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206-022
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 P2-36A K-Valve Redesign Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 206-022 50-029-22801-01-00 16272 Conductor Surface Intermediate Liner Liner 9034 80 7170 14109 505 2045 16196 20" 9-5/8" 7" 4-1/2" 3-1/2" x 2-7/8" 9045 35 - 115 34 - 7204 33 - 14142 13993 - 14498 14187 - 16232 35 - 115 34 - 4968 33 - 8814 8727 - 9022 8840 - 9040 none 1500 3090 7020 7500 11160 none 3060 5750 8160 8430 10570 15050 - 16190 4-1/2" 12.6# 13Cr80 13Cr80 31 - 14000 9032 - 9045 Structural 4-1/2" Baker S-3 Perm 2227 / 2104 13944 8698 Torin Roschinger Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com 907.564.4061 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 , 0034624 220 334 199 337 673 1727 1867 2229 717 615 323-291 13b. Pools active after work:PT MCINTYRE OIL 4-1/2" K Valve 13944 / 8698 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:06 pm, Jun 19, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.06.19 13:59:28 -08'00' Torin Roschinger (4662) WCB 1-31-2024 DSR-6/21/23 ACTIVITYDATE SUMMARY 5/1/2023 ***WELL S/I ON ARRIVAL*** (sssv maintenance) RAN 3.85" G. RING TO 425' SLM (paraffin on tools) RAN 4-1/2" BRUSH & 3.25" G. RING TO CLEAN UP RESTRICTION AT 425' SLM & TAG PB VALVE AT 2,227' MD ***CONTINUE ON 5/2/23 WSR*** 5/1/2023 Assist SL. Movement to location. *** Job continued to 5-2-2023 *** 5/2/2023 ***CONTINUED FROM 5/1/23 WSR*** (sssv maintenance) B&F TBG w/ 4-1/2" BRUSH & 3.85" G. RING TO 2,227' MD w/ LRS ASSIST (42 bbls 180* crude pumped) PULLED 4-1/2" CA-WFD PB VALVE (sn: 16420-R) AT 2,227' MD DRIFT w/ 4-1/2" BRUSH & 3.80" G. RING TO RESTRICTION AT 11,550' SLM (unable to get further) DRIFT w/ 4-1/2" BRUSH & 3.65" G-RING TO DEPLOYMENT SLEEVE @ 14187' MD (no issues) SET 3-1/2" WHIDDON CATCHER (wcs-33) ON XN NIP @ 14205 MD PULLED INT-DGLV IN ST# 6 @ 13067' MD PULLED INT-DGLV IN ST# 5 AT 11679' MD ***CONTINUE ON 5/3/23 WSR*** 5/2/2023 *** Job continued from 5-1-2023 *** T/I/O = 1912/1491/41. Temp - SI. Assist SL. Pumped 2 bbls 60/40 and 42 bbls 190* Crude. SL in control of well upon departure. FWHP's = 1550/1628/42 5/3/2023 ***CONTINUED FROM 5/2/23 WSR*** (sssv maintenance) PULLED INT-DGLV IN ST# 4 (10796' md), INT-OGLV AT ST# 2 (8236' md) & INT- LGLV AT ST# 1 (5504' md) SET INT-LGLV IN ST# 1 (5504' md), ST# 2 (8236' md), ST# 4 (10796' md) & ST# 5 (11679' md) ***CONTINUE ON 5/4/23 WSR*** 5/4/2023 ***CONTINUED FROM 5/3/23 WSR*** (sssv maintenance) SET INT-OGLV IN STA #6 @ 13,067' MD PULLED WHIDDON FROM 14,190' SLM SET 4-1/2" CA-FLOW THRU SUB W/ SBHPS GAUGES ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 5/9/2023 T/I/O = 380/2240/70. Temp = 76°. Warm TIFL PASS (Under Eval). ALP = 2400 psi, online. OA cemented to surface. Pumped 3 gallons of hydraulic oil down each the control and balance lines. Pressure in C&B balance lines bled off within a minute after pumping hydraulic oil. IA FL @ 13067' (sta #6 SO, 229 bbls). SI wing and stacked well out to 2180/2240/70 in 2 hrs. Bled IAP to production from 2240 psi to 890 psi in 2 hrs. Monitored for 1 hr. IAP unchanged, IA FL unchanged (PASS). Released to Ops for POP. Final WHPs = 2180/890/70. SV, WV = C. SSV, MV = O. IA & OA = OTG. 18:00 5/14/2023 ***WELL FLOWING ON ARRIVAL*** PULLED 4-1/2'' CA-FLOW THRU SUB W/ SBHPS GAUGES FROM SSSV NIP @ 2227'MD ***WELL LEFT S/I ON DEPARTURE*** 5/19/2023 ***WELL FLOWING ON ARRIVAL*** R/U POLLARD #58 ***WSR CONT ON 5-20-23*** Daily Report of Well Operations PBU P2-36A ) PULLED 4-1/2" CA-WFD PB VALVE (sn: 16420-R) AT 2,227' MD Daily Report of Well Operations PBU P2-36A 5/20/2023 ***WSR CONT FROM 5-19-23*** RAN KJ, 3.805" G-RING, 3' x 1-2/3" STEM, 4-1/2" BLB, B.NOSE, BRUSH SSSV NIP @ 2216' SLM/ 2227' MD SET 4-1/2" DB-LOCK, DSSV (=66" lih) w/ UPPER & LOWER SET OF PACKING, SWELL FIT/ OS PACKING ATTEMPT TO GAIN CONTROL / BALANCE LINE INTEGRITY - FAIL PULLED DSSV @2,206' SLM (2,227' MD) SET 3.81" DB LOCK & DSSSV W/ 3 PKG STACKS (2 os pieces & o-rings on top & btm stacks) (=57" lih) ATTEMPT TO GAIN CONTROL / BALANCE LINE INTEGRITY - FAIL PULLED DSSV @2,206' SLM (2,227' MD) B&F w/ BLB, 3.79" G-RING TO 3.81" NIP @2,212' SLM (2,227' MD) (lrs pumped 50bbls *180 crude @ 1/2bpm) PURGE CONTROL & BAL LINES w/ 3-1/2 GAL HYDRO EACH (cont on next day) ***WSR CONT ON 5-21-23*** 5/20/2023 T/I/O=1639/2098/39 (SSSV MAINTENANCE) Assist Slickline with Brush and Flush the SSSV Nipple. Pumped 50 bbls 190* Crude doen TBG. ***Job Continued 5/21/23*** 5/21/2023 ***WSR CONT FROM 5-20-23*** SET 4-1/2" WRDP-2 ( 3 SETS OF FREUDENBERG PACKING / BAL-O - SER#. HABS-0441 / BAL-OPERATED)(LIH 104") ATTEMPTED TO GAIN CONTROL & BALANCE LINE INTEGRITY (fail) PUMPED 2.5 GAL HYDRO MIXED w/ GX SEALENT (5gal hydro mixed w/2 cans gx sealent) DOWN BAL LINE & CHASE w/ 1.5 GAL HYDRO LRS FP FLOW W/ 8bbls 60/40 CONTINUE ATTEMPTING TO GAIN CONTROL & BALANCE LINE INTEGRITY - FAIL PULL WRDP FROM 2,227' MD, PKG ON LOCK TORE UP, W/ STEEL NUBBIN IN IT RAN KJ, BLB, 3.79" GAUGE RING TO BRUSH NIP @2,227' MD SET 3.81" DB LOCK, K-VALVE (sn # K45C, 527 psi @60, =41" lih), & PERFORM PASSING DRAWDOWN TEST ***WELL S/I ON DEPARTURE*** 5/21/2023 ***Job Continued From 5/20/23*** (SSSV MAINTENCE) Assist Slickline FP FL 8 bbls 60/40 down FL Pressure up to 1000 psi turn well over to Slickline. 5/23/2023 State test witness waived by Sully Sullivan -P,P,P - (retest SSV and performance test new K-valve). Closed at 415 psi. Close to CL pressure. @ SET 3.81" DB LOCK, K-VALVE (sn # K45C, 527 psi @60, =41" lih), & PERFORM PASSING DRAWDOWN TEST State test witness waived by Sully Sullivan -P,P,P - (retest SSV and performance test yy ( new K-valve). Closed at 415 psi. Close to CL pressure 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU P2-36A K-Valve Redesign Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 206-022 50-029-22801-01-00 ADL 0034627 16272 Conductor Surface Intermediate Liner Liner 9034 80 7170 14109 505 2045 16196 20" 9-5/8" 7" 4-1/2" 3-1/2" x 2-7/8" 9045 35 - 115 34 - 7204 33 - 14142 13993 - 14498 14187 - 16232 3088 35 - 115 34 - 4968 33 - 8814 8727 - 9022 8840 - 9040 none 1500 3090 7020 7500 11160 none 3060 5750 8160 8430 10570 15050 - 16190 4-1/2" 12.6# 13Cr80 13Cr80 31 - 140009032 - 9045 Structural 4-1/2" Baker S-3 Perm 4-1/2" K Valve 13944 / 8698 2227 / 2104 Date: Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com 907.564.4061 PRUDHOE BAY Current Pools: PT MCINTYRE OIL Proposed Pools: PT MCINTYRE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 5-19-23 By Grace Christianson at 12:43 pm, May 16, 2023 323-291 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.05.16 11:32:14 -08'00' 10-404 MGR16MAY23 , ADL 0034624 SFD SFD 5/16/2023 DSR-5/16/23 3088 GCW 05/17/23JLC 5/17/2023 5/17/23Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.17 10:22:51 -08'00' RBDMS JSB 051823 P2-36A SSSV PTD:206022 Well Name:P2-36A API Number:50-029-22801-01 Current Status:Under Evaluation Rig:Slickline Estimated Start Date:5/19/2023 Permit to Drill Number:206022 Reg.Approval Req’std?10-403, 404 Regulatory Contact:Carrie Janowski First Call Engineer:Eric Dickerman 907-564-4061 307-250-4013 Second Call Engineer:Dave Bjork 907-564-4672 907-440-0331 Current Bottom Hole Pressure:3,968 psi @ 8,800’ TVD 8.7 PPGE | SBHPS 1/9/2020 Max. Anticipated Surface Pressure:3,088 psi (Based on 0.1 psi/ft. gas gradient to surface) Last Shut in WHP:1,912 psi (Taken on May 2, 2023) Min ID:2.377” ID @ 14,451’ – XO from 3-1/2” to 2-7/8” in production liner. Max Angle:98.82 Deg @ 14,751’ Brief Well Summary: P2-36A has utilized a subsurface controlled subsurface safety valve since June 2003. On 4/21/23 the subsurface controlled subsurface safety valve failed to hold pressure during routine safety valve system testing. The valve was removed, a new gas lift design was installed, then pressure/temperature gauges were hung in the safety valve landing nipple to collect data during flowing conditions, and the well was put online for 8 days. On 5/14/23 the pressure/temperature gauges were pulled and a new K valve design was determined. There are additional diagnostics that can be performed to determine if a surface controlled subsurface safety valve can be utilized. Objective: Set new subsurface safety valve. Procedure: 1. Troubleshoot the safety valve landing nipple in an attempt to complete the well with a surface controlled subsurface safety valve that will pass drawdown and SVS testing. 2. If Step 1 is unsuccessful (unable to set a surface controlled subsurface safety valve), set a K valve (subsurface controlled subsurface safety valve). a. See attached Initial K valve design. It may require multiple designs before the job is complete, and each design will be communicated with the AOGCC. 3. Return well to production. 4. Conduct SVS testing within 5 days after stabilized flow. Attachments: 1. Wellbore Schematic 2. Initial K Valve Design 3. Sundry Revision Change Form P2-36A SSSV PTD:206022 Wellbore Schematic: P2-36A SSSV PTD:206022 Initial K Valve Design: P2-36A SSSV PTD:206022 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 1 Regg, James B (OGC) From:Regg, James B (OGC) Sent:Monday, April 24, 2023 8:44 AM To:PB Wells Integrity Cc:Wallace, Chris D (OGC); Oliver Sternicki; Bo York Subject:RE: UNDER EVALUATION: Producer P2-36 (PTD #2060220) Sustained Casing Pressure Over NOL IA Correct well name is P2‐36A. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, April 23, 2023 6:17 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: UNDER EVALUATION: Producer P2‐36 (PTD #2060220) Sustained Casing Pressure Over NOL IA Mr. Regg, Producer P2‐36 (PTD #2060220) operations reported IA casing pressure at 2535 psi over NOL on 04/22/23. Subsequent TIFL failed which confirms failure of one or more well barriers. At this time, the well is classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Change out GLV 2. Downhole Diagnostics: TIFL 3. Well Integrity: Further action as needed Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, March 19, 2017 2:27 PM To: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com>; AK, GWO SUPT Well Integrity CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other:Set PB Valve m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-022 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22801-01-00 7. Property Designation(Lease Number): ADL 0034627 8. Well Name and Number: PRUDHOE BAY UN PTM P2-36A 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: RECEIVE ,. Total Depth: measured 16272 feet Plugs measured feet true vertical 9034 feet Junk measured feet A p R 2 6 2017 Effective Depth: measured 16196 feet Packer measured 13944 feet true vertical 9045 feet Packer true vertical 8697.76 feet OGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"133#H-40 35-115 35-115 3060 1500 Surface 7170 9-5/8"40#L-80 34-7204 34-4968 5750 3090 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 15050-15200 feet 15250-15500 feet 16100-16190 feet True vertical depth: 9032-9032 feet feet 9032-9038 feet 9054-9045 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 31 -14000 31 -8730 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"PB Valve 2227 203.82 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: scpaitiED MAA01 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 160 388 2493 1971 458 Subsequent to operation: 58 135 1863 1939 761 14.Attachments:(required per 20 AAC 25 070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil IZI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-120 Authorized Name: Sauve,Mark A Contact Name: Sauve,Mark A Authorized Title: /GPMA/Lisburnee Lead PE Contact Email: Mark.Sauve@bp.com Authorized Signature: / l-��U Date: 1— III Contact Phone: +1 907 564 4660 666 _/�— / r[� ` Form 10-404 Revised 04/2017 ,44$06(e rr� "//b /,'� R V , r I 7 Submit Original Only • • Alaska Oil and Gas Conservation Commission RECEIVED 333 West Seventh Avenue APR 2 6 2117 Anchorage, AK 99501-3572 AOGCC RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary April 25, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for P2-36A, PTD # 206-022 Set PB SSSV Valve to close out Sundry Application # 317-120. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • S C) Qoo00 0 d7 .- N O O — to O v O to to r (o to f- l- N- V y o O o 0 o O '- cotovCOM CO O N. C v Cr Cotof- c000 to to cO N M N O r CO CO r N O) M O) v CO O O) I� v CO CO 01 CO CO I- N- CO O tf) v M CO N 'Cr I- CY) M Cr) C'7 f- CO Co CO CO CO • M ' O (NI co) r O to � vrntno E a � c`o-•4- r r r r r co• � I 1 .�.