54.988 N 148 26 38.883 W -Polygon 2 49.80 -1202.35 10229.94 5997625.97 691606.02 70 23 52.931 N 148 26 26.204 W -Polygon 3 49.80 153.04 11511.29 5999011.97 692854.02 70 24 6.243 N 148 25 48.609 W -Polygon 4 49.80 352.87 11686.20 5999215.97 693024.02 70 24 8.206 N 148 25 43.475 W -Polygon 5 49.80 187.71 13379.80 5999091.97 694721.02 70 24 6.553 N 148 24 53.863 W -Polygon 6 49.80 844.09 13373.73 5999747.97 694699.02 70 24 13.009 N 148 24 54.007 W -Polygon 7 49.80 911.13 11518.69 5999769.97 692843.02 70 24 13.698 N 148 25 48.358 W -Polygon 8 49.80 250.89 10777.40 5999091.97 692118.02 70 24 7.216 N 148 26 10.106 W P2-11A Fault! 49.80 527.12 9288.58 5999331.98 690623.03 70 24 9.952 N 148 26 53.716 W -Polygon 1 49.80 527.12 9288.58 5999331.98 690623.03 70 24 9.952 N 148 26 53.716 W -Polygon 2 49.80 -413.30 14154.49 5998509.98 695510.03 70 24 0.628 N 148 24 31.200 W P2-11ATarget2 9027.80 358.07 11307.20 5999211.97 692645.03 70 24 8.262 N 148 25 54.579 W P2-11A Target! 9036.80 -109.33 10739.65 5998730.97 692089.03 70 24 3.674 N 148 26 11.227 W P2-11ATarget3 9036.80 584.01 11683.82 5999446.97 693016.03 70 24 10.479 N 148 25 43.534 W P2-11ATarget4 9110.80 560.96 13209.81 5999460.97 694542.04 70 24 10.227 N 148 24 58.825 W Annotation MD TVD ft ft 15075.14 8973.41 TIP 15100.00 8974.46 KOP 15120.00 8975.86 End of 9 Deg/ 100 DLS 15150.00 8977.42 4 15550.00 8998.77 5 15975.00 9026.12 6 16220.00 9032.78 7 ~~ by BP Alaska $ Baker Hughes INTEQ Planning Report iNTEQ Company; BP AmdCO Date: 2!9/2006 Time: 2023:17 Page: 2 FYeld: Point Mclntyns Ce-ordinate(NE) Reference: ` Weil: P2-11, True North Site: Pt Mac 2 Vertfeal (TVD) Reference: P2-1149.8 Well: P2-11 Section (VS) Re[erence: WeN (O.OON;O.OOE,86.34Azi) Wellpath: PIan7, P2-11A Survey Calculation Method: Minimum Curvature Db: OraGe Annotation MD TVD ft ft 16470.00 9029.84 8 16870.00 9025.79 9 16995.00 9025.93 10 17745.00 9048.13 11 18345.00 9077.88 12 19000.00 9109.85 TD Plan Section Information Mt) Intl ' Azim TVD +N/-S +FJ-W DLS Bnihl Tarn- TFO 'Target ft deg deg ft Tt ft deg/100ft deg/100ft deg/t0pft deg 15075.14 89.82 22.12 8973.41 -977.38 10069.17 0.00 0.00 0.00 0.00 15100.00 85.35 18.06 8974.46 -954.06 10077.70 24.28 -1 7.98 -16.33 222.16 15120.00 86.62 19.33 8975.86 -935.16 10084.10 9.00 6.37 6.37 45.00 15150.00 87.40 22.24 8977.42 -907.16 10094.73 10.00 2.60 9.67 75.00 15550.00 86.73 82.28 8998.77 -617.50 10357.88 10.00 -0.17 10.01 92.00 15975.00 86.24 19.70 9026.12 -304.73 10629.76 10.00 -0.12 -10.02 268.00 16220.00 90.69 43.81 9032.78 -98.09 10757.72 10.00 1.82 9.84 80.00 16470.00 90.63 68.81 9029.84 39.47 10964.08 10.00 -0.03 10.00 90.00 16870.00 90.48 28.81 9025.79 297.57 11258.99 10.00 -0.04 -10.00 270.00 16995.00 89.39 41.26 9025.93 399.71 11330.61 10.00 -0.87 9.96 95.00 17745.00 87.72 116.27 9048.13 535.72 12014.45 10.00 -0.22 10.00 92.20 18345.00 87.13 56.21 9077.88 573.16 12585.41 10.00 -0.10 -10.01 268.00 19000.00 87.90 121.77 9109.85 583.93 13204.41 10.00 0.12 10.01 91.00 Survey MD Ioci Az1m Sys TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft degl100ft ft deg 15075.14 89.82 22.12 8923.61 -977.38 10069.17 5997846.96 691439.86 0.00 10115.52 0.00 MWD 15080.00 88.95 21.33 8923.66 -972.86 10070.97 5997851.52 691441.54 24.28 10116.81 222.16 MWD 15100.00 85.35 18.06 8924.66 -954.06 10077.70 5997870.48 691447.82 24.28 10121.42 222.16 MWD 15120.00 86.62 19.33 8926.06 -935.16 10084.10 5997889.52 691453.75 9.00 10125.69 45.00 MWD 15150.00 87.40 22.24 8927.62 -907.16 10094.73 5997917.78 691463.70 10.00 10133.17 75.00 MWD 15200.00 87.24 27.24 8929.96 -861.81 10115.62 5997963.61 691483.48 10.00 10148.92 92.00 MWD 15250.00 87.10 32.24 8932.43 -818.46 10140.39 