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206-039
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU C-22A Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 206-039 50-029-20758-01-00 11450 Conductor Surface Intermediate Liner Liner 8994 80 2638 8552 888 2341 11180 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 8998 30 - 110 29 - 2667 28 - 8579 8402 - 9290 9107 - 11448 29 - 109 29 - 2667 28 - 7751 7603 - 8401 8226 - 8994 11364 2670 4760 5410 7500 11180 5380 6870 7240 8430 10033 - 11350 4-1/2" 12.6# 13Cr80 26 - 9116 8993 - 8996 Structural 4-1/2" Baker S3 Packer 9059 8181 Torin Roschinger Operations Manager Finn Oestgaard@hilcorp.com finn.oestgaard@hilcorp.com 907-564-5026 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028305 26 - 8235 N/A N/A 439 620 44687 35579 0 128 1270 1625 1520 850 13b. Pools active after work:Prudhoe Oil No SSSV Installed 9059, 8181 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations 325-065 By Grace Christianson at 8:07 am, Apr 03, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.04.02 16:23:35 - 08'00' Torin Roschinger (4662) DSR-4/7/25JJL 5/8/25 RBDMS JSB 041025 ACTIVITY DATE SUMMARY 3/25/2025 SLB CTU #8 - 1.75" Coil x 0.156" wt Job Objective: Set CIBP, Ext. AddPerf MIRU CTU. Make up drift/log BHA with 3.50" DJN. RIH. Load the well with KCL. Log up from 11350 CTM. Paint correlation flags. POOH. ...Job Continued 3/26/25... 3/26/2025 SLB CTU #8 - 1.75" Coil x 0.156" wt ***Job continued from 3/25/25*** Job Objective: Set CIBP, Ext. AddPerf Good data from log, +1' correction. MU NS CIBP. RIH. Correlate to COE at the flag. Set CIBP 11180 COE. Stack 5K on thh plug. POOH. L&K well 1.5x's BHV. Establish a loss rate above minimum continuous hole fill rate. Flow check well - good check. Deploy 3.125" Geo Basix perf guns (110' loaded) on contiuous hole fill. Perform well control drills with both day and night crew. Kick while deploying/undeploying, stabbing the safety joint as well as the contingency of dropping the BHA. Safety joint XO physically made up to SJ and perf guns to confirm threads. ***Job Continued on 3/27/2025*** 3/27/2025 SLB CTU #8 - 1.75" Coil x 0.156" wt ***Job continued from 3/26/25*** Job Objective: Set CIBP, Ext. AddPerf Continue in hoile with 3.125" Geo Basix perf gun. TIe into flag and perforate 10440- 10550. POOH and bullhead well with 250bbl of 1% KCL. Flow check the well - no flow. Establish loss rate of .35 bpm with 60/40 and retrieve guns. All shots fired, ball recovered. Well is freeze protected with 40.5 bbl of 60/40. ***Job Complete*** Daily Report of Well Operations PBU C-22A 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU C-22A Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 206-039 50-029-20758-01-00 341J ADL 0028305 11450 Conductor Surface Intermediate Liner Liner 8994 80 2638 8552 888 2341 11365 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 8996 30 - 110 29 - 2667 28 - 8579 8402 - 9290 9107 - 11448 2430 29 - 109 29 - 2667 28 - 7751 7603 - 8401 8226 - 8994 11364 2670 4760 5410 7500 None 5380 6870 7240 8430 10033 - 11350 4-1/2" 12.6# 13Cr80 26 - 91168993 - 8996 Structural 4-1/2" Baker S3 Packer No SSSV Installed 9059, 8181 Date: Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 PRUDHOE BAY 2/21/2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-065 By Gavin Gluyas at 8:54 am, Feb 10, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.02.07 16:16:07 - 09'00' Torin Roschinger (4662) 10-404 Perforate JJL 2/10/25 SFD 2/12/2025 Perforating gun BHA not to exceed 500'. Reestablish pressure containment prior to perforating. Perform and document well control drill on each shift using attached standing orders. Ensure well is dead before breaking containment DSR-2/18/25*&: 2/18/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.18 15:35:15 -09'00' RBDMS JSB 022125 Page 1 of 10 Plug & Extended Perforating C-22A PTD: 206-039 Well Name: C-22A API Number: 50-029-20758-01 Current Status: Operable, Shut-in Rig: CTU Estimated Start Date: 2/21/25 Estimated Duration: 2 days Reg.Approval Req’std? 10-403 Date Reg. Approval Rec’vd: Regulatory Contact: Abbie Barker First Call Engineer: Finn Oestgaard (907) 350-8420 Current Bottom Hole Pressure: 3310 psi @ 8,800’ TVD 7.3 PPGE | (Average Ivishak BHP) Maximum Expected BHP: 3310 psi @ 8,800 TVD 7.3 PPGE | (Average Ivishak BHP) Max. Anticipated Surface Pressure: 2430psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 2300 (estimated) Min ID: 3.725” @9,103’ XN-nipple Max Angle: 96° @ 10,175’ Brief Well Summary: C-22A is a horizontal rotary sidetrack Z1B/2A gravity drainage producer drilled in 2006. The well is currently SI for HGOR. The well has been a cycle well the past year and after its last cycle, it is no longer shows strong cycling characteristics. The subsurface team got together, and it has been decided to adjust the flow configuration of the well. The toe most perforations of the well are believed to contribute the most significant amount of gas from a previous PPROF. A plug will be set over these perforations and 110’ of infill perforation in the belly of the well will be added. Objective:Shut off the toe perforations and add footage in Z1B sands. Procedure Coil 1. Make up Tie-In Drift BHA. (Configuration per WSL discretion) RIH and flag for plug set - target set depth @ 11,180’ MD Drift NOTE: Coil has not entered the well since CIBP was milled in 2015, the next time we were in the well was when SL drifted with a 3.79 G-Ring to the XN @ 9,103’ on 5/19/23. Well does not have very many recent drift data points. - Send Tie-In to Finn Oestgaard & Corey Ramstad 2. Set CIBP@ 11,180 MD - Setting in 4-1/2” Liner 12.6# ID = 3.958” (will need to pass through XN nipple @ 9,103’ w/ ID = 3.725”) Coil – Extended Perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 3. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. Page 2 of 10 Plug & Extended Perforating C-22A PTD: 206-039 4. Bullhead 1.2x wellbore volume ~184 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi, can go to 2750 psi to overcome SIWHP. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 153 bbls b. 4-1/2” tubing/liner – 10,033’ X .0152 bpf = 153 bbls 5. At surface, prepare for deployment of TCP guns. 6. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 7.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review standing orders with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. c.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 Use 2-1/2” Millenium guns or similar Perf Interval Tie In and perforate these depths Total Gun Length Weight of Gun (lbs) 10,440 – 10,550’110’~965.8 lbs (8.78 ppf) 9. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 10. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary, before pulling to surface. 11. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 12. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 13. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 14. RDMO CTU. 15. Turn well over to Operations POP. Attachments: x Wellbore Schematic x Proposed Schematic x Tie-In Log x BOPE Schematic x Standing Orders x Equipment Layout diagram x Sundry Change Form Page 3 of 10 Plug & Extended Perforating C-22A PTD: 206-039 Current Wellbore Schematic Page 4 of 10 Plug & Extended Perforating C-22A PTD: 206-039 Proposed Wellbore Schematic 10,440’-10,550’ – 110’ Perforations 11,180’ - CIBPc Page 5 of 10 Plug & Extended Perforating C-22A PTD: 206-039 Tie-in Log Set plug mid element @ 11,180’ Page 6 of 10 Plug & Extended Perforating C-22A PTD: 206-039 Perforate 10,440 – 10,550 Page 7 of 10 Plug & Extended Perforating C-22A PTD: 206-039 BOP Schematic Page 8 of 10 Plug & Extended Perforating C-22A PTD: 206-039 Page 9 of 10 Plug & Extended Perforating C-22A PTD: 206-039 Page 10 of 10 Plug & Extended Perforating C-22A PTD: 206-039 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date RECEIVE,._: STATE OF ALASKA • SKA OIL AND GAS CONSERVATION COMA JION APR 0 9 2015 REPORT OF SUNDRY WELL OPERATIONS , 1 Operations Abandon U Repair Well U Plug Perforations U Perforate LJ Other U" ~Iill F'ICUg c Performed Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extensions Change Approved Program ❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Wells 2 Operator 4 Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development El Exploratory ❑ 206-039-0 3 Address P O Box 196612 StratigraphiC Service ❑ 6 API Number Anchorage,AK 99519-6612 50-029-20758-01-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028305 PBU C-22A 9 Logs(List logs and submit electronic and pnnted data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 11450 feet Plugs measured None feet true vertical 8993 9 feet Junk measured 11364 feet Effective Depth measured 11365 feet Packer measured See Attachment feet true vertical 8996 08 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 29 8-109 8 29 8-109 8 0 0 Surface 2635 5 13-3/8"72#L-80 29.3-2664 8 29.3-2664 65 4930 2670 Intermediate 8551 5 9-5/8"47#L-80 27.5-8579 27 5-7750 94 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10033-10048 feet 10048-10063 feet 10063-10078 feet _ 10160-10410 feet 10670-11140 feet 11220-11350 feet True Vertical depth 8992 74-8995 98 feet 8995 98-8998 65 feet 8998 65-9000 99 feet 9002 34-9002 39 feet 8998 07-8998 16 feet 8997 63-8996.23 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 25 5-9115 69 25 5-8234 44 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) 500100 _ _ Treatment descnptions 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 32 3182 1 218 Subsequent to operation 196 4829 16 381 14 Attachments. 15 Well Class after work Copies of Logs and Surveys Run Exploratory❑ Development❑, Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil Q Gas ❑ WDSPLI GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCS 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Nita Summerhays Email Nita.Summerhaysbp.com Printed Name Nita Summerh- .' / Title Petrotechnical Data Engineer i / Sig - ,dere / / Phone 564-4035 Date 4/8/2015 v r` ¢ l6l/ }RBDMSAAPR 1 0 2015 � Form 10-404 Revised 10/2012 i'(l//�5' Submit Original Only Daily Report of Well Operations ADL0028305 ACTIVITYDATE r SUMMARY CTU #3 w/ 1.75" Coil (CTV=30.4) Objective - mill CIBP and push to bottom 3/14/2015 Stand by for Well Support to finish RU. MIRU CTU. Continued 03/15/2015 WSR CTU #3 w/ 1.75" Coil (CTV=30.4) Objective - mill CIBP and push to bottom RIH w/3.70" 3-bladed junk mill while bleeding WHP from 2100 psi. Tag CIBP at 10071' (Up). Correct electronic depth to top of CIBP = 10111.4' (set by E-line on 7/6/12). Paint yellow flag. 10111.4' E/ 10112' M. Circulate bottoms up. Mill CIBP with zero stalls. Had some difficulty pushing plug past 10120', likely due to 90+ degree deviation and 22 degree DLS. 5 stalls while working through this area. Push plug to PBTD 11367 (ctm). pumped 75bbl safelube and 38 bbls of meth to FP well. POOH. RDMO 3/15/2015 Complete FLUIDS PUMPED BBLS 161 60/40 METH 550 1% SLICK KCL 225 1% SLICK KCL W/SAFELUBE 936 TOTAL a) a o 0 0 0 0 (No-� vLOL() O Ln f- N U y O O O O O L I- V CO CO CO 3 CO N Cr O m CO ti CO t CO LO LO CO 6) O) 6) co V D O O M V 4 O Lc) co O) CO co I� 4' O) CO N 00 (b N CO 1 1 1 1 1 H N - OO LC) NI- N- CO L() O O N O N N O N N N N- CO O O Lf) co CO LC) N CO r CO O N 6) C.) ( LO C 4-• 1 < M CO N- CO 0) c i OM CV CO CD C•1 CO C O 16 O � J F- Q o o °� o00 co U O _1 c J M • a) CO I* J (fl N �# (O U ON - (N CV N- M N O ' 13)O Lo V CO 6) C co Ln cocc' CO O a) a0 N N -J Ct CD C O0 CI W tva cc cc z UOO �' ZZ_ » U Z J J C) - f Packers and SSV's Attachment ADL0028305 SW Name Type MD TVD Depscription C-22A PACKER 8414.42 7613.21 7" Baker ZXP Top Packer C-22A PACKER 9058.25 8180.79 4-1/2" Baker S-3 Hydro Set Packer C-22A PACKER 9118.28 8236.87 5" Baker ZXP Top Packer TREE= 6-3/8"CNVr. TY NOTES: WELL ANGLE>70 9997'*"MAX WEL LHErAD= IIrEVOY C -22A I DOGLEG:22.3•@ 10111'"" 4-CHROMES TBG " ,ACTUATOR= BAKER C NTIAL KB.ELE 67.4' I I BF.ELEV= 34.86' KOP= 3700''. ' t 2210' H4-1/2"HES X NP,L?=3 813" Max Angie= 96"• 10175' Datum MD= 9787' Datum TVDss= 8800' 2596" —19-5/8"DV PKR� 13-3/8"CSG,72#,L-80 BUTT,D=12.347' —i 2667' GAS LFT MANDRELS ST M) ND DEV TYPE VLV LATCH PORT DATE 4 3267 3267 3 MAG DOME RK 16 12/11/12 _ 3 5434 5213 39 MMG SO RK 20 12/11/12 Minimum ID = 3.725" @ 9103' I. 2 6930 6375 36 MNG DMY RK 0 05/14/06 4-1/2" HES XN NIPPLE 1 8255 7478 32 MAG DRAY RK 0 05/14/06 8402' —19-5/8"X 7"BKR LTPw/11.61'PBR,D=6.25" 8420' —j 9-5/8"X r BKR HMC HGR,D=6.32" 9-5/8"WHIPSTOCK H —8579 9-5/8"CSG,47#,L-80 BTRS,D=8.681' —8579 l EZSV(05/02/06) 8600' 1 MLLOUT WNDOW(C-22A) 8579'-8596' I ' 9038' —{4-1/2 HES X fes?D=3.813" z X 9059' —j 7"X 4-1/7 BKR S-3 PKR,13=3.870" I 9082' H4-1/2"HES X NP,D=3.813" ' , 9103' H4-1/2"FEB XN NP,D=3.725" 4-1/2"TBG, 12.6#,13CR VAM TOP, —{ 9115' k, 9107' —I 7"X 5"BKR ZXP LTP w/11.42 PBR D=4.40" .0152 bpf,D=3.958" 9115' —14-1/2"WLE 3,D=3.958" 7"LNR,26#,L-80 BTC,.0383 bpf,D=6.151" H 9290' —I 9124' --{7"X 5"BKR HMC HGR,D=4.41' \y , 9131' --15"X 4-1/2"XO,D=3.958 PERFORATION SUM%RY REF LOG: MWD GR(05/08/06) ANGLE AT TOP FERE:76"a 10033' t 9667--17"MARKER JOINT Note:Refer to Production DB for historical perf data SIZE SFENTE TIAL Opn/Sgz SHOT SQZ 2-7/8" 6 +10033-10048 0 11/10/13 2-7/8" 6 10048-10063 0 07/06/12 2-7/8" 6 10063-10078 0 07/06/12 2-1/2" 4 10160-10410 C 05/14/06 2-1/2" 4 10670-11140 C 05/14/06 2-1/2" 4 11220-11350 0 05/14/06 — 136T CTM —{FISH-CBP PALLED&RJSFED TO BIM(03/15/15) PB TD —1 11365' `....... 4-1/7 LNR 12.6#,L-80 BT-M,.0152 bpf,D=3.958" —j 11448' ' DATE REV BY COMMENTS - DATE REV BY CONC ENTS PRUDH OE BAY UNIT 08/17/82 'ME ORIGINAL COMPLETKN4 03/15/15 AM PJC WILL CEP&HUSH DOWN HOLE WELL: C-22A 02/05/97 CTD SCAB LINER 03/18/15 PJC REFORMAT/CSG/Lk/R UPDATES PERMIT No:'2060390 05/15/06 NIES SIDETRACK"A" AR No: 50-029-20758-01 12/18/12 WRR/JMC GLV CIO(12/11/12) SEC 19,T11N,R14E,994'Fist&1523'FEL 07/18/13 DU/JM) TREE CO(07/13/13) 11/18/13 RMWJMD ADPFS(11/10/13) _ ! BP Exploration(Alaska) STATE OF ALASKA RECEIVED i ,KA OIL AND GAS CONSERVATION COMA,, _ION FEB 1 1 2015 REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate❑ Other Vhc9S6CL/G/ Performed: Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ 5-rir✓1vlal`lG, Change Approved Program❑ Operat Shutdown E Stimulate-Other 0 Re-enter Suspended W❑ 2 Operator 4 Well Class Before Work 5.Permit to Drill Number BP Exploration(Alaska),Inc Name. Development 0 Exploratory 206-039-0 3 Address. P O Box 196612 Stratigraphic ❑ Service 6.API Number Anchorage,AK 99519-6612 50-029-20758-01-00 7.Property Designation(Lease Number) 8.Well Name and Number: ADL0028305 PBU C-22A 9 Logs(List logs and submit electronic and printed data per 20AAC25.071). '10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 11450 feet Plugs measured 10120 feet true vertical 8993 9 feet Junk measured None feet Effective Depth measured 10120 feet Packer measured See Attachment feet true vertical 9004.53 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x30" 298-1098 298-1098 0 0 Surface 2635.5 13-3/8"72#L-80 29 3-2664 8 29 3-2664 65 4930 2670 Intermediate 8551 5 9-5/8"47#L-80 27 5-8579 27.5-7750 94 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10033-10048 feet 10048-10063 feet 10063-10078 feet 10160-10410 feet 10670-11140 feet 11220-11350 feet True Vertical depth 8992 74:8995 98 feet 8995 98-8998 65 feet 8998 65-9000 99 feet 9002 34-9002 39 feet 8998 07-8998 16 feet 8997 63-8996 23 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 25 5-9115 69 25 5-8234 44 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured): 10033'-10078'. Treatment F=� ` 6 0 Treatment descriptions including volumes used and final pressure 15 48 Bbls 12%HCL,53 Bbls 9 1 Mud Acid,2272 psi 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 30 5357 3 1700 200 Subsequent to operation 14 1319 1 1400 218 14.Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG E 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 Garry Catron Email Garrv.Catronta.BP.Com Printed Name Garry Catron p Title PDC PE Signature L J !„ C � Phone 564-4424 Date 2/10/2015 t'r/_ i/13/),5--- RBDMS 1 FEB 1 3 2015 Form 10-404 Revised 10/2012 Submit Onginal Only Lm U co EL LL O• Zr) - Y O. ( 0 •� daa ✓ a= a m I- c X• Lm X N Y N L (0 Nm a) Y _ Y CO m m O v to E . co `Vj O I� -i 0N N- 00 Q to 00 M ✓ ~ M (rE' O0 ON0 O O 0J Q C CV in L N CO CD V cd cd r In () 00 6) CL w w w W O. • Q Q Q d d O- w m o• N N N t Z N N N U U U N a) a o 0 0 0 0 cO (No0 N- (0 LU O V LO I- N t` U y o 0 0 0 0 V M 01 M 00 N V CA V m CO N- CO CO V V Ln LO CO 0) 0) d) CO CA O O C7 r 4 O Lc-) O 0) CO CO - r CA co N 00 CO N CO H N Ct CO LO CO U') O ~ O N CA N N N N N f� CO CDco O C) O LO CO CA CO LO LO N CO - CO O) N CA CU 1=1 QO Ma CO O CN N N N CO CY) C O J 0 1o D o Oo 0D co U It J J M C CD b I N # • N X *k N r` (� O N _ 0\O U N N - LO i CV O � N N CO CD M CN a• )O LO CO O C CO LO CO CO CO O a) co O N N CA J W OW W U 0 CC CC C W Z Z L1.1 LLJ c-15 Q } Z_ Z_ D 0 U Z J J (/) a -o o 0 . 0)o a) m a) m a) a) c a)) tl 0 -0O -0 - CO 0 Ecco U?.�c a 0 0 0 0 coC ,- N N N -Q N o .c -o N N N Cl.) 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Ln N o CO c c o a Ln D a U Q- Ln r- Ln In a) in o U - L N cn .0 5 O '� M •- CC '- D szt co) ` N O CO 0 Q) u) co O .� a) Cl — = N (I) ) •C +. aco J > D N o N O U) ) E o O N c Q N ▪ p " N > O N a U Un Q E U U o C U) o U O E c O J .. '' < 0 � c COLO 0D ca as m c0i) 4'_ i 0) c oco c 0 0 N 0 II 0 u) N d 13 '(--) d 0 LL a) _o N a) in * L) 0) 4) t E N c O Cc 0 (.00 l\ Q — O _0 O Lo II G1 a Q 0. � o QO 0 c I� E Q M — D d CO II 0- N O -a o ~ �0 J �* ca t * 0 < a) -6 ) 0 d 5 0 A Q II C N Q O1cf) E cn O L ~ n c c co O 0 U o ? U 0) Q * N N TREE= 63/8"CNV SAFETY I is 70°@ 10000'HORIZONTAL *"*4-112" WELLHEAD= Nb EVOY 2 2 CHROME TBG'*` s'ACTUATOR= BAKER C NT1AL KB.Ell 67.4' BF.ELEV= 34.86' KOP= 3700' Max Angle= 96'@ 10175' 2210' —{4-1/2"liES X NP,D=3.813' Datum MD= 9787' Datum TV Dss= 8800' i .„,, X--1 2596* —I 9-5/8"DV R02 13-3/8"CSG,72#,L-80,13=12.347" —I 2667' , GAS LFT MANDRELS ST MD TVD DEV TY FE VLV LATCH PORT DATE t 4 3267 3267 3 MVIG DONE RK 16 12/11/12 3 5434 5213 39 MVIG SO RK 20 12/11/12 Minimum ID = 3.725" @ 9103' 2 6930 6375 36 MNG DMY RK 0 05/14/06 4-112" HES XN NIPPLE 1 8255 7478 32 lVVIG DMY RK 0 05/14/06 E V 8402' —9-5/8"X 7"BKR I-NC LNR HGR i� w/ZXP LTP,D=3.870' MI.LOUT WrDOW(C-22A) 8579'-8596' 9038' —4-1/2"HES X MP,D=3.813" WHPSTOCK --I ? .1 — 9059' l--Ir X 4-1/2"BKR S-3 PIT,D=3.870" %,.':, ,t , \A EZSV(05/02/06) H 8600' -y, 9082' _—I4-1/2"HES X NP,D=3.813" ii 9103' H4-1/2"HES XN NP D=3.725" - 9107' Hr X 4-112"ZXP LTP, D=4.40" 1A4A 9115' -J4-1/2"WLEG 9-5/8"CSG,47#,L-80,D=8.681" H 9314' *'Ji,�'v,'ii. •iii,.4 iii ,r. PETiFORATION SIJAARY ...*1$.►�.�i':': REF LOG: MA/VD GR(05/08/06) ':.:�.�`,�.: ` 10111' —14-1/2"CEP ANGLE AT TOP PERF:76°@ 10033' .i 444: ` (07/06/12) """ Note:Refer to Ftoduction DB for historical pert data 4,4,44,4,4, �/ t FWD — 11365' SIZE SPF NTERVAL Opn/Sqz SHOT S(]Z '••••••4 2-7/8' 6 10033-10048 0 11/10/13 4-1/2"TBG,12.6#,13-CR VAM TOP, H 9115' • 2-7/8" 6 10048-10063 0 07/06/12 .0152 bpf,D=3.958" 44. 2-7/8' 6 10063-10078 0 07/06/12 4\\\i` 2-1/2" 4 10160-10410 C 05/14/06 7"LNR 26#,L 80, 9290' �b� 2-1/2" 4 10670-11140 C 05/14/06 .0383 bpf,D=6.151" 2-1/2" 4 11220-11350 0 05/14/06 4-1/2'LNR,12.6#,L-80,.0152 bpf,13=3.958' —I 11448' DATE REV BY C OIVIvENTS DATE REV BY COMMENTS PRUDHOE BAY MT 08/17/82 ORIGINAL COMPLETION 07/10/12 JM) LEGETD CORRECTIONS WELL C-22A 02/05/97 CTD-3-1/2"SCAB LNR 12/18/12 VVRR/JMJ GLV C1O(12/11/12) R32MT No: 2060390 05/15/06 N7E5 SIDETRACK"A" 07/18/13 DU/JM3 TREE CIO(07/13/13) AR No: 50-029-20758-01 05/28/06 DAV/PJC GLV CJO 11/18/13 RM-VJM? ADFBZFS(11/10/13) Sec.19,T11N,R14E,994'FNL&1523'FEL 12/12/06 OOB/PJC DRLG DRAFT CORRECTIONS 07/10/12 JTCIJM7 ADPERFS&SET CEP(07/06/12) BP Exploration(Alaska) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - ~~ 9 Well History File Identifier Organizing (done) Two-sided III IIII II II III II III ^ Rescan Needed III (I'lll II II III III R CAN DIG TAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ( ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: Q g /s/ Prvect Proofing I II I III II III II IIII I BY: Maria Date: og /s/ Scanning Preparation ~L x 30 = ~~ + =TOTAL PAGES CLr~ ~/ / (Count does not include cover sheet) BY: Maria Date: ~ nR lSl I V V Production Scanning Stage ~ Page Count from Scanned File: ~L (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES _ BY: Maria Date: ~ ~/O Stage 7 If NO in stage 1, page(s) discrepancies were found: YES 8Y: Maria Date: Scanning is complete at this point unless rescanning is required. NO /s, -~P NO "6uuiiiumuu ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III II'I III 10/6/2005 Well History File Cover Page.doc • STATE OF ALASKA RECEIVED A. KA OIL AND GAS CONSERVATION COMMISSION DEC 11 2013 REPORT OF SUNDRY WELL OPERATIONS ((y�►��(,//�^�''�� ((/��� 1.Operations Abandon U Repair WellU Plug Perforations U Perforate U OtherH A (DCCC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development 0 Exploratory ❑ 206-039-0 . 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20758-01-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028305 • PBU C-22A . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL It Present Well Condition Summary: Total Depth measured 11450 feet Plugs measured 10120 feet true vertical 8993.9 feet Junk measured None feet Effective Depth measured 10120 feet Packer measured See Attachment feet true vertical 9004.53 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"94#H-40 28-108 28-108 1530 520 Surface 2635 13-3/8"72#L-80 27-2662 27-2661.85 4930 2670 Intermediate None None None None None None Production 8553 9-5/8"47#L-80 26-8579 26-7750.94 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth_ 10033-10048 feet 10048-10063 feet 10063-10078 feet 10160-10410 feet 10670-11140 feet 11220-11350 feet True Vertical depth 8992.74-8995.98 feet 8995.98-8998.65 feet 8998.65-9000.99 feet 9002.34-9002.39 feet 8998.07-8998.16 feet 8997.63-8996.23 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 25-9115 25-8233.79 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED JAN 2 7 2014 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: 14 1553 1 0 165 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Explorator)Q Development El• Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil Ill• Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC•J 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 Garry Catron Email Gar .Catron • BP.Com Printed Name Garry Catron Title PDC PE Signature E, Phone 564-4424 Date 12/11/2013 V Ir1� FiBrAt DEC 16 2U ► /lo / l1-Form 10-404 Revised 10/2012 e OyAr Submit Original Only a) U f0 a 4(7 31 a °,co a CL d ) N XX � CU (0 - Y - — CO co NI- r r E V RS el to $i N M ~ 00 00 CO O co RI L p Nr 5.1 a) w gTro � • 400) 0) cc cc re V a 0.YYY Q 0 Q aaa m R N N N Z N N N U U U N w Mc) 00000 `— cqv ( ° )) N- (DLC O to f- Tr N V CC)) Tr CC) NO co C) • U) N V- co 0) yr m1- N- O CID d' 00 U) CO V 0 0) 000ACA00N- o O M O r- 01 Tr 00) N CD N 00 00 I's N CO Tr CO N- N CO N NO N N N N CO N A N- O O CA N O O N LO a CA T- co N CO 03 LC) CI O M CO CD 00 (0 N- co ago N N co N N N C CD .Q o J ~• Q O0 O o � o o 87 0 °�° CO J d = JO N4 N N 4* 1* CV 4 I,- CO C U CO - - N V N -- ;7:0 CO (V "? - N I ch � r 4 co co t _ 11 0 0 Tr O M 00) J CO co CC) 01 N 000 N 0 Z • O w rn > > UC� '5DCCcoii1 Z v Z w w O ce m O Z Z ce n D U 7 _iacnF- o to \ % ® k7 0) ••c, ® on = / } � /\ R / I $ 5 ) �a _' / * D \ \ \ / / 2 o G A 0 ¥ m = wCOp\ / + / c § ® LL \ I7 \ / ± E / - .cTi .s o f \ o- It # ■ a » E/ c 7 » /c = -5 � 0 b a c o 6 \ cam = 2 RS tw / R R 7 = � I � / c 0. g ._ r Oo § o � E \ w £ , @ ¥ ) ■ = a '% Z 7} - I % g - % + ° 7® J ��o /� � tO � / / � � % pf /-6 o < o a_co 0 < < / 9 I < ± Go_ m Ce o2 6w �0c—N a a PT,/ Dc Cj) c) / 2 � A $ A % .0 ° / \ U 7 ° U w D o co _ \ � 7$ c\ ƒ\ / Ik N.. ® 2 N- k / c a) \ E §/ . c & � � �/ _ R .7- / 2 5. 0 j / \ U ± i o 2 = 2 U co co \ CV \ a TREE= 6-3/8"CN1/ VVELLHEAD= M EVOY SAFETY Nt.._.i:70°@ 10000'HORIZONTAL """4-1/2" ` ACTUATOR=........ BAKER C C -2 2 A CHROME TRW.'" INMAL KB.ELE 67.4' BF.ELEV= 34.86' KOP= 3700' Max Angle= 96°@ 10175' I I 2210' —14-1/2"HES X NP,D=3.813" Datum MD= 9787' Datum TVDss= 8800' i ... = 2596' H 9-5/8-DV PKR 113-3/8"CSG,72#,L-80,13=12.347" H 2667' ■ GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3267 3267 3 MMG DOME RK 16 12/11/12 3 5434 5213 39 MAC SO RK 20 12/11/12 Minimum ID = 3.725" c@ 9103' j 2 6930 6375 36 WIG OMY RK 0 05/14/06 4-1/2" HES XN NIPPLE j 1 8255 7478 32 WAG DMY RK 0 05/14/06 E A 8402' —I 9-518'x 7"BKR HMC LNR HGR w/ZXP LTP,13=3.870" MLLOUT VVNDOW(C-22A) 8579'-8596' 9038' H4-1/2"HES X NP,D=3.813" WHPSTOCK H ? • 9059' Hr X 4-1/2"BKR S-3 PKR,P D=3.870" I EZSV(05/02/06) —) 8900' �; 9082' H4-1/2"HES X N 13=3.813" vi 9103' AH4-1/2"HES XN NP,D=3.725" i i 910T —7"X 4-1/2"ZXP LTP, D=4.40" iii• ,� 9115' H4-1/2"WLEG 9-5/8"CSG,47#,L-80,13=8.68r H 9314' A * 'y v o o fi% ••■ 4• '�:i.v, •�• .,I PERFORATION SUMMARY 4,i,•i S ',,' vs. „1111 REF LOG: MUVD GR(05/08/06) #'.4 '4 4?i l: `, 10111' —4-1/2"CEP ANGLE AT TOP PERF:76°@ 10033' ��.1�`lt (07/06/12) Note:Refer to Production DB for historical perf data titititititi SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 'A-A•❖••'A' ■ PBTD 11365' 2-7/8" 6 10033-10048 0 11/10/13 4-1/2"TBG,12.64,13-CR VAM TOP, — 9115' % 2-7/8" 6 10048-10063 0 07/06/12 .0152 bpf,D=3.958" 44 2-7/8" 6 10063-10078 0 07/06/12 7"LNR 26#,L 80, 9290' X44 ►` 2-1/2" 4 10160-10410 C 05/14/06 2-1/2" 4 10670-11140 C 05/14/06 .0383 bpf,13=6.151" 2-1/2" 4 11220-11350 0 05/14/06 4-112"LNG 12.64,L-80,.0152 bpf,D=3.958" H 11448' DATE REV BY CONVENTS DATE REV BY COMMENTS PRIDHOE BAY UNIT 08/17/82 ORIGINAL COMPLETION 07/10/12 JMJ LEGEND CORRECTIONS WELL C-22A 02/05/97 CTD=3-1/2"SCAB LNR 12/18/12 VVRR/JMJ GLV C/O(12/11/12) FERMI-No: 2060390 05/15/06 N7ES SIDETRACK"A" 07/18/13 DU/JMD TREE C/O(07/13/13) API No: 50-029-20758-01 05/28/06 DAV/PJC GLV GO 11/18/13 RMVJ ) ADPERFS(11/10/13) Sec.19,T11N,R14E,994'FNL&1523'FEL 12/12/06 OOB/PJC DRLG DRAFT CORREC1IONS 07/10/12 JTC!JMJ ADPERFS&SET CEP(07/06/12) BP Exploration(Alaska) tIt(. IVED STATE OF ALASKA ALIA OIL AND GAS CONSERVATION COMMI•N SEP 1 8 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations Ld Perforate ✓ f Other [J Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeIQ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 0 Exploratory ❑ - 206 -039 -0 3. Address: P.O. Box 196612 Stratigraphk❑ Service ❑ 6. API Number: r Anchorage, AK 99519 -6612 50- 029 - 20758 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028305 PBU C -22A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11450 feet Plugs measured None feet true vertical 8993 feet Junk measured None feet Effective Depth measured 11365 feet Packer measured See Attachment feet true vertical 8996.08 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H-40 30 - 110 30 - 110 1530 520 Surface 2638 13 -3/8" 72# L -80 29 - 2667 29 - 2666.85 4930 2670 Intermediate None None None None None None Production 8568 9 -5/8" 47# L -80 28 - 8596 28 - 7764.95 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10048 - 10063 feet 10063 - 10078 feet 10160 - 10410 feet 10670 - 11140 feet 11220 - 11350 feet True Vertical depth 8995.98 - 8998.65 feet 8998.65 - 9000.99 feet 9002.34 - 9002.39 feet 8998.07 - 8998.16 feet 8997.63 - 8996.23 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 25 - 9115 25..8233.79 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED JAN 2 Q 2 03 Ht I O 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: 626 40257 23 0 1750 Subsequent to operation: 119 3882 4 0 225 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - El Gas U WDSPUU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature 04“47 C.f iL Phone 564 -4424 Date 9/14/2012 RBBDMS SEP 2 0 j'l 1.z I,, Form 10-404 Revised 11/2011 Submit Original Only • • Packers and SSV's Attachment ADL0028305 SW Name Type MD TVD Depscription C -22A PACKER 8402 7540.38 7" Baker ZXP Top Packer C -22A PACKER 9059 8119.13 4 -1/2" Baker S -3 Packer C -22A PACKER 9107 8163.92 4-1/2" Baker ZXP Packer Casing / Tubing Attachment ADL0028305 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H-40 30 - 110 30 - 110 1530 520 LINER 888 7 26# L -80 8402 - 9290 7602.74 - 8400.65 7240 5410 LINER 2341 4 -1/2" 12.6# L -80 9107 - 11448 8226.28 - 8993.96 8430 7500 PRODUCTION 8568 9 -5/8" 47# L -80 28 - 8596 28 - 7764.95 6870 4760 SURFACE 2638 13 -3/8" 72# L -80 29 - 2667 29 - 2666.85 4930 2670 TUBING 9090 4 -1/2" 12.6# 13Cr80 25 - 9115 25 - 8233.79 8430 7500 • • Daily Report of Well Operations ADL0028305 ACTIVITYDATE I SUMMARY - ..... mow. ** *JOB CONTINUED FROM 07/05/12 * ** (ELINE SET CIBP /PERF) RAN IN W/ TRACTOR/ 4 1/2" HES CIBP, SET @ 10120' ELM' (MAX OD 3.66" / LENGTH = 25.13 ") CORRELATED TO SLB MCNL DATED 7- MARCH -2012 BASED ON GR OVER THE INTERVAL 10000' - 10175'. RAN TRACTOR W/ 15' x 2 -7/8" PJ 2906 HMX GUNS. PERFORATED INTERVAL 10063' 10078' Y- CURRENTLY PULLING OUT OF HOLE AFTER FIRST PERF RUN :. .: • 7/6/2012 ** *CONTINUED ON 07/07/12 * ** ** *JOB CONTINUED FROM 06- JULY - 2012 * ** (ELINE- PERFORATION) RIH WITH HEAD /ERS /TRACTOR/WPGR/WPST /ATPS /FIRING HEAD /GUN OVERALL LENGTH 37',OVERALL WEIGHT 550# GUN 15' 2 -7/8" PJ 2906 HMX, 6 SPF, PHASING 60 DEG,PENETRATION 25.3 ", ENTRANACE HOLE 0.38 ",SWELL 3.08" PERFORATION INTERVAL 10048' TO 10063', TOOL ZERO TO TOP SHOT 5.5', TOOL ZERO STOP DEPTH 10042.5' SWAB,SSV= CLOSED OA/IA =OTG DSO NOTIFIED OF DEPARTURE FINAL T /IA/OA= 130/800/0 7/7/2012 ** *WELL SI ON DEPARTURE * ** TREE = 6" CNV SAFETY N 70° @ 10000' HORIZONTAL "'•4 -1/2" WELLHEAD = Iv1vEVOY C-22A AGTURTCGR = -- CH KB ELEV = 67.36' BF. ELEV = 34.86' - . ..._._.. KOP = 3700' Angle = 96° @ 10175' I I I 2210' - I4 -1/2" HES X NIP, ID = 3.813" Datum MD = 9787' Datum TVDss = 8800' i ... = 2596' —19 -5/8" DV PKR 13 CSG, 72 #, L -80, ID = 12.347" H 2667' i GAS LIFT MANDRELS ST MD `:V') DEV TYPE VLV LATCH PORT DATE 4 3267 3267 3 MMG DOME RK 16 05/28/06 3 5434 5213 39 MMG SO RK 20 05/28/06 Minimum ID = 3.725" @ 9103' 2 6930 6375 36 MMG DMY RK 0 05/14/06 4 -1 l2 HES X N NIPPLE 1 8255 7478 32 MMG DMY RK 0 05/14/06 Ig 8402' 1 9 -5 /8 "X 7" BKR HMC LNR HGR w /ZXPLTP, ID =3.870" MILLOUT WINDOW (C -22A) 8579' - 8596' 9038' H4 -1/2" HES X NIP. ID = 3.813" WHIPSTOCK H ? I N I. 9059' I-17" X 4 -1/2" BKR S -3 PKR, ID = 3.870" I IEZSV (05 /02/06) - 8600' y, 9082' — 14 -1/2" HES X NIP, ID = 3.813" �i 9103' I 14-12" HES XN NIP, ID = 3.725" i t 9107' — 7" X 4-1/2" ZXP LTP, ID =4.40" /114 9115' — I4 -1/2" WLEG I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 9314' "' 11 "" s;. /1. ::: 1 ii ii 11 'ii PERFORATION SUMMARY 0 • REF LOG MWD GR (05/08/06) . [ 1 �' 10111' —{ 4 112 CIBP ANGLE AT TOP PERF: 79° @ 10048' ' WOO (07/06/12) 1•1•1•1•1•�•i Note: Refer to Production DB for historical pert data . 0.0 0 * ,` PBTD H 11365' r SIZE SFF INTERVAL Opn /Sgz -DATE / 2 -718" 6 10048 - 10063 0 t 07!06!12 • 4-1/2" TBG, 12.6 #, 13 -CR VAM TOP. — 9115' • 2 -7/8" 6 10063 - 10078 0 07/06! .0152 bpf, ID = 3.958" � 2-1/2" 4 10160 10410 C `iJ5 14/06 7" LNR, 26#, L -80, — 9290' _ �1. ► 2-1/2" 4 10670 - 11140 C 05/14/06 .0383 bpf, ID = 6.151" 2 -12" 4 11220 - 11350 0 05/14/06 4-1/2" LNR, 12.6 #, L -80, .0152 bpf, ID= 3,958" H 11448' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08117182 ORIGINAL COM PLET ION 07/10/12 JMD LEGEND CORRECTIONS WELL: C-22A 02/05/97 CTD=3 -112" SCAB LNR PERMIT No. '2060390 05/15106 N7ES SIDETRACK "A" API No: 50- 029 - 20758 -01 0528/06 DAV /PJC GLV C/O Sec. 19 T11 N, R14E, 994' FNL & 1523' FEL 12/12/06 OOB /PJC DRLG DRAFT CORRECTIONS 07/10/12 JTC/JMD ADPERFS & SET CIBP (07/06/12) BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 C Mr. Tom Maunder RECEIVED' Alaska Oil and Gas Conservation Commission AUG 3 1 2011 333 West 7 Avenue Anchorage, Alaska 99501 ;Alaska OH & Gas Gaye, Goinnission Subject: Corrosion Inhibitor Treatments of GPB C -Pad Aaafr3rag0 a06— ° 35 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad 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, Torin Roschinger BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C -01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C -20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 e C -21 1820810 500292074503 1.7 NA 1.7 (,..NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -28B 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -35B 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -37B 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C -41A 2041880 500292238501 Sealed NA NA NA NA NA C -42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 2Q -p 39' 13-JUL -2011 2 - \ 2 . 2 S7 Schlinherger N C D 2 7 2 Company: 5764 Alaska Data & Consulting Services %maw r�D Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD W -223 BCRJ -00086 ISOLATION SCANNER 18- May -11 1 1 W -221 BJGT -00040 USIT 16- Jun -11 1 1 C -11A BLPO -00111 PPROF W GHOST 14-Jun-11 1 1 H -19B BLPO -00109 MEMORY PPROF W GHOST 12- Jun -11 1 1 V -227 BCRJ -00090 SCMT 19-Jun-11 1 1 X -22A AWJI -00143 USIT 18- Jun -11 1 1 MPI -09 BCRC -00067 MEMORY LEAK DETECTION LOG 18- Jun -11 1 1 14 -36 BCRJ -00091 IPROF 21 - Jun - 1 1 J -27A BAUJ -00090 PPROF W GHOST 20Jun -11 1 1 D -06A BL65 -00041 PPROF W DEFT GHOST 24-Jun-11 1 1 16 -05A BSM4 -00008 LEAK DETECTION LOG 27-Jun-11 1 1 Z -27 BSM4 -00009 GAS LIFT SURVEY 2- Jul -11 1 1 09 -22 BJGT -00048 (PROF 4-Jul-11 1 1 W -08A BBSK -00076 SCMT 25-Jun-11 1 1 Y -04 AWJI -00147 PPROF W DEFT GHOST 22-Jun-11 1 1 R -28 BJGT -00047 SBHPS 3- Jul -11 1 1 U -11B BG4H -00058 PPROF 16- Jun -11 1 1 Z -31 BCRJ -00093 SCMT 10Jul -11 1 1 F-48 BG4H -00062 PPROF W DEFT GHOST 9-Jul-11 1 1 06 -11 BSM4 -00012 PPROF W DEFT GHOST 4-Jul-11 , 1 1 C -32C BLPO -00117 PPROF W GHOST 5-Jul-11 1 1 01 -31 BP5G -00001 RST EDIT 17- Mar -11 1 1 N -17 BJOH -00007 PDC -GR EDIT 9- Feb -11 1 C -12B BAUD -00064 MCNL EDIT 9-Mar-11 1 1 C -22A BL65.00022 MCNL EDIT 7-Mar-11 1 1 14 -33A BL65 -00023 MCNL EDIT 6- Apr -11 1 1 S -129 10AKA0109 OH PDC-GR EDIT 7- Nov -10 1 1 S- 129PB1 10AKA0109 OH PDC-GR EDIT 7- Nov -10 1 1 S- 129PB2 10AKA0109 OH PDC-GR EDIT 7 -Nov-10 1 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 0 Schiamberger No. 5748 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 - 2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 02 -12C BCRD -00105 SCMT - 5/6/2015 1 1 20 6 - 03 ' C -22A BL65 -00022 MEMORY PPROF W/ GHOST 3/7/2015 1^ 1 ■ A MPE -28 BCRJ -00085 CEMENT BOND LOG 5/14/2015 1 1 H -22A BL65 -00028 MEMORY PPROF W/ DEFT 5/8/2015 1 1 I C -02 AWJI-00136 PPROF W/ GHOST 3/28/2015 1 _ 1 Z -112 BD88- 00093 MEMORY PPROF WI DEFT 3/29/2015 _ 1 1 MPH -10 AV1P -00087 USIT 4/21/2015 1 1 06 -16 BCRD -00090 RST 3/9/2015 1 1 S -128 BCZ2 -00035 CH EDIT (USIT) 1/3/2015 _ 1 A -39A BL65 -00018 CH EDIT (PDC -GR) 2/4/2015 1 E -356 BHGR -00003 , OH IFLEX EDIT 12/03/10 1 1 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E Benson Blvd Anchorage, AK 99503 -2838 ';',,%..„ r .n[1 .R film al 20ki .r..~- x ~' ~ ,, 'mow ~ ~t s ~~.,, `~ E ti ..~~~ ~~ MICROFILMED 6/30/20.1.0 DO .NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc 1 ~ J tl~ DATA SUBMITTAL COMPLIANCE REPORT 6/19/2008 Permit to Drill 2060390 Well Name/No. PRUDHOE BAY UNIT C-22A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20758-01-00 MD 11450 TVD 8994 Completion Date 5/15/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey es DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR /RES / PWD, MWD DIR / GR /RES, MWD DIR / GR / Well Log Information: Log/ Electr Dat Digital Dataset Log Log Run T e Med/Frmt Number Name Scale Media No (data taken from Logs Portion of Master Well Data Maint Interval OH / r Stan. Stop CH Received Comments E D Asc Directional Survey 8495 11450 Open 9/15/2006 Rpt / Dir tional Survey v~ 8495 11450 Open 9/15/2006 QED C Las lS ,,~ nduction/Resistivity 9672 10155 Open 10/12/2007 DRHB, RPM, GR, NPHI, RPD, RPS w/EMF graphics field data ~ D C Lis ``// 15781 Induction/Resistivity 8416 11449 Open 12/21/2007 LIS Veri, GR, ROP, PRS, PRM, DRHO w/PDS and TIF graphics og Induction/Resistivity Blu 8396 11450 Open 12/21/2007 MD Vision Service Final 10- ~~ May-06 og Induction/Resistivity Blu 8396 11450 Open 12/21/2007 TVD Vision Service Final 10-May-06 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y !~ Chips Received? ~fiV-~ Analysis 1~FiN. Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~/ N Formation Tops r1 Comments: DATA SUBMITTAL COMPLIANCE REPORT 6/19/2008 Permit to Drill 2060390 Well Name/No. PRUDHOE BAY UNIT C-22A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20758-01-00 MD 11450 TVD 8994 Completion Date 5/15/2006 Completion Status 1-OIL Current Status 1-OIL UIC N -I Compliance Reviewed By: _ Date: 12/19/07 ~~~~~~~~~~~~ NO. 4525 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite a00 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: P.Bay, Milne Pt., Lisburne WPII .Inh $ Inn rlasrrin4inn Ih4n RI r nlnr Crl 15-39A 11661174 MCNL '~ 09/24/07 1 14-32 11676961 RST 09/14/07 1 1 X-30A 11649992 CH EDIT PDC GR (JEWELRY LOG '} 1 y 10/06/07 1 03-36A 11745217 CH EDIT PDC GR (USIT) ~ ( U1'~- 05/03/07 1 15-30A 11767139 MCNL - ~ 09/05!07 2 1 18-126 11216204 MCNL > 07/04/06 2 1 E-21B 11133205 MCNL -/G~ $ 12/07/05 2 1 P2-56 11686777 RST - ~ 08/08/07 2 1 H-33 11686792 RST GjL - '~ 10/20/07 2 1 06-16 11686797 RST _ < 11/15107 2 1 L2-16 11626482 RST 05110/07 2 1 D-226 11661167 MCNL ~ ) 5 08/26/07 2 1 03-14A 11212846 CH EDIT SDCL GR (USIT1 ~(Xp - (j8 ~5 ~ 04/24/06 2 1 MPB-21 PROD 11628749 MCNL (MEM PPROF) ~ -~~ ~(~ 4 j), 01/15107 2 1 C-22A 40013486 OH MWD/LWD EDIT („ -p ~ '~ ~S/ 05/10/06 2 1 E-15C 40013555 OH MWD/LWD EDIT O - (o (~ ~ "~-~d 06103/06 2 1 F'LCAJC Nl.nrvV VVLtUUt Ktla1Y 1 tST JIlSNING ANU Kt I UKNINId UIVt I;UYY tAGM I U: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. - Anchorage, Alaska 99508 Date Delivered: r' sa j ~ i~d y Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~,- Date 10-12-2007 Transmittal Number:92907 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) f you have any uestions, lease contact llouglas llortch at trie Ylll; at Jb4-4y i.5 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 01-01 C_~~=~~ ~a553_~il_ _. - - -.._ 01-08A u z~ BC~~tq 5 _1_-_S~3`~_ - _ 03-14A w~ Oaf i ~S~l f __ -- - 03-36A ~-I'a5 l~l ~ f~P.a.. ~- ____ _ 05-36A a~ _~-~a 1s~~a _ 05-36AP61 ~O~ -6`~ l$'S~ 06-13A - ~ _ 06-13APB1_ ao ~ -[o~_L~_y,_~-_^ __ u 12-05A ~ _e~.~ - it r.~~i~ 12-05APB1 .~o~-C63 ._" t~S.Y~ ___--~u._.... C-22A.--ate ~._ __~~-~___._~.S's`~K g E-15C am _..~ ,. t ~ ~.-rc.a ------ - - K-02D -~blo a6lo _._",1_SS5(___.__.._.__~ K-02DPB1~Q.~-DSSQ.*/:S_~Sa ---_.._ W -213 ;~ a°~___~s~ _ ~ / Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 a ~~~- o3q STATE OF ALASKA ALAS IL AND GAS CONSERVATION COSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,~ECEt~V~'D JIJN 1 2 2006 Alaska Oil & Gas Cons. C~rnission Anchorage 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.,os zoAACZS.,,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. 5/15/2006 12. Permit to Drill Number 206-039 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 5/4/2006 13. API Number 50-029-20758-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 5/10/2006 14. Well Name and Number: PBU C-22A FNL, 1523 FEL, SEC. 19, T11N, R14E, UM 994 Top of Productive Horizon: 2182' FNL, 4021' FEL, SEC. 19, T11 N, R14E, UM g, KB Elevation (ft): 62.36' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool -Total Depth: 2022' FNL, 2516' FEL, SEC. 19, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 11365 + 8996 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 663847 y- 5960214 Zone- ASP4 10. Total Depth (MD+TVD) 11450 + gg94 Ft 16. Property Designation: ADL 028305 TPI: x- 661380 y- 5958972 Zone- ASP4 Total Depth: x- 662881 Y- 5959165 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: if ff h 19 W t d th rmafrost f P 20 Thi k 18. Directional Survey ®Yes ^ No ore . a er ep , o s N/A MSL ness o c e . 1900' (Approx.) 21. Logs Run: MWD DIR / GR /RES / PWD, MWD DIR / GR /RES, MWD DIR / GR /RES ABI /DEN / NEU ASING, INER AND EMENTING ECORD CASING ETTING EPTH MD ETTING EPTH';TVD HOLE OUNT SIZE WT. PER FT. GRADE Op OTTOM OP'`': t OTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2667' Surface 2667' 17-1/2" 3767 cu ft Arcticset II 9-5/8" 47# L-80 Surface 8579' Surface 7751' 12-1/4" 1285 cu ft Class'G', 130 cu ft AS I 7" 26# L-80 8402' 9290' 7603' 8401' 8-1/2" 235 cu ft Class'G' 4-1/2" 12.6# L-80 9107' 11448' 8226' 8994' 6-1/8" 357 cu ft Class'G' 23. Perforations open to Production (MD +TVD of Top and " " 24. TUBING RECORD none Bottom Interval, Size and Number; if none, state ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr 9115' 9059' MD TVD MD TVD 10160' - 10410' 9002' - 9002' 10670' - 11140' 8998' - 8998' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11220' - 11350' 8998' - 8997' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protected with 150 Bbls of Diesel 26. PRODUCTION TEST Date First Production: May 30, 2006 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 6/3/2006 Hours Tested 4 PRODUCTION FOR TEST PERIOD • OIL-BBL 354 GAS-MCF 413 WATER-BBL 4 CHOKE SIZE 176° GAS-OIL RATIO 1,167 Flow Tubing Press. 28 Casing Pressure 800 CALCULATED 24-HOUR RATE OIL-BBL 2,126 GAS-MCF 2,480 WATER-BBL 22 OIL GRAVITY-API (CORK) 25.2 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None COir4Fi_~ ION ~ d~ ~ r~ °~ ~J,~~ 7/cS/ /G''~ BFI. ~uN~~'2o06 IFi~o ,` Form 10-407 Revised-t2C1D03 C9NTINUED ON REVERSE SIDE - G 2~. GEOLOGIC MARKE 29' ORMATION 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". Sag River 9286' 8397' None Shublik A 9318' 8428' Shublik B 9351' 8460' Shublik C 9371' 8480' Sadlerochit 9400' 8509' Top CGL 9607' 8710' Base CGL 9675' 8770' 22TS 9788' 8863' 21 TS /Zone 2A 9874' 8923' 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. ~ n /~ Z/(y~ Signed Terrie Hubble Title Technical Assistant Date PBU C-22A 206-039 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Barbara Lasley, 564-5126 INSTRUCTIONS GeNeRA~: 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). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: 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 "Nave". Form 10-407 Revised 12/2003 -'"` Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: C-22 Common Name: C-22 _- Test Date Test Type _ ~est Depth (TMD) ~ Test Depth (TVD) I - AMW Surface Pressure Leak Off Pressure (BHP) EMW 5/3/2006 FIT 8,596.0 (ft) 7,766.0 (ft) 10.20 (ppg) 525 (psi) 4,640 (psi) 11.50 (ppg) 5/7/2006 FIT 9,290.0 (ft) 8,419.0 (ft) 8.40 (ppg) 700 (psi) 4,374 (psi) 10.00 (ppg) Printed: 5/22/2006 11:57:45 AM BP EXPLORATION Page 1 of 13 Operations Summary Report Legal Well Name: C-22 Common Well Name: C-22 Spud Date: 7/29/1982 Event Name: REENTER+COMPLETE Start: 4/27/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/15/2006 Rig Name: NABOBS 7ES Rig Number: Date From - To 'Hours Task ;Code NPT Phase Description of Operations I 4/27/2006 15:00 - 00:00 9.00 MOB P PRE Prepare to move to C-22. Rig down Top Drive and rig floor. String up bridle lines to blocks to lower derrick. Rig down pit module and disconnect from sub base.Lay down derrick. Remove 4 high matting board configeration from under mud pits and rig sub base. Move satellite camp, truck shop, pits to C-22. 4/28/2006 00:00 - 16:00 16.00 MOB P PRE Move rig to C pad. 16:00 - 18:00 2.00 MOB P PRE Set matting boards on C-22a. Lay herculite 18:00 - 18:30 0.50 MOB P PRE Spot and level sub base over C-22a 18:30 - 20:30 2.00 MOB P PRE Set pit module in place. Hook up service lines from pit module to sub base, Berm cellar area, Set cuttings tank in place, Spot service personal units. 20:30 - 00:00 3.50 MOB P PRE Raise and pin derrick in place. Raise cattle chute, Hook up lines, Bridal down, Hook top drive to blocks. Take on 8.5 ppg 130 degrees sea water in mud pits, Install secondary annulus valve. Rig up hose's to circulate out freeze protect from well bore. Rig accepted at 24:00 hours 4-28-06 4/29/2006 00:00 - 00:30 0.50 KILL P DECOMP Pre Spud and Enviromental meeting with all personal involed. 00:30 - 02:00 1.50 KILL P DECOMP Pull back pressure valve with DSM lubricator. 02:00 - 05:00 3.00 KILL P DECOMP Reverse circulate pumping 8.5 ppg 130 degree sea water down the annuls displacing out 37 bbls of freeze protection from the tubing. Contiue circulating down the annuls circulating out 70 bbls of freeze protect at 128 gpm 84 psi. Caculated pump strokes indicate tubing parted at + - 1600'. Sea water weight in 8.5 ppg, Out 8.5 ppg. Monitor well. Rig down and blow down lines. Install BPV and test from below to 1000 psi. Note: Recovered 107 bbls of freeze protect. 05:00 - 07:30 2.50 WHSUR P DECOMP Nipple down tree and adapter flange. Remove tree and adapter flange from cellar. Inspect and verify hanger threads as 7" IJ4S. 07:30 - 10:30 3.00 BOPSU P DECOMP Nipple up BOP. 10:30 - 12:00 1.50 BOPSU P DECOMP Rig up up test equipment. 12:00 - 13:00 1.00 BOPSU P DECOMP Hook up kill line, Center up BOP stack, Install bell nipple. 13:00 - 17:30 4.50 BOPSU P DECOMP Pressure test BOP. 250 psi low, 3500 psi high. Chart and put in well file. Test witnessed by AOGCC representative John Crisp, Larry W urdeman Nabors Tool Pusher and Duncan Ferguson BP WSL. Rig down test equipment. 17:30 - 18:30 1.00 BOPSU P DECOMP Pull TWC valve from tubing hanger with DSM lubricator. Rig down lubricator. 18:30 - 21:30 3.00 FISH P DECOMP Rig up Schlumberger E-line unit. Run and cut 5 1/2" tubing with 4.15"jet cutter at 2145'. Rig down E-line unit. 21:30 - 22:30 1.00 PULL P DECOMP Pick up cross over and joint of 4" drill pipe. Back out lock down screws. Hanger pulled free with 80K Engage tubing hanger and pull tubing to the rig floor with 60K. 22:30 - 23:00 0.50 PULL P DECOMP Circulate 114 bbl seawater at 278 GPM with 60 psi. Recover 1 bbl diesel. Rig up Camco control line spooling unit. 23:00 - 00:00 1.00 PULL P DECOMP Lay down tubing hanger. Recover end of control line. POH and lay down 5 1/2" 17# L-80 A/B BTC-M tubing. Printed: 5/22/2006 11:57:50 AM BP EXPLORATION Operations Summary Report Page 2 of 13 Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name; From - To _t C-22 C-22 REENTE NABOB NABOB Hours ~ _ R+COM S ALASK S 7ES i Task ; PLET A DRI Code E LLING NPT Start I Rig Rig Phase Spud Date: 7/29/1982 : 4/27/2006 End: Release: 5/15/2006 Number: Description of Operations 4/30/2006 00:00 - 03:30 3.50 PULL P DECOMP POH and lay down 37 joints 5 1/2" 17# L-80 A/B BTC-M tubing and 28.85' of parted joint. Joints badly corroded and pitted. Top offish at 1611'. Recover 1/4" control line and 19 rubber clamps with pins and 2 SS bands. 03:30 - 04:30 1.00 PULL P DECOMP Rig down 5 1/2" tools and clear rig floor. 04:30 - 10:00 5.50 BOPSU P DECOMP Rig up to test BOP lower pipe rams. Pull wear bushing, install test plug and test joint, and attempt to test lower pipe rams. Test plug not holding, pull test plug and change out rubber seal on test plug, reinstall test plug and run in all lock down screws. Test lower pipe rams to 250 psi low 3500 psi high.Rig down test equipment and install wear bushing. 10:00 - 10:30 0.50 PULL N RREP DECOMP Replace reservoir cup for brake control on top drive. 10:30 - 13:00 2.50 FISH P DECOMP Make up BHA #1, 2-7/8" bull nose, Spear dressed with a 4.805" grapple, Tubing spear dressed with a with 5.048" grapple, Bumper jar, Fishing jar, Cross over sub, 9 6-3/8" spiral drill collars, Cross over sub. 13:00 - 15:00 2.00 FISH P DECOMP Run in the hole picking up 4" HT-40 drill pipe from pipe shed. Break circulation at 68 gpm 60 psi, tagging top of fish at 1615' DPM. Engauge fish with 5k down weight. Up weight 71 k, Slack off weight 75k. Monitor well bore. 15:00 -.16:00 1.00 FISH P DECOMP Pull out of the hole 16:00 - 17:00 1.00 FISH P DECOMP Stand back BHA 17:00 - 17:30 0.50 FISH P DECOMP Rig up 5-1/2" tubing equipment and lay down a 14.60' cut off joint of 5-1/2" 17# L-80 A/B BTC-M tubing. 17:30 - 18:00 0.50 FISH P DECOMP Rig up Schlumberger/Camco control line spooling unit 18:00 - 19:30 1.50 FISH P DECOMP POH and lay down 5-1/2" 17# L-8- A/B BTC-Mod tubing. Recovered 12 full joints, 1 SSSV and a 16.24' cut off. Recovered 5 rubber clamps with pins and 1 SS band. Recovered a total of 24 rubber clamps and 3 SS bands. 19:30 - 20:00 0.50 FISH P DECOMP Rig down 5-1/2" tubing equipment and Schlumberger/Camco control line spooling unit. 20:00 - 21:00 1.00 FISH P DECOMP Make up BHA #2, 2-7/8" bull nose, 5-1/2" spear pack off, Spear dressed with a 4.805" grapple, Tubing spear dressed with a 6-1/2" stop and a 5.048" grapple, Bumper jar, Fishing jar, Cross over sub, 9 6-318" drill collars. 21:00 - 23:30 2.50 FISH P DECOMP Run in the hole picking up 55 joints of 4" HT-40 drill pipe from pipe shed. Break circulation at 128 gpm 105 psi. Up weight 75k, Slack off weight 75k. Tagging top of fish at 2149" DPM. Inserting spear bottoming out on stop sub with 5k down weight. Pick up 20' to ensure tubing cut. Up 190k. Monitor well bore. 23:30 - 00:00 0.50 FISH P DECOMP Circulate 50 bbl "Safe Surf O" sweep around at 342 gpm 830 psi. 5/1/2006 00:00 - 02:00 2.00 FISH P DECOMP Continue to circulate 50 bbl "Safe Surf O" sweep around at 342 gpm 830 psi. Taking returns out to the cuttings tank until sea water returns clean up. Monitor well bore. Sea water weight in 8.6 ppg, Out 8.6 ppg Note: At Calculated bottoms up approx. 5 bbls of Paraffin / Diesel mix was observed. 02:00 - 04:00 2.00 FISH P DECOMP Pull out of the hole. Monitor well bore. 04:00 - 05:00 1.00 FISH P DECOMP Stand back drill collars. 05:00 - 06:00 1.00 FISH P DECOMP Break and lay down 16' cut off joint with spear. Rig up 5-1/2" tubing equipment. Printed: 5/22/2006 11:57:50 AM BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: ~ Date Name: ell Name: e: Name: From - To C-22 C-22 REENTE NABOR NABOR ~ Hours ~ R+COM S ALASK S 7ES Task PLET A DRI ~ Code - E LLING NPT ~ - Start I Rig Rig Phase ~ - Spud Date: 7/29/1982 : 4/27/2006 End: Release: 5/15/2006 Number: Description of Operations ---- 5/1/2006 06:00 - 16:00 10.00 FISH P DECOMP POH and lay down 144 joints 5 1/2" 17# L-80 A/B BTC-M tubing, 1 X-Nipple assy. and a 19.90' cut off joint. Recovered 1 rubber clamp. Wrap and apply steam to 13-3/8 X 9-5/8 casing spool, too warm pack off area. 16:00 - 16:30 0.50 FISH P DECOMP Rig down 5-1/2" tubing equipment. 16:30 - 21:00 4.50 BOPSU P DECOMP Pull wear bushing. Make up pack off running tool J into 9-5/8" pack off and attempt to retrive pack off, pulling 90k up. Pump hyd fluid thur test ports recovering approx a half cup of frimalite plastic, continue to work pack off from 5k to 130k to no avial. Remove and inspect lock down screws to ensure none busted. Remove and lay down pack off running tool. Install wear bushing. 21:00 - 21:30 0.50 BOPSU P DECOMP Run in the hole picking up 12 joints of 4" HT-40 HWDP from pipe shed. 21:30 - 22:30 1.00 BOPSU N RREP DECOMP Trouble shoot Iron Ruff Neck. Pipe spinners would not release / open to remove Iron Ruff Neck from pipe after pipe make up was complete. 22:30 - 00:00 1.50 BOPSU P DECOMP Continue running in the hole picking up 9 more joints 4" Ht-40 HWDP. Make up 9-5/8" storm packer and set storm packer with 20k string weight 8' below casing spool. Test 9-5/8" storm packer to 1000 psi. 5/2/2006 00:00 - 02:30 2.50 BOPSU P DECOMP Remove wear bushing. split BOP at casing spool and set BOPS back on stand. Remove casing spool with pack off. 02:30 - 07:00 4.50 BOPSU P DECOMP Remove lower half of 9-5/8" pack off from tubing spool. Retrieve seal and junk ring. Clean and prepare 9-5/8" casing stub for new pack off. Install new 9-5/8" pack off. Run in lock down screws and energize Y-Seal with plastic. Nipple up new tubing spool. Test to 5000 psi for 30 minutes. 07:00 - 09:30 2.50 BOPSU P DECOMP Nipple up BOP and bell nipple. 09:30 - 11:00 1.50 BOPSU P DECOMP Install test plug. Full body test BOP and tubing spool flange to 250 psi low 3500 psi high. Rig down test equipment, pull test plug and install wear bushing. 11:00 - 13:00 2.00 BOPSU P DECOMP Retreive storm packer and lay down. Pull out of the hole with 4" HT-40 HWDP. 13:00 - 19:30 6.50 DHB P DECOMP Rig up Schlumberger wireline and run in the hole with 8-1/2" gauge ring and junk basket to top of 5-1/2' tubing stump at 8698' ELM. Work thur tight area's at 4410' and 6700'. Pull out of the hole with 8-1/2" gauge ring and junk basket at surface found 8 pieces of plastic sheathing from encapsulated control line 6 to 10 inches long. Run in the hole with 8-1/2" gauge ring and junk basket to 5-1/2" tubing stump to 8698'. No tight hole encountered. Pull out of the hole with 8-1/2" gauge ring and junk basket. Found 1 piece of plastic sheathing from encapsulated control line 6 inches long. 19:30 - 23:00 3.50 DHB P DECOMP Make up EZSV, arm firing head and run in the hole setting EZSV at 8607' ELM. Pull out of the hole and rig down Schlumberger wireline. 23:00 - 00:00 1.00 DHB P DECOMP Test casing to 3500 psi, pressure drop after 15 minutes. Check surface equipment. Bleed pressure off and change out brass seal on kill line to BOP. 5/3/2006 00:00 - 01:00 1.00 DHB N RREP DECOMP Attempt to test 9-5/8" casing to 3500 psi, Observed small drip on 2" demco valve at stand pipe. Bleed pressure off. Inspect Printed: 5/22/2006 11:57:50 AM BP EXPLORATION Operations Summary Report Page 4 of 13 Legal Well Name: C-22 Common Well Name: C-22 Spud Date: 7/29/1982 Event Name: REENTER+COMPLETE Start: 4/27/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/15/2006 Rig Name: NABOBS 7ES Rig Number: Date !From - To i Hours Task Code NPT ( Phase Description of Operations 5/3/2006 00:00 - 01:00 1.00 DHB N RREP DECOMP body of 2" demco and replace O-Ring on bonnent of 2" demco valve. 01:00 - 01:30 0.50 DHB P DECOMP Test 9-5/8" casing to 3500 psi for 30 minutes. 01:30 - 06:00 4.50 STWHIP P WEXIT Pick up and make up Baker gen 2 whipstock, Starter mill, bit sub, String mill 1 joint of 5" HWDP, Float sub, Cross over sub, MW D, UBHO, Bumper sub, Cross over sub. 9 6-3/8" nm sprial drill collars, cross over sub, cross over sub, 21 4" HT- 40 hwdp. 06:00 - 07:00 1.00 STWHIP P WEXIT Run in the hole with 4" HT-40 drill pipe to 4330'. Shallow pulse test MW D at 2430' 455 gpm 955 psi. 07:00 - 13:30 6.50 STWHIP P WEXIT Run in the hole with 4" HT-40 drill pipe. Picking up 140 joints from the pipe shed. Filling drill pipe every 90 joints picked up. 13:30 - 14:30 1.00 STWHIP P WEXIT Install blower hose. Orient whipstock 57 degrees left of high side. Up weight 185k, Slack off weight 160k Tag EZSV at 8600' DPM, Set bottom anchor on whipstock with 15k down weight, Pick up to 195k to verify whipstock set, Shear brass lug with. 25k down weight. 14:30 - 15:30 1.00 STWHIP P WEXIT Displace well to 10.2 ppg milling fluid at 531 gpm 2125 psi. Mud weight in 10.2 ppg, Out 10.2 ppg. 15:30 - 00:00 8.50 STW HIP P WEXIT Milling 8.5" window from 8579' to 8596' + 6' of new formation to 8602'. Up weight 175k, Slack off weight 155k, Rotating weight 165k, 90 rpm, 4k rotary torque off bottom, 6-7k rotary torque on bottom, 526 gpm 2820 psi, WOB 2 to 10K. Top of Window at 8579'. Bottom of Window at 8596'. 5/4/2006 00:00 - 01:00 1.00 STW HIP P WEXIT Drilling new formation from 8602' to 8608'. Half of slide + 12' as per RP. Up weight 180k. Slack off weigh 150k. Rotating weight 160k. 6k off bottom torque. 8k to 10k torque on bottom. WOB 12 to 15k. 527 gpm 2775 psi. Recovered 228# of metal while milling 8-1/2" window 01:00 - 02:30 1.50 STWHIP P WEXIT Circulate Hi-Vis sweep surface to surface 550 gpm 2760 psi. Work wndow area with pumps on and off, Rotary on and off. With no obstructions. Monitor well bore. Pull out of the hole to 8523'. Mud weight in 10.2 ppg, Out 10.2 ppg. 02:30 - 03:30 1.00 STWHIP P WEXIT Rig up test equipment and perform FIT to equivalent mud weight of 11.5 ppg 525 psi. MD 8596', TVD 7766'. Rig down and blow down test equipment. 03:30 - 08:30 5.00 STWHIP P WEXIT Pump dry job and pull out of the hole with milling assembly. Stand back 4" HT-40 HWDP. 08:30 - 11:30 3.00 STWHIP P WEXIT Lay down 9 6-3/8" spiral drill collars, Bumper sub, UBHO, MW D, Float sub, String mill and Starter mill. Note: String mill full gauge. 11:30 - 13:00 1.50 STWHIP P WEXIT Pick up ported sub and wash /jet BOP stack to remove any metal from BOP ram cavities. 13:00 - 15:30 2.50 STWHIP P WEXIT Pick up BHA #4. 8-1/2" bit, 1.15 deg 6-3/4" PDM motor, NM string stb, ARC, MWD, NM string stb, 2 NM drill collar, MN string stb, NM spiral drill collar, Float sub, Hyd jar, cross over sub. and run in the hole with 23 joints of 4" HT-HWDP. Shallow pulse test MW D at 935' OK. 15:30 - 17:30 2.00 STW HIP P WEXIT Run in the hole picking up 57 joints of 4" HT-40 drill pipe 1788' from pipe shed. Printed: 5/22/2006 11:57:50 AM BP EXPLORATION Page 5 of 13 Operations Summary Report Legal Well Name: C-22 Common Well Name: C-22 Spud Date: 7/29/1982 Event Name: REENTER+COMPLETE Start: 4/27/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/15/2006 Rig Name: NABOBS 7ES Rig Number: Date From - To ~ Hours Task Code NPT Phase '~ Description of Operations 5/4/2006 15:30 - 17:30 2.00 STWHIP P 17:30 - 20:00 2.50 STWHIP P 20:00 - 21:00 1.00 STWHIP P W EXIT W EXIT Run in the hole from 2723' to 8458' with 4" HT-40 drill pipe. Filling drill pipe at 3774', 6640', 189 gpm 605 psi. W EXIT Orient bit 60 deg left of high side and Mad Pass with pumps off from 8458' to 8600' at 200' an hour. No problems going thru whipstock. INT1 Drilling 8-1/2" hole from 8608" to 8756'. TVD 7908'. Up weight 180k, Slack off weight 150k, Rotating weight 165k, Torque off bottom 4k, On bottom 5k, WOB 10 to 15k. 527 gpm 3275 psi. Mud weight in 10..2 ppg. Out 10.2 ppg. AST = 1.41 hr, ART = 0 hr, ADT = 1.41 hr. Jar 52.6 hr. INT1 Drilling 8-1/2" hole from 8756' to 8844'. TVD7966". Up weight 180k, Slack off weight 150k, Rotating weight 165k, Torque off bottom 4k, On bottom 5k, 90 rotary rpm, WOB 15k. 527 gpm 3275 psi. AST = 1.41 hr, ART = .25 hr, ADT = 1.66 hr. Jar 52.8 hr. RREP INTi Pull out of the hole from 8844' to 8550' to repair top drive RREP INT1 Replace busted dies in tong block for pipe grabber on Top Drive. RREP INT1 Orient bit 60 deg left of high side and run in the hole from 8550' to 8844'. No problems going thru whipstock. INT1 Drilling 8-1/2" hole from 8844' to 9290'. TVD 8400'. Up weight 185k, Slack off weight 165k, Rotating weight 165k, Torque off bottom 5k, On bottom 5 to 8k, 100 rotary rpm, WOB 15k. 509 gpm 3542 psi. AST = 1.01 hr, ART = 3.23 hr, ADT = 4.24 hr. Jar 57.10 hr. Survey Projected to bit 9290' MD, TVD 8400', 15.30 Deg, Azim 246.22 INT1 Circulate bottoms up for geo. Samples confrim casing point with 3% glauconitic sand. Mud weight in 10.2 ppg. Out 10.2 PPg• INT1 Monitor well bore. Short trip to top of 8-1/2" window at 8579'. No problems INT1 Slip and cut 150' of drilling line. INT1 Run in the hole from 8579' to 9290'. Washing the last 90' to bottom as a precautionary measure. No fill on bottom. INT1 Circulate 30 bbl high-vis sweep around at 509 gpm 3300 psi. Rotating and reciprocating pipe, 185k up weight, slack off weight 165k. Mud weight in 10.2 ppg. Out 10.2 ppg. INTi Pull out of the hole with 1 stand of 4" HT-40 drill pipe. Monitor well bore, drop 2-15/16" drift down 4" HT-40 drill pipe, pump dry job and pull out of the hole with 4" HT-40 drill pipe. INT1 Lay down BHA, 23 joints 4" HT-40 HWDP, Cross over sub, Hyd jar, Float sub, NM spiral dc, NM stab, 2 NM spiral dc, NM string stab, MW D, ARC, NM string stab, 1.15 deg PDM motor and bit. LNR1 Clear and clean floor. Rig up 7" casing equipment. LNR1 PJSM w/ all personal, Baker hand, WSL, Tour pusher. Monitor well bore. RIH w/ 7" 26# L-80 BTC-Mod intermediate liner. Note: Static loss rate 1/2 bbl hr. Lost 17 bbl to well bore. LNR1 Continue to RIH w/ 7" 26# L-80 BTC-Mod intermediate liner. 21:00 - 00:00 I 3.001 DRILL I P 5/5/2006 ~ 00:00 - 00:15 ~ 0.25 (DRILL ~ P 00:15 - 00:30 0.25 DRILL N 00:30 - 01:15 0.75 DRILL N 01:15 - 01:30 0.25 DRILL N 01:30 - 07:30 6.00 DRILL P 07:30 - 08:30 I 1.001 DRILL I P 08:30 - 09:30 1.00 DRILL P 09:30 - 11:00 1.50 DRILL P 11:00 - 12:00 1.00 DRILL P 12:00 - 13:00 1.00 DRILL P 13:00 - 17:30 I 4.501 DRILL I P 17:30 - 21:00 ~ 3.50 ~ DRILL ~ P 21:00 - 22:00 1.00 CASE P 22:00 - 00:00 2.00 CASE P 5/6/2006 ~ 00:00 - 00:30 ~ 0.50 ~ CASE ~ P Printed: 5/22/2006 11:57:50 AM BP EXPLORATION Operations Summary Report Page 6 of 13 Legal Well Name: C-22 Common Well Name: C-22 Spud Date: 7/29/1982 Event Name: REENTER+COMPLETE Start: 4/27/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/15/2006 Rig Name: NABOBS 7ES Rig Number: Date From - To ~ Hours Task Code NPT -- 5/6/2006 00:00 - 00:30 0.50 CASE P 00:30 - 01:00 0.50 CASE P 01:00 - 01:30 0.50 CASE P 01:30 - 07:30 6.001 CASE P 07:30 - 08:00 I 0.501 CASE I P 08:00 - 09:00 ~ 1.00 ~ CASE ~ P 09:00 - 09:30 0.50 CASE P 09:30 - 10:00 0.50 CASE P 10:00 - 11:00 ~ 1.001 CASE ~ P 11:00 - 12:00 I 1.00 I CASE I P 12:00 - 12:30 I 0.501 CASE I P 12:30 - 13:00 0.501 CASE I P 13:00 - 16:30 I 3.501 CASE I P Phase Description of Operations LNR1 Running a total of 21 joints. Baker loc the first 3 joints ran. Run 7" x 8-1/4" straight blade centralizer free floating on joints 1 and 2. Using Best-O- Life thread dope. Average make up toqure 9000 foot pounds. LNR1 Rig down 7" casing equipment. LNR1 Pick up Baker liner top packer /liner hanger assy and run in the hole with 1 stand 4" HT-40 drill. Circulate 1 liner volume at 124 gpm 92 psi. Up weight 55k, Slack off weight 55k. LNR1 Run in the hole with 7" 26# L-80 BTC-Mod intermediate liner and 4" HT- 40 drill pipe to top of window at 8579'. Filling every 10 stands on the run. LNR1 Circulate 1 liner volume at 167 gpm 444 psi. Up weight 165k, Slack off weight 145k. LNR1 Run in the hole with 7" 26# L-80 BTC-Mod intermediate liner and 4" HT- 40 drill pipe to 9290'. No problems thru out open hole. Lost 34 bbls mud while running 7" liner. LNR1 Pick up and make up cement head. LNR1 Circulate 1-1/2 times open hole volume. Staging pump up to 128 gpm 350 psi. LNR1 Pre Job Safety Melting w/ Baker and Dowell / Schlmberger. Test lines to 4500 psi. Mix and pump 35 bbl 12.0 ppg mud push. Mix and pump 42 bbls 15.8 ppg Class G at 3.9 bpm 1015 psi. Drop drill pipe wiper dart and kick it out with 5 bbls of water, saw the plug launch indicator trip. Switched to rig pumps to complete displacement of cement with 10.2 ppg mud. LNR1 Pump displacement at 4.7 bpm at 1400 psi. Slow to 3 bpm to see drill pipe wiper dart latch up with liner wiper plug but no indication seen. Increase rate to 4.7 bpm until 81 bbls displaced then slow to 2 bpm until plug bump. Plug bumped at 105 bbl, 1816 stks. Maintained full returns during cement job. Pressure up to 4000 psi to shear pins and set HMC liner hanger. Slack off liner weight + 50k# on liner hanger. Bleed off pressure to 0 psi. Rotate drill pipe / C2 running tool 12 turns to right. Pressure up on drill pipe to 1000 psi and pick up until pressure started to drop indicating packoff free of extension sleeve. Pick up additional ten feet above liner top to clear top of liner with rotating dog sub. Circulate 50 barrels down drill pipe to clear cement up annulus above liner running tools. Pick up and slack off 45k lbs. on dog sub 3 times. See 1st and 2nd sets of screws shear. Pick up and slack off final time while rotating dog sub down on liner top. Slack of 45k lbs. while rotating. Liner top packer set. CIP C~3 11:00 Top of 7" liner at 8402' LNR1 Pick up until tools free of liner top and circulate down drill pipe at 11.5 bpm with 10.2 ppg mud at 2250 psi. Saw CW100/Mud Push come back to surface. PH increased from 8.4 to 12.3. Seeing a trace of cement at surface. Continue pumping until mud clean at surface. Mud weight in 10.2 ppg. Out 10.2 ppg. LNR1 Pump dry job. Rig down and blow down lines. Lay down cement head. LNR1 Pull out of the hole with 4" HT-40 drill pipe and liner running tools. Printed: 5/22/2006 11:57:50 AM BP EXPLORATION Page 7 of 13 Operations Summary Report Legal Well Name: C-22 Common Well Name: C-22 Spud Date: 7/29/1982 Event Name: REENTER+COMPLETE Start: 4/27/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/15/2006 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To Hours ! Task ~ Code' NPT Phase 5/6/2006 16:30 - 17:00 0.50 CASE P LN R 1 17:00 - 17:30 0.50 CASE P LNR1 17:30 - 19:00 1.50 DRILL P PROD1 19:00 - 21:00 2.001 DRILL P PROD1 5/7/2006 102,00 - 03.30 1.50 DRILL P PROD1 03:30 - 05:00 I 1.501 DRILL I P I I PROD1 05:00 - 08:00 3.001 DRILL P PROD1 08:00 - 11:00 3.00 DRILL P PROD1 11:00 - 11:30 0.50 DRILL P PROD1 11:30 - 12:30 1.00 DRILL P PROD1 12:30 - 15:30 3.00 DRILL P PROD1 15:30 - 16:00 0.50 DRILL N FLUD PROD1 16:00 - 19:30 3.50 DRILL P PROD1 19:30 - 20:00 I 0.501 DRILL I N 20:00 - 00:00 4.00 DRILL P FLUD IPRODI Description of Operations Lay down liner running tools. Service Top Drive. Pick up BHA #5. Including Hughes 6-1/8" MX-18HDX, 1.69 deg short pak motor. Bypass sub, Flex lead collar, Impulse MWD, NM cross over sub, 3 NM flex dc, Circulating sub, Hyd jar = 191.17' Pick up 60 joints 1905' of 4" HT-40 drill pipe from pipe shed. Shallow pulse test MW D at 1143'. Run in the hole with BHA #5 to 6000'. Continue to run in the hole with BHA #5 from 6000' to 9136'.' Tag cement at 9136', wash stringers of cement from 9136' to top of 7" landing collar at 9206'. Up weight 175k, Slack off weight 140k, Rotating weight 160k, RPM 35, Torque 4k, WOB 5 to 10k, 218 gpm 1500 psi. Test 7" casing to 3500 psi. Record on chart for 30 minutes. Blow down lines. Drill out cement, plug, landing collar and float collar to 9280' Up weight 175k, Slack off weight 140k, Rotary weight 160k. 30 rpm, Torque 6 to 7k, 200 gpm 1234 psi. Displace wellbore to 8.4 ppg FloPro mud. Pumping 100 bbls H2O then 509 bbl of FloPro mud. 250 gpm 1180 psi. Drill out 7" 26# shoe at 9290' + 20' of new hole to 9310'. Perform FIT to equalivent mud weight of 10.0 ppg with 8.4 ppg mud at 700 psi. Directional drill 6-1/8" hole from 9310' to 9452'. 