� a CMh- viz tovco ,tin � ccc) cocococ, Ch v co Cr r r 13 er I— WCO o O L L OvO OtoOOO p ap J F L 2 c',7; = C Z a) � JCO4 •() 0 N C') r CO r CO C = C c) _O N N co N U r %- C‘ a O ~ N N r r r Oto 0) 4 O � C) N to v Co C CO r to N- O C0 0) C) C) to t[) N Cr) J `_ r w w Q Q C O0 N U w uJ w 00 l c1 az z � wwwwET) O z z O w Z Z J � • • Packers and SSV's Attachment PRUDHOE BAY UN PTM P2-36A SW Name Type MD TVD Depscription P2-36A SSSV 2227 2103.82 4-1/2" PB Valve P2-36A TBG PACKER 13943.78 8697.76 4-1/2" Baker S-3 Perm Packer P2-36A PACKER 13992.87 8726.38 4-1/2" Baker ZXP Packer R 2 • -J a 2 > m 3 m U 0 9 R D k I- < E k• � O < E as � < 0 j E \ z > 0.• 2 0 E mR / f 0 \ TD 2O f 00 Cl) = Lil- t <ii it c O W Ce CI 0 /J / Cl $ L m_ c C Ce c UJ Z 0. qa > 0 co � .7-1( 2a E / ƒ ED E =• ƒ ± 2 c ) R � 2 O z2 / � J $ g i L / ~ \ / _ 0 • TREE- 4-1/16"CNV 'WELLFEAD= 11'FRAC SAFETY NOTES:WELL REQUIRES A SSSV. WELL ACTUATOR= BAKE C P2-36A ANGLE>70°CO,14556'."'CHROME TBG&LNR'** KB.ELEV= 47.55' BF.ELEV= 15.05' KOP= �yy Yu1020' 01 Max Angle= 99°@ 14751' 4 l; 2092' 9-5/8"HES ES CEMENTER Datum MD= 14198' ,, Datum TVD= 8$00 SS 4.4 2227' 4-1/2"CAMCO BAL-O SSSV N,D=3.813" 20"CONDUCTOR 133#,H-40,D=? H 125' 6� 2227' 4 1/2"FS VALVE{03/29!17) 14 GAS LET MANDRELS q ST MD TVD DEV TYPE VLV LATCH PORT DATE 9-5/8"CSG,40#,L-80 BTC,0=8.835" H 7204' • 1 5504 4021 55 KBG-2-LS DOME NT 16 11/21/16 2 8236 5517 57 KBG-2-LS SO INT 24 11/21/16 Minimum ID = 2.377" @ 14451' I 3 9701 6309 57 KBG-2-LS "DAY SVT 0 08/12/05 3-1/2" X 2-7/5" XO PIN L 4 10796 6920 56 KBG-2-LS Y INT 0 10/01/97 5 11679 7417 55 KBG-2-LS DW NT 0 05/31/16 6 13067 8210 58 KBG-2-LS OW MIT 0 10/01/97 r CSG,26#,L-80 BUTT,D=6276' XO TO 29#, -I 13570' f/ i 7 13915 8681 55 KBG-2-LS "DMY INT 0 08/12/05 13CR-SO NSCC,D=6.184" "DMY HAS EXTENDED PACKING 7"MARKER Sr (19') -I 13805' g 13942' H7"X 4-1/2'BKR S-3 PKR,D=3.875" ' , 13975' -14-1/2"FES X Nip,D=3.813" ' , 13986' H4-112"HES X MP,D=3.813" 13993' H7"X 5-1/2"BKR ZXP PKR,D=4.760' TOP OF 4-1/2"LNR -I 13993' 13998' H4-1/2- WLEG,D=3-958' 4-1/2'TBG,12.6#,13CR NSCT- 13998' 13995' HELM)TT LOGGED 09/25/98 .0152 bpf,ID=3.958" 14007' Hr X 4-1/2"BKR HMC LNR HGR,D=3.938" 7"CSG,29#,13CR-80 NSCC, -j 14142' { A 0371 bpf,D=fi.1 S4" 14187' -1 3-1/2"BOT DEPLOY SLV,D=2.972" 4 ESTMAA 1 t3J TOP OF CEMENT H 14186' 14197 -{4-1/2"HES X NP,D=3.813"(BBOtD)PIPE) 14439' H4-1/2'FES X tom',D=3.813'(BERM)PIPE) 414205' H3-1/2"OTIS XN NP,D=2.750" 4 4 4 0 4 0 3-1/2"LNR,8.81#,13CR-80 STL,.0087 bpf,D=2.972" -{ 14451' 4 ► 14451' H3-1/2"X 2-7/8"XO,D=2.377" t • WFD WHIPSTOCK(02128/06) H 14483' I—,:l./7„.0.i I4LLOLITWNDOVV(P2-36A) 14498'-14504' RA PP TAG -I 14507' r-s;4'4 •.•�4.•4 4-1/2"HES CBP(05/20/02) -{ 14547' {-�4�4:4:4 1 16195' H MID(MLLED) PERFORATION SUMMARY •A••• REF LOG: CNIJGR/CCL ON 03/26/06 •�•A A A ANGLE AT TOP PERF- 91°@ 15050' Note:Refer to Production OB for historical perf data SCE SFE KNTB?VAL Opn/Sqz DATE 2-7/8"LNR,6.5#,13CR-80 STL XO TO L-80 STL -{ 15491' �%2" r 6 15050-15200 0 03/27/06 � if2" r 6 15250-15500 0 03/27/06 2" r 6 16100-16190 0 03/27/06 2-7/8"LNR,6.5#,L-80 STL,.0058 bpf,D=2.441" - 16232' DATE REV BY COMMENTS DATE REV BY COM4ENTS PONT MICtNIY RE UNIT 10/02/97 ORIGINAL COMPLETION 08/16/16 SJW/TLH F$VLV PULL(04/24/16) WELL: P2-36A 06/29/06 NORDIC 1 CTD"A" 10/13/16 R IUND OA CMT DOWNSOZ(10/09/16) PERMIT No:"`2060220 06/27/06 ?/PJC DRLG DRAFT CORRECTIONS 12/06/16 SR/JMD GLV C/O(11/21/16) AR Nb: 50-029-22801-01 08/22/07 DMS/PJC DRL.G DRAFT CORRECTIONS 04/05/17 DG/J14121 SET PB VALVE(03/29/17) SEC 14,T12N,R14E 273'FNL&1348'RM.. 02/03/16 GRCJTLH FB VLV UPDATE P62 STATE BEGS 06/01/16 MSS/JMD GLV CIO(05/31/16) BP Exploration(Alaska) PtiOF 7 • • Ofr, �/7:4, THE STATE Alaska Oil and Gas Of LAsKA Conservati®n Commission i 333 West Seventh Avenue '. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "FiV Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Kaity Burton ! I; Pad Engineer SCONE BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Pt. McIntyre Oil Pool, PBU PTM P2-36A Permit to Drill Number: 206-022 Sundry Number: 317-120 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, i°2V-ty Cathy . Foerster Chair DATED this Zfy of March, 2017. RSDMS (,te - 3 2017 RECEIVED • STATE OF ALASKA • MAR 2 1 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 0 � 20 AAC 25.280 AO GCC Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other PB Valve Design 0• 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 206-022• 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0. 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-22801-01-00 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 m PRUDHOE BAY UN PTM P2-36A• 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 TVD: MPSP(psi): Plugs(MD): Junk(MD): 16272, 9034 • 16196 9045 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"133#H-40 35-115 35-115 3060 1500 Surface 7170 9-5/8"40#L-80 34-7204 34-4968 5750 3090 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 31-14000 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 12.Attachments: Proposal Summary RI Wellbore Schematic I7j 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic ❑ Development Service 0 14.Estimated Date for Commencing Operations: 3/28/17 15. Well Status after proposed work: Oil ffi. 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 SignatureC/ � Phone +1 907 564 5554 Date OS/L(12011 / COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: ;k1 -A2_0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: NSF- (2q 111 Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 No Subsequent Form Required: /n IFC I APPROVED BYTHE Approved by:aley /0 COMMISSIONER COMMISSION Date:3.25— /7 v-rL 3/2c70.7- R€3®MS CA' APR - 3 2017 ORIGINAL / ,4/7 ., 3 z /7 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • m fa• O o 0 o O O (435? O I 5? OO) �- N O — C M t[) N- r V 4gC353 COM COQ) • Or- CN — d' c. m M CC) OD OD UD in CUD r-OD _M N - O CD [h UD O C o Nr co OD O) 00 UD 01111111 H Cn [f M 003 N CD e- 07 M Ch d ti CO Ch Q 03 00 UD 4mi CC G � OcNoD — O Ea � N �i � vvo • C � M `t d' .c i I . i I I . 4.0 N- it( O) M 0D M M c Cr) MEM e • MCa O O _ W O CD 2 OD 2 D)O � � � C C) 2 0 s- C = N O .JCOit N Q co 4t CO r CO = N r- Bo N OD O)N CV O CV N V O I� N --(=1 N C r S 4 C)p r,O C") CV LO 'V CO c 00 LO C` O CO O) w 1,7 CC) C() CV W W ct I — O WN UV OW— ZOu_ XcWW Z Ct W W W W 0 D F- F Z Z D • • m ea ea • Lo M ti t N O d CO M tri p O O O 0) 0) 0) 0. 0 N I- U) t N- co O) ce3 0 CO O O > p 0) 0) 0) 0 W 0 Z Lu 3g Y ° o W Q U co mWY Y F U U WLu M s+ 0 0 0) J J J Q Q V1cc CN 12- LO0m ° S2 v www 0 ? 0 IV N— ' zz z OJJ JQ J w _ a a d W a g U 0 0 W D Z 0 Z 0 2 2 2 O c) c~n u)i coci Q j a C � aLLo 0 Q 0 0 tO m co ui O Qc J = 0 0 U) J d _ g 0 u) co co u) co E o Ce a EwWW maga a 0 a) d a m I- 0 co co 0 0 j j 0 C 0 0 0 LU J J z O (NI N N ZO o_ 3. IssW W W N N N Z p. 0 W 0 W N uj N LL COr) M Q 0 0 J � H J J 0 0 Lu W O fX a 0. 0 CO OXOCLw J --133 w w Q QmCl. mu) L_ LL L. CO d CC CO CO Co E may' CO M M W d CO 0 U. N LL y a a a < < m m u_ v0) u0) a cc • • Packers and SSV's Attachment PRUDHOE BAY UN PTM P2-36A SW Name Type MD ND Depscription P2-36A TBG PACKER 13943.78 8697.76 4-1/2" Baker S-3 Perm Packer P2-36A PACKER 13992.87 8726.38 4-1/2" Baker ZXP Packer • • Ver 4 1 6/6/01 Wireline Work Request P2-36A global wells organization Distribution Wireline(4) Well: P2-36A AFE: APBWEINRSL Reading File Date: 3/20/2017 Engineer: John Paul Kenda IOR: 50 FTS: No AWGRS Job Scope: - SSSV Reg. H2S Level: Problem Description Install PB SSSV with different design pressure to attempt for well to operate at lower WHP. Initial Problem Review With lower WHP and relatively shallow gas lift design Well is slugging by—150 psi at full open choke. Deeper design has been submitted to APE. For now well has been choked back to—458 psi. Well FTP is targeted at —500 psi with PB SSSV installed. (Remedial Plan -WIRELINE ACTION Install PB SSSV to comply with State regulations. Weatherford set PB Valve at 773 psi at 60 deg F. DSO please flow well above 500 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-Weliwork Date of FL Survey: / / Follow-up Recommendations: • • "PB"Valve Calculation Sheet Well: P2-36A Date: 03/20/17 Test Data Test Date 03/17/17 Gross Fluid Rate 2653 BLPD Flowing Well Head Pressure 458 psi Flowing Well Head Temperature 111 deg F GOR 943 scf/bbl TGLR 1635 scf/bbl Flowing Pressure Calculations Based on Hagedorn-Brown Multiphase Flow Correlation "PB"Valve Setting Depth TVD 2104 ft Flowing Tubing Pressure With Gas Lift 458 psi Flowing Tubing Pressure Without Gas Lift NA psi Valve set to close at 500#Pwh Flowing Tubing Pressure @ 500# Pwh 879 psi PB"Valve Test Rack Set Pressure at 60 deg F 773 psi Valve Size 4-1/2" NOTE: Well needs to flow at> 500# Pwh Valve set to close at 500# Pwh • • Tubing Pressure at Valve 879 _ BPT(psis) 893 _ >1238 <1238 Temperature(deg F)at Valved 123 a 1.159E-05 1.92402E-05 1.144774 1.121842 Base Pressure 796.857633 c -910.221 -893.54238 Base Temp (TV-60) 63 788.80917 785.9028279 Corrected Pressure 785.902828 psia TCF 0.87967632 Pb @ 60 = 773.235489' Test Rack Pressure = 773 I •TREE= 41116"CNV SA NOTES:WELL REQUIRES A SSSV. WELL ACTUAT R= 11'FMC p2 36A ANGLE>70"014556'.`"'CHROME TBG&LNR"' fLCTUATCX2= BAKER C � KB.ELEV= 47.55' BF.ELEV= 15.05' KOP= 1020' I 1/ 1/ I Max Angle= 994 @ 14751' 1• EN I $1 2092' 9-5/8"HES ES CEMENTER Datum MD= 14198' 01 ./ Datum TVD= 8800'SS ,1 •'1 2227' 4-1/2"CA MCO BAL-0 SSSV N,D=3.813" 20"CONDUCTOR 133#,H-40,D=? 125' 01 '� ••1 •k1 GAS LFT MANDR11S �1 �/ ST MD TVD DEV TY FE VLV LATCH PORT DATE 9-5/8"CSG,40#,L-80 BTC,D=8.835" — 7204' 1 5504 4021 55 KBG-2-LS DOME INT 16 11/21/16 Minimum ID = 2.377" @ 14451' 2 8236 5517 57 KBG-2-LS SO INT 24 11/21/16 3-1/2" X 2-7/8" XO PIN 3 9701 6309 57 KBG-2-LS "DMY NT 0 08/12/05 4 10796 6920 56 KBG-2-LS DMY NT 0 10/01/97 / 5 11679 7417 55 KBG-2-LS DMY INT 0 05/31/16 / 6 13067 8210 58 KBG-2-LS DMY Nf 0 10/01/97 7"CSG,26#,L-80 BUTT,D=6.276" XO TO 29#, H 13570' 7 13915 8681 55 KBG-2-LS **DMY NT 0 08/12/05 13CR-80 NSCC,D=6.184" "'DMY HAS EXTB+DED PACKING 7"MARKER JT (19') Jl 13805' //1pp1 L 13947 J 7"X 4-1/2"BKR S-3 PKR D=3.875" 13975' H4-1/2"HES X NP,ID=3.813" ' 13986' —14-1/2"HES X NP,ID=3.813" TOP OF 4-1l2"LNR — 13993' L I 13993' —17"X 5-1/2"BKR ZXP PKR,D=4.760" 13998' —14-112" WLEG,D=3.958" III 4-1/2"TBG,12.6#,13CR NSCT J 13998' 13995' —ELMD TT LOGGED 09/25/98 .0152 bpf,ID=3.958" 14007' —{7"X 4-1/2"BKR HMC LNR HGR,D=3.938" 7"CSG,29#,13CR-80 NSCC, H 14142' (-411 .0371 bpf,ID=6.184" ; ,' 14187' —13-1/2"BOT DEROY SLV,D=2.972" ►� 1419--14-1/2"HES X NP,D=3.813"(BEHIND PIPE) ESTIMA i ti.)TOP OF CHNENT H 14186' ►, ►' 14439' J4-1/2"HES X NP,13=3.813"(BEHIND PIPE) . ► 14205' —3-1/2"OTIS XN NP,D=2.750" 3-1/2"LNR,8.81#,13CR-80 STL,.0087 bpf,13=2.972" — 14451' .4 14451' J—I3-1/2"X 2-7/8"XO,1=2.377" 4 VVFD WHPSTOCK(02/28/06) —{ 14493' MLLOUT WINDOW(P2-36A) 14498'-14504' ticisbl RA PP TAG -{ 14507' r4••• 4-1/2"FES CP(05/20102) H 14547' • •�•�•�• B 4 MO 4%1444116195' PBTD(WILLED) PERFORATION SUMMARY 1.1.1.1.':' REF LOG: CNJGR/CCL ON 03/26/06 ANGLE AT TOP FERE: 91"@ 15050' Note:Refer to Production DB for historical pert data SIZE SFF INTERVAL Opn/Sqz DATE 2-7/8"LNR,6.5#,13CR-80 STL XO TO L-80 STL 15491' 2" 6 15050-15200 0 03/27/06 ; STATE OF ALASKA "'ALASKA OIL AND GAS CONSERVATION COMMIlliN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Il Re-enter Susp Well 0 Other:OA Squeeze m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-022 3. Address: P.O.Box 196612 Anchorage, Development II Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22801-01-00 7. Property Designation(Lease Number): ADL 0034627 8. Well Name and Number: PTM P2-36A 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: ECEIVED Total Depth: measured 16272 feet Plugs measuredfeet __. true vertical 9034 feet Junk measured feet NOV measured 13942 Effective Depth: measured 16196 feet Packer feet u2015 true vertical 9045 feet Packer true vertical 8697 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"133#H-40 35-115 35-115 3060 1500 Surface 7170 9-5/8"40#L-80 34-7204 34-4968 5750 3090 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 15050-15200 feet 15250-15500 feet 16100-16190 feet True vertical depth: 9032-9032 feet feet 9032-9038 feet 9054-9045 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 30.:_1. 