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205-057
7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will 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 P2-37A RWO-Tbg Swap Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-057 50-029-22576-01-00 ADL 0034627 14453 Conductor Surface Intermediate Production Liner 9130 80 4581 13442 1335 14419 20" 10-3/4" 7-5/8" 3-1/2" x 2-7/8" 9119 40 - 120 40 - 4621 38 - 13480 13118 - 14453 3129 40 - 120 40 - 3419 38 - 8987 8771 - 9130 unknown 520 2480 4790 10530 None 1530 5210 6890 10160 13800 - 14190 4-1/2" 12.6# 13Cr80 35 - 131519006 - 9057 Structural 4-1/2" BKR S-B , 13095 , 8757 4-1/2" K Valve , 2110 , 2040 Date: Bo York Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com (907) 903-5990 PRUDHOE BAY 1-15-26 Current Pools: PT MCINTYRE OIL Proposed Pools: PT MCINTYRE 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 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.12.23 11:58:00 - 09'00' Bo York (1248) 325-775 By Grace Christianson at 3:58 pm, Dec 23, 2025 10-404 AOGCC witnessed BOP test to 3500 psi and Annular test to 2500 psi. A.Dewhurst 24DEC25 DSR-12/29/25 X J.Lau 12/30/25 12/30/25 RWO Tbg Swap PBU P2-37A PTD: 205057 Well Name:PBU P2-37A API Number: 50-029-22576-01 Current Status:Operable w/ K-Valve AFE Rig:ASR Rig Estimated Start Date:1/15/2026 Estimated Duration:6 days Reg Approval Required?10-403 Date Reg. Approval Recvd: Regulatory Contact:Carrie Janowski IOR 150 First Call Engineer:Michael Hibbert (907) 903-5990 (O) Second Call Engineer:Dave Bjork (907) 440-0331 (O) Current Bottom Hole Pressure:4009 psi @ 8,800 TVD Reservoir Est KWF 8.8 ppg Plan on using 8.4 ppg fluid throughout the RWO Max. Anticipated Surface Pressure:3,129 psi BHP minus gas gradient Last SI WHP:2,350 psi (11/30/2025) Min ID:2.377 Liner XO @ 13,404 MD Min ID in upper completion:3.812 Locked out SSSV @ 2,110 Max Angle:106 Deg @13,695 MD/ 70 deg @ 13,571 MD Brief Well Summary: P2-37A has operated with a K-valve/PB-valve since 2006. This has resulted in flowing the well at excessive tubing pressures and has led to some slugging production behavior. A new upper completion with a functioning SSSV will allow for increased production, better slugging behavior and ability to change out gas lift valves successfully (current GLMs are scaled up). Objective: Cut tubing at 13,055. Circulate well to 1% KCL/seawater with diesel freeze protect. Complete a tubing swap RWO by pulling the existing 4-1/2 completion and running a new 4-1/2 13Cr gas lift completion with new tubing retrievable SSSV on the ASR Rig. Well Completion Information: Tree: CIW 4-1/16 Wellhead: FMC 13-5/8 Existing Production Packer: 7-5/8 x 4-1/2 BKR S-B Packer Pre RWO work: Wellhead: 1. PPPOT-T to 5000 psi, PPPOT-IC to 3500 psi. Last completed in March 2014 and May 2015. 2. Cycle tubing LDS. Slickline w/ Fullbore assist Secure and PT 1. Set RWO PX plug w/ extra long prong and large equalizing ports at 13,084 MD. Set junk catcher on top of PX plug. 2. Attempt to pull deep GLV to establish circulation point. Station #6 is the most likely to be successful. 3. Circulate well to production and liquid pack tubing and IA. 4. CMIT-TxIA to 3,000 psi, 3300 psi max applied. RWO Tbg Swap PBU P2-37A PTD: 205057 Need 10-403 Sundry Approval before executing any of the following steps: E-line: 3. MU mechanical tubing cutter. 4. Cut tubing @ 13,055 in the middle of the first 40 joint above the X-nipple at 13,084. (Tubing tally attached) Fullbore: 5. Circ well to 1% KCL including a soap pill. 6. Either wait 1-2 hours and circ additional crude out of the well after fluids swap or return the following day to circ out remaining crude. 7. Place diesel cap on tubing and IA. DHD: 8. Bleed WHP to 0 psi. Valve Shop: 9. Set and test TWC Cameron H 4-1/16 RWO Procedure: 10. MIRU ASR Workover Rig. 11. Nipple down tree and tubing head adaptor. Inspect landing threads. 12. NU BOPE configuration top down: Annular, 2-7/8 x 5-1/2 VBRs, blind/shear rams, integral flow cross, 2-7/8 x 5-1/2 VBRs, and adapter. 13. Test BOPE to 250psi Low/3,500psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). a. Record accumulator pre-charge pressures and chart tests. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test the 2-7/8 x 5-1/2 VBRs with 4-1/2 test joint and 3-1/2 test joint. e. Test the annular with 4-1/2 test joint, and 3-1/2 test joint. f. Submit a completed 10-424 form to the AOGCC within 5 days of BOPE test. 14. RU and pull TWC. a. Use lubricator if pressure is expected. 15. Rock out diesel freeze-protect. 16. MU landing joint or spear,BOLDS and pull hanger to the floor. a. Expected PU weight in 8.4ppg = 144k-lbs calculated. Pickup casing jacks if needed. b. Rig up control line spooler and recover and count clamps. RWO Tbg Swap PBU P2-37A PTD: 205057 17. Pull 4-1/2 tubing to floor, circulate bottoms up. 18. Lay down 4-1/2 completion. Document cut tubing stub. Tubing will not be salvaged. 19. Run 4-1/2 13Cr premium connection tubing with gas lift mandrels a. Torque turn connections. b. Proposed completion tally attached c. GLMs 2-5 should be run w/ dummies and GLM #1 with a shear out valve. d. TRSSSV. 20. Land Hanger and reverse in corrosion inhibited 8.4 ppg KCl or seawater. 21. Drop ball and rod and set packer with 3000 psi. 22. Perform MIT-T to 3,000 psi. 23. Bleed off tubing pressure to 1000 psi and MIT-IA to 2,500 psi for 30 charted minutes. 24. Bleed tubing pressure down to shear the shear out valve in the top GLM. FP Tubing and IA with diesel to 2200 MD. 25. Set TWC. 26. ND BOPE 27. NU tree and tubing head adapter. 28. Test both tree and tubing hanger void to 500psi low/5,000psi high. 29. RDMO Workover Rig. Post-rig valve shop work 30. Pull TWC. Post-rig Slickline Work 31. Pull Shear-out valve, run gas lift design per gaslift engineer pull/run sheet. 32. Pull ball and rod and RHC profile. 33. Pull junk catcher andPX plug. Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. Annotated Log for tubing cut 4. Rig BOP Schematic and choke manifold 5. Existing tubing tally 6. Proposed Completion Tally 7. Sundry Revision Change Form RWO Tbg Swap PBU P2-37A PTD: 205057 Current Wellbore Schematic RWO Tbg Swap PBU P2-37A PTD: 205057 Proposed Wellbore Schematic RWO Tbg Swap PBU P2-37A PTD: 205057 Tie-In Log for Tubing Cut RWO Tbg Swap PBU P2-37A PTD: 205057 Cut tubing @ 13,055 in first full joint above packer and nipple. RWO PX Plug set in this nipple @ 13,084 RWO Tbg Swap PBU P2-37A PTD: 205057 ASR BOP Stack Upper VBR 2-7/8 x 5-1/2 Lower - Blinds VBR 2-7/8 x 5-1/2 2-1/16 Double manual valves on Kill Line Choke Line 2-1/16 HCR Valve 13-5/8 x 5M flange Choke Line 2-1/16 Manual Valve RWO Tbg Swap PBU P2-37A PTD: 205057 Existing Tbg Tally: RWO Tbg Swap PBU P2-37A PTD: 205057 Proposed Completion Tally VT VamTop or other premium 4-1/2 gas tight connection. RWO Tbg Swap PBU P2-37A PTD: 205057 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the first call engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 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 P2-37A Install K Valve Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-057 50-029-22576-01-00 14453 Conductor Surface Intermediate Production Liner 9130 80 4581 13442 1335 14419 20" 10-3/4" 7-5/8" 3-1/2" x 2-7/8" 9119 40 - 120 40 - 4621 38 - 13480 13118 - 14453 40 - 120 40 - 3419 38 - 8987 8771 - 9130 unknown 520 2480 4790 10530 None 1530 5210 6890 10160 13800 - 14190 4-1/2" 12.6# 13Cr80 35 - 13151 9006 - 9057 Structural 4-1/2" Baker S-3 , 13095 , 8757 4-1/2" K valve , 2110 , 2040 13095 8757 Bo York Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com (907) 903 - 5990 PRUDHOE BAY / PT MCINTYRE 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 0034627 35 - 8790 248 120 0 100 2585 870 1945 2125 358 865 325-494 13b. Pools active after work:PT MCINTYRE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 12:14 pm, Sep 22, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.09.22 10:57:20 - 08'00' Bo York (1248) RBDMS JSB 092525 J.Lau 11/6/25 ACTIVITYDATE SUMMARY 8/31/2025 ***WELL SI ON ARRIVAL*** BRUSH SSSV NIPPLE @ 2110' MD SET 4.5" K VALVE IN MODIFIED 3.85" MODIFIED NO GO IN DB NIPPLE @ 2110' MD 3.85" MODIFIED NO GO DB LOCK (41" LIH) valve type: 22kx14 serial number k-09, dome set @ 520 @ 60 deg ***WELL SI ON DEPARTURE*** Daily Report of Well Operations PBU P2-37A PBU P2-37A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-057 50-029-22576-01-00 ADL 0034627 14453 9130 80 4581 13442 1335 14419 20" 10-3/4" 7-5/8" 3-1/2" x 2-7/8" 9119 40 - 120 40 - 4621 38 - 13480 13118 - 14453 3129 40 - 120 40 - 3419 38 - 8987 8771 - 9130 UnknownNone 1530 5210 6890 10160 13800 - 14190 4-1/2" 12.6# 13Cr80 35 - 131519006 - 9057 4-1/2" Baker S-3 Packer No SSSV Installed 13095, 8757 Bo York Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY 9/4/2025 PT MCINTYRE OIL PT MCINTYRE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.08.20 13:50:34 - 08'00' Bo York (1248) 325-494 By Grace Christianson at 3:22 pm, Aug 20, 2025 10-404 DSR-8/26/25JJL 8/21/25 SFD 8/27/2025JLC 8/27/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.27 14:52:31 -08'00'08/27/25 RBDMS JSB 082825 SSSV Installation Well: P2-37A Well Name:P2-37A API Number:50-029-22576-01 Current Status:Shut in-operable PTD:205-057 Estimated Start Date:9/04/2025 Rig:Slickline Reg. Approval Req’d?10-403 & 10-404 Date Reg. ApprovalRec’vd: First Call Engineer:Michael Hibbert Phone Number:(907) 903-5990 Job Type:SSSV installation Estimated Bottom Hole Pressure:4009 psi @ 8,800 TVDss MASP:3129 psi Last SITP:2200 psi on5/19/25 Max Dev:106 deg @ 13,695’ MD Min ID:2.377” XO @ 13,404’ MD Brief Well Summary: P2-37A is a PAL producer that requires an SSSV. During a CTD operation in 2006 the TRSSSV was damaged and has needed a K/PB valve installed to be on production since then. In recent history a PB valve has been used, but since that company no longer supports PB valves then we are moving to a K-valve that is supported by Halliburton. Objective: Set K-valve SSSV in locked out SSSV at 2,110’. Slickline Procedure: 1. MIRU Slickline. 2. Run k-valve in nipple at 2,110’ per the attached design sheet. 3. Turn well over to Operations. POP well. Test SSSV 1. AOGCC witnessed safety valve test within 5 days of P2-37A being brought online. a. Notify AOGCC 24 hours in advance b. Ensure state test kit is complete and a digital gauge is calibrated and functional. Gauge will have a suitable range for the test. c. A 15 minute criteria to reach dome pressure is achieved after beginning bleed d. After reaching dome pressure the SSSV must actuate and close within 4 minutes. e. After valve closure with a measurable pressure differential across the valve, there must be no detectable leakage as evidenced by a stabilized, flat-line pressure response. Attachments: Wellbore Schematic K Valve Design Sundry Change Form SSSV Installation Well: P2-37A Current Wellbore Schematic: SSSV Installation Well: P2-37A K-Valve Design Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: August 20, 2025Subject: Changes to Approved Sundry Procedure for Well P2-37ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date STATE OF ALASKA SKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIO 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Install PB Valve Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 205-057 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22576-01-00 7. Property Designation(Lease Number): ADL 0034627 8. Well Name and Number: PRUDHOE BAY UN PTM P2-37A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PT MCINTYRE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 14453 feet Plugs measured feet FEB 1 �/rf true vertical 9130 feet Junk measured 13118 feet EB 6 2017 Effective Depth: measured 14419 feet Packer measured 13095 feet true vertical 9119 feet Packer true vertical 8757 feet G`4-e► Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 40-120 40-120 1530 520 Surface 4581 10-3/4"45.5#NT-8 40-4621 40-3719 4560 1730 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 285 3-1/2"8.81#13CR 13118-13404 8771 -8941 Perforation Depth: Measured depth: 13800-13860 feet 14010-14050 feet 14070-14110 feet 14170-14190 feet True vertical depth: 9006-9002 feet feet 9012-9021 feet 9026-9036 feet 9052-9057 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 35-13151 35-8790 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 13095 8757 true vertical depth) 4-1/2"PB Valve 2110 2040.41 12.Stimulation or cement squeeze summary: Intervals treated(measured): MAR 0 2�}q Treatment descriptions including volumes used and final pressure: �(���� 8 t1 t7 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 294 29 1039 2263 1066 Subsequent to operation: 425 172 1511 2237 781 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-646 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature A - Phone +1 907 564 4424 Date 2/16/17 Form 10-404 Revised 5/2015 Submit Original Only • • w In cg-3 O 1O - N 1- f.- O r 't N U 11M (0000) C) M op � vCDLCD OD a) OCD C) a) v0~DTra) N rs O CA f� r M 00 00 OD 0D (0 '- 00 - 1- L() Nr Tr co (0 ( 92M CO O r O r I- OD O Lf) Ea a- (R. r C r r r 03 ic i . i i i QLim Z 00r N- CC') = r r Ma W 0 I- 00 0 I LO Ns 4t .N O y N O N C) O � NOD _ oD r a N co 0\0 N N a In r r N- ti M d O)OOODDMNr t v- C OO LU 0 0 co r M Tr N J r r Z Z a,O OO 'v 0000 O O LL O O CLZ Z W O O W m O D O a Z D Ucnaa :3H • • • 2 Tp �' 2 0 _1 0 0 w I- ►on 0 o ma z EsO 0 0 0 c\ co o Ca Ci Fe +-�7 I- z0 3 O C N N O Z O N gQ "' ? o a o Q E2 .. cYi co cis Z oaCD � U) (i) () Q m a 0 /m O NJ N a) ._ o = w � DO m C 0 co 2 co Q N m - 2 co 4, w < 0 N (n0 U) co F- J (n Z a Q'� QLL N � ND 0 . 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J4QW WWF- 'TaUJ 1111- 00 _10I-LI � wWU) � 0 * DowwDww Omwo* oiw ' wmipi < UvDc * * Qi < W ? a 2 U) a a (n a ' C co co + Z : 0 N co co * CL : H : : a la- : « > * I-- U) * (O CO CO co r- r r r (73 C(O Cr) N co NI- NN N r r r O M f0 rN Ea) a 0 I as z >- 0 < CO ow 0. 0 c >+ � 'ca re oa 0 C 0C" CDa) Lt) M IFda,= 4-16"O N FLS * S NOTES:WELL REQUIRES A SSS """4-1/2" VNaLHEAd= FMC P2-3A 2_3A CH V.E TBG,3-1/2"&2-7/8"CHROME LNR'S&7-5/8" ACTUATOR= BAKER C CHROME CSG—WELL ANGLE>70e eD 13571'. OKB.ELEV= 52.1' BF.ELEV= I .._'. 2110' -4 LOCKED OUT(1/2'CA MCO TRCF-4A TRSSSV,D=3.812" KOP= 11195' I 04/06106) Max Angle= 106'@ 13695' Datum lVD= 13254' 2110' -{4-1/2'PSVALVE(01/24/17) Datum TVD= 8800'SS `10-3/4"CSG,45.5#,NT-80,D=9.953" H 4621' , GAS LFT MANDREIS Minimum ID =2.377" ( 13404' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 5096 4004 54 KM3G DOME BK 16 08/30/97 3-1/2" x 2-7/8" XO 2 7637 5506 53 KM3G DMY BK 0 09/04/95 3 8957 6298 55 KWBG DOPE BK 16 09/05/14 4 9994 6902 53 KM3G DMY BK 0 09/04/95 5 10826 7393 54 KM3G DMY BK 0 09/04/95 6 11661 7889 53 KM3G SO BK 22 09/05/14 7 13018 8711 53 KM3G SO BK 20 08/29/97 7-5/8"CSG,29.7#,L-80,D=6.875" 13076' ' 13084' —14-112"OTIS X NP,ID=3.813" k4/. 1 13095' —7-5/8"X 4-1/2"BKR S-B FKR,ID=4.00" ilk I ? —I FISH-GLM LATCH SPRING(09/06/14) TOP OF CEMENT — 1311$' 1. 13118' H3.70"BKR DEPLOY SLEEVE,ID=3,00" � 1 � 11 4 1/ 13129' —4-1/2"OTES XN MP,D=3.80" MLLE)(02116/06)(BEHIND PIPE) I �1 1 11 13150' H4-1/2"WLE�,D=3.958"(BEHIND PIPE) 1 4-1/2"TBG, 12.6#,13-CR,.0152 bpf,D=3.958" 13150' 11 111 /1�Iy. 13154' --1 E LMD TT LOGGED 09/11/95 ► 111111 1.1'1.1 J 111 1'1'1'1 13158' -I3-1/2"XN NP,D=2.75" ►111111 1111111 1M1 1111111 3-1/2"LNR,8.81#,13CR-80 STL, — 13404' �4� ---___.... /t/Y 1 13404' 1--{3-1/2"x 2-7/8"XO,D=2.377" .0087 bpf,D=2.992" /111111' �1111111� 11111/ •.11111 [MECHANICAL WHIPSTOCK 1H 13476' 141A`I 1 RA TAG H 134$6' MILLOUT WINDOW 13480'-13488' 1111114.11111111/1* 111111111. 11111111111111111i1 PERFORATION SUM 4RY 11111111111111111111 REF LOG: SWS MCNL/CCR/GR ON 03/17/06 1111111111' 1111111111 ` 11111111111 ANGLE AT TOP PERF: 92°@ 13800' 1111111111' 11111111111111111i1 Note:Refer to Production DB for historical perf data 1111111111111111111, SIZE SPF INTERVAL Opn/Sqz SHOT SOZ ►1111111111111111411* 2" 6 13800-13860 0 03/18/06 11111111111111111i1 PST', - 14419' .= 2' 6 14010-14050 0 03/18/06 11111111111111111111 2" 6 14070-14110 0 03/18/06 111111/1•* 111111•• • 2" 6 14170-14190 0 03/18/06 111 ,�1�1 1 1114 2-7/8'LNR,6.164,13CR-80, J 14453' N•. . 1••11 .1.1.4.1./•1.4.1.1.1A 0058 bpf,D=2.441" 1111111111111111111111 ►111111111111111111111 7-5/8"CSG,29.74,NT-13-CR-80S,D=6.875' H 13815' 1.1.1.1.1.1.1.1.1.1.1 DATE REV BY C MA:NTS DATE REV BY COMIVEM S PONT MCN[Y RE UPIT 09/03/95 ORIGINAL COMPLETION 11/17/16 CJNYJM) RESET PB VALVE/LOCK OUT TRCF-4A WELL: P2-37A 03/18/06 NORCIC1 CTD SIDETRACK(P2-37A) 12121/16 ZV/JM) RJLL R3 VALVE'SEF FLO-ThRU SUB PERMIT No: 2050570 05/27/06 DAV/PJC CRLG DRAFT CORRECTIONS 01/05/17 CJWJMJ PULLED FLO-11RU SW&GAUGES API No: 50-029-22576-01 02/03/16 GRCITLH RI VLV UPDATE PER STATE REGS 02/08/17 MGS/JMJ SET PB VALVE(01/24/17) SEC 14,T12N,R14E,4643'FEL&2480'FAL 06/28/16 JIuD OORRECTED PB VERBIAGE 11/02/16 GJB/JND SET NEW PB VALVE(10/28/16) BP Exploration(Alaska) OF TjJt r • g;i&\\\9/y,�it THE STATE Alaska Oil and Gas f Conservation Commission OALAs A 333 West Seventh Avenue GOVERNOR BILL WALKER *4 Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Y' Fax: 907.276.7542 www.aogcc.alaska.gov Kaity Burton Engineer a 00E0 ti 2 '9 Z(..'1?, Pad Eneer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Point McIntyre Oil Pool,PBU PTM P2-37A Permit to Drill Number: 205-057 Sundry Number: 316-646 Dear Ms. Burton: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this /g1 day of January, 2017. RBDMS R. JAN 2 6 2017 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI ION DEC 29 201 APPLICATION FOR SUNDRY APPROVALS <775 /M/dier 20 AAC 25.280 cp 1. Type of Request: Abandon 0 PlugPerforations Fracture Stimulate 0 YP 4 ❑ Repair Well ❑ Operations shu own Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other PB Valve Design 121• 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 205-057 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development [JJ. 99519-6612 Stratigraphic 0 Service 0 6 API Number: 50-029-22576-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No I3 PRUDHOE BAY UN PTM P2-37A • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0034627- PRUDHOE BAY,PT MCINTYRE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 14453 - 9130 - 14419 9119 13118 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 40-120 40-120 1530 520 Surface 4581 10-3/4"45.5#NT-80 40-4621 40-3719 4560 1730 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 285 3-1/2"8.81#13CR80 13118-13404 8771 -8941 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 35-13151 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 13095, 8757.10 4-1/2"Camco TRCF-4A SSSV-Locked 2110,2040.44 12.Attachments: Proposal Summary 0 Wellbore Schematic ® 13.Well Class after proposed work: Detailed Operations Program 10 BOP Sketch ❑ Exploratory 0 Stratigraphic ❑ Development ® ^ Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 , WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Burton,Kaity be deviated from without prior written approval. Email Kaity.Burton@bp.com Printed Name Burton,Kaity Title Pad Engineer Signature ✓(i/l/ t 4 '1 - Phone +1 907 564 5554 Date121ZS /2016 _`��/"/ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number Integrity ��• 4 6 Plug g ty 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: �e Post Initial Injection MIT Req'd? Yes 0 No // Spacing Exception Required? Yes 0 No Itd Subsequent Form Required: /0 — .si 0 4 / APPROVED BYTHE/ al Approved by: �./__ e47 Vr� o,! r 3 / COMMISSIONER COMMISSION Date: f fg_17 RDDIVIS LA, JAN 2 6 2017 ORIGINAL /d/27201/‘4 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • Ver.4.1 6/6/01 (11 Wireline Work Request P2-37A Distribution global wells organization Wireline(4) Well: P2-37A AFE: APBWELIRSL Reading File Date: 12/26/2016 Engineer: John Paul Kenda ICR: 150 FTS: Yes AWGRS Job Scope: SSSV Changeout H2S Level: Problem Description Install optimized PB valve design to allow operations to produce well with lower flowing well head pressure. • Initial Problem Review Lower common line pressure due to new line at P2. Remedial Plan -WIRELINE ACTION Install PB SSSV with dome pressure of 683 psi @ 60 degrees F. DSO flow well with a tubing pressure greater than 417 psi.Valve set to close at a flowing wellhead pressure V less than 417 psi. Date Work Completed Well Status/Results Date by Problem Resolved ? Y N : Well Review(Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate (STBL/D) Expected NOB: Avg. WC (%) Actual NOB: Lift Gas (MMSCF/D) MGOR used for NOB: TGLR (SCF/STBL/D) FTP (psi)/Steady? MAINTENANCE ONLY CLP (psi)/Steady? (e.g. Fix AC, Shallower for Slugging) Casing Press. (psi)/Steady? RATE (Non-Post-WW) Orifice Depth: (e.g.deepen, optimize orifice) IA Fluid Level: Post-Wellwork Date of FL Survey: / / Follow-up Recommendations: • • "PB"Valve Calculation Sheet Well # P2-37 Date: 12/29/16 Test Data Test Date 12/21/16 Gross Fluid Rate 5576 BLPD Flowing Well Head Pressure 317 psi Flowing Well Head Temperature 138 deg F GOR 1367 scf/bbl TGLR 796 scf/bbl Flowing Pressure Calculations Based on Hagedorn-Brown Multiphase Flow Correlation "PB"Valve Setting Depth TVD 2040 ft Tubing Pressure at depth 712 psi Temperature at depth 151 Valve set to close at 417# Pwh Flowing Tubing Pressure @ 417# Pwh 812 psi PB"Valve Test Rack Set Pressure at 60 deg F 683 psi Valve Size 4-1/2" NOTE: Well needs to flow at> 417# Pwh Valve set to close at 417# Pwh • Tubing Pressure at Valve 812 BPT(psia) 826 >1238 <1238 Temperature(deg F) at Valve 148 a 1.619E-05 2.68752E-05 b 1.202224 1.170192 Base Pressure 706.789474 c -849.896 -826.59888 Base Temp (TV-60) 88 700.33074 695.2766303 Corrected Pressure 695.27663 psia TCF 0.84133184 Pb @ 60 = 683.161452 Test Rack Pressure = 683 i • • O• O O O O co N M O O) O N 10 C V N- U y 0 0 0 0 O L M (D O) O) CO • LO LO CO CO - m CO CO CO co CY) CO O 'Cr 00 O) N N- O) O) I� CO CO CO 00 CO H (0 w— O O I� V M ti ti co Q co co ti C M CO O �- 0 — N- 00 0L0 Eo r' c`"oOvv � M M M M � r r r r a CO co Z oor� � � �n co co F—• m c000000wcc W CDL 00WW UUU C)O 'T Z -J CO M CO • 0) Lo *k • �# *k •� V l() 0) N. r- O V) 0) N Oj co (Ni U Et o «3 N007 A N co Lo 00 N N I� M CO01 O co CO V CO = 00 10 O O 00 — J `- N • • Z Z aO 0 0 • 0 0 N 00 Uou_ OOctZ Z w O O w m O D w Z D 0w0_ a_ r • d N f9 CP 1) Cfl CO N- L 00 CO I, a O LO I- , O N CO LO O 0 0 0 Co D 0) O) O) 0) > I- Q 0 H CO CO M N- L N- — N- CO G• Ln N LC) O • O — N Lf) W 0 0 0 0 0 > a CA L) rn rn 0 > 2 H w 0 0 a w z w w 0w o ~ H J a W Q 00 0 0 Q OcM1— mw U U aC9LOoC) J ddY H Z o � �av � 0 J "JQz z z o a a -E a 2 0 0 0 LZLi 2 Z HO Z •� W W UJ a H H < J < C) a 2 2 2 0 co cn cn cn Ln ca Z < 0 H C ro000) e a O O Q 0, co 00 0 o NI- vv cam O O2 cc cn Y 0 0 cn _ 2 2 2 0 cn v~) u") v) W ao „ a o CLf CY m W W W W ;, aaaa Q 0 t U) m I- is CO CO CO CO 0 0 0 0 0 0 0 D c 0 0 0 O W J J Z N N N N Z w 0_ 1 Q W '_' CO CO CO 0000 U ujLOL w N W r .- a .7 w .7 J o w 0= Ws,. Z -.1-1 0 w lu LL. W O M M M M CO• 0 r 0 Y W - -1 J D a • noa �ocn Li LL IL cn a a d E Q Q Q < NNN- N M M M M LL a U) 0 LL N a' LL Uacncca0_ aQ < < CO 00 a TRIS.,= ' 4-16"CNV FLS • Y NOTES:WELL REQUIRES A SSSV. '""4-112" WH LFEAD= FMC P2-37A 2— $7 A CHROME TBG,3-1/2"&2-7/8"CHROME LNR'S&7-5/8" ACTUATOR= BAKERC V CHROMECSG"`WELL ANGLE>70°(8/13571'. OKB.ELEV= 52.1' BE ELEV= KOP= 1106' 2110' —4-1/2"Ct1MCO TRCF 4A TRSSSV,ID=3,812" Max Angle= 106°@ 13695' ; = LOCKED OUT(04/06/06) Datum MD= 13254' 2110' —4-1/2'FLOW THRU SUB w/DH GAUGES Datum TVD= 8800'SS ON DB LOCK(12!19/16) 10-3/4"CSG,45.5#,NT-80,D=9.953" H 4621' GAS LFT MANDRELS Minimum ID =2.377" @ 13404' ST MD TVD DEV TYPE VLV LATCH PORT DATE 3-1/2" x 2-7/8" XO 1 5096 4004 54 KMBG DOME BK 16 08/30/97 2 7637 5506 53 KMBG DMY BK 0 09/04/95 3 8957 6298 55 KMBG DOME BK 16 09/05114 4 9994 6902 53 KMBG DMY BK 0 09/04/95 5 10826 7393 54 KMBG DMY BK 0 09/04/95 6 11661 7889 53 KMBG SO BK 22 09/05/14 7 13018 8711 53 KMBG SO BK 20 08/29/97 7-5/8"CSG,29.7#,L-80,D=6.875 J-1 13076' \ 13084' H4-1/2"OTIS X NP,ID=3.813" It M413095' —�7-518"X 4-112"BKR S B PKR ID=4.00" ? HASH-GLM LATCH SPRING(09/06/14) (TOP OF CEMENT — 13118" , ► 13118' —{3.70"BKR DEPLOY SLEEVE,ID=3.00" r 1 13129' —4-1/2"OTISXNNP,D=3.80" MILLED(02/16/06)(BEHIND PIPE) 1 1 13150' 4-1/2 WLEG,D=3.958"(BEHIND PIPE) 1 4-1/2"TBG, 12.6#,13-CR-0152 bpf,D=3.958" 13150' v1�11• �*ft 13154' -{Et MD TT LOGGED 09/11/95 1 �•• 13158' H3-1/2"X N NP,D=2.75" ... ►111 1.1.1 1.14 3-1/2"LNR 8.81#,13CR-80 STL, —{ 13404' •444 141�1�1 --�3-1/2"x 2-7/8"XO,D=2.377" ��� �'�'t'1 .0087 bpf,D=2.992" .........4S kiii.S//41 1k11 14.1 MECHANICAL WHIPSTOCK — 13476' RA TAG — 13486' —e �1��`41�4k1 MILLOUT WINDOW 13480'-13488' t1t1t1111/11t1t1*A 111111/111 1111/11/1/111111111 PERFORATION SUMMARY 111111111/1111111.1 REF LOG: SWS MCNUCC R/GR ON 03/17/06 1.1.111/111111/111/ 1111111111 ANGLE AT TOP PERE: 92°@ 13800' 1111111111' ` 1111111111111111111 Note:Refer to Production DB for historical perf data 111111111, SIZE SFF INTERVAL Opn/Sqz SHOT SQZ 1111/1111111111111 1111111111' 2" 6 13800-13860 0 03/18/06 111111111 .*A 2" 6 14010-14050 0 03/18/06 1111/1111111111/11 PBTD H 14419' •� 2" 6 14070-14110 0 03/18/06 1/1///1/.•*•111/1/v 2" 6 14170-14190 0 03/18/06 1//*1:/1, 1.1111 11\ **IPt11111 2-7/8"LNR 6.16#,13CR-80, — 14453' 0.0:1.14/!/.4.1: .0058 bpf,D=2.441" X11.1.1.1.1.111.1.1.1 11111111111 1111111111 7-5/8"CSG,29.7#,NT-13-CR-80S,D=6.875" — 13815' •1.1.1.1.1.1.1.1.1.1.1 DATE REV BY COMMENTS DATE REV BY COMMENTS PONT MC I NTY RE UNIT 09/03/95 ORIGINAL COMPLETION 11/17/16 CJWJM) RESET PB VALVE/LOCK OUT TRCF 4A WELL: P2-37A 03/18/06 NORDICI CTD SIDETRACK(P2-37A) 12/21/16 ZV/JMD RILL PB VALVE/SET FLO-THRU SUB PERMIT No: 2050570 05/27/06 DAV/PJC DREG DRAFT CORRECTIONS API No: 50-029-22576-01 02/03/16 GRC/TLH PB VLV UPDATE PER STATE REGS SEC 14,T12N,R14E,4643'FEL&2480'FNL 06/28/16 JM) CORRECTED PB VERBIAGE 11/02/16 GJB/JM)SET NEW PB VALVE(10/28/16) BP Exploration(Alaska) PZ-574- 0 • PthSOS-70 Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Tuesday, December 20, 2016 9:10 AM � IZI �� To: Regg,James B (DOA); DOA AOGCC Prudhoe Bay '\ Cc: AK, OPS FF Well Ops Comp Rep; Cocklan-vendl, Mary E; AK, OPS GPMA Field O&M TL; AK, OPS GPMA OSM;AK, OPS LPC DS Ops Lead;AK, GWO SUPT Well Integrity Subject: P2-37 online for SSSV sizing C�vttiti,,c\ Mr. Regg z-37 A I wanted to inform you that we currently have well P-..27 online without a SSSV installed to evaluate well flow conditions to properly size the ambient valve to be set. We have the well on our Defeated Safety Device tracker and the well is tagged/flagged indicating the defeated safety component. We will send a future alert when the well is SI for the downhole pressure gauges to be pulled. Regards, Lee Hulme Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony—7187 p� (Alternate: Vince Pokryfki) SCANNED MAY la?? 1 • ID • V OF T„ ,41.