280 gpm 1350 psi. Due to excessive mud loss over shale shaker screens. Shaker screens were changed from 250/250/250/ 250 to 250/250/175/175 on two shakers and to 250/250/210/210 on the other two shakers. 70 bbls of FloPro mud was lost over a 3 hr time period. Directional drill 6-1/8" hole from 9452' to 9654'. 280 gpm 1550 psi. Circulate at 80 gpm 800 psi. Due to excessive mud loss over shale shaker screens. Shaker screens were changed to 250/250/210/ 210 to 250/250/165/165 on two shakers and to 250/230/230/230 and 250/250/210/210. Lost a total of 85 bbls of FloPro mud over a 3-1/2 hour time period. PROD1 Directional drill 6-1/8" hole from 9654' to 9870'. 8924' TVD. Up weight 188k, Slack off weight 153k, Rotating weight 168k, RPM 30, Torque 4k off bottom 5k on bottom, 30 RPM, WOB 20 to 50k, 280 gpm 1300 psi off bottom 1500 psi on bottom. Mud weight in 8.4 ppg. Out 8.4 ppg. AST= 4.67 hr ART= 2.18 hr ADT= 6.85 hr Jar = 6.85 Lost a total of 155 bbls of ProFlo Mud over shale shakers for last 24 hours. Used 4-1/2 drums of Screen Klen in 580' to aid in keeping fluid Printed: 5/22/2006 11:57:50 AM BP EXPLORATION Operations Summary Report Legal Well Name: C-22 Common Well Name: C-22 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 7ES Date From - To ~ Hours Task ~ Code NPT 5/7/2006 20:00 - 00:00 4.00 DRILL P 5/8/2006 00:00 - 08:00 8.00 DRILL P 08:00 - 09:00 09:00 - 11:00 1.00 I DRILL P 2.001 DRILL I P Start: 4/27/2006 Rig Release: 5/15/2006 Rig Number: Page 8 of 13 Spud Date: 7/29/1982 End: Phase '~ Description of Operations PROD1 from running of the end of shaker screens. PROD1 Directional drill 6-1/8" hole from 9870' to 10157'. 9004' TVD. Up weight 190k, Slack off weight 160k, Rotating weight 170k, RPM 30, Torque 4k off bottom 5k on bottom, WOB 20 to 30k, 275 gpm 1315 psi off bottom 1485 psi on bottom. Mud weight in 8.4 ppg. Out 8.4 ppg. AST= 4.67 hr ART= 2.18 hr ADT= 5.10 hr Jar = 11.95 hr Lost a total of 37 bbls of ProFlo Mud over shale shakers. PROD1 Pumping out of the hole from 10157' to 9845'. Up weight 185k. Slack off weight 150k. 279 gpm 1342 psi PROD1 Circulate a 9.2 ppg weighted sweep around at 278 gpm 1330 psi. Rotating and reciprocating pipe from 9767' to 9826' due to high dog legs below 9826'. Up weight 170k. Slack off weight 165k. Rotating weight 170k. Mud weight 8.4 ppg in. Out 8.4 PPg• Note: Sweep brought back no notable results. 11:00 - 11:30 0.50 DRILL P PROD1 Pull out of the hole from 9767' to 9266'. Drop dart and open circ sub with 2000 psi. Pump dry job. 11:30 - 15:30 4.00 DRILL P PROD1 Pull out of the hole from 9266' to 65'. Stand back NM flex drill collars. 15:30 - 16:30 1.00 DRILL P PROD1 Lay down BHA #5. Jar. Cir sub. NM stab. ShortPak 1.69 deg PDM motor and bit. 16:30 - 17:30 1.00 DRILL P PROD1 Down load MWD. Clean and clear rig floor. 17:30 - 19:00 1.50 DRILL P PROD1 Pick up BHA #6. Including Hyclog 6-1/8" DSX146HYGJNUW bit, 1.50 deg PDM motor. Circ sub, NM stab, Flex lead collar, Impulse MWD, ADN4 RA source. RIH with 3 NM flex drill collar. Pick up Jar. Shallow pulse test MWD. 19:00 - 23:00 4.00 DRILL P PROD1 Run in the hole to 9210'. (7" shoe at 9290') up weight 175k, Slack off weight 150K. Filling drill pipe every 30 stands ran. 23:00 - 00:00 1.00 DRILL P PROD1 Slip and cut 75' of drilling line. 5/9/2006 00:00 - 00:30 0.50 DRILL P PROD1 Service top drive. 00:30 - 02:00 1.50 DRILL P PROD1 Run in the from 9210' to 10130'. Taking 45k down weight at 10130', stage pumps up slowly to 250 gpm 1400 psi. Orient motor to high side and slide to bottom at 10157' w/no further problem. 02:00 - 06:30 4.50 DRILL P PROD1 Set depth with MWD and real time log up from 10155' to 9756' MD at 150' per hour. Up weight 180k. 260 gpm 1278 psi. 06:30 - 07:00 0.50 DRILL P PROD1 RIH (/9756' to 10155'. 07:00 - 23:00 16.00 DRILL P PROD1 Directionally drill 6-1/8" hole f/10155' MD/9006' TVD to 11122' MD/8998' TVD. Up wt. 190K, SO wt. 150K, Rot wt. 165K, 280 gpm, 1450 psi off, 1750 psi on, 60 rpm, 5K tq. off, 8K tq. on. Circ 45 vis, 10.6 ppg, sweep around C 280 gpm, 1525 psi. 5-10% increase in cutings over shakers. 23:00 - 00:00 1.00 DRILL P PROD1 Directionally drill 6-1/8" hole f/11122' MD/8998' TVD to 11153' MD/8998' TVD. Up wt. 190K, SO wt. 150K, Rot wt. 165K, 280 gpm, 1450 psi off, 1750 psi on, 60 rpm, 5K tq. off, 8K tq. on. ADT for 24 hrs. = 9.11 hrs. ART = 2.6 hrs. AST = 6.51 hrs. Footage f/24 hrs. = 998. Printed: 5/22/2006 11:57:50 AM BP EXPLORATION Page 9 of 13 Operations Summary Report Legal Well Name: C-22 Common Well Name: C-22 Spud Date: 7/29/1982 Event Name: REENTER+COMPLETE Start: 4/27/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/15/2006 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task ~ Code, NPT Phase Description of Operations 5/10/2006 00:00 - 05:00 5.00 DRILL P PROD1 Drill 6-1/8" hole directionally from 11153' MD/8998' TVD and TD well per geo at 11450' MD/8994' TVD. Up wt. 190K, SO wt. 150K, Rot wt. 165K, 280 gpm, 1450 psi off, 1750 psi on, 60 rpm, 5K tq. off, 8K tq. on. 05:00 - 06:00 1.00 DRILL P 06:00 - 08:00 2.00 DRILL P 08:00 - 08:30 0.50 DRILL P 08:30 - 10:00 1.50 DRILL P 10:00 - 11:30 1.50 DRILL P 11:30 - 13:30 2.00 DRILL P 13:30 - 15:00 1.50 DRILL P 15:00 - 19:00 4.00 DRILL P 19:00 - 20:30 1.50 DRILL P 21:00 - 22:00 1.00 CASE P 22:00 - 22:30 0.50 CASE P 22:30 - 00:00 1.501 CASE P 5/11/2006 00:00 - 02:30 2.50 CASE P 02:30 - 03:30 1.00 CASE P 03:30 - 07:30 4.00 CASE P 07:30 - 09:30 2.00 CASE P 09:30 - 10:30 1.00 CASE P 10:30 - 11:30 1.00 CASE P 11:30 - 13:00 I 1.501 CASE I P 13:00 - 14:00 I 1.001 CASE I P ADT for 24 hrs. = 2.37 hrs. ART = 1.65 hrs. AST = .72 hrs. Footage f/24 hrs. = 297. PRODi CBU @ 11,450 tt. TD. 276 gpm, 1450 psi. PROD1 Short trip to 7" shoe at 9290' w/no problems. PROD1 Service topdrive and clear rig floor. PROD1 RIH to TD at 11450' w/no problems. PROD1 Circulate sweep around. 10.6 ppg, 276 gpm, 1475 psi. No cuttings increase. PROD1 POH to to place circ. sub at 7" liner top at 8502'. PROD1 Drop dart to open circ. sub and CBU at 480 gpm, 1100 psi. Good cuttings returns over shakers. PROD1 Pump dry job, BD top drive, drop rabbit and POH to BHA. PROD1 PJSM on handling Schlumberger nukes. Pull nuke sources and LD BHA # 6. RUNPRD Clear floor and RU to run 4.5" 12.6 #IBT-M liner. RUNPRD PJSM w/all hands, WSL on liner handling and running. Discuss proper utilization of pipe skate. Discuss utilizing tugger line to bring all non standard OD or short lengths of pipe and equipment from pipe shed to floor. RUNPRD Baker-Lok shoe track and RIH to 665' w/4.5" 12.60# IBT-M liner. Check floats and till liner every 10 jts. while running in hole. RUNPRD RIH w/ a total of 56jts - 4.5" 12.6# liner + marker jt. and Baker ZXP/HMC liner top packer/liner hanger equipment. to 2341'. RUNPRD Circulate 1.5 liner volumes. RD 4.5" casing handling equipment. Clear floor. RU to RIH w/liner on 4" drill pipe. RUNPRD RIH w/4.5" liner on 4" drill pipe to shoe at 9290'. RUNPRD CBU at shoe staging pumps up as follows: 2.3 bpm at 190 psi, 2.9 bpm at 279 psi, 6 bpm at 486 psi. Losing mud to well bore. Slow pumps to 4 bpm at 350 psi and losses stop. Up wt. 160K, SO wt 140K. RUNPRD RIH f/shoe at 9290' to 11432'. Drift unused stands 89 through 95 from derrick. RUNPRD PU top drive head and cementing manifold and MU to a single. RUNPRD Tag bottom at 11450' and circulate 211 gpm, 725 psi. Reciprocate 20' strokes, Up wt. 180K, SO wt. 140K. PJSM while circulating w/Schlumberger, all hands, Baker rep, and WSL. Identify pressure and spill hazards. RUNPRD Pressure test to 4500 psi. Pump 25 bbls of CW 100 and stage pumps up as follows: 3 bpm, 542 psi, 14%flowline returns; 4 bpm, 600 psi, 18% flowline returns; 5 bpm, 705 psi, 20% flowline returns. Pump 35 bbls of 10 ppg Mudpush. Pump 59 bbls of 15.8 ppg class "G" cement w/Gasblok plus additives. Shut down and drop drill pipe wiper dart. Wash up lines to Tee at floor. Switch to rig pumps. Pump clean 35 bbl 8.4 ppg Flo Pro perf pill followed by old drilling mud and displace at 5 bpm. Reciprocate throughout job. Up wt. 180K, SO wt 140K. Printed: 5/222006 11:57:50 AM BP EXPLORATION Operations Summary Report Legal Well Name: C-22 Common Well Name: C-22 Event Name: REENTER+COMPLETE Start: 4/27/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/15/2006 Rig Name: NABOBS 7ES Rig Number: Date From - To ;Hours Task Code ! NPT Phase 5/11/2006 13:00 - 14:00 ~ 1.00 CASE ~ P ~ RUNPRD 14:00 - 14:30 ~ 0.50 ~ CASE ~ P 14:30 - 15:30 1.00 CASE P 15:30 - 16:00 0.50 CASE P 16:00 - 17:30 1.50 CASE P 17:30 - 22:00 4.50 CASE P 22:00 - 23:00 1.00 23:00 - 00:00 1.00 5/12/2006 00:00 - 04:00 4.00 04:00 - 04:30 0.50 04:30 - 06:00 1.50 06:00 - 13:30 7.50 13:30 - 16:30 3.00 16:30 - 17:00 I 0.50 P P N P P N P P RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD SFAL RUNPRD RUNPRD RUNPRD SFAL RUNPRD RUNPRD RUNPRD Page 10 of 13 Spud Date: 7/29/1982 End: Description of Operations Catch up w/plug and see pressure climb as cement is lifted from 400 psi to 700 psi. See drill pipe wiper dart catch liner wiper plug as pressure increased from 700 psi to 1600 psi and then dropped back to 800 psi when plugs sheared as expected from plug holder bushing. Pressure increased as cement was lifted from 800 psi to 1550 psi and plugs bumped landing collar as expected. Increase pressure to 3500 and slack off to 70K and confirm HMC liner hanger set. Hold pressure 3 minutes. Bleed pressure to zero and check floats. OK. CIP at 14:00 hrs. Pressure back up to 1000 psi and rotate string 15 turns to right at liner running tools to release tools from liner carry in sub. PU on string and see pressure loss from 1000 psi to 450 psi indicating packoff is free from extension sleeve while still lifting annular column of cement. Circulate 30 bbls. 5 bpm at 900 psi w/stinger at bottom of running tools below liner top to clean liner extension sleeve area and up annulus. Slow pump rate to 2 bpm 500 psi and slack off until rotating dog sub contacts extension sleeve. Slack off additional 50 K and see both sets of screws shear, indicating good set on liner top packer. PU to neutral weight and rotate at 5 rpms. Slack off 50K while rotating on rotating dog sub to work weight down to liner top and confirm liner top packer set. Repeat paker setting x 2. PU until stinger clear of liner top and CBU. Up wt. 160K indicating liner weight loss as expected. Pump 10 bpm, 1350 psi. See 10 bbls. cement back to surface. LD single jt. drill pipe w/TD cementing head. Displace well to clean 8.4 ppg seawater from liner top at 9107' to surface. 11.5 bpm, 1600 psi. Slack off to bring tool jt. to floor level. 175K Up wt. (indicating 10K-15K of over pull), was noticed when pulling off bottom. Driller notified WSL of overpull. Up weight dropped back to 165K after pulling away from liner top. Continue POH and LD liner running tools. WSL and Baker hand inspected tools and found that the liner wiper plug bushing had been damaged leaving 2.5" x 3" x 1/4" thick piece in the well. Pull wear bushing and rig up for BOP test. Test BOP. 250- psi low side and 3500 psi high side test pressure. Chuck Scheve w/AOGCC waived AOGCC attendance during BOP test. Test witnessed by NAD TP L. Toussant and BP WSL L. Anderson. Test plug started leaking. Attempt to reset plug with no sucess. Pull test plug and LD same. Drift and tally 2 7/8" PAC DP while mobilizing new test plug from Cameron. Test 4 1/2" x 7" x 9 5/8" casing 3500 psi / 30 mins. Good Test. Install new test plug. Con't with BOPE test. Hydril element failed during test. Change out Hydril element. RU test equipment and continue w/BOP test. 250 psi low pressure test, 3500 psi high pressure test. Witnessed by NAD TP -Jim Davidson and WSL -Lance Vaughan. AOGCC rep C. Scheave waived witness. RD test equipment and clear rig floor. Printed: 5/22/2006 11:57:50 AM BP EXPLORATION Page 11 of 13 Operations Summary Report Legal Well Name: C-22 Common Well Name: C-22 Spud Date: 7/29/1982 Event Name: REENTER+COMPLETE Start: 4/27/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/15/2006 Rig Name: NABOBS 7ES Rig Number: Date 5/12/2006 From - To !Hours Task 17:00 - 18:00 1.00 CLEAN 18:00 - 19:00 1.00 CLEAN 19:00 - 21:30 21:30 - 22:00 22:00 - 22:30 Code i NPT I Phase N N 2.50 CLEAN N 0.50 CLEAN N 0.50 CLEAN N 22:30 - 00:00 5/13/2006 00:00 - 01:30 01:30 - 02:30 02:30 - 03:30 03:30 - 05:00 1.50 CLEAN N 1.50 CLEAN N 1.00 CLEAN N 1.00 CLEAN N 1.50 CLEAN N 05:00 - 10:00 5.00 CLEAN N 10:00 - 11:00 1.00 CLEAN N 11:00 - 14:00 3.00 CLEAN N 14:00 - 14:30 0.50 CLEAN N 14:30 - 15:00 0.50 PERFO P 15:00 - 16:00 1.00 PERFOB~ P 16:00 - 17:30 1.50 PERFO P 17:30 - 18:00 0.50 PERFO~ P 18:00 - 19:30 1.50 PERFO P 19:30 - 00:00 4.50 PERFO P 5/14/2006 ~ 00:00 - 01:00 ~ 1.OOj PERFOB P 01:00 - 01:30 I 0.501 PERFOBI P 01:30 - 02:30 I 1.001 PERFOBI P 02:30 - 07:00 I 4.501 PERFOBI P Description of Operations DPRB CLEAN RU to run 2-7/8" PAC drill pipe. DPRB CLEAN PU dress/cleanout mill BHA # 7 consisting of 3.75" bladed mill to push possible junk in 4.5" liner to bottom, bumper sub and jars, 71 jts of 2-7/8" PAC drill pipe to top of 4.5" liner, XO, 5" string mill to clean ID of liner hanger and ZXP packer, liner top dressing mill to dress 4.5" liner top, XO to 4" HT and 4" HT drill pipe to surface. DPRB CLEAN PU and single in w/71 jts of 2-7/8" PAC drill pipe. DPRB CLEAN RD 2-7/8" PAC drill pipe handling equipment. DPRB CLEAN PU and MU liner top cleanout portion of BHA # 7 to 2-7/8" PAC drill pipe. DPRB CLEAN RIH w/4" HT-40 drill pipe stands to 4290'. DPRB CLEAN Continue RIH w/4" drill pipe to 4.5" liner top at 9107'. Tag liner top w/3.75" bladed mill on bottom of BHA #7 and see it take wt. to 5K#. Rotate off and drop through liner top w/no further trouble. Up wt. 155K, SO wt. 145K, Rot. wt 150K. DPRB CLEAN Continue to RIH w/ BHA # 7. Wash down last jt and tag. liner top w/liner top dress mill at 9107' and lower bladed junk mill at 11356'. Up wt. 180K, SO wt 150K, Rot wt 163K off, tq. off 3.5K. DPRB CLEAN Circulate at 250 gpm, 3200 psi and mill 4 inches from top of 4.5" liner top w/liner top dress mill. Pump 250 gpm, 3200 psi, rotate 50 rpm, tq. on 4.5K to 5.7K. DPRB CLEAN PU and CBU. See good indication of Flo-Pro pert pill and circulate until clean seawater to surface. Circulate 35 bbls. clean 8.4 ppg Flo-Pro pert pill to 4.5" liner and follow w/105 bbls. clean seawater. DPRB CLEAN POH to BHA # 7. MW 8.5 ppg. seawater. DPRB CLEAN LD upper liner top dress mill portion of BHA #7. DPRB CLEAN LD 2-7/8" PAC drill pipe. DPRB CLEAN LD lower dress mill portion of BHA # 7. Clear rig floor. OTHCMP PJSM w/Schlumberger, all hands, toolpusher, and WSL on gun handling procedures. OTHCMP RU equipment to run tubing conveyed perforating guns. OTHCMP PU 1251' of 2.50" 4SPF perforating guns and blanks, w/e-fire head, HDF fill sub, debris sub, and safety disconnect. OTHCMP RU to run 2-7/8" PAC drill pipe. OTHCMP PU 35 jts. of 2-7/8" PAC drill pipe and RIH. OTHCMP RIH w/4" drill pipe stands from derrick to 10000'. Slowed run in speed but saw no indication of entry into 7" liner top at 8402' or 4.5" liner top at 9106'. OTHCMP RIH w/4" drill pipe and space TCP guns out w/bottom shot at 11350'. OTHCMP Activate Schlumberger E-Fire firing head pressure sequence and perforate 4.5" liner sections per program w/4SPF Schlumberger 2506PJ charges as follows :10160' to 10410', 10670' to 11140', 11220' to 11350'. Immediate fluid loss of 16 bbls. 8.5 ppg seawater when guns activate. OTHCMP POH standing back drill pipe immediately after pert gun activation to 160' above top pert to 10000'. MW = 8.6 ppg seawater in and out. Monitor well. Losing 8.5 ppg seawater at 80 bph. OTHCMP POH w/TCP assembly laying down238 jts. of drill pipe. Fluid Printed: 5/22/2006 11:57:50 AM BP EXPLORATION Page 12 of 13 Operations Summary Report Legal Well Name: C-22 Common Well Name: C-22 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 7ES > >~ Date From - To ~ Hours i Task i Code ~ NPT Spud Date: 7/29/1982 Start: 4/27/2006 End: Rig Release: 5/15/2006 Rig Number: Phase Description of Operations 5/14/2006 02:30 - 07:00 4.50 PERFO P 07:00 - 08:00 1.00 PERFO P 08:00 - 08:30 0.50 PERFO P 08:30 - 11:00 2.50 PERFO P 11:00 - 12:00 1.00 PERFO P 12:00 - 13:30 1.50 PERFO P 13:30 - 16:30 3.00 PERFO P 16:30 - 17:00 0.50 17:00 - 19:00 2.00 19:00 - 19:30 ~ 0.50 19:30 - 00:00 I 4.50 5/15/2006 ~ 00:00 - 08:00 ~ 8.00 08:00 - 10:00 I 2.00 10:00 - 12:30 I 2.50 12:30 - 14:30 I 2.00 14:30 - 15:30 1.00 BOPSUFI P 15:30 - 17:30 2.00 BOPSUF~ P 17:30 - 20:00 2.50 WHSUR P 20:00 - 21:00 I 1.001 WHSUR I P 21:00 - 22:00 I 1.001 WHSUR I P OTHCMP loss 50 bph. OTHCMP RU 2-7/8" PAC handling equipment. LD 35 jts. of 2-7/8" PAC drill pipe. OTHCMP PJSM w/crew, Schlumberger, WSL on handling of TCP guns coming out of hole. Discuss procedures if unfired charges are encountered. OTHCMP LD TCP guns. All charges fired. All firing heads, carriers and blanks intact and undamaged. OTHCMP RD TCP running equipment. Clear rig floor. Monitor well. Losses 50 bph. 474 bbls 8.6 ppg seawater lost to hole since perfing completed at 02:30. OTHCMP RIH w/ remaining 40 stds of 4" HT-40 drill pipe from derrick. OTHCMP Monitor well. MW 8.6 ppg seawater in and out. POH laying down 120 jts. of 4" HT-40 drill pipe. RUNCMP Pull wear bushing and make successful dummy run w/hanger. RUNCMP RU Nabors 4.5" 13Cr 12.6 #VAM Top tubing handling equipment to include stabbing guide, compensator, tongs, and torque turn recording equipment. RUNCMP PJSM w/Baker, all hands, WSL. Discuss pipe skate safety and handling of the variable lengths encountered during completion process. Discuss good handling practices for VAM Top 13Cr tubing. RUNCMP RIH w/4.5" VAM Top 12.60# tubing to 2700'. 8.5 ppg. seawater fluid losses averaging 20 bbls/hr at 23:59. Loss of fluid for 12 hrs. = 113 bbls. Total fluid losses for 24 hrs. = 587 bbls. RUNCMP RIH w/4.5" 12.6# VAM Top completion. 