9_98 30-8729 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 13942 8697 true vertical depth) 4-1/2"K Valve 2227 2104 12.Stimulation or cement squeeze summary: Intervals treated(measured): OA from Surface Treatment descriptions including volumes used and final pressure: SCANNED APR 2 U f 10 Bbls 50/50 Methanol/Water,216 Bbls Fresh Water,218 Gallons Surfactant,218 Gallons Mutual Solvent,12 Bbls 13.5 ppg Spacer,307 Bbls 15.8 ppg Class G Cement,400 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 224 138 520 2102 1236 Subsequent to operation: Well Shut-In 80 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development Fif Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I 1 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-401 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature _ " Phone +1 907 564 4424 Date 11/17/16 Form 10-404 Revised 5/2015 Vf� L�3_/ 2 i l Submit Original Only A474:e7 RBDMS LA- NOV 2 8 2016 '�/ • • N C V CA + a) C Va N -0 O . p C 3 Q O > O N ca Co 0) ° � 3 (a coo0 _c co -.. a) od D > aa) 0 c ami = o \ a o D m o II 0 0 5 4 o) ui 0 a - c- o c c) 0 ° in o ` � Q 0 0- cn ° g .0 o C L p 7 `� ." O C C C 7 ° 0 C O O 7 J 7 Ln C Ln O Cl) r= p (N U p -0 II ca 2 N J -O -Q m E -0 fA a) () u) ° m J 4171- ° p �. C . a E Ln �•_ CD T > J C N w O 0 "O 1- N (A o N a) O` a- (7) Q _10CL O J J +. 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C Qco � ° co Ct d a m o O N 0 `) a O 0_-0 a ° c o o--o a ° O 0 Y >+ co •_;-_-, Ia.-o > o -0 � oa co � s on o � 0 o Q � � � c) Iii II o0 .CU a) c E a) = 0)-o U I- ' :� O m 0 H o c�a v '>- c o u m v� 0 Q o H co . 1 w aE) o a) > _o o j •. > ° > o 0 ° c cop c5o a) ° ° = ZH ° a) v) 0 O to ° m L a) + (n V .. U Z CO U U > 0 Z . 0)15 m N * p g> j 5 -C C c. N 0 (13 '` .. c°o 0 " E 00 O L H N - O 11 0 * > co u) •c l.i ui i > ) Z > � }->, o Z -00 a) ° > a`> > o `. Z " io ° - Cl) CO c a) u) > v>) 0Oa a) .E (n 0 - 0 ai , -0 co (n -0 0 l� a) •- m u) vim) us ate) (� 4) ` CO O m co c >_ _o II > o c c IL II a) U c,: a .._' •C U) •N L II E II a) O S O = _a m II O O t Q•- N .ct OoOE _9, u) O 3U Ocn � � OL30 . Oma n- a) > 2 ' w .......— ...... ,S > ,...—c a) m c - Tam 0 a) cp coo : - 0 a> 0.- 1- u) HcCC) : O o ._ QH Uv) I- _cli o 122 _a00I- .cu > i * F- bov CO CO c0 CO (0 CO CO CO CO r a r r r r 0 0 0 0 o O o 0 0 N N N N N N N I- 00 CO 0000 0) c- N C N N N N N O O O O ) O) 0) 0) 0) r r r • • QQ c -o a O = ° co ° o Q EW OM N � v) N , rn 0)m V Op c o m O Y r N ° W -EO Q Q Y 3 c 03 -0 = c E I I o = 3 r) I ami N °) ' r ° a) �`-� V) @ J i J > a0 C Q II U o > a O ° m cn w cn .- U) a) E a +. m 0 J ,_ Cm r (� U -° "O E cSS V) a) i N Q "_ c0 d ° c ° Q J C �O O O fUQ a) . �U�`` C C U -0 a,_. _c r co N N • L 0 c U u) V ° a) 0 't w = U m ° U ° ° m ° .- o ° 7 m U >(DEa32 -0 c t .- � � � © vi - ac) co (no0-,na) * @ � rnr3co � Eaa)) Q ° - " 2 E U d co rn rn m 7, c •Q m .x c @ 0 2 _C J vt U — J ° c E ° E E ° 2 cn ui Qo (n QN Nom ° C'm � 1 r. < oQoE � �, E co Q C QD Q 03 N OO M CO ` O .Q o a) J O O-.*K N N CL o ° v o E •- r rn 0 c o o Q m QtO Q o E a) .._ ° Q II cYa 3 0 ° C ° I I o �° ao Y E o N U ° U Cl) ca co 0)-,•=, d N U) 7 a -. a3 a) .0 N w o Q > U o 2 j m n ° o Q Q. CO a) L- C 0 4) C C N (nom m QE -0 QU N � U T rn (f) L w ° E N Q �: E co > cn eu Q N co "d o r U c in a 3 ° i. 1� > Q'3 r ° Q E I.-. N Q cn O N v CO U >,M 4 = o c t j C 0 2 o o ° 0 Q ° F + M ° N LI ° O O H O v 92 c .E O > y- _a a) ch m > 3 U > r a w > ° ° v O M N ' U ° O > _ \O p �. C O J = C O ° 1] QY m 0 Q c13 0 a) To �.., O m O to c -p 0 N rn L "p• ° o C .2 O U • p * O U) t .E p N E _C O r a) E O i .� co O a) E U +. O omLL .2 0) QQ (1) Q * O II �c ° -1--, '' 0000E0 * Ea m p Q O U U Q * c E ECO C -c O v - Q w Q c -0 r ° c > • Q MO ') EO > m Q O _ H d o y �O 'c m -, ~ 0p N cpi) O U ° 0 (g)6w ° I Oor mai „ co ° � —� aico a) � * o0 .v33 QM r Q 3 C N •E • _O v a aa)) u) -a U o t� N Q Y .- 0 o O a) c d N o uu)) o N Y0 o D d ° a C o N o 0 w co-c ° c c • c 2 () - p 'C >+Ct a N < II c N II m co ¢ a7 O IQ C .0 3 Q Z N c ° E — LLQ � � E ° U O � H � � ° 3c4oa. ° 'cn � � E � Eo � ° Cl 0 a0i c o - - (I) (13 H o > o E = cII w Q , 'i aU) z U E .� m0 (1.) m- -f m Z oap o �, o o ° '§ ° Z U J .- - v, S U p co ° o Z o o Q ° o o0"-- 1E o .co) c • W crLj = -° - HQ c°opJp c ° mac < = tO ol- ao2 r is o ._ � v � c`') > a) a) Z02 `Cpp ° c � oOp 34- ZN .--;„a) mCt O v n > rn U o 3 O U ai o aEi .c° rn ai (n ° ( a°i ) O > U U u) UU) a a°) N > E ..c-, in OU oDN c) o E c QwE, U - cUci) o -ciS II a>) o 4 o n I- U - c O E a ° = ui CO 0 3 II - ._ U o Q Y c C C U C O D a) > Cl -a ° cn .--+-' U J C in• ` O j +, : •••=... = 0_ 000 > 0 ..._- C a) *K* o = co a) c0 U O > O > rn ° rn*K> �_ C a) a) O * H o _cUU a) UH co s * -' O rnUU a) U a) > co O ow H ca c.) 3U 0 0 co co 0 0 co r r r r r r r O o O o o O o N N N N N N N O o O o o O 6- ,- r r r r r r • 0 1-2 -a a) o c N a) ac°i 0 @ c o c-`o p ate) ° 2 a) * ca o c d Ta i * o> a N °) 0 j m 'uo) o c U Q Q > .- U ' Q CLL = catu co (RalY > cE c• � rnc � c * c E o ai c o U m .2 -0 co U - a) ) C m a) > u) C o a) a N co = -c) Q !Z a) o_ O a) rn c N 'c U O E a) •- a U O = o o a) O N U o O a) - N O O O co > U co O fo 7 U ��ll Q U ll) c ` d co E \ C "a7 N j V Oo c o N a) O to > a) YLT > f° n- Uc (V c a) U c) * E o * E U N (o J Q II a) J - a) - .`-, II rn QO ac a aEi Q - a0 � O U O N `� J v • c o (a a _ N- ii p o Q U N Q ,- c > ❑ CO to O• 1� o c N m Q r ---6 V 7 _N a) • ° N c > p a) p U c .0 a) < a) y a) O- Q- U rc0i > ao C 0 c � z � o Qy COEv Ua ea a) o c a) a) - p a) O .c �) o 0_ -- i 1` c � `Oo rn co E � o N v) .0 0 Cao QCNI O a) N O — a) O o cn O cu C o co O O co O U O +. a) :q tici co N .0 Q)0p Q: (N a) a) c, Q coo_ r a) (n O a aa) U -p C" N Q o Q > o a'- 4 O a) o � Oc o_ d J -E •- o ff .E O o u) > Z IO- o ate) o Q H 1- _0 O 0 Q p 3 3 c -IO U - a ,c . Oo C O O 0 L • „a) p o Q = a) .� Q2 � cUi> > m a Q > .- o rnQ �0 c � Q � Q O _ Q � � c) � O a- EN cn � O _ a) Z cO • coo O Ea O M p o..ols Q N ❑ v) -, a) U) > , v) c o -r121- 11 > - - II > Q- — II a) -0 o Q O cu W N U ( ,c N- = Q O o co_Y c - rn Ema) s Et a co ) Ocn c‘i II oc aEiaEiu> OEo wO E uc O m 0 E > c 0-ii H a) > Hm a) OQ II H U C - a a) 2- . N.."."-' c a) E 0 E a - o a) > + `t 3 - > c +. U a) -a o co .,..,4=, a) m 0) o co o a3 . o = c ~ u' to EUU O a) U rnrnOU o — 'CU U �( O U0 CO fX = C N II < • (a) < c N 11 Q E N ( 11 Q V >) C 11 U # u) O > Omo a)Q > m °) oww me -0 oa)o : ja) vaZ U U UH (A Ho a) cZo aiN to 12 4E.' rnc o oiQ11 II Lis n ` 11 op11 >(1)i aa) OUBc .c c 5EOE o •,-- TD Oasa) O E z cma) U co_ C Op 0 0 pj p - p \ > - > c °) _c >UM � Un -3UF- U F- 5 .Eu) H co o0oI- H I_ u) c/) H\ O (7 co co co co co co co N- r r r r 0 C) 0 C) C) C) C) CO a) 0) o CO v o C) 0 0 o O o 0 r r r • a C 0 +' E a� ti Q G1 N (A T Q. C -o cn O M .5 — o ,1 m 0 0 Q 0 0 O Q. d N Ce 0- a) L L �� a) > > U a) •— — L 0 TD t. n 4-(15-�-1 /— a) m o fn U ca• a) ) O (0 Q Q CO CO m N CO LO N 11) '- O r • 00000 O cooco 'tNoO 0 CO lf) I- N- N- U y o 0 0 0 Co O CO 10 CO CO CO 3 O h N - m M cc I,- Cb CO CO Lo CO N M N 0) Cfl CO N 6) N CA cr CO O O I� Nt CO CO O) CO CO I O) I- (O O V cc co N V O M M N- CO Cr) CO COCO CO OCO CO � O) Lf) O) c- (NI CO Nr CO C.) p CO MM N O) CO O ci M M Ln in O `- M a) M M co � : F- OCoOO _ a o - ' Oj COO CO co CO N M O O cn co - N N CO N Uooco N N N CV N c OC M N Lo V co C CO T- M I- O CO O) w 10 Ln N CO J W Q Q N o U LLI w 0 O 0 u f Z zcwwwwm � � _ _ O � z z D 0 Cn z z J J F- IKEE= 4-1/16"CAN • WELLHEAD= 11'FMC NOTES:NOTES:WELL REQUIRES A SSSV. WELL ACTUATOR= BAKER C P2-36A 70°e#14556'."-CHROME TBG&LNR"- KB.ELEV= 47.55' BF ELEV= 15.05' I , ', I KOP 1020' 4 Max Angle 99°@ 14751' #14 •,1 2092' 9-5/8"t SES CEMENTER Datum MD= 14198' 1� �, Datum TVD= 8800'SS 4 • 4 2227' 4-112"CAMCO BAL-O SSSVN,D=3.813" 20"CONDUCTOR,133#,H-40,D=? 125' •; p; �4 oi4 GAS LFT MANDF2B S 9-5J8"CSG,40#,L-80 BTG,D=8.835' - 7204' �4 rA4 ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 5504 4021 55 KBG-2-LS DMY INT 0 05/31/16 Minimum ID = 2.377" @ 14461' 2 8236 5517 57 KBG-2-LS DAM INT 0 05/31/16 3-112" X 2-718" XO PIN 3 9701 6309 57 KBG-2-LS *"DMY INT 0 08/12105 4 10796 6920 56 KBG-2-LS DMY INT 0 10/01/97 / / 5 11679 7417 55 KBG-2-LS DMY INT 0 05/31/16 6 13067 8210 58 KBG-2-LS DMV INT 0 10/01/97 7"CSG,26#,L-80 BUTT,D=6.276" XO TO 29#, H 13570' 7 13915 8681 55 KBG-2-LS "DMY INT 0 08/12/05 13CR-80 NSCC,D=6.184" "DMY HAS EXTENDED PACKING 7"MARKER JT (19') H 13805' Z X 13942' ---17"X 4-1/2"BKR S-3 PKR,D=3.875" ' , 13975' H4-1/2"HES X NP,D=3.813" ' ' 13986' JH4-1/2"HES X NP,D=3.813' 13993' --{7"x 5-1/2"BKR zxP PKR,D=4.760" TOP OF4-1/2"LNR -J 13993' �-/ /� ` 13998' I-4-1/2" WLEG,D=3.958" 4-1/2"TBG,12.6#,13CR NSCT--I 13998' `� 13995' H aMD TT LOGGED 09/25/98 .0152 bpf,D=3.958" 14007' H7"X 4-1/2"BKR HMC LNR HG R,D=3.938" 7"CSG,29#,13CR-80 NSCC, H 14142' 0371 bpf,D=6.184' P 14187' H3-1/2"BOT DEPLOY SLV,D=2.972" 4 ESTIMATED TOP OF CEMENT H 14186' ► 14192' —141/2"Has NP,D=3.813"{BEHIND PIPE) 14439' H4-1/2"HES X NP,D=3.813"(BEHIND PIPE) 4 ►' 14205' H3-1/2"OTIS xN NP,D=2.750" ► 4 4 ► 3-1/2"LNR,8.81#,13CR-80 STL,.0087 bpf,D=2.972" H 14451' 4 C 14451' -{3-1/2"X 2-718"XO,D=2.377" t WFD Wt STOCK(02/28106) 14493' MLLOUT WIDOW(P2-36A) 14498'-14504' ititih RA PP TAG 14507' v•-•-•• • 4-1/2"HES CBP(05/20/02) -{ 14547' _••_•_•.• 6 16195' HF TD(MLLED) FERFORATION SUMMARY •..... REF LOG: CMJGR/CCL ON 03/26/06 At ANGLE AT TOP PERF: 91*@ 15050' Note:Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8"LNR,6.54,13CR-80 SR XO TO L-80 STL 15491' 2" ir 6 15050-15200 0 03/27/06 i o. 2" ' 6 15250-15500 0 03/27/06 �!do: .�� 2" r 6 16100-16190 0 03/27/06 2-7/8"LW,6.5#,L-80 SR,.0058 bpf,D=2.441" -1) 16232' I DATE REV BY COM TENTS DATE REV BY CX)Mu1ENTS PONT AACNTY RE UNIT 10/02/97 ORIGINAL COMPLETION 02/03/16 GRCITLH FB VLV UPDATE PER STATE REG; VVELL: P2-36A 06/29/06 NORDIC 1 CTD"A" 06/01/16 MSSJJMJ GLV C/O(05/31/16) FB2MTND:'. 060220 06/27/06 ?/PJC DRLG DRAFT CORRECTIONS 08/16/16 SJWITLH FB VLV RLL(04/24/16) AR No: 50-029-22801-01 08/22/07 DMS/PJC DRLG DRAFT CORRECTIONS 10/13/16 MOUND OA CMT DOWNSOZ(10/09/16) SEC 14,T12N,R14E 273'FM,&1348'FWL, 02/18/11 MB/JMD ADDED SSSV SAI-EI Y NOTE 05/07/12 LEC/JMD GLV C/O(04/30/12) BP Exploration(Alaska) • • Quick, Michael J (DOA) From: Quick, Michael J (DOA) Sent: Thursday, November 10, 2016 2:22 PM I 1 \O To: 'Worthington, Aras J' P' Cc: Schwartz, Guy L(DOA) Subject: RE: MITOAs p-v—tb ,2 D b - 1 1 v at Aras— You are approved to not perform the MIT-OA as was outlined in your procedure,on these 3 sundry's. Michael Quick Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th AvenueSCANIEQ .JUN 9 2U t Anchorage,AK 99501 (907)793-1231(phone) (907)276-7542(fax) mike.quick@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). it may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Mike Quick at 907-793-1231 or mike.quick@alaska.gov. From:Worthington,Aras J [mailto:Aras.Worthington@bp.com) Sent:Thursday, November 10, 2016 1:41 PM To:Quick, Michael J (DOA)<michael.quick@alaska.gov> Subject: FW: MITOAs Mike, As per phone discussion we are requesting that we forego the MITOA on these three approved job Sundrys. The complete 403 approved packages are attached to this e-mail for reference. Our rationale is as follows: 1. The MITOA typically will not pass conventional pressure test criteria (30 minute test with 10%pressure loss) due to the extremely small volume we are trying to test in a fully cemented OA. The 30 minute test criteria was designed for a large volume (un-cemented,fluid packed tubing or casing and associated annuli). 2. Due to point#1, BP does not consider a passing"MITOA"to be the appropriate measure of success or failure of the repair. 3. BP proposes that the indicator for job success will be bringing the well online under evaluation and monitoring the conductor for any leak,weep, etc. as well as monitoring any thermal pressure buildup in the small void space in the OA daily. 4. In the future, BP will submit Sundries for these types of repair without an MITOA included for the above reasons. 1 • • If you agree,could you please respond to this e-mail with "approved"or"agreed"? Thank you for your time, Aras Worthington Well Interventions & Integrity Engineer BP Alaska Inc. Office: (907)564-4102 Cell: (907)440-7692 2 • • v of r �` '",���//7,,s, THE STATE Alaska Oil and Gas —sem , �f T AsKA Conservation Commission fS 7:---12:14: 333 West Seventh Avenue c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Op -- P Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Aras Worthington Interventions and Integrity Engineer BP Exploration(Alaska), Inc. scWtiog) J/-\N 1 3 LGI7� P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PBU P2-36A Permit to Drill Number: 206-022 Sundry Number: 316-401 Dear Ms. Worthington: 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, C‘1-61 Cathy P. Foerster Chair DATED this I jh ay of August, 2016. RBDMS i-" AUG 1 5 2016 STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COMM, APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 , Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Cement OA II 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: • 5. Permit to Drill Number: 206-022 ' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22801-01-00 . 