-„ ,,, ,-4-. THE STATE Alaska Oil and Gas ti -- � 14 ofALASKA Conservation Commission 5 333 West Seventh Avenue ” ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ..., Main: 907.279.1433 OFALAS�)' Fax: 907.276.7542 www.aogcc.alaska.gov Kaity Burton Pad Engineer SC QED FEB 27 2017, BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Point McIntyre Oil Pool, PTM P2-37A Permit to Drill Number: 205-057 Sundry Number: 316-504 Dear Ms. Burton: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, dx, /9.0-4,-- Cathy P. Foerster Chair DATED this I7' day of October, 2016. RBDMS l vOCT 1 4 2016 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMM1ANi,T O2�I APPLICATION FOR SUNDRY APPROVALS 0.S /a J 13� 1 Z, 20 AAC• 25.280 +a'^ ° 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Install PB Valve IT 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 205-057 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development H 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-22576-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No I1 PTM P2-37A , 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0034627 • PRUDHOE BAY,PT MCINTYRE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 14453 , 9130 • 14419 ' 9119 . 13118 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 40-120 40-120 1530 520 Surface 4581 10-3/4"45.5#NT-80 40-4621 40-3719 4560 1730 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 285 3-1/2"8.81#13CR80 13118-13404 8771-8941 0 0 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 35-13151 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 13095, 8757.10 4-1/2"K Valve 2110,2040.41 12.Attachments: Proposal Summary 0 Wellbore Schematic a 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development RI ° Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil IJ • WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Burton,Kaity be deviated from without prior written approval. Email Kaity.Burton@bp.com Printed Name Burton,Kaity Title Pad Engineer Signature 7 C1 -- Phone +1 907 564 5554 Date /t /O 3/Z0/ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number:3 I to-50Li Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: Lic, Post Initial Injection MIT Req'd? Yes 0 No f Spacing Exception Required? Yes 0 NoI Subsequent Form Required: /(i-- 4 C 4— C. APPROVED BYTHE / Approved by: ? COMMISSIONER COMMISSION Date: A.*16, V'7` /OH/i, ORIGINAL ,e/e44 RBDMS /(OCT 1 4 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) • General Information Well Name: P2-37A Well Type: Gas Lift Producer API Number: 50-029-22576-01 Well Activity Conventional 4 Classification: Activity Description: SSSV optimizing Cost Code/AFE: APBWELIR Field/Reservoir: PTMAC 12 Month Avg IOR, bopd: Job T ype: SSSV Estimated Cost, $K: AWGRS Job Scope: SSSV MAINTENANCE Other regulatory None requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Kaity Burton Contact numbers: (907) 564-5554 (907)360-6002 Well Intervention Engineer: Contact numbers: No Data No Data Lead Engineer: Mark Sauve Contact numbers: (907) 564-4660 (907) 748-2865 Date Created: September 22, 2016 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injection Date (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Pressure Cut(%) (Mscf/Day) (psi) 8/16/2016 537 1874.6 bwpd, 96 179 53 4,014 1,114 WC 77.74% Current Status: Operable Shut In Inclination>70°at Depth(ft) 13,571' MD Recent H2S (date,ppm) 7/3/2016 70Maximum Deviation (Angle and ppm Depth) 106° 13,695' MD Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 36° 13,633' MD Reservoir pressure(date, 3/19/2015 4,152psi Minimum ID and Depth psig) P 2.377" 13,404' MD Reservoir Temp, F 183° F Shut-in Wellhead Pressure 1,800 psi Known mech. integrity stuck GLVs problems(specifics) Last downhole operation (date, operation) 12/23/2014 Ran 3.76"cent to top of deployment slv-no obstruction located in tubing Most recent TD tag (date,depth, CT milled scale in liner to 14083' (not TD) hard scale, called toolstring OD) 8/25/2014 14,083' MD off1 ob Surface Kit Fit-for-Service? YES If No,Why? If well has been shut in for > 1 year or job cost>$500M, fill out Non Rig Surface Equipment Checklist. Comments,well history, P2-37A has a history of severe scaling and had two recent coil milling jobs to clean out the small liner. background information, Both jobs were stopped short of TD, the last job leaving TD in the 3rd (of 4) sets of perfs. Job was etc: cancelled after milling came to a near halt and progress was no longer being made. A new GLD was planned so mandrel#7,6,3,1 were bead blasted in prep but mandrel#2,4 were not. Slickline came to pull and replace valves but were unable to pull 1,2,4,7 leaving an odd partial design with two SO valves in place. The well has been highly unstable since. Due to the need for a PB valve (set to close on dome pressure not hydraulics)the well is choked back to maintain pressure—300psi above the dome trip • pressurSas not to trip the valve on the slugs. With the trition to STP-36 the header pressure in the line is anticipated to go down, but the amount is unknown. For this reason, it is desired to acquire flowing data on the well with no SSSV at stabilized header pressures for proper sizing of the dome valve. Because dome pressure operated SSSV valves rdquire sundries to change pressure limits and this well is highly competitive at PM2 and for GC1, itis desired to replace old PB valve and flow well choked back while . waiting on sundry and new PB valve. This work will require SL to enter well multiple times. Well currently makes —500bopd choked back. Prosper modelling suggests at a conservative FTP of 700psi this well can . make- 750bopd. Resizing of the valve and acquiring exact flowing data will be critical in ensuring this well is operated as optimally close to header pressure as possible. • • Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: HP SSSV Specific Intervention or Well Objectives: 1 Replace PB valve with conservative PB valve for start-up. Obtain flowing data for P2-37A at low STP-36 pressure,re- size SSSV,set new SSSV 2 3 Key risks,critical issues: Mitigation plan: 1 Pulling SSSV for flowing data We are allowed 14 days to flow well with no SSSV 2 Pilot trip pressure with unknown header pressure Pilot is requested to be set at 340psi trip pressure giving us an allowable FTP range of 340-1360psi STP-36 pressure is derated to-500psi high alarm,so by 3 PB valve is set too low setting the PB slightly higher than this intially we ensure this well stays online up to the high limit of the line. Summary Step# Service Line Activity 1 S Put PB valve from 2110' MD and set new 560psi LP PB valve. This step requires a sundry. 2 SP Pull LP PB valve from 2110'MD. Set flow-thru sub with memory gauges set to capture data every 30 seconds for- 2 weeks. 8-10 days after setting the gauges, pull flow-thru sub from 2110' MD. Download gauge data and send to 3 SF' APE as well as GLE (AKOPSGasLiftEngr@bp.com). Set OLD PB valve calibrated to 560psi trip pressure at 2110'MD. This step does not require a sundry. 4 SP Pull 560psi PB valve from 2110' MD and set new custom LP PB valve. This step requires a sundry. Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: 750 MMSCFD: 4 BWPD: 2950 Expected Production Rates: FTP(psi): 700 Choke setting: 176 PI(bfpd/psi dp) Post job POP instructions: Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: • • "PB"Valve Calculation Sheet Well# P2-37 Date: 09/23/16 Test Data Test Date 08/16/16 Gross Fluid Rate 2412 BLPD Flowing Well Head Pressure 1114 psi Flowing Well Head Temperature 98 deg F GOR 179 scf/bbl TGLR 1704 scf/bbl Flowing Pressure Calculations Based on Hagedorn-Brown Multiphase Flow Correlation "PB"Valve Setting Depth TVD 2040 ft Tubing Pressure at depth 877 psi Temperature at depth 126 Valve set to close at 560# Pwh Flowing Tubing Pressure @ 560# Pwh 870 psi 'B"Valve Test Rack Set Pressure at 60 deg F 767 psi Valve Size 4-1/2" NOTE: Well needs to flow at> 560# Pwh Valve set to close at 560#Pwh . • • TREF,- 4 lb-CM/1-1S SAFETY 115 WELL REQUIRES A SSSV. -4.112" WaLFEAD- TIC P2-37A 1 GRROMF TEC,3 1t7'&2 74-CHROME UM'S&7-5/8" ACTUATOR- BA KM C CHROMIC C SG-WT1 L A NGCE 70'0 13071. OKB ELEV 521 Er R.EV= -----T106' 211W 14 17(AM)110 4A TR5.E.SV,ID..3.812* 1 Max Anglo- 106"@ 13695' 0 21W -4 V7 FSVALVE10546(15)1 Datum MD- 13254' Datum IVO= 88C47 SS GAS LFTIAANNELS Sf 143 T TV 13 DEV T TY FE VLV LATCH FVRT DATE I 1-10-314•CSG.45 59,pa-so.o•a 963.1--[ 4821* --Al 1 5096 4004 54 KIA36,COW OK 18 0013097 7 11'631 5506 53 INY.J..R1 INIY MK 0 09.04/35 3 ; 8957 62913 56 K1A3G DOM BK 16 09,0914 Minimum/D =2.377" @ 34O4.714 9994 8902 53 101.0G DAN BK o oso4/cr, 3-1/2" 2-7/8" 5 1108261 7393 54 i 04G DIN i BK 0 03.134/96 1x X0 1 6 11661 7889 53 0.43G SO 1 BK 22 09,05(14 713018 8711 53 K.LOG SO ,, BK 20 0829/97 -__ 1 1-51S"CSG,29 7*.L-80.13.6 8751-1 1307V I \ 13011414 ltr OTIS X INIP 12 3 813' 4 ja.,-,4 13006, HP-sor x 4-177 BKR S-B R(Ft.ID.4 001 ilik I ? I--ELLIN Cl 1.4 tAICII SFRING(09138.14) I ITC'OF OBAENT *1---i 1 3144r 1 p 11M irl-1172'81(711EFLOY SLEEVE,0-3 00' 1 9 I ) io 0 i :0 1312ir-1- ---117 OTIS XN NIP 0 3 Mr latIO(132/16/08)MERINO PIPE) I 1 t *4 0 0 -- 131S0 lit 1r7 VILEG,0,-3.95Ir(118043PIPO 1 al al 4 1,2'IldG,12 E.,13 GR. 0152 00.(3"3 9671. 1- 131617 lif 'e, L -' i 13154' ' IH14rt i(X)GED owl ins 1 eel YA 1 rfl 13168' .3 1/7 XNP N D•2.75'1 Y11.4 tYll 0 0.134 3- vi vr L.sfe.a els.13CR-80 sn. -f 4M' 1 444 0 V9IP a‘al 114114* 3-ur IF 2-7ffr in a)•7 37r 1 9 9 0 PV9 0087 bpf U-2992' yoSS ?4yla '4•11 'Ni NEL3-111PAAL WHIPSTOCK I 1347Irit,. •"1/4..... ,RATA111 1- 110=111 vv._ v.. , —10lit ve MOW 13480'•134411 I "r9'11'4444311.11 1109.94499014 9.4.0.944.9t9 9' 949419999 SP FEFFORATIONSL9411Allf 11444•04.14 ••••••••• 41.14146. 144-1 OO SAG 1.124)CCNCR ON0371708 99444.9999 94.411994/9 9.4•400990 A N3LE AT TOP FERF 97 @ 138047 949149999 419941101994 -wq11410040 Nick 9110 Poducbon CO for hatortal part data 99449449. 4.419944•4 944409940 WI SR NIERVAL CIPI*544 SHOT SQZ , ••••••••••• 999019999' 'IN 7 6 13800-13860 0 0371808 999114011994 9994.9999 [—MI5-1-i-1444.• NI 7 6 14010 14050 0 03/181(36 0040000004 400.04000 r 8 14070-14110 0 0318708 9 9994'4..4, $$$ W. 7 6 14170 14193 0 03118106 94.'4. '19, • $$0. /4. 2-7,r ink 614M,ISCR4141, I 14453')....,..,..4 . ..........,...v.v.v.v 006$w,(3-2 44V V.T.V9Teeli 91144494•441 19999444999 99944.1944i 7-S/a-CSG,29 7f,NT-13-CRAIDS.I3-,4,875' --. 1381 5' 6411111411•111111411 , ()A Ii Fav liv 00044 N IS DA TI REV BY (OPAEN —TS IN)IIT PACIITY RE UNT , 1 09613/96 ON GIME COMPLETION 0306,14 00.0.4) TRIT CIO(0302,14i HELL P2 37A , il 03i1ivo6lica)c 17C TD SIDETRACK(P2-37A) I' I. 14 'APF PJC GIN CO FE.HDOHN FO F maxi-ND '050570 ,0507,06 QV/px4 CRLG CRAFT OORRECT10N5 .2103116 GRUM-CM VLV LFDATF PER STATE F6rs5 AR 1%b 50-029-22576-01 OG21/06 DAvrr FT4AL UP9A TES 06128116 AV C04,44ECTED FT3 VERBIACE SEC 14 T1214.R14E,46-43'FEL 8 2480 FI4_ 111.1f116 A1/1111 IT T13 RFF LOG LFDA TV . _ 02.13 111 TA14J1.AD•A MID SSSV SAFETY NOTE BP Exploration(Alaska) • • v fin p 0 0 0 O co M O C) O U y 0 o p 0 O M CO (3) (A M 7 to LC) CO CO tY CO Cr (fl CO CO O CO r O 'Cl" CO O N- O O CO CO CO CO CO CI 1 1 1 I 1 1 H co r O O LC) CO N. CO CO CO ✓ O O r O rI- CO O LC) N N O V' �t r r M M CO CO r r r V 0 Q I I 1 1 rco co CN1 co c) co co co = a r r i—• �- cocCCOOCOco a ZJMccoM rIrt N •(n C(j 6) r (O (Q O N O) c U O = = - _ co Lc) CO N N 1 N- p I� LC) r 1 1 (A (O O co M V LC) r • CO Lo O O CO r J co V N co Z Z a)0 0 0 .7)• 0 0 0 CISU 11 p p Z Z O OODLtLYZD W m 0 U) 0 d J F- • • • a) N 10 m LO co M f- L co co ti •- d O N CO Lf) 0 0 0 0 0 p O 6) 6) 6) F O F" CO CO M t- L CO Lf) N Lf) • O N Lf) W 0 0 0 0 0 > p 6) 6) 6) O 0 w 0 0 0 w z I- H O w 0 a Co Y 0 0 > CO O O w Y Y g O O O O J C3 0 W w tt. CO LU 6) J J J Q Q (n W ^ CO Cr - _0 _0 _0 J W W 0 Z 0 W �— r- Z Z Z O J J J D J CO o 0 a a 0 0 0 W ¢ QQOH W W O N cn 0 cn cn cn -+ Qa N 2 = Q. L OOOO • O 1"-- 0 `O 2 c> CO OO • F— O V N Lao OO) Y = 0 0 u)2 2 2 O co co can cJn can a) CL 0 To' W W W W Q 0 t a> a a, H CO CO CO CO 0 0 0 0 0 0 0 D c 0 0 0 O W J J Z O N N CV N Z U 1 1 < CO CO CO CO 11 0 1J w N LL NZ d' 0 0 W a W O c•-;--,.) 0--;5 0"--3 m 0 Y 0 W J J J D C J J Q 0 W W Qa 11 cn u_ L_ LL cn O a' E QQ Q Q N- r) co co co) W a. cn 0 LL N d u_ u) aQ < < mLi a STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMI1N • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well V Re-enter Susp Well ❑ Other:K-Valve [d 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 205-057 3. Address: P.O.Box 196612 Anchorage, Development El Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22576-01-00 7. Property Designation(Lease Number): ADL 0034627 8. Well Name and Number: PTM P2-37A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PT MCINTYRE OIL 11.Present Well Condition Summary: Total Depth: measured 14453 feet Plugs measuredfeet R IVFO E , true vertical 9130 feet Junk 13118 feet measured [� ��?? Effective Depth: measured 14419 feet Packer L. 2 201,, measured 13095 feet true vertical 9119 feet Packer true vertical 8757 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 40-120 40-120 1530 520 Surface 4581 10-3/4"45.5#NT-8 40-4621 40-3719 4560 1730 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 285 3-1/2"8.81#13CR 13118-13404 8771-8941 Perforation Depth: Measured depth: 13800 13860 feet 14010-14050 feet 14070-14110 feet 14170-14190 feet True vertical depth: 9006-9002 feet feet 9012-9021 feet 9026-9036 feet 9052-9057 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 35-13151 35-8790 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 13095 8757 true vertical depth) 4-1/2"K Valve 2110 2040.41 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 369 1067 1041 2199 1067 Subsequent to operation: 432 / 0 1522 2218 750 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development II Service 0 Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil IZI Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-095 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ,14„,.....r (1,.„.A Phone +1 907 564 4424 Date 2/26/16 Form 10-404 Revised 5/2015 VII' ,ri /1 Mg*BDMS L,v FEB 2 9 2016 Submit Original Only • d 0.0 0 0 0 0 • NLn M O) O) O 0 L� 2 8 8OO) cc,3 • tntoCO00 r '- CO CO CO 0 O) CD I- r O CV r O O) W N- d7 O) 1-- M 00 CO CO co H CO r O O ▪ ct M CO N- ✓ r CO O - r O r- co O Cn CN CV O [t r co co co co • r r r r co• . . . . . I C CO CO a)cj v cjM = Ii r r F- 0000 a 3 CD 00 H CO U U U • m = • N 4# Lo # RI N O N co cV U b co _ _ N cotn -0O (V N r 4 t t0 co 0 Co MctlL) r c 0 CO 0 0 CO r M V CN J r r coO 00 • 0 0 0 0 ) OO � OOIXZ Z CLO O w m OOCCCLZD Ucnaa = F- . • 0 / N @ c 0 0- 2 2 0 z - z > G f -2 2 2 / w n Lo $ / < r- co CV < / 4 0O20 0 ob 2 2 b b m m | / k bow & & O 2p 2 co CN < © E q / c / 0 o >- 2 � I0 =0 0k < k 0 / i. 2 zo R fx c , 0 < _ § E O 2 2 � - / \ cR0 \ 0 k 2I- o < 2 ^ � � � $ f1 ƒ k & Q 3- - C -b0F_ 4R ( i0w w - 2 3 � £ _ aekn 2 m � �? 0 < 13. Ts CN O C 0 0 D - < o 44- E - L 2 = 0_ : w (U > > JtiQI - \ 1- < > Z ƒ o 0- $ / ® $ ® E / > w § W G I- 0. ¥ 0 = m -- 00 -::-co 2 $ CL \ kms \ < q § 2LL26ow °- < 5 ©uja / � Z0 5U) 0 L > 2 ° Irw 2 < > 1_ < - R . Cl) \ re51E NE0 / b - / � b ¢ & 5 ƒ ƒ = g _1 o ¥ $ _1 \ - 4 ® Ii- if \ _ w - mi \ _ o @ / < 0 < w 44'4' 4' w _i / $ •1: I: 4 a. ; : I m m : a w k in ® in \ / Cl) CO CV LO CO OP a < TREE=+, 4-16"CNV FLS 0 NOTE'S:WELL REQUIRES A SSSV. ""4-112" ` *sRI LEAD= C P2-37A C ME TBG,3-1/2"&2-7/8"CHROME LNR"S&7-5/8" ACTUATOR= BAKER C CHROME CSG*"*INELL ANGLE>70"fa 13571'. OKB.ELEV- 52.1' BF.aEV a Max Angie= 106"@ 13695 • 2110' —I4-1/2"CAMCO TRCF-4A TRSSSV,D=3.812" Datum AD= 13254' 2110' H4-1/2"PB VALVE INSTALLED 05/05/15 Datum TVD= 8800'SS GAS LFT MANDRH_S ST MD TVD DEV TY FE VLV LATCH PORT DATE 10-3/4"CSG,45.5#,NT-80,D=9.953" —1 4621' 1 50% 4004 54 KMBG DOME BK 16 08/30/97 2 7637 5506 53 KMBG [LW BK 0 09/04/95 3 8957 6298 55 KMBG DOME BK 16 09/05/14 Minimum ID =2.377" 13404' 4 9994 6902 53 KMBG DIN BK 0 09/04/95 3-1/2" X 2-718" XO 5 10826 7393 54 KMBG DM1' BK 0 09/04/95 6 11661 7889 53 KMBG SO BK 22 09/05/14 7 13018 8711 53 KMBG SO BK 20 08/29/97 7-5/8"CSG,29.7#,L-80,D=6.875" —I 13076' J' ' ' 13084' H4-1/2"OTIS X NP,D=3.813" S M 13095' H7-5/8"X 4-1/2"BKR S-B R(R,D=4.00' ? H FtSH-GLM LATCH SPRING(09/06/14) TO'of CEEMEIVT —I 13118' 1311W —I 3.70"BKR DEPLOY SLEEVE,D=3.00" 1 ( 13129' —4-1/2"OTIS XN NP,D=3.80" 1 A4LLED(02/16/06)(BEIM)PIPE) i 1; 13150' —1:47-1/2"WLEG,D=3.958"(BERM)PIPE) 1 4-1/2"TBG, 12.6#,13-CR,.0152 bpf,D=3.958" H 13150' 1 113154' 1—SMD TT LOGG®09111!95 111 110'1 44 4.4 :: 1: 13158' —H3-1/2"XN NP,D=2.75' 4.1 111 1111 111 111 3-1/2"LNR,8.81#,13CR-80 STL, H 13404' 1�1�11 '1�1�ii 13404' 3-1/2"x 2-7/8"XO,D=2.377" .1.1.1 .0087 bpf,D=2.992" 1111111 X11111 1ti'c4/!44: 114*** 411 MECHANICAL WHPSTOCK —I 13476' 4 RA TAG --I 13486' •4,•4`#4`4, MILLOUT WINDOW 13480'-13488' 1111111111111111111 1111111111111111111 PERFORATION SUMMARY 111111111 1111111111 REF LOG: SINS MCNL/CCR/GR ON 03/17/06 1111111111111111111*111111111 ANGLE AT TOP FUZE 92'@ 13800' 1111111111111111111*I Note:Refer to Production DB for historical pert data 111111111111111111 1111111111 SIZE SFF INTERVAL Opn/Sq7 SNOT SQZ 111111111 1111111111, 2" 6 13800-13860 0 03/18/06 111111111 .� 111111111111111111 PBTD —I 14419' .�- 2" 6 14010-14050 0 03/18/06 1111111111111111111 2" 6 14070-14110 0 03/18/06 1.1.4....".•11111, 2" 6 14170-14190 0 03/18/06 1e•41`1111' 2-7/8'LNR,6.16#,13CR-80, 14453' 11.1 `%1A11.... x.11 .0058 bpf,D=2.441" •1.1.1.1.1.1.1.1.1.1 1111111111111111111111 7-5/8"CSG,29.7#,NT-13-CR-805,D=6.875' H 13$15' r*i*i*i*i*i*i*i�* 4 DATE REV BY COMMENTS DATE REV BY CONVENTS PONT MCIYTY RE UM" 09/03/95 ORIGINAL COMPLETION 03/26/14 DIVJMD TREECJO(03/22/14) WELL P2-37A 03/18/06 NOR)IC1 CTD SIDETRACK(P2-37A) 09/05/14 WR PJC GLV CO-FISH DOWN HOLE PE MT No:'2050570 05/27/06 DAV/PJC DRLG DRAFT CORRECTIONS 02/03/16 GRCITLH FB VLV UPDATE PER STATE REGS AR No: 50-029-22576-01 06/21/06 DAV/ILH FINAL UPDATES SEC 14,T12N,R14E,4643'Fa&2480'FNL 10/17/06 AF/TLH FERE RIP LOG UPDATE 02/18/11 P B/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) ti OF Tit, ID I//7 s. THE STATE Alaska Oil and Gas f �, oLASI�:A Conservation Commission __ l Aft 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALASFax: 907.276.7542 www.aogcc.alaska.gov Ryan Daniel Alaska Wells Integrity and Compliance Team Leader SCANNED MAR 0 3 2016 BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PTM P2-37A Permit to Drill Number: 205-057 Sundry Number: 316-095 Dear Mr. Daniel: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / 1./ F-224: 54- Cathy '. Foerster Chair DATED this 2r3 day of February, 2016. RBDMS t_L FEB 2 4 2016 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM ION • APPLICATION FOR SUNDRY APPRO ALS I20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 I Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tabing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other K-Valve Design Q ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 205-057 ' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development Q 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-22576-01-00 • 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No Q PTM P2-37A • 9. Property Designation(Lease Number): Field/Pools: g 4 01r _ ADL 0034627 • 110. zPRUDHOE BAY,PT MCINTYRE OIL • 0'CS Z 1233 1 t. PRESENT WELL CONDITION SUMMARY '') ,z l Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): I Plugs(MD): Junk(MD): 14453 . 9130 • 14419 9119 ' 13118 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 40-120 40-120 1530 520 Surface 4581 10-3/4"45.5#NT-80 40-4621 40-3719 4560 1730 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 285 3-1/2"8.81#13CR80 13118-13404 8771 -8941 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: I Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 35-13151 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 13095, 8757.10 4-1/2"K Valve 2110 12.Attachments: Proposal Summary Q Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development Q • Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil Q • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 OpShutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Daniel,Ryan be deviated from without prior written ap oval Email Ryan.Daniel@bp.corrt Printed Name Daniel,Ryan Title Alaska Wells Integrity&Compliance Team Leader Signature Phone +1 907 564 5430 Date (f IZd/6 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number:3`LJZ —096 Plug Integrity0 BOPTest 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes❑ No II Subsequent Form Required: `0-404 APPROVED BYTHE Date: -23-76 Approved by: _1...,„,.., `• COMMISSIONER COMMISSION Z ORIGINAL RBDMS u FEB 2 4 2016 tAsia. .2 l l(1. Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. 4 Attachments in Duplicate .�/�`i 2 4, •---s-2) z •8,t, • • m cN,000o O N CO d) O O O U tI5 L O CO Q C)) CO M 10 LC) CO CO Ca v- CO CO CO O O CO f� O N •"' CO V CA O Oco co co co co ti I O r-- Cn M M CO CO it a) r O O cr h CO 0 Cf) N O cr r d M CO CO Cr) a-cO r r V 4.0 �..� Q i I i i i CO CO �N Vv Orj co � Ca • O O O O a o COXX CO Vi Z co M _ d Lo = (D N Rj (nC7) V N6j0N N C) lC) C0 CV N p ‘-- ,S M d' CO O coM V LC) = co co O O co Q) d V NCO Z Z �O O O a F- W E-- F— 'mOVUU U O. O O u Z ZQOOWE O D f Q Z D • • y 10 CO LO CO CO N- O CO f� ‘- p �- O In N. d O N M t 0 0 0 0 0 p 0) 0) 0) a) 0. 0 F- CO CO co N- . r� TN- co QCfiN (xir ❑ d O N Cn UJ 00000 0 rn ca rn rn 0 ❑ 0I-u LU w O w g g Y U O > Y Y 0 O Ill cc 2 O 0 O O J a a u w 0 0 Li a s < W a d p Z Z Z O ? p _ _ = S o o a w 0U U 0 W I2 ..cora 2 2 2 O ci u~i cn cnO can CO N- 4-, M QO � .N ~ _ s 0 O o 0 o 2d co0or- �;, o - ' . - O cn co cn cn co G) CL y a 0 U .2 CC CC f ca W W W W 0aaaa Q O a) a) a F- 0 0 0 0 CO ❑ D 0 c 0 0 0 0 W _J _I Z O N N N N Z 1 1 a w Ow e, CO CO CO CO ❑ a :7 ;U ❑ W LU aj G CO CO CO CO a - ❑ - ❑ cCLL O m ❑ Y D X w a 0 w w < a m a m cn 1E 1 LL. cn a K m E Q Q Q Q ti M M CO CO N N N N LL' C- v) O LL N L LL. a a a a < < m mu. co a a m • •616101 1.3A Wireline Work Request P2-37 ADWDistribution PALMA MIN i WM Wireline(4) Well: P2-37 AFE: APBWELIRSL Reading File Date: 4/27/2015 Engineer: Kenda IOR: 50 FTS: AWGRS Job Scope: SSSV for Rate H2S Level: Problem Description Install SSSV set at lower closing pressure for lower Pwh and increased production rate. . Initial Problem Review - Remedial Plan -WIRELINE ACTION Install 4.5"K SSSV at HES closing shop pressure 880 psi at 60 degrees. NOTE: Design is based on a 4.5"SSSV, make sure HES uses that size. Pad Operator need to flow well at a Pwh of greater than Pwh of 870 psi. Date Work Completed Well Status/Results Date by Problem Resolved ? Y N : Well Review(Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate (STBL/D) Expected NOB: Avg. WC (%) _ Actual NOB: Lift Gas (MMSCF/D) MGOR used for NOB: TGLR (SCF/STBL/D) FTP (psi)/Steady? MAINTENANCE ONLY CLP (psi)/Steady? (e.g. Fix AC,Shallower for Slugging) Casing Press. (psi)/Steady? RATE (Non-Post-WW) Orifice Depth: (e.g.deepen,optimize orifice) IA Fluid Level: Post-Wellwork Date of FL Survey: / / Follow-up Recommendations: • • "K"Valve Calculation Sheet Well# P2-37 Date: 04/27/15 Test Data Test Date 04/25/15 Gross Fluid Rate 1865 BLPD Flowing Well Head Pressure 870 psi Flowing Well Head Temperature 95 deg F GOR na scf/bbl TGLR 1770 scf/bbl Flowing Pressure Calculations Based on Downhole Pressure/Temp Gauges "K"Valve Setting Depth TVD 2040 ft Flowing Tubing Pressure at SSSV 1280 psi Flowing Tubing Temperature at SSSV 107 psi Valve set to close at 870#Pwh Flowing Tubing Pressure @ 870# Pwh 1280 psi "K"Valve Test Rack Set Pressure at 60 deg F ( 880 psi Valve Size&Volume Ratio 4-1/2" 1.314 NOTE: Well needs to flow at> 870# Pwh Valve set to close at 870#Pwh • • Tubing Pressure at Valve 1280 BPT(psia) 1294 >1238 <1238 Temperature (deg F)at Valve 106.5 a 8.556E-06 1.42011E-05 b 1.106857 1.089931 Base Pressure 1188.15181 c -1306.816 -1294.50509 Base Temp(TV-60) 46.5 1170.0714 1169.862828 Corrected Pressure 1169.86283 psia TCF 0.90378772 /olume Ratio for Valve Size = 1.314 Pb @ 60 = 1156.84829 Test Rack Pressure = 880 Volume Ratios 4 1/2" & 5 1/2" 1.314_ 3 1/2" 1.257 2 7/8" 1.211 2 3/8" 1.204 114t= 4-16'CNV FLS • S NOTES:WELL REQUIRES A SSSV. "'4-1/2- ,/, ,D P 2-3 7 A C ME TBG,3-1/2"&2-7/8"CHROME LNR S&7-Sf8" ACTUATOR= BAKER C CHROME CSG"WaL ANGLE>70"6 13571'. OKB EE/= 52.1' BF V__.____.__.___ KOP= 1106' Max 69.._ 2110' —14-1/2'CARCO TRCF-4A TRSSSV,D=3.812' Max Angle= 106°@ 13695' • ()Mum M)= 13254 2110' —4-1/7 F8 VALVE INSTALLED 05/05/15 Daturn ND=__.___..8800'SS GAS LFT MANDRELS ST PA) ND DEV TY FE VLV LATCH FORT DATE 10-3/4'CSG,45.5#,NT-80,D=9.953' - 4821' m 1 5096 4004 54 KAOG DOLE BK 16 08/30/97 2 7637 5506 53 KMBG DMV BK 0 09/04/95 ' 3 8957 6298 55 KME3G DOME BK 16 09/05/14 Minimum ID =2.377" @ 13404' 4 9994 2 53 KM3G DMY BK 0 09/04/95 3412" X 2-718" XO 5 10826 7393 54 KP.43G DMY BK 0 09/04/95 6 11661 7889 53 K1EG SO BK 22 09/05/14 7 13018 8711 53 KM+3G SO BK 20 08/29/97 7-5/8'CSG,29.74,L-80,D=6.875' H 13076' N 13084' H4-12"OTIS X NP,D=3.813" M ►.1 13096' --17-5/8-X 4-12'BKR S-B FKR,D=4.00". 11 it ? -FISH-GIM LATCH SPRING(09/06/14) TOP OF CF3AE3JT — 13118' ' o1 013118' —3.70'BKR DEPLOY SLEEV E,D=3.00' 1 °' :1 13129' —4-12'OTIS XN NIP,D=3.80' MLLES)(02/16/06)(BEHIND PIPE) � 1 /1 13160' H4-12'MEG,D=3.958'(BEAM)PIPE) 4-12'TBG,12.6#,13 CR,.0152 bpf,D=3.958' — 13150' I►1 ►1 13154' -1 E3MD TT LOGO 09/11/95 111 ►1'1'1 111 1.1.1, X444 �O'V 13158' —312'XNOP,D=2.75" .41 111 111 3-1/2'LHR,8.81#,13CR-80 STL, — 13404' 1.1.1 114• A1A1�14 . 1S404• 3-12'x 2-7/8'XO,D=2.377' ,0087 bpf,D=2.992" 1111111 ►11111111 .1411 4.111 NECHACAL -FSTOCK H 13476' .141*4 4,,.. 4.141 MV11 RA TAG — 13486' ,•,`4O. MILLOUT WINDOW 13480'-13488' 41,141.1/141.4.0 1/1/1111111111111/1 111111111 PERFORATION SLIWARY 1111111111 111111111 RET LOG SVVS MCNJCX R/GR ON 03/17/06 1111111111 111111111* ANGLE AT TOP FERE: 92°@ 13800' 111111111111/111111*' 1111111111 Note:Refer to Production DB for historical perf data 111111111111444. SIZE SFF INTERVAL OPSHOT SQZ 111111444. 1111111/11 , *********A7 6 13800-13860 0 03/18/06 11111111111114 4 WV 4. pB TD — 14419' 2' 6 14010-14050 0 03/18/06 144111111411/111114 2' 6 14070-14110 0 03/18/06 111411111*.4\11111, 7 6 14170-14190 0 03/18/06 4t'.44` `)41 4 111 x11 2-78'LHR,6.16#,13CR-80, 14453' 11. . `>11N1 .1..�/...