211 in the hole. Losing 8.5 ppg. seawater at 20 bbls/hr. Total losses to 08:00 140 bbls. Up wt. 128K, SO wt. 118K. RUNCMP Stab WLEG into liner top extension sleeve and space out. PU landing joint and MU 13-5/8" x 7" tubing hanger x 4.5" VAM Top X-over to tubing. Land tubing hanger w/WLEG spaced out in liner top extension sleeve at 9115'. Run in lock down screws. RUNCMP Reverse circulate 288 bbls. corrosion inhibited seawater and follow w/173 bbls. clean seawater. Pump 3 bpm, 200 psi. RUNCMP Drop 1-7/8" ball and rod assembly to No-shear RHC plug installed in XN-Nipple at 9103'. Note: OD 2.125" w/1-3/8" fish neck. Pulling tool for ball and rod = 2" RB. Pulling tool for RHC-M = 4.5" GS/GR. When ball on seat pressure up to 3500 psi on tubing to set S-3 permanent packer. Hold 30 mins. f/tubing test. Bleed tubing psi to 1500 psi. Pressure annulus to 3500 psi. and hold for 30 mins. for annulus test. Bleed off psi on both sides. Pressure up on annulus and see the DCK valve shear at 2600 psi. Pump both ways to confirm shear. RUNCMP LD landing jt. RIH w/Two Way Check valve. Test ok to 1000 psi. f/below. RUNCMP ND BOP stack. RUNCMP NU adapter flange and pressure test to 5000 psi. NU tree and pressure test to 5000 psi. RUNCMP RU drill site maintenance and lubricate Two Way Check valve out. RD drill site maintenance. RUNCMP PJSM, RU Little Red Hot Oil Svc. and pressure test to 3500 Printed: 5/22/2006 11:57:50 AM Printed: 5/22/2006 11:57:50 AM i } ~~ ,~~. C-22A Su Report Date: 10-May-O6 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: C-PAD / C-22 Well: C-22 Borehole: C-22A UWUAPI#: 500292075801 Survey Name /Date: C•22A /May 10, 2006 Tort /AHD / DDI / ERD ratio: 291.821 ° / 4784.94 ft / 6.249 / 0.531 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaVLong: N 70.29765107, W 148.67308597 Location Grid NIE Y/X: N 5960214.000 ftUS, E 663847.000 ftUS Grid Convergence Angle: +1.24925758° ~o~ Schlumberger R Survey /DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 247.430° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 62.36 ft relative to MSL Sea Bed /Ground Level Elevation: 34.86 ft relative to MSL Magnetic Declination: 24.546° Total Field Strength: 57605.908 nT Magnetic Dip: 80.896° Declination Date: May 09, 2006 Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corr Mag North -> True North: +24.546° • Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft n n ft ft de oo ft ftUS ftUS Hlt U.UU U.UI Lyl.y3 -62.36 U.UU U.11 U.UU V.lb U.Ut) -U.14 U.UU b`J6U'L14.Ub 6t)J2546.Cb N /U.Zy/b51ZZ VV 14rS.U/JViS/Uy CB GYRO MS 95.00 0.17 291.93 32.64 95.00 0.21 0.15 0.30 0.11 -0.27 0.17 5960214.10 663846.72 N 70.29765138 W 148.67308820 195.00 0.48 218.08 132.64 195.00 0.68 0.66 0.69 -0.16 -0.67 0.46 5960213.82 663846.33 N 70.29765063 W 148.67309140 295.00 0.43 215.45 232.64 295.00 1.37 1.45 1.40 -0.80 -1.15 0.05 5960213.18 663845.87 N 70.29764889 W 148.67309526 395.00 0.38 214.82 332.63 394.99 1.96 2.16 2.08 -1.38 -1.55 0.05 5960212.59 663845.48 N 70.29764731 W 148.67309855 495.00 0.43 255.03 432.63 494.99 2.61 2.83 2.74 -1.75 -2.11 0.28 5960212.21 663844.93 N 70.29764630 W 148.67310302 595.00 0.62 241.57 532.63 594.99 3.52 3.75 3.62 -2.10 -2.94 0.23 5960211.84 663844.10 N 70.29764533 W 148.67310981 695.00 0.37 229.45 632.62 694.98 4.37 4.61 4.48 -2.57 -3.67 0.27 5960211.35 663843.39 N 70.29764406 W 148.67311565 795.00 0.17 172.17 732.62 794.98 4.71 5.05 4.87 -2.93 -3.89 0.31 5960210.99 663843.17 N 70.29764308 W 148.67311747 895.00 0.20 105.05 832.62 894.98 4.61 5.33 4.84 -3.12 -3.70 0.21 5960210.80 663843.37 N 70.29764256 W 148.67311594 995.00 0.15 314.10 932.62 994.98 4.53 5.51 4.75 -3.07 -3.63 0.34 5960210.85 663843.44 N 70.29764268 W 148.67 1095.00 0.32 169.28 1032.62 1094.98 4.64 5.77 4.90 -3.25 -3.67 0.45 5960210.67 663843.40 N 70.29764218 W 148.67 1195.00 0.38 155.43 1132.62 1194.98 4.68 6.38 5.17 -3.83 -3.48 0.10 5960210.09 663$43.61 N 70.29764061 W 148.6731 414 1295.00 0.20 91.92 1232.62 1294.98 4.51 6.84 5.21 -4.14 -3.17 0.34 5960209.79 663843.92 N 7029763977 W 148.67311161 1395.00 0.22 118.33 1332.62 1394.98 4.23 7.20 5.09 -4.24 -2.82 0.10 5960209.70 663844.27 N 70.29763950 W 148.67310883 1495.00 0.37 102.27 1432.62 1494.98 3.85 7.71 4.98 -4.39 -2.34 0.17 5960209.56 663844.76 N 70.29763907 W 148.67310491 1595.00 0.72 93.72 1532.61 1594.97 3.02 8.66 4.72 -4.50 -1.40 0.36 5960209.47 663845.70 N 70.29763877 W 148.67309728 1695.00 0.92 103.67 1632.60 1694.9.6 1.81 10.09 4.73 -4.73 0.01 0.24 5960209.27 663847.11 N 70.29763814 W 148.67308589 1795.00 0.92 89.35 1732.59 1794.95 0.42 11.69 5.17 -4.92 1.59 0.23 5960209.12 663848.70 N 70.29763764 W 148.67307307 1895.00 0.78 76.48 1832.58 1894.94 -1.00 13.16 5.65 -4.75 3.06 0.24 5960209.32 663850.16 N 70.29763810 W 148.67306121 1995.00 0.77 80.48 1932.57 1994.93 -2.33 14.52 6.26 -4.48 4.38 0.06 5960209.62 663851.48 N 70.29763884 W 148.67305049 2095.00 0.57 72.70 2032.56 2094.92 -3.48 15.68 6.95 -4.22 5.52 0.22 5960209.90 663852.61 N 70.29763955 W 148.67304127 2195.00 0.53 112.38 2132.56 2194.92 -4.30 16.61 7.70 -4.25 6.42 0.38 5960209.90 663853.51 N 7029763947 W 148.67303397 SurveyEditor Ver SP 1.0 BId( doc40x_56) C-22\C-22\C-22A\C-22A Generated 6/9/2006 11:30 AM Page 1 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude - Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS LGyS.UU U.// 1bU. 5b L'L:SL.bb LL`J4. `Jl -4,/1 1/./V t5./5 -b.Ul /.1 t3 U.425 5yC5ULUy.lS 25l):Si554.'Ly N /U .'Ly/19;5/:Sy W 1425.0/JU'1/C;S 2395.00 1.12 120. 70 2332.54 2394. 90 -5. 37 19.31 10.34 -6.09 8.35 0.59 5960208.09 663855.48 N 70 .29763443 W 148.67301835 2495.00 0.98 105. 08 2432.52 2494. 88 -6. 64 21.13 12.11 -6.81 10.02 0.32 5960207.41 663857.16 N 70. 29763246 W 148.67300486 2595.00 0.88 100. 95 2532.51 2594. 87 -7. 95 22.76 13.64 -7.18 11.60 0.12 5960207.07 663858.75 N 70. 29763145 W 148.67299207 2695.00 1.88 105. 42 2632.48 2694. 84 -9. 89 25.16 15.95 -7.76 13.93 1.01 5960206.54 663861.10 N 70. 29762986 W 148.67297316 2795.00 1.98 110. 58 2732.42 2794. 78 -12. 44 28.53 19.26 -8.81 17.13 0.20 5960205.57 663864.32 N 70. 29762701 W 148.67294726 2895.00 2.20 108. 92 2832.35 2894. 71 -15. 14 32.18 22.88 -10.04 20.56 0.23 5960204.42 663867.78 N 70. 29762365 W 148.67291946 2995.00 1.88 104. 30 2932.29 2994. 65 -17. 89 35.73 26.40 -11.06 23.97 0.36 5960203.46 663871.20 N 70. 29762085 W 148.67289189 3095.00 1.65 103. 57 3032.24 3094. 60 -20. 36 38.81 29.43 -11.81 26.96 0.23 5960202.78 663874.21 N 70. 29761882 W 148.67286769 3195.00 1.78 162. 48 3132.21 3194. 57 -21. 39 41.55 31.88 -13.63 28.83 1.69 5960201.01 663876.11 N 70. 29761385 W 148.67285257 3295.00 3.02 195. 88 3232.12 3294. 48 -19. 61 45.63 33.58 -17.64 28.57 1.82 5960196.99 663875.95 N 70. 29760288 W 148.67 2 3395.00 3.47 218. 58 3331.96 3394. 32 -15. 32 51.22 34.38 -22.54 25.96 1.35 5960192.03 663873.45 N 70. 29758949 W 148.67 3495.00 5.03 234. 98 3431.69 3494. 05 -8. 39 58.58 34.23 -27.42 20.49 1.96 5960187.03 663868.08 N 70. 29757616 W 148.67292009 3595.00 6.78 239. 15 3531.16 3593. 52 1. 73 68.86 35.02 -32.97 11.83 1.80 5960181.30 663859.54 N 70. 29756101 W 148.67299020 3695.00 9.08 240. 48 3630.19 3692. 55 15. 41 82.66 39.88 -39.88 -0.11 2.31 5960174.13 663847.76 N 70. 29754212 W 148.67308885 3795.00 12.32 240. 32 3728.44 3790. 80 33. 83 101.22 51.68 -49.05 -16.25 3.24 5960164.61 663831.83 N 70. 29751706 W 148.67321753 3895.00 14.18 241. 92 3825.77 3888. 13 56. 61 124.14 70.23 -60.10 -36.33 1.90 5960153.12 663812.00 N 70. 29748687 W 148.67338010 3995.00 16.57 243. 75 3922.19 3984. 55 83. 04 150.65 93.81 -72.18 -59.92 2.44 5960140.54 663788.67 N 70. 29745389 W 148.67357118 4095.00 19.20 244. 87 4017.35 4079. 71 113. 70 181.35 122.39 -85.47 -87.60 2.65 5960126.65 663761.29 N 70. 29741758 W 148.67379531 4195.00 20.87 246. 57 4111.29 4173. 65 147. 94 215.61 155.02 -99.54 -118.84 1.77 5960111.90 663730.37 N 70. 29737914 W 148.67404820 4295.00 22.68 248. 45 4204.16 4266. 52 185. 03 252.70 190.72 -113.70 -153.12 1.94 5960097.00 663696.41 N 70. 29734044 W 148.67432575 4395.00 24.68 249. 42 4295.73 4358. 09 225. 18 292.86 229.66 -128.12 -190.60 2.04 5960081.76 663659.25 N 70. 29730104 W 148.67462923 4495.00 26.62 249. 48 4385.87 4448. 23 268. 43 336.15 271.96 -143.32 -231.13 1.94 5960065.69 663619.07 N 70. 29725953 W 148.67495741 4595.00 29.63 250. 90 4474.06 4536. 42 315. 51 383.28 318.20 -159.26 -275.48 3.08 5960048.78 663575.08 N 70. 29721596 W 148.67531652 4695.00 32.20 252. 88 4559.84 4622. 20 366. 72 434.65 368.61 -175.20 -324.31 2.76 5960031.79 663526.61 N 70. 29717243 W 148.67571190 4795.00 34.98 254. 18 4643.14 4705. 50 421. 72 489.97 422.88 -190.86 -377.36 2.87 5960014.97 663473.91 N 70. 29712963 W 148.67614146 4895.00 36.33 250. 77 4724.40 4786. 76 479. 76 548.24 480.48 -208.43 -432.92 2.40 5959996.19 663418.76 N 70. 29708162 W 148.67659128 4995.00 38.37 246. 78 4803.90 4866. 26 540. 38 608.89 540.96 -230.43 -489.43 3.16 5959972.97 663362.75 N 70. 29702151 W 148.6770 79 5095.00 37.87 240. 93 4882.60 4944. 96 601. 94 670.59 602.62 -257.59 -544.80 3.64 5959944.61 663307.99 N 70. 29694730 W 148.67 5195.00 37.63 240. 78 4961.67 5024. 03 662. 76 731.81 663.72 -287.41 -598.27 0.26 5959913.64 663255.18 N 70. 29686584 W 148.67 1 5295.00 37.53 241. 67 5040.92 5103. 28 723. 38 792.80 724.62 -316.76 -651.72 0.55 5959883.13 663202.39 N 70. 29678562 W 148.67836280 5395.00 38.42 243. 05 5119.75 5182. 11 784. 67 854.33 786.13 -345.30 -706.23 1.23 5959853.41 663148.52 N 70. 29670765 W 148.67880413 5495.00 39.18 243. 35 5197.68 5260. 04 847. 16 916.99 848.78 -373.55 -762.16 0.78 5959823.95 663093.22 N 70. 29663045 W 148.67925696 5595.00 39.27 244. 02 5275.15 5337. 51 910. 26 980.22 912.02 -401.58 -818.84 0.43 5959794.69 663037.16 N 70. 29655385 W 148.67971588 5695.00 39.58 244. 52 5352.39 5414. 75 973. 67 1043.73 975.52 -429.15 -876.05 0.44 5959765.88 662980.57 N 70. 29647852 W 148.68017906 5795.00 39.73 244. 67 5429.38 5491. 74 1037. 41 1107.55 1039.33 -456.53 -933.70 0.18 5959737.26 662923.54 N 70. 29640371 W 148.68064577 5895.00 39.93 244. 78 5506.18 5568. 54 1101. 39 1171.60 1103.38 -483.88 -991.62 0.21 5959708.65 662866.24 N 70. 29632898 W 148.68111469 5995.00 39.82 244. 70 5582.92 5645. 28 1165. 43 1235.71 1167.48 -511.24 -1049.60 0.12 5959680.04 662808.87 N 70. 29625421 W 148.68158411 6095.00 39.85 244. 73 5659.71 5722. 07 1229. 42 1299.77 1231.54 -538.60 -1107.52 0.04 5959651.43 662751.56 N 70. 29617944 W 148.68205304 6195.00 39.48 244. 47 5736.69 5799. 05 1293. 17 1363.60 1295.36 -565.97 -1165.18 0.41 5959622.80 662694.52 N 70. 29610463 W 148.68251985 6295.00 39.03 244. 28 5814.13 5876. 49 1356. 35 1426.87 1358.64 -593.34 -1222.23 0.47 5959594.20 662638.08 N 70. 29602984 W 148.68298174 SurveyEditor Ver SP 1.0 Bld( doc40x_56) C-22\C-22\C-22A\C-22A Generated 6/9/2006 11:30 AM Page 2 of 5 Comments Measured Inclination Azimuth SulrSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude - Depth Section Departure ft de de n n ft ft ft tt ft de 100 ft ftUS ftUS Ei3yb. UU 3y. U"1 "144. L/ btiyl.til byb4.1/ 141y. L3 14tiy.tf4 14"Ll. lil -Ei"LU.ti/ -1'L/tf.yli U.U7 5ybyb(ib.ti4 (i(i'LSkSI.y/ N /U.[`J5`J5515 W 14tS.btS:i44U`Jif 6495. 00 39. 05 244. 27 5969.49 6031. 85 1482. 11 1552.82 1484. 59 -648.01 -1335.69 0.03 5959537. 07 662525.85 N 70 .29588043 W 148.68390029 6595. 00 38. 53 244. 17 6047.43 6109. 79 1544. 66 1615.47 1547. 23 -675.26 -1392.10 0.52 5959508. 60 662470.05 N 70 .29580597 W 148.68435698 6695. 00 37. 78 244. 20 6126.07 6188. 43 1606. 34 1677.24 1609. 01 -702.16 -1447.72 0.75 5959480. 50 662415.04 N 70 .29573244 W 148.68480721 6795. 00 37. 38 243. 72 6205.32 6267. 68 1667. 21 1738.23 1670. 00 -728.93 -1502.51 0.50 5959452. 54 662360.84 N 70 .29565927 W 148.68525081 6895. 00 36. 68 243. 88 6285.15 6347. 51 1727. 31 1798.45 1730. 22 -755.52 -1556.55 0.71 5959424. 78 662307.40 N 70 .29558660 W 148.68568826 6995. 00 35. 93 244. 18 6365.74 6428. 10 1786. 42 1857.66 1789. 43 -781.45 -1609.78 0.77 5959397. 70 662254.76 N 70 .29551574 W 148.68611917 7095. 00 35. 12 244. 35 6447.12 6509. 48 1844. 43 1915.77 1847. 53 -806.68 -1662.12 0.82 5959371. 33 662202.98 N 70 .29544678 W 148.68654289 7195. 00 34. 15 244. 15 6529.40 6591. 76 1901. 18 1972.60 1904. 37 -831.37 -1713.31 0.98 5959345. 54 662152.34 N 70. 29537930 W 148.68695730 7295. 00 34. 28 243. 97 6612.09 6674. 45 1957. 31 2028.83 1960. 60 -855.97 -1763.87 0.16 5959319. 84 662102.33 N 70. 29531207 W 148.68736664 7395. 00 33. 85 243. 67 6694.93 6757. 29 2013. 21 2084.84 2016. 61 -880.68 -1814.14 0.46 5959294. 04 662052.62 N 70. 29524452 W 148.687 7495. 00 33. 93 243. 97 6777.94 6840. 30 2068. 86 2140.60 2072. 37 -905.28 -1864.18 0.19 5959268. 36 662003.13 N 70. 29517728 W 148.6881 64 7595. 00 33. 60 243. 85 6861.08 6923. 44 2124. 34 2196.18 2127. 95 -929.72 -1914.10 0.34 5959242. 84 661953.76 N 70. 29511047 W 148.68858271 7695. 00 33. 48 243. 93 6944.43 7006. 79 2179. 48 2251.43 2183. 20 -954.04 -1963.71 0.13 5959217. 45 661904.69 N 70. 29504401 W 148.68898434 7795. 00 33. 18 244. 60 7027.98 7090. 34 2234. 35 2306.38 2238. 14 -977.90 -2013.21 0.47 5959192. 52 661855.74 N 70. 29497879 W 148.68938500 7895. 00 32. 58 245. 32 7111.96 7174. 32 2288. 58 2360.67 2292. 42 -1000.88 -2062.39 0.72 5959168. 47 661807.07 N 70 .29491598 W 148.68978314 7995. 00 32. 68 245. 17 7196.18 7258. 54 2342. 46 2414.59 2346. 33 -1023.46 -2111.36 0.13 5959144. 83 661758.61 N 70. 29485426 W 148.69017952 8095. 00 32. 52 245. 38 7280.42 7342. 78 2396. 30 2468.47 2400. 20 -1045.99 -2160.29 0.20 5959121. 24 661710.18 N 70 .29479265 W 148.69057567 8195. 00 32. 27 245. 67 7364.86 7427. 22 2449. 85 2522.04 2453. 76 -1068.19 -2209.05 0.29 5959097. 98 661661.92 N 70. 29473198 W 148.69097038 8295. 00 31. 65 246. 78 7449.70 7512. 06 2502. 77 2574.97 2506. 66 -1089.53 -2257.49 0.85 5959075. 59 661613.96 N 70. 29467363 W 148.69136247 CB GYRO MS 8395. 00 32. 42 248. 22 7534.47 7596. 83 2555. 81 2628.01 2559. 61 -1109.82 -2306.50 1.08 5959054. 24 661565.41 N 70. 29461816 W 148.69175917 Tie-In Survey 8495. 00 33. 22 250. 57 7618.51 7680. 87 2609. 96 2682.21 2613. 59 -1128.88 -2357.22 1.50 5959034. 08 661515.11 N 70. 29456604 W 148.69216981 TOW (Blind) 8579. 00 33. 74 252. 73 7688.58 7750. 94 2656. 17 2728.54 2659. 56 -1143.46 -2401.20 1.55 5959018. 55 661471.47 N 70 .29452617 W 148.69252581 BOW (Blind) 8596. 00 35. 29 248. 78 7702.59 7764. 95 2665. 78 2738.17 2669. 13 -1146.64 -2410.29 16.01 5959015. 17 661462.45 N 70. 29451748 W 148.69259937 End of Mill (Blind) 8608. 00 35. 29 248. 78 7712.38 7774. 74 2672. 71 2745.10 2676. 05 -1149.15 -2416.75 0.00 5959012. 52 661456.05 N 70 .29451062 W 148.69265169 Inc+Trend 8674. 94 30. 04 246. 25 7768.72 7831. 08 2708. 82 2781.22 2712. 11 -1162.91 -2450.14 8.10 5958998. 04 661422.97 N 70 .29447300 W 148.69292194 Inc+Trend 8768. 83 23. 41 241. 59 7852.54 7914. 90 2750. 92 2823.40 2754. 28 -1181.27 -2488.10 7.40 5958978. 86 661385.42 N 70 .29442281 W 148.69322923 MW D -Standard 8864. 99 23. 79 236. 00 7940.67 8003. 03 2788. 94 2861.87 2792. 54 -1201.21 -2520.99 2.36 5958958. 21 661352.98 N 70 .29436831 W 148.6 8959. 98 23. 34 242. 51 8027.75 8090. 11 2826. 48 2899.81 2830. 30 -1220.61 -2553.57 2.78 5958938. 10 661320.83 N 70 9 .29431528 W 148.69 9055. 15 22. 03 243. 64 8115.56 8177. 92 2863. 07 2936.51 2866. 99 -1237.24 -2586.29 1.45 5958920. 76 661288.49 N 70 .29426982 W 148.69 9152. 84 18. 69 246. i 5 8207.14 8269. 50 2897. 01 2970.49 2900. 96 -1251.70 -2617.03 3.53 5958905. 63 661258.07 N 70 .29423026 W 148.69427280 Last MW D -Standard 9216. 66 17. 11 246. 22 8267.86 8330. 22 2916. 62 2990.11 2920. 57 -1259.62 -2634.97 2.48 5958897. 32 661240.30 N 70. 29420861 W 148.69441805 MWD+IFR+MS 9319. 78 14. 56 246. 28 8367,06 8429. 42 2944. 75 3018.24 2948. 69 -1270.96 -2660.72 2.47 5958885. 43 661214.81 N 70. 29417762 W 148.69462651 9352. 35 9. 01 244. 92 8398.93 8461. 29 2951. 40 3024.89 2955. 34 -1273.69 -2666.79 17.06 5958882. 57 661208.80 N 70. 29417016 W 148.69467558 9385. 05 3. 61 238. 56 8431.42 8493. 78 2954. 98 3028.48 2958. 93 -1275.31 -2669.99 16.63 5958880. 88 661205.64 N 70. 29416572 W 148.69470148 9415. 35 0. 99 104. 65 8461,71 8524. 07 2955. 71 3029.39 2959. 68 -1275.87 -2670.55 14.37 5958880. 30 661205.09 N 70 .29416418 W 148.69470602 9447. 99 5. 01 81. 11 8494.30 8556. 66 2954. 10 3031.08 2958. 09 -1275.73 -2668.87 12.63 5958880. 49 661206.77 N 70 .29416459 W 148.69469241 9480. 35 8. 29 71. 30 8526.43 8588. 79 2950. 40 3034.82 2954. 42 -1274.76 -2665.26 10.69 5958881. 53 661210.36 N 70 .29416723 W 148.69466321 9511. 05 12. 48 66. 79 8556.62 8618. 98 2944. 87 3040.35 2948. 91 -1272.74 -2660.11 13.89 5958883. 66 661215.46 N 70 .29417275 W 148.69462154 9542. 80 16. 76 66. 61 8587.34 8649. 70 2936. 86 3048.36 2940. 90 -1269.57 -2652.75 13.48 5958886. 99 661222.74 N 70 .29418142 W 148.69456198 9575. 50 22. 31 66. 61 8618.15 8680. 51 2925. 93 3059.29 2929. 98 -1265.23 -2642.72 16.97 5958891. 55 661232.68 N 70 .29419328 W 148.69448078 SurveyEditor Ver SP 1.0 Bld( doc40x_56) C-22\C-22\C-22A\C-22A Generated 6/9/2006 11:30 AM Page 3 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude . Depth Section Departure ft de de ft ft ft ft ft ft ft de 00 ft ftUS ftUS 9606. 07 23. 40 65. 86 8646. 32 8708. 68 2914. 06 3071. 16 2918.11 -1260.45 -2631.86 3.69 5958896. 57 661243.44 N 70 .29420637 W 148.69439283 9638. 74 26. 24 63. 99 8675. 97 8738. 33 2900. 36 3084. 87 2904. 40 -1254.62 -2619.44 9.02 5958902. 66 661255.72 N 70 .29422229 W 148.69429235 9670. 85 30. 41 62. 33 8704. 22 8766. 58 2885. 18 3100. 11 2889. 18 -1247.73 -2605.86 t 3.22 5958909. 84 661269.15 N 70 .29424112 W 148.69418240 9701. 72 32. 66 60. 64 8730. 53 8792. 89 2869. 12 3116. 25 2873. 06 -1240.02 -2591.68 7.83 5958917. 86 661283.16 N 70 .29426221 W 148.69406762 9734. 10 34. 37 61. 48 8757. 53 8819. 89 2851. 35 3134. 13 2855. 21 -1231.37 -2576.03 5.47 5958926. 85 661298.61 N 70 .29428585 W 148.69394097 9766. 30 37. 30 62. 00 8783. 63 8845. 99 2832. 60 3152. 98 2836. 38 -1222.45 -2559.43 9.15 5958936. 13 661315.01 N 70 .29431024 W 148.69380657 9798. 12 41. 37 62. 66 8808. 24 8870. 60 2812. 51 3173. 14 2816. 23 -1213.09 -2541.57 12.86 5958945. 88 661332.67 N 70 .29433582 W 148.69366200 9830. 76 45. 20 63. 05 8831. 99 8894. 35 2790. 21 3195. 52 2793. 86 -1202.88 -2521.66 11.76 5958956. 51 661352.35 N 70 .29436372 W 148.69350083 9865. 19 49. 87 62. 01 8855. 23 8917. 59 2764. 91 3220. 91 2768. 49 -1191.16 -2499.13 13.74 5958968. 72 661374.61 N 70 .29439576 W 148.69331850 9893. 79 55. 06 61. 55 8872. 65 8935. 01 2742. 35 3243. 58 2745. 84 -1180.44 -2479.16 18.19 5958979. 88 661394.35 N 70 .29442508 W 148.69315682 9926. 25 60. 23 62. 42 8890. 02 8952. 38 2715. 06 3270. 99 2718. 46 -1167.57 -2454.95 16.09 5958993. 27 661418.26 N 70 .29446026 W 148.69 9956. 98 63. 98 61. 43 8904. 39 8966. 75 2688. 03 3298. 14 2691. 33 -1154.79 -2431.00 12.53 5959006. 57 661441.93 N 70 .29449520 W 148.692 0 9987. 69 68. 60 60. 73 8916. 74 8979. 10 2660. 09 3326. 25 2663. 28 -1141.19 -2406.39 15.19 5959020. 70 661466.23 N 70 .29453237 W 148.69256785 10020. 19 74. 14 59. 48 8927. 12 8989. 48 2629. 56 3357. 04 2632. 59 -1125.84 -2379.71 17.43 5959036. 63 661492.57 N 70. 29457432 W 148.69235185 10052. 76 79. 60 58. 46 8934. 51 8996. 87 2598. 20 3388. 75 2601. 05 -1109.50 -2352.54 17.04 5959053. 56 661519.37 N 70. 29461900 W 148.69213195 10085. 78 82. 22 58. 40 8939. 73 9002. 09 2566. 00 3421. 35 2568. 64 -1092.43 -2324.76 7.94 5959071. 23 661546.77 N 70 .29466565 W 148.69190711 10111. 23 87. 71 59. 80 8941. 96 9004. 32 2540. 93 3446. 69 2543. 43 -1079.42 -2303.02 22.26 5959084. 71 661568.23 N 70. 29470122 W 148.69173109 10140. 16 93. 92 61. 24 8941. 55 9003. 91 2512. 22 3475. 60 2514: 60 -1065.19 -2277.85 22.03 5959099. 48 661593.08 N 70. 29474011 W 148.69152736 10175. 45 96. 11 62. 76 8938. 47 9000. 83 2477. 23 3510. 76 2479. 50 -1048.68 -2246.81 7.54 5959116. 66 661623.74 N 70. 29478523 W 148.69127613 10203. 70 92. 90 63. 57 8936. 25 8998. 61 2449. 15 3538. 92 2451. 35 -1035.97 -2221.69 11.72 5959129. 91 661648.59 N 70. 29481997 W 148.69107273 10236. 40 90. 02 65. 48 8935. 41 8997. 77 2416. 51 3571. 60 2418. 67 -1021.92 -2192.18 10.57 5959144. 61 661677.78 N 70. 29485840 W 148.69083388 10268. 27 89. 23 68. 48 8935. 62 8997. 98 2384. 64 3603. 47 2386. 82 -1009.45 -2162.85 9.73 5959157. 71 661706.82 N 70. 29489247 W 148.69059647 10298. 28 87. 51 71. 62 8936. 48 8998. 84 2354. 68 3633. 47 2356. 95 -999.22 -2134.66 11.93 5959168. 55 661734.78 N 70 .29492045 W 148.69036824 10332. 42 87. 89 75. 74 8937. 85 9000. 21 2320. 78 3667. 58 2323. 25 -989.64 -2101.93 12.11 5959178. 85 661767.30 N 70. 29494665 W 148.69010328 10364. 26 88. 27 79. 04 8938. 91 9001. 27 2289. 44 3699. 40 2292. 21 -982.69 -2070.88 10.43 5959186. 47 661798.19 N 70 .29496565 W 148.68985191 10395. 15 88.75 82.80 8939. 72 9002.08 2259. 42 3730. 28 2262. 59 -977.82 -2040.39 12.27 5959192.00 10426. 34 88.99 88.23 8940. 33 9002.69 2229. 79 3761. 46 2233. 54 -975.38 -2009.31 17.42 5959195.12 10459. 49 88.17 92.44 8941. 15 9003.51 2199. 27 3794. 60 2203. 87 -975.57 -1976.18 12.93 5959195.65 10490. 49 90.12 98.18 8941. 62 9003.98 2171. 88 3825. 60 2177. 54 -978.44 -1945.33 19.55 5959193.45 10523. 09 92.08 98.96 8940. 99 9003.35 2143. 98 3858. 19 2151. 01 -983.30 -1913.11 6.47 5959189.30 10555. 06 92.49 99.32 8939. 72 9002.08 2116. 81 3890. 14 2125. 36 -988.37 -1881.57 1.71 5959184.91 10586. 28 91.74 98.30 8938. 57 9000.93 2090. 17 3921. 34 2100. 37 -993.15 -1850.74 4.05 5959180.81 10618. 81 92.32 96.17 8937. 41 8999.77 2061. 97 3953. 84 2073. 98 -997.25 -1818.49 6.78 5959177.42 10650. 62 92.11 95.77 8936. 18 8998.54 2034. 04 3985. 63 2047. 93 -1000.55 -1786.87 1.42 5959174.80 10681. 99 89.82 94.94 8935. 66 8998.02 2006. 33 4016. 99 2022. 19 -1003.48 -1755.65 7.76 5959172.56 10714. 21 89.54 94.93 8935. 83 8998.19 1977. 75 4049. 21 1995. 78 -1006.25 -1723.55 0.87 5959170.49 10746. 79 89.27 95.49 8936. 17 8998.53 1948. 93 4081. 79 1969. 35 -1009.21 -1691.10 1.91 5959168.24 10777. 82 90.40 94.21 8936. 26 8998.62 1921. 39 4112. 82 1944. 23 -10ti.83 -1660.19 5.50 5959166.29 10809. 37 90.43 94.60 8936. 03 8998.39 1893. 27 4144. 37 1918. 72 -1014.25 -1628.73 1.24 5959164.55 10841. 46 89.71 94.36 8935. 99 8998.35 1864. 69 4176. 46 1892. 