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 Q PBU P2-36A , R_ECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: AUG 0 2 201 6- ADL 034627 - PRUDHOE BAY,PT MCINTYRE OIL d 8 I , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Jun 16272 • 9034 • 16196 9045 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 35-115 35-115 3060 1500 Surface 7170 9-5/8" 34-7204 34-4968 5750 3090 Intermediate 14109 7" 33-14142 33-8813 7240/8160 5410/7020 Liner 505 4-1/2" 13993-14498 8726-9022 8430 7500 Liner 2045 3-1/2"x 2-7/8" 14187-16232 8840-9039 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 15050-16190 9032-9045 4-1/2"12.6# 13Cr80 30-13998 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and ND(ft): 13942/8697 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary H Wellbore Schematic ® 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development p - Service 0 14.Estimated Date for Commencing Operations: August 15,2016 15. Well Status after proposed work: Oil II ' 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 Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington@bp.com Printed Name Worthington,n,Aras J Title Interventions&Integrity Engineer Signature //_ ,/ Phone +1 907 564 4102 Date 8/4(41.07e2/‘ ��+ f COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3‘ LQ - qo Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 NoCt r ��C I Spacing Exception Required? Yes 0 No Subsequent Form Required: /b —ft),4, �C / APPROVED BYTHE Approved by: / COMMISSIONER COMMISSION Date:a_ !/ —!L it'le6 wiz, ORIGINAL RBDMS L.� , 2016 AUG 5 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attach nts in Duplicate • • • Well: P2-36 P2-36 OA Cement Downsqueeze Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Kaity Burton (907) 564-5554 Expected Start Date: August 15th 2016 History P2-36A is a gas lifted producer that has struggled with low flow and hydrate formation. During a routine hot job 12/2015 the well started bubbling in the cellar and was reclassified as non-operable. An MITOA failed 03/11/2016 with more bubbling in the cellar. SL came out in 05/2016 to try and secure the well but was unable to set a plug due to residual scale in the tubing. Throughout this duration, P2- 36A was flowing fluid to surface via the conductor flutes and required regular vac truck attention. In light of continued fluid to surface the GL valves were dummied and passing MITIA performed to verify the formation was not the source of communication to the OOA. Due to the leak, excavation to clean up was pursued and able to visually identify the leak source on the surface casing about 36" below the OA casing valve at or near the top of cement in the casing by conductor annulus. The leak path was determined to be down the OA, out the surface casing leak into the conductor and out the conductor circ port into the cellar. Additional bleed and monitor established build-up rate in the cellar of -1" per hour and only 1/4" per hour when holding an open bleed on the OA. A plan to mitigate the continued fluid to surface or slow the rate was developed and executed 06/22/16. This mitigated the need for a vac truck on location but fluid is still building at -.5gal/day rate. The proposed plan is to break down the OA shoe and pump OA downsqz to seal the leak to surface from the OA. Current Status The well is currently classified as "Non Operable" by BP due to the OA x Conductor leak. The well is currently shut-in until the leak is fixed. Job Economics Over the next 10 years, there are 310mbo estimated to be recovered as a result of getting this well back on production. Current economics do not support a rig-workover, therefore this alternative integrity repair is proposed to regain operability of the well. Objective The objective of this job is to cement the OA (9-5/8" x 7" annulus) to seal-off the OA x conductor leak and regain operability of the well. Cement will be pumped down the OA and into formation. The intent is to have cement in the OA from the Surface Casing Shoe to Surface. Post-Job Evaluation MITOA to verify no fluid leaking to Conductor Long-Term Integrity Monitoring ➢ Daily pressure-monitoring of WHPs Periodic inspection of the Conductor/Cellar to ensure no wellbore fluid leaks • • Job Notes • Surface casing leak to conductor near surface. • Conductor is filled with Class G cement to slow leaking fluids to manageable rates but the well remains not operable. 2 • IIII 4 116".11W SAFETY NOTES:Wirl L PEQUIRESA SSS V VELI •Vill_HEAD- 11'FMC ACTUATOR, BAKER C P2-36 Current . i ANOLE>70°kr 145,..',r,' '''erltROME TBG&I.Nit— i ."---- . — KB EIEV- 4755' BF BEV- 15.05' I M—lto"It A‘ KOP' 1020' Mix Angle r 99°a 14751' j 0 2097 9-5/8"HFS FS CiFhimaRe Datum MD- 1419E , Datum Tv D.,- XXV'ss 2227' ___4-1/2'CAMCO UAL-0 SSSV r. I ,.1.I l' 20"CONDuctrx4, 133a,I-1-40,ID=7 _I—i 126' -- GA s LIF-1 WAN113F1 5 - 9-5/8"CSG,400,-80 ETC., ID 8 8.35-1-1 7204' 1 k ST MD IVD DEV TYPE VLV LATCH'.PORT lac r'.1, t — 1 5504 4321 55 KBG-2-LS DONE INT 16 04/ 0#12 Minimum ID = 2.377" @ 14451' 2 8236 551?' 57 K8G-2-LS DOLE INT 16 08;21415 2 1/2" X 2 VS" XO PIN I-1 3 9701, 8309 57 KBG-2-LS 'MY INT 0 08/12415 4 10796 6920 56 KI3G-2-LS OW INT 0 10/C1.97., / / 5 11679 7417 55 KBC.-24.S SO INT 20 081214:6 6 13067 8210 58 K130-2-LS INT 0 101C-1197 1 1 --, DAY ?'CSG,260,L-80 BUTT,ID=0 276' X0 TO 2134, !---11 13670' -/ 7 13915 8681' 55 I KBG-2-L.S **MAY INT ' 0 08112/051 -"MY HAS EILTEPCIED PACKING 13CR-1110 CC.ID=6.164' . - 7"MARKER JT (19') -- 13905' A X' I. 13942' j--1,'X 4 Il f tiKht S.i-4'R LI z 3 8/5" I r -- 13076' _____...... , -i 13993' 1—r x 5-lir 13144.1..XP PtcR,U=4.160' [TOPCIF-4"1/2 "LM] - fialk - - ---— -- , L 13998' —4-112' 4EC.D=3 958' ..■ 4-1/7"TBG,12 al,13C0 Nscl -f 1399Ir 1 , n .13995' I I II MO TTI OfiC41)0425/98 I 0157 bpf.113=3958 14007' 1-4,r X 4 1r2"8KRI-NG L.NR,-GB,0 C r tau,turf. ezurt-so maw., ---i 1414S lk 1 ii141ST 1-1_3-1/7"130I nf T1(-1./ 51 v .0371 bpf,ID.6.184" i ii ESTPAA INI TOP 01 C14/1141 --L 14108* I. -1.,_1 4)92. 1 it-112-HES X W gL3 813 661,111141)PIPE) I e ..........,. 1443W I—4-ii2-hes x Np.ID=leis.(BEI PIDP11;4 1 II p -----1 14205' F-3-112-OTIS XN1462, rP: 4 * 3-1/7 LNR,8.610.13CR-110 SR_.0087 bpi,0297F 14461' 4 .t. iMilla 3-1/2"X 2-7,1r XO,0=2.377- ,k VICOMINFSTOCK(02126+06} 14493' '''.. MILLOUr KIKOOW(P2 3M) 14498' 14504' 1 RA PC,TAG — 14507' 4,••• 4-1/2'HES CEP(05/20/02) H iiscr 0 1 131W --1P0 IU(PAULO) i PERFORATION Sts /AR' -414••-•• LOMA, REF LOG Cft.fGRXL O4 03/26/06 ANGLE AT TOP FH 91°43 115050' Note Hater to 1-koductur LB for historical perf data SIZE SPF ' INTERVAL Cpn/Sqz DATE 12-70'1NR.651.13C12-84 STL X0 T01-60 511 16491' .., 6 ! 15050-15290 0 03/27/06 2' P. 6 ' 15250-15500 0 03/27/06 ---- k 2' P. 6 16100-16190 0 03/27/06 12-7/6"LW,6.50,L-80 STL,.0058 NO,ID=2.44r F- 141237-1 _ [ATE REV BY ' 03NME4TS DATE REV BY COMENTS 1 PO.,11 NCETTY RE UNIT 10/02/97 ORIGINAL COMPLETION 02/03/1E GRC/ILH PB VV GPEATE PER STATE RE-GE NELL P2-36A 86129/08 NORDIC 1 t CTD"A" 44/26/1€ SWUM) RLE)PB VALVE{04/24/16) - PERMIT No* '2360220 062716 71 PJC DRLG CRAFT CORRECTIONS _ AR NI): 51029-22801-01 , 0822/07 DMS/R/C DRI_G CRAFT COWECITONS SEC 14, 112N,R14E 273FNL.& 134E PAIL, ,....,_ 0218/11 11/4.13/JIND 'ADEED SSSV SAFETY ND FE — I ___ 05,17:12 LE-CJJMD GLV 00(04/30/121 - ______ _ BP Exploration(Alaska) 3 _ • • FREE- 4-1116"L1W WEL1.1-1EA D 11'B/D SAFETY NOTES:WELL REQUIRES A sssyt Wil L • - ACTUATOR- BAKER C 'a 1466r ''"ChiRomt I MI&L Nit'•' P2-36 Proposed AZ''7°' - KB EL EV - 47 55' Zt? 61 FIB/ ..- 15.05 KOP- 1020' I, I: [7 1- Surface Cement in OA from 9-5/8"Shoe to Max Angle= 99'a o 14751' Datum MD,-- 14198' t rritirn-rvn- mon 222T2"--1_14-1, CANCO BA L-0 S -S''ii.,,r,I)‘-• t n I I- , 4,1 X'CONPUCTOR. i Via K40 LI=7 1-i 125' . _ ... , &t5 LFT MAPERF1 5 -k. 9-5/8" G,404 ._" 83 STC, 13-8 835 -1 7204' i .' L ST kV :TVD'DEV TYPE VLV LATCH'.FORT DA TE 1 5504 49211 55 KBG-2-LS COW INT ' 16 04/30/12 ( Minimum ID = 2.377" @ 14451' 2 8236 5517 57 K130-2-LS COME INT 16 08/21435 2 1/2" X 2 7( - XO PIN Wil 3 9701 6300 57 10:3G-2-LS •13MY INT 0 08/124:6 4 10796 6920 56 KBG-2-LS DAY INT 0 10/C1/97 / 5 11679 7417 55 KBG-2-LS' SO INT 20 06/21435 6 13067 3210 58 KBG-2-1S Dar INT 0 101C1/97 7"CSG,269,L-80 MITT.ID 7-6 270' XO TO 299, --{ 13570' 7 13915 R8.81 55 KBG-2-LS "MY INT 0 08/12A _ . -CM Y 148S EXTENEIECI PACKING 13CR-80 SISCC.D=6_184' i z 't 13942 1 f'X 4 Pe'tiskti:,i PKIt 1..),.i ars* I r MARKER ST (19) - 13805' Or4 I I.R- - ' 13075' J--4 tr2-HEE X NP,ID.--•3.813' I I 13986' ' H4-1/2"FES X NP,13=3.813•1 13993 -I-X 5-1/2"13104 ZXP P1/01.6=4 1701;-4-4--1/21-N1 1 3807' 13998 J-4-1/2' MA_EG,13=3.958' PM Ft-1/2-TOG 12 61/,13CR NSCI i 13998' ' 13896' j [FLIAD TT LOGGED thr.75+96 1 0152 bpf,ID-3 958- 141307' 1-ri;X 4-1/2"9KR I-NC LM HGR,ID=3.936'1 LLFIF. L.x.n-wa neut., -i 14144 1_0371 bpi,ID.6 184' 0' r 4 1 141ST H3-1/2"807 DER.OY&V ID=2 977 ; { 1-1[ „ ,es npm.ut)try of (14w•ro 1,i 14186' 14192 4 117 H115 X NP•1.)-3 817(BEIIND PIPE) - - ---------- _.__ •• ii" 0.1. le! 141-4--13£1" -4-VT ribs X P1.0--,3.81T(BUIPMPIPE) o ) 14205' F-3-1/7-OM XN IMP,ID=2.750' °• I ir lo • 4 3-1/2"LNR,8_814,13CR-110 sli... C4387 bpl,0=2.972" 14461' :, t 14451' 3-1/2"X 2-ria-xo,u=2.377' is, 0 A '4 VVFOVAlFSTOCK(02/28106) 14493' ", ML L01./7 VVINDOW(P2 38A) 14498' 14504' i 'RA 1:97 TAG I.-- 14$07- r•-•4-4••• ••••.. ••••41 •••• 4-1/2"FES CEP(05/20/02) I- 14ser ,,b-e-•-•- ; IMI 16196' i ilAiIIIIMILLUtl I FERFORA BON SUMMARY 1 AhlipiptAl ....,........,...... REF LOG. CNLIGR/rX:L ON 03/26/06 ANGLE AT TOP FEPF 91°CI)15050' Nate Refer to Producbor UB for historical pert data ot SIZE SIT ' ICERVAL Opn/Sqz LATE 1 12-7.18-LNR,6.58,13CR-80 SR X0 TO L-80 STL -I 2" 4'. 6 ' 15050-15200 0 03/27/06 7 ' 6 I 15250-15500 0 03/27/06 -t. 2' r 6 16100-16190 0 03/27/06 12-7/8'LNR,85 ,L-80 Sm,.0058 bp!,0 1441' I- 16232' _ -DATE REV BY COW/NTS 1)A1f1---REV BY 1 COM.CNTS 1 FONT LCUTY FE 1.1111 10/02/97 ORIGINAL COMPLETION S2/1.13/1t c;itCrILH 1:13 V.A./UFT1ATE PER STATE REG: Mat' P2-36A 08/29108 NORDIC 1 CTD"A" 04/28/1E SWJM) FILL_ED PB VALVE(04/24i16) FEiair Nt-. 080220 06,27/06 Z PJC CR1G CRAFT CORREC1101,16 AFI 11k,: 50-029-22801-01 b8:727157415Jd"--riFtLG CRAFT CORR.ECTIONIS SEC 14, 11214,"OIL 273'FNL&1348'FW 02;16.11 ACIJIVU ALX3EDSSSVSAFETYNDT-E- 05/07/12 LEL/J(A) GLV CO(04(30/12) ____ BP Exploration(Alaska) I 4 II IP • 4-1 MT CfW .NAEI.HEAD- 11.AOC P2-36 Proposed P&A re NOTES;WO L RE94ARE!A SSSV WEI.I t:I.10'tal 1,4.556.' ***CRIRCIAL TOG&L.NR-- ACTUATOR= BAKER C — KB ELEV- 4755' BF BEV= 15.05' KOP= 1020' I C i:':•;•i,,,MieViiiWii:g 1.41x Angle= 99",1) 14751' 1.-.,-p:O.WRAWR: ,.II Cement plug #3 circulated down Datum ND- 14198' 4k4VONg412 li tubing, through tubing punches @ , DI71111 71 IVO. 8800' 0 7r,-cow/ix:T.0R, I mav,1440,III r-- ' fi 125' 1 500' MD and up IA to surface _ On LIT WHERE 5 13T 1.1) ,. DC/ TYPE VLV LATCH!FORT DA-.t. 9 518"CSG AN _8081C II-5.635' -- 7204" ,_ , ' 5504 4021 55 KBG-2-LS DOW INT 15 04:7.012 Minimum ID = 2.377" @ 14451' ....„. 2 1/2" X 2 VS" XO PIN Cement plug#2 circulated down ced12105 ,....., ,-...;.,. L .... ......„.. ' i tubing, through tubing punches 10/C1,787 0802111:6 above packer, and up IA lorci,97! ,;...:::•,:.:..,.4.:m:::::m 7"CSG,264,L-80 BUTT,ID=6 276* X0 TO 290, I 13570' i ASS:iMiN ' - OW 1240 13CR-80 MCCE-6.134MlHAS EXTRI3Ei PACKING 5' — NINOWD. Mi:1]:Nft x4 1 *".•-::::: ' — 13 2' i i ' S-..i H.4 t!. a Y.]I:•:•:.:.::::: : imi 94 _ _ II BM li, r MARKER ST{ISO 13005' r- Fill]i]i : ir.4 ---- 13975' - 4II '2.r IFS X Nr n-3 5 3- I .:•!,••'..:•::,••:..:••:',•••:.••1,••1,•••1,••••' :••••' ...... . Cement plug #1 pumped FB or laid uui,,, i sum mw/CT .•::::: : ••••••• .......:....:....::..:...,....:• .: ....... .:.:.:.:.:.:. : :•••....,.•.•••••••••••••••••••••••• •: ...... . 13893' -r X 5-1/Z'802 ZXP P10;ID=4.750* TOP OF 4 IT LNK -I 1 3991 , iii: i ----- 11.1)i' ''.:•;. ' 'On 130--iff-' 1-14-1t2" iht.EG,ID=1958" il ISO 128$,13CR NSCI 1- 13998 [------ , .: /Wr 1 3996' I Inman-t000m o ,93 0152 bpi,ID=3 9514- E:: iM ' 14007' I-4-FX 4 1/2'SKR HMC L,Ni -GR,l,)' .,. ,.....,,,,,.. ......N-sts Nbus..,, 14 t41 ::::::: . , — I Ai ar --13-lir HOT OFR OY sot ila,..'2 sir i .0371 bpf.ID.6 164. /g iii 1 FPS TINIA THTTOP Or Tr1=1,444-1 14186' V 111111111 14192' 1-14-112*f+S X NIP.,ID-3 813*(MIND PIPE) 14439' J-41/r tits X ri3.ID 2 3.81r memo PIPE) 14205' 3-IIT OTS XN PIP,ID=2.750" ..... . .. ..... 3-1+2-LNR 8.818.13CR80 Sit, 0087 bryt,ID 2 2 872" H 14451• ,! L14,451' 3-1 /...._j-i !2,zmarr I-. 77- IAIFD1A411PSTOCK(02028106) H 14493' Zji ;;*iiii -MILLOUTWINDOW(P2-350) 14495 14504. - IRA PIP TAG,- 14507' 4-1/2-HES CRP(0520102) ^^ 14547' 1 MED ..::..: 1-51-‘' -1141-64-41Ldil PERFORATIONSUMPARY REF LOG C7'LIGR/00_ON 03/26/06 • ..,,,,,, ANGLE AT TOP FIFE 91*41).150.50 Nate.Hetet to Produebon LB for hssLortci4 pert data SIZE SPF INTERVAL OpniSqz CIAM 12-T(8"LNR,6.58,13CR-80 SR XO TOL-80 511. 