�. .0058 bpf,D=2,441- - •1.1.1.1.1.1.1.1.1.1• ►111111111111111111111 7-5/8'CSG,29.74,NT-13-CR-805,ID=6,875' —I 13815' DATE REV BY COMEINITS DATE REV BY CX)O.I1.UNTS PONT MCNTY RE UNIT 09/03/95 ORIGINAL COMPLETION 03/26/14 DLIJMD II EG/0(0322/14) WELL P2-37A 03/18/06'ND1 3101 CTD SIDETRACK(P2-37A) 09/05/14 WPJC GLV CIO-FISH DOWN HOLE FERMI No:"2050570 0527/06)34V/P DRLG DRAFT FS TIONS 02/03/16 GRCTILH FB VLV URIATE PER STATE S API No: 50-029-22576-01 06/21/06 DAV P'FHA UP[3A I I� SEC 14,T12N,R14E,4643'F7 L&2480'FT& 10/17/06 AF/TLH FEZF REF LOG UPDATE 02/18/11 MB/AID ADDED SSSV SAFETY NOTE 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. ~Q 5 - ~~~ Well History File Identifier Organizing (done) ^ Two-sided III II~III II III II III ^ Rescan Needed III (I'lll II II III III RE CAN Cotor Items: ~Greyscale Items: ` C~ ^ Poor Quality Originals: VU ^ Other: NOTES: BY: .Maria Project Proofing BY: Maria Scanning Preparation BY: Maria _ Production Scanning ^ Other:: Ip ~~Q /s/ iuuiuuiimiui d + ~ =TOTAL PAGES__~~ (Count does not include cover sheet) D g ISl r Stage ~ Page Count from Scanned File: ~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES _ BY: Maria Date: ~ ~ ~ ~O S Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. NO /s/ NO "iiiuimiuniuu ReScanned BY: Maria Date: Isl Comments about this file: DIG TAL DATA Diskettes, No. f ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: Date: L j _x30= Date:~j , Date: ~ J a~,~„~~~~ iuimmiiimiii P P 10/6/2005 Well History File Cover Page.doc • I bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 F May 20, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission a °5 5 7 333 West 7 Avenue Anchorage, Alaska 99501 ?� 7 Subject: Corrosion Inhibitor Treatments of GPMA PM -2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA PM -2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, q7 Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) GPMA PM-2 Date: 04/30/'2012 Corrosion Vol. of cement Final top of Cement top Corrosion inhibitor/ sealant Well Name PTD # API # Initial top of cement pumped cement off date inhibitor date ft bbls ft na gal P2 -01 1970730 50029227610000 0.3 NA 0.3 NA 1.70 6/22/2009 P2-03 1970440 50029227490000 2.0 NA 2.0 NA 10.20 6/22/2009 P2-04 1981560 50029229070000 1.0 NA 1.0 NA 5.10 6/22/2009 P2-06 1931030 50029223880000 4.0 NA 4.0 NA 30.60 6/22/2009 P2 -07 1940580 50029224690000 2.0 NA 2.0 NA 13.60 6/22/2009 P2-08A 2061690 50029228960100 0.8 NA 0.8 NA 4.30 6/21/2009 P2 -09 1980660 50029228760000 0.3 NA 0.3 NA 0.85 6/21/2009 P2 -10 1980970 50029228860000 0.3 NA 0.3 NA 1.70 6/21/2009 P2 -11A 2060260 50029229230100 3.5 NA 3.5 NA 69.70 6/21/2009 P2 -12 1931150 50029223950000 Sealed conductor NA NA NA NA NA P2 -13 1970600 50029227570000 0.5 NA 0.5 NA 2.60 6/21/2009 P2 -14 1981050 50029228880000 1.5 NA 1.5 NA 10.20 6/21/2009 P2 -15A 2070320 50029224090100 Sealed conductor NA NA NA NA NA P2 -16 1931230 50029223970000 3.0 NA 3.0 NA 28.10 6/20/2009 P2 -17 1981370 50029229020000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -18 1940600 50029224710000 0.8 NA 0.8 NA 2.60 6/20/2009 P2 -19A 2070120 50029227650100 0.3 NA 0.3 NA 0.90 6/20/2009 P2 -20 1960590 50029226640000 0.5 NA 0.5 NA 2.60 6/20/2009 P2 -21 1940530 50029224670000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -22 1972490 50029228500000 1.0 NA 1.0 NA 7.70 6/20/2009 P2 -23 1940320 50029224530000 1.3 NA 1.3 NA 11.10 6/20/2009 P2 -24 1980080 50029228540000 1.5 NA 1.5 NA 10.20 6/15/2009 P2 -25 1971110 50029227760000 1.8 NA 1.8 NA 17.90 6/10/2009 P2 -27 1971250 50029227850000 1.3 NA 1.3 NA 8.50 6/10/2009 P2 -28 1950440 50029225510000 3.3 NA 3.3 NA 37.40 4/18/2012 P2 -29 1931470 50029224070000 10.3 NA 10.3 NA 71.40 6/15/2009 P2 -30 1920950 50029222890000 2.8 NA 2.8 NA 17.90 6/10/2009 P2 -31 1940360 50029224560000 2.2 NA 2.2 NA 21.30 6/20/2009 P2 -32 1951350 50029225930000 Surface casing leak NA NA NA NA NA P2 -33B 1972310 50029228120200 2.0 NA 2.0 NA 16.60 6/9/2009 P2 -34 1950660 50029225580000 1.5 NA 1.5 NA 11.50 6/9/2009 P2 -35 1951790 50029226200000 1.0 NA 1.0 NA 13.60 6/9/2009 P2 -36A 2060220 50029228010100 1.1 NA 1.1 NA 6.00 6/9/2009 -P P2 -37A 2050570 50029225760100 2.0 NA 2.0 NA 23.00 6/9/2009 P2 -39 2111230 50029234540000 0.8 NA 0.8 NA 10.20 4/30/2012 P2-40 1972260 50029228370000 0.5 NA 0.5 NA 5.10 6/9/2009 P2-41 1952050 50029226330000 1.5 NA 1.5 NA 17.00 6/9/2009 P2-42 1931430 50029224050000 19.3 NA 19.3 NA 121.60 6/20/2009 P2-43 2050240 50029232500000 0.8 NA 0.8 NA 6.00 6/8/2009 P2-44 1960630 50029226660000 2.3 NA 2.3 NA 23.80 6/8/2009 P2-45B 2080210 50029227690200 0.8 NA 0.8 NA 5.10 6/8/2009 P2-46 1931320 50029224010000 2.3 NA 2.3 NA 25.50 6/8/2009 P2-47 1951900 50029226280000 0.0 NA 0.0 NA NA NA P2-48 1921260 50029223090000 0.2 NA 0.2 NA 1.70 4/18/2012 P2-49 1920240 50029222520000 2.5 NA 2.5 NA 18.70 6/7/2009 P2 -50B 1950960 50029222610200 2.0 NA 2.0 NA 23.00 6/8/2009 P2 -51 1920380 50029222620000 0.3 NA 0.3 NA 0.85 6/7/2009 P2 -52 1972010 50029228260000 3.8 NA 3.8 NA 47.60 6/7/2009 P2 -53 1960410 50029226560000 2.0 NA 2.0 NA 21.30 6/7/2009 P2 -54A 2030300 50029224700100 0.8 NA 0.8 NA 3.40 6/7/2009 P2 -55 1920820 50029222830000 4.0 NA 4.0 NA 79.90 6/22/2009 P2 -56 1951620 50029226100000 2.8 NA 2.8 NA 17.90 6/7/2009 P2 -57A 2022140 50029221830100 15.5 NA 15.5 NA 77.40 6/22/2009 P2 -58 1900080 50029220000000 Sealed conductor NA NA NA NA NA P2-59A 1982010 50029220960100 Sealed conductor NA NA NA NA NA P2-60 1910910 50029221920000 8.3 NA 8.3 NA 56.10 3/13/2012 .~ ,. r ,4` , ~~ +~ _~ :~ti ~ ~. i . _.,~ ~. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C\temp\Temporary Internet Files\OLK9\Microfilm Marker.doc ~ • __ ~ i'~ ~ ~.~-~CEiL I~~~MES 1~~Ils~~- A~Il~s ~~~~~ ~~5~~~~~~~~~ ~.~~~ CUMYANY li(' ~;Xt'WKAI l(1N (ALASKA) 1NC WELL NAME P2-37A P2-37APB t FIELD POINT MCINTYRE CUUNCY NUK1H SLUk'~ t3UKUUGH STATE ALASKA DATE 7/ 16/2009 THIS DISTRIBUTION L[ST AUTHORIZED BY: CATRINA GUIDRY SO #: 1087>93 Copics of Copies Digrtal Copies of Copics Digital Each Log of Film Data Each Log oCFilm Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF 0[L & GAS Person PETROTECHNICAL DATA CENTER Person COR~IZON NfANAOt$ Address LR2-1 Address ~50 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE. AK 99508 ANCHORAGE AK 99501 1 Company EXXON MOBIL PRODLCTTON CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE 1~IAHNKEN Person .4ddress 333 W. 7TH AVE Address SUITE l00 ANCHORAGE. AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv BAKER ATL4S-PDC 17015 Aldi~e Westfield Houston. Texas 7%073 This Distribution List Completed By'. ,~ , ~~ ~ ~~~ .~ ~~ ~:~ ~~~~{~ ' ~Ju~ ~`;;~~~~~~._~. ~~~ ~w .~. ~ ~ ~-~-~- Page I of 1 . • ~1~~~~ ~~~ ~ ~~~~ ~~°~~~~i~~~~ ~~~~ ~~ ~: ~~~~~ ~~ ~~~~~~ m~~~~~~ ~~~ ~~o ~~~ ~~~e ~~g~~ ~~o ~~~-~~~a~~9 ~-a~~a ~95~~ Attention: c~ha-as~ine I~ahnk~n It~ference, P2-37A ~i P2-37AP~1 ~ontains the following: 1 LDWG Compact Disc (Includes Graphic Image files} 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) ' LAC Job#: 1087593 •a-y"•~4~~~~:~4 ~i',j_~~ ~ ~ ~U~~~ ~U`J -~J`~~' I~~~~~ J~ ~~5~ Sent by: Catrina Guidry / Datec 07/16/09 , ~ r,, ~Z~eegved bye ~ ~f ; ~°~ ~ ate: \_~ ~,° _ ~]~..,,~A~~ A~ ~W~...EDGE 12ECE~P'~ ~3~ SI~I~IIN~ ~c RE'~I1 Il~t~ ~~ FAXII~i~ YObTR C'~P~ 1FAXe (~07) 2~7-6623 ~ ~~. 7 ~T~;c~ ~a~~~- ~~,g~,~~ g~~~~ 7260 Homer Drive Anchorage, Alaska 99~ 18 Direct: (907) 267-6612 FAX: (907) 267-6623 06/25/08 Schl~mberg~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall .Inh fk NO. 4750 Company: State of Alaska ~Q~U Alaska Oil & Gas Cons Comm ~~~~~ ~~j~ U U Attn: Christine Mahnken ~y 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Inn rlecrrin+inn nea4n RI r`nlnr rr\ P1-12 11978462 STATIC PRESS &TEMP = ~ (~~ o°( -^ - ~'1 06/01/08 1 X-12 11978466 PRODUCTION PROFILE - ~p'E°, J ~ 06/04/08 1 1 G-05 12017499 PRODUCTION PROFILE f ,• ...-j ^='- "rj- ~ ~~ ~ 06/12/08 1 1 E-14A 12034899 SCMT f ~¢'s~ .. f'=T° d;, <-"p " `~ 06/10/08 1 1 MPH-17 12066526 MEM INJ PROFILE t," a -'-~ . ' ~? ~ ~' ~"" ~ 05/26/08 1 1 L-220 11975763 CH EDIT PDC GR (USIT) REVISED CD'S ONLY:.- % ~ ~ •"l_ 04/22/08 1 L-220 40016915 OH MWD/LWD EDIT _ ~yat•3. ~~°" ~ 04/18/08 3 "`'I"~~~ 1,~: ~~ .y, ,~~ L-221 40016787 OH MWD/LWD EDIT .- <~< ,_~.--; C ..z°-.~ 04/03/08 3 1 ' 01-01C 40015644 OH MWD/LWD EDIT '"' '=a-- °~3 a~ ~ (r~ <°`' = °~. 08/15/07 2 1 G-19B 40015844 OH MWD/LWD EDIT~~y" ~ -- g ~~ s ;.y°""" 10/20/07 2 1 X-17 12057619 RST •,~ ;,/ "T,7`1 ! 05/24/08 1 1 L3-11 11966254 RST R r,_-.-' ~~~ ,~¢~ `"~~'°P 05/01/08 1 1 Y-36 12014013 RST I r^ °? • • '~ ~ ~- ~ ~. ' 05/11/08 1 1 P2-37A 11216182 MCNL ~'' 03/17/08 1 1 05-34A 40016888 OH MWD/LWD EDIT <.j,.-. :?~°'~-- ~ -'"~'la. 04/27/08 2 1 fLGMJG NV n.1YV YYLGLJLIG nG{.r Glr' 1 O r a~tarvuvu Nrvu ncl ~nrvlrvu vrvc ~vrT eH~n I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 - 900 E. Benson Blvd. Anchorage, Alaska 99508 ! ,, j,. ~° .~ Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 40R Anchorage, AK 99503-288 `I ATTN: Beth ~ f " Received by: ( i~ ,~ ; • • ~~J L g ~^~ DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drilt 2050570 Well Name/No. PRUDHOE BAY UN PTM P2-37A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22576-01-00 MD 14453 ND 9130 Completion Date 2/18/2006 REQUIRED INFORMATION Mud Log No DATA INFORMATI ON Types Electric or Other Logs Run: MWD ROP / GR / MPR, MGR /CCL / CNL Well Log Information: Log/ Electr Data Digital Dataset Tye Med/Frmt Number Name D D Asc Directional Survey F~p Directional Survey p~ Directional Survey og Production ~og S~Idotes G'(~. " / ED C 15302 Gamma Ray ~. g 15302 induction/Resistivity Log ~ 15302 Induction/Resistivity ~ Log 15302 Gamma Ray .E~ C 15303l~amma Ray !~ 15303 Induction/Resistivit y C JCo 15303 Induction/Resistivit „ g y -~ 15303 Gamma Ray Completion Status 1-OIL Current Status 1-OIL UIC N Samples No Directional Survey Yes (data taken from Logs Portion of Master Weil Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 13695 14453 Open 3/28/2006 ALSO PB 1 13340-13906 13695 14453 Open 3/28/2006 13340 13906 Open 3/28/2006 PB 1 5 Blu 1 13018 14123 Open 1/29/2007 Mem PPL w/Deft, PSP, ~,~, GR, CCL, Pres, Temp, Gradio, Spin 15-Nov-2006 5 Blu 1 13038 14030 ~ 4/20/2007 Mem Depth Control Log, ~csae_ Mem LEE CCL, GR 11- Feb-2007 13480 14452 Open 7(31!2007 LIS Veri, GR, ROP, w/Graphics Meta, TIF and PDFs 25 Blu 1 13488 14453 Open 7/31/2007 MD Multi Prop Resistivity, GR 15-Mar-2006 25 Blu 1 13488 14453 Open 7/31/2007 ND Multi Prop Resistivity, GR 15-Mar-2006 25 Blu 1 13488 14453 Open 7/31/2007 MD, GR 15-Mar-2006 13480 13906 Open 7!31/2007 PB1 LIS Veri, GR, ROP, w/Graphics Meta, TIF and PDFs 25 Blu 1 13488 13906 Open 7/31/2007 P61 MD Multi Prop Resistivity, GR 11-Mar- 2006 25 Blu 1 13488 13906 Open 7/31/2007 P61 ND Multi Prop Resistivity, GR 11-Mar- 2006 25 81u 1 13488 13906 Open 7/31!2007 P61 MD GR 11-Mar-2006 C DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2050570 Well Name/No. PRUDHOE BAY UN PTM P2-37A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22576-01-00 MD 14453 TVD 9130 Completion Date 2/18/2006 Completion Status 1-OIL Current Status 1-OIL UIC N ~D C Las 15632LAleutron 12912 14338 Open 10/26/2007 LAS, FCNL, GR, NCNL, NPHI w/PDF graphics IiED C Las 15633 nduction/Resistivity 13177 13905 Open 10/26/2007 P61 LAS, ATR, GR, ROP Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / N Daily History Received? Y ! N Chi s R i d? Y / N ~/ N T F ti p ve ece orma on ops Analysis Y / N Received? Comments: Compliance Reviewed By -Date: .~-J ~~ - la Date 10-12-2007 Transmittal Number:92914 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Douglas Dortch at the PDC at 564-4973 elivery Contents CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: ?-16CP61_ap ~--pg~...~tSfof9 _.__ 4-01 A ~0~.- 03.x__ -~ LS-I~-C~-.-_-_--__ 5-166 r7(j(o_- c~33-----t_'~~_L 5-16BPB1.__ ~"j~-Q~-3 ~5'~ _-____... 8-27Ds~Q~-1~3 ~~`L.~___...__ .-42A___~ -13 c~ _ r5~a~_ _ . ___ . __.. _.. a-24A a~ - o~a___ ,_s~~~ __.v_ a-24AP61 ~Ulo_-QYa.._.l.~f~`~-.___..~~__~-- '2-11 AP61 .2.CULo.-<5_a_!o_.._l~b~_4__..,______,_.._._ :-102 - ~..~_.__.~ ~. ,_ :: k1.~ ~PS :-102PB -- _ 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 • Transmittal Form r~~~ BAKER NUGNES INTEQ To: AOGCC 333 West 7t'' Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: P2-37A Anchorage GEOScience Center ~ Contains the following: 1 LDWG Compact Disc ~ - ° _ F (Includes Graphic Image files) ""°~ = °°~ i~ 1 LDWG lister summary ° ~'a' 3 I 1 blueline - GR Directional Measured Depth Log _, 3j 1 blueline - MPR/Directional TVD Log. ~ ' ~~ 1 blueline - MPR/Directional Measured Depth Log ~ ' 'I ,, m- I ii _ ,~ I _~ i. T-{ i _ ' ~~ ; - _: _' ~~ r' - -..-__ 3i LAC Job#: 1087593 S ~~~~ _._:~-- Sent By: Deepa Joglekar Date: ~ _ ~~ .~Y ~i ~ ~f _ ~~ Received By: Date: 9, ~ ~ ~ ~, ~~. U~-~-_ p y~ g ~y~ ,~q~' tC ~ tYf~~€3~71aAJIt~. JV1~~~~11J~~ ~ ~ T PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RE ING ~-.'~-! ~ ~: OR FAXING YOUR COPY "; ~ FAX: (907) 267-6623 ' ~ ""'~ ~O`J "6 Baker Hughes INTEQ . _._. ~ ' JeY~ ,.. ` 7260 Homer Drive ~ ° "' i$ ~S3b~ Anchorage, Alaska ' ~.....=°^~~°_ 99518 Direct: (907) 267-6612 ~ ~, FAX: (907) 267-6623 Transmittal Form ~~~~ BAKER NUGNES INTEQ Anchorage GEOScience Center ;.,, ~, To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: PZ-37APB1 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files} 1 LDWG lister summary 1 blueline - GR Directional Measured Depth Log f 1 blueline - MPR/Directional TVD Log ~ 1 blueline - MPR/Directional Measured Depth Log =-1 ! _ ~. .~_ ;: ---, -- _...._~ - ~ ~-- -- ~ LAC Job#: 1087593 ~ t ~~ .~ _~_. Sent By: Deepa Joglekar Date: ~ '~ ~ ,~~ ;f ,r- -- --- -r-- 1 Received By: Date: ~i ~, ~~~] ~. 1 .~~~ <~?: ~ ~,~ns. Com~issson PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RET~1~'>~1NG ; ~ , ,~ ~ OR FAXING YOUR COPY ~ ~' FAX: (907) 267-6623 a p~-dS/~ Baker Hughes INTEQ _ ~ 7260 Homer Drive -~-~, { Anchorage, Alaska ~ ~53~3 99518 Direct: (907) 267-6612 ! •: FAX: (907) 267-6623 ~-~ I_~ _ _ _ ~'~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall _Inh ~f aoS--~S~ Inn nncn.:..F:nn n~~.. NO 4214 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 04/16/07 02-15 11661130 MEM PROD PROFILE 02/25/07 1 U-06B 11469946 MEM PROD PROFILE 02/24/07 1 P-09L1 11676933 LEAK DETECTION LOG 03/18/07 1 U-12A 11649941 MEM PROD PROFILE 02/17/07 1 Z-326L1 11661128 MEM PROD PROFILE 02/19/07 1 L-04 11649945 MEM SPINITEMPlPRESS LOG 02i18i07 1 DS 16-22 11676935 LEAK DETECTION LOG 03/22/07 1 DS 12-31 11594485 LEAK DETECTION LOG 03/23/07 1 DS 07-35 11676932 LEAK DETECTION LOG 03/17/07 1 06-07 11637114 LEAK DETECTION LOG 03/16/07 1 LS-28AL1 11660526 MEM PROD PROFILE 02/08/07 1 03-33B 11661131 MEM TEMP/PRESS SURVEY 03/01/07 1 Z-19A 11649953 STATIC PRESS & TEMP LOG 03/21/07 1 F-11B 11649954 MEM PROD PROFILE 03/22/07 1 P2-37A 11628754 MEM DEPTH CONTROL LOG 02111/07 1 P2-58 11661129 MEM STATIC PRESS SURVEY 02/24/07 1 Y-06A 11628751 MEM INJECTION PROFILE 02/09/07 1 Z-35 11628753 DEPTH CONTROL LOG 02/10/07 1 P2-40 11637320 PROD PROFILE 02/25/07 1 05-20B 11649952 MEM DEPTH DETERMINATION 03/20!07 1 03-36 11649951 MEM STATIC PRESS 8~ TEMP 03/18/07 1 ,..,........~~...,~ ..~..~... ., . .,.v.....v ....., ..~ ~ v.".u.v vnc vvr : cn~.n : v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Bivd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~f FW: P2-37 K-Valve Redesign t .{ 2,~2~a°~ CC: "(_~f'B, I_PC DS OT~s L.~a~l" =GPBLPC'DSOi~sL.e~i~1;u;B['.co~~~=~, "~~'~'arr~er, Ross L'• ~~_Ross.~~'~lrner~crbp.com=> "vSt_i. AD~~' 1~'~'cll Operations Supcr~~isor'~ -NSL~.=1D~~'Wc110per~ltionsSuper~~isorr~t;t3P.com-- Pz-3~~ Subject: FW: P2-37 K-Valve Redesign From: "GPB, Gas Lift Enb " <GPBGasLiftEngr~ BP.com> Date: Fri, 02 Feb 2007 09:50:31 -0900 ~L~~D~ '['o: jinn_rc~;~ri~i'admin.statc.ak.us aos= D~~ Dear Jim, Our plan is to move forward with the K-Valve redesign in order to lower the well's normal flowing tubing pressure (far better IQR) and still comply with State regulations. Please let me know if you have any objections or questions, Regards, Johnny Kenda From: GPB, Gas Lift Engr Sent: Saturday, January 27, 2007 3:07 PM To: jim_regg@admin.state.ak.us Cc: NSU, ADW Well Operations Supervisor; Warner, Ross L; GPB, LPC DS Ops Lead; NSU, ADW WL £~ Completion Supervisor Subject: P2-37 K-Valve Redesign Hello Jim, Please note the attached K-Valve SSSV redesign for your approval. The current K-Valve requires the well to be choked back 674 psi wellhead pressure to remain open. The attached redesign attempts to lower the operating weNhead pressure to 400 psi. I will wait to hear from you before proceeding with the actual K-Valve change out. Please let me know if you have any questions. «P2-37 K-Valve Request 01-27-07 .ZiP» Regards, Johnny Kenda Arctic Lift Systems Inc. GPB, Gas Lift Eng. 907-659-5863 907-659-3423 (p) 601-807-8992 (c) 'P2-37 K-Valve Request 01-27-07 .ZIP Content-Description: ZIP 7 K-Valve Request 01-27-07 1 of 2 2/2/2007 10:13 AM FW: P2-37 K-Valve Redesign ,' ' Content-Type: application/x-zip-compressed Content-Encoding: base64 2 of 2 2/2/2007 10:13 AM ,,,,~ Wireline Work Request ': well: P2-37 Date: 1 /27!2006 _ _ - IOR: 150 AFE: Engineer: FTS: AWGRS Job Scope: PMP02WL37-C Kends SSSV Reset for Rate Problem Description ~,s,fi,o, P2-37 Distribution Wireline (4) Reading File ZS LeveE: Current K Valve installation requires well to be choked back to 674 psi to remain open. Rede_ sign K Valve to ope lower Pwh of 400 psi for increased drawdown and production. Initial Problem Review Remedial Plan - WIRELINE ACTION K-Valve set to flow and remain open with Pwh_ rester than 400 psi. _ __ __ __ HES needs to set valve at 428 psi @ 60 degrees. Date Work Completed Well Status/Results Date by Problem Resolved ? Y N Well Review (Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate (STBL/D) Expected NOB: Avg. WC (%) Actual NOB: _ Lift Gas (MMSCF/D) _ _ __ _MGOR used for NOB: _ TGLR (SCF/STBL/D) _ _ _ FTP (psi)/Steady? MAINTENANCE ONLY CLP (psi)/Steady? (e.g. Fix AC, Shallower for Slugging) - -- - Casing Press. (psi)/Steady? _ ___ ' ' RATE (Non-Post-WW) Orifice Depth: __ _ (e.g. deepen, optimize orifice) IA Fluid Level: Post-Wellwork - - __ Date of FL Survey: _ / _ / Follow-up Recommendations: ! ~ ~ y,z~~ "K" Valve Calculation Sheet Well # P Date: 12/21 /06 Test Data Test Date Gross Fluid Rate Flowing Well Head Pressure Flowing Well Head Temperature GOR TGLR 2-37~} 01 /23/07 2271 BLPD 714 psi 120 deg F 1196 scf/bbl 1382 scf/bbl Flowing Pressure Calculations Based on Hagedorn and Brown Multiphase Flow Correlation "K" Valve Setting Depth TVD 2040 ft Flowing Tubing Pressure With Gas Lift 400 psi Flowing Tubing Pressure Without Gas Lift NA psi Flowing Tubing Pressure @ 400# Pwh 646 psi "K" Valve Test Rack Set Pressure at 60 deg F 428 psi Valve Size 8~ Volume Ratio 4-1/2" 1.314 ;~ . _ ~' • ~~~ Pz- 3~~ ~~-v~v~ _Tubing Pressure at Valve &4s _BPT (psia) - 660 ' >1238 -- ~ <1238 emperature (deg F) at Valv _ 130 a _~ 1.288E-0~ ` 0.000021378 ' _ __ b_~ 1_.16086 _ 1.13538 ress --- B ~ c - 582.04740 - ~ -679.09 _ -- -660.5582 TV-60 ~ Ba e Tem P( ) - - -- ~-- - 581.2403 575.557424 Corrected Pressure 5'75.557424 ~ psia ~- TCF 0.871528504 ~ - olume Ratio for Valve Size = 1.334 Pb @ 60 = 563.007413 _ Test Rack Pressure = 428 f l V R ti ~ ume os o a 4 1/2" & 5 1/2" " 1.314 _ ~ ~ _ ~ - _ 3 1/2 1.257 _ 2 7/8° 1.211 - - -- -- - 2 3/8" 1.204 --- - - -; _,__ 2~~ -O S ~ ~. ~~ ~(~~~ ~~ ~~ .~~s~e.. d~ e,- w~...~. SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 February 2, 2007 Mr. Johnny Kenda Gas Lift Engineer, PRB 20 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit ("PBU") P2-37A (205-057) Subsurface Controlled Subsurface Safety Valve ("SSCSV") Dear Mr. Kenda: BP Exploration (Alaska), Inc. ("BPXA") notified the Alaska Oil and Gas Conservation Commission ("Commission") of the installation of a subsurface controlled subsurface safety valve ("SSCSV") on December 30, 2006. Additional information was provided by electronic mail on February 2, 2007. Approval of this alternate type of subsurface safety valve was requested from BPXA for the subject well as allowed in 20 AAC 25.265 (a)(2). BPXA's request to employ a subsurface controlled subsurface safety valve is GRANTED. Due to a control line failure, the tubing retrievable subsurface control valve in PBU P2-37A is inoperable; efforts to repair with wireline intervention have been unsuccessful. BPXA has provided the information necessary to make a decision about this valve, including design specifications and test rack data demonstrating the valve is capable of successfully halting flow from the well when the pressure above the valve is reduced below the established set point. Subsequent testing of P2-37A must be conducted when installed and in conjunction with the scheduled tests of other safety valve systems on PBU P2-pad wells. Please contact the Commission at least 24 hours in advance for an opportunity to witness these tests. A tubing workover of PBU P2-37A will invalidate this approval and necessitate the reinstallation of a surface controlled subsurface safety valve. Sincerely, ~'~~. ~ ~. James B. Regg Sr. Petroleum Engineer 01!25!2007 Alaska Data 8: Consulting Services - -~ z ~ ~1 ;1~ i~~ t` 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth :~ ~''t~ Wr±ll Jnh i! ~ n.. NO. 4125 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay P2-37i4 11491392 MEM PROD PROFILE 71/15/06 1~ yv Y-23B 11418299 MEM PROD PROFILE 09/06/06 NK-07A 11588698 MEM GLS 12I21-06 1 07-01A 11555031 GAS ENTRY SURVEY 12/19/06 1 NK-08A 11485780 MEM GLS 12/20/06 1 NK-27 11588699 MEM GLS 12/22/06 1 NK-43 11513659 PRODUCTION PROFILE 12!22/06 1 DS 09-32 11555530 INJECTION PROFILE 12/16/06 1 P2-14 11539745 MEM PROD PROFILE 12/07/06 1 Y-05A 11539744 MEM INJECTION PROFILE 12I06I06 1 S-02A 11285936 MEM PROD PROFILE 08/17/06 1 12-32 11536184 USIT 12/05/06 1 MPS-10A 11486087 COMPOSITE WFLILDL 12/14/06 1 Z-19A 11226013 SCMT 10/28/06 1 Y-30L1 11588700 MEM PROD PROFILE 12/23/06 1 E-11 B 11434757 DSI 10/24/06 1 E-11 B 11434760 DSI 10I29I06 1 E-11 B 11434760 FMI 10/29/06 1 G-14A 11485777 MEM PROD PROFILE 11/27/06 1 G-14A 11485777 SCMT 11/27/06 1 ni cnco nr~r~inun onn_~ n~ nc~nr n BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: 11 1I u • ~" \ Re: P2-37 K-Valve Z~3? ~ P Subject: Re: P2-37 K-Valve From: James Rebg yim_regg@,admin.state.ak_us> Date: Thu, 04 Jan 2007 13:52:02 -0900 '['~~: "G}'E3, G<is Lift ~n~~r" °=GPRGasLittEn~~r'~i.BP.c~~i7~~ ~`C: Soh rah Tati~cshi ~sohrab.Tafreshi~~r'bp~com=~~ // I Thanks for the information. We will send a letter approving the installation; who should it be addressed to? Also, we will need a copy of the K-valve test done by the Pad Operator. Jim Regg AOGCC GPB, Gas Lift Engr wrote: Jim, The TRSSSV in well P2-37 has a control line integrity issue and required the installation a K-Valve for state compliance. I completed a K-Valve design as a contingency plan if the slickline crew could not successfully troubleshoot the TRSSSV and restore it to service. There was a miscommunication issue and the K-Valve was installed on 12/24/06 prior to getting your approval of the K-Valve design. After installation, the K-Valve was tested by the Pad Operator and successfully closed at a Pwf of 539 psi. I have called Winton to inform of the situation and apologize for not getting the design to you prior to the installation of the K-Valve. I have attached the Wireline Work Request and K-Valve Design Sheet for your review. «P2-37 K-Valve Request 12-21-06 .ZIP» Please feel free to call if there are any questions or issues you would like to discuss. Regards, Johnny Kenda Arctic Lift Systems Inc. GPB, Gas Lift Eng. 907-659-5863 907-659-3423 (p) 601-807-8992 (c) 1 of 1 1/4/2007 1:53 PM R ~ ~., ~I~ ~,, Wireline Work Request R Well: P2-37~ AFE: PMP02WL37-C Date:_12/21/2006 Engineer: __ _ Kenda _ _ IOR: 500 FTS: AWGRS Job Scope: SSSV Reset for Rate Problem Description FI25 Levef. Well has Ieakinc~TRSSV. SL trying to troubleshoot, may need K Valve if TRSSV can't be repaired. Initial Problem Review Remedial Plan - WIRELINE ACTION K-Valve set to flow and remain open with Pwh_~ greater than 400 psi. _ _ _ _ _ HES needs to set valve at 549 si 60 degrees. _ _ _ _ __ Date Work Completed Well Status/Results Date by Problem Resolved ? Y N Well Review (Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate (STBL/D) Avg. WC (%) Lift Gas (MMSCF/D) TGLR (SCF/STBL/D) FTP (psi)/Steady? CLP (psi)/Steady? Casing Press. (psi)/Steady? Orifice Depth: __ IA Fluid Level -....-- Date of FL Survey: _ / / -_ Follow-up Recommendations: Expected NOB: Actual NOB: MGOR used for NOB: MAINTENANCE ONLY (e.g. Fix AC, Shallower for Slugging) '. ' RATE (Non-Post-WW) (e.g. deepen, optimize orifice) Post-Wellwork "K" Valve Calculation Sheet • Well # P2-37 Date: 12/21 /06 Test Data Test Date 11/17/06 Gross Fluid Rate 5037 BLPD Flowing We{{ Head Pressure 454 psi Flowing Well Head Temperature 127 deg F GOR 3366 scf/bbl TGLR 1295 scf/bbl Flowing Pressure Calculations Based on Mukerjee and Brill Multiphase Flow Correlation "K" Valve Setting Depth TVD 2040 ft Flowing Tubing Pressure With Gas Lift NA psi Flowing Tubing Pressure Without Gas Lift 894 psi Flowing Tubing Pressure @ 400# Pwh 840 psi "K" Valve Test Rack Set Pressure at 60 deg F 549 psi ,,~ Valve Size ~ Volume Ratio 4-1/2" 1.314 ~wh ~ ~ Pal ~~37A 1<-JaP~lC _ - Tubing Pressure at Valve 840 - _ ~ _- _- __ --~ _ - - BPT (psis) 854 >1238 <1238 _ em erature de Fat Valv 136 p (. 9 )- -- - - - a b -- - - -- _ 1.398 2.32104E-05 1 174648 146984 1 __ _ _ ____ ~ _ ___ Base Pressure ! 745.449664 -- ; __ _ ' c . , . -874.69 -854.57176 -~- -- Base Temp (TV-60) - 76 ~~ -- -- - ~ _ _ _ - __ - - - - - - --- 738.15517' 734.1530504 - - - ------ Corrected Pressure -- 734.1530504 ~ sia ~ p -~ - TCF ' _ 0.859261529 ~ ~~ __~ _ olume Ratio for Valve Size - 1.314 I ~ - - ~ Pb @ 60 _ 721.779684 _ -- - - Test Rack Pressure = 549 I _~_- _ ~ -~ Volume Ratios 41/2" & 5 1/2" _ 1.314 - -_~____ 3 1/2", 1.257 ~ -- - - 2 7/8~ - 1.211 __ ----_ - - -- - 2 3/8" _ 1 204 - -- - -- ; . -~~.n~u.re C.1-~.~-~ o,.t Cl1fY~~av~ -~c~-Ors ~~ ~ ~ .--.--~ ~a~~~ ~ 1~'~07 Q cue cA.o~ -~s~- ~~ t nS~x,C(n~~ wzs 53~ ~ ~' d~ U . ~~~ i~¢~o~ a ~ a a a FRANK H. MURKOWSK/, GOVERNOR ~47~. OII• ~ ~7~47 333 W. 7"' AVENUE, SUITE 100 CO1~SFiRQA.'I'I011T CO1rII1'IISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 June 15, 2006 AOGCC Industry Guidance Bulletin No. 06-04 Subsurface Safety Valves Alaska Oil and Gas Conservation Commission ("Commission") regulations governing automatic shut in equipment are contained in 20 AAC 25.265. Where required, subsurface safety valves are to be fail-safe automatic surface controlled devices unless the Commission approves another type of subsurface valve. Recent installations of alternate subsurface valves have resulted in some confusion about the approval requirements. The Commission provides the following guidance on subsurface safety valves. Pre-approval is required for all alternative subsurface valves other than those that are surface controlled. A request far approval must include information about the mechanical configuration of the valve and specifications, fluid flow composition, pressures, model used to size the valve, trip pressure and any other information that establishes the suitability of the valve as an alternate to a surface controlled subsurface safety valve. All installed subsurface controlled valves must be flow tested at least every 6 months. The operator shall maintain an inventory list of all wells with alternate subsurface safety valves installed showing well, date of installation, type of valve, last test date and test result. in order to ensure regulatory compliance, please share this guidance with all appropriate members of your organizations. Please direct q estions or discussion to Jim Regg at (907) 793-1236. ~~ Re: P2-37A (ZOS-057): Request to flow well without SSSV i ~- Subject: Re: P2-37A (205-057): Request to flow well without SSSV From: Thomas Maunder <tom maunder@,admin.state.ak.us> Date: Tue, 19 Dec 2006 10:39:07 -0900 To: "~~ arner. Ross L" ~~-Ross.