5998007.55 691507.19 10.00 10168.75 91.77 MWD 15300.00 86.98 37.25 8935.02 -777.45 10168.84 5998049.24 691534.63 10.00 10192.50 91.52 MWD 15350.00 86.88 42.25 8937.70 -739.07 10200.75 5998088.37 691565.60 10.00 10219.98 91.26 MWD 15400.00 86.80 47.26 8940.46 -703.63 10235.89 5998124.65 691599.87 10.00 10250.99 90.99 MWD 15450.00 86.75 52.27 8943.27 -671.40 10273.99 5998157.80 691637.17 10.00 10285.30 90.71 MWD 15500.00 86.73 57.28 8946.11 -642.61 10314.75 5998187.57 691677.22 10.00 10322.63 90.43 MWD 15550.00 86.73 62.28 8948.97 X17.50 10357.88 5998213.72 691719.72 10.00 10362.72 90.15 MWD 15600.00 86.56 57.28 8951.90 -592.38 10400.99 5998239.87 691762.21 10.00 10402.80 268.00 MWD 15650.00 86.43 52.27 8954.96 -563.61 10441.75 5998269.63 691802.26 10.00 10440.13 268.29 MWD 15700.00 86.32 47.26 8958.12 -531.39 10479.83 5998302.76 691839.54 10.00 10474.42 268.60 MWD 15750.00 86.24 42.25 8961.37 -495.97 10514.95 5998339.02 691873.79 10.00 10505.41 268.92 MWD 15800.00 86.19 37.24 8964.67 X57.62 10546.84 5998378.12 691904.74 10.00 10532.87 269.24 MWD 15850.00 86.17 32.23 8968.00 -416.64 10575.26 5998419.78 691932.15 10.00 10556.59 269.57 MWD 15900.00 86.17 27.22 8971.35 -373.33 10599.99 5998463.68 691955.82 10.00 10576.39 269.91 MWD 15950.00 86.21 22.21 8974.67 -328.02 10620.84 5998509.47 691975.56 10.00 10592.11 270.24 MWD 15975.00 86.24 19.70 8976.32 -304.73 10629.76 5998532.98 691983.92 10.00 10598.40 270.58 MWD 16000.00 86.67 22.17 8977.87 -281.42 10638.68 5998556.49 691992.26 10.00 10604.69 80.00 MWD 16050.00 87.57 27.10 8980.38 -236.05 10659.48 5998602.35 692011.96 10.00 10620.36 79.85 MWD 16100.00 88.48 32.01 8982.11 -192.59 10684.12 5998646.39 692035.54 10.00 10640.05 79.60 MWD 16150.00 89.40 36.93 8983.03 -151.39 10712.41 5998688.26 692062.82 10.00 10663.61 79.43 MWD 16200.00 90.32 41.84 8983.16 -112.76 10744.13 5998727.65 692093.59 10.00 10690.87 79.34 MWD 16220.00 90.69 43.81 8982.98 -98.09 10757.72 5998742.64 692106.82 10.00 10702.76 79.33 MWD 16250.00 90.69 46.81 8982.61 -77.00 10779.05 5998764.24 692127.62 10.00 10721.63 90.00 MWD 16300.00 90.69 51.81 8982.01 X4.41 10816.94 5998797.74 692164.72 10.00 10755.69 90.04 MWD 16350.00 90.68 56.81 8981.41 -15.26 10857.54 5998827.87 692204.59 10.00 10792.82 90.10 MWD 16400.00 90.66 61.81 8980.83 10.25 10900.52 5998854.42 692246.93 10.00 10832.72 90.16 MWD 16450.00 90.64 66.81 8980.26 31.92 10945.56 5998877.17 692291.43 10.00 10875.09 90.21 MWD 16470.00 90.63 68.81 8980.04 39.47 10964.08 5998885.17 692309.76 10.00 10892.66 90.27 MWD 1~ ~~~ by BP Alaska S Baker Hughes INTEQ Planning Report iNTEQ Company: BP Amoco Date: 2!9!2006 Time: 20:23:17 Pagr. 3 Field: Point McIntyre Co-0rdlaate(NE) Reference: Weli: P2- 11, True NoRh Site: Pt Mac 2 Vertlcal ('f VD) References P2-11 49.8 We11: P2-11 SeMlon (VS) Reference: -Well (O.OON,O.OOE96.34Azi) Wellpatb: PIan7, P2-1 1A Survey Calculatlou Metbodz Minimum Curvature Db: Orade Survey MD Iucl Azim Sys TVD `N/S EIW MapN MapE DLS VS ' TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 16500.00 90.63 65.81 8979.71 51.04 10991.75 5998897.40 692337.14 10.00 10918.89 270.00 MWD 16550.00 90.62 60.81 8979.16 73.49 11036.41 5998920.93 692381.24 10.00 10960.79 269.97 MWD 16600.00 90.61 55.81 8978.62 99.75 11078.93 5998948.21 692423.12 10.00 11000.16 269.91 MWD 16650.00 90.60 50.81 8978.10 129.61 11119.01 5998979.03 692462.46 10.00 11036.70 269.86 MWD 16700.00 90.58 45.81 8977.58 162.86 11156.34 5999013.17 692498.96 10.00 11070.12 269.81 MWD 16750.00 90.56 40.81 8977.09 199.22 11190.62 5999050.36 692532.35 10.00 11100.18 269.75 MWD 16800.00 90.53 35.81 8976.61 238.44 11221.61 5999090.32 692562.37 10.00 11126.64 269.70 MWD 16850.00 