98 -1016.76 -1596.74 2.37 5959162.74 661828.56 661859.57 661892.70 661923.60 661955.92 661987.56 662018.49 662050.81 662082.49 662113.77 662145.92 662178.42 662209.39 662240.88 662272.92 N 70.29497899 W 148.68960509 N 70.29498567 W 148.68935350 N 70.29498516 W 148.689 N 70.29497735 W 148.68 N 70.29496411 W 148,68 N 70.29495027 W 148.68831922 N 70.29493723 W 148.68806960 N 70.29492607 W 148.68780852 N 70.29491706 W 148.68755256 N 70.29490908 W 148.68729974 N 70.29490153 W 148.68703986 N 70.29489347 W 148.68677719 N 70.29488632 W 148.68652687 N 70.29487972 W 148.68627220 N 70.29487289 W 148.68601319 SurveyEditor Ver SP 1.0 Bld( doc40x_56) C-22\C-22\C-22A\C-22A Generated 6/9/2006 11:30 AM Page 4 of 5 Comments Measured Inclination Azimuth Sub-Sea NO ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude . Depth Section Departure ft de de n n ft ft ft ft ft de 100 ft ftUS ftUS 10572.72 89.61 92.60 8936.18 6998.54 1536.61 4207.72 1567.77 -1018.66 -1565.54 5.64 5959161.53 10904.92 90.54 89.99 8936.14 8998.50 1807.16 4239.92 1841.28 -1019.39 -1533.35 8.60 5959161.50 10937.07 90.78 87.69 8935.77 8998.13 1777.24 4272.07 1814.24 -1018.74 -1501.21 7.19 5959162.85 10968.16 90.57 87.44 8935.40 8997.76 1748.05 4303.15 1787.87 -1017.41 -1470.15 1.05 5959164.85 11000.74 90.40 87.63 8935.13 8997.49 1717.46 4335.73 1760.39 -1016.01 -1437.60 0.78 5959166.96 11033.10 90.57 89.19 8934.85 8997.21 1687.24 4368.09 1733.55 -1015.12 -140526 4.85 5959168.56 11063.72 90.06 88.58 8934.68 8997.04 1658.75 4398.71 1708.48 -1014.52 -1374.64 2.60 5959169.83 11095.29 89.13 87.94 8934.91 8997.27 1629.24 443028 1682.62 -1013.56 -1343.09 3.58 5959171.47 11127.76 88.49 87.49 8935.58 8997.94 1598.79 4462.74 1656.05 -1012.27 -1310.65 2.41 5959173.47 11158.17 90.84 88.90 8935.76 8998.12 1570.36 4493.15 1631.51 -1011.31 -1280.26 9.01 5959175.09 11195.21 90.26 91.73 8935.40 8997.76 1536.24 4530.19 1602.74 -1011.51 -1243.23 7.80 5959175.70 11222.92 90.36 92.16 893525 8997.61 1511.03 4557.90 1581.96 -1012.45 -1215.53 1.59 5959175.36 11254.58 90.88 92.28 8934.91 8997.27 1482.29 4589.56 1558.58 -1013.68 -1183.90 1.69 5959174.82 11292.29 90.64 94.04 8934.41 8996.77 1448.32 4627.26 1531.55 -1015.76 -1146.25 4.71 5959173.57 11319.33 90.57 93.22 8934.13 8996.49 1424.06 4654.30 1512.62 -1017.47 -1119.27 3.04 5959172.44 11350.57 90.36 94.04 8933.87 8996.23 1396.03 4685.54 1491.05 -1019.45 -1088.09 2.71 5959171.15 Last MWD+IFR+MS 11392.10 91.60 95.14 8933.16 8995.52 1359.09 4727.06 1463.44 -1022.77 -1046.70 3.99 5959168.73 TD (Projected) 11450.00 91.60 95.14 8931.54 8993.90 1307.85 4784.94 1426.51 -1027.96 -989.06 0.00 5959164.80 Survey Type: Definitive Survey NOTES: CB GYRO MS - (Camera-based gyro multishot --Traditional optically referenced gyro surveys run on wireline - including "level rotor" gyros and Sperry-Sun SU3. Replaces ex-BP "PGMS" model. ) INC + TREND - (Inclinometer + know n azi trend --Inclination only surveys in near-vertical hole-where formation dip and experie nce enables direction of drift to be predicted. Replaces ex-BP "Inclinometer (azimuth in known quadrant)" model. ) MWD-Standard - (MWD -Standard -- Measurement While Drilling with no (or no known) special corrections. The model allows for the fact that axial interference may marginally exceed the upper limit specified when the well is near horizontal east/west. MWD +IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Descriation: Surface : 4286 FSL 1524 FEL S19 T11 N R14E UM 5960214.00 663847.00 Tie-In : 4286 FSL 1524 FEL S19 T11 N R14E UM 5960214.05 663846.86 BHL : 3257 FSL 2516 FEL S19 T11 N R14E UM 5959164.80 662880.66 882304.15 N 70.29488//3 W 146.885/(iU59 662336.35 N 70.29486576 W 148.68549999 662368.46 N 70.29486755 W 148.68523979 662399.48 N 70.29487118 W 148.68498833 662431.99 N 70.29487502 W 148.68472482 662464.31 N 70.29487749 W 148.68446295 662494.90 N 70.29487914 W 148.68421511 662526.42 N 70.29488177 W 148.68395964 662558.82 N 7029488532 W 148.68369704 662589.18 N 7029488795 W 148.68345099 662626.21 N 70.29488741 W 148.68 662653.91 N 70.29488486 W 148.68 662685.57 N 70.29488152 W 148.682 4 662723.25 N 70.29487586 W 148.68236604 662750.26 N 70.29487119 W 148.68214757 662781.47 N 70.29486580 W 148.68189516 662822.92 N 70.29485674 W 148.68156008 662880.66 N 70.29484260 W 148.68109338 • SurveyEditor Ver SP 1.0 Bld( doc40x_56) C-22\C-22\C-22A\C-22A Generated 6/9/2006 11:30 AM Page 5 of 5 TREE = 6" CM1 WELLHEAD ` ACTUATOR = McEVOY OTIS KB. ELEV = 67.36' BF. ELEV = 34.86' KOP = 8580 Max Angle = Datum MD = 90 @ 10268' __ __ Datum TVDss = I 13-3/8" CSG, 72#, L-80, ID = 12.347" I C-22A fr L T 2209' 4-1/2" HES X NIPPLE, ID = 3.813" 2596' I~ 9-5/8" DV PKR I 2667' I Minimum ID = 3.725" @ 9103 XN Nipple @ 9103 ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3267 3267 3 MMG DOME RK 16 05/28/06 3 5434 5213 39 MMG SO RK 20 05!28/06 2 6930 6375 36 MMG DMY RK 0 05/15/06 1 8255 7478 32 MMG DMY RK 0 05/15!06 8402' BAKER HMC LINER HANGER, ZXP PKR W/ TBS 8579' BAKER WHIPSTOCK (TOP OF WINDOW) 9037' 4-1/2" HES X NIPPLE; ID = 3.812" 9-5/8" HES CIBP 8593' TUBING JET CUT 8700' TUBING SEAL ASSY 8741' 4-1 /2" OTIS X NIP, ID = 3.813" - 8826' 3-3/4" BKR DEPLOYMENT SLV, ID = 3.00" $$$g' ,,~~ t- ` TOP OF 3-112" SCAB LNR, ID = 2.992" 8869' ;. yF 9-518" CSG, 47#, L-80, ID = 8.681" 9314' .__ ~~ ; s _ `~ _ > ~ ~, Y~ ~ :7 - y ~~ ~. - ,F' 3-1 /2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" - 9994' ~ 1#' l?~ `'ice 3-1/2" LNR SHOE, MILLED ID = 2.70" _ 9974' K ~ ~` (CTD 02/05(97) ELMD ~~ s ` ' ~' PBTD 10200' ~ ' 7" LNR, 29#. L-80, .0371 bof, ID = 6.184" 10243' 9058' 4-112 X 7 BAKER S-3 PERM PKR; ID = 3.88" gOg2' 4-1/2" HES X NIPPLE; ID = 3.812" 9103' 4-112" HES XN NIPPLE; ID = 3.725 9115' 4-1/2" 12.6# 13CR-80, DRIFT ID = 3.833", 0.01522 BPF 9106' BAKER HMC LINER HANGER, ZXP PKR W/TBS 9290' 7" LNR, 26#, L-80, 0.03826 bpf, DRIFT ID = 6.151" 11364' PBTD 11450' 4-1/2" 12.6# L-80, DRIFTlD = 3.833", 0.01522 BPF DATE REV BY COMMENTS DATE REV BY COMMENTS 10!03105 STG SIDETRACK 05/15/06 LV Actual Completion 05(28/06 DAV/PJC GLV C.IO PRUDHOE BAY UNR WELL: G22A PERMff No: API No: 994' SNL & 1523' WEL, Sec. 19, T11N, R14E BP Exploration {Alaska) SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ....................: Prudhoe Bay Well ...................... C-22A API number ...............: 50-029-20758-01 Engineer .................: Hernandez Rig :.....................: Nabors 7ES STATE :...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ---- Permanent datum..........: Depth reference..........: GL above permanent.......: KB above permanent........ DF above permanent.......: ------------------ Mean Sea Level Driller's Pipe Tally 34.86 ft N/A Top Drive 62.36 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 82.03 degrees V"~ [(c)2006 IDEAL ID10 2C O1] - - 10-May-2006 07:23:48 Page 1 of 7 Spud date ................: 03-May-06 Last survey date.........: 10-May-06 Total accepted surveys...: 78 MD of first survey.......: 8495.00 ft MD of last survey........: 11450.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date ............: 02-May-2006 Magnetic field strength..: 57606.04 LAMA Magnetic dec (+E/W-).....: 24.56 degrees Magnetic dip .............: 80.90 degrees ----- MWD survey Reference Reference G ............... Reference H ..............: Reference Dip ............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 57606.00 LAMA 80.90 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.56 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.56 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • • SCHLUMBERGER Survey Report --- -------- ------ -- Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 1 8495.00 33.22 250.57 2 8579.00 33.74 252.73 3 8596.00 35.29 248.78 4 8608.00 35.29 248.78 5 8674.94 30.04 246.25 6 8768.83 23.41 241.59 7 8864.99 23.79 236.00 8 8959.98 23.34 242.51 9 9055.15 22.03 243.64 10 9152.84 18.69 246.15 11 9216.66 17.11 246.22 12 9319.78 14.56 246.28 13 9352.35 9.01 244.92 14 9385.05 3.61 238.56 15 9415.35 0.99 104.65 16 9447.99 5.01 81.11 17 9480.35 8.29 71.30 18 9511.05 12.48 66.79 19 9542.80 16.76 66.61 20 9575.50 22.31 66.61 21 9606.07 23.40 65.86 22 9638.74 26.24 63.99 23 9670.85 30.41 62.33 24 9701.72 32.66 60.64 25 9734.10 34.37 61.48 26 9766.30 37.30 62.00 27 9798.12 41.37 62.66 28 9830.76 45.20 63.05 29 9865.19 49.87 62.01 30 9893.79 55.06 61.55 [(c}2006 IDEAL ID10 2C O1] Course length (ft) 0.00 84.00 17.00 12.00 66.94 93.89 96.16 94.99 95.17 97.69 63.82 103.12 32.57 32.70 30.30 32.64 32.36 30.70 31.75 32.70 30.57 32.67 32.11 30.87 32.38 32.20 31.82 32.64 34.43 28.60 TVD depth (f t) 7680.87 7750.94 7764.94 7774.74 7831.07 7914.90 8003.03 8090.11 8177.92 8269.49 8330.22 8429.42 8461.29 8493.78 8524.06 8556.65 8588.79 8618.98 8649.70 8680.50 8708.67 8738.32 8766.58 8792.89 8819.88 8845.99 8870.59 8894.35 8917.59 8935.01 10-May-2006 07:23:48 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) -2490.98 -1128.88 -2357.22 -2536.55 -1143.46 -2401.20 -2545.99 -1146.64 -2410.29 -2552.74 -1149.15 -2416.75 -2587.71 -1162.91 -2450.13 -2627.85 -1181.27 -2488.10 -2663.18 -1201.20 -2520.98 -2698.14 -1220.61 -2553.56 -2732.85 -1237.24 -2586.28 -2765.30 -1251.70 -2617.02 -2784.17 -1259.62 -2634.97 -2811.24 -1270.96 -2660.72 -2817.63 -1273.69 -2666.78 -2821.02 -1275.31 -2669.98 -2821.65 -1275.87 -2670.54 -2819.97 -1275.73 -2668.86 -2816.26 -1274.76 -2665.26 -2810.88 -1272.74 -2660.11 -2803.16 -1269.57 -2652.75 -2792.62 -1265.23 -2642.72 -2781.20 -1260.44 -2631.85 -2768.10 -1254.62 -2619.44 -2753.69 -1247.73 -2605.86 -2738.58 -1240.02 -2591.67 -2721.88 -1231.37 -2576.03 -2704.20 -1222.45 -2559.42 -2685.21 -1213.09 -2541.56 -2664.08 -1202.88 -2521.65 -2640.15 -1191.16 -2499.13 -2618.88 -1180.44 -2479.15 Pa Total displ (ft) 2613.59 2659.56 2669.13 2676.04 2712.10 2754.27 2792.53 2830.29 2866.99 2900.96 2920.57 2948.69 2955.34 2958.92 2959.67 2958.09 2954.42 2948.91 2940.90 2929.98 2918.11 2904.40 2889.17 2873.05 2855.21 2836.38 2816.23 2793.86 2768.48 2745.84 ~e 2 of At Azim (deg) 244.41 244.54 244.56 244.57 244.61 244.60 244.52 244.45 244.43 244.44 244.45 244.47 244.47 244.47 244.46 244.45 244.44 244.43 244.42 244.42 244.41 244.41 244.41 244.43 244.45 244.47 244.48 244.50 244.52 244.54 7 DLS Srvy (deg/ tool 100f) type 0.00 TIE IN POINT 1.55 BP_BLIND 16.01 BP_INC+TREND 0.00 BP_BLIND 8.10 BP_INC+TREND 7.40 BP_INC+TREND 2.36 BP_MWD 2.78 BP_MWD 1.45 BP_MWD 3.53 BP MWD 2.48 BP_MWD 2.47 BP_MWD+IFR+MS 17.06 BP_MWD+IFR+MS 16.63 BP_MWD+IFR+MS 14.37 BP_MWD+IFR+MS 12.63 BP_MWD+IFR+MS 10.69 BP_MWD+IFR+MS 13.89 BP_MWD+IFR+MS 13.48 BP_MWD+IFR+MS 16.97 BP_MWD+IFR+MS 3.69 BP_MWD+IFR+MS 9.02 BP_MWD+IFR+MS 13.22 BP_MWD+IFR+MS 7.83 BP_MWD+IFR+MS 5.47 BP_MWD+IFR+MS 9.15 BP_MWD+IFR+MS 12.86 BP_MWD+IFR+MS 11.76 BP_MWD+IFR+MS 13.74 BP_MWD+IFR+MS 18.19 BP_MWD+IFR+MS ~~ SCHLUMBERGER Survey Report 10-May-2006 07:23:48 Page 3 of 7 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 31 9926.25 60.23 62.42 32 9956.98 63.98 61.43 33 9987.69 68.60 60.73 34 10020.19 74.14 59.48 35 10052.76 79.60 58.46 36 10085.78 82.22 58.40 37 10111.23 87.71 59.80 38 10140.16 93.92 61.24 39 10175.45 96.11 62.76 40 10203.70 92.90 63.57 41 10236.40 90.02 65.48 42 10268.27 89.23 68.48 43 10298.28 87.51 71.62 44 10332.42 87.89 75.74 45 10364.26 88.27 79.04 46 10395.15 88.75 82.80 47 10426.34 88.99 88.23 48 10459.49 88.17 92.44 49 10490.49 90.12 98.18 50 10523.09 92.08 98.96 51 10555.06 92.49 99.32 52 10586.28 91.74 98.30 53 10618.81 92.32 96.17 54 10650.62 92.11 95.77 55 10681.99 89.82 94.94 56 10714.21 89.54 94.93 57 10746.79 89.27 95.49 58 10777.82 90.40 94.21 59 10809.37 90.43 94.60 60 10841.46 89.71 94.36 [(c)2006 IDEAL ID10 2C O1] Course length (ft) 32.46 30.73 30.71 32.50 32.57 33.02 25.45 28.93 35.29 28.25 32.70 31.87 30.01 34.14 31.84 30.89 31.19 33.15 31.00 32.60 31.97 31.22 32.53 31.81 31.37 32.22 32.58 31.03 31.55 32.09 TVD depth (ft) 8952.37 8966.75 8979.09 8989.47 8996.87 9002.08 9004.32 9003.91 9000.82 8998.60 8997.77 8997.98 8998.83 9000.20 9001.27 9002.07 9002.69 9003.51 9003.97 9003.35 9002.07 9000.92 8999.77 8998.54 8998.01 8998.19 8998.53 8998.62 8998.39 8998.35 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) -2593.13 -1167.57 -2454.95 -2567.63 -1154.79 -2430.99 -2541.38 -1141.19 -2406.39 -2512.82 -1125.84 -2379.70 -2483.65 -1109.50 -2352.54 -2453.77 -1092.43 -2324.76 -2430.44 -1079.42 -2303.01 -2403.54 -1065.19 -2277.85 -2370.51 -1048.68 -2246.81 -2343.87 -1035.97 -2221.68 -2312.69 -1021.91 -2192.18 -2281.92 -1009.45 -2162.85 -2252.58 -999.22 -2134.66 -2218.84 -989.64 -2101.92 -2187.13 -982.69 -2070.87 -2156.26 -977.82 -2040.39 -2125.14 -975.38 -2009.31 -2092.36 -975.57 -1976.18 -2062.20 -978.44 -1945.33 -2030.96 -983.30 -1913.10 -2000.43 -988.37 -1881.56 -1970.56 -993.15 -1850.73 -1939.19 -997.24 -1818.48 -1908.34 -1000.55 -1786.87 -1877.82 -1003.48 -1755.64 -1846.42 -1006.25 -1723.54 -1814.70 -1009.21 -1691.10 -1784.44 -1011.83 -1660.18 -1753.63 -1014.25 -1628.73 -1722.29 -1016.76 -1596.74 Total displ (f t) 2718.46 2691.33 2663.27 2632.59 2601.04 2568.64 2543.43 2514.60 2479.49 2451.35 2418.67 2386.82 2356.95 2323.24 2292.20 2262.59 2233.54 2203.87 2177.53 2151.01 2125.36 2100.37 2073.98 2047.93 2022.19 1995.78 1969.34 1944.22 1918.71 1892.98 At Azim (deg) 244.56 244.59 244.63 244.68 244.75 244.83 244.89 244.94 244.98 245.00 245.01 244.98 244.92 244.79 244.61 244.39 244.11 243.73 243.30 242.80 242.29 241.78 241.26 240.75 240.25 239.72 239.17 238.64 238.09 237.51 DLS Srvy (deg/ tool 100f) type 16.09 BP_MWD+IFR+MS 12.53 BP_MWD+IFR+MS 15.19 BP_MWD+IFR+MS 17.43 BP_MWD+IFR+MS 17.04 BP_MWD+IFR+MS 7.94 BP_MWD+IFR+MS 22.26 BP_MWD+IFR+MS 22.03 BP_MWD+IFR+MS 7.54 BP_MWD+IFR+MS 11.72 BP MWD+IFR+MS 10.57 BP_MWD+IFR+MS 9.73 BP_MWD+IFR+MS 11.93 BP_MWD+IFR+MS 12.11 BP_MWD+IFR+MS 10.43 BP_MWD+IFR+MS 12.27 BP_MWD+IFR+MS 17.42 BP_MWD+IFR+MS 12.93 BP_MWD+IFR+MS 19.55 BP_MWD+IFR+MS 6.47 BP_MWD+IFR+MS 1.71 BP_MWD+IFR+MS 4.05 BP_MWD+IFR+MS 6.78 BP_MWD+IFR+MS 1.42 BP_MWD+IFR+MS 7.76 BP_MWD+IFR+MS 0.87 BP_MWD+IFR+MS 1.91 BP_MWD+IFR+MS 5.50 BP_MWD+IFR+MS 1.24 BP_MWD+IFR+MS 2.37 BP_MWD+IFR+MS SCHLUMBERGER Survey Report 10-May-2006 07:23:48 Page 4 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy ## depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (f t) (ft) (f t) (ft) (ft) (ft) (deg) 100f) type 61 10872.72 89.61 92.60 31.26 8998.54 -1691.65 -1018.66 -1565.53 1867.77 236.95 5.64 BP _MWD+IFR+MS 62 10904.92 90.54 89.99 32.20 8998.50 -1659.88 -1019.39 -1533.35 1841.28 236.38 8.60 BP _MWD+IFR+MS 63 10937.07 90.78 87.69 32.15 8998.13 -1627.96 -1018.73 -1501.21 1814.23 235.84 7.19 BP _MWD+IFR+MS 64 10968.16 90.57 87.44 31.09 8997.76 -1597.02 -1017.41 -1470.15 1787.87 235.31 1.05 BP _MWD+IFR+MS 65 11000.74 90.40 87.63 32.58 8997.48 -1564.59 -1016.01 -1437.60 1760.39 234.75 0.78 BP _MWD+IFR+MS 66 11033.10 90.57 89.19 32.36 8997.21 -1532.43 -1015.12 -1405.25 1733.55 234.16 4.85 BP _MWD+IFR+MS 67 11063.72 90.06 88.58 30.62 8997.04 -1502.03 -1014.52 -1374.64 1708.47 233.57 2.60 BP_ MWD+IFR+MS 68 11095.29 89.13 87.94 31.57 8997.26 -1470.65 -1013.56 -1343.09 1682.61 232.96 3.58 BP_ MWD+IFR+MS 69 11127.76 88.49 87.49 32.47 8997.94 -1438.34 -1012.27 -1310.65 1656.04 232.32 2.41 BP_ MWD+IFR+MS 70 11158.17 90.84 88.90 30.41 8998.12 -1408.11 -1011.31 -1280.26 1631.50 231.69 9.01 BP_ MWD+IFR+MS 71 11195.21 90.26 91.73 37.04 8997.76 -1371.47 -1011.51 -1243.22 1602.74 230.87 7.80 BP_ MWD+IFR+MS 72 11222.92 90.36 92.16 27.71 8997.61 -1344.17 -1012.45 -1215.53 1581.95 230.21 1.59 BP_ MWD+IFR+MS 73 11254.58 90.88 92.28 31.66 8997.27 -1313.01 -1013.68 -1183.90 1558.57 229.43 1.69 BP_ MWD+IFR+MS 74 11292.29 90.64 94.04 37.71 8996.77 -1276.02 -1015.76 -1146.25 1531.55 228.45 4.71 BP_ MWD+IFR+MS 75 11319.33 90.57 93.22 27.04 8996.48 -1249.53 -1017.47 -1119.26 1512.61 227.73 3.04 BP_ MWD+IFR+MS 76 11350.57 90.36 94.04 31.24 8996.23 -1218.93 -1019.45 -1088.09 1491.04 226.87 2.71 BP_ MWD+IFR+MS 77 11392.10 91.60 95.14 41.53 8995.52 -1178.40 -1022.77 -1046.70 1463.43 225.66 3.99 BP MWD+IFR+MS 78 11450.00 91.60 95.14 57.90 8993.90 -1122.03 -1027.96 -989.05 1426.51 223.90 0.00 P rojection to TD [(c)2006 IDEAL ID10 2C Ol] ~,: ~. ~ ~ 1 g ~ ~ ~ ~ n~ ~ ~ ~ y ~ $~ S ~ ~ y d ~ ? ~ ~ ~ ~ ;, ~ ~ ± ~ ,~' ~ r ~ ,~, , ~ ¢~ FRANK H. MURKOWSKI, GOVERNOR ~ ~ t ~~~~ ~,~~~++ 1 ~-7~ O~ ~ GA5 ~~ 333 W. T" AVENUE, SUITE 100 CO1~T5ERQA'1`IO1~T COMi~II55IO1~T ~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU C-22A BP Exploration (Alaska) Inc. Permit No: 206-039 Surface Location: 994' FNL, 1523' FEL, SEC. 19, T 11 N, R 14E, UM Bottomhole Location: 1990' FNL, 2927' FEL, SEC. 19, T 11 N, R 14E, UM Dear Mr. Wesley: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). halrman DATED this day of March, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ' ~_ ,~ ~~' ALAS~IL AND GAS CONSERVATION COMMI~N ~(2~' PERMIT TO DRILL 20 AAC 25.005 ,~;-' ~ 7 2006 ~. ~."~ ~.Qf)3 1SSlQ1~ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is propo aa $$ ^ Coalbed Methane ^ Gas Hyd~Tes ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: o` PBU C-22As~$' 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11075 TVD 9009 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 994' FNL 1523' FEL SEC 19 T11 N R14E UM ~ 7. Property Designation: ADL 028305 Pool , , . , , , Top of Productive Horizon: 2004' FNL, 3728' FEL, SEC. 19, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: April 7, 2006 Total Depth: 1990' FNL, 2927' FEL, SEC. 19, T11 N, R14E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: 23,000 4b. Location of Well (State Base Plane Coordinates): Surface: x-663847 y-5960214 Zone-ASP4 10. KB Elevation plan (Height aboveGL): 61.68 feet 15. Distance to Nearest well within Pool: 1,000 16. Deviated Wells: Kickoff Depth: 8580 feet Maximum Hole Angle: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3673 Surface: 2835 8. Casi P ram: dons T - Settln th -.B ottom Qu ofiCement, c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M 851' 8430' 7627' 9281' 8379' 27 cu ft Class'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1945' 9130' 8235' 11075' 9009' 81 cu ft Class 'G' 19. PRESE NT'WELL CONDITION S UMMARY (To be completed f or Redrill' and Re-entry Operations) Total Depth MD (ft): 10250 Total Depth TVD (ft): 9192 Plugs (measured): 8826 Effective Depth MD (ft): 8826 Effective Depth TVD (ft): 7957 Junk (measured): None Casin Len h Size Cement Volume MD TVD Conductor /Structural 110' 20" x 30" cu ds Concrete 110' 110' Surface 2667' 13-3/8" 767 cu ft Arcticset II 2667' 2667' Intermediate 9314' 9-5/8" 1285 cu ft Class 'G', 130 cu ft AS I 9314' 8367' Liner 1416' 7" 76 cu ft Class 'G' 8827' - 10243' 7958' - 9185' cab Liner 1108' 3-1/2" 124 cu ft Class 'G' 8866' - 9974' 7990' - 8944' Perforation Depth MD (ft): 9994' - 10063' Perforation Depth TVD (ft): 8962' - 9024' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ® Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Printed Name ave Wesley Si nature ~ ~F ~ ~ ~- ~'~ Contact Barbara Easley, 564-5126 Title Senior Drilling Engineer Prepared By Name/Nurt~er. Phone 564-5153 Date~~/~~°~`' Terrie Hubble, 56a-4628 Commission Use Onl Permit To Drill Number: Z ©~ -~ API Number: 50- 029-20758-01-00 Permit Approval Date: • d 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, gas hydrates, or gas contained shales: t e s~} ~o ~ E - f0 ~SDD ~' ~ Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No HZS Measures: Yes ^ No Dir i al Sunray Req'd:~Yes ^ No Other: ~2/ Z ~ A~/'~-C Z S. O 3 S r! Gt~ ~I ~ ~ a.~ ~er vt.a, ~e ~ ~ ~ C cwc. d {- Y~ ou-e ~~Gt~ 112d . 