«/~uneri"a~bp.coin Ross, Your request is appropriate. As planned in your procedure, the SSSV must be installed following the 24 hour flow period. The SSV must be capable of shutting in the well while it is being tested. Call or message with any questions. Tom Maunder, PE AOGCC Warner, Ross L wrote, On 12/19/2006 10:32 AM: Dear Mr. Tom Maunder, I am requesting permission to flow this well for 24 hours without a SSSV in place after the Scale Inhibitor is pumped. Listed below is a general outline of this work. Currently a coil unit is rigging up on the well. Drilling permit for this well is 205057 The SSSV has been out of this well for over fourteen days, but the well has been shut in since 11 /19/06. The main reason for this request is two fold: 1) obtain an immediate test after a two hour soak period and for general well cleanup. 2) During November the Field made many unsuccessful attempts at setting the SSSV. Warming the tubing up may assist in making a set after this job. Ross Warner Phone # 250-3441 P2-37A: Scale Cleanout and Scale Inhibition Treatment. Summary 1 S Pull the SSSV. Drift tubing to Deployment Sleeve. 2 C Scale Cleanout and Underream. 3 C Scale Inhibition Treatment with coil immediately after SCO. 4 O Obtain well test. Flow well for 24 hours. 5 S Set SSSV 6 O Well head sampling. 1 of 1 12/19!2006 10:39 AM STATE OF ALASKA ALAS IL AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ®Oil ^ Gas ^ Plugged p Abandoned zoAACZS.,os ^ GINJ ^ WINJ ^ WDSPL No. of Completions ^ Suspended p WAG zoAACZe.,,o One Other 1 b. Weli Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 3/18/2006 12. Permit to Drill Number 205-057 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 3/9/2006 13. API Number 50-029-22576-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 3/14/2006 14. Well Name and Number: PBU P2-37A 287 SNL, 1342 EWL, SEC. 14, T12N, R14E, UM Top of Productive Horizon: 2424' SNL, 5188' EWL, SEC. 13, T12N, R14E, UM g. KB Elevation (ft): 52.1' 15. Field /Pool(s): Prudhoe Bay Field /Point Mclntyr Pool Total Depth: 3178' SNL, 271' EWL, SEC. 18, T12N, R15E, UM 9. Plug Back Depth (MD+TVD) 14419 + 9119 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 681585 y- 5998297 Zone- ASP4 10. Total Depth (MD+TVD) 14453 + 9130 Ft 16. Property Designation: ADL 034627 _ TPI: x- 690762_ y- 5996388 Zone- ASP4 Total Depth: x- 691145 Y- 5995643 Zone- ASP4 11. Depth where SSSV set 2110' MD 17. Land Use Permit: 18. Directional Survey ®Yes p No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD ROP / GR / MPR, MGR / CCL / CNL 22. ASING, INER AND EMENTING ECORD CASING ETTING EPTH MD ETTING EPTH-TVD HOLE MOUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM S2E CEMENTING RECORD PULLED 20" 94# H-40 Surface 80' Surface 80' 30" 250 sx Arcticset Ap rox. 10-3/4" 45.5# NT80LHE 40' 4621' 40' 3719' 13-1/2" 1130 sx PF'E', 375 sx Class 'G' 7-5/8" 29.7# USS95 / NT13Cr80 38' 13481' 38' 8987' 9-7/8" 485 sx Class 'G' 3-,/z" x z-~/a° 8.81 # / 6.16# 13Cr80 13118' 14453' 8771 9130 4-1/8" x 3-3/4" 131 sx Class 'G' 23. Perforations open,to Production (MD +TVD of Top and, " 24. TUBING RECORD Bottom Interval, Slze and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr 13151' 13095' MD TVD MD TVD 13800' - 13860' 9006' - 9002' 14010' - 14050' 9012' - 9021' 25. AetD„ FRACTURE, CEMENT SQUEEZE, ETC. 14070' - 14110' 9026' - 9036' 14170' 14190' 9052' 9057' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED - - 5250' Freeze Protected with 80 Bbls of Diesel 26• PRODUCTION TEST Date First Production: April 7, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 4/19/2006 Hours Tested 11 PRODUCTION FOR TEST PERIOD • OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-Oll I~AT10 176 1,104 Flow Tubing Press. 26 Casing Pressure 2,384 CALCULATeo 24-HOUR RATE OIL-BBL 1,677 GAS-MCF 1,852 WATER-BBL 5,385 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of Iithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Su It core chips; if none, state "none". None ' ~ ~~,{ 7~~ 0 7 w~ ~..~- ~' /.~ y ~ J rs ~~ ~ ~ ~~ ~~~ ~1_ ~~~~ ~~~ MA1` ~ ~ 20Q6 -.-, -.~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. 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". Top Kuparuk / LC3 13462' 8976' None LC2 13492' 8994' LC 1 14175' 9053' L61 1431 T 9087 LA 14352' 9097' 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. Or +~ / `1 ~ Signed Terrie Hubble ~ Title Technical Assistant Date / ~~o PBU P2-37A 205-057 Prepared ey Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. t)rl~~Inq Engineer: Mary Endacott, 564-4388 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. Irma 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. {TeM 4b: TP{ (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. ITeM 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. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion}, so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". ITeM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Operations Summary Report Legal Well Name: P2-37 Common Well Name: P2-37 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours I Task f Code ' NPT _ _ I` 2/28/2006 02:00 - 02:30 0.50 MOB I P Start: 2/27/2006 Rig Release: 3/18/2006 Rig Number: N1 Page 1 of 18 Spud Date: 8!1611995 End: 3/18/2006 Phase Description of Operations PRE 02:30 - 12:00 I 9.50 MOB P PRE 12:00 - 00:00 ~ 12.00 MOB N WAIT PRE !2006 00:00 - 02:00 2.00 MOB N WAIT PRE 02:00 - 12:00 10.00 MOB N WAIT PRE 12:00 - 16:00 1 4.00 f RIGU I P I I PRE 16:00 - 00:00 I 8.001 BOPSUR P I I PRE 3/2/2006 ~ 00:00 - 01:00 ~ 1.00 ~ BOPSUp P ~ ~ PRE 01:00 - 04:00 I 3.001 KILL I P I I PRE 04:00 - 04:40 I 0.671 CLEAN I P I I PRE 04:40 - 08:00 3.331 CLEAN P I PRE 08:00 - 19:00 I 11.001 CLEAN P PRE 19:00 - 21:30 I 2.501 CLEAN I P l I PRE 21:30 - 22:00 ~ 0.50 ~ CLEAN ~ P ~ ~ PRE 22:00 - 00:00 2.00 CLEAN P PRE 3/3/2006 00:00 - 00:45 0.75 CLEAN P PRE SAFETY MEETING. Held pre rig move meeting with all personnel. Reviewed rig move plan and hazards. Moved rig to P2 pad with no incidents. Rig on standby while waiting for well and location prep. Removed wellhouse and flowline. Surveyed rig footprint area. Wait on Veco to grade location level for rig footprint. Rig on standby while waiting for Veco to arrive on location. Veco graded location level for rig footprint. Survey location again for level. Little Red on location attempt to kill well with 4% Bio and pressure test OA.Tubing pressure 250 psi. Back up to well Tubing pressure 450 psi. Close SSSV. Back over well. ACCEPT RIG AT 12:00 HR5. N/U BOPE. General rig up of tanks, trailers and hardline. Test BOPE. Test witnessed by BP WSL Rick Whitlow, AOGCC witness waived by Inspecter Jeff Jones. Send test report to AOGCC. Pump 5 bbls methanol, insert dart, displace dart with KCI water. Dart on seat at 57.7 bbls. Pump open SSV and SSSV. Hold 4500 psi on SSSV. SIWHP = 320 psi. Kill well with 9.7 ppg Brine / Biozan. Pump 2.9 bpm at 2080 psi. Pump 220 bbls. Monitor well. Well is dead. M/U BHA #1, U/R BHA with BOT DB UR with 6.81" blades. OAL = 52.95'. RIH with UR BHA. Run SWS CT Inspect on coil on trip in hole. RIH at 80 fpm. Start reeming operation at 13421 CT measured..6 bpm at 1700 psi, increase rate to 1.29 bpm at 4000. RIH13422.4 Cutter pressure fell to 3000psi. Knives open, Increase rate to 1.81 @ 3600 psi. Ream at 1 ft/min PU, 48.5 K Up Wt. Underreeming at 1.9 bpm at 1700 psi .2ft/min. establish pattern increase rate to 2.3 ~ 2290 psi. time ream down at .2 fUmin. Ream down at 10 fph to prevent stalling. Had total of 5 stalls to get started. UR with 2.4 bpm, 2600 psi. No stalls at i0 fph. Last stall at 13,465'. UR down to 13522' at 10 fph. Take scale samples every 10'. Backream up to 13450' at 5 fpm. 46K up wt. UR down at 1 fpm, 2.5 bpm, 2800 psi, 5K down wt. UR down to 13522'. No stalls or motor work. Pull up into tubing with no pump, no overpull. Pul! to 13050'. RIH to 13470'. Insert 3/4" steel ball and displace to circ sub. Ream down while circ. Ball on seat at 51 bbls. Increase pump up to 3 bpm. POH while circ thru circ sub at 3 bpm, 2900 psi. Lay out underreaming BHA, underreamer blades appeared full open while underreaming, based on wear. Printed: 3/20/2006 12:12:00 PM BP EXPLORATION Operations Summary Report Legal Well Name: P2-37 Common Well Name: P2-37 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To ~ Hours ~, Task ~! Code ~~ NPT 3/3/2006 00:45 - 01:00 L _ 0.25 _ - LEAN P 01:00 - 01:45 0.75 CLEAN P 01:45 - 05:30 3.75 CLEAN P 05:30- 05:50 0.33 CLEAN P 05:50 - 13:00 7.17 CLEAN P 13:00 - 13:30 13:30 - 20:00 20:00 - 21:00 21:00 - 23:00 23:00 - 23:15 23:15 - 00:00 3/4/2006 00:00 - 02:00 02:00 - 04:00 04:00 - 04:45 04:45 - 05:00 05:00 - 06:30 06:30 - 07:50 Page 2 of i 8 Spud Date: 8/16/1995 Start: 2/27/2006 End: 3/18/2006 Rig Release: 3/18/2006 Rig Number: N1 Phase ~ Description of Operations PRE SAFETY MEETING -reviewed procedure, hazards and mitigation to make-up and run slickline PDS caliper logging BHA and dummy WS. PRE M/U PDS caliper logging BHA on slickline. PRE RIH w/ PDS caliper. Sat down at 13,200'. Unable to get any deeper. POH. PRE M/U dummy whipstock BHA with 18' x 3.625" dummy whipstock to drift hole. PRE RIH with 3.6" x 18 ft dummy whipstock on S- line.. NO GO at 12225' which is in the tubing. Had to jar free. Seen 450 -650# drag for the first 300'. POH No debris or damage to tool. RIH with bailer. Clear at 12225 but set down at 13211'. Hard set down no over pull. POH. Bailer recovered a couple finger tip sized pieced of asphalstine imbedded with some form of carbonite possibly Barium Carbonite (Witherite). Release S- line. 0.50 CLEAN N DPRB PRE PU cleanout assy with four 3.625" O.D. weight bars to simulate whipstock length and stiffness. 6.50 CLEAN N DPRB PRE RIH to 13520. No problems No motor work. PU to tail pipe. Circulate 30 bbl hi vis pill. Chase pill to surface. Got about 20 gat of high weight scale /metal on shaker. POH while pumping 3 bpm. 1.00 CLEAN N DPRB PRE Lay out BHA. Well is dead. SSSV press = 4600 psi. 2.00 CLEAN N DPRB PRE Rig up SWS Sline unit. MIU 3.6" x 18' dummy whipstock on Sline tools. 0.25 CLEAN N DPRB PRE PJSM for S-line dummy WS run. 0.75 CLEAN N DPRB PRE Continue M/U dummy WS BHA on S-line. 2.00 CLEAN N DPRB PRE Continue dummy WS run on Sline. Sit down 3 times at 13,211', just below tailpipe. Jar down and then need to jar upwards to free. 600# overpull off bottom. POOH. 2.00 CLEAN N DPRB PRE POOH with dummy whipstock. Rig down Sline unit. Not able to run whipstock on E-Line. Will deploy it on CT with BHI tools and BOT FAIV. Will run Memory GR/CCL first to flag coil for depth control. 0.75 WHIP P WEXIT Cut 50' for chrome mgmU M/U coil connector and P-test 0.25 WHIP P WEXIT PJSM to pick up and run memory GR/CCL tool with BHI mud-pulse tools and BOT FAIV. Plan to shallow depth test Baker tools and proceed to flag pipe based on tubing jewelry near tubing tail. Prep for setting WS on coil. 1.50 WHIP P WEXIT M/U SLB memory GR/CCL with BHI mud pulse tools and BOT FAIV. 1.33 WHIP P WEXIT RIH to 3000 TEST Baker MWD Rate Pressure on/off 1.6 1700 off 1.8 2370 yes pulsing 2.0 2644 drop to 1400 psi good downlink .5 hertz data rate 2.0 2900 drop to 1500 psi good down link .5 hertz data rate 2.15 2950 drop to 1700 psi good down link .36 hertz data rate This is the max design data transmittion rate. This is the time it takes to transmit one bite of information. Painted: 3/20/2006 12:12:00 PM BP EXPLORATION Operations Summary Report Page 3 of 18 Legal Well Name: P2-37 Common Well Name: P2-37 Spud Date: 8/16/1995 Event Name: REENTER+COMPLETE Start: 2/27/2006 End: 3/18/2006 Contractor Name: NORDIC CALISTA Rig Release: 3/18/2006 Rig Name: NORDIC 1 Rig Number: N1 _i Date From - To I Hours ~! Task Code NPT Phase Description of Operations 3/4/2006 106:30 - 07:50 1.3~WHIP ~ P f WEXI7 ~ Will check to see it FAIV armed once back to surface. FAIV arms theoritically at 2.3 bpm 07:50 - 09:00 1.17 WHIP P WEXIT 09:00 - 09:50 0.83 WHIP P WEXIT 09:50 - 10:45 I 0.921 WHIP I P I I WEXIT 10:45 - 11:00 0.25 WHIP P WEXIT 11:00 - 11:20 0.33 WHIP P WEXIT 11:20 - 11:55 0.58 WHIP P WEXIT 11:55 - 12:40 0.75 WHIP P WEXIT 12:40-14:00 1.33 WHIP P WEXIT 14:00-16:001 2.OOIWHIP IP I (WEXIT 16:00-16:101 0.171WHIP IP I (WEXIT 16:10 - 17:30 1.33 WHIP P WEXIT 17:30 - 21:00 3.50 WHIP P WEXIT 21:00-21:15 0.25 WHIP P WEXI7 21:15 - 21:30 0.25 WHIP P WEXIT 21:30 - 00:00 2.50 WHIP P WEXIT 3/5/2006 00:00 - 00:15 0.25 WHIP P WEXIT 00:15 - 01:15 1.00 WHIP P WEXIT 01:15 -04:00 2.75 WHIP P WEXIT 04:00 - 04:15 0.25 WHIP P WEXIT 04:15-04:30 0.25 WHIP P { WEXIT 04:30 - 05:00 0.50 WHIP P WEXIT 05:00 - 06:30 1.50 WHIP P WEXIT 06:30 - 09:00 2.50 WHIP P WEXIT 09:00 - 11:15 2.25 WHIP P WEXIT 11:15 - 12:00 0.75 WHIP P 12:00 - 12:30 0.50 WHIP P WEXIT 12:30-13:00 0.50 WHIP P WEXIT 13:00-14:00 1.00 STWHIP P WEXIT 14:00-16:45 2.75 STWHIP P WEXIT Continue to RIH to 12000'. Circulating at 1.2 bpm Q 1200 psi. LOG 12000 to 12520 at 30 fUmin. Flagg at 13400 EOP. Log from 12520 to 11100 @ 60 ft/min. Log 11100 to 11000 ~ 600 ft/hr. POH at 1.2 bpm ~ 1050 psi. LOG down 11200 to 11350 2.2 bpm 3530 psi to acquire MW D GR data for comparative purpose. POH to surface circulating 1.1 bpm at 870 psi. Replace bearing in Goose neck. POH to 200'. Confirm the FAIV was not armed. Shut down pump and restart pump. Broke circulation. POH. LD BHA and memory tool. Correction to flag =+4'. FAIV ports showed signs of washing out: Lesson learned circulation in and out at 1.2 bpm washed out ports. Secondly the shear screws in FAIV partially sheared. We were close to activating FAIV. UP Baker whipstock and new FAIV. Stab onto well. Circulate 1.8 bpm at 2900 psi.to check MW D. Shut Down FAIV activated. Stab off well. Redress FAIV. Stab onto well. RIH with WS. Correct to flag, reset to 13494.3'. P/U to 13489.6(bottom of string). WS length 17.53ft. Orient to 21 degrees ROHS. BHI tools working well at 2.ibpm. Pressure up to 4300psi (2.5 bpm) to arm FAIV. Release WS. TOWS at 13472'. Pick-up and set down 2k# to confirm placement. POOH to lay down WS setting BHA. Continue POOH w WS setting tools. OOH -lay down tools. Pick up cementing nozzle. RIH to abandon perfs and lay in cement to above TOWS. Tagged 2k# at 13487'. Perform infectivity test. Hole took no fluid at 1000psi. PJSM for cementing -lay in to abandon perfs and support whipstock. R/U cementers. Pick-up to 13440'. Pump 15 bbls 9.7 brine, 2 bbls fresh water, 12 bbls 15.8ppb unislurry cement, 2 bbls of water and 15 bbls brine. WCTOC 12600'. P/U to 12300' and wait for cement to swap prior to cleanout with 1.5ppb biozan. RIH to WS circulating 2.73 bpm at 2750 psi.. Seeing pressure increase indicating in cement at 12800'. wash to WS at 13486. POH POH. Flush stack Cut 150 of coil .Pipe management for 13% CR production tubing. Behead pull and presure test coil connector. MU window milling BHA. RIH at minumum pump rate .66 by ~ 460 psi .13400. UP Wt Printed: 3/20/2006 12:12:00 PM BP EXPLORATION Operations Summary Report Legal Well Name: P2-37 Common Well Name: P2-37 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task ,Code ~, - -- 3/5/2006 ~ 14:00 - 16:45 I 2.751 STWHIPI P Page 4 of 18 Spud Date: 8/16/1995 Start: 2/27/2006 End: 3/18!2006 Rig Release: 3/18/2006 Rig Number: N1 NPT Phase Description of Operations 50K DN WT 9.7K. Tag WS and correct to 13477'. Pinch point 5.5' below top of WS. At 2.7 bpm 2250 psi FS. Mill window per time schedule Continue milling window at 1 fUhr. Normal milling parameters: 3100-3400psi circ pressure, 2.5-4k# WOB. Max of 5000 psi circ p and 5.5k# WOB. No stalls. Mill-off at 13483.7'. 6.7' window length. Drill 10' of open-hole. Ream and dry tag .Good clean window. Circulate new mud to the bit POH laying in new mud. LD window milling BHA Behead coil. Pull test to 35000# and pressure test to 3500 psi. M/U 3.2 degree motor drillig assembly. RIH wo pumping. RIH to 13200 attempt tie-in. Attempt to tie-in.having trouble with MWD software depth. decided to tag td and relog. Attempt tie-in to GR from 13200' to 13280'. Log at 100'/hr. Continuing BHI depth encoder problems. Change out BHI depth encoder system. Calibrate. Tie-in to GR from 13200' to 13280'. Log at 100'fhr. Depth correct based on GR and PDC log. Working on getting toot to orient to exit window. Working on getting tool to orient to exit window. POOH for BHI orienter failure. Laydown BHI HOT and DGS. Download tools. P/U new BHI HOT and DGS. RIH with new BHI HOT and DGS to attempt to drill build again. SSSV tagged at 4550 psi. Pumped up to 5000 psi, still no go. Cycle SSSV shut and open. POH Swap BHA RIH Set down on SSSV at 2i 09' holding 5050psi on control line. Set down 4 K. Pressure up to in increments to 1800 psi gradual bleed off. Volume to pressure up indicated some bypass. Increase slack off wt to 10K. No Go. Tap SSSV at 40 ft/min with 1400 psi in well. NO GO. POH for S line unit. LD nozzel BHA. Wait on S-line. Held PJSM with all personnel for slickline operations. R/U S/Line tools & stripper head. M/U tools & stab stripper on lubricator. RIH with 3.825" centralizer. Zero C~3 rig floor. Set down 02100 W LM. POOH & L/O S/Line tools. Pressure tbg to i800psi. RIH with 3.825" no-go, 3" bar, 3.625" centralizer & flapper checker. OAL - 72" & from no-go to flapper checker = 56". Tag several times C~3 same spot (2103' WLM). Run up & down thru valve without pulling any bind. Dump SSSV pressure & still tag @ same spot. Run up & down thru valve without pulling any bind. POOH & pop off & inspect flapper catcher. Observe the btm 3 WEXIT 16:45 - 00:00 7.25 STWHIP P WEXIT 3/6/2006 00:00 - 05:00 5.00 STWHIP P WEXIT 05:00 - 07:45 2.75 STWHIP P WEXIT 07:45 - 08:15 0.50 STWHIP P WEXIT 08:15 - 11:00 2.75 STWHIP P WEXIT 11:00 - 12:00 1.00 STWHIP P WEXIT 12:00 - 12:45 0.75 DRILL P PROD1 12:45 - 13:45 1.00 DRILL P PROD1 13:45 - 16:30 2.75 DRILL P PROD1 16:30 - 19:05 2.58 DRILL N S FAL PRODi 19:05 - 19:40 ~ 0.58 ~ DRILL ~ N ~ SFAL ~ PRODi 19:40 - 21:45 2.08 DRILL N S FAL PROD1 21:45 - 22:30 0.75 DRILL P PROD1 22:30 - 22:45 0.25 DRILL P PROD1 22:45 - 00:00 1.25 DRILL N DFAL PROD1 3/7/2006 00:00 - 00:15 0.25 DRILL N DFAL PRODi 00:15 - 02:15 2.00 DRILL N DFAL PRODi 02:15 -04:15 2.00 DRILL N DFAL PRODi 04:15 - 04:30 0.25 DRILL N DFAL PROD1 04:30 - 05:45 1.25 DRILL N DPRB PROD1 05:45 - 06:00 0.25 DRILL N DPRB PROD1 06:00 - 08:00 2.00 DRILL N DPRB PROD1 08:00 - 08:30 0.50 DRILL N DPRB PRODi 08:30 - 09:00 0.50 DRILL N DPRB PROD1 09:00 - 09:30 0.50 DRILL N DPRB PRODi 09:30 - 10:00 0.50 DRILL N DPRB PROD1 10:00 - 11:25 1.42 DRILL N DPRB PRODi 11:25 - 11:50 0.42 DRILL N DPRB PROD1 11:50 - 12:45 0.92 DRILL N DPRB PRODi 12:45 - 13:05 0:33 DRILL N D PRB PROD1 13:05 - 14:20 1.25 DRILL N DPRB PROD1 14:20 - 15:25 1.08 DRILL N DPRB PROD1 15:25 - 16:15 0.83 DRILL N DPRB PROD1 16:15 - 17:20 I 1.081 DRILL I N I DPRB I PROD1 Printed: 3/20/2006 12:72:00 PM BP EXPLORATION Page 5 of 18 Operations Summary Report Legal Well Name: P2-37 Common W ell Name: P2-37 Spud Date: 8/16/1995 Event Nam e: REENTE R+COM PLET E Start : 2/27/2006 End: 3/18/2006 Contractor Name: NORDIC CALIST A Rig Release: 3/18/2006 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To ' Hours ' Task Code ~ NPT I Phase ~I Description of Operations ~ 3/7/2006 - __1 16:15 - 17:20 _- - , 1.08 _ DRILL j . N _ DPRB _ _ - - ! PROD1 - _- - ---- - brass pins bent upwards -could be that the flapper is partially open and/or the pins bent after dumping the pressure. 17:20 - 18:00 0.67 DRILL ! N DPRB PROD1 M!U & RIH with 3.825" no-go, 3" bar, 3.625" centralizer, 5" x ~ 1-1/4" stem & flapper checker. From no-go to flapper end = i 133". Run up & down thru valve and pull bind. 18:00 - 21:00 3.00 DRILL ! N DPRB PROD1 POOH. Wait on friction tool. PJSM on Sline work after crew I changeout. 21:00 - 23:45 2.75 DRILL i N DPRB PROD1 RIH with no-go to top of SSSV. POOH, L/D no go. P/U and RlH with friction tool to attempt to move the SSSV sleeve. No movement noted. 23:45 - 00:00 0.25 DRILL N DPRB PROD1 Friction tool stuck in place. Attempt to circulate to aid in release. 3/8/2006 00:00 - 02:00 2.00 DRILL i N DPRB PROD1 Friction tool remained stuck at SSSV. Small movement of about 4 feet noted periodically. No further progress. Send for wire cutter. 02:00 - 03:45 1.75 DRILL N DPRB PROD1 Wait on wire cutter and oil jar system to free stuck friction tool. 03:45 - 04:00 0.25 DRILL I N DPRB PROD1 Run Sline cutter into hole to free from stuck friction tool. 04:00 - 04:15 0.25 DRILL N DPRB PROD1 Cut sline and POOH 04:15 - 05:00 0.75 DRILL N DPRB PROD1 RIH with overshot to fish sline cutter. 05:00 - 05:30 0.50 DRILL N DPRB PROD1 POOH with cutter. 05:30 - 06:00 0.50 DRILL ~ N DPRB PRODi RIH with grapple and oil jars on Sline to fish friction tool. 06:00 - 07:15 1.25 DRILL N PROD1 Pull friction tool free. POOH & UD S/Line tools. 07:15 - 07:30 0.25 DRILL N DPRB PROD1 Crew change. Held PJSM with all personnel for slickline operations. 07:30 - 08:30 1.00 DRILL N DPRB PROD1 Wait on LIB tool. 08:30 - 09:00 0.50 DRILL N DPRB PROD1 M/U & RlH 3.75" tapered LIB spaced 56" from 3.825" no go. (Zero @ no-go). Set C~ SSSV & tap down 1x. 09:00 - 10:15 1.25 DRILL N DPRB PROD1 POOH with LIB tool. Observe a +/-45degs indentation @ the tip of the LIB with some scratch marks on the side. Review situation with PEs & ANC & decide to run the swedge tool to attempt to shift the flapper into the recess. 10:15 - 11:45 1.50 DRILL N DPRB PROD1 M/U &RIH 4-1/2" GR with swedge tool. OAL - 122.5". (Zero no-go). Set @ 2097' SLM. Work tool down 4'. OAL of TRCF = 61.17". Thus will locate with 57" (ca. 5') of swedge below TRCF. 11:45 - 12:15 0.50 DRILL N DPRB PRODi POOH with swedge tool. Observe scratch marks on tapered section of tool. Also tale-tell brass pins on no-go were sheared. File up scratch marks & prep tool for repeat run. Need to work tool ca. 1' deeper. 12:15 - 15:15 3.00 DRILL N DPRB PROD1 RIH with wedge tool. OAL -122.5". Same as last run. Work SSSV flapper to move into recess 15:15 - 15:25 0.17 DRILL N DPRB PROD1 POOH with wedge tool. Full travel of 62" down to no-go gained resulting in clearance of 3.81". Need to verify. 15:25 - 16:15 0.83 DRILL N DPRB PROD1 Run flapper checker to verify clearance past the flapper in SSSV. 16:15 - 16:45 0.50 DRILL N DPRB PROD1 Flapper checker came back clear. None of the brass pins were damaged. 3.81" clearance verified. 16:45 - 17:45 1.00 DRILL N DPRB PROD1 RIH with swedge. Set ~ 2102' SLM. Move down to 2107' SLM. 17:45 - 18:45 1.00 DRILL N DPRB PRODi POOH with swedge tool. 18:45 - 19:00 0.25 DRILL N DPRB PROD1 Crew change. Held. PJSM with all personnel for slickline operations. 19:00 - 20:45 1.75 DRILL N DPRB PROD1 M/U tools for drift run. Take out all QC's. M/U 8' x 1-718" stem, 5' x 2-1/8" & LSS. RIH with 3.805" swedge drift thru TRCF to Printed: 3/20!2006 12:12:00 PM BP EXPLORATION Page 6 of 18 Operations Summary Report Legal Well Name: P2-37 Common Well Name: P2-37 Spud Date: 8/16/1995 Event Name: REENTER+COMPLETE Start: 2/27/2006 End: 3/18/2006 Contractor Name: NORDIC CALISTA Rig Release: 3/18/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task ~ Code NPT Phase Description of Operations - - - - _ _._ 3!8/2006 19:00 -20:45 1.75 - -~ - DRILL N DPRB ~ PROD1 12118' SLM i.e. ca. 10-12' thru flapper. PUH & redrift 20x with no 20:45 - 21:15 0.50 DRILL I N 'DPRB PROD1 21:15 - 22:45 1.50 DRILL i N DPRB PROD1 22:45 - 23:15 ~ 0.50 ~ DRILL ~ N ~ DPRB ~ PROD1 23:15 - 00:00 0.75 DRILL N DPRB PROD1 00:00 - 01:45 1.75 DRILL N DPRB PROD1 01:45 - 02:45 ~ 1.00 ~ DRILL ~ N ~ DPRB ~ PROD1 02:45 - 03:15 I 0.501 DRILL I N I DPRB I PROD1 03:15 -04:15 1.00 DRILL N DPRB PROD1 04:15 -04:45 0.50 DRILL N DPRB PROD1 04:45 - 05:00 0.25 DRILL N DPRB PRODi 05:00 - 05:15 0.25 DRILL P PROD1 05:15 - 06:30 I 1.251 DRILL I P 06:30 - 09:00 I 2.501 DRILL I P PROD1 PROD1 09:00 - 10:20 I 1.331 DRILL I N 1 SFAL 4 PROD1 10:20 - 10:50 0.50 DRILL P PROD1 10:50 - 11:10 0.33 DRILL P PROD1 11:10 - 14:25 3.25 DRILL P PROD1 14:25 - 15:15 0.83 DRILL N DFAL PROD1 15:15 - 16:15 1.00 DRILL N DFAL PROD1 16:15 - 16:40 0.42 DRILL P PROD1 problems. POOH with drift toot. C/O tools to 5' x 2-5/8" stem &LSS. OAL - 95.5" & spaced 62" from 3.825" no go. M/U &RIH TRCF dimpling/lock-out tool. Set @ 2107' SLM. Pressure up wellbore in stages to 1500psi to actuate collet to push down flow-tube (if not already down). Beat on dimpler several times to dimple flow tube with 1450psi WHP. Bleed off WHP. PUH & get stuck with dimpling tool. Suspect we're hydraulically locked in due to cold/gelled-up flopro fluid in wellbore & tight tolerance of O-ring & no-go tool. Surge wellbore a couple of times & pull free. Will re-run dimpler 2x with smaller stem & without collet & O-rings to allow better fluid bypass. POOH with dimpling/lock-out tool. Bullhead 33bbls of warm flopro mud downhole @ 0.5bpm/1500psi. Meanwhile redress lock-out tools. Remove O-rings & collet. MU 8' x 2-1/8" stem, 3' x 1-7/8" stem, OJs & LSS. RIH with 4-1/2" TRCF lock-out tool to no-go @ 2107' SLM. Jar down for 20mins to dimple flow-tube. Tap up. PUH & hung up @ 2030' SLM. Hit jar lick & come free. POOH with dimpling/lock-out tool. Redress &RIH with 4-1l2" TRCF lock-out tool to no-go @ 2107' SLM. Jar down for 20mins to dimple flow-tube. POOH with dimpling/lock-out tool. R/D SLB S/Line. Held pre-operations resumption safety meeting with all personnel. Review well status, hazards and drilling BHA M/U procedures. M/U drilling BHA #10 with 3deg X-treme motor, BHI HOT-DGS-DPS-SBS-BGPM package & rebuilt Hughes 3-314" x 4-1/8" RWD2ST bicenter bit #4. Scribe tools. Initialize BHI tools & M/U injector. RIH w BHA #10 to drill build section. Passed all the way through the SSSV with BHA, then pulled BHA back above the SSSV and then proceeded down to GR tie in depth. Pass the SSSV at 25 ftfmin w 5500 psi on the control line of the SSSV as precaution. No indications of sticking passing the SSSV on weight indicator. Attempt tie in to GR and function check the BHI tools/orienter. Frozen dump line off of mud manifold (connects the BHI surface actuator to the mud pit). Tie in to GR. Correct +2.5'. Function check the BHI tools/orienter. Run through window and drill build section. ROP 15 ft/hr initially -motor stalling assuming stick-slip with tools across window. ROP of 40 ft/hr average. Problems downlinking to BHl tools. Pull up into 7-5/8" casing to Orient. Run back to bottom. BHI tools able to orient on bottom, but not able to hold TFO as the bit starts to drill. 