90.50 30.81 8976.16 280.22 11249.05 5999132.74 692588.79 10.00 11149.31 269.66 MWD 16870.00 90.48 28.81 8975.99 297.57 11258.99 5999150.33 692598.31 10.00 11157.28 269.61 MWD 16900.00 90.22 31.80 8975.81 323.47 11274.13 5999176.58 692612.81 10.00 11169.46 95.00 MWD 16950.00 89.78 36.78 8975.81 364.76 11302.29 5999218.55 692639.96 10.00 11192.89 95.02 MWD 16995.00 89.39 41.26 8976.13 399.71 11330.61 5999254.17 692667.42 10.00 11217.18 95.02 MWD 17000.00 89.37 41.76 8976.19 403.46 11333.93 5999258.00 692670.65 10.00 11220.06 92.20 MWD 17050.00 89.18 46.76 8976.82 439.25 11368.81 5999294.63 692704.65 10.00 11250.77 92.19 MWD 17100.00 89.00 51.76 8977.61 471.87 11406.67 5999328.15 692741.71 10.00 11284.80 92.13 MWD 17150.00 88.82 56.75 8978.56 501.07 11447.23 5999358.32 692781.54 10.00 11321.89 92.05 MWD 17200.00 88.66 61.75 8979.66 526.62 11490.18 5999384.90 692823.86 10.00 11361.75 91.96 MWD 17250.00 88.50 66.75 8980.90 548.32 11535.19 5999407.69 692868.32 10.00 11404.09 91.85 MWD 17300.00 88.36 71.75 8982.27 566.03 11581.91 5999426.52 692914.60 10.00 11448.57 91.72 MWD 17350.00 88.23 76.75 8983.76 579.59 11630.00 5999441.25 692962.34 10.00 11494.87 91.59 MWD 17400.00 88.11 81.75 8985.36 588.90 11679.08 5999451.75 693011.18 10.00 11542.62 91.44 MWD 17450.00 88.00 86.75 8987.06 593.91 11728.78 5999457.96 693060.74 10.00 11591.47 91.28 MWD 17500.00 87.91 91.76 8988.84 594.56 11778.73 5999459.82 693110.66 10.00 11641.04 91.11 MWD 17550.00 87.84 96.76 8990.70 590.85 11828.54 5999457.32 693160.54 10.00 11690.96 90.93 MWD 17600.00 87.78 101.76 8992.60 582.81 11877.84 5999450.48 693210.01 10.00 11740.84 90.74 MWD 17650.00 87.75 106.77 8994.56 570.50 11926.25 5999439.36 693258.70 10.00 11790.31 90.55 MWD 17700.00 87.72 111.77 8996.53 554.02 11973.40 5999424.03 693306.23 10.00 11838.99 90.36 MWD 17745.00 87.72 116.27 8998.33 535.72 12014.45 5999406.73 693347.72 10.00 11881.82 90.16 MWD 17750.00 87.70 115.77 8998.53 533.53 12018.94 5999404.65 693352.26 10.00 11886.52 268.00 MWD 17800.00 87.54 110.77 9000.60 513.80 12064.82 5999386.04 693398,60 10.00 11934.30 268.02 MWD 17850.00 87.39 105.77 9002.82 498.14 12112.24 5999371.54 693446.38 10.00 11983.15 268.23 MWD 17900.00 87.27 100.77 9005.15 486.69 12160.84 5999361.26 693495.24 10.00 12032.72 268.45 MWD 17950.00 87.16 95.76 9007.58 479.51 12210.24 5999355.29 693544.80 10.00 12082.61 268.68 MWD 18000.00 87.08 90.75 9010.10 476.67 12260.08 5999353.66 693594.69 10.00 12132.46 268.93 MWD 18050.00 87.02 85.75 9012.67 478.20 12309.98 5999356.40 693644.53 10.00 12181.88 269.18 MWD 18100.00 86.98 80.74 9015.29 484.07 12359.55 5999363.47 693693.94 10.00 12230.50 269.44 MWD 18150.00 86.97 75.73 9017.93 494.24 12408.41 5999374.82 693742.54 10.00 12277.95 269.70 MWD 18200.00 86.97 70.73 9020.58 508.64 12456.20 5999390.38 693789.97 10.00 12323.85 269.96 MWD 18250.00 87.01 65.72 9023.21 527.16 12502.56 5999410.02 693835.86 10.00 12367.88 270.23 MWD 18300.00 87.06 60.71 9025.80 549.65 12547.12 5999433.58 693879.86 10.00 12409.69 270.49 MWD 18345.00 87.13 56.21 9028.08 573.16 12585.41 5999458.00 693917.57 10.00 12445.15 270.75 MWD 18350.00 87.12 56.71 9028.33 575.91 12589.58 5999460.86 693921.66 10.00 12448.98 91.00 MWD 18400.00 87.04 61.72 9030.88 601.47 12632.46 5999487.45 693963.91 10.00 12488.78 90.97 MWD 18450.00 86.99 66.72 9033.48 623.18 12677.41 5999510.24 694008.31 10.00 12531.06 90.72 MWD 18500.00 86.96 71.73 9036.12 640.88 12724.08 5999529.07 694054.54 10.00 12575.49 90.46 MWD 18550.00 86.96 76.74 9038.77 654.44 12772.11 5999543.79 694102.23 10.00 12621.73 90.20 MWD 18600.00 86.98 81.74 9041.42 663.76 12821.15 5999554.30 694151.02 10.00 12669.44 89.93 MWD 18650.00 87.02 . 