1 5491" 2" IF- 6 15050-15200 0 03/27/06 sit. itttii 2" 7 6 15250-15500 0 03127/06 2" ' 6 16100-16190 0 03/27/06 12-7/T LNR,5.54,L-80 STL,.0058 spr,Os 2.441' 10232* ----- DAM REV BY ' CONIVENtS GATE WV8Y--- ---------cakairmrs -----1 PONT NUM RE LOW 10102/97 06201NAL cam PLETION 02,103/1E GROILli 313 V_V UPDATE Plat STATE REG: VIEW P2 35A 08129008 NORDIC 1 CTO-A" 04126116 SWJM) FULLED PB VALVE(04/24116) P13;941-kr' 060220 062706 .N PJC CRL.G DRA.FTCOMEGTIONS AR ND: 50-029-22801-01 0822107 0NC/R1G-PARLG ORA Ff4044S SEC 14,112N,MAE 273'FM &1348'FAIL ? i&) ALiDEDSSSV SAFETY t'L)TE 05107`12 LECLIIi1E) GLV OC(041300121 BP Exploration(Alaska) 5 • • Cement Calculations OA fillup volume of Cement 204 Bbls Total cement to pump 225 Bbls Key Parameters Ppg: 15.8 ppg Class G — Mix on the fly Slurry Temperature: between 80° and 110°F API fluid loss: 40 - 200 cc Thickening Time: Minimum 4 hours Compressive Strength: 2000 psi in 24 —48 hours Cement thickening time: Mix on the fly Activity Time(hours) Shearing time, quality control, PJSM 0 Cement displacement 2 Cement contamination 0 Safety 2 Minimum required thickening time: 4 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 65 0 2:00 65 0 5:30 52 0 10:00 46 0 16:30 42 0 24:00 39 0 Volumes: top volume MD bot MD Size ID bbls/ft. Ft. bbls 9-5/8"40#x 8.835" 9-5/8" x 7" annulus 0 7204' 7" 26# x 7" 0.0282 7204' 204 7" 26#x 4- 6.184" 7"x 4-1/2" annulus 0 13,942' 1/2" 12.6# x 4.5" 0.0175 13,942' 244 6 _ • Fullbore/S•ecial Pro-ects • 1. Have a vac truck rigged up on location to vac fluids from conductor/cellar during the job. Note: No personnel should enter the wellhouse during the injectivity test due to the known leak from the conductor. 2. RU LRS to OA. 3, Using diesel, fill up OA and pressure up the OA until it starts taking fluid and the shoe is broken down. Max OA pressure is 3000 psi. Record the injectivity rate and pressure after the shoe breaks down. Target 3-5 bpm if attainable. Vac out the conductor continuously during the pumping job to ensure all fluids remain in containment. Note: A LOT (Leak-Off-Test) on this shoe was performed by the rig with the result of injection established @ 1150 psi w/ 9.1 ppg drilling mud @ 4950' TVD. Subsequently the OA was Freeze-Protected with 112 bbls of Diesel at an injection pressure of 1950 psi @ 2 bpm. This equates to -4000' MD of Diesel in the OA. However, Drilling Mud remaining in the OA after the FP (below the diesel) has likely settled and may make injection into the shoe impossible. Slickline 1. Pull DGLV from Station #2 @ 8236' MD and run Circulation Sleeve @ same. 7 Fullbore Cement 1. Have a vac truck rigged up on location to vac fluids from conductor during the job. Note: No personnel should enter the wellhouse during the injectivity test due to the known leak from the conductor during pumping. 2. RU LRS to the IA. Pump 130 bbls of hot (180F) crude down the IA through to heat the wellbore prior to the cement squeeze. Max pressure 2500 psi. 3. RU Cementers to the OA. RU in such a way that the OA can be closed in and wash up water diverted upstream of the OA. Mix cement on the fly. Pump the following schedule at maximum rate below 2500 psi treating pressure. ➢ 10 bbls neat MEOH • 100 bbls hot (180 deg) freshwater + surfactant; 2 gal/bbl Surfactant and 2 gal/bbl Mutual Solvent ➢ 10 bbls of 13.5 ppg Spacer ➢ 10 bbls of neat cement ➢ 50 bbls of cement with 15-ppb aggregate/pressure-seal ➢ 165 bbls of neat cement No displacement behind cement. Slow rate to -1 bpm as aggregate gets to the casing shoe. (OA volume is -204 bbls, aggregate will be at the shoe @ 214 bbls total cement away/10 bbls left to pump). Swap to take returns from upstream of the OA while still on cement (S/D pumping as needed), and as the last couple of barrels are pumped (3-5 bbls left to pump). Ensure that returns are swapped to taking cement returns to surface before the last of the cement is pumped downhole to ensure nothing but cement goes down the OA. SI the OA and flush lines through a different route than down the OA. Note that the OA may be on a vacuum and may suck any wash up water that is pumped across the OA down into the OA if allowed to do so and would likely freeze and crush the casing and/or tubing (thus swapping and SI OA before wash up water). 4. After washing up surface lines, hold open bleed on OA for 1 hour, sniff for LEL's, then ND gate valve and manually clean any residual cement from the valve and VR profile. (See MOC #10083 for specific deviation details allowing for this operation). 5. Grease the OA gate valve to clear of all cement & NU valve. DHD 1. Wait on Cement -3 days. 2. Shoot fluid level on OA to locate TOC. 3. If fluid level is "near surface" then strap TOC to verify actual depth. 8 S•ecial Pro'ectsNalve Sho. 1. ND OA Gate Valve, strap TOC. 2. NU OA Integral. 3. Bleed Annuli, Prep OA, Squeezecrete OA top job to 2500 psi per RP: "Small volume cement squeeze". DHD 4. WOC for 7 days. MITOA to 1200 psi. Slickline 1. Run Generic GLV design. Well Integrity Coordinator 1. POP under evaluation and monitor conductor and cellar for any fluid leakage. 9 STATE OF ALASKA ()ALASKA OIL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Conductor Top Cmt Job m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-022 3. Address: P.O.Box 196612 Anchorage, Development I1 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22801-01-00 7. Property Designation(Lease Number): ADL 0034627 8. Well Name and Number: PTM P2-36A 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: RECEI VED Total Depth: measured 16272 feet Plugs measured feet true vertical 9034 feet Junk measured feet J U L 2 5 2016 Effective Depth: measured 16196 feet Packer measured 13942 feet true vertical 9045 feet Packer true vertical 8697 feet ``VV[ ' CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"133#H-40 35-115 35-115 3060 1500 Surface 7170 9-5/8"40#L-80 34-7204 34-4968 5750 3090 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 15050-15200 feet 15250-15500 feet 16100-16190 feet True vertical depth: 9032-9032 feet feet 9032-9038 feet 9054-9045 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 30-13998 30-8729 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 13942 8697 true vertical depth) 4-1/2"K Valve 2227 2104 12.Stimulation or cement squeeze summary: Intervals treated(measured): At Surface,Around Conductor. Treatment descriptions including volumes used and final pressure: SCANNED `�'rN 1 , 12 Gallons Neat Class G Cement,Atmospheric Pressure. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 224 138 520 2102 1236 Subsequent to operation: Shut-In 0 0 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 RI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 7/21/16 � /i� v JUL 2 6 2016 RBDMS v Form 10-404 Revised 5/2015 7(4 0 /3/// fj Submit Original Only • • QooQOO 0 all O O) N O O IS o v O LO ) G r- co tip C) y o o o o o O *- (13 L CO Cr) Cr) = 0N- CV ,- •4- co 0N- N ,- •m M Ln � 00 CO CO Lo 00 Cr) N CA CO CO 1- N O) O) CO O 0) 1— •crCC) COO) oocO CI O 1- CO O L CO 00 N CO Cr) r- CO co co co co co C O N CO 00 O In st O) Mr Mr Mr Cf) CO Q II .40= M LOcy, V Mr- cnco° o (V MMMT = a .0 0 o O coco U 4* lisk ---1 CO *k 4* # .N N co • N LO ~ r-- N (V N 1 O)0 Oa M N CC) d O d CO M N- 0 CO O) L0 LO N CO J � W W CO - - .NUVww 22 UDIQi_ Cer c n z z o w w w w m 0 z zz J J • • .. ._< £ 2 & / & % R \ R $ > o c > - % � / 'c � k c ca (U o . \ (9 e" ° J k oag p77 © 2 $ co 7 o Sc ° _j o : k 7 ° « / e To o c o �� co f o00 / fes k22 « a � ® c °E co J § C0 m� _2 © o as 0 k 0 C ¥ e o $ E q § m ra ± 5 m 2 S 2 2 E o a k § c E \ k / F- O Q / / b k ( ( 0 _2 N = cm o / / 0 1.1 k a 2 A-.2oes c , r o I , / ( / . � » \ • o O $ . L- 0mc2 < = CJ �2 ƒ d >. E 2 SERF ii 12 S E I c § > E as o _ 0 Q o 3 6 / 2 ® a o_ $ E d do ° O Q G = o ° ° c 0-> « § o �� � k . ¥ 2 � > a a ? > 2 o R m a) q g o co -c 2 ii .F; @ < cc i, c - -0 c / �4- 0W0c = ° / / k / /§ / / 3 / d L < co o - \ / / 2 > h \ P 6 6 < TREE= 4-1116"CNV11110 SA NOTES:WELL REQUIRES A SSSV. WELL ACTUATOR= 11' C ACTUATOR= BAKERRC P2-361k ANGLE>70°0 14556%""'CHROME TBG&LNW*" KB.ELEV= 47.55' , BF.ELEV= 15.05' I I KOP= 1020' Max Angle= 99°@ 14751' a D---{ 2097 9-5/8"HES ES CEMENTER Datum MD= 14198' Datum TVD= 8800'SS 2227' _44-1/2"CA MCO BAL-O SSSVN,D=3.813" 20"CONDUCTOR,133#,H-40,D=? 125' 2227' 4-112"PB VALVE INSTALLED 10/18/14 GAS LFT MANDRELS ST MD TVD DEV TY FE VLV LATCH PORT DATE 9-5/8'CSG,40#,L-80 BTC,D=8.635" H 7204' -41 1 5504 4021 55 KBG-2-LS DMV IVT 0 05/31/16 Minimum ID = 2.377" @ 14461' 2 8236 5517 57 KBG-2-LS DMY NT 0 05/31/16 3-1/2" X 2-7/8" XO PIN I '1 3 9701 6309 57 KBG-2-LS MONY INT 0 08/12/05 4 10796 6920 56 KBG-2-LS DMY NT 0 10/01/97 / 5 11679 7417 55 KBG-2-LS DMY NT 0 05/31/16 / 6 13067 8210 58 KBG-2-LS DMY NT 0 10/01/97 7"CSG,26#,L-80 BUTT,D=6.276" XO TO 29#, H 13570' 7 13915 8681 55 KBG-2-LS "DMV INT 0 08/12/05 13CR-80 NSCC,I)=6.184" "'DMV HAS EXTB+DED PACKING 7'MARKER JT (19') —{ 13805' g X 13942' H7"X 4-1/2"BKR S-3 PKR,D=3.875" 13975' -±4..-1/2"FES X NP,ID=3.813" ' ' 13986' H4-1/2"HES X NP,ID=3.813" TOP OF 4-112"LNR — 13993' 13993' {—7"X 5-1/2"BKR 2XP PKR,D=4.760" v, 13998' H4-1/2" WLEG,D=3.958" 4-1/2"TBG,12.6#,13C R NSCT--I 13998' 13995' H ELMD TT LOGO 09/25/98 .0152 bpf,ID=3.958" 14007' H 7"X 4-1/2"BKR HMC LNR HGR,D=3.938" 7"CSG,29#,13CR-80 NSCC, —{ 14142' {--A I .0371 bpf,D=6.184" ' 14187' —13-1/2"BOT DEPLOY SLV,D=2.972" 1 ESTIMATE)TOP OF CEMENT H 14186' 1 14192' H4-112"HES X NP,D=3.813"(BEHIND PIPE) 14439' --I4-1/2'HES X NP,D=3.813"(BEHIND PIPE) 1. 4 r 14205' H3-1/2"OTIS XN NP,D=2.750" 4 r 3-1/2"LNR,8.81#,13CR-80 STL,.0087 bpf,D=2.972" —1 14451' 4t 14451' {3-112"X 2-718"XO,D=2.377" • FD M-$PSTOCK(02/28/06) — 14493' fi 1A/FD MLLOUT Mk/DOW(P2-36A) 14498'-14504' RA PP TAG H 1450T -� •♦♦♦♦•♦1 4-1/2"FES CBP(05/20/02) H 14547' --i-i!i ❑ 16195' HPBTD(ML.LED) PERFORATION SUNfvfARY Att.A'A REF LOG: CNUGR/CCL ON 03/26/06 •'•A� ANGLE ATTOP PEW 91°@ 15050' 44114414. Note:Refer to Production OB for historical perf data SIZE SPF NTERVAL Opn/Sqz DATE 2-7/8"LNR,6.5#,13CR-80 STL XO TO L-80 STL 15491' 2" 6 15050-15200 0 03/27/06 ro.�" 2" r 6 15250-15500 0 03/27/06 �!Q iso" 2" ' 6 16100-16190 0 03/27/06 2-7/8"LNR,6.5#,L-80 STL,.0058 bpf,ID=2.441" — 16232' DATE FEV BY COMMENTS DATE REV BY COP &NTS PONT MCNTY RE UNIT 10/02/97 ORIGINAL COMPLETION 02/03/16 GRC/TLH PB VLV UFDATE PER STATE REG; WELL: P2-36A 06/29/06 NORDIC 1 CTD"A" 06/01/16 MSS/JMD GLV GO(05/31/16) PERMT No ' 060220 06/27/06 ?/PJC DRLG DRAFT CORRECTIONS API No: 50-029-22801-01 08/22/07 DMS/PJC DRLG DRAFT CORRECTIONS SEC 14,T12N,R14E 273'FNL&1348'FW_, 02/18/11 MB/JMD ADDED SSSV SAFELY NOTE 05/07/12 LEC/JMD GLV C/O(04/30/12) BP Exploration(Alaska) STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMA/IL ` REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate `❑ / Alter Casing 0 Change Approved Program 0 Plug for Redrill CI Perforate New Pool 0 Repair Well b! Re-enter Susp Well 0 Other: PB-Valve Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-022 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-22801-01-00 7. Property Designation(Lease Number): ADL 0034627 8. Well Name and Number: PTM P2-36A 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 16272 feet Plugs measuredfeet RECEIVED true vertical 9034 feet Junk measured feet FEB �p 6 2015 Effective Depth: measured 16196 feet Packer measured 13942 feet 2 true vertical 9045 feet Packer true vertical 8697 feet G Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"133#H-40 35-115 35-115 3060 1500 Surface 7170 9-5/8"40#L-80 34-7204 34-4968 5750 3090 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 15050-15200 feet 15250-15500 feet 16100-16190 feet True vertical depth: 9032-9032 feet feet 9032-9038 feet 9054-9045 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 30-13998 30-8729 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 13942 8697 true vertical depth) 4-1/2"K Valve 2227 2104 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: :Sr 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 87 0 1613 2237 758 Subsequent to operation: 333 215 1159 2204 900 14.Attachments:(required per 20 AAC 25.070.25.071,8 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 ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-094 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron, Garry R(Wipro) Title PDC Principal Engineer Signature 0504,r1_ Phone +1 907 564 4424 Date 2/26/16 Form 10-404 Revised 5/2015 rr'' 3/11 // G RBDMS u u FEB 2 9 24161 rt Original Only • • fl,00000 O mOO - O O C M in NN r N V (OLO CDM cc) 7 O N N r- m CO CO Ps 00 CO 00 Lo 00 N- M N Q) CD CO — CV O CV r O CP CO O O N- V* 00 00 0 00 CO O Is CO O 1.0 CO 00 N M CO Tt CO CO 00000000 CO p N- _- OCNI CO LC) N M I I o o a ° u, ,rMr- CD00o �N 1.0 1.0 M M MMM [t M C a O0 O a o U � U) oC° CCOUUU 00 CO M Cr) V- 0) 4t ,4# JM *k4* *k .N N M - CD CO N om _ N N co N V _ � co NLi' N fV dM 4 p)O M N In CD J co LO O co O � N W W Q Q C0 0VaWw O O L W E O Z Z c W W W W OSI 1ZZ , UCO ZZJJF- • • CO J w N �U D N C a _I co 0 co 2 Cl) to - Cl) O c) D a 15 co I. 