3 attempts unsuccessful. Drilling ahead using manual mode and compensating for Printed: 3/20/2006 12:12:00 PM BP EXPLORATION Operations Summary Report Legal Well Name: P2-37 Common Well Name: P2-37 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 i Date From-To ,Hours Task Code ~~ NPT - ~ - 3/9/2006 16:15 - 16:40 0.42 DRILL P 16:40 - 17:15 0.58 DRILL P 17:15 - 17:20 0.08 DRILL P 17:20 - 17:40 0.33 DRILL P 17:40 - 17:45 0.08 DRILL P Start: 2/27/2006 Rig Release: 3/18!2006 Rig Number: N1 Phase PROD1 PROD1 PRODi PROD1 PROD1 17:45 - 18:10 0.42 DRILL P I PRODi 18:10 - 20:15 2.08 DRILL N DFAL i PROD1 20:15 - 23:00 I 2.751 DRILL I N I DFAL f PROD1 23:00 - 00:00 I 1.001 DRILL I N I DFAL I PROD1 3/10/2006 00:00 - 00:30 0.50 BOPSU P PROD1 00:30 - 01:00 0.50 DRILL N DFAL PROD1 01:00 - 01:30 0.50 DRILL N DFAL PRODi 01:30 - 01:45 0.25 DRILL P PROD1 01:45 - 03:00 1.25 DRILL N DFAL PRODi 03:00 - 06:00 I 3.001 DRILL I N I DFAL I PROD1 06:00 - 10:00 I 4.001 DRILL I P I I PRODi 10:00 - 12:30 I 2.501 DRILL I P I PROD1 12:30 - 12:45 0.25 DRILL P PROD1 12:45 - 13:30 0.75 DRILL P PRODi 13:30 - 15:15 1.75 DRILL P PROD1 15:15 - 17:30 2.25 DRILL P PROD1 17:30 - 18:30 1.00 DRILL P PROD1 18:30 - 19:00 0.50 DRILL P PROD1 Page 7 of 18 Spud Date: 8/16/1995 End: 3/18/2006 Description of Operations reactive torque on BHI orienter. Average of 50 fUhr. P/U & downlink TF to tool. Drill to 13562' with 75R TF, 2.45/2.45bpm, 3100/3200psi, 3k WOB & 40fph ave BOP. P/U & downlink TF to tool. Drill to 13563' with 75R TF, 2.4/2.4bpm, 3100/3250psi, 3k WOB & 20fph ave BOP. P/U & downlink TF to tool. Tool will not orient. PUH above window & try to orient. Up wt = 32k. S/O wt = 12k. PVT = 317bb1s. Troubleshoot HOT. Try among other things, low & high flow rates without luck. Decide to POOH for inspect tools. POOH drilling BHR#10. Pull thru TRCF clean with pumps down. RBIH clean thru TRCF without problems. Continue POOH with drilling BHA. OOH. PJSM. S/B injector. UD drilling BHA. Check bit -grade 1/2/1. Observe the hydraulic orienter stuck after 400degs of rotation. Conduct weekly BOP function test. R/U hydraulic cutter & cut 50' of CT for chrome fatigue management. Have 15350' of CT left on reel. Behead & install SLB CTC. Pull test to 35k & pressure test to 3500psi. Meanwhile discuss BHA situation with BHI Germany & decide to rerun same BHA & keep the orienter on manual on next run. Swap out BCPM sub for subsquent memory data download. Held PJSM for M/U drilling BHA. M/U drilling BHA #11 with same 3deg X-treme motor, rebuilt Hughes 3-3/4" x 4-1/8" RWD2ST bicenter bit #5, BHI HOT-DGS-DPS-SBS & new BCPM package. Scribe tools. Initialize BHI tools & M/U injector. Download memory GR data. Logged RA Pip tag (~ 13485.8'. Corrected TOWS = 13476', TOW = 13481', BOW = 13488'. RIH drilling BHA #11 to 13200'. Downlink TF of 20R to tool. Run clean thru window & tag btm C~ 13565' correct CTD to 13563'. Drill to 13664' with 15R TF, 2.40/2.45bpm, 3100/3500psi, 4-6k WOB & 55fph ave instantaneous BOP. Drilling in manual mode compensating for reactive torque - 2nd BHI orienter. POOH for lateral drilling BHA. Pull slowly through the 7 518" casing to ensure good hole cleaning in larger diameter. PJSM prior to laying down BHA #11 and P/U BHA #12. UD BHA #10. Reset motor bend to 1.5deg & P/U BHI USMPR tool. Program the BHI tools for 2secs sampling rate & P/U lateral drilling BHA #12 with 1.Sdeg X-treme motor, BHI HOT-USMPR-DGS-DPS-SBS-BCPM package & rebuilt Hughes 3-3/4" x 4-1/8" RWD2ST bicenter bit #6. Scribe tools. Initialize BHI tools & M/U injector. RIH drilling BHA #12 to 13400'. Downlink to put tool in logging mode. Log down GR & tie-into Geology PDC log. No correction to CTD. Printed: 3/20/2006 12:12:00 PM BP EXPLORATION Operations Summary Report Legal Well Name: P2-37 Page 8 of 18 Common Well Name: P2-37 Spud Date: 8/16/1995 Event Name: REENTER+COMPLETE Start: 2/27/2006 End: 3/18/2006 Contractor Name: NORDIC CALISTA Rig Release: 3/18/2006 Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To !~ Hours ~ Task ~ Code I NPT I, Phase ~ Description of Operations 3/10/2006 19:00 - 20:00 I 1.00- _ _ _- - - ~ _ - - - DRILL ~ P ~ PROD1 ~ Run clean thru window without pumps. Continue RIH & tag 20:00 - 21:20 I 1.33 DRILL P PRODi 21:20 - 21:30 ~ 0.17 DRILL P PROD1 21:30 - 22:00. 0.501 DRILL I P I I PROD1 22:00 - 22:20 0.33 DRILL P PROD1 22:20 - 23:20 1.00 DRILL P PROD1 23:20 - 23:45 I 0.421 DRILL I P I I PRODi 23:45 - 00:00 I 0.251 DRILL I P I I PROD1 3/11/2006 00:00 - 00:05 0.08 ~ DRILL P PRODi 00:05 - 00:35 0.50 ~ DRILL P PROD1 00:35 - 00:40 0.08 DRILL P PROD1 00:40 - 00:45 0.08 DRILL P PROD1 00:45 - 01:05 0.33 DRILL P PRODi Oi:05 - 01:45 0.67 DRILL P PROD1 01:45 - 02:50 1.08 DRILL N SFAL PRODi 02:50 - 03:05 0.25 DRILL N SFAL PROD1 03:05 - 03:15 0.17 DRILL N SFAL PROD1 03:15 - 03:45 0.50 DRILL N SFAL PROD1 03:45 - 04:00 I 0.251 DRILL I P I I PROD1 04:00 -04:05 0.08 DRILL P PROD1 04:05 - 04:15 0.17 DRILL P PROD1 04:15 - 04:45 0.50 DRILL P PROD1 04:45 - 04:55 0.17 DRILL P PROD1 04:55 - 05:25 0.50 DRILL P PROD1 05:25 - 05:35 0.17 DRILL P PROD1 05:35 - 05:50 0.25 DRILL P PRODi btm. Working to get tool insync, PUH conducting MAD pass from 13,665 ft to 13,500 ft SD pump and switch data mode from logging to drilling mode. RIH and tag bottom at 13,667 ft Drilling with 94R TF. Working on communications skills between surface software and BHA. Setting up display monitor in ops cap. O = 2.612.6 bpm CTP = 3200 / 3600 psi; Vp = 308 bbls at 2130 hrs ROP 55 FPH Stopped at 13,690 ft to down link Down link data, PU off bottom, clean Drilling with 75R TF. 0=2.6/2.6 bpm CTP = 3200 / 3600 psi; Vp = 308 bbls at 2130 hrs ROP 55 FPH PU of bottom, SD pump, 1 min, Brings pump up, eased backed to before pulsing began. Took Survey at 13,720 ft Down link data. Adjusting the BPA to get the correct signal to orient the TF.. Orient TF from 75R to 145R by PU from 13,730 ft to 13,670 ft before. RIH BHI zeroed WOB Drilling with 140 R TF. 0=2.6/2.6 bpm CTP = 3200 / 3600 psi; Vp = 308 bbls at 2130 hrs ROP 55 FPH Took survey at 13745 ft by PUH and SD pumps P/U off btm for survey. RBIH to btm. Drill to 13769' with 145R TF, 2.65/2.65bpm, 3350/3575psi, 1.5k DWOB & 45fph ave ROP. P/U off btm for survey. RBIH to btm. P/U wt = 31 k. S/O wt = 8k. Drill to 13771' with 145R TF, 2.65/2.65bpm, 3350/3575psi, 1.5k DWOB & 60fph ave ROP. PUH & downlink TF to 115R. Wiper above window to TT in order to C/O BPA. R/U new BPA. P/test against new BPA - OK. Downlink TF to 20R. RIH clean thru window with pumps down. bring on pumps. Downlink to TF to 90R. Continue RIH to btm. Drill to 13785' with 90R TF, 2.5/2.5bpm, 3200/3425psi, 1.7k DWOB & 45fph ave ROP. P/U off btm for survey. RBIH to btm. Downlink TF to 135R. Drill to 13800' with 135R TF, 2.6/2.6bpm, 3200/3425psi, 2.25k DWOB & 30fph ave ROP. P/U off btm & survey 2x. RBIH to btm. Drill to 13820' with 135R TF, 2.5/2.5bpm, 3200/3600psi, 2.5k DWOB & 40fph ave ROP. Downlink TF 2x to 110R. Drill to 13832' with 110R TF, 2.5/2.5bpm, 3250/3600psi, 2.8k DWOB & 50fph ave ROP. Printed: 3120/2006 12:12:00 PM BP EXPLORAT{ON Operations Summary Report Legal Well Name: P2-37 Common Well Name: P2-37 Event Name: REENTER+COMPLETE Start: 2/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 3/18/2006 Rig Name: NORDIC 1 Rig Number: N1 Date ~~1 From - To ~~~ Hours ~~~ Task ~ Code ~ NPT Phase 3!1112006 05:50 - 06:00 0.17 DRILL ~ ~ PROD1 06:00 - 06:45 0.75 DRILL P PROD1 06:45 - 06:50 0.08 DRILL P PROD1 06:50 - 07:20 0.50 DRILL P PROD1 07:20 - 07:30 ' 0.17 DRILL P PROD1 07:30 - 08:20 0.83 DRILL P PROD1 08:20 - 08:25 0.08 DRILL P PROD1 08:25 - 09:00 0.58 DRILL P PRODi 09:00 - 09:50 0.83 DRILL P PROD1 09:50 - 10:20 0.50 DRILL P PRODi 10:20 - 12:30 2.17 DRILL C PROD1 12:30 -.13:45 1.25 DRILL C PROD1 13:45 - 14:15 I 0.501 DRILL I X I SFAL I PRODi 14:15 - 15:00 ~ 0.75 ~ STKOH ~ C ~ ~ PROD1 15:00 - 17:20 2.33 STKOH C PROD1 17:20 - 17:35 0.25 STKOH C PROD1 17:35 - 18:00 0.42 STKOH C PROD1 18:00 - 20:00 I 2.001 STKOH I C I I PROD1 20:00 - 22:45 I 2.751 STKOH I X I DFAL I PROD1 22:45 - 00:00 I 1.251 STKOH I X I DFAL I PROD1 3/12/2006 00:00 - 00:05 0.08 STKOH X DFAL PROD1 00:05 - 01:30 1.42 STKOH X DFAL PRODi 01:30 - 01:50 0.33 STKOH X DPRB PROD1 Page 9 of 18 Spud Date: 8/16/1995 End: 3/18/2006 Description of Operations P/U off btm for survey. RBIH to btm. Drill to 13846' with 105R TF, 2.55/2.55bpm, 3250/3600psi, 4k DWOB & 35fph ave ROP. Penetrated the kalubik shale @ +/-13820' (8939ftssvd) _> Came in 15ftssvd deeper than the prognosed 8924ftssvd. Angle Cbit = 95degs -will drill +/-130' and before getting out of the Kalubik. P/U off btm & downlink TF to 180R. Drill to 13866' with 180R TF, 2.5/2.5bpm, 3175/3400psi, 4k DWOB & 15fph ave ROP. P/U off btm for survey. RBIH to btm. Drill to 13895' with 180R TF, 2.5/2.5bpm, 3175/3500psi, 5k DWOB & 35fph ave ROP. P/U off btm for survey. RBIH to btm. Drill to 13904' with 180R TF, 2.6/2.6bpm, 3350/3700psi, 5k DWOB & 15fph ave ROP. Stacking wt & acting sticky. Wiper trip to window. RBIH to btm. Drill to 13906' with 180R TF, 2.5/2.5bpm, 3350/3550psi, 8k DWOB & 2fph ave ROP. Stacking wt & drilling ratty. Review situation with ANC & decide to POOH for OH sidetrack C +/-13695'. POOH drilling BHA #12. OOH. PJSM. S/B injector. L/D BHA 312. Bit grade 7/4/1 with a rung out pilot. L/O & download resistivity tool. Reset motor bend to 2degs. C/O HOT &DGS tools. Observe tube oil leaking from SLB planetary reel drive motor. SLB mechanic drain oil, inspect motor & found nothing amiss. Fill back oil & function test motor- OK. M/U OHST BHA #13 with 2deg X-treme motor, new Hughes 3-314° R60ST sidetrack bit #7 with brass cap, BHI HOT-DGS-DPS-SBS-BCPM package. Scribe tools. Initialize BHI tools & M/U injector. RIH OHST BHA #13 to 13400'. Downlink TF of 15R & put tool in logging mode. Log down GR & tie-into Geology PDC log. No correction to CTD. RIH & tag 2x ~ BOW without pumps. Suspect brass cap has been knocked off & is lying @ window or TFS is wrong. Note: Tool was in manual mode when tagging the WS initially. Down linked to steering mode and tried 120R, 20R and 45R and tagged. Adjusted the SPA. Set TF at 45R, tagged. Downlinked to a TF of 20L POOH to look at bit and /brass nose cone. Flow check at 10,460 ft to confirm hole fill. OK. POOH filling backside with backside closed in at 0.6 bpm Pull BHA out of hole, no brass nose cone, bit looked good. Installed new 3.75" R-60 with brass nose cone. Confirmed external tool offset (36 deg). Cut off 50 ft CTC for CT Management in Chrome tubing. Installed new CTC, pulled tested to 40k and PT to 3800 psi. Finished prep CTC and injector head to make ready to RIH. RIH While RIH at 6445 ft, noticed the out flowrate was increasing, stopped and checked flow, Some gas to surface. Well flowing, Printed: 3/20/2006 12:12:00 PM BP EXPLORATION Operations Summary Report Legal Well Name: P2-37 Common Well Name: P2-37 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours ~ Task ~ Code NPT ~ Phase - _ ' _ -- - - ~ - _t' _-~ - ~-- - 3/12/2006 01:30 - 01:50 ~ 0.331 STKOH I X ~ DPRB i PROD1 01:50 - 03:07 ; 1.28 STKOH X i 03:07 - 03:45 0.63 1 STKOH X 03:45 - 05:00 1.25 STKOH X 05:00 - 05:25 0.42 STKOH X 05:25 - 06:00 0.58 STKOH X 06:00 - 07:30 1.50 STKOH X 07:30 - 07:40 0.17 STKOH X 07:40 - 08:00 0.33 STKOH X 08:00 - 08:10 0.17 STKOH C 08:10 - 08:20 0.17 STKOH C 08:20 - 08:50 08:50 - 10:00 10:00 - 10:30 10:30 - 11:40 11:40 - 12:10 12:10 - 13:20 13:20 - 13:50 13:50 - 14:20 14:20 - 15:20 15:20 - 16:20 0.50 STKOH C 1.17 STKOH C 0.50 STKOH C 1.17 STKOH C 0.50 STKOH C 1.17 STKOH C 0.50 STKOH C 0.50 STKOH C 1.00 STKOH C 1.00 STKOH C DPRB i PROD1 DPRB . PROD1 DPRB I PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: 2/27/2006 Rig Release: 3/18/2006 Rig Number: N1 Page 10 of i 8 Spud Date: 8/16/1995 End: 3/18/2006 Description of Operations SWI and monitored Flowrate SIWP 33 psi to 133 psi in 10 minutes. Lined out to take returns to tiger tank. Notified Veco, 7ES WSL and TP along with SLB CTU Unit 7 on venting gas to TT. Wind direction in our favor. RIH at 0.3 bpm and 86.0 fpm holding 100 to 150 psi on wellhead taking returns to the TT Stopped at 13,200 ft. Inc Op to 2.5 bpm and circulate out wellbore while holding +200 psi on wellhead. Pumped 100 bbl while RIH to 13,300 ft. SW I at 0346 hrs. D= 13,050 ft Stablized at 290 psi 15 min 388ps 20 min SIWHP = 400 psi (stable}. Pump fluid thro CT peroidicaliy while holding 400 psi to keep warm. Wait on fluid from MI Deadhorse. Load pits and circulate well while holding 400 to 450 psi on well to keep CT warm. Circulating out wellbore fluid at 1.5 to 2.0 bpm holding 400 to 450 psi After pumping 25 bbl. Op(in/out) = 2.0 / 2.0 bpm and Density(in/out) = 9.7 ppg / 9.4 ppg Pumped 140 bbl and SD Density (in/out) = 9.8 / 9.6 ppg Bleed down 750psi WHP in stages to 100psi. SI well & pressures stabilize @ 120psi. Bleed off WHP. Downlink TF to 20R. Attempt to run thru window without pumps -tag 3x @ BOW. PUH. RBIH & set down @ BOW (13489'). Stack max wt, roll pumps 2x & work BHA in#o OH. Continue RIH to TD to circ all gas out. Set down in KLB shale. P/U & run thru to TD tagged @ 13906'. PUH with 20-30k overpull thru the KLB shale & with partially plugged jets. Continue PUH to 13650'. Unplug jets & establish circ @ 2.5bpm/3200psi. Got final gas bubble with little crude @ btms up. Downlink TF 4x to 170L. Up wt = 34k S/O wt = 14k. Trough up from 13700' - 13675' with 170E TF, 2.5bpm/3225psi & 20fph. Trough down from 13680' - 13700' with i70L TF, 2.62bpm/3365psi, 0.11-0.18k DWOB & 60fph. Trough up from 13700' - 13675' with i70L TF, 2.58bpm/3390psi & 20fph. Trough down from 13680' - 13700' with 170E TF, 2.55bpm/3300psi, 0.12k & 60fph. Trough up from 13700' - 13675' with 170E TF, 2.58bpm/3390psi & 20fph. Trough down from 13680' - 13699' with 170E TF, 2.55bpm/3300psi, 0.24k & 40fph. Park bit @ 13699' & time drill for 30mins with 170E TF, 2.55bpm/3250psi. Time drill from 13699' to 13700' with 170E TF, 2.55bpm/3200psi & ifph. Time drill from 13700' to 13701' with 170E TF, Printed: 3/20/2006 12:12:00 PM BP EXPLORATION Operations Summary Report Legal Well Name: P2-37 Common Well Name: P2-37 Event Name: REENTER+COMPLETE Start: 2/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 3/18/2006 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To Hours ~' Task .Code NPT ~ .Phase __ - ' - 2/2006 15:20 - 16:20 1.00 STKOH C ~ PROD1 { 16:20 - 17:20 ~ 1.00 STKOH C PROD1 17:20 - 17:50 I 0.501 STKOH I C I i PROD1 17:50 - 18:20 I 0.501 STKOH I C I I PROD1 18:20 - 19:23 ~ 1.051 STKOH ~ C ~ PROD1 19:23 - 21 a 7 1.90 ~ STKOH C PROD1 21:17 - 22:50 1.55 STKOH C PROD1 22:50 - 23:30 { 0.671 STKOH I C I I PROD1 23:30 - 00:00 0.50 STKOH C PROD1 3/13/2006 00:00 - 00:30 0.50 STKOH C PROD1 00:30 - 05:30 5.00 STKOH C PROD1 05:30 - 08:00 2.501 STKOH C PROD1 08:00 - 08:30 I 0.501 STKOH I C I I PROD1 08:35 - 09:05 0.50 STKOH C I PROD1 PROD1 09:05 - 10:00 1 0.921 STKOH I C I C PROD1 10:00 - 12:30 ( 2.501 STKOH I C I I PRODi 12:30 - 13:00 0.501 STKOH C I PROD1 13:00 - 13:30 I 0.50 ~ STKOH C ~ PROD1 13:30 - 14:30 I 1.001 DRILL I C I I PROD1 Page 11 of 18 Spud Date: 8/16/1995 End: 3/18/2006 Description of Operations 2.55bpm/3200psi & 1fph. Time drill from 13701' to i 3702' with 170E TF, 2.55bpm/3200psi & 1fph. Time drill from 13702' to 13703' with 170E TF, 2.55bpm/3200psi & 2fph. Time drill from 13703' to 13704' with 170E TF, 2.55bpml3200psi & 2fph. Time drill from 13704' to 13705' with 170E TF, 2.55bpm/3200psi & 2fph. Started adding wt at 13706 at 0.1 fpm from 13606 to 13709 ft PUH to 13,675 ft to ream trough from 13675 ft to 13,730 ft. Reaming trough at 4.5 fpm at 170E and then reamed at 135 L. Reamed at 20 R from 13,625 ft to 13730 ft SD pumps to take survey and got 37 ppm small gas to surface. Seeing gas to surface from bottoms up after SD to take surveys. Density is 9.88 ppg in and 9.66 ppg out off MM. Observed the mud as somewhat gas cut. Down linked to change TF to 165 deg. Reamed i back reamed 13,675 ft to 13,730 ft. Talked with town engineer and planned way forward. PUH to above WS PUH to 13450 ft Cir at 1.2 bpm waiting on 10.2 ppg Naar/NaCI mud being made and delivered to location. Loading at 04:00 hrs Density = 9.8+ppg in and 9.69 ppg out. Started unloading pits at 05:15 hrs Started mud swap Op = 2.3 at 2640 psi. Complete swapping well to 10.2ppg Naar/NaCI. Observed 78% losses ~ 2.42bpm in & 0.53bpm out. S/D pumps to observe static losses -seems like well is flowing. SI well, dump off CTP & observe WHP increase from 15psi to 100psi in 30mins. Open up well. Circ 3bbls to warm up CT. SI well, dump off CTP & observe WHP increase from Opsi to 172psi in 30mins. Suspect well is breathing back lost fluid. IAP = Opsi, OAP = 72psi, PVT = 220bb1s. Open up well. Circ & confirm ECD of 12.6ppg with 10.2ppg mud. Note that ECD with 9.7+ppg mud was 11.5ppg. Review situation with ANC & decide to POOH & RBIH with lateral BHA minimizing losses, swap the well back to 9.9ppg mud & drill ahead monitoring losses. POOH OHST BHA ~ i00fpm circ i.0110.53bpm. Lost 5bbis while POOH to 10400' & POOH aprox. 1 for 1 from 10400' to surface. Did not get back any gas on surface. Lost a total of 76bbls of 10.2ppg mud & 25bbls of 9.8ppg mud. Monitor well & perform exhale test for 30mins - no flow. Meanwhile held PJSM for VD BHA #14 & for P/U BHA #15. S/B injector. VD OHST BHA #14. Bit lost only one cutter. VO motor. P/U new motor & set bend to 1.5deg. P/U BHI USMPR tool. P/U lateral drilling BHA #15 with 1.5deg X-treme motor, BHI HOT, USMPR, DGS, DPS, SBS, BCPM package & new Hughes 3-3/4" x 4-1/8" RWD2ST bicenter bit #9. Scribe tools. Printed: 3/20/2006 12:12:00 PM BP EXPLORATION Operations Summary.. Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: P2-37 P2-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 ~ - Task Code NPT Date From - To Hours - - -- 3/13/2006 ~ 13:30 - 14:30 1.00 DRILL C 14:30 - 17:00 2.50 DRILL C 17:00 - 17:10 0.17 DRILL C 17:10 - 17:25 0.25 DRILL C 17:25 - 18:15 I 0.831 DRILL I C 18:15 - 18:55 I 0.671 DRILL I C 18:55 - 19:00 I 0.081 DRILL I C 19:00 - 20:30 ~ 1.50 ~ DRILL ~ C 20:30 - 20:50 0.331 DRILL C 20:50 - 22:25 I 1.581 DRILL I C 22:25 - 22:40 0.251 DRILL ~ C 22:40 - 00:00 I 1.331 DRILL I C 3/i4/2006 00:00 - 00:15 0.25 DRILL C 00:15 - 01:15 1.00 DRILL C 01:15 - 01:34 0.32 DRILL C 01:34 - 01:45 0.18 DRILL C Page 12 of 18 Spud Date: 8!16!1995 Start: 2/27/2006 End: 3/18/2006 Rig Release: 3/18/2006 Rig Number: N1 Phase Description of Operations PROD1 Initialize BHI tools & M/U injector. PROD1 RIH lateral drilling BHA #15 to 13410'. PROD1 Downlink TF of 25R & put tool in logging mode. PROD1 Log down GR & tie-into Geology PDC log. Subtract 1' from CTD. Meanwhile swap well 10.2ppg to 9.9ppg mud. PROD1 RIH clean thru window with pumps down. Bring on pumps. Downlink to TF to 170R. Continue RIH clen thru S/T pt to btm tagged @ 13735'. PROD1 Finish Mud Swap. With 216 bbl pumped, Density at 10 / 10 ppg amd flow rates at 2.6 ! 2.6 bpm PROD1 SD pump, flow check with 10/10 ppm density all around. No flow after 5 minutes PROD1 Make ready to drill. Working to get better detection from tool. Drilling in steering mode at 120R TF Op = 2.7 / 2.7 bpm CTP = 3100 / 3384 psi Density = 10 / 10 ppg. WOB = 2.17k1b and ROP = 44 fph Tough spot at 13741 ft, lots of stalls, worked through. 1st Time: Down linked on btm drilling and it worked. PROD1 PUH 13705 ft, RIH stopped at 13748 ft, SD pump to take survey for 1 min. bring pump and RIH to tagged bottom..Survey at 13705 ft Suvey bad, Gtotal was out of range. Re-survey Finished Mud swap at 20:45 hrs PROD1 Drilling in steering mode at 105-108R TF Op=2.7/2.7 bpm CTP=3100/3384 psi Density = 10 / 10 ppg. Vp = 328 bbl at 21:00 hrs WOB = 1.65-2.17k1b and ROP = 20-40 fph. With no experience in drilling with saturated salt muds on N1, the MM is being effect by salt content and will vary from the pressure mud balance scale. Downlinked to 100R while drilling. PROD1 Survey. How to: PU 60 ft, RIH 5 ft of bottom, SD pump for 1 min. Started pump up and RIH back to drilling PRODi Drilling in steering mode at 75-90R TF Op = 2.7 / 2.7 bpm CTP = 3100 /3484 psi Density = 10 / 10 ppg. WOB = 1.65-2.17k1b and ROP = 20-40 fph Down linked to 90R then to 75R while drilling. PRODi Survey PRODi Drilling in steering mode at 60-80R TF Op = 2.7 / 2.7 bpm CTP = 3100 / 3484 psi Density = 10 / 10 ppg. WOB = 1.65-3.17 klb and ROP = 20-40 fph Tried to get survey on the fly and to much noise PROD1 Survey on bottom without drilling To much noise to get a good survey PROD1 Drilling in steering mode at 90R TF Op = 2.7 / 2.7 bpm CTP = 3150 / 3584 psi Density = 10 / 10 ppg. WOB = 1.65-3.17 klb and ROP = 20-40 fph Printed: 3/20/2006 12:12:00 PM BP EXPLORATION Page 13 of 18 Operations. Summary Report Legal Well Name: P2-37 Common Well Name: P2-37 Spud Date: 8/16/1995 Event Name: REENTER+COMPLETE Start: 2/27/2006 End: 3/18/2006 Contractor Name: NORDIC CALISTA Rig Release: 3/18/2006 Rig Name: NORDIC 1 Rig Number: N1 Date ~~ From - To ' Hours ' Task ~! Code i NPT Phase Description of Operations i - - -. fi - t __ __ _ - - ~'- -- - __. - - - 3/14/2006 01:45 - 01:58 0.22 ~ DRILL I C PROD1 Survey, PUH and survey 5 ft off bottom 01:58 - 02:45 0.78 ~ DRILL C PROD1 Drilling in steering mode at 84R-140R TF Op = 2.7 / 2.7 bpm CTP = 3150 / 3584 psi Density = 10 / 10 ppg. Vp = 327 bbl W OB = 2.0-3.0 klb and ROP = 20-50 fph Down linked to 140R 02:45 - 03:00 025 DRILL C PRODi Survey 03:00 - 03:37 0.62 DRILL C PRODi Wiper trip to window. Some motor work and drag pulling through ST area at 13705 ft Down linked to 165 R above 13,650 ft BHI tool worked good in down linking while tripping 03:37 - 04:04 0.45 DRILL C PROD1 Drilling in steering mode at140R TF Op = 2.7 / 2.7 bpm CTP = 3200 /3484 psi density = 10 / 10 ppg. Vp = 327 bbl WOB = 1.65-3.17 klb and ROP = 40-70 fph 04:04 - 04:25 0.35 DRILL P PROD1 Survey. Had to survey twice 04:25 - 05:00 0.58 DRILL P PROD1 Down linked to 110R TF Drilling in steering mode at 110R 95R TF Op = 2.7 / 2.7 bpm CTP = 3220 /3484 psi Density = 101 i 0 ppg. WOB = 2.17 klb and ROP = 50-70 fph 05:00 - 05:15 025 DRILL P PROD1 Survey 05:15 - 06:10 0.92 DRILL P PROD1 Down linked to 110R TF then to 130R Drilling in steering mode at 110 R 95R TF Op = 2.7 / 2.7 bpm CTP = 3,220 / 3,484 psi Density = 10 / 10 ppg. WOB = 2.17 klb and ROP = 10-70 fph Drilling changed at 13,963 ft, slower ROP with stalls 06:10 - 07:10 1.00 DRILL P PROD1 Drill to 14001' with 130R TF, 2.6/2.6bpm, 3200/3450psi, 2.7k DWOB, 11.74ppg ECD & 40fph ave ROP. 07:10 - 07:20 0.17 DRILL P PRODi P/U 100' &RBIH 5' off btm. SID pump & shoot survey. RBIH to btm. Up wt = 33k, S/O wt = 13k. IAP = 530bb1s, OAP = 540psi, PVT = 326bb1s. 07:20 - 08:00 0.67 DRILL P PROD1 Drill to 14032' with 130R TF, 2.6/2.6bpm, 3200/3450psi, 2.17k DWOB, 11.77ppg ECD & 45fph ave ROP. 08:00 - 08:05 0.08 DRILL P PROD1 P/U 60' &RBIH 5' off btm. S/D pump & shoot survey. RBIH to btm. PVT = 320bb1s. 08:05 - 08:20 0.25 DRILL P PRODi Drill to 14050' with 130R TF, 2.6/2.6bpm, 3200/3450psi, 2.17k DWOB, 11.77ppg ECD & 75fph ave ROP. 08:20 - 09:00 0.67 DRILL P PROD1 Wiper trip to the window. Observe some motorwork & O/pull while pulling thru S/T pt C~ 13695'. RBIH to 13650'. Downlink TF to 170L. Run thru S~f pt clean. 09:00 - 09:10 0.17 DRILL P PROD1 Downlink TF to 85R. S/D pump & shoot survey. RBIH to btm. 09:10 - 09:35 0.42 DR1LL P PROD1 Drill to 14080' with 85R TF, 2.6/2.6bpm, 3150/3450psi, 2.7k DWOB, 11.85ppg ECD & 75fph ave ROP. 09:35 - 09:45 0.17 DRILL P PROD1 PIU 60' &RBIH 5' off btm. SiD pump & shoot survey. RBIH to btm. PVT = 318bb1s. 09:45 - 10:00 0.25 DRILL P PROD1 Drill to 14094' with 85R TF, 2.6/2.6bpm, 3150l3450psi, 2.7k DWOB, 11.82ppg ECD & 55fph ave ROP. 10:00 - 10:10 0.17 DRILL P PROD1 P/U 60' &RBIH 5' off btm. S/D pump & shoot survey. Downlink TF to 100R. RBIH to btm. PVT = 318bb1s. 10:10 - 10:30 0.33 DRILL P PROD1 Drill to 14111' with 100R TF, 2.7/2.7bpm, 3350/3650psi, 2.73k DWOB, 11.82ppg ECD & 55fph ave ROP. Printed: 3/20/2006 12:12:00 PM BP EXPLORATION Page 14 of 18 Operations Summary Report Legal Well Name: P2-37 Common W ell Name: P2-37 Spud Date: 8/16/1995 Event Nam e: REENTE R+COM PLET E Start : 2/27/2006 End: 3/18/2006 Contractor Name: NORDIC CALIS TA Rig Release: 3/18/2006 Rig Name: NORDIC 1 Rig Number: N1 Date ! 1 From - To Hours ~ Task Code j NPT I Phase - Description of Operations - - - 3/14/2006 __ 10:30 - 10:40 - _ 0.17 _ _~ DRILL P PROD1 _ _ - __ _ _ _ __ P/U 60' &RBIH 5' off btm. S/D pump & shoot survey. RBIH to btm. PVT = 317bb1s. 10:40 - 11:25 0.75 DRILL P PROD1 Drill to 14144' with 95R TF, 2.6/2.6bpm, 3250l3600psi, 2.73k DWOB, 11.84ppg ECD & 45fph ave ROP. Downlink TF to 90L while drilling on btm. 11:25 - 11:35 0.17 DRILL P PROD1 P/U 60' &RBIH 5' off btm. S/D pump & shoot survey. RBIH to btm. PVT = 315bb1s. 11:35 - 12:30 0.92 DRILL P PROD1 Drill to 14173' with 90L TF, 2.6/2.6bpm, 3250/3600psi, 1.04k DWOB, 11.89ppg ECD & 50fph ave ROP. 12:30 - 12:40 0.17 DRILL P PROD1 P/U 60' &RBIH 5' off btm. S/D pump & shoot survey. RBIH to btm. PVT = 314bb1s. 12:40 - 13:00 0.33 DRILL P PRODi Drill to 14200' with 90L TF, 2.6/2.6bpm, 3250/3600psi, 2k DWOB, 11.82ppg ECD & 75fph ave ROP. 13:00 - 13:45 0.75 DRILL P PROD1 Downlink TF to 170L. Wiper trip to the window. Observe no motorwork & O/pull while pulling thru S/T pt. Downlink TF to 20R. PUH thru window with pumps down. Continue wiping to TT. 13:45 - 14:25 0.67 DRILL N RREP PROD1 Park bit C~3 13210' & circ while Nordic investigate loss of motor pressure from rig Gen set #2. C/O oil filters & oil in Gen set #2 motor & function test OK. 14:25 - 14:30 0.08 DRILL P PROD1 RBIH to 13410'. 14:30 - 14:35 0.08 DRILL P PROD1 Downlink & put tool in logging mode. 14:35 - 14:45 0.17 DRILL P PRODi Log down GR & tie-into Geology PDC log. Add 7' to CTD. 14:45 - 15:25 0.67 DRILL P PRODi RIH clean thru window with pumps down. Bring on pumps. Downlink to TF to 170R. Continue RIH clen thru S/T pt to btm tagged @ 14205'. 15:25 - 15:40 0.25 DRILL P PROD1 Downlink TF to 90L. PUH. S/D pump & shoot survey 3x (due to high G-Total). RBIH to btm. 15:40 - 16:15 0.58 DRILL P PROD1 Drill to 14240' with 90L TF, 2.7/2.7bpm, 3450/3800psi, 2.17k DWOB, i 1.94ppg ECD & 75fph ave ROP. 16:15 - 16:20 0.08 DRILL P PROD1 PUH. S/D pump & shoot survey. P/U wt = 34k. S/O wt = 12.5k. 16:20 - 16:45 0.42 DRILL P PROD1 Drill to 14253' with 90L TF, 2.7/2.7bpm, 3350/3750psi, 1.17k DWOB, 11.94ppg ECD & 75fph ave ROP. Downlink TF to 105L. P/U & O/pulled. 