3 ~ ~O r O r PPROVED BY THE COMMISSION Date ~j ,COMMISSIONER Form 10-401 Revised 12/2005 !"1 ("1 ~ ~ ~ R 1 A 1 ~ / ~ `--~'~ Submit In Duplicate • • To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission h From: Barbara M. Lasley, Drilling Engineer ICJ Date: March 15, 2006 Re: C-22A Sidetrack Permit to Drill The sidetrack, C-22A, is scheduled to be drilled by Nabors Rig 7ES during the second week of April. The plan is to exit the parent C-22 wellbore at 8,580' md. A whipstock will be run and an 8-1/2" window will be milled in the 9-5/8" casing. An 8-1/2" hole will be drilled to the Top of the Sag River formation. A 7" liner will then be run and cemented. The 6-1/8" wellbore then builds to horizontal, landing just above the base of Zone 2A. The planned well runs horizontally for approximately 950', staying above the HOT. A solid 4-1/2" production liner will be cemented in place. Planned Well Summary Well Horizontal Target Well C-22A Type Sidetrack Ob'ective Zone 2A AFE Number: PBD4P2431 API Number: 50-029-20758-01 Surface Northin Eastin Offsets TRS Location 5,960,214 663,847 994' FNL / 1523' FEL 11 N, 14E, 19 T Northin Eastin Offsets TRS arget L ti 5,959,156 661,669 2004' FNL / 3727' FEL 11 N, 14E, 19 oca ons Bottom Northin Eastin Offsets TRS Location 5,959,188 662,469 1990' FNL / 2927' FEL 11 N, 14E, 19 Planned KOP: 8,580' and / 7,751' tvd Planned TD: 11,075' and / 9,009' tvd J Ri Nabors E CBE: 33.18' RTE: 61.68' C-22A Sidetrack Page 1 Directional Program A roved Well tan: W 05 Exit oint: 8,580' and / 7,751' tvd Maximum Hole Inclination: ~90° in the tanned 61/8° roduction section. Proximi Issues: All wells ass ma'or risk criteria. Survey Program: Standard MWD/IIFR/MS. Nearest Well within ol: Well C-21 at 1000 ft. Nearest Pro a Line 23,000' North Logging Program Hole Section: Required Sensors /Service 81/2" intermediate: Real time MWD Dir/GR/Res/PWD throu hout the interval 6 1/8" production: Real time MWD Dir/GR/Res in the build Real time MWD Dir/GR/Res/ABI/Den/Neu in the lateral. MAD pass build for Den/Neu. Sam les at 50' intervals throw hout. Cased Hole: None tanned O en Hole: None tanned Mud Program Hole Section / o eration: Mill window in the 9 5/8" casin at 8,580' and T Densi MBT PV YP API FL H LSND 10.2 <12 15-22 30-40 <6.0 9.0 -10.0 Hole Section / o ration: Drillin 8 1/2" interval from -8600' and to section T e Dens' MBT PV YP API FL H LSND 10. <15 15-22 20-24 4.0 - 6.0 9.0 -10.0 Hole Section / o eration: Drillin 6.1/8° roduction interval T Densi LSRV PV YP API FL H FloPro SF 8.4 - 8.6 >20,000 8 -12 22 - 28 6 - 8 9.0 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd 8 1 /2" 7" 26.0# L-80 BTC-M 851' 8430' / 7627' 9281' / 8379' 61 /8" 4 '/z° 12.6# L-80 I BT-M 1945' 9130' / 8235' 11, 075' / 9009' Tubin 4'/i° 12.6# 13Cr Vam To 9130' Surface 9130' / 8235' Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9 5/8" casin Bride lu to surface 30 min recorded 3,500 si surface 9 5/8" casin window 20' new formation be and FIT 11.5 EMW 7" casin Float a ui ment to surface 30 min recorded 3,500 si surface 7" casin shoe 20' new formation be and FIT 10.0 EMW 4'/z" roduction liner Float a ui ment to surface 30 min recorded 3,500 si surface C-22A Sidetrack Page 2 Cementing Program Casin Strin : T', 26#, L-80, BTC-M intermediate liner Lead slurry: None planned. Slurry Design Basis: Tail slurry: 700' of T' X 8-1/2" annulus with 40% excess, plus 80' of T', 26# " ' ' " ' ' x 4 drill pipe liner lap, plus 200 of T shoe track, plus 150 of T x 9-5/8 annulus. Pre-Flush None lanned Fl id S / V l • S acer 35bbls MudPUSH at 12.0 u s equence o ume ' Lead Slur None lanned Tail Slur 40.5 bbl / 227.3 cf / sxs Class `G', 15.8 .1 f/sk. Casin Strin 4 1/2", 12.6#, L-80, IBT-M solid roduction liner Lead slurry: none planned Slurry Design Basis• ' Tail slurry: 1,794' of 4 1/2" X 6 1/8" annulus with 40% excess, plus 80' of 4 ' ' X 4 X 4 /~ Ilner lap, plus 200 of T 1/2 , 12.6# shoe track, plus 150 of T drill i e annulus. Pre-Flush 25bbls CW 100 Fl id S /V l S acer 35bbls MudPUSH at 9.6 u s equence o ume: Lead Slur None lanned Tail Slur 50.1 bbl / 281.1 cf / 3 x Class `G', 15.8 1.17 c k. Well Control Well control equipment consisting of 5,OOOpsi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. ROPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8 1/2" intermediate interval Maximum anticipated BHP: 3,673 psi at 8,379' TVD. Maximum surface pressure: 2,835 pSl (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 11.5 ppg EMW FIT Planned ROPE test pressure: 250 psi low / 3,500 psi high 7 day test cycle (Pre drilling phase) 14 da test c cle Drillin o erations ROPE configuration for 7" Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams drilling liner. while running 851' of T' liner. In the event of a kick the rig will follow the current best practice of picking up a joint of drill pipe crossed over to casing thread and running in the hole placing the drill pipe across all rams. This configuration provides two sets of employable rams, rather than one. Well Interval: 61/8" roduction interval Maximum antici ated BHP: 3,230 si at 8,800' TVDss. Maximum surface ressure: 2,350 SI (based upon BHP and a full column of as from TD ®0.10 psi/ft) Calculated kick tolerance: Infinite with 10.0 EMW FIT. Planned ROPE test ressure: 250 si low / 3,500 si hi h -14 da test c cle Drillin o erations Planned com letion fluid: 8.4 seawater / 7.1 Diesel BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. C-22A Sidetrack Page 3 Disposal Annular In'ection: No annular irection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling- All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 r for i ection. All Class I wastes are to be hauled to Pad 3 for dis osal. Geologic Prognosis Est. Formation To s Uncertain Commercial Hydrocarbon Bearin .Est. Pore Press. Formation (TVDss) eet) (Yes/No) (Psi) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are re aired from surface to TD for all new wells LCU -7509 TJD -7905 TJB -8134 No TSGR -8317 20 Yes TSAD -8429 20 Yes TCGL -8626 20 Yes BCGL -8687 20 Yes 23SB -8744 20 Yes 22TS -8796 20 Yes 3230 21TS -8856 20 Yes TZ1B -8946 20 Yes HOT -8953 20 Yes BSAD -9006 20 No Drill to TD unless drilling conditions deteriorate. Wellplan can be extended if optimal TD Criteria: placement of wellbore due to 14N shale coming in higher than expected is encountered. Fault Prognosis No fault crossings expected in The proposed C-22A well lies in a moderate risk province of the field for lost circulation at faults as documented by the WORD team and the risk of loss circulation events should be below average. No faults are expected to be encountered by the proposed well and only two loss circulation events were encountered in the Ivishak and Kingak sections in 1 of the surrounding 17 wells as detailed below. Several faults are present 230 feet and 330 feet to the north of the planned well path as well as 240 feet and 440 feet to the south. The north and south boundaries of the drilling polygon are thus hardlines. An additional fault lies 360 feet beyond the planned TD of the well. The well can be extended if necessary, but only in a southeast direction. Loss Circulation Events Well Type Loss (bbl) MD SSTVD Formation Fault? D-30 Rig 230 9300 -8441 Shublik No C-22A Sidetrack Page 4 ;7 • D-30 Ri 50 10234 -8972 Zone 2 No C-22A Sidetrack Page 5 Operations Summary Current Condition: / SI since April 2005. / 5-1/2", 17#, L-80 x 4-1/2", 12.6#, L-80 tubing, WLEG (behind pipe) ~ 8909' MD. / 9-5/8" X 4-1/2° OTIS HCL packer at 8761' MD. / 4-1/2" `XX' tubing tail plug set at 8,741' MD (8715' SLM) in SBR $COpe * Notify the field AOGCC representative with intent to plug and abandon * Pre-Rig Work• 1. Rig up slickline. Pull XX plug from SBR. Drift 5-1/2" x 4-1/2" x 3-1/2" tubing/straddle. Tag and record PBTD below W LEG. Rig down slickline. a. Expect fill. Sample bailer run from April 2005 found PBTD at 9982' SLM. 2. Fluid pack the tubing and inner annulus. 3. P&A the perforations in the T' liner. RU CTU. RIH with coil to PBTD (9982' SLM). Lay in i 1 bbls of cement to -8785' MD (at base of production packer). Wash down to confirm TOC ~ 8785' MD. POH with coil. RD CTU. NOTE: Adjust cement volume as required for actual PBTD tag. a. Bottom of cement will be PBTD from slickline tag. b. Top of cement will be at the base of the production packer in the original tubing tail at 8785' MD. c. Cement Calculations: • 7" liner = 9,982' - 9,974' (8 ft at 0.0371 bpf = 0.3 bbls) • 3-1/2" scab liner = 9,974' - 8,866' (1108' at 0.0087 bpf = 9.6 bbls) • 4-1/2" tubing tail = 8,866' - 8,785' (81' at 0.0152 bpf =1.2 bbls) • Total cement volume of 11 bbls. 4. Rig up E-line. Drift/tag TOC. Jet cut the 5-1/2" tubing at ~ 8,700' MD. RD E-line. 5. Pressure test T X IA to 3,500 psi for 30 minutes. Done 11/01/05 6. Pressure test OA to 2,000 psi for 30 minutes. Done 11/08/05 7. Circulate the well to sea water through the cut. Freeze protect the IA and tubing with diesel to 2,100' TVD. 8. Bleed OA, IA & TBG to zero. Test the 9-5/8" pack-off to 3,500 psi and tubing hanger seals to 5,000 psi. Function test lock-down screws. Repair or replace as needed. 9. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 10. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. Rig Operations: 1. MIRU Nabors 7ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Test pressures will be 250 psi low, 3500 psi high (rams), 2500 psi high (annular). Pull TWC. 4. Pull 5-1/2" tubing from the pre-rig cut 8,700'. Spool up SSSV control lines. a. Caliper log indicates that multiple fishing runs will be required. 5. RU a-line for the following runs. a. Gauge Ring /Junk basket and CCUGR for 9-5/8", 47# casing to 5-1/2" tubing stub 8,700'. C-22A Sidetrack Page 6 • • b. Set and test 9-5/8" CIBP at 8,600 to 3500 psi. The CIBP should be set at a depth so that a casing collar will not be across the whipstock tray face. Verify tool lengths with Baker. c. Once CIBP in place, change the 9-5/8" packoff. 6. PU 9-5/8" whipstock and bottom trip anchor with an 8-1/2" window milling assembly. RIH with 4" DP to CIBP. Orient WS 60 deg LOHS with MWD and set the whipstock. Swap well over to 10.2 ppg LSND i milling fluid. 7. Mill a window in the 9-5/8" casing at ± 8,580' MD plus 20' from mid-window. Perform FIT to 11.5 ppg EMW. POOH for Drilling BHA. 8. MU and RIH with the 8-1/2" drilling assembly with DIR/GR/RES/PWD ~S (,p _ ~p~9. Drill 8-1/2" interval to the casing point at the Top of Sag River at ~ ,28 .Short trip and condition hole ^ n~~~~ for 7" liner run. POOH. '^1- 10. Run and cer~r ent a T' drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing 150' to 8,430' MD. Set hanger /liner top packer and displace cement with mud. POOH. 11. MU and RIH with 6-1/8" build BHA with DIR/GR/RES and 1.83 deg motor. 12. Pressure test wellbore to 3,500 psi for 30 minutes. ~ 13. Drill out 7" shoe track. Swap over to 8.5 ppg FloPro SF mud and drill 20' of new formation. Perform FIT to 10.0 ppg EMW. 14. Drill the 6-1/8" build interval as per directional plan building to -90° (estimated -10,127' MD / 8946' TVD). POOH for horizontal assembly. 15. MU and RIH with 6-1/8" BHA with DIR/GR/ABI/RES/NEU/DEN and 1.5 deg motor. Drill horizontal i interval to an estimated TD of 11,075' MD. Condition well bore for the 4-1/2" solid, cement liner. POOH. LD drilling assembly. 16. Run and cement a 4-~/~" solid production liner extending the liner lap 150' into the drilling liner. Set liner top packer and displace well to clean seawater above the liner top. POOH. j a. Note: A pert pill will be left in the 4-1/2" liner. 17. RIH with DPC pert guns, Perf intervals to be determined from LWD logs. Plan to perforate overbalance. POOH, LD DP and pert guns. / 18. Run the 4-1/2", 12.6#, 13Cr, VamTop completion spaced out into the 4-1/2" liner top. Land tubing, / RILDS. Set TWC. 19. ND BOPE and NU the tree. Test tree to 5000 psi. Pull TWC 20. Reverse circulate in sufficient diesel to freeze protect the well to 2200' TVD, allow to U-tube. 21. Drop rod and ball. Pressure up on tubing and set the packer. 22. Test tubing to 3,500 psi for 30 minutes. Test annulus to 3,500 psi for 30 min. Record each test. 23. Set and test TWC. Secure the well. RDMO Post-Ria Work: 1. Install wellhouse and flowlines. "S" Riser may need modification. 2. Pull the ball and rod / RHC plug from `XN' nipple below the new production packer. 3. Install gas lift valves. C-22A Sidetrack Page 7 Phase 1: Move In / Rig Up /Test ROPE Planned Phase Time Planned Phase Cost 61 hours $307,810 includes re-ri costs Reference RP • "Drilling/VUork-over Close Proximity Surface and Subsurface Wells Procedure" SOP • "Hydrogen Sulfide" SOP. • "ADW Rig Move" RP. Issues and Potential Hazards - BOP test interval during this phase is 7 days. - No wells will require shut-in for the rig move onto C-22, as it is on the corner of the pad. Well C- 21 is 114' to the North; this is the closest neighboring well. As always, care should be taken while moving onto the well. Spotters should be employed at all times. - During MI/RU operations, the C-22 well bore will be secured with the following barriers: o Tubing: the cement P&A plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. - During ND/NU BOPE operations, the C-22 well bore will be secured with the following barriers: • Tubing: the cement P&A plug, kill weight fluid, and a TWC/blanking plug. • IA: Annulus valves and kill weight fluid. • OA: Annulus valve and kill weight fluid. - C-Pad is not designated as an H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading C-21 No Data C-15 No Data C-20 No Data C-21 No Data The maximum level recorded of H2S on the pad wa 20 pm in well C-18A on 05/26/2005. - Post Permit to Drill and Summary of Drilling Hazards in t e~dog house and camp prior to spud Phase 2: De-complete Well Planned Phase Time Planned Phase Cost 88 hours $259,680 Reference RP • "De-completions" RP Issues and Potential Hazards - BOP test interval during this phase is 7 days. - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. C-22A Sidetrack Page 8 ~J - Have all wellhead and completion equipment NORM-tested, following retrieval. - This wellhead is a 13-3/8" 5000 psi McEvoy with 7-1 /6 x 6-3/8" bore tree. Verify with Cameron that all replacement parts and required equipment is available. - Once the stack has been nippled down, verify the hanger thread and type in preparation for de- completion. Records indicate 7" IJ4S top and bottom threads with a crossover below to 5-1/2" A/B mod Butt. Be prepared with the appropriate tubing spear, in the event it becomes necessary. - The current completion has a 5-1/2" Otis SSSVN at 2105' MD, there is one control line. There is no record of the amount of clamps/steel bands run. - A caliper log shows a tubing part at 1611' MD. Be prepared to work with parted tubing/broken control line at surface. - Run GR/CCL Log from the bridge plug setting depth to surface after setting the CIBP. Phase 3: Run Whip Stock Planned Phase Time Planned Phase Cost 35 hours $226,126 Reference RP • "Whip stock Sidetracks" RP Issues and Potential Hazards - Records indicate 15.8 ppg Class G cement behind the 9-5/8" casing at KOP - Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled Phase 5: Drill 81/2" Intermediate Hole Interval Planned Phase Time Planned Phase Cost 51 hours $408,548 Reference RP • "Shale Drilling, Kingak and HRT' RP • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management' RP Issues and Potential Hazards - No logs were run in the intermediate hole section. Primary Depth Control will be based off of off- set wells. All C-22A MWD/LWD logs need to be tied in and depth shifted to the PDCL from the wellsite geologist. Record a minimum of 200' of LWD logs above the window to provide PDC tie- in. - For this well, the Kingak will require a mud weight of 10.2 ppg. Maintain mud weight at 10.2 ppg, minimally, to the 7" casing point. Follow all shale drilling practices to minimize potential problems. - KICK TOLERANCE: In the worst-case scenario of 8.9 ppg pore pressure, a fracture gradient of 11 ppg at the 9 5/8" casing window, and 10.2 ppg mud in the hole, the kick tolerance is i finite: - l`#e above kick tolerance is based on an FIT of 11.5 ppg EMW; if this is not reached contact the ODE. - No faults are anticipated in this hole section. C-22A Sidetrack Page 9 • • Phase 6: Run and Cement 7" Intermediate Casing Planned Phase Time Planned Phase Cost 24 hours $213,264 Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards - The completion design is to run a 7", 26#, L-80, BTC-M solid liner. - Sufficient 7" liner will be run to extend 150' back up into the 9-5/8" casing. - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab /surge pressures could initiate HRZ /Kingak instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. Phase 7: Drill 6 1/8" Production Hole Interval Planned Phase Time Planned Phase Cost 106 hours $592,683 Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • °Prudhoe Bay Directional Guidelines° RP Issues and Potential Hazards - The geologic polygon is bounded on the North, South, and East by a fault proximity. - No faults are anticipated in this hole section. Phase 9: Run 4~/z" Production Liner Planned Phase Time Planned Phase Cost 30 hours $277,363 Reference RP • "Modified Conventional Liner Cementing" RP Issues and Potential Hazards - The completion design is to run a 4 ~/~", 12.6#, L-80 solid liner throughout the production interval. - Sufficient 4-'/z" liner will be run to extend 150' back up into the 7" liner shoe. - Differential sticking is possible. The 8.4 ppg Flo-Pro will be -600 psi over balanced to the Ivishak Zone 2A formation. Minimize the time the pipe is left stationary while running the liner. - Ensure the 4 ~/~" liner top packer is set prior to POH. C-22A Sidetrack Page 10 • Phase 10: DPC Perforate Well Planned Job Time Planned Job Cost 30 hours $326,754 Reference RPs • DPC Perforating RP • Schlumberger DPC Perforating Guidelines Issues and Potential Hazards - The production interval of the well will be DPC perforated prior to running the completion. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with pert guns. - The Asset will provide a minimum clean out depth. This will define how far off depth the guns can be and still be fired without coming out of the hole to perform a clean out trip in the event the guns cannot tag the landing collar due to cement/fill. Phase 12: Run 4 ~/~", 12.6#, 13Cr, VamToa Completion Planned Phase Time Planned Phase Cost 26 hours $549,893 Reference RP • "Completion Design and Running" RP • "Tubing connections" RP • "Handling and Running 13 Chrome" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. - The completion design will be a 4~/z", 12.6#, 13Cr, VamTop production tubing string with 7" x 4- 1/2" Baker S-3 packer with 4 GLM's. Phase 13: ND/NU/Release Rio Planned Phase Time Planned Phase Cost i 2 hours $41,589 Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - No wells will require shut-in for the rig move off C-22, as it is on the comer of the pad. Well C-21 is 114' to the North; this is the closest neighboring well. As always, care should be taken while moving off the well. Spotters should be employed at all times. C-22A Sidetrack Page 11 by C-22A (P5) P Report Dab: February 7, 2006 CSerd: BP ExpkKatan Alaska FIB: Prudha Bay UnR - WOA Stnreture I Slot GPAD I G22 WeN: G22 Dorehob: Plan G22A ~~ UWYAPI{: 500292075801 Sunray Name i Deb: G22A (PS) / A3sil 20, 2006 Tort IAND / DDI I ERD ratlo: 228.468° / 4427.42 R 16.09510.491 Grid Coordinab Syabm: NAD27 Alaska State Planes, Zone 04, US Feet Loatlon LaflLonp: N 70.29765107, W 148.07308597 Laeetlon Gdd NIE YIX: N 5960214.000 ftUS, E 663847.000 ftUS Grid Comreryenee Mille: +1.24925758° Schlumberger ;al Survey /DLS Computation Madad: Minimum Curvature / Lubirtki Venial Sectlon Aalmulir: 82.030° Vertleal Section OrigM: N 0.000 R, E 0.000 R TVD Retarorrce Dahmr: Rotary Table TVD Rsbrnke Elevatlon: 61.68 ft relative to MSL Sea Dad 1 Ground LevN t-lavatlon: 33.18 ft relative to MSL MapneSc Deo®nattbrr: 24.566° Told FiNd Sberrptlr: 57605.852 nT MapwRe Dip: 80.895° DeelMrifon Dale: April 20, 2006 Meynetk Dee9natlon ModN: BGGM 2005 Nortlr R~erena: True NoM Total Corr Mag NoM a True NoAh: +24.566° Loal Coordinsba Retanrrad To: WeU Fbad Comment M°a ~ IrtdinMbn Azknutlr Subsea TVD TVD V NS EW DLS Tool Face DuRd Rat WaSc Rat NoRhkrp Egtlrrp LaBbrde Lon~tude p SeeUo ft R R R R R o0 R 00 R 00 R RUS RUS rre-rn~urvey ts4~.sc ss.cc cou.or row.ai roou.ia -c4au.aa -irca.ao -csor.cc i.au or.awu u.au c..~ aaaaus4.va ooiara.rc rrv.cywaoawrrr4o.oycroaau 8500.00 33.26 250.73 7623.27 7684.95 -2494.04 -1129.91 -2360.16 1.67 67.71 G 0.83 2.82 5959032.98 661512.20 N 70.29456322 W 148.69219359 Top Whipstock 8580.00 33.78 252.95 7689.96 7751.64 -2537.51 -1143.67 -2402.13 1.67 -60.OOG 0.68 2.78 5959018.31 661470.54 N 70.29452559 W 148.69253335 Base Whipstock 8596.00 34.78 250.04 7703.19 7764.87 -2546.37 -1146.54 -2410.68 12.00 O.OOG 6.22 -18.22 5959015.27 661462.06 N 70.29451777 W 148.69280250 KOP Crv4/100 8808.00 34.78 250.04 7713.04 7774.72 -2553.06 -1148.87 -2417.11 0.00 -168.05G 0.00 0.00 5959012.79 661455.68 N 70.29451138 W 148.89265458 8700.00 31.18 248.56 7790.21 7851.89 -2601.91 -1166.54 -2463.96 4.00 -166.82G -3.90 -1.80 5958994.10 661409.24 N 70.29446306 W 148.69303381 End Crv 8784.19 27.92 246.92 7863.43 7925.11 -2642.14 -1182.24 -2502.39 4.00 O.OOG -3.88 -1.95 5958977.58 661371.18 N 70.29442015 W 148.69334489 TJD 8831.23 27.92 246.92 7905.00 7966.68 -2663.41 -1190.87 -2522.65 0.00 O.OOG 0.00 0.00 5958968.51 661351.09 N 70.29439655 W 148.69350890 Crv 4/100 8958.42 27.92 246.92 8017.39 8079.07 -2720.90 -1214.21 -2577.43 0.00 -177.77G 0.00 0.00 5958943.98 661296.83 N 70.29433274 W 148.69395237 9000.00 28.25 246.78 8054.41 8116.09 -2739.17 -1221.65 -2594.84 4.00 -177.84G -4.00 -0.35 5958936.16 661279.60 N 70.29431240 W 148.69409326 TJB 9087.48 22.76 246.41 8134.00 8195.88 -2774.14 -1236.05 -2628.14 4.00 -177.31G -4.00 -0.42 5958921.03 661246.62 N70.29427301 W148.69436279 9100.00 22.26 246.35 8145.56 8207.24 -2778.75 -1237.97 -2632.53 4.00 -177.25G -4.00 -0.50 5958919.02 1361242.27 N 70.29426776 W 148.69439833 9200.00 18.26 245.73 8239.36 8301.04 -2812.04 -1252.02 -2664.17 4.00 -176.67G -3.99 -0.131 5958904.29 661210.95 N 70.29422936 W 148. TSAG 9281.05 15.03 245.01 8317.00 8378.68 -2834.28 -12131.68 -2685.28 4.00 -175.98G -3.99 -0.89 5958894.17 661190.06 N 70.29420294 W 148.69482 End Crv / 7" Csg Pt 9281.75 15.00 245.00 8317.68 8379.36 -2834.46 -1261.76 -2685.45 4.00 O.OOG -3.99 -1.08 5958894.09 8131189.89 N 70.29420273 W 148.69482 Crv 13.3/100 9301.75 15.00 245.00 8337.00 8398.68 -2839.41 -1263.94 -2690.14 0.00 177.OOG 0.00 0.00 5958891.80 661185.25 N 70.29419675 W 148.69488465 TSAD 9395.04 2.69 258.87 8429.00 8490.68 -2853.19 -1269.49 -2703.28 13.30 -95.83M -13.20 14.87 5958885.97 6131172.24 N 70.29418159 W 148.69497100 9400.00 2.07 264.17 8433.96 8495.64 -2853.39 -1269.52 -2703.48 13.30 -21.92M -12.56 106.74 5958885.93 661172.03 N 70.29418150 W 148.