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WELL WELL__._ __.. __ .__._ P2-36A ANGLE>70° 14556'."**CHROMETBG&LNR'"" +ACTUATOR= BAKERC KB.REV= 47.55' BF.ELEV= 15.05' I I KOP 1020' Max Angle= 99°C 14751' a D--1 2092' 9-5/8"HES ES CEMENTER Datum MD= 14198' Datum1VD= 8800'SS 2227' 4-1/2'CAMCO BAL-O SSSVN,D=3.813" 20"CONDUCTOR,133#,H-40,D=? ® 0 ..----------L.L...._227' 4-1/7 PB VALVE INSTALLED 10/18/14 GAS LFT MANS Al ST NO TVD DEV TYPE VLV LATCH PORT DATE 9-518"CSG,40#,L-80 BTC,D=8.835" H 7204' 1 5504 4021 55 KBG-2-LS DOME NT 16 04/30/12 Minimum ID = 2.377" @ 14461' 2 8236 5517 57 KBG-2-LS DOME NT 16 08/21/05 3-1/2" X 2-7/$" XO PIN I '1 3 9701 6309 57 KBG-2-LS **DMY NT 0 08/12/05 4 10796 6920 56 KBG-2-LS DMY NT' 0 10/01/97 / 5 11679 7417 55 KBG-2-LS SO NT 20 08/21/05 / 6 13067 8210 58 KBG-2-LS DMY NT 0 10101/97 7'CSG,26#,L-80 BUTT,13=6.276" XO TO 29#, H 13570' J 7 13915 8681 55 KBG-2-LS *"DMY NT 0 08/12/05 13CR-80 NSCC,0=6.184" **DMY HAS EXTENDED PACKING 7"MARKER JT (19') — 13805' Z X 13942' ...--17*X 4-1/7 BKR S-3 PKR,D=3.875" I , 13975' --14-1/2"I ICS X NP,D=3.813" I I 13986' —14-1/2"HES X NP,D=3.813" 13993' j--7'X 5-1/2"BKR ZXP PKR,0=4.760" TOP OF 4-1/2"LNR H 13993' 1--- 13998' —14-1/7 WLEG,D=3.958' 4-1/2"TBG,12.6#,13CR NSCTH 13998' 13995' -HMD TT LOGGED 09/25/98 .0152 bpf,0=3.958' 14007' H T"X 4-1/2"BKR HMC LNR HGR,0=3.938" 7'CSG,29#,13CR-80 NSCC, — 14142' 1-4 111. 0371 bpf,D=6.184" i, 14187' -1 3-1/2"BOT DEPLOY SLV,D=2.972" C ► ESTE)TOP OF CEt(4RrT H 14186' 14192' H4-1/2"HES X NP,0=3.813"(BEHIND PIPES ► 14439' H4-1/2"HIPS X NP,0=3.813"(BEHIND PIPE) ►� ; 14205' —13-1/2'OTIS XN NP,D=2.750" 4 -► 4 ► 0 ► 3-1/2"LM1MZ 8.81#,13CR-80 STL,.0087bP f,D=2.972" H 14451' 4 C 14451' --13-1/2"X 2-718"XO,D=2.377" WFD W PSTOCK(02/28/06) 14493' `, MLLOUT WINDOW(P2-36A) 14498'-14504' RA PP TAG 1450T , ' V•.V.4-1/2"HES CEP(05/20/02) —1 1454T 'iimi-a. 1 16195' -�PBTD(MLLE)) FERFORATTON SUMMARY l'Atee• REF LOG: CNUGR/CCL ON 03/26/06 ANGLE AT TOP PERF: 91"@ 15050' Note:Refer to Production DB for historical pert data SIZE SFF NTER1/AL Opn/Sgz DATE a ♦ 2-7/8'LNR,6.5#,13CR-80 STL XO TO L-80 STL 15491' .. 2" 6 15050-15200 0 03/27/06 iO*. WOOL* 2" r 6 15250-15500 0 03/27/06 Al 2" r 6 16100-16190 0 03/27/06 2-7/8"LIR,6.5#,L-80 STL,.0058 bpf,D=2.441" — 16232' 1 DATE REV BY COMA/NTS DATE REV BY COMENTS PONT MC'1TYREUNIT 10/02/97 ORDINAL COMPLETION 02/03/16 GRCJTLH PB VLV UPDATE PER STATE REG WELL: F2-36A 06/29/06 NORDIC 1 CTD"A" FERMI No:"2060220 06/27/06 ?/PJC DRLG DRAFT CORRECTIONS AR No: 50-029-22801-01 08/22/07 DMS/PJC DRLG DRAFT CORRECTIONS SEC 14,T12N,R14E 273'FNL&1348'FVVL, 02/18/11 MB/JM) ADDED SSSV SAFETY NOTE 05/07/12 LEC/JM) GLV C/O(04/30/12) BP Exploration(Alaska) • OF Tb • 4 y � � s., THE STATE Alaska Oil and Gas - =d ='a ofLASI�;A Conservation Commission -� � A 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Vir-"' Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Ryan Daniel Alaska Wells Integrity and Compliance Team Leader BP Exploration(Alaska), Inc. P.O. Box 196612 __ _._., ._.. .. ,... , . Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PTM P2-36A Permit to Drill Number: 206-022 Sundry Number: 316-094 SCANNED MAR 0 3 2016 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, Cathy . Foerster Chair DATED this GD day of February, 2016. RBDMS LL- FEB 2 5 2016 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate El Pull Tabing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well El Alter Casing 0 Other PB-Valve Design Q - 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 206-022 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development Q. 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22801-01-00 - 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 P2-36A • qF;(' N ior C r 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0034627 ° PRUDHOE BAY,PT MCINTYRE OIL Y'1''''S 2_12;111xa 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 16272 ` 9034 • 16196 9045 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"133#H-40 35-115 35-115 3060 1500 Surface 7170 9-5/8"40#L-80 34-7204 34-4968 5750 3090 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 30-13998 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 13942, 8696.60 4-1/2"K Valve 2227, 2103.60 12.Attachments: Proposal Summary Q Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ 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 El WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 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 approval. Email Ryan.Daniel@bp.com Printed Name Daniel,Ryan , Title Alaska Wells Integrity&Compliance Team Leader Signature / Phone +1 907 564 5430 Date �/ ,-/ G/L 2 /6 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3‘t - o9z{ Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes El No ❑ Spacing Exception Required? Yes Yes❑ No E II' Subsequent Form Required: 10— 404 CPPROVD NYTHE Approved by: COMMISSIONER COMMISSION Date: Z .23_,/ C RI G I N A L RBDMSFES 2 5 2016 t•-\3131 Z I Y A Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. 111 '�, Attachments in Duplicate - il� , •%5,, Z--i- /4 • • 0.0 O O O O O O C) �o O �t opoo) O M CC) ti U y 0 0 0 0 0 O I.. CO to ct CO M M O f� N NY m co Lc) N co co cc oo f— co N st O) 03 d' CO O 00) (NI V co o0 6) 0o co 1 1 1 1 1 1 H Uo (000CV V CD M CO 4 •,:t N- CO CO CO CO CO CO cv co coC Lo V V O Cl) O E r � c� rrr C.) o (Q Q * I I (0 Lov. c � rncco Cr) s- - co CAN M M M r M C r — r 1' OOO moo- OO 0rco 5 OCo co U co = J 00 U co N N M Cl) osi CV M U _ _ N d ~ N N N N M 4' 0 O CI)O 0 M N Co et CO C 00 - N- 0 CO C3) In N CO J W Q Q NoUoo O 0 u_ CKf n a Z ZUJWWW 0 F Z Z_ 0 fn Z Z J J �-- • m• lC) M � (NJ O NI- 0. N O LO y co co NY O 0 0 co 0) O O H Q. 0 N N- CO r N- CO O O. M 0 LLI • O O O O co cm rn 0 � 0 O 0 Z w w O w 0 H I- 5 < w gQ a 0 o' 0 0 Y Y CD cn WU U CN 2 = _0 _0 _0 LU W C7 -1 O a) N r Z Z Z0 0 0 0 = 0 0 4. W 0- 0 0 0 waro Z O Z V 2 2 2 0 (0 (1) (0 rn 0)i co CD 4-1 M Q 0.I 2 a- = s CD CD CD Lo o o E a) CD (N ++ O L() Lt) (O cca � O 2 CC u) Y = 0 0 C/ ) `2 2 2 O co cn (1) 0) 0) d a 0 0 c .2 aa' a co W W W ;, aaa a 0 C, m m I- ia CO CO CO : -9 0 0 0 0 D D c O O O LU _j Z O N N N Z 1E12 a 0_ < W W 0 W JJ 0 JJ J W O W N N N LL Z a .9 J .9 0 J-J W W LL W O M M < 0 r 0 W J J 0 D 0: Q. Q 0 W w Q Q m 0_ m (n LL IL 4 LL U) 0_ CC N E t0 co co co LL 0_ (1) O LL N Q' LL N 0_ a a ¢ m m � U- � o • 10 6/6/01 Alt Loft 17,, Wireline Work pow Request P2-36 (Distribution Wireline(4) Well: P2-36 AFE: APBWEINSL Reading File Date: 6/28/2012 Engineer: Kenda IOR: 400 FTS: AWGRS Job Scope: SSSV H2S Level: Problem Description According to AOGCC regulations a subsurface safety valve needs to be installed in this well.A Weatherford PB safety valve will be used. NOTE: Pressures were recorded by gauge at FTP of 901 psii. Valve calculations were based on these pressures. Initial Problem Review Remi edial Plan -WIRELINE ACTION AM -"' Pad Operator Info Operate well at>840 psi FTP Valve designed to close when FTP drops to 840 psi. Shop use only: PB SSSV set to close at 1215 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: • • • "PB"Valve Calculation Sheet Well# P2-36 Date: 06/28/12 Test Data Test Date 06/25/12 Gross Fluid Rate 1619 BLPD Flowing Well Head Pressure 901 psi Flowing Well Head Temperature 96 deg F GOR 208 scf/bbl TGLR 1317 scf/bbl Setting pressures based on measured data taken at time of test. Flowing Pressure Calculations Based on Muk -Brill Multiphase Flow Correlation "PB"Valve Setting Depth TVD 2104 ft Flowing WHP 840 psi Flowing Pressure © SSSV 1350 psi Flowing Temp @ SSSV 109 Deg. Valve set to close at 840# Pwh Valve set to close at 1340 psi @ depth 1340 psi PB"Valve Test Rack Set Pressure at 60 deg F I 1213 'psi NOTE: Well needs to flow at> 450# Pwh Valve set to close at 225# Pwh • • Tubing Pressure at Valve 1350 BPT(psia) 1364 >1238 <1238 Temperature(deg F)at Valves, 109 I a 9.016E-06 1.49646E-05 1 b 1.112602 1.094766 Base Pressure 1246.90334 c -1377.483 -1364.51074 Base Temp (TV-60) 49 1225.8953 1225.853899 Corrected Pressure 1225.89532 psia TCF 0.89848675 • /olume Ratio for Valve Size = 1.257 Pb @ 60 = 1212.95711 Test Rack Pressure = 965 Volume Ratios_ 4 1/2" & 5 1/2" 1.314 3 1/2" 1.257 2 7/8" 1.211 2 3/8" 1.204f TREE= 4-1/16'aw • WELLI-EAD= 11'FARC I� NOTES:WELL REQUIRES A SSSV. WELL ACTUATOR= BAKERC P2-36A ANGLE>70'ett14556'."'CHROMETBG&LNR"' KB.BLE/= 47.55' BF.f3 EV= 15.05' I I KOP= 1020' Max Angle= 99'@ 14751' a D--1 2(192' 9-5/8'I ES ES CEMENTER Dation140= 14198' Datum TVD= 8800'SS 2227' 4-1/2'CAMCO BAL-O SSSVN,D=3.813' 20"CONDUCTOR 133#,1+40,D=? MM. • �' 2227' _4-1/2'PB VALVE INSTALLED 10/18/14 GAS LET MANDRELS ST M) TVD DEV TYPE VLV LATCH PORT DATE 9-5/8'CSG,404,L-80 BTC,D=8.835" H 7204' H1 1 5504 4021 55 KBG-2-LS DOLE NT 16 04/30/12 Minimum ID = 2.377" @ 144451' 2 8236 5517 57 KEG-2-LS DOME NT 16 08/21/05 3-1/2" X 2-7/8" XO PIN I i 3 9701 6309 57 KBG-2-LS **ENV INT 0 08/12/05 4 10796 6920 56 KBG-2-LS [MY NT 0 10/01/97 \ / 5 11679 7417 55 R03Cr2 LS SO NT 20 08/21/05 / 6 13067 8210 58 K8G2-LS DMY NT 0 10/01/97 7"CSG,26#,L-80 BUTT,D=8.276' XO TO 294, 13570' 7 13915 8681 55 KBG-2-LS "IJ�AY NT 0 08/12/05 13CR-80 NSCC,D=6.184' "DMY HAS EXTENDED PACKING 7'MARKER JT (191 13805' /2 X 13942' —r X 4-12"BKR S-3 P1C11ti D=3.875' - ,--I 13975' —4-1/2'FES X NP,E)=3.813' 13986' H4-12-FEES XNP,D=3.813" 13993' H7'X 5-1/2"BKR ZXP PKR,D=4.760' TOP OF 4-12"LNR — 13993' ' - 18 13998' (—4-12WD " LEG, =3.958" 4-1/2'113G, 12.6#,13CR NSCT 13998' 13995' }—B_MD TT LOGO 09/25/98 0152 bpi,D=3.958' 14007' I--7"X 4-12'BKR HMC LNR HGR,D=3.938' 7'CSG,29#,13CR-811 NSCC, —1 14142' , 0371 bpf,0=6.184' ► 14187' —3-12'BOT DEPLOY SLV,D=2.972' P ► ESTIMATED TOP OF CEMENT —1 14186' ' 14192' �4 1/2'HES X NP,0=3.813"(BEHIND PIPE) ►� ► 14439' H4-1/2"HES X NP,D=3.813'(BEHIND PIPE) ► p ►, ► p . 14206' H3-12.OTISXN NP,D=2.750- I 0 ► ►. ► 3-12'LW,8.81#,13CR-80 STL,.0087 bpf,D=2.972' H 14451' C 14451' H3-12-X 2-7/8'XO,D=2.377' WFDW-IPSTOCK(0228/06) -I 14493' 0.74-.-` ML LOUT IN DOW(P2-36A) 14498'-14504' RA PP TAG 1450T ►..,♦ 4-1/2'HES CEP(05/20/02) --{ 14547' --�•7--- PERFOR A TDN SUMMARY 16185' —MID(MLLE)) ►�1 ��, REF LOG: CNJGR/CCL ON 03126/08 •••'• ANGLEo TOP nERF: 91" 15050" Rite:Refer to Production DB for historical roal pert data SIZE SPF INTERVAL Opn/Sgz DATE 2-7/8'LNR,6.54,13CR-80 SR XO TO L-80 SR 15491' 2' 6 15050- 15200 0 03/27/06 ; ;, 2' ' 6 15250-15500 0 03/27/06 ••;.p 2' ' 6 16100- 16190 0 03/27/06 2-7/8"LW,6.54,L-80 SR,.0058 bpf,D=2.441" I— 16232' DATE REV BY COMIANTS DATE REV BY (X*UNTS FONT MC/GYRE RE LIrIT 10/02/97 i ORIGINAL COMPLETION 02/03/16 GRCJTLH PB VLV LI TE F@R STATE REGE WELL: P2-36A 06/29/06 NORDIC 1 CTD"A" PART No:'2060220 0627/06 ?/PJC DRLG DRAFT CORRECTSAR No: 50-029-22801-01 0822/07 DMS/PJC DRLG DRAFT CORRECTIONS SEC 14,T12N,R14E 273'FrL&1348'FWL, 02/18/11 AB/JM) ADD®SSSV SAFETY NOTE 05/07/12 LEC/JAAD GLV C/O(04/30/12) _ BP Exploration(Alaska) •(- z- P2 602-7o Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, February 16, 2016 4:10 PM 'Q6.):7 ?l/6 t lto To: Regg,James B (DOA) Cc: AK, OPS FF Well Ops Comp Rep;AK, D&C Well Integrity Coordinator;Igbokwe, Chidiebere; Gerik, Bob G;AK, OPS Gas Lift Engr Subject: Producer P2-36A (PTD#2060220) PB Valve Changed Out Jim, This email is to serve as a notice that Producer P2-36A(PTD#2060220) downhole PB valve was changed out on February 11, 2016. As the location and the dome pressure remained the same (1,215 psi), no sundry will be filed with the AOGCC. This notification is in line with 20 AAC 25.265 and Industry Guidance Bulletin 06-04. Please call with any questions. Thank you, Laurie Climer SCANNED SEP. 2 3 2016 HII!ta in for If'hitnev 1't'ltt,0 BP Alaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 MINED AUG t LUli Mr. Jim Regg Alaska Oil and Gas Conservation Commission a06 ,0?„?- �} 333 West 7 Avenue 3 �jr' Anchorage, Alaska 99501 /V�` 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, 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 - -+1P2 -36A 2060220 50029228010100 1.1 NA 1.1 NA 6.00 6/9/2009 P2 -37A 2050570 50029225760100 2.0 NA 2.0 NA 23.00 6/9/2009 P2 -39 2111230 50029234540000 0.8 NA 0.8 NA 10.20 4/30/2012 P2 -40 1972260 50029228370000 0.5 NA 0.5 NA 5.10 6/9/2009 P2 -41 1952050 50029226330000 1.5 NA 1.5 NA 17.00 6/9/2009 P2-42 1931430 50029224050000 19.3 NA 19.3 NA 121.60 6/20/2009 P2 -43 2050240 50029232500000 0.8 NA 0.8 NA 6.00 6/8/2009 P2 -44 1960630 50029226660000 2.3 NA 2.3 NA 23.80 6/8/2009 P2 -45B 2080210 50029227690200 0.8 NA 0.8 NA 5.10 6/8/2009 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 g ~ ~ ~ , .