86.75 9044.04 668.77 12870.81 5999560.51 694200.54 10.00 12718.25 89.66 MWD 18700.00 87.08 91.76 9046.61 669.42 12920.73 5999562.37 694250.42 10.00 12767.78 89.40 MWD 18750.00 87.17 96.76 9049.12 665.71 12970.51 5999559.87 694300.28 10.00 12817.67 89.14 MWD 18800.00 87.27 101.77 9051.55 657.67 13019.78 5999553.03 694349.73 10.00 12867.53 88.89 MWD 18850.00 87.40 106.77 9053.87 645.37 13068.17 5999541.91 694398.40 10.00 12916.98 88.65 MWD 18900.00 87.55 111.77 9056.07 628.89 13115.31 5999526.57 694445.92 10.00 12965.65 88.42 MWD 18950.00 87.72 116.77 9058.14 608.35 13160.84 5999507.16 694491.93 10.00 13013.17 88.20 MWD 19000.00 X87.90 121.77 9060.05 583.93 13204.41 5999483.80 694536.08 10.00 13059.17 87.99 3.50" s • ___ _:::-r~::::. - ~ I q~ e e d o -~- -.- --:::::i::-::-::: S - ---1--'J ~_~ j4A ~1g~2~ 3i d~ ___._ ._-_ -. _ '~ --_ _. - -:y'::::.. eel! ~......- -- --- ---_ j---'.-r _.. 1 .._ ~..r - i:.:.:..~~: ~ ::: - --~-- -- :. 3 ~ e ~ i ~ - [W I+WwwA•WM.~ ~i i ~ -- ~ ~ ~~ffff 9x~d~~~~6xi~# . s ceaeaa ~ e~@r®~ t ~ l~~FC~ii~~9~i ~ S ~ :% ~ ~ ? g ea~sss N c'Q ~ ' -~ ~ ! ~ E ~ s~~$ j s'3 t~~s~ 3 CRRRRRRi ~ i ~ ~~~~~~~~~'~.~ ~ ~~~~ '<_3:: 4 tecce~ Q . ~ ~ t 8f ! ~ , s~R 5RR•q I ~ ~ 6~tlii#~"i1d6i a m ' ~~ ~~ ~ ~ ~~~ ~ ~~ii~~i~~i~i ~ ; ~ ' s~~ ~ a3g~~d~~:l~: ~ ~~c i ~~~~~oe ~ ~ s44~ i l S 2 ~~5~16~~~~~ ~ ~~~65' i 8 i 9 t! I E ''"'. 8 1~ • TERRIE L RUBBLE BP EXPLORATION AK INC PO BOX 1.96612 MB 7-5 "Mastercard Check" ANCHORAGE, AK 99519=8612. PAY TO THE 1L ~ /1 /1 A /~_ ~ n J ORDERDF ~~~..000~~`VVV...fff~~~ -P7T ~ if L l ss-si,z52 255 DATE ~ I ~.~~ t ~, First NationaP Bank Alaska Anchorage, AK 99501 MEMO 2~ '= 1 25 200060;99 L4..i6 2 27~~~ L 556~~• 0 255 • ~ TRANSMITTAL LETTER CHECKLIST WELL NAME PTD# 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 /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are ftrst 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 welly until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~Compan~Zmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\j ody\transmittal_checkl ist • ~'1 ~J ^^ a ~ , Q ~ ~~ ~, ~ ~ ~ I ~ ~ ~ ~ o t ~ ~ ~ O ~ : O ~ ~ , , ~ , ~ ;~ , ~ , ~ . , a ~ ~ ~ •y, a , ,~ D o ~ ~ , ~ '~ ~, ; a ~ , of . , a a m m C7 ~ ~ °~~ o v c'~ ~ , ~ I ~ '~ Z i ~ ~ ~. j , , ~ ~ ~ ~, o. , a ~ ~~ ~ ~ ~ ~ ~ ~ yr, o ~ Q, ~ ~ ~ ~~ x, ~ ~ a m d ~~ QI ~ ~ ~ ~ ~ ~ cn v' . ' ur ~' F-' i y' N tl) y' y~ y' N N N N UY UY (/h y~ y~ y~ y N N, N: N d, N N tlf ~ ~ ~ N, Q, Q, Q, Q, ~ ~ ~ Q, Q, Q, Q, O, tl} N, y~ y' N. N, f/b ~ y~ y. y' y: tlA N. Q, N. N, N, N: N. VA N. Q. ~ ' ~ d , ~'' , , , , ~'' >'' >"' ~'' , , , : ~'' >'' ~' >"' >'' }' }' }' 2, Z, Z, Z, Z, Z, Z Z, 2, ~' ~'' ~' ~'~ Z, ~' ~~ ~' >"' ~'~ ~"~ Z, Z. Z, ' Z, Z `V may-. ~~ ~ d. y. E. 3. , i - ~ ~ , ~ ~ ; ~ • ~ Z, ~~,. y. ,. _ ~ m V. w ~ ~ ~ C' l6' LO' O, Z , d ~ ~ ~ I ~ a N. N ~: N. ~ ~, i a, ~ _ a~ y ~: , ` ~ ~ o: o y o y G x Z ~ c' O, ~ ~ ~~ O o d c, v C w ~ ~, N: d f0: m. o ~. C ~~ .6, ~' N' ~. y: a~ ~ ~~ ~ ~ ay d T ', a' a O 'O tlY Of ~' ~ G N ~ ~ N' ~ ~" a. 00~ N 4_.~ t6 G7~ N ~ ~ O' ~ V . N C N ) ~ ~ ~ ~ 3 C G ~. 3 ~ ~ O ~ . 4 _ y U ~ N • Q , - C, N ~ O~ •~ p~• ~, ~~ ~ ~~ a~ - N, ~ ~ y~ y Q ~ ~ , c _ N O ~ N y c ~. >~ ~ N ~, ~ ; ~ ' ~, $. ~ a O rn t ' o23, ~ ' a. 4 N ~ ~ O, M 7 ' 'n y' Q~ 4 , N' vyi N' , m w Z = 'p L of ~ Z O C .O. ~ O N' .c~. m a, N: N. O; a, c tq _ ~~ O~ C, y CO, c ~ O, ~ O O~ p, - N a N C C ~ N C O) ~ .. Q1 O ~ ~~ _ E -, '00, C. C: ~ ~: f~ ~~ O fy6, C C, f~/1, ~~ 7 ~' ~,. ~ ~ ~T ~~ .0..~ ~_, C~ ~ N, •.~.