(39497264 "Vertical' Point 9415.00 0.78 338.08 8448.96 8510.64 -2853.69 -1269.45 -2703.79 13.30 58.25M -8.56 492.74 5958885.99 661171.72 N 70.294181139 W 148.69497513 9500.00 11.41 58.25 8533.39 8595.07 -2846.11 -1264.48 -2696.83 13.30 3.93G 12.51 94.32 5958891.12 661178.57 N 70.29419529 W 148.89491882 End Crv 9593.75 23.87 60.35 8622.56 8684.24 -2819.89 -1250.16 -2672.36 13.30 O.OOG 13.28 2.23 5958905.97 661202.72 N 70.29423444 W 148.68472077 TCGL 9597.52 23.87 60.35 8628.00 8687.68 -2818.48 -1249.40 -2671.04 0.00 O.OOG 0.00 0.00 59589013.75 661204.03 N 70.29423650 W 148.139471005 BCGL 9664.22 23.87 130.35 8687.00 8748.68 -2793.40 -1236.05 -2647.58 0.00 O.OOG 0.00 0.00 5958920.61 661227.18 N 70.29427300 W 148.89452020 Crv 13.3/100 9(368.75 23.87 60.35 8691.14 8752.82 -2791.69 -1235.14 -2645.99 0.00 3.506 0.00 0.00 5958921.56 661228.76 N 70.29427548 W 148.69450730 9700.00 28.02 60.89 8719.23 8780.91 -2778.97 -1228.44 -2634.08 13.30 3.02G 13.28 1.73 5958928.51 661240.52 N 70.29429360 W 146.69441090 WeIlDesign Ver SP 1.0 Bid( doo40x_56) G22\G22\Plan C-22A\G22A (P5) Generated 3/3!2006 10:17 AM Page 1 of 2 Comments ~~ Inelinatlon Admuth Sut-Sea TVD TYD V NS t'sW DLS Tool Face 8u0d Rate Walk Rab Nonhhg EaaOng t.etllude t.onyRude Seetbn R R R R R fl 00 R 100 R 700 R RUS RUS 23S8 9728.58 31.81 81.27 8744.00 8805.68 -2765.68 -1221.55 -2621.80 13.30 2.89G 13.28 1.33 5958935.67 661252.84 N 70.29431263 W 148.69430994 22TS 9792.99 40.37 61.89 8796.00 8857.88 -2730.13 -1203.53 -2588.28 13.30 2.19G 13.29 0.96 5958954.42 661285.78 N 70.29436191 W 148.69404002 9800.00 41.30 61.94 8801.30 8862.98 -2725.83 -1201.37 -2584.21 13.30 2.15G 13.29 0.77 5958956.67 661289.78 N 70.29436781 W 148.69400727 21 TS 9879.72 51.90 62.44 8856.00 8917.68 -2671.41 -1174.40 -2533.04 13.30 1.80G 13.29 0.63 5958984.74 661340.35 N 70.29444152 W 148.69359307 9900.00 54.60 62.55 8868.13 8929.81 -2656.10 -1166.90 -2518.63 13.30 1.74G 13.29 0.51 5958992.55 661354.59 N 70.29446204 W 148.69347643 10000.00 67.89 62.98 8916.13 8977.81 -2573.52 -1126.88 -2440.85 13.30 1.53G 13.29 0.43 5959034.25 661431.47 N 70.29457143 W 148.69284684 10100.00 81.19 63.33 8942.73 9004.41 -2482.53 -1083.46 -2355.04 13.30 1.43G 13.30 0.36 5959079.53 661516.30 N 70.29469012 W 148.69215228 TZ1B 10126.84 84.73 63.42 8946.00 9007.68 -2457.48 -1071.62 -2331.41 13.30 1.42G 13.30 0.33 5959091.89 661539.67 N 70.29472250 W 148.69196101 End Crv 10165.30 89.87 63.55 8947.82 9009.50 -2420.89 -1054.39 -2296.87 13.30 O.OOG 13.30 0.33 5959109.87 661573.83 N 70.29476981 W 148.69168138 Crv 11/100 10213.17 89.87 63.55 8947.93 9009.61 -2375.48 -1033.06 -2254.01 0.00 88.83G 0.00 0.00 5959132.12 661616.21 N 70.29482790 W 148.69133444 Tgt 1 10271.82 90.00 70.00 8948.00 9009.68 -2318.92 -1009.94 -2200.14 11.00 90.OOG 0.23 11.00 5959156.40 661669.56 N 70.29489110 W 148.690898 10300.00 90.00 73.10 8948.00 9009.68 -2291.22 -1001.03 -2173.41 11.00 90.OOG 0.00 11.00 5959165.90 661696.08 N 70.29491548 W 148.690681 10400.00 90.00 84.10 8948.00 9009.68 -2191.55 -981.29 -2075.54 11.00 90.OOG 0.00 11.00 5959187.76 661793.50 N 70.29496947 W 148.68988962 End Crv 10467.54 90.00 91.53 8948.00 9009.68 -2124.40 -978.72 -2008.09 11.00 O.OOG 0.00 11.00 5959191.81 661860.87 N 70.29497655 W 148.68934359 TD / 41/7' Lnr 11075.71 ~ 90.00 91.53 8948.00 9009.68 -1524.57 -994.94 -1400.14 0.00 O.OOG 0.00 0.00 5959188.84 662468.99 N 70.29493260 W 148.68442154 rf Surface : 4286 FSL 1524 FEL S19 T11 N R14E UM Tie-In : 4286 FSL 1524 FEL S19 T11N R14E UM Tgt 1 : 3275 FSL 3727 FEL S19 T11N R14E UM TD / BHL : 32~ FSL 2927 FEL S19 T11N R14E UM Northing (Y) [ftUS] 5960214.00 5960214.05 5959156.40 5959188.84 Fasting (X) [ftUS] 663847.00 663846.66 661669.56 662468.99 WeliDesign Ver SP 1.0 Bld( doc40x 56) G22\G22\Plan G22A\G22A (P5) Generated 3/3/2610:17 AM Page 2 of 2 • by Schiumberger wEEE C-22A (P5) P~EO Prudhoe Bay Unit - WOA 81~'~ C-PAD Noah BOWIZ003 Op ao ~' OEY'. IipA l°. z003 lr. N1011 s15M WT-q 3~~00 Mis Cna Cam' .1 NV13)S!' 9d cn lb wl Rdry l~eb ~Et.esn yew. YBl) Mp Dec •US°S' F8: SzlOS.YnT WtbW1J t08 EaN.p 6&'fn1100 M1s Sa1.FSt OnYYa]OIYSS wn Gz1w (PSI 9rw ~: F.nrvy0l. zoos -3000 -2700 -2400 -2100 -1800 -1500 7500 7800 8100 0 M C ~~p 8400 U 8700 .•. ~ End Crv...... .... n W 00 11CrvITCp Pt ~.. -.. -.. -.. -.. -.. -.. -.. -..:.. _..-..-..-..-..-..-..-..y..-..-..-..-..-..-..-..-.i-..-..-..-..-..-..-..-..-i.-..-..-..-..-... ~Crv 13.1100 ?v.Em.r vaEd - - - - - ~ nd crv . .....T ..................................t..................................,...................................,....................., .~,. _Crv 17.3n00 to I a.1m 9000 9300 7500 7800 8100 8400 8700 9000 9300 -3000 -2700 -2400 -2100 -1800 -1500 Vertical Section (tt) Azim = 82.03°, Scale = 1(in):300(ft) Origin = -0.0019633 N/-S, 0.00492653 E/-V • • 0 0 0 o S ~ ~ ~ , 0 0 N C _ -~ 0 Q a V ~ ~ ~ Eg ~R ~~ C~ C ~ ~~ ~~ ii ~K O N o ~ N S 2~ ~x° n O N 0 3 ~~~ N ~m ~ s 3 8 ~ g g ~A~ m g °o 0a ~3 rn 0 N O t ` S ~A a ~s ~~~ W ~~~ O N gg R~ fd ~n y dLL O N ~ S a_ ~ ~' Q g ~ cv ~ ~ ~ ~~ 0 0 0 0 v ~ ~ $ O (~O N ao N A O ~ O ~ N w N O O N c n °o m o <~ rn N (n V O N O O N 0 TO` GC-2 • o WELL AND 6" PRODUCTION * SUBSIDENCE WELL ® WELL LINE AND CELLAR • WELL PAD C as of Jan 1, 1993 TO GC-3 --- GAS PIPLINE ACCESS ROAD ~ • SOIiIO ALASY.A PETROLEUM COMPANY •WELLHEAD LOCATION DATA 1) 1JELL C- 22 2) Pad C EXT 3) llellhead Location 994SNL 1523~VEL X = 663,847 Y = 5,960,214 LAT. 70° 17' 51.54" LONG. 148° 40' 23.10" 4) Bearing v. Gyro Marker N22° 20'E ~ig~P (True) 5) Local Benchmark Elevation ~N C-2 38.88 Ft. At•iSL 6) Top Edge of Cellar * 33.18 Ft• !•~ 7) Base Flange Elevation 3L~.~~~ Ft. A~iSL 8) Kelly Bushing Elevation (c-1 .'~' ~~ Ft. AF~SL * Base Flange and Kelly Bushing NOT Installed This Date. NOTES: 1) Items 1 and 2 should be filled in by the Grilling Supervisor on the rig when a new ~•rell spuds in. 2) The surveyor should fill in Items 3, 4, 5 and 6. 3) The completed form should be returned to Drilling Dept. for distribution. 4) The bearing of the Gyro t4arker is required as a True, not a tdagnetic bearing. 5) Base Flange and Kelly Bushing Elevations measured by the Drilling Supervisor. C I RCULATI O"i: c '' District Field Fngin~_r - 2 vy~p'••} ••''~'9',~ District Drillin En ineer/Drilling Engineer - 1 v~ ~e~ TH ;r~ :~ 9 9 - Slope - to Rig for Posting - 2 ~•'•'"' '"""yy"~•'•~••• ~•~ :;ell Record Clerk, Geology - 1 ~..•~.....•• •s•'~•• •••~ ~~ "ell Fi 1 es ~ ~.^ ; c:ry L McNs~ ; .°,+ Engineering Associate, Grilling -Original fId's,~,ti.~ tssizt •: owai •' °~ i ~~E11enuM.Ct~gllerring, SFO -1 a~d~e FFSSio•~~~0~ s~~1 ___ __ April 2.0, 1482___ ____ D3 to • ~ Oilfield Services, Alaska Schlumberger Drilling & Measurements 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Friday, March 3, 2006 Barbara Lasley BP Exploration Alaska Sshlnmberger Prudhoe Bay C-22A (P5) Nabors 7ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Program: Instrument Type Start Depth End Depth CB Gyro MS 94.32'md 8,494.32'md Inc + Trend 8,494.32'md 8,900.00'md MWD 8,900.00'md 10,300'md MWD + IFR + MS 8'900.00'md 11,075.71'md Close Aaoroach Analysis results: Under method (2), all wells may flow. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drilling Aids to be orovided: A drilling map will be provided. Checked by: Scott DeLapp 03/03/06 • • by BP Alaska Anticollision Report Company: - - BP Amoco _ -- -- Date: 3/312006 'IYme: 09:58:Oi Page: 1 Field: Prudhoe Bay. Reference Site: PB C Pad Co-ordinate(NE) Refereuce: Weq: C-22, True Notch ~I Reference Well: C-22 -- Vertical (TVD} Reference: C-22A Pi3n 61.7 ~ Reference Wellpath: Plan G22A Db; C)raGe NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM interpolation Method: MD + Stations interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Range: 8580.00 to 11075.71 ft Scan Method: Trav Cylinder Notch Maximum Radius:10000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Weilpath Date: 2/7/2006 Validated: No Version: 2 Planned From To Survey Toolcode Tool Name ft ft 94.32 8494.32 Survey #1 CB GYRO MS (94.32-10 CB-GYRO-MS Camera based gyro mul~shot 8494.32 8900.00 Planned: Plan #5 V3 INC+TREND Inclinometer + known azi trend 8900.00 10300.00 Planned: Plan #5 V3 MWD MWD -Standard 8900.00 11075.71 Planned: Plan #5 V3 MWD+IFR+MS MWD +IFR + Multi Stafion Casing Points MD TVD Diameter iialc Size Name ft ft in in i 2661.32 2661.17 13.375 17.500 13 3/8" 8580.00 7751.64 9.625 12.250 9 5/8" 9281.75 8379.36 7.000 8.500 T 11075.71 9009.68 4.500 6.125 41/2" Summary < --- Offset WeDpath - - -- ~ Refereuce. Offset Ctr-Ctr No-Go Allowable Site Web WeBpath MD MD Distance Area Deviation Warning ft ft ft ft ft ~ PB C Pad C-01 C-01 V1 ~ ~ Out of range PB C Pad C-01 C-01A VS Out of range PB C Pad C-02 C-02 V1 Out of range PB C Pad G03 C-03 VS Out of range PB C Pad C-03 C-03A V6 Out of range PB C Pad C-03 C-036 VS Out of range PB C Pad C-04A G04A V1 Out of range PB C Pad C-04APB1 C-04AP61 V1 Out of range PB C Pad C-04AP62 C-04AP62 V1 Out of range PB C Pad C-04AP63 C-04AP63 V1 Out of range PB C Pad C-04 C-04 V1 Out of range PB C Pad C-05 C-05 V2 8618.52 9090.00 2901.69 922.16 1979.53 Pass: Major Risk PB C Pad C-05 C-05A V9 8618.52 9090.00 2901.69 922.27 1979.42 Pass: Major Risk PB C Pad C-O6A C-O6A V1 Out of range PB C Pad C-06APB1 C-06AP61 V1 Out of range PB C Pad C-06 C-06 V1 Out of range PB C Pad C-07 C-07 V2 8580.06 9120.00 1579.82 550.35 1029.48 Pass: Major Risk PB C Pad C-07 C-07A V4 8580.06 9120.00 1579.82 550.35 1029.48 Pass: Major Risk PB C Pad C-08 C-08 V2 Out of range PB C Pad C-08 C-08A V3 Out of range PB C Pad C-08 C-08AP61 V2 Out of range PB C Pad C-08 C-08B V3 Out of range PB C Pad C-08 C-086P61 V1 Out of range PB C Pad C-09 C-09 V1 Out of range PB C Pad C-09 C-09A V1 Out of range PB C Pad C-10 C-10 V8 Out of range PB C Pad G10 C-10A V5 Out of range PB C Pad C-11 G11 V1 Out of range PB C Pad C-11 G11A V4 Out of range PB C Pad C-12A C-12A V1 Out of range PB C Pad C-12AP61 C-12APB1 V1 Out of range PB C Pad C-12 C-12 V1 Out of range PB C Pad C-13A C-13A V9 Out of range PB C Pad C-13 C-13 V1 Out of range PB C Pad C-14 C-14 V2 Out of range PB C Pad C-15 C-15 V1 10319.35 9655.00 1307.03 856.13 450.90 Pass: Major Risk PB C Pad G16 G16 V4 Out of range PB C Pad C-16 C-16A V5 Out of range PB C Pad C-16 C-16APB1 V5 Out of range by BP Alaska Anticollision Report Company: BP Amoco Field: Prudhoe Bay Reference Site: PB C Pad Reference Weu: C-22 Reference Wellpath: Plan C-22A Dibe: _..3!312006 Time: 09:58:01 Page: 2 Co-ordiBate(PiE) Reference: Well: G22, True t3orth Vertlcai {T'VD) Reference: G22A Plan 61.7 Db: Oracle Summary < Offset Welipatb ~ Reference Offset Ctr-Ctr Novo Allowable Site WeU Weilpath MD MD Dfatance Area Deviation Warning ft ft ft ft ft PB C Pad C-17A C-17A V1 Out of range PB C Pad C-17AP61 G17AP61 V1 Out of range PB C Pad C-17AP62 C-17APB2 V1 Out of range PB C Pad C-17 G17 V1 Out of range PB C Pad C-17 C-176 V17 Out of range PB C Pad C-18 C-18 V1 Out of range PB C Pad C-18 C-18A V1 Out of range PB C Pad C-19A G19A V6 Out of range PB C Pad C-196 G198 V4 Out of range PB C Pad C-196P61 G198PB1 V1 Out of range ~ PB C Pad C-19 G19 V1 Out of range PB C Pad C-20 C-20 V2 Out of range PB C Pad C-20 C-20A V1 Out of range PB C Pad C-20 C-208 V3 Out of range PB C Pad C-21 G21 V1 Out of range PB C Pad C-22 C-22 V3 11579.32 8585.00 0.01 903.81 -903.80 FAIL: Major Risk PB C Pad C-23 G23 V3 Out of range PB C Pad C-23 G23A V7 Out of range PB C Pad C-23 G23B V8 Out of range PB C Pad C-24 G24 VS 8958.29 9060.00 2052.38 889.10 1163.28 Pass: Major Risk PB C Pad C-24 G24A V7 9690.99 11275.00 1123.01 854.13 268.88 Pass: Major Risk PB C Pad C-25 C-25 V2 Out of range PB C Pad C-25 C-25A V2 Out of range PB C Pad C-25 C-25B V4 Out of range PB C Pad C-26A G26A V1 9500.00 13055.00 3498.69 961.36 2537.33 Pass: Major Risk PB C Pad C-26 C-26 V1 8628.21 9345.00 3957.75 880.29 3077.46 Pass: Major Risk PB C Pad C-27 C-27 V1 Out of range PB C Pad C-27 G27A V4 Out of range PB C Pad C-27 C-27APB1 V1 Out of range PB C Pad C-27 C-27B V2 Out of range PB C Pad C-28 C-28 V1 Out of range PB C Pad C-28 C-28A V2 Out of range PB C Pad C-29A G29A V1 Out of range PB C Pad C-29 C-29 V1 Out of range PB C Pad C-30 C-30 V1 Out of range PB C Pad C-31 G31 V3 Out of range PB C Pad C-31 G31A V1 Out of range PB C Pad C-31 C-31 B V2 Out of range PB C Pad C-32 C-32 V1 Out of range PB C Pad C-32 G32A V2 Out of range PB C Pad C-32 C-32B V3 Out of range PB C Pad C-33 C-33 V1 Out of range PB C Pad C-33 C-33A V3 Out of range PB C Pad C-33 C-33P61 V1 Out of range PB C Pad C-34 C-34 V1 Out of range PB C Pad C-35A C-35A V1 Out of range PB C Pad C-35 C-35 V1 Out of range PB C Pad C-36A C-36A V4 Out of range PB C Pad C-36AP81 C-36AP61 V1 Out of range PB C Pad C-36 C-36 V6 Out of range PB C Pad C-37 C-37 V4 Out of range PB C Pad C-37 C-37A V4 Out of range PB C Pad C-37 C-37APB1 V1 Out of range PB C Pad C-37 C-37AP62 V1 Out of range PB C Pad C-38 C-38 V1 Out of range PB C Pad C-39 C-39 V1 Out of range PB C Pad C-39 C-39A V2 Out of range PB C Pad C-39 C-39AP61 V7 Out of range PB C Pad C-41 C-41 V1 Out of range PB C Pad C-41 C-41A V10 Out of range PB C Pad C-41 C-41AP61 V3 Out of range PB C Pad C-42 G42 V1 Out of range Field: Prudhoe Bay Site: PB C Pad Well: C-22 Wellpath: Plan C-22A i 74 ° I -- - - _-- -'_._ ' i _._< soo goo s 3 91 90 898 , 0 27 , 5 i _5 6 / 96 i i 20 300 ".- _..._, ...__._.. .. 300 _ _...... _- _" -_ 21 ~ ~..,...,..\ 50 74 180 Travelling Cylinder Azimuth (TFO*AZI) [deg] vs Ceotre to Centre Separation [300tVin] TFt~ = 6" CM/ WELLHEAD= McEVOY ACTUATOR = OTIS KB. ELEV = 67.36' BF. ELEV = 34.86' KOP = 3700' Max Angle = 40 @ 5900' Datum MD = 9888' Datum TVDss = 8800' 13-3/8" CSG, 72#, L-80, ID = 12.347" ~--~ 266T Minimum ID = 2.70" @ 9962' 3-1/2" DAVIS L LNR FC @ 9926'. 0.0232 bpf, ~ = 4.892" 7" BOT LNR HGR W/ TACK SLV ~• 3-3/4" BKR DEPLOYMENT SLV, ~ = 3.00" TOP OF 3-1/2" SCAB LNR, ID = 2.992" - 4-1/2" TBG, 12.6#, L-80, - .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681 " - C-22 l 2105' --j 5-1/2" OTIS SSSVN, ~ = 4.562" 2596' 9-5/8" Dv PKR CAA S I IFf MA Nf~2Fl S ST MD TVD DEV TYPE VLV LATCH PORT DATE 13 3129 3061 2 OTIS-LBD DOME RA 16 11/13!96 12 4547 4428 28 OTIS-LBD SO RA 20 11/13/96 11 5541 5229 39 OTIS-LBD DMY RA 0 11/13/96 10 6161 5707 40 OTIS-LBD DRAY RA 0 11/13/96 9 6313 5824 39 OTC-LBD DMY RA 0 11/13/96 8 6707 6132 38 OTIS-LBD DMY RA 0 11/13/96 7 6867 6259 37 OTIS-LBD DM1' RA 0 11/13/96 6 7401 6696 34 OTIS-LBD DMY RA 0 11/13/96 5 7557 6825 34 OTIS-LBD DMY RA 0 11/13/96 4 8096 7277 32 OTIS-LBD DMY RA 0 11/13/96 3 8254 7411 32 OTIS-LBD DMY RA 0 11/13/96 2 8451 7577 33 OTIS-LBD DMY RA 0 11/13/96 1 8610 7710 34 OTIS-LBD DMY RA 0 11/13/96 -~ 8682' ~-i 5-1/2" OTIS XA SLIDMG SLV, ID = 4.562" 8741' 8741' TU61VG SEAL ASSY 8761' 9-5/8" X 4-1 /2" OTIS HCL PKR, ~ = 3.813" 8826' 4-1/2" OTIS X NIP, ID = 3.813" 882T 8826' 4-1/2" XX TTP (04/13!05) 8866' 8867' 4-1/2" OTIS XN NIP, ID = 3.725" (BB~ND F 8869' ' 8908 8909' 4-1/2" WLEG (BEHIND PIPE) $$$4' ELMD TT LOGGED 08/16!83 PERFORATION SUMMARY REF LOG: BHCA on 08!12/82 ANGLE AT TOP PERF: 27 @ 9884' Note: Refer to Production DB for historical perf data SIZE SPF ~1TERVAL Opn/Sqz DATE 3-1/8" 4 9884 - 9924 S 06/06/93 3-3/8" 6 9921 - 9925 S 11!03/96 3-1/8" 4 9944 - 10010 S 06/06/93 3-3/8" 6 9982 - 9997 S 11/03!96 2-1/2" 6 9984 - 9998 C 11/23/96 2-112" 6 10014 - 10034 C 11/09/96 2-1 /2" 6 10048 - 10063 C 11 /09/96 u~ 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9994' --~ 3-112" LNR, 9.3#, L-80, .0087 bpf, ~ = 2.992" 9974' ELMD 3-1/2" LNR SHOE, M~LED ID = 2.70" (CTD 02/05!97) 'NOTE 3 1/2" DAVIS L F-SHOE@ 9996' MILLED OUT TO 2.70" ID BY CTD ON 02/05!97. DATE REV BY COMMENTS DATE REV BY COMMENTS 08/17182 OI~GINAL COMPLETION 02/05197 CT~3-112" SCAB LNR 07/31/10 CWKAK CORRECTIONS 09/24/05 MOR/TLH XX TTP SET (04/13!05) PRUDHOE BAY UNfT WELL: G22 PERMff No: 1820880 API No: 50-029-20758-00 994' SNL & 1523' WEL, Sec. 19, T11N, R14E ~ Exploration (Alaska) TPJ~ = 6" CNV WELLHEAD= McEVOY ACTUATOR = OTIS KB. ELEV = 67.36' BF. ELEV =__ KOP =~~~ 34.86' 8580 Max Angle = 90 @ 10268' Datum MD = _ Datum TV Dss = C-2 13-3/8" CSG, 72#, L-80, tD = 12.347" ~--~ 2667' Minimum ID = 3.813" @ 2105' X Nipple @ 2105' 2105' 4-1/2" HES X NIPPLE, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3250 3250 0 DMY RA 0 3 5481 5250 39 DMY RA 0 2 6941 6400 36 DMY RA 0 1 8280 7500 32 DMY RA 0 8430' BAKER HMC LINER HANGER, ZXP PKR W/ TBS 8580' BAKER WHIPSTOCK (TOP OF WINDOW) 9044' 4-112" HES X NIPPLE; ID = 3.812" Proposed 9-5/8" HF.S CIBP 8593' TUBING JET Cllr ~- 8700' TUBING SEAL ASSY 8741' 4-1/2" OTIS X NIP, ID = 3.813' - 8828' 3-3/4" BKR DEPLOYMENT SLV, ID = 3.00" 8866' TOP OF 3-1/2" SCAB LNR, ID = 2.992" 8869' ~ 9-5/8" CSG, 47#, L-80, ID = 8.681' ~ 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" - 9994' 3-1/2" LNR SHOE, M~LED ID = 2.70" _ 9974' (CTD 02/05/97) ELMD 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10243' 9044' 4-1/2 X 7 BAKER S-3 PERM PKR; ID - 3.88" 9102' 4-1/2" HES X NIPPLE; ID = 3.812" 9123' 4-112" HES X NIPPLE; ID = 3.812" 9134' 4-1l2" 12.6# 13CR-80, DRIFT ID = 3.833", 0.01522 BPF 9134' BAKER HMC LdVER HANGER, ZXP PKR W/TBS 9284' 7" LNR, 26#, L-80, 0.03826 bpf DRIFT ID = 6.151" 10984' PBTD ~ 11075' ~-1/2 12.6# L-80, DRIFT 1 3.833", 0.01522 BPF DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 10/03/05 STG SIDETRACK WELL: C-22A PERMff No: API No: 994' SNL 8~ 1523' WEL, Sec. 19, T11N, R14E BP Exploration (Alaska) PERFORATION SUNflNARY G22 MOTH~iBORE REF LOG: BHCA on 08/12/82 ANGLE AT TOP PERF: 27 @ 9884' Note: Refer to Production DB for historical pert data SQE SPF IMfftVAL Opn/Sqz DATE 3-1/8" 4 9884 - 9924 S 06/06/93 3-3l8" 6 9921 - 9925 S 11/03/96 3-1/8" 4 9944 - 10010 S 06/06/93 3-3/8" 6 9982 - 9997 S 11/03/96 2-1 /2" 6 9984 - 9998 C 11 /23/96 2-1 /2" 6 10014 - 10034 C 11 /09/96 2-1 /2" 6 10048 - 10063 C 11 /09/96 • • • e „ 89-671252 262 TERRIE L NUBBLE $P EXPLORATION AK 1NC ~~Mastercard Check y~ PO BOX 196612 MB 7-5 ~~ ° I ~ • V ANCHORAGE, AK 99519-66.12 DATE AY TO THE ~ ~~ $ ~~ P ORDER OF ARS First Nationa Bank Alaska Anchorage, AK 99.501 MEMO ~ • ~:L252OOO6O~:99L4~~~6227~~~~556~-' 0262 • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~~ ~~z~~ PTD# ~- ~ - O. 5-~ 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 first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. Company NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\j ody\transmittal_checkl ist __ - WELL PERMIT CWECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 _ _ Well Name: PRUD_HO_E_ BAY UNIT C-22A _ ___ _ Program DEV___ _ __ __ Well bore seg !, PTD#:2060390 Company BP EXPLORATION (ALASKA)_INC __ _ __ ______ _ Initial ClasslType ___DEV 11-O1L__GeoArea 890 _ Unit 11650___... ___ On/Off Shore On _____ Annular Disposal J Administration ',1 Permd fee attached _ Yes 'i2 Lease number appropriate - - - - - - - - ... Yes ~'3 Uni-que well-name and number Yes 4 Well located in a defined pool - - - - - - - - - _ - - - - Yes ~I5 Well.located proper distance_from.drilling unit-boundary- - - - Yes 'i6 Well located proper distance. from other wells. - . - _ _ - - - - - - - - - - - - - - Yes . 7 Sufficient acreage available in_drilling unit. - - - - - - - - - -- - - - - - _ - - . - - . - - Yes _ 8 If deviated, is_wellbore plat included _ . _ _ _ ... _ _ - _ _ - --- - - - - - - - - - - _ Yes - '9 Operator only affected party Yes '10 Operator has appropriate_bond in force _ _ Yes 111 Permit can be issued without conservation order- Yes 12 Permit can be issued without administrative-approval Yes Appr Date '13 Can permit be approved before 15-day wait Yes RPC 3120/2006 14 Well located within area andstrata authorized by Injection Order # (put_IO# in comments) (For NA 15 All wells. within 1/4 mile area of review identified (Far service wel_I only) - NA 16 Pre-produced injector: duration ofpre-production less than 3 months_(For service well only) NA ACMP finding of Consistency. has been issued for this project. -_ __ NA _ _ _ 18 __ _ --- _ Conductor string provided NA _. engineering 19 Surface casingprotects_allknowrUSDNls NA 20 CMT voladequate-te circulate on conductor & surf_csg NA 21 CMT vol. adequate to tie-in long string to surf csg NA '22 CMT Wiii coverall known productive horizons.. Yes Adequate excess. 23 Casing designs adequate for C, T, B &_permafrost Yes 24 Adequate tankage or reserve pit Yes Nabors 7ES. 25 If a re-drill, has. a .0-403 for abandonment been approved Yes 3/812G06. 26 A.dequaie wellbore separation proposed Yes 27 if (iive~rter required, does if meet regulations NA Sidetrack, 28 s~ ~ ~r~;1 tluid pr: ;r~,m schematic & equip list adegi.iate - Yes Mar MW 10.2 ppg. Appr Date p9 oCPEs, do they meet reguiaiiun Yes 'J~JGA 3/^.012Q06 30 3JF'f; press ~athig appropnate; test to (put prig in comm?nts)_ Yes Test to 3500_psi. MSP 2835 psi, 31 Cnokemanfold compiieswlAPl RP-53 (May 84)... Yes '32 Work will occur without operation shutdown Yes 33 Is presence pf H2S gas probable. Ne Not an H2S pad. 34 Mechanical condition cf wells within AOR verified (For service well only) NA ' __ 35 _. __ __ _ _ _ _ _ __ Permit can be issued wlo hydrogen-sulfide measures o _ Ii Geology __ 36 Data preserted on_ potential overpressure zones NA i 37 Seismic analysis of shallow gas zones.. NA Appr Date 38 Seabed condition survey (if off-shore) NA RPC 3/2012006 39 Contact namelphone forweeklyprogress reports [exploratory only] NA Geologic Engineering i Commissioner: Date: Commissione : Date Co i er Date prs 3~ ~~~ l~~r/~- 3-2g~6 3.20 -0.6 t