° ~. ~~ ~. ~t ~ `-~.. Mr ty~~4' ~ ~ ~ DO NOT PLACE ANY NEW MATERIAL UIV~DER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc MICROFILMED 6/30/2010 • • Regg, James B(DOA) u~ ~~- v~2 From: Regg, James B(DOA) `~~~ A! ~~ ~d~ Sent: Monday, November 09, 2009 10:54 AM To: GPB, Ops Supt Cc: DOA AOGCC Prudhoe Bay Subject: RE: RE: P2-36A SSSV Testing, Failures & Clarification Request Attachments: SVSFailurePolicy.pdf Refer to Item 3 of our Failure policy (attached); P2-36A needs to remain shut in until the SSSV is repaired/replaced and passes a retest. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 SVSFaiI urePolicy. pd f (182 KB) t~'i.Y~~ti~t~z~~ ~~~`: ~- ~' G~U~ From: GPB, Ops Supt [mailto:GPBOqsSuptCQ)bq.com] Sent: Wednesday, October 28, 2009 9:44 AM To: Regg, ]ames B (DOA) Cc: GPB, LPC DS Ops Lead; GP6, Ops Supt; Fleckenstein, Robert J(DOA) Subject: RE: P2-36A SSSV Testing, Failures & Clarification Request Jim, We are seeking some clarifications from AOGCC regarding PBU Well P2-36A. We have seen a series of failures on the SSSV (K-valve). Below is a timeline of the events. Timeline: 10/10/09: PBU Well P2-36A was Routine tested, during which the SSSV (K-valve) failed to close (failure code 8). The remaining components (LPS and SSV) passed. The ADW team was notified to replace the K-valve. The well remained online per allowance within AOGCC regs. 10/24/09: ADW pulled the existing K-valve and replaced with a different K-valve. The well was left SI by ADW upon their departure from location. 10/25/09: PBU Well P2-36A was brought online by Ops, post K-valve replacement, and allowed to stabilize its production characteristics. 10/27/09: PBU Well P2-36A was Re-Tested, during which the recently replaced SSSV failed to close (failure code 8). The other components were not re-tested. Ops SI the well after the failed retest, and that is the current status of the well. BP is seeking clarification/guidance from AOGCC on whether or not PBU Well P2-36A should remain SI or can be put online until a new/different K-valve can be installed and re-tested - within the prescribed 14 day window. The main question we have is whether the corrective action attempt, i.e. replacing the SSSV that failed on 10/10/09 with a different K-valve essentially "resets" the 14 day period to take subsequent corrective action after the 10/27/09 failed Retest? Please contact me with any questions, or if additional clarification is needed. Again, the current status of PBU Well P2-36A is SHUT-IN. Regards, Travis M. Rybicki (Joel Krueger) GPB Ops Superintendent NS Office 907-659-5224 Cell 907-748-2118 Harmony #860 or 907-758-0860 EOA Pager 907-659-5100 # 1283 GPBOpsSupt a(~.bp.com ~ ~ • ' ~'' ~AKER Mus~~s ~ C;UMYt1N Y WELL NA1vIE FIELD • ~a~~~- A~ia~ PRINT DISTRIBUTION LIS'I' t3Y ~;XYLUfZAl1UN (ALASKA) 1NC C(JUN'fY NUKTH SLUYr; t3UKUU(iH P2-36A STATE ALASKA POINT MCINTYRE DATE 7/23/2009 THIS DISTRIBliTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 1100529 Copies of Copia Digital Copia of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MP.IVAOIS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE AK 99508 .4hICHORAGE AK 99501 1 Company EXXON MOBII, PRODUCTION 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 MAHNKEN Person Address 333 W. 7TH AVE Address SLJITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 1701 ~ Aldine Wesffield. Houston, Texas 77073 This Distribution List Comqleted Bv: '~~ ~~~ ~^';~~`~n: e~~`s~ ta~ ~', ~J 1 t' L. ~1.fv Page 1 of I • u I1~T'TE Lo~ ata ~ra s ittal For ~r~: s~~~~ o~ ~~~~~~ -~o~~~ 333 Wo 7`h Avem Suite 100 Anchorage, Alaska 99501 Attention: Christane Mahnken Reference: P2-36A ;_ . , _ , _ _ . _ , ~.~ ~ E, ,;~~ Contains the following: `~ ~~~ •° `~~~ ~ ~a t~~~r~ ~~~ 1 LDWG Compact Disc ' (Includes Graphic Image files) 1 LDWG lister summary ' 1 color print - GR Directional Measured Depth Log (to follow) i 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) ` Corrected files. This Data replaces all previously delivered digital data. ! LAC Job#: 1100529 Sent by: Catrina Guidry a Date: 07/23/~' _~ Received by: ~ Date: ~ ,- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY ~~ _~~ FAX: (907) 267-6623 ~~~5~ Baker Hughes INTEQ ~~` 7260 Homer Drive - ~~~ Anchorage, Alaska 99518 ;n ~ Direct: (907) 267-6612 ~~~~~ FAX: (907) 267-6623 06/04/08 • i ~hlam~er~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth i~,~p JUN ~ ~ 2DO8 NO. 4736 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Woll Inh ~ L-220 11975963 CH EDIT PDC GR (USIT) / 04/22/08 V VIVI VV 1 L-221 11962592 CH EDIT PDC GR (USIT) ~' 04/07/08 1 V-223 40016679 OH MWD/LWD EDIT 03/20/08 2 1 W-30 12034892 RST ~ -( ~/ 04/11/08 1 1 G-116 11963085 MCNL 0~- / 04/01/08 1 1 05-286 11649987 MCNL (o- 08/17/07 1 1 P2-36A 11209594 MCNL - 03/26/06 1 1 07-01B 12021155 MCNL / `j~ 04/28/08 1 1 OS-34 11966251 CH EDIT PDC GR (USIT) 04/13/08 1 17-12 12057613 PRODUCTION PROFILE - G (~ 05/23/08 1 1 W-31 11999015 LDL 05/25/08 1 1 GNI-02A 12057618 PRESS/TEMP SURVEY (o - 3 ~ 05/24/08 1 1 13-12 11982434 USIT _ [. ~-~- 05/29/08 1 1 DI CACC nrlr~ln~nn enn_c oe nclr~r ov n -__-___-___.._~~.. ~. .............+.-..~v .~r~v~~~~~~~~w v1~~. VVf 1 GMV11 IV. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~ ii I ~ Date Delivered: - Alaska Data & Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 99503- 83 ATTN: Beth Received by: r~;;,_ t{..i~rti?1?. ~8 DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060220 Well Name/No. PRUDHOE BAY UN PTM P2-36A Operator BP EXPLORATION (ALASKA) INC MD 16272 TVD 9034 Completion Date 3/28/2006 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No Samples No Directional Survey Ye: u ~J DATA INFORMATION Types Electric or Other Logs Run: MWD ROP / GR / MPR, MGR CCL / CNL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 34 16272 Open 5/15/2006 Electronic Transfer ~pt Directional Survey 14465 16272 Open 5/11/2006 C ftpt 15272 LIS Verification 14487 16275 Open 7/6/2007 LAS GR, ROP w/Graphics PDF and Meta Lo Incjuction/Resistivity 5 Blu 14504 16272 Open 7/6/2007 Multi prop Res GR D C Lis 1527 nduction/Resistivity 14487 16275 Open 7/6/2007 Multi prop Res GR Log Gamma Ray 5 Blu 14504 16272 Open 7/6/2007 GR ~! ~D C Las 15631 Neutron 13420 .16126 Case 10/26/2007 LAS CCL, FCNL, GR, ~/ NCNL, NPHI w/PDF L graphics Well Cores/Samples Information: Interval Name Start Stop ADDITIONAL INFORMATION Well Cored? Y' l~ Chips Received? 'tf-N- Analysis Y Tt~-' Received? Comments: API No. 50-029-22801-01-00 UIC N Sample Set Sent Received Number Comments Daily History Received? /l.~ N Formation Tops ~ N DATA SUBMITTAL COMPLIANCE REPORT si2o~2oos Permit to Drill 2060220 Well Name/No. PRUDHOE BAY UN PTM P2-36A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22801-01-00 MD 16272 TVD 9034 o pletion Date 3/28/2006 Completion Status 1-OIL Current Status 1-OIL1 , ,,UInC N Compliance Reviewed By: ___ __ Date: __Q~1_~39`"v • ~a Date 10-12-2007 Transmittal Number:92914 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have anv Questions, please contact Douglas Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 02-12B o~b~--_p~~[__~_~5!~l~_..... 02-1_FC c~O~~O_'~Zf_'~ _~ cs-_~r_-~____ __ _-_ __ 02-16CPB1 a0 '~--0£~!~_. ~_lS_6~9 _ .._ s.r~a,v v ~_ -. i__ __._ -.. _ -_ _. -. 04-01A app-o3.~__~-.5~2-U------, 15-16B_ ~ - v~3,.__.4~6a-L. 15-16BP61 __~~~~_ _E~~_____ 15-16B.FBZ .~n~~ t.s~,~~ , 18-27DP61 - a0~_13~._.l_S~~S_=.- ----__-__ ___.- A-42A----_~-t3c~__ /S~a~_ _. __-_..___-. G-24A - s~6G-_O_~t2___~~~-`___ G-24AP61 a-Ulo-~~.__. t..~f~~.~.._._______ P2-11 A _~Q~ -Caa~_ _t5__4t 2`.~._________._.---_ P2-11APB1 _aV~-o.a_!o_.._.~S_b3.0....___.__.__... P2-36A _.~5~.~..._.Qaa.. _.1573/.:..... _.. -. P2-37A aDS -05~- _.. ~ ... --~~~o3a P2-37APB1,..: ~;b 5::_D~~.---1 ~"fa~--~-~----- ~ l~P.-_ -102 _ z -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 995 1 9-66 1 2 ~ ~ ~~ .;~ 3, Transmi~t~a~ ~'~`rm 3, ~~~~° ~~~~; INTEQ • ~~ !-T 4 3.~ ~~ ~` ?_~L e ~ BAKER HUGHES _ ®_ '~~9N~Anchorage GEOScience Center -y To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: P2-36A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GAR Directional Measured Depth Log 1 blueline - MPR/Directional TVD Log 1 blueline - MPRlDirectional Measured Depth Log LAC Job#: 1100529 Sent By: Deepa Joglekar Da y Q ~^' n l`,~ Received By: ~~,~ ~ .._- Date: '° ~ ~~'~ has .. ~,~~xt~s~ri PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & ~ ~' NING OR FAKING YOUR COPY FAK: (907) 267-6623 ~-~ ~% ~ 'L-' ~~ Baker Hughes INTEQ 7260 Homer Drive l ~ ~ ~ Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 t_'---- ---'v----'~. ~ ~F_ ~: _ -= F ~ _~. I :._ ~,~ -- -..=-a ~ ~ "_ , ,' ~- I ; __ _ - I -a ; ; __'! 1_ February 26, 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") P2-36A (206-022) Subsurface Controlled Subsurface Safety Valve ("SSCSV") Dear Mr. Kenda: SARAH PALInI, GOVERAIOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 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 February 9, 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. Information provided with the request indicates the SSCSV installed in PBU P2-36A failed its recent compliance shutdown test, requiring the valve's set pressure to be revised. 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 P2-36A 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 P2-36A will invalidate this approval and necessitate the reinstallation of a surface controlled subsurface safety valve. Sincerely, ~~ Cathy . Foerster Commissioner P2-36a K-Valve Redesign. ~~ Subject: P2-36a K-Valve Redesign. ' ~~ ~~~ From: "GPB, Gas Lift Engr" <GPBGasLiftEngr@BP.com> Date: Fri, 09 Feb 2007 13:28:05 -0900 TU. ~1T11 I'tg~(U_-~1CIT11JIl.SI~TC.~1k.llS CC: "GPB, LPC DS Ops Lea~j" <GPBLPC'DSOpsL_e~i~l(u:!BP.corli-~ Hello Jim, Please review the attached K-Valve redesign and change out request. I will proceed with the K Valve redesign installation unless I hear other otherwise from you. «P2-36 K-Valve Redesign 02-09-07 .ZIP» Regards, Johnny Kenda Arctic Lift Systems Inc. GPB, Gas Lift Eng. 907-659-5863 907-659-3423 (p) 601-807-8992 (c) Content-Description: P2-36 K-Valve Redesign 02-09-07 .ZIP P2-36 K-Valve Redesign 02-09-07 .ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 1 of 1 2/20/2007 4:54 PM ~auau.tr~u weil:__ P2-36A Date: 2/9/2007 IOR: 650 • Wireline Work Request AFE: Engineer: FTS: AWGRS Job Scope: PMP02WL36-C U,. ~,~,. i w Set SSSV ~~ ~ sisioi P2-36A 2~23~a~ Distribution Wireline (4) Reading File FI2S Level: Problem Description K Valve would not close during compliance SD test. Set SSSV (K-Valve in well to comply with state regulations while allowing well to produce without being choked back excessively. Initial Problem Review K-Valve Set up Pressure @ 60 deg F = 417 psi Remedial Plan - WIRELINE ACTION Install K-Valve _ . . ~ _ .. _ . ~ ~ ~'~ i Date Work Completed Well Status/Results Date Problem Resolved ? Y N by 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? Follow-up Recommendations: Expected NOB: Actual NOB: MGOR used for NOB: MAINTENANCE ONLY (e.g. Fix AC, Shallower for Slugging) RATE (Non-Post-WW) Orifice Depth: (e.g. deepen, optimize orifice) _ _ ____ IA Fluid Level: ' Post-Wellwork Date of FL Survey: / / i "K" Valve Calculation Sheet Date: 04/07/06 Test Data Well # P2-36 Test Date Gross Fluid Rate Flowing Well Head Pressure Flowing Well Head Temperature GOR TGLR 01 /22/07 2819 BLPD 522 psi 121 deg F 1127 scf/bbl 1577 scf/bbl Flowing Pressure Calculations Based on Hagedorn-Brown Multiphase Flow Correlation "K" Valve Setting Depth TVD 2104 ft Flowing Tubing Pressure With Gas Lift 792 psi '~~1~~: _ :{~ _.. .J,~ Flowing Tubing Pressure @ 375# Ptivh 630 psi "K" Valve Test Rack Set Pressure at 60 deg F 417 psi 0 Valve Size 8~ Volume Ratio 4-1/2" 1.314 ~1~~- Z„~~'I 2~ Tubing Pressure at Valve &3fl i - ----- - BPT (psis) _ 644 ---- ~ >1238-- ~ <1238 ___ - __ -- - em erature de Fat Valv p ( g ) 131 a 1.306E-05 2.16834E-05 _ b 1.163158, 1.137314 __ --- - _ -_ - -- ~ 566.984772, c 663.357 644.56046 _ Base Tem TV-60 _.-- t . 71 - ---- - 566.69989 ` 560.7443993 ~ - - --_ - -- ---I Corrected Pressure -------- 560.744399 , ~ - psis TCF ~ 0.870180632 olume Ratio f or Valve Size =! 