16:45 - 17:10 0.42 DRILL P PROD1 P/U 60' &RBIH 5' off btm. S/D pump & shoot survey. Downlink TF to 115L. RBIH to btm. PVT = 306bb1s. 17:10 - 19:35 2.42 DRILL P PROD1 Drill to 14351' with 115E TF, 2.7J2.7bpm, 332513750psi, i.73k DWOB, 11.94ppg ECD & 40 - 55 fph ave ROP. PVT 305 bbl 19:35 - 20:10 0.58 DRILL P PROD1 Wiper trip to the window. Observe no motorwork & O/pull while pulling thru S/T pt. 20:10 - 20:45 0.58 DRILL P PROD1 RBIH, orient TF to 195 L, no problems sliding thru OHST 20:45 - 21:05 0.33 DRILL P PRODi Drill to 14363' with 90L TF, 2.7/2.7bpm, 3966/4250psi, FS 3450 psi, 2.3k DWOB, 11.97ppg ECD & 55 fph ave ROP. PVT 302 bbl 21:05 - 21:15 0.17 DRILL P PRODi PUH to 14300', RBIH to 14355', shut down pumps, Survey at 14311' 21:15 - 00:00 2.75 DRILL P PROD1 Drill to 14450' with 90L TF, 2.7/2.7bpm, 3700/4000psi, FS 3450 psi, 1.17k DWOB, 11.91 ppg ECD & 55 fph ave ROP. PVT 323 bbl, recieved 27 bbls of liner pi11 3/15/2006 00:00 - 02:30 2.50 DRILL P PROD1 MAD Pass/wiper trip combo thru window to 13400', no hole problems 02:30 - 03:00 0.50 DRILL P PROD1 Orient TF to 20 R after second attempt, failed to take original command Printed: 3/20(2006 12:72:00 PM BP EXPLORATION Page 15 of 18 Operations Summary Report.. Legal Well Name: P2-37 Common W ell Name: P2-37 Spud Date: 8/16/1995 Event Nam e: REENTER+COM PLET E Start : 2/27/2006 End: 3/18/2006 Contractor Name: NORDIC CALIST A Rig Release: 3/18!2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To ' Hours ' ~ Task Code ~ NPT ' ~ ~ Phase Description of Operations - , 1 ' 3/15/2006 03:00 - 03:45 0.751 DRILL P PROD RIH to 13500 , Log do w/ tie-in pass to RA tag, unable to detect ~ RA tag due to heavy scale surrounding RA tags, PUH to ~ I 13410', tie in to base of HRZ/top of Kalubik, +T correction 03:45 - 04:15 0.50 DRILL P PROD1 i RIH, downlink to 170L, slide thru OHST, RIH to btm, tagged ! and corrected TD to 14453', hole looks good 04:15 - 06:50 2.58 DRILL P PROD1 POH, & lay in liner pill. Paint EOP at -13050' and -12050'. POH to BHA. ~ 06:50 - 07:20 0.50 DRILL P PROD1 Monitor well for 30mins - no flow. Meanwhile held PJSM for L/D BHA #15. 07:20 - 08:30 1.17 DRILL P PROD1 S/B injector. L/D lateral BHA #15. Bit grades 2/2lI. L/O tools & download BHI USMPR tool. 08:30 - 09:00 0.50 CASE P RUNPRD Install Baker CTC. Puff test to 35k & pressure test to 3500psi. 09:00 - 10:15 1.25 CASE P RUNPRD M/U dart catcher. Load wiper dart, launch/chase dart with mud & pig CT. Dart bumped on catcher @ 57.4bbls. 10:15 - 10:30 0.25 j CASE P RUNPRD Held PJSM for M/U &RIH with chrome 3-1/2" x 2-7/8" completion liner. 10:30 - 13:00 2.50 CASE P RUNPRD M1U 2-718" STL rotating guide shoe, 2 float collars, 1 chrome shoe jt & landing collar. M/U 34jts of 2-7/8" STL 6.16# 13Cr80 liner, Chrome XO, 8jts of 3-1/2" STL 8.81# 13Cr80 liner, Chrome XN nipple, 1jt of 3-1/2" STL 8.81# 13Cr80 liner & Chrome 3-1/2" pup. M/U Chrome BKR deploy sleeve &CTLRT. OAL - 1343.94'. M/U injector. 13:00 - 15:45 2.75 CASE P RUNPRD RIH with liner circ @ min rate. Correct CTD -2.5' @ 1st flag. Wt check: Up = 38k. Run-in wt = 14k. Continue RIH smoothly 50fpm thru window. RIH smoothly to TD tagged 2x C~? 14453'. P/U @ 41 k to ball drop position. 15:45 - 16:30 0.75 CASE P RUNPRD Establish circ. Load 5!8" steel ball &circ with Q 2.4i/2.41bpm & 2450psi. Set down 10k down on CTLRT. Continue circ ball to seat. Slow down @ 48.7bbls away. Ball on seat @ 50.6bbls. Pressure up to 3500psi & release CTLRT. P/U (~ 37k & confirm release. 16:30 - 19:10 2.67 CASE P RUNPRD Circ well to 9.9ppg KCL1NaCL brine with double friction reducer 3/3bpm & 2750 psi. Send used FloPro to MI for reconditioning. Meanwhile R/U SLB cementers. Loading pits w/ new 9.9 ppg brine f/ vac trk, build 30 bbl biozan pill. 19:10 - 19:25 0.25 CASE P RUNPRD PJSM on cmt job operations and pumping. 19:25 - 19:50 0.42 CEMT P RUNPRD Batch mix 30 bbls of 15.8ppg 'G' {atex cmt with additives. PVT 292. 19:50 - 21:00 1.17 CEMT P RUNPRD PIT cement lines to 4000 psi, Pumped 27 bbls of CL "G" at 1.6 bpm, 1000 - 330 psi, 1.6 bpm returns. Clean cement line. Insert Dart, launch w/ 500 psi, Displace dart with 30 bbls Biozan water ~ 2.9 bpm at 550 - 300 psi, caught up to cement after pumping 9 bbls, slow rate to 2.7 - 2.6 bpm at 1800 - 2800 - 2225psi, slowed rate to 1.5 bpm w/ 1000 psi after pumping 82 bbls, dart engaged liner wiper at 84.4 bbls pumped, sheared at 3139 psi, bumped plug w/ 92.4 bbl at 1.3 bpm, pressured up f/ 1300 psi to 2300 psi ,held for 5 minutes, bled of floats held, CIP at 20:50 hrs on 3/15/06. No fluid loss to formation during cement job. Top of FS at 14451' ist(Btm) FC at 14450' Printed: 3/20/2006 12:12:00 PM BP EXPLORATION Operations Summary Report Legal Well Name: P2-37 Common Well Name: P2-37 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date' From - To ~~ Hours~~ TasK ~ Code~NPT 3!15/2006 119:50 - 21:00 1.171 CEMT ~ P Start: 2/27/2006 Rig Release: 3118!2006 Rig Number: N1 Page 16 of 18 Spud Date: 8/16/1995 End: 3/18/2006 Phase Description of Operations -1- -- -- __ _ - - - RUNPRD 2nd(Top} FC at 14449' LC at 14419' BOT Liner Deployment Sleeve at 13118' 21:00 - 00:00 3.00 i CEMT P RUNPRD 3/16/2006 00:00 - 01:00 1.00 CEMT i P RUNPRD 01:00 - 07:30 6.50 BOPSU P RUNPRD 07:30 - 08:00 0.50 EVAL P LOWERI 08:00 - 08:30 0.50 EVAL P LOWERI 08:30 - 08:45 0.25 EVAL P LOWERI 08:45 - 11:00 2.25 EVAL P LOWERI 11:00-13:15 2.25 EVAL P LOWERI 13:15 - 13:30 0.25 CLEAN N DPRB LOWERI 13:30-14:00 0.50 CLEAN N DPRB LOWERI 14:00-15:45 1.75 CLEAN N DPRB LOWERI 15:45 - 16:00 0.25 CLEAN N DPRB LOWERi 16:00 - 17:00 1.00 CLEAN N DPRB LOWERI 17:00 - 17:15 0.25 CLEAN N DPRB LOWERI 17:15 - 17:45 0.50 CLEAN N DPRB LOWERI 17:45 - 18:00 0.25 CLEAN N DPRB LOWERI 18:00 - 18:15 0.25 CLEAN N DPRB LOWERI 18:15 - 18:40 0.42 CLEAN N DPRB LOWERI 18:40 - 20:45 2.08 CLEAN N DPRB LOWERI 20:45 - 21:00 0.25 CLEAN N DPRB LOWERI 21:00 - 00:00 3.00 CLEAN N DPRB LOWERI 3/17/2006 00:00 - 06:00 6.00 CLEAN N DPRB LOWERI 06:00 - 07:00 1.00 CLEAN N DPRB LOWERI 2 7/8" tbg and accessories was drifted to 2.347"; 3 1/2" tbg and accessories was drifted to 2.867° Pressured up to 500 psi, unsting f/ deployment sleeve, POH slow, operating off one generator, filling voidage POH slow, operating off one generator, std back injector, LD Baker R/T, RD handling tools, offload excess tubulars from pipeshed. RU test equipment, greased tree, Test BOP's as per AOGCC reg's, witnessed by Lou Grimaldi w/ AOGCC. Repaired Pump # 1 leaking packing, Cat man troubleshot Gen motor #2 leaking oil, found transfer pump had blown seal, ordered transfer pump, should arrive tomorrow for change out & SCR blower motor out, electrician to repair. R/U floor for running logging/cleanout BHA. Initialize & test logging tools. P/U tools to rig floor. PJSM on P/U &RIH MCNL tools & 1-1/4" CHS tbg. P/U logging/cleanout BHA #17 with 2.30" D331 mill, 2-1/8° straight motor, XO, 2jts of 1-1/4" CSH tbg, MCNUGCUGR logging tool carrier, XO, lower MHA, 46jts of 1-1/4" CSH tbg, XO & upper MHA. M/U Injector. RIH with mill, motor & MCNUGR/CCL. Tag cmt stringer 11332'. Wash down to 11415' with 1.5bpm/1560psi. Mill hard cmt from 11415' to 11417' with 1.5/1.5bpm & 1560/1750psi. Not making much milling progress. Decide to POOH to P/U full milling BHA. POOH logging/cleanout BHA #18. Circ out little cement contaminated fluid. PJSM for R/B CSH. OOH. S/B injector. UD upper MHA. R/U & R/B 23 stands of 1-1/4" CSH. PJSM for UD SWS MCNUGCUGR logging tool. UD lower MHA, SWS MCNUGCUGR logging tool, X/Os, 2 jts of 1-1/4" CSH, motor & mill. R!U hydraulic cutter & cut 50' of CT for chrome fatigue management. Have i 5250' of CT left on reel. Install Baker CTC. Pull test to 35k & pressure test to 3500psi. M/U cleanouUmilling BHA #18 with a 3.78" HC D331, Baker straight Xtreme motor &MHA. M/U injector. RIH w/ BHA to 11300', FS at 1685 psi w12.56 bpm, Up Wt 32 k,DnWt11.5k Started precautionary washing f/ 11300' - 11417 Drill cement f/ 11417 - 11711' w/ 2.57 bpm, 2150 psi, sweep hole w/ 10 bbl tlo-pro hi-vis pill every 100', steady cement cuttings in returns, avg ROP 98fph Drill cement f/ 11711' - 12350' w/ 2.71 bpm, 2385 psi, sweep hole w/ 10 bbl flo-pro hi-vis pill every 100', steady cement cuttings in returns, avg ROP 102 fph Drill cement from 12350' to 12470' with 2.7/2.7bpm, 2450psi, Printed: 3/20/2006 12:12:00 PM BP EXPLORATION Page 17 of 18 Operations Summary Report Legal Well Name: P2-37 Common Well Name: P2-37 Spud Date: 8/16/1995 Event Name: REENTER+COMPLETE Start: 2/27/2006 End: 3/18/2006 Contractor Name: NORDIC CALISTA Rig Release: 3/18!2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To ~ Hours ~~ Task Code NPT ' Phase 3/17/2006 ~ 06:00 - 07:00 1' 1.00 CLEAN N I DPRB LOW ER1 i i 07:00 - 07:15. 0.25 CLEAN N 07:15 - 09:15 2.00 CLEAN N I 09:15 - 09:30 i 0.25 CLEAN N 09:30 - 10:00 0.50 CLEAN N 10:00 - 10:50. 0.83 CLEAN N 10:50 - 11:30 0.67 CLEAN N 11:30 - 14:00 2.50 CLEAN N 14:00 - 14:30 0.50 CLEAN N 14:30 - 15:00 0.50 EVAL P 15:00 - 15:15 0.25 EVAL N 15:15 - 15:30 0.25 EVAL N 15:30 - 17:00 1.50 EVAL N 17:00 - 19:30 2.50 EVAL N 19:30 - 20:15 0.75 EVAL P 20:15 - 20:45 0.50 EVAL ~ P Description of Operations <1 k WOB & 120fph ave ROP. Not seeing much WOB. GPB is currently in phase-1/level-1 weather/driving conditions on all main roads, access roads & Pads. DPRB LOWERi 100' wiper. Wt check: Up = 38.5k. Run-in wt = 9k. Freespin = 2450psi Q 2.7bpm. DPRB LOWER! Wash in hole from 12470' to 12512' with 2.7/2.7bpm, 2450psi, <1k WOB & 250fph ave ROP. Sta1i @ 12512'. P/U & continue washing down Cam? 200fph to 12900'. Sweeping hole with 10bbls flopro hi-vis pill every 100' drilled. DPRB LOWER! 100' wiper. Wt check: Up = 41 k. Run-in wt = 10k. Freespin = 2450psi Q 2.7bpm. DPRB LOWER! Wash in hole from 12900' to 13017' with 2.7/2.7bpm, 2450psi, <ik WOB & 240fph ave ROP. Sweeping hole with 10bbls flopro hi-vis pill every 100' drilled. Add 1.5' to CTD Q EOP flag. DPRB LOWER! Wash in hole from 13017' to 13071' with 2.7/2.7bpm, 2450psi, <ik WOB & 140fph ave ROP. Stall ~ 13071'. P/U & continue washing down ~ 100fph to TOL tagged ~ 13118'. Sweeping hole with 10bbls flopro hi-vis pill every 100' drilled. DPRB LOWER! Pump down 20bbls of flopro hi-vis pill &circ out of mill. DPRB LOWER! POOH @ 50-100fpm circ pill out C~? 2.7bpm/2500psi. DPRB LOWER! OOH. PJSM. S/B injector. UD milling BHA#18. LOW ER1 Line up & P/test liner lap as follows: Time WHP CTP IAP Onset -37 0 137 0 2000 0 272 15 1926 0 250 30 1886 0 240 _> Passed: Leaked 5.7% of test pressure in 30 mins. DPRB LOWER! PJSM on P/U &RIH MCNL tools & 1-1/4" CHS tbg. DPRB LOW ER1 R/U floor for running logging/cleanout BHA. DPRB LOWER! P/U logging/cleanout BHA #19 with 2.30" D331 mill, 2-1/8" straight motor, XO, 2jts of 1-1/4" CSH tbg, MCNUCCUGR logging tool carrier, XO, lower MHA, 48jts of 1-1/4" CSH tbg, XO & upper MHA. M/U Injector. DPRB LOWER! RIH with mill, motor & MCNUGR/CCL to 13000' LOWER! LOWER! 20:45 - 21:00 0.25 EVAL P LOWER! 21:00 - 22:45 1.75 EVAL P LOWER! 22:45 - 00:00 1.25 EVAL P LOWER! 3/18/2006 00:00 - 01:25 1.42 EVAL P LOWER! 01:25 - 03:25 I 2.001 EVAL I P I I LOWER! GPB is now in phase-2/level-2 weather/driving conditions on all main roads, access roads & Pads. Log do from 13000' to PBTD at 14418', did not see any cement throughout {finer lap/liner, logging do at 30 fpm w/ 1.22 bpm, 2000 psi, displacing well to new 9.9 ppg brine, pumped 40 bbl flo-pro hi-vis pill followed by new 9.9 ppg brine Log up from PBTD at 14418' at 60 fpm w/ 1.22 bpm, 1230 psi, displacing well to new 9.9 ppg brine, displacing well to new 9.9 ppg brine RIH to PBTD at 14418', displacing well to new 9.9 ppg brine Displaced well to new 9.9 ppg brine POH to 7534', spotting perf pill in liner POH to BHA, circ hole clean at 1.28 bpm w/ 900 psi, Set back Injector 2 hrs RU, handling tools, PJSM, POH w/ BHA, Std Bk 1 1/4" CSH, LD MCNL tools, LD mtr and mill. PJSM Brk do loggng tool, Printed: 3/20/2006 12:12:00 PM BP EXPLORATION Page 18 of 18 Operations Summary Report Legal Well Name: P2-37 Common W e11 Name: P2-37 Spud Date: 8/16/1995 Event Nam e: REENTE R+COM PLET E Start : 2/27/2006 End: 3/18/2006 Contractor Name: NORDIC CALIST A Rig Release: 3/18/2006 Rig Name: NORDIC 1 Rig Number: N1 Date i i From - To '' Hours Task Code NPT Phase I~ Description of Operations - 3/18/2006 _ __ __ 01:25 - 03:25 I 2.00 _ EVAL _~ P _ - LOW ER1 r _ -- - _ _ - remove source. Brk do logging tool, remove f/floor 03:25 - 04:15 0.83 EVAL P LOWERI ; PU nozzel and wash stack 04:15 -04:40 0.42 PERFO P LOWERI RU handling tools, Hold PJSM on handling and running pert - guns, Fax CNL log to ANC Geo. ANC Geo OKs preliminary pert picks. From log data, PBTD = 14410.16' & TOL = 14128'. 04:40 - 06:20 1.67 PERFO P LOWERI M/U, RIH w/ 19 jts of 2" HSD 6spf 2006PJ guns & blanks with CBF firing system, 15 stds of 1 1/4" CSH. 06:20 - 09:10 2.83 PERFO P LOWERI ~ RIH with perforating BHA#19 circ pert pill @ min rate. Wt check @ 13000': Up - 42k; Run-in - 15k. Tag PBTD 2x @ 14412'. Pull to P/U wt & correct CTD to 14410' (PBTD as per MCNL log). PUH & position btm shot @ 14190'. Meanwhile R/U sonogram detector to the wellhead for shot detection. 09:10 - 09:45 0.58 PERFO P LOWERI Isolate CT. Line up & P/test liner lap again as follows: Time WHP CTP IAP ! Onset -26 0 0 O 2029 0 6 15 1992 0 0 _> Good test simi{ar to last one -Leaked 1.8% of test pressure in 15 mins. 09:45 - 10:30 0.75 PERFO P LOWERI RBIH to ball drop postion @ 14208'. Load & launch 518" AL ~ ball. PUH & position btm shot @ 14190'. Chase ball @ 2.5bpm/2250psi. Slow to 0.73bpm/200psi @ 40bbls. Ball on seat after 53.9bbls away. S/D pumps & RBIH to 14195'. PUH very slowly & ramp up to 3500psi with btm shot @ 14190'. Observe guns fire with good pressure drop indication & sonogram detection. Perforated interval = 13800' - 13860', 14010' - 14050', 14070' - 14110' & 14170' - 14190'. 10:30 - 11:15 0.75 PERFO P LOWERI POOH with pert gun BHA @ 22fpm pumping down the CT @ 1.35bpm & 480psi. POOH to 13000'. 11:15 - 11:30 0.25 PERFO P LOWERI S/D pump &flowcheck well for 15 mins -well stable. 1 i:30 - 14:00 2.50 PERFO P LOWERI POOH with pert gun BHA @ 60fpm pumping down the CT @ 1.45bpm & 480psi. 14:00 - 14:15 0.25 PERFO P LOWERI SID pump &flowcheck well -well stable. 14:15 - 14:30 0.25 PERFO P LOWERI PJSM for R/B 1-1/4" CSH. 14:30 - 15:15 0.75 PERFO P LOWERI ~ S/B injector. RIB 15 stands of 1-1/4" CSH. 15:15 - 15:30 0.25 PERFO P LOWERI R/U to UD perf guns. 15:30 - 15:45 0.25 PERFO P LOWERI PJSM for LD perf guns. 15:45 - 16:30 0.75 PERFO P LOW ER1 UD 19 jts of perf guns & blanks. ASF! 16:30 - 16:45 0.25 PERFO P LOW ER1 Load out spent perf guns & blanks. 16:45 - 17:15 0.50 W HSUR P POST M/U check valve, X/O & nozzle. M/U injector. 17:15 - 18:00 0.75 WHSUR P POST R!H nozzle to 5250' 18:00 - 18:30 0.50 WHSUR P POST Circ diesel to nozzle @ 2.35bpm/800psi. 80 bbls 18:30 - 19:30 1.00 WHSUR P POST POH, shut well in w/ 600 psi below swab valve, Secured wel{, LD BHA 19:30 - 22:00 2.50 WHSUR P POST Blow back CT 1 bbl, ND BOP, offload pits, test tree cap Release Nordic Rig #1 at 22:00 hrs on 03/18/06 Printed: 312012006 12:12:00 PM by BP Alaska Baker Hughes INTEQ Survey Report I/.~~ INTEQ Company: BP Amoco Date: 3!24/2006 Time: 16:35:56 Page: 1 Field: Point Mclnlyre Co-ordinate(NE) Reference: WeN: P2-37, True North Site: Pt Mac 2 Vertical (TVD) Reference: 52:37 8/16/1895 00:00 52.0 Well:. P2-37 Section (VS) Reference:. User (O.OON,O.OOE,149.OOAzi) WelipatY: P2-37APB1 Survey Calculation Metbod: Minimum Curvature Db: Orade Field: Point McIntyre North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Daturo: NAD27 (Clarke 1866) Coordinate System: WeU Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Pt Mac 2 TR-12-14 UNITED STATES :North Slope Site Position: Northing: 5995140.76 ft Latitude: 70 23 32.530 N From: Map Easting: 674873.98 ft Longitude: 148 34 37.934 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: P2-37 Sbt Name: 37 P2-37 Well Position: +N/-S 2998.87 ft Nortbing: 5998297.28 ft Latitude: 70 24 1.993 N +E/-W 6783.59 ft Easting : 681585.12 ft Longitude: 148 31 19.199 W Position Uncertainty: 0.00 ft Wellpath: P2-37APB1 Drilled From: P2-37 50-029-22576-70 Tie~on Depth: 13340.51 ft Current Datum: 52:37 8/16/1995 00:00 Height 52.00 ft Above System Datum: Mean Sea Level Magnetic Data: 3/29/2005 Declination: 25.07 deg Field Strength: 57611 nT Mag Dip Angle: 80.96 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 41.00 0.00 0.00 149.00 Survey Program for Definitive Wellpath Date: 3/29/2005 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 109.82 13340.51 1 : MWD -Standard (109.82-138 MWD MWD -Standard 13410.03 13906.00 MWD (13410.03-13906.00) MWD MWD -Standard AnnOtatlOa MD TVI) ft ft 13340.51 8902.95 TIP 13410.03 8944.61 KOP 13906.00 8987.07 TD Survey: MWD Start Date: 3/13/2006 Company: Baker Hughes INTEQ Engineer: BP Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD tnd Azim TVD Sys TVD N/5 E/W MapN MapE VS DLS Tool ft deg deg fit ft ft ft ft ft" ft deg/1 UOft 13340.51 53.32 102.46 8902.95 8850.95 -2112.03 9007.23 5996404.87 690640.45 6449.43 0.00 MWD 13410.03 53.05 101.24 8944.61 8892.61 -2123.46 9061.70 5996394.76 690695.18 6487.28 1.46 MWD 13476.00 53.28 101.77 8984.16 8932.16 -2133.99 9113.44 5996385.49 690747.15 6522.95 0.73 MWD 13504.90 56.78 105.20 9000.73 8948.73 -2139.52 9136.45 5996380.52 690770.30 6539.55 15.53 MWD 13539.44 66.30 109.50 9017.18 8965.18 -2148.62 9165.38 5996372.13 690799.43 6562.24 29.65 MWD 13570.53 75.78 113.23 9027.27 8975.27 -2159.34 9192.72 5996362.08 690827.02 6585.51 32.53 MWD 13602.41 86.54 116.20 9032.16 8980.16 -2172.50 9221.28 5996349.62 690855.89 6611.51 34.98 MWD 13632.52 97.14 118.34 9031.20 8979.20 -2186.27 9247.99 5996336.50 690882.93 6637.06 35.91 MWD 13664.52 105.30 126.20 9024.97 8972.97 -2202.97 9274.50 5986320.45 690909.84 6665.04 35.07 MWD 13695.03 105.53 129.34 9016.85 8964.85 -2220.98 9297.75 5996303.01 690933.51 6692.45 9.95 MWD 13718.37 106.46 133.37 9010.42 8958.42 -2235.80 9314.59 5996288.61 690950.71 6713.82 17.07 MWD rir ap BP Alaska s Baker Hughes INTEQ Survey Report 1LNTEQ Company: BP Amoco Date: 3/24/2006 Time: 16:35:56 Page: 2 Field:. Point McIntyre Co-ordiaataNE) Reference: WeN: P2-37, TrUS Narth Site: Pt Mac 2 Vertical (TVD) Reference: 52:37 8/16/1995 00:00 52.0 Well: P2-3T Seetios (VS) Reference: User (O.OON,Ott?OE,149.OOAzi) Wellpath: P2-37AP81 Survey Gakalation Method: Minimum Curvature Db: Aracle Survey MD Iacl Azim TVD Sys TVD N/S IE/VV MapN MapE VS DLS Tool R deg deg ft R ft tt ft $ tt deg/100It 13751.97 102.31 136.24 9002.07 8950.07 -2258.73 9337.67 5996266.24 690974.33 6745.37 14.87 MWD 13783.65 100.42 138.90 8995.83 8943.83 -2281.66 9358.62 5996243.84 690995.83 6775.81 10.17 MWD 13817.69 97.01 140.20 8990.67 8938.67 -2307.26 9380.44 5996218.77 691018.27 6808.99 10.71 MWD 13847.63 94.94 146.16 8987.55 8935.55 -2331.09 9398.28 5996195.39 691036.68 6838.60 20.97 MWD 13906.00 86.00 146.16 8987.07 8935.07 -2379.52 9430.75 5996147.76 691070.31 6896.84 15.32 MWD ~.r by BP Alaska ~~s Baker Hughes INTEQ Survey Report 1NTEQ Company: BP Amoco Date: 3/24/2006 Time: 16:37:36 Page: 1 .Field: Point McIntyre Co-ordinate(NE) Reference: We1L' P2-37, True North Site: Pt Mac 2 Vertical (TVD) Refereneer 52:378/16/1.995.00:00 52.0 Well: P2-37 Sectio® (VS) Reference: Well (O.OON,O.OOE,149.OOAzi) Wefipath: P2-37A Survey Calcelation Methods Minimum Curvature Db: OraGe Field: Point McIntyre North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Daturo: NAD27 (Clarke 1866) Coordiuate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Pt Mac 2 TR-12-14 UNITED STATES :North Slope Site Position: Northing: 5995140.76 ft latitude: 70 23 32.530 N Froro: Map Easting: 674873.98 ft Longitude: 148 34 37.934 W Position Uncertainty: 0.00 ft North Reference: TNe Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: P2-37 Slot Name: 37 P2-37 Well Position: +N/-S 2998.87 ft Northing: 5998297.28 ft Latitude: 70 24 1.993 N +E/-W 6783.59 ft Easting : 681585.12 ft Longitude: 148 31 19.199 W Positron Uncertainty: 0.00 ft Welipath: P2-37A Drilled From: P2-37APB1 50-029-22576-01 Tie-on Depth: 13695.03 ft Current Datam: 52:37 8/16/1995 00:00 Height 52.00 ft Above System Datum: Mean Sea Level Magnetic Data: 3/17/2006 Declination: 24.69 deg Field Strength: 57616 nT Mag Dip Angle: 80.97 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 41.00 OAO 0.00 149.00 Survey Program for Definitive Welipath Date: 3/17/2006 Validated: Yes Version: 1 Actual From To Survey Tooicode Tool Name ft fl 109.82 13340.51 1 : MWD -Standard (109.82-138 MWD MWD -Standard 13410.03 13695.03 MWD (13410.03-13906.00) (1) MWD MWD -Standard 13704.72 14453.00 MWD (13704.72-14453.00) MWD MWD -Standard Annotation MD TVD ft ft 13695.03 9016.85 TIP 13704.72 9014.45 KOP 14453.00 9130.48 TD Survey: MWD Start Date: 3/17/2006 Company: Baker Hughes INTEQ Engineer: Toot: MWD;MWD - Standard Tied-to: From: Definitive Path ~.r by BP Alaska $ Baker Hughes INTEQ Survey Report INTEQ Company: SP Amoco. Date: 3!24/2006 Tim e: 16:37:36 Pale: 2 .:Field: Point MGnty~e Co-ordmataNE) Reference: Weli: P2=37, True North Site: Pt Mac 2 Vertical (TVD) Reference; 52 i 37 8/16/t995 00:00 52.0 Well: P2-37 Section (VS) Retereace: Well (O.OON,O.OOE,149.OOAzi) Wellpatb: P2-37A Sarvey Cakulatioa MetLod: Minimum Curvature Db: Oracle Survey MD Iact Azitn TVD Sys TVD N/S E/W MapN MapE VS DLoS Tool ft deg deg ft ft ft ft ft ft ft deg1100ft 13695.03 105.53 129.34 9016.85 8964.85 -2220.98 9297.75 5996303.01 690933.51 6692.45 0.00 MWD 13704.72 103.22 127.77 9014.45 8962.45 -2226.83 9305.09 5996297.34 690940.99 6701.24 28.54 MWD 13737.13 95.18 127.77 9009.27 8957.27 -2246.41 9330.36 5996278.38 690966.73 6731.04 24.81 MWD 13766.66 92.94 133.13 9007.18 8955.18 -2265.51 9352.76 5996259.83 690989.59 6758.95 19.63 MWD 13796.62 92.01 139.03 9005.88 8953.88 -2287.07 9373.52 5996238.79 691010.86 6788.12 19.92 MWD 13831.63 94.53 146.01 9003.88 8951.88 -2314.78 9394.77 5996211.60 691032.78 6822.82 21.16 MWD 13861.42 93.64 150.82 9001.76 8949.76 -2340.09 9410.33 5996186.68 691048.95 6852.52 16.38 MWD 13891.59 89.40 154.10 9000.96 8948.96 -2366.82 9424.27 5996160.30 691063.53 6882.62 17.76 MWD 13921.72 85.90 158.53 9002.20 8950.20 -2394.38 9436.36 5996133.05 691076.28 6912.47 18.73 MWD 13951.93 84.94 164.65 9004.61 8952.61 -2422.93 9445.86 5996104.73 691086.48 6941.84 20.44 MWD 13986.71 82.29 170.77 9008.48 8956.48 -2456.69 9453.22 5996071.17 691094.66 6974.56 19.07 MWD 14001.92 80.48 173.41 9010.76 8958.76 -2471.58 9455.29 5996056.33 691097.09 6988.39 20.88 MWD 14032.74 76.82 178.05 9016.83 8964.83 -2501.70 9457.55 5996026.28 691100.08 7015.37 18.94 MWD 14062.00 75.78 183.62 9023.76 8971.76 -2530.11 9457.14 5995997.87 691100.36 7039.51 18.83 MWD 14093.96 75.58 187.10 9031.67 8979.67 -2560.94 9454.25 5995966.98 691098.21 7064.45 10.57 MWl7 14121.62 74.79 196.11 9038.76 8986.76 -2587.10 9448.88 5995940.69 691083.48 7084.11 31.62 MWD 14161.62 73.87 194.87 9049.56 8997.56 -2624.21 9438.59 5995903.35 691084.10 7110.62 3.77 MWD 14191.86 75.11 188.95 9057.65 9005.65 -2652.71 9432.59 5995874.71 691078.79 7131.96 19.30 MWD 14221.62 76.47 183.17 9064.96 9012.96 -2681.39 9429.55 5995845.97 691076.45 7154.97 19.37 MWD 14252.19 77.67 177.92 9071.81 9019.81 -2711.17 9429.27 5995816.20 691076.89 7180.35 17.19 MWD 14281.62 76.81 170.46 9078.32 9026.32 -2739.70 9432.17 5995787.74 691080.48 7206.31 24.89 MWD 14311.62 74.92 165.44 9085.65 9033.65 -2768.14 9438.23 5995759.46 691087.24 7233.81 17.41 MWD 14342.13 72.59 162.34 9094.19 9042.19 -2796.28 9446.35 5995731.53 691096.04 7262.11 12.39 MWD 14372.07 71.28 157.55 9103.47 9051.47 -2823.01 9456.11 5995705.05 691106.44 7290.04 15.83 MWD 14402.29 70.33 153.45 9113.41 9061.41 -2848.97 9467.94 5995679.38 691118.90 7318.39 13.19 MWD 14453.00 70.33 153.45 9130.48 9078.48 -2891.69 9489.28 5995637.20 691141.27 7366.00 0.00 MWD WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP = 13476' Max Angle = 106° @ 13695' Datum MD = 13254' Datum TV D = 8800' SS 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" 4621' Minimum ID = 2.37" @ 13404' 2-7/8" STL LNR 7-5/8" CSG, 29.7#, L-80, ID = 6.875" ~~ 13076' EST TOP OF CEMENT I-{ 13118' ~3-1/2" XN NIP, ID = 2.75" ~ 131 58' 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 13150 °°°~ • P 2 -3 7 A FMC BAKERC CTD Sidetrack 51.5' DRLG DRAFT PERFORATION SUMMARY REF LOG: MCNL/CCUGR OF 3117/2006 TIE-IN LOG: GEOLOGY PDC LOG A NGLE AT TOP PERF: 92.25° @ 13800' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 13800' - 13860' Opn 03/18/06 2" 6 14010' - 14050' Opn 03/18/06 2" 6 14070' - 14110' Opn 03/18/06 2" 6 14170' - 14190' Opn 03,'18106 MECHANICAL WHIPSTOCK 13476' WINDOW 13481' - 13488' ~ RA PIP TAG 13485.8' PBTD 13731' 7-518" CSG, 29.7#, NT-13-CR-805, ID = 6.875" 13815' I SAFETY NOTES: 4-1 @" CHROME TBG & 7-518" CHROMECSG. 3-1/2" X 2-7/8" CHROME LNR 2110' ~-1 4-1/2" CAMCO TRCF-4A TRSSSV, ID = 3.812" ~ ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 5096 4004 53 KMBG BK 2 7637 5506 53 KMBG BK 3 8957 6298 55 KMBG BK 4 9994 6903 53 KMBG BK 5 10826 7393 54 KMBG BK 6 11661 7889 54 KMBG BK 7 13018 8712 53 KMBG BK 13084' 4-1/Z" OTIS X NIP, ID = 3.813" 13095' 7-5/8" X 4-1/2" BAKER S-B PACKER 13118' TOP OF 3-1/2" X 2-7/8" 13CR80 LNR 13118' BOT DEPLOY SLEEVE. 6' LONG, 3" ID 13129' 4-1 /2" OTIS XN NIP, ID =MILLED TO 3.8" 13150' 4-4/5" TUBING TAIL, WLEG 13154' ELMD TT LOGGED 09/11/95 13403' 3-1/2" X 2-7/8" X-OVER 14419' PBTD 3-1/2" X 2-718" 13CR80 CMTED & PERFED 13650' -{ 3.7" BROACH, PARTED AT SUCKER ROD CONNECTION DATE REV BY COMMENTS DATE REV BY COMMENTS 09!03/95 ORIGINAL COMPLETION 09/16!01 RN/KAK CORRECTIONS 03/17/04 MDC/TLP ADD PERFS 03/31/05 MSE PROPOSED CTD SIDETRACK 02/11/06 JUE NORDIC-1 CTD SIDETRACK I 14453' I ~ HAMMER PUSHED TO BOTTOM OF HOLE ~ POINT MCINTY RE UNIT WELL: P2-37A PERMff No: 205-057 API No: 50-029-22576-01 SEC 14, T12N, R14E, 4643.28' FEL & 2480.42' FNL BP Exploration (Alaska) ~ 1 ~) , '"~ ~ a , FRANK H. MURKOWSKI, GOVERNOR ~~ AI.~A:SSi~ OIIt A1~D G~--S ' 333 W. 7"' AVENUE, SUITE 100 CO1~T5ERQA'1`IO1~T COM1~iISSIOIQ ~ ~ ANCHORAGE, ALASKA 99501-3539 > PHONE (907) 279-1433 FAX (907} 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay P2-37A BP Exploration (Alaska) Inc. Permit No: 205-057 Surface Location: 287' FNL, 1342' FWL, SEC. 14, T12N, R14E, UM Bottomhole Location: 3221' FNL, 280' FWL, SEC. 18, T12N, R15E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely -,. ~~,. l ~ y ~ ~ ~ ~~ f .