+~ OI ~ N L y d C O • ~ sl ~ ~ ~ ~: ~~ a V -O~ ~~ ~~ N, y p 0~ T ~~ ~, C : (~, d ~ C ~' V' O~ w~ a~ ' I ~' 3' ~' ' j' ( 6' ~' y N M N V~ ' Q ~, O ~ C ~ C C T ~ ~ a O O, V. N ly, C, C N C ~„ a, Y f0 ~~ ~~ O, y f6~ Z O' ~6 N ~p Q~ • 3' N O- ' ~ ~ y ' G t O l0 CI O' 3' ' Qy O N ~ E a - l ~ 4 ' N ' , O i , ' w 4 ~ ~ ~ + 7 ' m •- a~ ~ c O N ' • ~ °' 3 a Q. c , °:, m c m' :° c .o s ~ ~ ~ ~, :° ~ d d a m. m ~, ' a. .N m' , a: ~ a y ~? ' 3 ~: m' : o: ~ o ~ ,~ o ayi ~' ~ •°-~' y d 3 y' o 0 ~ 3 c °= - f6 ~ °, c o w o Zi o (]~ •Q a c ~ o. o ~. 'a. ~ •~, o, a ~ 3 3 'v > o' a~~ d a. a m ~: ~, .., ~ a m' ~ a a , .> •~ ~ o' o ~ a o c ~' ~ c o' , p , d o o d a ~' y a` ~' ~ m' E' ~ . ~' °~ o; , aai' o d ~ 2' ~' ~' c U d i ~! ~' f6 N, . y f0 ~~ ~j~ N, N O, 7 p d' ~ d C' Y. d ~ a ~ ~ ..,, 0' ~ Zj l N .«. ~ C y. O . O ~.; ~~ L' p N, ~ d d N N, d ~ y~ .~ d y~ tll el N. v- d ~~ r O ::. .p-ry - f0 Cl O: (0 t6 t0' N O) t6' ` N; C U CI~ 3 O ~ ~ ~ - a Z y: G ~ O d ° • v. =° m ~ o d ~ o, ~ 3 m' ~ y, N d m c a~ 3 5 , c. ~ ~, ~ ~ a~ ~ y c m y ~ _ ~ ~ a ~ o ~ o ~ ~ . ~ c ~ o' a 4: ~', v Gr O - a ~~~ LL ~ - m. , a~ c .Q - a a, ~ y x m' a~ -o u •- c' m ~ ~ c° •p ~ ~ a r a~ :o • c a y 'y: ~ ~ >: ~ .N N yp t d t 3 ~ ti o vi ~ o ' o °~ m ' c~ c c c' ° ' c~a - ' , ~ E m :?, u: ia ~ :?, o L, c c ~ a?, 3 ~ c , E ' m m' o ~ ' a~ a _ :: ~ a ~ ~ . ~, , :; ` ~ o. • : m, ~i m o c: F, W i ' , g, c c~ v ~, , ~ ~ ~ o o % LL y v ~ o, e 2'i o o ' 3 ~ ' m v ~ m ~ m a y 3 ~ c o ~ d ~ a, • •~, cn ai ~ . o ~ o; o _ o ~ ~ ~ ~ :~ ~ € ' a o -y d a ~ ~; c > > `~° I- ~ F- ~ ~ y ~ y ~ w w, Y a a o ~ L € E ~ m uj J ~ ~ ~ d' m ~ m d, ~ d c y. 3 y. c. , y, ar ~ . L , : a~, ~ d ~ ' ~ d, a~i, o. p w Q ~ *- a~ M N O N f0 ~ t~ GO ~ M V ~ (O r' a0 O~ O N r N N N M N I ~fl N N CO h a0 O O N M M M N N N N M ~f M M ~ M (O M t~ 00 M M O M V C~ _ _ CD - - _ _ (O (O O f0 W C O ~ ' R Q N ~ I ~ C R N ~ ~ t0 N Q~ .~ O O h O ~ ~o N • N ~ N ~ ' o y m m U E J N ~ C •~ ~ V C Q Q ~ p, C..) U w ~ a a a ~ ~w a~ ~ a~ • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 07/05/08 BHI Ol LIS Customer Format Tape **** TAPE HEADER **** MWD 06/04/15 1108858 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: WRAP. NO: Well Informa tion Block #MNEM.UNIT Data Type STRT.FT 15087.0000: STOP.FT 17640.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD FIELD: LOC LOCATION: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. P2-11A Point McIntyre 70 deg 24' 4.825"N 148 deg 31' 25.868"W 1'FSL, 1115'FWL CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 15-APR-06 API API NUMBER: 50029229230100 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 11 TOWN.N 12N RANG. 14E PDAT. MSL EPD .F 0 LMF RKB FAPD.F 49.8 DMF KB EKB .F 49.8 EDF .F N/A EGL .F 11.4 CASE.F N/A OS1 DIRECTIONAL ~ ~C~~v-`~~o ~ l S/a Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor and a Rib Steering Motor with a Near bit Inclination Sensor. (6) Data presented here is final and has not been adjusted to a PDC (Primary Depth Control) log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The side track was drilled from through a milled window in 7" liner. Top of Window 15079.8 ft.MD (8923.6 ft.SSTVD) Bottom of Window 15087.6 ft.MD {8923.9 ft.SSTVD) (8) The interval from 17616 ft.MD to 17640 ft.MD (9063.9 ft to 9071.4 ft.SSTVD) was not logged due to bit to sensor offset. (9) Tied to P2-A at 15075.14 ft.MD (8923.61 ft.SSTVD) (10) This wellbore P2-11A was kicked off the plugback wellbore P2-11APB1 at 15887.0 ft.MD (8970.6 ft.55TVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROP5 -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 69 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN P2-11A 5.xtf LCC 150 CN BP Exploration {Alaska) Inc. WN P2-11A, FN Point McIntyre COUN North Slope Borough STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and .has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP U GR GR GRAX 0.0 ROP ROP ROPS 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Lenqth 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 172 Tape File Start Depth = 14546.500000 Tape File End Depth = 17640.