-- Daniel T. Seamount, Jr. Commissioner DATED this ~ day of April, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1~.PGl~- ¢i5 2e-o5 STATE OF ALASKA R~~~~~D ALAS OIL AND GAS CONSERVATION~MM1SS10N PERMIT TO DRILL pp~ _ ~ ~oa5 20 AAC 25.005 / Alaska Qil & Cas Gins. Commission 1 a. Type of work ~ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class g p ^ Exploratory ®DeveloPment Oil ~gly{~pyp Zone ^ Strati ra hic Test ^ Service ^ Develo ment Gas in one 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number: PBU P2-37A / 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 14450 ND 907688 12. Field /Pool(s): Prudhoe Bay Field /Point 4a. Location of Well (Governmental Section): Surtace: 287' SNL 1342' EWL SEC 14 T12N R14E UM 7. Property Designation: ADL 034627 McIntyre Pool , , . , , , Top of Productive Horizon: 2424' SNL, 5162' EWL, SEC. 13, T12N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: April 16, 2005 Total Depth: 3221' SNL, 280' EWL, SEC. 18, T12N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 4500' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 681585 y- 5998297 Zone- ASP4 10. KB Elevation (Height above GL): 52.1' feet 15. Distance to Nearest Well Within Pool 1400' 16. Deviated Wells: Kickoff Depth: 13472 feet Maximum Hole Angle: 105 de rees 17. Maximum Anticipated Pressures in psig (see 20 AA 5) Downhole: 4250 Surface: 337 18. asing rogram: Size Specifications Setting Depth To Bottom n o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data a-va° x ~-~a• -~-iir X zaia' 9.3# / 6.16# 13Cr80 STL 1330' 13120' 8720' 14450' 9076' 6 sx Class 'G' ~ 19. PRESENT WELL CONDITION SUMMARY (To be completed. for Redrill AND Re-entry Operations) Total Depth MD (ft): 13815 Total Depth TVD (ft): 9184 Plugs (measured): None Effective Depth MD (ft): 13731 Effective Depth TVD (ft): 9135 Junk (measured): 13650 Casin Len th Size Cement Volume MD TVD r r n u r 80' 20" 50 sx Arcticset A rox. 80' 80' 4581' 10-3/4" 1130 sx Permafrost 'E', 375 sx Class 'G' 4621' 3719' I Pro tin 13772' 7-5/8" 85 sx Class 'G' 13810' 9181' Perforation Depth MD (ft): 13430' - 13620' Perforation Depth TVD (ft): 8957' - 9070' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mary Endacott, 564-4388 Printed Name Mary Endacott Title CT Drilling Engineer ~ ~? _ Preparetl By Name/Number: Si nature ° ,~~ ~ ~~ ~,~3- ~ ~ ~~ . ~ Phone 564-4388 Date ~ ~ j Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number:Zos= G7,S API Number: 50-029-22576-01-00 Permit Appr al Date: Z{ ~ p See cover letter for other requirements Conditions of Approval: Samples Required ^ Yes No Mud Log Required ^ Yes ~No Hydrogen Sulfide Measures Yes ~_~ No Directional Survey Required Yes ~,=; No Other: ~e5~" i~,~0 ~L ~ ~S©C~ ~S~f , Original Sighed By QAND SEAMOUNT ,~ APPROVED BY i~ ~ ~ ~ ~ ~ R~, r~~, THE COMMISSION ~ ~`OS A roved B : Date Form 10-401 Revised 06/2004 "`° ` ' '"` " "'"" Submit In Duplicate BP P2-37A Sidetrack CTD Sidetrack Summary 1) Mill window off whipstock 2) Drill sidetrack 3) Run liner, cement Mud Program: • Well kill: 9.6 ppg 'n • Milling/drilling• pg used Flo Pro, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • 3 1/2" x 2 7/8" solid cemented liner completion 0 3-1l2" liner 13120'- 13500' 0 2-7/8" liner 13500' - 14450' • The liner cement volume is planned to be 9.$~bbls of 15.8 ppg class G. f Casin~/Liner Information 10 3/4", NT-80, 45#, Burst 5210 psi; collapse 2480 psi 7 5/8", NT-13-CR-80S 29.7#, Burst 6890, collapse 4790 psi planned 3 1/2" 13Cr-80 STL, 9.3#, Burst 10180 psi; collapse 10540 psi (hole size 4.125") 2 7/8" 13Cr-80 STL 6.16#, Burst 10570 psi; collapse 11170 psi (hole size 3.75") Well Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. ~ The annular preventer will be tested to 400 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 105 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line is 4500'. • Distance to nearest well within pool: 1400' Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. Hazards /' • P2 is designated as an HZS pad. H251evel 145 pm recorded in P2-60. PPE, HSE, etc per standard H2S precautions for pad >100ppm • Lost circulation risk is considered "low". Reservoir Pressure Res. press. is estimated to be 4250 psi at 8800'ss (9.3 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 3370 psi. i TREE = COOPER WELLHEAD = FMC ACTUATOR = BAKER C K~. ELEV.- __ 51.5' BF. ELEV = KOP = 1106' _.... Max Angle = 55 @ 9104' Datum MD = 13254' Datum TV D = 8800' SS SAFETY NOTES: 4-1 /2" CHROME TBG P 2'~3 7 & 7-5/8" CHROME CSG 2110' 4-1/2" CAMCO 7RCF-4A TRSSSV, ID = 3.812" 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" 4621' Minimum ID = 3.725" @ 13129' OTIS XN NIPPLE 7-5/8" CSG, 29.7#, L-80, {D = 6.875" ~-i 13076' 4-1/2" TBG, 12.6#, 13-C R, .0152 bpf, ID = 3.958" ~-i 13150' PERFORATION SUMMARY REF LOG: SWS CDR/GR ON 08/29/95 ANGLE AT TOP PERF: 53 @ 13430' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 13430 - 13450 O 03/17104 3-3/8" 6 13464 - 13540 O 09!12/95 2-7/8" 6 13470 - 13490 O 03/17/04 2-7/8" 6 13500 - 13510 O 03/17/04 2-718" 6 13510 - 13530 O 03/17/04 3-3/8" 6 13560 - 13620 O 09/12/95 PBTD 13731' 7-5/8" CSG, 29.7#, NT-13-CR-80S, ID = 6.875" 13815' GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 5096 4004 53 KMBG BK 2 7637 5506 53 KMBG BK 3 8957 6298 55 KMBG BK 4 9994 6903 53 KMBG BK 5 10826 7393 54 KMBG BK 6 11661 7889 54 KMBG BK 7 13018 8712 53 KMBG BK 13084' 4-1/2" OTIS X NIP, ID = 3.813" 13095' 7-5/8" X 4-1/2" BAKER S-B PACKER 13129' ~--'~ 4-1/2" OTIS XN NIP, ID = 3.725" 13j 15U' ~-1 4-4/5" TUBING TAIL, WLEG I 13154' ELMD Tf LOGGED 09/11/95 13650' -{ 3.7" BROACH, PARTEDAT SUCKER ROD CONNECTION 13730' I-i HAMMER PUSHED TO BOTTOM OF HOLE DATE REV BY COMMENTS DATE REV BY COMMENTS 09/03/95 ORIGINAL COMPLETION 09/16/01 RN/KAK CORRECTIONS 03/17/04 MDC/TLP ADD PERFS POINT MCINTYRE UNff WELL: P2-37 PERMff No: 1951060 API No: 50-029-22576-00 SEC 14, T12N, R14E, 4643.28' FEL & 2480.42' FNL BP Exploration (Alaska) TREE = COOPER WELLHEAD= FMC ACTUATOR= BAKERC KB. ELEV = 51.5' BF. ELEV = KOP = 1106' Max Angle = 55 @ 9104' Datum MD = 13254' Datum ND = 8800' SS 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" 4621' Minimum ID = 3.725" @ 13129' OTIS XN NIPPLE (milled to 3.8") 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 13076' Top of Cement 13120' TOP OF 3-1/2" 13cr80 LNR 13120' 3.5" XN Nip 2.75" I 13150 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 13150' PERFORATION SUMMARY REF LOG: SWS CDR/GR ON 08/29/95 ANGLE AT TOP PERF: 53 @ 13430' Note: Refer to Production DB for historical perf data SIZE SPF WTERVAL Opn/Sqz DATE 2-7/8" 6 13430 - 13450 isolated proposed 3-3/8" 6 13464 - 13540 isolated proposed 2-7/8" 6 13470 - 13490 isolated proposed 2-7/8" 6 13500 - 13510 isolated proposed 2-7/8" 6 13510 - 13530 isolated proposed 3-3/8" 6 13560 - 13620 isolated proposed 14450' / 3.7" BROACH, PARTED AT SUCKER ROD CONNC-CTION 13730' HAMMER t 7-5/8" CSG, 29.7#, NT-13-CR-SOS, ID = 6.875" 1 13815' I DATE REV BY COMMENTS DATE REV BY COMMENTS 09/03/95 ORIGINAL COMPLETION 09/16/01 RN/KAK CORRECTIONS 03/17(04 MDCITLP ADD PERFS 03/31/05 MSE PROPOSED CTD SIDETRACK POINT MCINTYRE UNIT WELL: P2-37A PERMfT No: API No: 50-029-22576-01 SEC 14, T12N, R14E, 4643.28' FEL & 2480.42' FNL BP Exploration (Alaska) P2-37A Proaosed CTD Sidetrack SAFETY NOTES: 4-1 /2" CHROME TBG 8 7-518" CHROME CSG 2110' I-i 4-1l2" CAMCO TRCF-4A TRSSSV, ID = 3.812" I GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 5096 4004 53 KMBG BK 2 7637 5506 53 KMBG BK 3 8957 6298 55 KMBG BK 4 9994 6903 53 KMBG BK 5 10826 7393 54 KMBG BK 6 11661 7889 54 KMBG BK 7 13018 8712 53 KMBG BK 4-1/2" OTIS X NIP, ID = 3.813"1 7-5/8" X 4-1/2" BAKER S-B PACKER -~ 13129' ~• 13150' 13154' • 13500' 3-1. 1 4-1/2" OTIS XN NIP, ID = 3.725" (milled to 3.8") 4-4/5" TUBING TAIL, WL~ ELMD TT LOGGED 09/11/95 2 x 2-7/8 X-over 3-1/2" X 2-7/8" 13Cr80 cmt'ed and 13472' Mechanical Whipstock ~;: ~~ q~ BP Amoco weurerx oe>uu n.nex, na> eoaxrzxssa+ r. w.ewm, na Te en tlD+ +aaeo.e+ +s.e. o.e m~ sa ~ ar>1~wwaes oomo ax.aaR ue.oo• om o.oo e+.oo REFERENCE INFORMATION Co-ad'mate (N/E) Relerence: Well Centre: P2-37, True NoM ~, VerGral (ND) Relerence: System: Mean Sea Level ~ Sectlon (VS) Relerence: User Dented (O.OON,O OOE) Measured Depm Reference: 52:378/76/199500:00 62.00 Celalation Metlrotl: Minimum Curvature + er.r ar.... v w.r ii+ii°no u» ... _.T-.......____......._..____-'--._.... •wraunoea ,•A~E•oE••"s eeso.ea +aa,o.s+ >w i;..c°eM°°.;r emo °. .~°~'" one.n +>.n.oo ^w ew+.sx +aeex.oo ow rnao•oH.e >vm ..vas was mm~ sw++. w.. sne.s: +aeoe.xe e n>o.>e +aw+.n or emnoo ou ewx.v+ +a>ee.>s s esxe.v> +asnas ewasv nwv>a > eme.xa +nn.>a e es>s.>v +ueo.ao ro LEGEND T p,Zimuths to True North Ren: Plan p2 (P2-37/Plan#2. P2-37) - Pz 38 P2 3s) M Ma nelic North: 24.93° created B Bill Michaelson Date: 3/2s/zoos P2-37 P2-37 9 Y - RarW2, P2-3~ 4.„ - Ran n2 Magnetic Field contact inro~-nal;o~., lJ'.I Slfenglh: 57647nT James Ohl;nger Dip Angle: 80.93° o,rea (so7) 267-6670 Date: 3/29/2005 care (907) 250-7375 Model: bggm2OO4 E-mail: jamae.ohlinger(o]integ.com • PM ~ • ~,~, Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~~ t~-c>~r~ Companyo- BP Amoco Date: .3/29/2005 Time: 13:38:29 Page: Field: Point Mac Co-ordinate(NE) Reference: :Well: P2-37, True North I~ Site: Pt Mac 2 <Vertical (1'VD) Reference: ' 52:37 8/16/1995 00:00 52.0 Well: P2-37 Wellpathc Plan#2, P2-3T Section (VS) Reference: Well (0'OON,O.OOE,107.13Azi) Survey Calculation Method: 'Minimum Curvature Db: Oracle Field: Point Mac North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Pt Mac 2 TR-12-14 UNITED STATES :North Slope Site Position: Northing: 5995140 .76 ft Latitude: 70 23 32.530 N From: Map Easting: 674873 .98 ft Longitude: 148 34 37.934 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: P2-37 Slot Name: 37 P2-37 Well Position: +N/-S 2998.87 ft Northing: 5998297 .28 ft Latitude: 70 24 1.993 N +E/-W 6783.59 ft Easting : 681585 .12 ft Longitude: 148 31 19.199 W Position Uncertainty: 0.00 ft Wellpath: Plan#2, P2-37 Drilled From: P2-37 50-029-22576-01 Tie-on Depth: 13340.51 ft Current Datum: 52:37 8/16/1995 00:00 Height 52 .00 ft Above System Datum: Mean Sea Level Magnetic Data: 3/29/2005 Declination: 24.93 deg Field Strength: 57647 nT Mag Dip Angle: 80.93 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 41.00 0.00 0.00 107.13 Plan: Plan #2 Date Composed: 3/29/2005 Version: 2 Principal: Yes Tied-to: From: Definitive Path Targets Map Map G-- Latitude => <-- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip.+. Dir. ft ft ft ft ft _; P2-37 Polygon 52.00 -1985.57 9035.88 5996531.97 690666.02 70 23 42.411 N 148 26 54.550 W -Polygon 1 52.00 -1985.57 9035.68 5996531.97 690666.02 70 23 42.411 N 148 26 54.550 W -Polygon 2 52.00 -2228.57 8990.96 5996287.97 690627.02 70 23 40.022 N 148 26 55.874 W -Polygon 3 52.00 -2430.12 9175.13 5996090.97 690816.02 70 23 38.038 N 148 26 50.487 W -Polygon 4 52.00 -3151.96 9363.66 5995373.97 691022.02 70 23 30.936 N 148 26 44.992 W -Polygon 5 52.00 -3048.73 9726.30 5995485.97 691382.02 70 23 31.947 N 148 26 34.369 W -Polygon 6 52.00 -2432.33 9595.23 5996098.97 691236.02 70 23 38.011 N 148 26 38.184 W -Polygon 7 52.00 -2100.61 9406.22 5996425.97 691039.02 70 23 41.275 N 148 26 43.707 W P2-37 Target 2 8982.00 -2377.56 9358.47 5996147.97 690998.02 70 23 38.552 N 148 26 45.116 W P2-37 Target 1 9028.00 -2188.05 9217.03 5996333.97 690852.02 70 23 40.418 N 148 26 49.252 W P2-37 Target 3 9128.00 -2928.22 9501.14 5995600.97 691154.02 70 23 33.135 N 148 26 40.958 W Annotation MD > TVD ft °ft 13340.51 8902.95 TIP 13472.00 8981.77 KOP 13492.00 8993.52 End 9°/100' D LS 13604.26 9027.62 4 13641.77 9022.74 End 40°/100' DLS 13748.76 8994.91 5 13847.76 8981.97 6 13947.76 8994.80 7 • • ~,~ Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~.. ~~ ri~~ - Company: BP Amoco Date: 3/29!2005 Time: 13:38:29 Page: 2 ~ Field: Point Mac Co-ordinate(NE) Reference: Well: P2-37, True North ` Site: Pt Mac 2 Vertical (TVD) Reference: 52:37 8/16/1995 00:00 52.0 -We1L• P2-37' Section (VS) Reference: 'Well (O.OON,OOOE,107.1 3Azi) Wellpath: Plan#2, P2-37 Survey CalculaUon'Method: Minimum Curvature Db: Oracle Annotation ~ MD TVD ft ft _ I 1419776 9061.23 8 , 14450.00 9127.79 TD Plan Section Information MD Incl. Azim TVD: tN/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ` ft ft deg/100ft deg/100ft degl100ft deg 13340.51 53.32 102.46 8902.95 -2112.03 9007.23 0.00 0. 00 0.00 0.00 13410.03 53.05 101.24 8944.61 -2123.46 9061.70 1.46 -0. 39 -1.75 254.18 13472.00 53.26 101.74 8981.77 -2133.34 9110.30 0.73 0. 34 0.81 62.46 13492.00 54.82 102.84 8993.52 -2136.78 9126.11 9.00 7. 82 5.50 30.00 13604.27 90.00 132.79 9027.62 -2187.75 9216.73 40.00 31 .33 26.67 45.00 13641.77 105.00 132.79 9022.74 -2212.93 9243.94 40.00 40. 00 0.00 0.00 13748.76 104.95 149.40 8994.91 -2293.04 9308.59 15.00 -0 .04 15.53 88.00 13847.76 90.10 149.40 8981.97 -2377.29 9358.41 15.00 -15. 00 0.00 180.00 13947.76 75.10 149.40 8994.80 -2462.41 9408.74 15.00 -15. 00 0.00 180.00 14197.76 7521 188.25 9061.23 -2694.34 9454.53 15.00 0 .04 15.54 95.00 14450.00 75.33 149.08 9127.79 -292825 9501.45 15.00 0. 05 -15.53 265.00 Survey MD Inc! Azim - SS TVD <N!S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/f00ft ft deg 13340.51 53.32 102.46 8850.95 -2112.03 900723 5996404.87 690640.45 0.00 9229.75 0.00 MWD 13350.00 5328 10229 8856.63 -2113.66 9014.66 5996403.42 690647.92 1.46 9237.34 254.18 MWD 13375.00 53.18 101.86 8871.59 -2117.85 903425 5996399.70 690667.60 1,46 925728 25428 MWD 13400.00 53.09 101.42 8886.59 -2121.88 9053.84 5996396.15 69068728 1.46 9277.19 254.54 MWD 13410.03 53.05 10124 8892.61 -2123.46 9061.70 5996394.76 690695.18 1.46 9285.17 254.81 MWD 13425.00 53.10 101.36 8901.61 -2125.80 9073.43 5996392.70 690706.96 0.73 9297.08 62.46 MWD 13450.00 53.19 101.56 8916.60 -2129.78 9093.04 599638921 690726.66 0.73 9316.98 62.39 MWD 13472.00 5326 101.74 8929.77 -2133.34 9110.30 5996386.07 690744.00 0.73 9334.52 6226 MWD 13472.38 5329 101.76 8930.00 -2133.40 9110.59 5996386.01 690744.29 9.00 9334.82 30.00 P2-37 T 13475.00 53.49 101.91 8931.56 -2133.83 9112.65 5996385.63 690746.37 9.00 9336.92 29.99 MWD 13492.00 54.$2 102.84 8941.52 -2136.78 9126.11 5996383.01 690759.89 .00 9350.65 29.90 MWD 13500.00 57.12 105.53 8946.00 -2138.41 9132.54 5996381.54 690766.36 0.00 935727 45.00 MWD 13525.00 64.60 113.14 8958.17 -2145.68 9153.09 5996374.77 690787.07 40.00 9379.05 43.49 MWD 13550.00 72.43 119.83 8967.33 -2156.07 9173.86 5996364.89 690808.09 40.00 9401.97 39.78 MWD 13575.00 80.47 125.96 8973.19 -216927 9194.23 5996352.19 690828.78 40.00 9425.32 37.32 MWD 13600.00 88.61 131.80 8975.57 -2184.88 9213.58 5996337.06 690848.49 40.00 9448.40 35.88 MWD 1360427 90.00 132.79 8975.62 -2187.75 9216.73 599633426 690851.71 40.00 945226 35.32 MWD 13625.00 9829 132.79 8974.12 -2201.78 9231.89 5996320.60 69086721 40.00 9470.88 0.00 MWD 13641.77 105.00 132.79 8970.74 -2212.93 9243.94 5996309.75 690879.52 40.00 9485.68 360.00 MWD 13650.00 105.04 134.06 8968.60 -2218.40 9249.71 5996304.43 690885.43 15.00 9492.81 88.00 M W D 13675.00 105.12 137.95 8962.10 -2235.76 9266.48 5996287.48 690902.61 15.00 9513.94 88.33 MWD 13700.00 105.13 141.83 8955.58 -225421 9282.02 5996269.41 690918.60 15.00 9534.23 89.34 MWD 13725.00 105.07 145.72 8949.06 -2273.68 929628 5996250.30 690933.33 15.00 9553.59 90.36 MWD 13748.76 104.95 149.40 8942.91 -2293.04 9308.59 599623124 690946.10 15.00 9571.06 91.37 MWD 13750.00 104.77 149.40 8942.59 -2294.08 930920 599623022 690946.74 15.00 9571.95 180.00 MWD 13775.00 101.02 149.40 8937.01 -2315.05 9321.60 5996209.56 690959.64 15.00 9589.97 180.00 MWD 13800.00 9727 149.40 8933.04 -233629 9334.16 5996188.63 690972.71 15.00 960823 180.00 MWD 13825.00 93.52 149.40 8930.69 -2357.71 9346.83 5996167.52 690985.90 15.00 9626.65 180.00 MWD 13847.76 90.10 149.40 8929.97 -237729 9358.41 599614823 690997.94 15.00 9643.48 180.00 MWD 13850.00 89.77 149.40 8929.97 -237922 9359.55 5996146.33 690999.13 15.00 9645.13 180.00 MWD 13875.00 86.02 149.40 8930.89 -2400.72 937226 5996125.15 691012.36 15.00 9663.62 180.00 MWD 13900.00 8227 149.40 8933.44 -2422.12 9384.92 5996104.06 691025.53 15.00 9682.01 180.00 MWD 13925.00 78.52 149.40 8937.61 -2443.34 9397.46 5996083.16 691038.59 15.00 970025 180.00 MWD 13947.76 75.10 149.40 8942.80 -2462.41 9408.74 5996064.37 691050.33 15.00 9716.64 180.00 MWD • ~,~, Baker Hughes INTEQ Baker Hughes INTEQ Planning Report fir ~cv~r~gi Company: BP Amoco Date: 3/29/2005 - Time: .13:38:29 Page: 3 Field: Poi nt Mac Co-ordinate(NE) Reference: WeILiP2-37, True North l Site: Pt Mac 2 Vertical (TVD) Reference: 52:37$/16/1995 00:00 52.0 ` Well: P2-37 Section (VS) Reference: Well (O.OON ,O.OOE,107.1 3Azi) i Wellpath: Plan#2, P2-37 Survey Ca)cuiation Method: Minimum Curvature Db: -- Oracle ' -----~ Survey - MD Incl Azim 'SS TVD , N/S E/W MapN MapE DLS VS TFl3 Tool ~~ ft deg deg ft' ft ft ft ft deg/100ft ft deg 13950.00 75.08 149.75 8943.38 -2464.28 9409.83 5996062.53 691051.47 15.00 9718.24 95.00 MWD 13975.00 74.79 153.62 8949.88 -2485.52 9421.28 5996041.57 691063.43 15.00 9735.44 94.91 MWD 14000.00 74.57 157.50 8956.49 -2507.47 9431.25 5996019.87 691073.93 15.00 9751.43 93.90 MWD 14025.00 74.41 161.39 8963.18 -2530.02 9439.71 5995997.53 691082.93 15.00 9766.15 92.88 MWD 14050.00 74.32 165.29 8969.92 -2553.08 9446.61 5995974.65 691090.39 15.00 9779.54 91.84 MWD 14072.49 74.31 168.79 8976.00 -2574.18 9451.46 5995953.68 691095.75 15.00 9790.39 90.79 P2-37 T 14075.00 74.31 169.18 8976.68 -2576.55 9451.93 5995951.32 691096.27 15.00 9791.53 89.84 MWD 14100.00 74.36 173.08 8983.43 -2600.33 9455.64 5995927.64 691100.56 15.00 9802.08 89.73 MWD 14125.00 74.48 176.97 8990.15 -2624.31 9457.73 5995903.71 691103.23 15.00 9811.15 88.68 MWD 14150.00 74.67 180.85 8996.80 -2648.40 9458.19 5995879.64 691104.28 15.00 9818.68 87.64 MWD 14175.00 74.92 184.73 9003.36 -2672.49 9457.01 5995855.53 691103.69 15.00 9824.65 86.60 MWD 14197.76 75.21 188.25 9009.23 -2694.34 9454.53 5995833.63 691101.73 15.00 9828.71 85.59 MWD 14200.00 75.18 187.90 9009.80 -2696.48 9454.22 5995831.48 691101.48 15.00 9829.05 265.00 MWD 14225.00 74.90 184.03 9016.25 -2720.50 9451.71 5995807.41 691099.56 15.00 9833.72 265.09 M W D 14250.00 74.67 180.15 9022.82 -2744.60 9450.83 5995783.30 691099.26 15.00 9839.98 266.09 MWD 14275.00 74.52 176.27 9029.46 -2768.69 9451.58 5995759.24 691100.60 15.00 9847.79 267.11 MWD 14300.00 74.43 172.38 9036.15 -2792.65 9453.96 5995735.34 691103.56 15.00 9857.13 268.14 MWD 14325.00 74.41 168.48 9042.87 -2816.39 9457.97 5995711.71 691108.14 15.00 9867.95 269.18 MWD 14350.00 74.46 164.59 9049.58 -2839.81 9463.57 5995688.43 691114.31 15.00 9880.20 270.23 MWD 14375.00 74.58 160.70 9056.26 -2862.80 9470.76 5995665.63 691122.05 15.00 9893.84 271.27 M W D 14400.00 74.76 156.82 9062.87 -2885.27 9479.49 5995643.38 691131.33 15.00 9908.80 272.31 MWD 14425.00 75.01 152.94 9069.39 -2907.12 9489.74 5995621.79 691142.10 15.00 9925.03 273.34 MWD 14450.00 75.33 149.08 9075.79 -2928.25 9501.45 5995600.94 691154.32 15.00 9942.44 274.35 MWD • All Measurements are from top of Riser 3/24/2005 L ~_ ~ P2-37A BAG / 7 1/16" 5000 psi. bttm of bag of slips of pipes of flow cross of of pipe/slips Blind/Shears TOTs ~ 2 3/8" combi ram/slips X71/16" 5ooopsi Mud Cross I I Mud Cross 7 1/16" 5000psi variable bore pipe 3 1/2"-2 7/8" _ TOTs / 2 3/8" combi ram/slips 7 1/16" 5ooopsi Flow Tee ... ss-sn 25z 191.. TERRIE L NUBBLE BP EXPLORATION AK INC °Mastercard Check" ,1 PO BOX 196612 MB 7-5 -U' -V 5 ..ANCHORAGE, AK 99519-6612 DATE PAY TO THE ORDER OF DOLLARS - First National nk Alaska Anchorage, AK 99501. ~ MEMO.- +:L25200Q60~:99L4..~6227..~L556u• OL'9L s • C7 • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~?R~., / Z ' . ~ ~~ PTD# Zob~' ~ O S ~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS MiTLTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PIT) records, data and togs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\j ody\transm ittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PT MCINTYRE OIL - 640180 Well Name: PRUDHOE BAY UN PTM P~37A Program DEV Well bore seg ^ PTD#:2050570 Company BP EXPLORATION (ALASKA)_INC __ Initial ClasslType DEV 11-0IL GeoArea 890 _- Unit 11650 OnlOff Shore Off Annular Disposal --- Administration 1 Permit_feeattached___________________-_-_______-__________---- Yes_ __---.-_____-_---__________-- 2 Lease number appropriate- - - - - - - - - - - - - - - - -------------- Yes _ _ , - - - - 13 Uniquewell_nameandnumber__-___-____________________________ Yes_ ___-______-_._ ---------------------------------------------------------- 4 Well located in a. defined_pool ________________--_____-,-_--_____, Yes_ ______.--_ 5 Well located proper distance from drilling unit_boundary_ - - - Yes 6 Well located properdistance_from4therwells_________________ ____________ Yes- __-_____---_--______.--.- i 7 Sufficient acreageayailablein-drilling unit____---________________________ Yes_ ___- -- -- 8 Ifdevlated,is-Wehboreplatincluded_____________ _____-.--________-_ Yes_ ___---____ 9 Operator onlyaff_ectedparty---------------------- ----------------- Yes- ------------------- 10 Ope[atorhas-appr_opriate.bondinfarce, ---------- -- - - ---- Yes. -- - - - ------- -- -- - -- -- -- ------ -- -- ~ - ---- - - - ~ 11 Permit can be issued without conservation order______________________--.-_ Yes_ --.--_______-.-______--__-_____---______-_----______-_---_----__--_-_ Appr Date '1 12 Permit_can be issued without administrative-approval _ _ - Yes - - - - RPC 41412005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in_comments).(FQr_ NA- - - _ _ - . _ _ _ _ _ - - _ _ . - - _ _ - - - - - - - - - - - - - - - - - - - - - 15 All wells within 114_mile area of review identified (For service well only) - - - - - - - - - - - - - - - NA_ _ _ _ _ _ _ _ _ _ _ - . - _ - - _ _ _ _ _ - - - ------------ 16 Pre-produced injector duration_of pr_e production less than 3 months_(For_service well only) NA_ _ - _ - - - - - - - i 17 ACMP_FindingofConsistency-hasbee_nissued_forthisproject___- ---.__-__---.. NA__ ___________________________________________ ________________________ _____ Engineering 1, 18 Conduckorstring_provided__ ______________________________________ NA__ ____,--_.___ 19 Surface casingp_rotects aII known USDWs - - - NA - - - - - 20 CMT-vol. adequate_to circulate_o_n conductor & surf-csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ - _ _ - - ~ 21 CMT-voladeguate_totie-in long stringfosu_rfcsg____________ _______________ NA__ ___- ______ - - ! 22 CMT,will cover all know_n_productive honzgns_ _ - - - _ _ _ , Yes _ - 23 Casing designs adequatefo[C,TB&-permafrost---------------------- Yes- ------.-----------------------------------------------.-------- --_-- 24 Adequate tankage.or reserve pit - - Yes CTDU.. - - j 25 If a re-drill, has a 1.0-403 for abandonment been approved _ Yes - , - 26 Adequate wellbore separationproposed.. _ _ _ _ _ _ _ . _ _ _ - _ - . - - Yes _ _ _ _ _ _ _ _ . - 1 27 If_diverter required, does it meet regulations. - _ _ - - _ _ NA_ - _ _ _ Sidetrack. - _ _ , - _ _ _ _ _ . ------------ Appr Date 28 Drillingfluid_programschematic&equiplistadequate_________________________ Yes_ --___MaxMW-9,6ppg._____--_-_____,-_____-________-----_---_--___-:-_-- WGA 41512005 29 BOPEs, do they meet regu_lotion - Yes - - - - - - 30 BOPS-press ratingapp[op[iate;testto_(putpsigincomments)-__________________ Yes_ --___Testto 3500gsi•_MSP3$70psi._-____---_-___,-__-_____-__-_____---____-.--_ 31 Choke_manifoldcomplieswlAPl_RP-53 (May84)_____--_.--___ _-_-__ Yes_ _-___-_-----_____ - - 32 Work willoccur-withoutoperationshutdown_____________________-__ Yes_ -____ -_----____-_- - - - 33 Is presence_of H2S gas probable- - - - Yes 145_ppm, - - - - - - - 34 Mechanical condition of Wells withinAORyerified(Forservicewell4nlya_____-.-____. NA__ __ ________________,________-_---__- _-:_--__-----_-_--___---__-_--_-- Geology 1 35 Permitcanbeissuedwlo_hydrogensulfidemeasures__ _-._______________ tJo__ --___ _-__-______-__ _-__--_--_---__--_-_---__----_ --------------------- ~36 Data_presented on-potential overpressure zones _ - - - - NA_ - - - - Appr Date 37 Seismic analysis ofshallow gaszones_ - _ - - _ - _ - NA_ _ - _ - _ - - - RPC 41412005 38 Seabed condition survey-(ifoff-shore) - _ .. - - NA_ - _ - - - 39 _Contactnamelphone_forweeklyprogress_reports[e~loratoryonly]_ _______________ NA__ ___-----_______-__-__-__.______--__.-_ ___----_____--_----_----- ---___ Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date ~~~~;~ ¢-S-OS • • • • Well Nisiory File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this calegory of information. • • **** REEL HEADER *~** MWD 09/07/07 BHI O1 LIS Customer Format Tape **** TAPE HEADER *~~* 06/03/15 1087593 O1 3.125" CTK ~~'~ LIS COMMENT RECORD ~** tapescan.txt ~~ji'~ x ,'~y~~~''~"` w,lj~. .r ~x~ a.~`ac'~. ~ .::xt~ !!!!!!!!! !!!!!!!!!! Remark File Version 1.000 !!!!!!!!! !!!!!!!!!! Extract File: ldwg.las ~version znformation VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame ~well Information Block #MNEM.UNI T Data Type Information #-------- - ------------- ------------------------------- STRT.FT 13174.0000: starting DePth STOP.FT 13908.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: P2-37APB1 FLD . FIELD: Point McIntyre LOC . LOCATION: 70 deg 24' 1.993"N 148 deg 31' 19.199"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3.125~~ CTK DATE. LOG DATE: 15 Mar 2006 API . API NUMBER: 500292257670 ~Paramete r znformation Block #MNEM.UNI T Valu e Description #-------- - -------------- ----------- ------------------------------- SECT, 14 . Section TOWN.N T12N . Township RANG. R14E . Rdng2 PDAT. MSL . Permanent Datum EPD .F 0 . Elevation Of Perm. Datum LMF . DF . Log Measured from FAPD.F 52.1 . Feet Above Perm. Datum DMF . DF . Drilling Measured From EKB .F 0 . ElevdtiOn Of Kelly BUShing EDF .F 52.1 . Elevation of Derrick Floor EGL .F 0 . Elevation of Ground Level CASE.F N/A . Casing Depth OS1 . DIRECTIONAL . Other Services Line 1 ~ttemarks (1) All depths are Measure d ~epths (M~) at the bit unless otherwise noted. (2) All Gamma Ray and Resi stivity is memory data. (3) Bak er Hughes INTEQ uti lized CoilTrak downhole tools and the Advantage surface system to log this well. Page 1 ~ C?5 ~ 1~5~~ ~ • • tapescan.txt (4) Tools ran in this string include BCPM (Bi-directional Communications and Power Module), DPS (Drilling Performance Sub, downhole wo~ and Pressure), ~GS (~irectional and Gamma Sub), HOT (Hydraulic orienting Sub with Near Bit Inclination), and uSMPR (Ultra Slim Multiple Propagation Resistivity) (5) Data presented here is final and has been depth adjusted to PDC (Primary ~epth Control) lo~ provided by schlumberger GR CCNL dated 17 Mar 2006 per ~ave soyer with BP Exploration (alaska), znc. <6) The sidetrack was drilled from P2-37 through a milled window in the 7 5/8 inch casing. Top of window 13481 feet MD (8936 feet Tvoss) Bottom of window 13488 feet MD (8940 feet Tv~ss) (7) Tied into the P2-37A at 13200 feet MD <8768 feet Tv~ss) (8) The interval from 13876 feet to 13906 feet MD (8934 feet to 8935 feet Tv~ss) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP~4VG -> Rdt2 Of P2112trdti011, feet/hour RACLX -> Resistivity (AT)(LS)400kHZ-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHZ-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHZ-Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHZ-Compensated Borehole Corrected (OHMM) TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 13180.2, 13178.4, ! -1.82129 13181.5, 13179.9, ! -1.63965 13184.2, 13183, ! -1.27539 13188.4, 13185.9, ! -2.5498 13190.4, 13187.7, ! -2.73242 13195.4, 13192.4, ! -2.91504 13196.6, 13194.3, ! -2.36719 13198.8, 13196.6, ! -2.18652 13203.5, 13201.5, ! -2.00391 13205.4, 13202.8, ! -2.5498 13207.9, 13205.7, ! -2.18652 13210.1, 13207.6, ! -2.5498 13214.5, 13211.7, ! -2.73242 13217.6, 13215.2, ! -2.36816 13221.8, 13218.7, ! -3.09668 13223.6, 13220.5, ! -3.09668 13226.5, 13223, ! -3.46094 13227.4, 13224.3, ! -3.09668 13229, 13226, ! -3.09668 13238, 13234.7, ! -3.27832 13240.2, 13238.2, ! -2.00391 13247.6, 13244.7, ! -2.91406 13251, 13248.5, ! -2.5498 13253.4, 13251, ! -2.36816 13257.4, 13255.2, ! -2.18652 13260.1, 13259.2, ! -0.910156 13264.9, 13264.3, ! -0.546875 13267.2, 13266.3, ! -0.911133 13269.6, 13268.9, ! -0.728516 13273.4, 13274, ! 0.546875 13281.1, 13282.7, ! 1.63965 13282.9, 13284.7, ! 1.82227 13285.4, 13287, ! 1.63867 13288.6, 13289.5, ! 0.911133 13291.4, 13293.2, ! 1.82129 13294.1, 13296.1, ! 2.00293 13296.5, 13297.9, ! 1.45801 13300.5, 13301.2, ! 0.728516 13303.6, 13303.7, ! 0.181641 13309.9, 13308.8, ! -1.09277 13312.3, 13311.6, ! -0.728516 13316.9, 13316.3, ! -0.546875 13318.3, 13318.3, ! 0 13320.1, 13319.8, ! -0.364258 13325.6, 13325.1, ! -0.546875 Page 2 C~ 13357.4, 13353.9, 13359.7, 13356.8, 13361.7, 13359, 13367.9, 13365, 13373.9, 13371.2, 13375.8, 13373.2, 13378.1, 13375.2, 13382.9, 13379.6, 13386.1, 13383, 13387.6, 13385.4, 13390.9, 13389.2, 13403.1, 13400.2, 13405.1, 13403.3, 13407.8, 13406.9, 13469.9, 13465.9, 13470.7, 13467.4, 13472.5, 13468.3, 13479.4, 13475, 13483, 13478.8, 13484.1, 13479.8, 13485.4, 13481.2, 13486.5, 13482.5, 13490.1, 13485.8, 13492, 13488, ! 13495.2, 13491.2, 13498, 13493.8, 13501.1, 13497.2, 13505.1, 13501.6, 13516.9, 13512.9, 13542.1, 13543.6, 13559.6, 13559, 13584.8, 13584.4, 13631.3, 13631.9, 13675.8, 13672.6, 13696.2, 13696.5, 13700, 13701.8, 13754.9, 13755.5, 13797, 13799.2, 13801, 13801.4, 13856.8, 13859.5, 13859.2, 13861, 13861.2, 13863.2, EOZ END ! BASE CURVE: GROH, Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER ~`'~** MWD .001 1024 tapescan.txt ! -3.45996 ! -2.91406 -2.73242 -2.91504 ! -2.73242 ! -2.5498 ! -2.91504 ! -3.27832 -3.09668 ! -2.18555 ! -1.63965 ! -2.91406 ! -1.82227 ! -0.911133 ! -4.00684 ! -3.27832 ! -4.18945 -4.37109 -4.18945 ! -4.37207 ! -4.18945 ! -4.00781 ! -4.37109 -4.00684 ! -4.00781 -4.18945 ! -3.8252 ! -3.46094 ! -4.00684 ! 1.45703 -0.546875 ! -0.364258 ! 0.546875 ! -3.27832 ! 0.364258 1.82227 ! 0.546875 2.18652 0.364258 ! 2.73242 1.82129 ! 2.00293 OFFSET CURVE: GRAX 158 records... 10 bytes 132 bytes **~ LIS COMMENT RECORD *** • !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth shifted to a Primary ~epth Control (P~C) log provided by Schlumberger GR CCNL dated 17 Mar 2006 per ~ave Boyer with BP Exploration (Alaska), ~nc. * FORMAT RECORD (TYPE# 64) Page 3 C~ tapescan.txt Data record type is: 0 ~atum Frame size is: 28 bytes Log~in9 direction is down (value= 255) Optical Lo~ Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] tvumber of frames per record is: 36 one depth per frame (value= 0) oatum Specification Block sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code samples units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM 1 Size ~ength 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 41 Tape File Start Depth = 13174.000000 Tape File End Depth = 13908.000000 Tape File ~evel Spacing = 0.500000 Tape File oepth Units = feet **~* FILE TRAILER **** Tape Subfile: 2 54 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes ~~~* FILE HEADER **** MWD .001 1024 *~`* LIS COMMENT RECORD '~'`* !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes ~og~ing direction is down (value= 255) Optical Lo~ Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 Page 4 C~ • tapescan.txt One depth per frame (valu e= 0) Datum Specification Block Sub-ty pe is: 1 FRAME SPACE = 0.250 '~ F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code samples units size ~ength 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4' 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total ~ata Records: 82 Tape File start ~epth = 13175.750000 Tape File End Depth = 13905.750000 Tape File ~evel spacing = 0.250000 Tape File Depth Units = feet *~~* FILE TRAILER ~`*** Tape Subfile: 3 95 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes *'~** TAPE TRAILER '`*~* MWD 06/03/15 1087593 Ol **** REEL TRAILER **'~* MWD 09/07/07 BHI O1 Tape Subfile: 4 Minimum record length Maximum record length 0 2 records... 132 bytes 132 bytes Page 5 • ~ C~ tapescan.txt rape subfile 1 is type: ~zs 0 Tape Subfile 2 is type: ~zs DEPTH GR ROP RAD RAS RPD RPS 13174.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13174.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13200.0000 121.2162 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13300.0000 558.8304 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13400.0000 81.4697 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13500.0000 255.8118 24759.8047 3.3963 2.6358 2.2898 1.6424 13600.0000 66.0230 66.2426 15.0294 18.2268 16.8334 15.8214 13700.0000 50.8414 51.6581 28.2263 40.8675 35.9978 33.0080 13800.0000 65.5724 31.5248 15.4931 22.6895 25.2171 27.4636 13900.0000 -999.2500 38.3000 -999.2500 -999.2500 -999.2500 -999.2500 13908.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 Tape File Start ~epth = 13174.000000 Tape File End Depth = 13908.000000 Tape File ~evel Spacing = 0.500000 Tape File Depth Units = feet 0 Tape Subfile 3 is type: ~IS DEPTH GR ROP RAD RAS RPD RPS 13175.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13176.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13200.0000 128.9000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13300.0000 783.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 13400.0000 80.7000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13500.0000 349.0000 29611.8008 2.4740 2.7140 2.9620 2.4610 13600.0000 65.1000 66.2000 15.0310 18.2360 Page 6 ~ tapescan.txt 16.8070 15.7650 13700.0000 48.4000 52.0000 28.2120 34.8750 32.0080 13800.0000 80.7000 34.5000 15.1640 25.2760 28.1990 13900.0000 -999.2500 34.4000 -999.2500 -999.2500 -999.2500 13905.7500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File start Depth = 13175.750000 Tape File End ~epth = 13905.750000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet 0 Tape Subfile 4 is type: ~IS -999.2500 ~~ 40.4440 22.8270 -999.2500 -999.2500 Page 7 • • tapescan.txt *'~*~ REEL HEADER '~*** MWD 09/06/26 BHI O1 LIS Customer Format Tape '~'~""~` TAPE HEADER 't""" i. a~-.g m~-«- ~ r +ry ?~ MWD i~'cti%r'~~,~i~i.g3~.~ ._1tJi. • .~. ~L~~~ 06/03/15 1087593 O1 3.125" CTK *** LIS COMMENT RECORD ~** !!!!!!!!! !!!!!!!!!! Remark File Version 1.000 !!!!!!!!! !!!!!!!!!! Extract File: ldwg.las ~version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame ~well ~nf ormation Block #MNEM.UNI T Data Type Information #-------- - ------------- ------------------------------- STRT.FT 13370.5000: Starting Depth STOP.FT 14449.5000: Ending Depth STEP.FT 0.5000: Level Spacing NU~~. -999.2500: ,4bsent value COMP. COMPANY: BP ExplOrdtiOn (A1dSkd), InC. WELL. WELL: P2-37A FLD . FIELD: Point McIntyre LOC . LOCATION: 70 deg 24' 1.993" N 148 deg 31' 19.199" w CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3.125~~ MPCTK DATE. LOG DATE: 15 Mar 2006 API . API ivuMBER: 500292257601 ~Paramete r Information Block #MNEM.UNI T Value Description #-------- - --------------- ---------- ------------------------------- SECT. 14 . Section TOWN.N 12N . Township RANG. 14E . Rd11ge PDAT. MSL . Permanent Datum EPD .F 0 . Elevation Of Perm. Datum LMF . DF . Log Measured from FAPD.F 52.1 . Feet Above Perm. Datum DMF . DF . Drilling Measured From EKB .F 0 . Elevation of Kelly Bushing EDF .F 52.1 . Elevation of Derrick Floor EGL .F 0 . Elevation of Ground Level CASE.F N/A . Casing Depth OS1 . DIRECTIONAL . Other Services Line 1 ~Remarks (1) All depths are Measured Depths (MD) at the Bit unless otherwise noted. (2) All Gamma Ray and Resis tivity are Memory data. (3) Baker Hughes INTEQ util ized CoilTrak downhole tools and the Advantage surface system to log this w ell. Page 1 ~OS -~S~" 1~2~55 • • tapescan.txt <4) Tools ran in this string include BCPM (Bi-directional Communications and Power Module), DPS (~rilling Performance Sub, downhole wo6 and Pressure), DG5 (~irectional and Gamma Sub), HOT <Hydraulic orienting Sub with Near Bit ~nclination), and USMPR (Ultra Slim Multiple Propagation Resistivity) (5) ~ata presented here is final and has been depth adjusted to P~C (Primary Depth Control) lo~ provided by Schlumberger GR CCNL dated 17 Mar 2006 per ~ave Boyer with BP Exploration (Alaska), znc. <6) The sidetrack was drilled from P2-37 through a milled window in 7 5/8 inch casing. Top of window 13481 feet MD (8936 feet Tv~ss) Bottom of window 13488 feet MD (8940 feet Tv~ss) (7) Tied to P2-37A at 13200 feet MD (8768 feet TVDSS) (8) This wellbore P2-37a was kicked off the wellbore P2-37APg1 at 13705 feet MD (8962.38 feet Tv~ss). (9) The interval from 14420 feet to 14450 feet MD (9067 feet to 9077 feet Tv~55) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAM -> Gamma Rdy [MWD] (MWD-API U11it5) ROP~4VG -> Rdte Of Pen etration, feet/hour RACLM -> Resistivity (AT)(LS)400kHZ-Compensated Borehole Corrected (OHMM) RACHM -> Resistivity (AT)(LS)2MHZ-~ompensated Borehole Corrected (OHMM) RPCLM -> R25i5tivity (PD)(LS)400kHz-COmpensated BOI'ehOle corrected (OHMM) RPCHM -> Resistivity (PD)(LS)2MHZ-Compensated Borehole Corrected (OHMM) TVD55 -> True Vel"tiC dl D2pth (SUb52d) CURVE SHIF T DATA BASELINE, MEASURED, DISPLACEMENT 13373.1, 13373.3, ! 0.181641 13375.5, 13375, ! -0.545898 13379.9, 13379.5, ! -0.364258 13383.5, 13385.3, ! 1.82227 13386.8, 13388.1, ! 1.27441 13467.9, 13463.3, ! -4.55371 13470.6, 13469, ! -1.6582 13477.5, 13475.4, ! -2.18555 13481.6, 13479.7, ! -1.82129 13482.9, 13481, ! -1.86523 13484.1, 13482.6, ! -1.45703 13487.9, 13485.6, ! -2.36816 13491.8, 13489.4, ! -2.36816 13493.6, 13490.7, ! -2.91406 13496.5, 13493.9, ! -2.5498 13497.6, 13495.9, ! -1.63965 13499, 1 3497.4, ! -1.63965 13502.7, 13501, ! -1.63965 13512.4, 13509, ! -3.46094 13517.9, 13515.9, ! -2.00391 13520.2, 13517.7, ! -2.5498 13526.7, 13524.7, ! -2.00391 13551.2, 13546.6, ! -4.55371 13554.1, 13549.3, ! -4.73535 13559, 1 3557.9, ! -1.09277 13563.2, 13561.4, ! -1.82129 13570.4, 13568.2, ! -2.18555 13584.2, 13582.2, ! -2.00391 13588.8, 13586.2, ! -2.5498 13591.5, 13589.5, ! -2.00391 13595.7, 13592.9, ! -2.73242 13599.9, 13596.2, ! -3.64355 13617.1, 13613.1, ! -4.00781 13625, 1 3625, ! 0 13629, 1 3628.2, ! -0.728516 13634.6, 13632.4, ! -2.18555 13645.5, 13642.6, ! -2.91504 13660.7, 13656.7, ! -4.00684 13668.5, 13664.5, ! -4.00781 13677.8, 13674.3, ! -3.46094 13689.1, 13689.6, ! 0.546875 13697.8, 13696.7, ! -1.09277 13701, 1 3700.1, ! -0.911133 Page 2 • 13708.1, 13707.6, 13724.7, 13719, 13731, 13725.4, 13739.6, 13734.9, 13744.9, 13741.1, 13751.8, 13749.8, 13763.7, 13762.3, 13769.2, 13767.7, 13773.7, 13772.8, 13782.7, 13783.2, 13791.4, 13791.4, 13796.1, 13795.8, 13801.4, 13801.2, 13817.9, 13815, 13826.3, 13823.7, 13838.1, 13835.6, 13852, 13849.2, 13886.5, 13885.2, 13891.2, 13889.9, 13910.7, 13907.6, 13917.8, 13914.9, 13923.4, 13920.3, 13939.8, 13936.7, 13947.8, 13944.9, 13956.9, 13953.1, 13972.3, 13968.3, 13978.5, 13977.7, 13987.8, 13985.9, 13992.3, 13991, 13996.1, 13996.1, 14018.5, 14017.1, 14031.4, 14030.3, 14042.7, 14041.2, 14046.3, 14045, 14048.3, 14046.3, 14052.3, 14049.4, 14058.9, 14056.3, 14065.7, 14064, 14073.3, 14074.2, 14091, 14090.8, 14103.7, 14100.5, 14110.7, 14107.8, 14117.6, 14117.8, 14132.2, 14133.6, 14158.5, 14158.3, 14175.6, 14175.1, 14180.2, 14179.6, 14193.1, 14189.8, 14197.2, 14193.5, 14199.7, 14197.2, 14202.1, 14199.9, 14204.8, 14203.9, 14210.7, 14209, 14215.9, 14213.4, 14219.4, 14217.2, 14223.8, 14221.4, 14233, 14229, 14242.7, 14242.3, 14258.7, 14257.8, 14269.6, 14268.7, 14279.3, 14277.8, 14290.5, 14288.5, 14300.8, 14298.1, 14311.4, 14311, 14315.1, 14313.8, 14326.2, 14323.3, EOZ tapescan.txt -0.545898 -5.64648 -5.64648 -4.73535 -3.82422 -2.00293 -1.45703 -1.45703 -0.911133 0.546875 ! -0.364258 ! -0.182617 ! -2.91406 ! -2.55078 ! -2.55078 ! -2.73242 ! -1.27441 ! -1.27539 ! -3.0957 ! -2.91504 ! -3.0957 ! -3.09668 ! -2.91406 ! -3.8252 ! -4.00781 ! -0.728516 ! -1.82129 ! -1.27539 i p ! -1.45703 ! -1.09277 ! -1.45703 ! -1.27441 ! -2.00391 ! -2.91504 ! -2.5498 ! -1.63965 ! 0.910156 ! -0.181641 ! -3.27832 ! -2.91406 ! 0.182617 ! 1.45703 ! -0.181641 ! -0.546875 ! -0.546875 ! -3.27832 ! -3.64355 ! -2.5498 ! -2.18555 ! -0.911133 ! -1.63867 ! -2.5498 ! -2.18555 ! -2.36816 -4.00684 ! -0.364258 ! -0.911133 ! -0.911133 ! -1.45801 ! -2.00391 ! -2.73242 ! -0.364258 ! -1.27441 ! -2.91406 END ! BASE CURVE: GROH, OFFSET CURVE: GRAX • Page 3 . Tape subfile: 1 Minimum record length: Maximum record length: *'~*'~ FILE HEADER **** MWD .001 1024 tapescan.txt 181 records... 10 bytes 132 bytes \J '~** LIS COMMENT RECORD ~~* !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth shifted to a Primary ~epth Control (P~c) log provided by Schlumberger GR CCNL dated 17 Mar 2006 per ~ave Boyer with BP Exploration (Alaska), znc. '` FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes ~og~ing direction is down (value= 255) Optical Lo~ Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame <value= 0) ~atum Specification Block 5ub-type is: 1 FRAME SPACE = 0.500 '` F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size ~ength 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total ~ata Records: 60 Tape File Start Depth = 13370.500000 Tape File End Depth = 14449.500000 Tape File ~evel Spacing = 0.500000 Tape File ~epth units = feet ~`**~ FILE TRAILER ~'*~* Tape subfile: 2 73 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes Page 4 ~ • tapescan.txt A**'~ FILE HEADER **** MWD .001 1024 *'~* LIS COMMENT RECORD '~*'~ Iilfllllllllillllll Remark File Vef5i011 1.000 This file contains the raw-unedited field data. * FORMAT RECORD (TYPE# 64) ~ata record type is: 0 Datum Frame Size is: 28 bytes ~og~ing direction is down (value= 255) Optical Lo~ Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) ~atum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 61 Tape File Start ~epth = 13370.500000 Tape File End Depth = 14452.500000 Tape File ~evel Spacing = 0.500000 Tape File Depth units = feet ~`*** FILE TRAILER ~~~~ Tape Subfile: 3 74 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes ''`~"~* TAPE TRAILER ~`"`* MWD 06/03/15 1087593 O1 Page 5 . '~~*'~ REEL TRAILER *~`*'~ MWD 09/06/26 BHI O1 tapescan.txt Tape Subfile: 4 Minimum record length: Maximum record length: ~ 2 records... 132 bytes 132 bytes 0 Tape Subfile 1 is type: LIS 0 Tape Subfile 2 is type: ~is DEPTH GR RPD RPS 13370.5000 -999.2500 -999.2500 -999.2500 13371.0000 -999.2500 -999.2500 -999.2500 13400.0000 98.4732 -999.2500 -999.2500 13500.0000 250.0134 2.6403 2.0662 13600.0000 70.9577 15.6880 13.7583 13700.0000 64.1560 19.1521 14.9347 13800.0000 53.8555 46.0171 42.2828 13900.0000 48.6131 11.8952 10.0662 14000.0000 58.3202 16.1734 15.8098 14100.0000 68.5087 16.4597 14.8252 14200.0000 60.9341 6.8950 6.8393 14300.0000 40.7505 2.5699 2.4626 14400.0000 102.8605 6.7458 6.3752 14449.5000 -999.2500 ROP -999.2500 -999.2500 -999.2500 27385.9297 37.8408 51.4687 32.2334 58.9726 RAD -999.2500 -999.2500 -999.2500 3.3507 14.5022 24.1705 28.4128 12.8841 73.8748 13.7832 58.4089 15.6686 787.3148 6.6989 49.3645 2.5644 67.3199 6.6770 61.3195 -999.2500 Page 6 LJ RAS -999.2500 -999.2500 -999.2500 Z.8795 16.5886 32.1418 59.9972 13.0087 16.3465 18.0261 6.7033 2.4543 7.1580 -999.2500 . . ~ tapescan.txt -999.2500 -999.2500 Tape File Start Depth = 13370.500000 Tape File End Depth = 14449.500000 Tape File ~evel spacing = 0.500000 Tape File Depth Units = feet 0 Tape Subfile 3 is type: ~zs DEPTH GR ROP RPD RPS 13370.5000 -999.2500 -999.2500 -999.2500 -999.2500 13371.0000 -999.2500 -999.2500 -999.2500 -999.2500 13400.0000 98.4000 -999.2500 -999.2500 -999.2500 13500.0000 289.0000 29611.8008 3.0340 2.4140 13600.0000 64.8000 66.2000 14.8220 13.0960 13700.0000 51.5000 52.0000 21.1320 17.1480 13800.0000 53.9000 32.1000 46.3150 42.6230 13900.0000 54.7000 60.8000 11.6690 9.7860 14000.0000 57.8000 77.1000 16.0850 15.8270 14100.0000 75.6000 53.5000 16.5060 15.4040 14200.0000 67.3000 74.3000 7.2630 6.7060 14300.0000 41.2000 82.2000 2.4300 2.3980 14400.0000 93.3000 63.6000 6.5390 5.9680 14452.5000 -999.2500 61.2000 -999.2500 -999.2500 Tape File 5tart ~epth = 13370.500000 Tape File End Depth = 14452.500000 Tape File ~evel spacing = 0.500000 Tape File Depth Units = feet 0 Tape subfile 4 is type: ~is RAD -999.2500 -999.2500 -999.2500 2.8730 14.2860 24.1270 28.4030 13.2710 13.7270 15.6550 7.3280 2.5090 6.7290 -999.2500 ~ RAS -999.2500 -999.2500 -999.2500 2.7210 16.3770 30.3500 60.1110 14.2420 16.3840 18.2310 7.3370 2.4190 6.9080 -999.2500 Page 7 **** REEL HEADER **** MWD 07/07/27 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 06j03/15 1087593 01 3.125" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 13480.0000: Starting Depth STOP.FT 14453.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: P2-37A FLD . FIELD: Point McIntyre LOC LOCATION: 70 deg 24' 1.993" N 148 deg 31' 19.199" W CNTY. COUNTY: North Slope STAT. ~ STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3.125" MPCTK DATE. LOG DATE: 15-Mar-06 API API NUMBER: 50029225760100 Parameter Information Block #MNEM.UNIT Value Description #--------- -- -------- ---------- SECT. 14 Section TOWN.N 12N Township RANG. 14E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 52.1 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 52.1 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks ~dS- p $'~. ~ tS3o~ (1) All depths are Measured Depths (MD) at the Bit unless otherwise noted. (2) All Gamma Ray and Resistivity are Memory data. (3) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well. (4) Tools ran in this string include BCPM (Bi-directional Communications and Power Module), DPS (Drilling Performance Sub, downhole WOB and Pressure), DGS (Directional and Gamma Sub), HOT (Hydraulic Orienting Sub with Near Bit Inclination), and USMPR (Ultra Slim Multiple Propagation Resistivity) (5) Data presented here is final and has not been depth adjusted to PDC (Primary Depth Control) log. The INTEQ MwD Gamma Ray is the PDC for this wellbore. (6) The sidetrack was drilled from P2-37 through a milled window in 7 5/8" casing. Top of window 13481 ft.MD (8936 ft.SSTVD) Bottom of window 13488 ft.MD (8940 ft.SSTVD) (7) The interval from 14420 to 14450 ft.MD (9067 to 9077 ft.SSTVD) was not logged due to sensor bit offset at TD. (8) Tied to P2-37A at 13200 ft.MD (8768 ft.SSTVD} (9) This wellbore P2-37A was kicked off the wellbore P2-37APB1 at 13705 ft.MD (8962.38 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 62 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN P2-37A 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN P2-37A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPS 0.0 RAD RAD RACLM 0.0 RAS RAS RACHM 0.0 RPD RPD RPCLM 0.0 RPS RPS RPCHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 55 Tape File Start Depth = 13480.000000 Tape File End Depth = 14452.500000 Tape File Level Spacing = 0.500000. Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 68 records... Minimum record length: 54 byte s Maximum record length: 4124 bytes **** FILE HEADER **** MGdD . 0 0 2 1024 • M *** INFORMATION TABLE: CONS MNEM VALU WDFN P2-37A.xtf LCC 150 CN BP Exploration (Alaska) WN P2-37A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0.0 ROPS ROPS ROPS 0.0 RACL. RACL RACLM 0.0 RACH RACH RACHM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F J Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 AAPI 2 ROPS MVTD 68 1 F/HR 3 RACL MWD 68 1 OHMM 4 RACH MWD 68 1 OHMM 5 RPCL MWD 68 1 OHMM 6 RPCH MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 109 Tape File Start Depth = 13480.000000 Tape File End Depth = 14452.500000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 122 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 06/03/15 1087593 01 **** REEL TRAILER **** MWD 07/07/27 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR ROP RPD RPS 13480.0000 789.4000 -999.2500 19635.0352 0.5580 13480.5000 859.1000 -999.2500 0.0820 0.1390 13500.0000 349.0000 29611.8008 2.9620 2.4610 13600.0000 65.1000 66.2000 16.8070 15.7650 13700.0000 48.4000 52.0000 34.8750 32.0080 13800.0000 53.9000 32.1000 46.3150 42.6230 13900.0000 54.7000 60.8000 11.6690 9.7860 14000.0000 57.8000 77.1000 16.0850 15.8270 14100.0000 75.6000 53.5000 16.5060 15.4040 14200.0000 67.3000 74.3000 7.2630 6.7060 14300.0000 41.2000 82.2000 2.4300 2.3980 14400.0000 93.3000 63.6000 6.5390 5.9680 14452.5000 -999.2500 61.2000 -999.2500 -999.2500 Tape File Start Depth = 13480.000000 Tape File End Depth = 14452.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet RAD RAS 0.7020 0.5160 2.2370 0.3280 2.4740 2.7140 15.0310 18.2360 28.2120 40.4440 28.4030 60.1110 13.2710 14.2420 13.7270 16.3840 15.6550 18.2310 7.3280 7.3370 2.5090 2.4190 6.7290 6.9080 -999.2500 -999.2500 Tape Subfile 3 is type: LIS DEPTH GRAX ROPS RPCL RPCH 13480.0000 733.9000 -999.2500 0.0520 0.0770 13480.2500 723.9000 -999.2500 0.0545 0.0795 13500.0000 289.0000 29611.8008 3.0340 2.4140 13600.0000 64.8000 66.2000 14.8220 13.0960 13700.0000 51.5000 52.0000 21.1320 17.1480 13800.0000 53.9000 32.1000 46.3150 42.6230 13900.0000 54.7000 60.8000 11.6690 9.7860 14000.0000 57.8000 77.1000 16.0850 15.8270 14100.0000 75.6000 53.5000 16.5060 15.4040 14200.0000 67.3000 74.3000 7.2630 6.7060 14300.0000 41.2000 82.2000 2.4300 2.3980 14400.0000 93.3000 63.6000 6.5390 5.9680 14452.5000 -999.2500 61.2000 -999.2500 -999.2500 Tape File Start Depth = 13480.000000 Tape File End Depth = 14452.500000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet RACL RACH 0.1150 0.0780 0.1365 0.0885 2.8730 2.7210 14.2860 16.3770 24.1270 30.3500 28.4030 60.1110 13.2710 14.2420 13.7270 16.3840 15.6550 18.2310 7.3280 7.3370 2.5090 2.4190 6.7290 6.9080 -999.2500 -999.2500 Tape Subfile 4 is type: LIS **** REEL HEADER **** MWD 07/07/27 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 06/03/11 1087593 Ol 3.125" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!rr!!r!r Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 13480.0000: Starting Depth STOP.FT 13906.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: P2-37APB1 FLD FIELD: Point McIntyre LOC LOCATION: 70 deg 24' 1.993" N 148 deg 31' 19.199" W CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3.125" MPCTK DATE. LOG DATE: 11-Mar-06 API API NUMBER: 50029225767000 Parameter Information Block #MNEM.UNIT Value Description ----- ---- -- ------ -- --- - -- --- SECT. -- - 14 Section TOWN.N 12N Township RANG. 14E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 52.1 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 52.1 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks ~oS-o~~ - '~~S3a3 ' • (1) All depths are Measured Depths (MD) at the Bit unless otherwise noted. (2) All Gamma Ray and Resistivity are Memory data. (3) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well. (4) Tools ran in this string include BCPM (Bi-directional Communications and Power Module), DPS (Drilling Performance Sub, downhole WOB and Pressure), DGS (Directional and Gamma Sub), HOT (Hydraulic Orienting Sub with Near Bit Inclination), and USMPR (Ultra Slim Multiple Propagation Resistivity) (5) Data presented here is final and has not been depth adjusted to PDC (Primary Depth Control) log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (6) The sidetrack was drilled from P2-37 through a milled window in 7 5/8" casing. Top of window 13481 ft.MD (8936 ft.SSTVD) Bottom of window 13488 ft.MD (8940 ft.SSTVD) (7) The interval from 13866 to 13906 ft.MD (8934 to 8933 ft.SSTVD) was not logged due to sensor bit offset at TD. (8) Tied to P2-37A at 13200 ft.MD (8768 ft.SSTVD) (9) The wellbore P2-37A was kicked off this wellbore at 13705 ft.MD (8962.38 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 62 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN P2-37APB1 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN P2-37APB1 FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted • • *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPS 0.0 RAD RAD RACLM 0.0 RAS RAS RACHM 0.0 RPD RPD RPCLM 0.0 RP5 RPS RPCHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MwD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 oHMM 4 4 24 Total Data Records: 24 Tape File Start Depth = 13480.000000 Tape File End Depth = 13906.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 37 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 • • *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN P2-37APB1.xtf LCC 150 CN BP Exploration (Alaska) WN P2-37APB1 FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0.0 ROPS ROPS ROPS 0.0 RACL RACL RACLM 0.0 RACH RACH RACHM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 AAPI 2 ROPS MWD 68 1 F/HR 3 RACL MWD 68 1 OHMM 4 RACH MWD 68 1 OHMM 5 RPCL MWD 68 1 OHMM 6 RPCH MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 48 Tape File Start Depth = 13480.000000 Tape File End Depth = 13905.750000 • Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 61 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 06/03/11 1087593 01 **** REEL TRAILER **** MWD 07/07/27 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP RPD RPS 13480.0000 789.4000 -999.2500 19635.0352 0.5580 13480.5000 859.1000 -999.2500 0.0820 0.1390 13500.0000 349.0000 29611.8008 2.9620 2.4610 13600.0000 65.1000 66.2000 16.8070 15.7650 13700.0000 48.4000 52.0000 34.8750 32.0080 13800.0000 80.7000 34.5000 25.2760 28.1990 13900.0000 -999.2500 34.4000 -999.2500 -999.2500 13906.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 13480.000000 Tape File End Depth = 13906.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet RAD RAS 0.7020 0.5160 2.2370 0.3280 2.4740 2.7140 15.0310 18.2360 28.2120 40.4440 15.1640 22.8270 -999.2500 -999.2500 -999.2500 -999.2500 • Tape Subfile 3 is type: LIS DEPTH GRAX ROPS RPCL RPCH 13480.0000 789.4000 -999.2500 19635.0352 0.5580 13480.2500 849.6000 -999.2500 24867.6875 0.7000 13500.0000 349.0000 29611.8008 2.9620 2.4610 13600.0000 65.1000 66.2000 16.8070 15.7650 13700.0000 48.4000 52.0000 34.8750 32.0080 13800.0000 80.7000 34.5000 25.2760 28.1990 13900.0000 -999.2500 34.4000 -999.2500 -999.2500 13905.7500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 13480.000000 Tape File End Depth = 13905.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet RACL RACH 0.7020 0.5160 0.8350 0.4390 2.4740 2.7140 15.0310 18.2360 28.2120 40.4440 15.1640 22.8270 -999.2500 -999.2500 -999.2500 -999.2500 Tape Subfile 4 is type: LIS