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 185 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN P2-11A.xtf LCC 150 CN BP Exploration (Alaska) WN P2-11A, FN Point McIntyre COUN North Slope Boro STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0.0 ROPS ROPS ROP 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GRAX MwD 68 1 AAPI 2 ROPS MWD 68 1 F/HR 3 RACL MWD 68 1 OHMM 4 RACH MWD 68 1 OHMM 5 RPCL MWD 68 1 OHMM 6 RPCH MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 344 Tape File Start Depth = 14547.000000 Tape File End Depth = 17640.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 357 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 06/04/15 1108858 01 **** REEL TRAILER **** MWD 07/05/08 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 14546.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14547.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14600.0000 158.6400 282.7200 -999.2500 -999.2500 -999.2500 -999.2500 14700.0000 100.6500 295.5200 -999.2500 -999.2500 -999.2500 -999.2500 14800.0000 26.1600 286.5900 -999.2500 -999.2500 -999.2500 -999.2500 14900.0000 35.4000 295.4400 -999.2500 -999.2500 -999.2500 -999.2500 15000.0000 172.4600 286.7500 -999.2500 -999.2500 -999.2500 -999.2500 15100.0000 172.4600 290.5000 3.1300 3.6700 4.1400 3.8500 15200.0000 42.6500 284.5600 15.2600 15.2600 16.8100 16.8800 15300.0000 37.2600 296,6300 18.9500 17.5000 17.4200 16.2700 15400.0000 34.0500 304.1000 27.4300 22.8100 20.7400 17.5200 15500.0000 40.5200 295.1500 31.3500 24.7100 22.8000 19.4100 15600.0000 34.2200 288.0900 51.3800 50.7800 27.1900 23.1900 15700.0000 41.1300 292.4300 44.8700 35.3300 30.9700 25.7100 15800.0000 23.2600 293.8300 57.5600 43.9500 43.3700 40.7600 15900.0000 41.8100 299.2400 41.4600 38.7300 31.5000 26.6500 16000.0000 39.9500 293.4400 36.9400 30.6400 30.4500 28.2200 16100.0000 37.5900 297.5700 31.3500 28.2900 24.8400 22.8600 16200.0000 44.7800 296.3100 26.8900 21.1400 19.9500 17.5200 16300.0000 48.2700 294.0800 23.6500 19.5600 17.5500 15.5800 16400.0000 39.2800 294.3500 11.5700 10.7600 11.8500 13.3700 16500.0000 38.6100 289.8600 24.4800 21,6100 16600.0000 28,0400 289.4700 103.9000 112.4700 16700.0000 33.5500 293.8700 56.4400 58.1100 16800.0000 38.7700 289.0700 30.6000 29.9300 16900.0000 39.1100 287.3400 31.5100 33.0600 17000.0000 40.7100 292.4600 30.2000 31.4100 17100.0000 43.1600 292.1900 24.1200 25.7100 17200.0000 43.1600 292.6200 23.7800 25.7100 17300.0000 49.8500 289.7900 22.3000 24.3700 17400.0000 117.0000 287.5900 12.7000 14.1500 17500.0000 43.2500 282.8900 19..9500 22.5400 17600.0000 51.5900 278.7300 7.0200 7.1300 17640.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 14546.500000 Tape File End Depth = 17640.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 34.8300 57.2900 37.3500 25.9900 22.7800 21.7600 17.5100 16.7700 15.8100 9.2800 14.0800 7.0400 -999.2500 30.9500 70.0100 46.8800 33.2300 28.2000 26.8800 21.5700 21.0500 19.1000 12.5200 17.0800 6.8600 -999.2500 • Tape Subfile 3 is type: LIS DEPTH GRAX ROPS RACL RACH RPCL RPCH 14547.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14547.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14600.0000 158.6400 282.7200 -999.2500 -999.2500 -999.2500 -999.2500 14700.0000 100.6500 295.5200 -999.2500 -999.2500 -999.2500 -999.2500 14800.0000 26.1600 286.5900 -999.2500 -999,2500 -999.2500 -999.2500 14900.0000 35.4000 295.4400 -999.2500 -999.2500 -999.2500 -999.2500 15000.0000 172.4600 286.7500 -999.2500 -999.2500 -999.2500 -999.2500 15100.0000 172.4600 290.5000 3.1300 3.6700 4.1400 3.8500 15200.0000 42.6500 284.5600 15.2600 15.2600 16.8100 16.8800 15300.0000 37.2600 296.6300 18.9500 17.5000 17.4200 16.2700 15400.0000 34.0500 304.1000 27.4300 22.8100 20.7400 17.5200 15500.0000 40.5200 295.1500 31.3500 24.7100 22.8000 19.4100 15600.0000 34.2200 288.0900 51.3800 50.7800 27.1900 23.1900 15700.0000 41.1300 292.4300 44.8700 35.3300 30.9700 25.7100 15800.0000 23.2600 293.8300 57.5600 43.9500 43.3700 40.7600 15900.0000 41.8100 299.2400 41.4600 38.7300 31.5000 26.6500 16000.0000 39.9500 293.4400 36.9400 30.6400 30.4500 28.2200 16100.0000 37.5900 297.5700 31.3500 28.2900 24.8400 22.8600 16200.0000 44.7800 296.3100 26.8900 21.1400 19.9500 17.5200 16300.0000 48.2700 294.0800 23.6500 19.5600 17.5500 15.5800 16400.0000 39.2800 294.3500 11.5700 10.7600 11.8500 13.3700 16500.0000 38.6100 289.8600 24.4800 21.6100 16600.0000 28.0400 289.4700 103.9000 112.4700 16700.0000 33.5500 293.8700 56.4400 58.1100 16800.0000 38.7700 289.0700 30.6000 29.9300 16900.0000 39.1100 287.3400 31.5100 33.0600 17000.0000 40.7100 292.4600 30.2000 31.4100 17100.0000 43.1600 292.1900 24.1200 25.7100 17200.0000 43.1600 292.6200 23.7800 25.7100 17300.0000 49.8500 289.7900 22.3000 24.3700 17400.0000 117.0000 287.5900 12.7000 14.1500 17500.0000 43.2500 282.8900 19.9500 22.5400 17600.0000 51.5900 278.7300 7.0200 7.1300 17640.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 14547.000000 Tape File End Depth = 17640.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 34.8300 57.2900 37.3500 25.9900 22.7800 21.7600 17.5100 16.7700 15.8100 9.2800 14.0800 7.0400 -999.2500 30.9500 70.0100 46.8800 33.2300 28.2000 26.8800 21.5700 21.0500 19.1000 12.5200 17.0800 6.8600 -999.2500 • Tape Subfile 4 is type: LIS • **** REEL HEADER **** MWD 07/05/07 BHI 01 LI5 Customer Format Tape **** TAPE HEADER **** MWD 06/04/05 1108858 O1 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: WRAP. NO: Well Informa tion Block #MNEM.UNIT Data Type STRT.FT 15087.0000: STOP.FT 16450.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD FIELD: LOC LOCATION: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. P2-11APB1 Point McIntyre 70 deg 24' 4.825"N 148 deg 31' 25.868"W 1'FSL, 1115'FWL CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 05-APR-06 API API NUMBER: 50029229230700 Parameter Information Block #MNEM.UNIT Value Description ----------------- SECT. -------------- 11 Section TOWN.N 12N Township RANG. 14E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 49.8 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 49.8 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 11.4 Elevation of Ground Level CASE.F N/A Casinq Depth OS1 DIRECTIONAL Other Services Line 1 ~o~ ~oa ~ ~ ~~raa • Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor and a Rib Steering Motor with a Near bit Inclination Sensor. (6) Data presented here is final and has not been adjusted to a PDC (Primary Depth Control) log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The side track was drilled from through a milled window in 7" liner. Top of Window 15079.8 ft.MD (8923.6 ft.SSTVD) Bottom of Window 15087.6 ft.MD (8923.9 ft.SSTVD) (8) The interval from 16428.0 ft.MD to 16450.0 ft.MD (8986.4 ft to 8986.1 ft.SSTVD) was not logged due to bit to sensor offset. (9) Tied to P2-A at 15075.14 ft.MD (8923.61 ft.SSTVD) (10) The wellbore P2-11A was kicked off this plugback wellbore P2-11APB1 at 15887.0 ft.MD (8970.6 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape 5ubfile: 1 69 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN P2-11APB1 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN P2-11APB1, FN Point McIntyre COUN North Slope Borough STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPS 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 78 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 2 91 Minimum record length: 54 Maximum record length: 4124 **** FILE HEADER **** MWD .002 15054.000000 16450.000000 0.500000 feet records... bytes bytes 1024 • • *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN P2-11APB1.xtf LCC 150 CN BP Exploration (Alaska) VJN P2-11APB1, FN Point McIntyre COUN North Slope Boro STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0.0 ROPS ROPS ROPS 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 AAPI 2 ROPS MGTD 68 1 F/HR 3 RACL MWD 68 1 OHMM 4 RACH MWD 68 1 OHMM 5 RPCL MWD 68 1 OHMM 6 RPCH MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 156 Tape File Start Depth = 15054.000000 Tape File End Depth = 16450.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • **** FILE TRAILER **** Tape Subfile: 3 169 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MR7D 06/04/05 1108858 01 **** REEL TRAILER **** MWD 07/05/07 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132. bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR ROP RPD RPS 15054.0000 -999.2500 -999.2500 -999.2500 -999.2500 15054.5000 -999.2500 -999.2500 -999.2500 -999.2500 15100.0000 172.4600 290.5000 4.1400 3.8500 15200.0000 42.6500 284.5600 16.8100 16.8800 15300.0000 37.2600 296.6300 17.4200 16.2700 15400.0000 34.0500 304.1000 20.7400 17.5200 15500.0000 40.5200 295.1500 22.8000 19.4100 15600.0000 34.2200 288.0900 27.1900 23.1900 15700.0000 41.1300 292.4300 30.9700 25.7100 15800.0000 23.2600 293.8300 43.3700 40.7600 15900.0000 61.3800 54.6000 48.0100 52.1000 16000.0000 58.9300 61.8000 49.9767 56.4900 16100.0000 58.7950 50.8000 47.2400 50.8000 16200.0000 49.9875 48.5000 51.6100 60.4700 16300.0000 57.8800 65.4000 45.5400 54.5400 16400.0000 177.8000 61.8000 13.5000 14.5200 16450.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 15054.000000 Tape File End Depth = 16450.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • RAD -999.2500 -999.2500 3.1300 15.2600 18.9500 27.4300 31.3500 51.3800 44.8700 57.5600 28.5000 29.2633 32.9800 27.1300 23.1700 10.9400 -999.2500 RAS -999.2500 -999.2500 3.6700 15.2600 17.5000 22.8100 24.7100 50.7800 35.3300 43.9500 41.1300 35.1267 34.5600 37.7100 35.5500 12.2300 -999.2500 • Tape Subfile 3 is type; LIS DEPTH GRAX ROPS RPCL RPCH 15054.0000 -999.2500 -999.2500 -999.2500 -999.2500 15054.2500 -999.2500 -999.2500 -999.2500 -999.2500 15100.0000 267.4800 -999.2500 -999.2500 -999.2500 15200.0000 58.1400 11972.2988 19.6000 21.5500 15300.0000 57.6150 63.7000 22.2800 23.9500 15400.0000 49.5950 46.4000 26.2100 26.4100 15500.0000 62.8700 55.5000 28.6900 28.5500 15600.0000 61.0300 76.2000 40.1000 43.0200 15700.0000 62.8700 72.1000 40.6600 50.4400 15800.0000 38.9400 70.1000 49.7450 55.3150 15900.0000 61.3800 54.6000 48.0100 52.1000 16000.0000 58.9300 61.8000 49.9767 56.4900 16100.0000 58.7950 50.8000 47.2400 50.8000 16200.0000 49.9875 98.5000 51.6100 60.4700 16300.0000 57.8800 65.4000 45.5400 54.5400 16400.0000 177.8000 61.8000 13.5000 14.5200 16450.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 15054.000000 Tape File End Depth = 16450.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet i RACL -999.2500 -999.2500 -999.2500 14.5600 16.3300 19.9500 22.7700 25.0300 33.4000 29.2450 28.5000 29.2633 32.9800 27,1300 23.1700 10.9400 -999.2500 RACH -999.2500 -999.2500 -999.2500 15.2950 18.5600 23.1900 27.2000 31.9600 39.2900 45.8700 41.1300 35.1267 34.5600 37.7100 35.5500 12.2300 -999.2500 ~ i Tape Subfile 4 is type: LIS