1.314 j _ _ Pb @ 60 = ~ 45 8 213798 ~--- _ - - Test Rack Pressure = 417 j ------- -- - - - Volume Ratios _ 4 1/2" & 5 1/2" 1.314 31/2" _ 1.257 -- - _ __ _._ __ 2 7/8~ -- -- 1.211 _ _ -2 3~8" ----- 1.204 ----- - yet ~h s-rl ~a~ STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COSIGN WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~` ;~ - 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned Q Suspended ^ WAG zoAACZS.ios zoAACZS.iio ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ®De~ent ^ Exploratory ^ Stratigraphic Q Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 3/28/2006 12. Permit to Drill Number 206-022 3. Address: P.O. Box 1.96612, Anchorage, Alaska 99519-6612 6. Date Spudded 3/21/2006 13. API Number 50-029-22801-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 3/24/2006 14. Well Name and Number: PBU P2-36A 273 FNL, 1348 FWL, SEC. 14, T12N, R14E, UM Top of Productive Horizon: 2149' FNL, 1279' FWL, SEC. 18, T12N, R15E, UM g• KB Elevation (ft): 47.55 15. Field / Pooi(s): Prudhoe Bay Field /Point Mclntyr Pool Total Depth: 2375' FNL, 3029' FWL, SEC. 18, T12N, R15E, UM 9. Plug Back Depth (MD+TVD) 16196 + 9045 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 681590 y- 5998311 Zone- ASP4 10. Total Depth (MD+TVD) 16272 + 9034 Ft 16. Property Designation: ADL 034627 TPI: x- 692126 y- 5996698 Zone- .ASP4 Total Depth: x- 693881 Y- 5996518 Zone- ASP4 11. Depth where SSSV set 2227' MD 17. Land Use Permit: Thi k f 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL ness of Perma rost 20. c 1900' (Approx.) 21. Logs Run: MWD ROP / GR / MPR, MGR CCL / CNL ASING, INER AND EMENTING ECORD CASING ETTING EPTH MD ETTING EPTH'TVD HOLE OUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 133# H-40 Surface 110' Surface 110' - Driven 9-5/8" 40# L-80 34' 7204' 34' 4967' 12-1/4" 1766 sx Coldset III, 593 sx Class 'G' 7" 26# / 29# L-80 / 13Cr 32' 14142' 32' 8813' 8-1 /2" 236 sx Class 'G' 4-1/2" 12.6# 13Cr 13993' 14498' 8727' 9022' 8-1/2" 236 sx Class 'G' 3-,!z• X z-~!s° 6.2# / 6.16# L-80 ! 13Cr80 14187' 16232' 8840' 9040' 4-1 /8" 118 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, 6spf 4-1/2", 12.6#, 13Cr 13998' 13942' MD TVD MD TVD _ 15050' - 15200' 9032' - 9032' 15250' - 15500' 9032' - 9038' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 16100' - 16190' 9054' - 9046' DEPTH INTERVAL MD AMOUNT Sc KIND OF MATERIAL USED 5250' Freeze Protected w/ 82 Bbls of Diesel 26. PRODUCTION TEST Date First Production: April 6, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 4/18/2006 Hours Tested 4 PRODUCTION FOR TEST PERIOD • OIL-BBL 225 GAS-McF 248 WATER-BBL 622 CHOKE SIZE 80 GAS-OIL RATIO 1,104 Flow Tubing Press. 49 Casing Pressure 2,341 CALCULATED 24-HOUR RATE OIL-BBL 1,349 GAS-MCF 1,490 WATER-BBL 3,734 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit c~e,chips; if none, state "none". ~ None ~ C ~` :. ~ d~~cJJI~ ~~~~ ~QZ/ ~v ' P ~~ ~~~.. MAY ~ "~ 2006 ~' Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. I GEOLOGIC MARKE 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME fVID TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kuparuk / LC1 14465' 9003' None LB2-4 14525' .9036' LB1 15570' 9042' LA 15862' 9056' LA 16117' 9053' LB 1 16220' 9041' Top Kuparuk 16220' 9041' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. / ~ / ( ~~~~~ Signed Terrie Hubble Title Technical Assistant Date PBU P2-36A 206-022 Prepared By Name/Number.- Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. oriurng Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing 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). ITeM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 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 page 1;of:7 Operations Summary Report Legal Well Name: P2-36 Common Well Name: P2-36 Spud Date: Event Name: REENTER+COMPLETE Start: 3/7/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 3/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 3/18/2006 22:00 - 23:00 1.00 RIGD P PRE Prep rig for move 23:00 - 00:00 1.00 MOB P PRE Move rig off P2-37A, stage on location 3/19/2006 00:00 - 04:45 4.75 MOB P PRE Nordic Rig # 1 on Standby waiting on Nabors Rig 7 ES to move. RU pump truck on P2-36, bullhead 375 bbls of 9.9 ppg brine followed w/ 30 bbls of MEOH at 4 bpm w/ 2900 psi, final pump rate/pressure at 3 bpm/1750 psi, Shut down pumps, 0 WHP, IA - 20psi, OA - 280 psi, also performed preventive maintenance on CT injector. 05:00 - 06:00 1.00 MOB P PRE Performed PJSM on moving and spotting rig over P2-36, Move Rig spot over P2-36. ACCEPT RIG AT 06:00 HRS ON 03/19/2006. 06:00 - 06:15 0.25 RIGU P PRE PJSM for N/U BOPE. 06:15 - 09:00 2.75 RIGU P PRE N/U BOPE & grease tree valves. 09:00 - 15:30 6.50 BOPSU P PRE Perform initial BOPE pressure /function test. AOGCC witness waived by Lou Gramaldi. BOPE testing witnessed by John Egbejimba, BP WSL. Meanwhile spot outside trailers & tanks. R/U hardline to tiger tank & PT to 4k. 15:30 - 16:15 0.75 BOPSU P PRE Circ & fill CT with 9.7ppg NaCL/KCL water. P/Test CTC & inner reel valve to 3500psi. 16:15 - 16:30 0.25 ZONISO P WEXIT Held pre-operations safety meeting. Reviewed well plan, potential hazards & cementing BHA M/U procedures. 16:30 - 17:00 0.50 ZONISO P WEXIT Fill rig pits with 9.7ppg NaCL/KCL water. 17:00 - 17:30 0.50 ZONISO P WEXIT M/U slick cementing BHA #1 with big hole (0.90" ID) nozzle & 6' CSH tbg pup. Strip into well & M/U injector. Open up well & observe Opsi WHP. IAP = 440psi & OAP = 350psi. 17:30 - 20:10 2.67 ZONISO P WEXIT RIH with cementing BHA #1 taking FP returns to tiger tank., Tagged at 14505' CTM corrected back to ELM of Whipstock setting depth of 14498', up wt 42 k, do wt 14 k 20:10 - 21:00 0.83 ZONISO P WEXIT PU 10' to 14488', flagged line, established injection rates w/ 9.7 ppg brine at 1 bpm - 975psi, 1.5 bpm - 1200psi, 2 bpm - 1400 psi, RU cementers 21:00 - 21:15 0.25 ZONISO P WEXIT PJSM on cement job 21:15 - 22:20 1.08 ZONISO P WEXIT Pump cement job as follows: pumped 5 bbls of FW, test lines to 4000 psi, 12.7 bbls of 15.8 ppg CL "G" neat cement slurry at 2.25 bpm, 900 psi, displace cement w/ 4.5 bbls of FW, shut in well at choke, switch over to rig pumps, pump 9.7 ppg brine, bullhead into formation at 2 bpm - 1285 psi, pressure increased to 1350 psi after 37.5 bbls pumped, slowed rate to 1 bpm after pumping 55 bbls w/ 1023 psi, pressure increased to 1475 psi w/ 58.6 bbls pumped, open choke maintaining 1475 psi WHP, POH, laying in remaining cmt 1:1, pumped 70.1 bbls 22:20- 22:30 0.17 ZONISO P WEXIT POH to 13000' w/ Est TOC at -13685' 22:30 - 23:00 0.50 ZONISO P WEXIT Circ while holding squeeze pressure of 1975 psi at 3/4 bpm in/out, 1000 psi over baseline inj WHP, monitoring in/out volumes 23:00 - 00:00 1.00 ZONISO P WEXIT Pump 25 bbl biozan pill followed by 9.7 ppg double slick brine, RIH, washing down to 14440' w / 3 bpm 1400 psi, 10' above whipstock tray w/ 1: 1 returns 3/20/2006 00:00 - 00:15 0.25 ZONISO P WEXIT POH to 13500' at 3 bpm w/ 1300 psi, returns show cement contaminated brine 00:15 - 00:30 0.25 ZONISO P WEXIT RIH to 14488' at 3 bpm w/ 1500 psi, returns w/ cement contaminated brine 00:30 - 03:00 2.50 ZONISO P WEXIT POH to BHA Printed: 4/14/2006 11:13:05 AM i ~ BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: P2-36 Common Well Name: P2-36 Spud Date: Event Name: REENTER+COMPLETE Start: 3/7/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 3/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From.- To Hours Task Code NPT Phase Description of Operations 3/20/2006 03:00 - 03:15 0.25 ZONISO P WEXIT POH w/ BHA, LD nozzle, pup jt 03:15 - 03:45 0.50 STWHIP P WEXIT PU, RIH w/ window mill assy, MU MHA, stab inj 03:45 - 06:00 2.25 STWHIP P WEXIT RIH w/ window mill assy present depth at 06:00 hrs 13900' 06:00 - 06:15 0.25 STWHIP P WEXIT Continue RIH & tag TOC @ 14478'. 06:15 - 08:00 1.75 STWHIP P WEXIT Mill cement from 14478' with 2.7/2.7bpm, 1600/1900psi, 3k WOB & 20fph. Stall & tag WS/Lnr pinch pt with pumps @ 14504.6'. Flag pipe & correct CTD to 14498' (pinch pt ELMD). 08:00 - 08:45 0.75 STWHIP P WEXIT Start milling window. Mill from 14498' to 14499' with 2.72/2.72bpm, 2100/2250psi & 2k WOB. 08:45 - 09:45 1.00 STWHIP P WEXIT Mill to 14500' with 2.72/2.72bpm, 2100/2350psi & 3k WOB. Collect btms up sample for scale analysis. 09:45 - 10:45 1.00 STWHIP P WEXIT Mill to 14501' with 2.72/2.72bpm, 2100/2400psi & 3k WOB. 10:45 - 11:45 1.00 STWHIP P WEXIT Mill to 14502' with 2.72/2.72bpm, 2100/2400psi & 4k WOB. Norm-tested 14500' & 14502' btms up samples for radioactivity recorded only normal background radioactivity of 3-5uRem/hr (not hot). 11:45 - 12:45 1.00 STWHIP P WEXIT Mill to 14503' with 2.72/2.72bpm, 2100/2400psi & 4k WOB. 12:45 - 14:15 1.50 STWHIP P WEXIT Control mill to 14504' with 2.72/2.72bpm, 2100/2400psi & 3k WOB. Exit into formation @ 14503.8'. 14:15 - 15:15 1.00 STWHIP P WEXIT Control mill formation to 14504.7' with 2.72/2.72bpm, 2100/2400psi & 3k WOB. Stall @ 14504.7'. P/U & ease back into milling. Mill to 14505'. 15:15 - 15:50 0.58 STWHIP P WEXIT Mill 10' formation to 14515' with 2.72/2.72bpm, 2100/2350psi, 15fph ave ROP & 2k WOB. 15:50 - 16:30 0.67 STWHIP P WEXIT Backream/dress window/rat hole 3x & drift 2x. Window looks clean. Tentative window depths are: TOWSITOW = 14498', BOW = 14503.8', RA PIP Tag = 14506.88'. Meanwhile swap the wellbore to 100% reconditioned 9.7ppg Flo-Pro mud with 3% L-T, 1 % of EMI776 (new Flo-Cube) & 8ppb K-G. 16:30 - 19:00 2.50 STWHIP P WEXIT POOH to window milling BHA #2, while displacing well to mud, std bk inj 19:00 - 19:25 0.42 STWHIP P WEXIT POH w/ BHA, LD milling assy 19:25 - 21:00 1.58 RIGD P WEXIT MU nozzle, stab inj, PJSM on handling and pickling CT w/ bleach and corrision inhibited pill, Pump 15 bbls of bleach, 60bbls of fresh water, 15bbls of corrosion inhibitor & 5 bbls of McOH. 21:00 - 22:00 1.00 RIGU P WEXIT P/T N2 lines -- OK, Blow down CT with N2 22:00 - 00:00 2.00 RIGD P WEXIT PU Injector, cut CTC, prep for pulling coil across and secure, pulled cable back to reel house. Prep CT reel for CT swap 3/21/2006 00:00 - 03:30 3.50 RIGD P WEXIT Held PJSM on critical lift, swapping CT reel, Spot reel, crane, RU crane, swap CT reel 03:30 - 04:00 0.50 RIGD P WEXIT PJSM w/ crew on RU hardline to reel, RU hard line 04:00 - 06:30 2.50 RIGU P WEXIT Held PJSM on stabbing CT, R/U cable and pulley, P/U injector head, Slip grapple into CT & pull test. Pull CT over pipe shed with winch & stab into injector, M/U injector to stripper, install SLB CTC. Pull test to 35k. 06:30 - 08:15 1.75 RIGU P WEXIT Install dart catcher. Pump 5bbfs McOH & 10bbls of fresh water. Close inner reel valve & PT hardline to reel - OK. Load wiper dart. Launch & chase with mud. Dart hit @ 73.3bbls. Press test inner reel valve &CTC to 3500psi -- OK. 08:15 - 08:30 0.25 DRILL P PROD1 Held pre-spud safety meeting. Reviewed well plan, potential hazards & drilling BHA M/U procedures. 08:30 - 09:30 1.00 DRILL P PROD1 M/U drilling BHA #3 with 3.2deg X-treme motor, BHI Printed: 4/14/2006 11:13:05 AM BP EXPLORATION Page 3 of 7 Operations Summary Report Legal Well Name: P2-36 Common Well Name: P2-36 Spud Date: Event Name: REENTER+COMPLETE Start: 3/7/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 3/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of'Operations 3/21/2006 08:30 - 09:30 1.00 DRILL P PROD1 HOT-DGS-DPS-SBS-BCPM coiltrack package & used Hycalogs 3-3/4" x 4-1/4" DS3611 bicenter bit #2. Scribe tools. Initialize BHI tools & M/U injector. 09:30 - 10:45 1.25 DRILL P PROD1 RIH drilling BHA #3 to 6600'. Saw the CT butt-weld @ 3500'. 10:45 - 11:15 0.50 DRILL P PROD1 SHT tools @ 6600' - OK 11:15 - 13:05 1.83 DRILL P PROD1 RIH drilling BHA #3 to btm at 14515', no problems running thru window 13:05 - 14:00 0.92 DRILL P PROD1 Orienting TF at 20R, pump #2 rate and pressure fluctuating, switch to pump #1, repeat downlink, orient to TF 30R 14:00 - 18:45 4.75 DRILL P PROD1 Directional Drill w/ TF at 5L, 2.5 bpm, 3750 psi, ROP at 30 -40 fph, ECD 11.71, PVT 329 bbls. MWD failure. 18:45 - 21:00 2.25 DRILL N DFAL PROD1 POH Pulser worked while POH. Possibly dog leg issue. will replace with MWD used on previous well with similar dogleg 33-40/100. 21:00 - 22:00 1.00 DRILL N DFAL PROD1 Change out MWD. 22:00 - 00:00 2.00 DRILL N DFAL PROD1 RIH 3/22/2006 00:00 - 01:00 1.00 DRILL N DFAL PROD1 RIH. 01:00 - 03:00 2.00 DRILL P PROD1 Directionally drill 2.47/2.47 3850 psi, FS= 3520 psi. WOB 3K, ROP 25 -50. Drill to 14650. ECD 11.73 ppg @ end of build. 03:00 - 04:45 1.75 DRILL P PROD1 POH to 14545. Down-link to higher record rate. Log tie-in. 04:45 - 07:15 2.50 DRILL P PROD1 POH to BHA for lateral drilling assembly. 07:15 - 08:00 0.75 DRILL P PROD1 POH w/ BHA, LD MWD, mtr and bit, download MWD 08:00 - 08:45 0.75 DRILL P PROD1 PU Lateral BHA w/ rebuild 4 1/8" bi-center Hughes bit, 1.2 deg mtr, MWD-Res-Gr, orient to mtr, upload MWD tools, MU MHA, MU to CTC, Stab inj 08:45 - 11:15 2.50 DRILL P PROD1 RIH w/ BHA to 14450' 11:15 - 12:25 1.17 DRILL P PROD1 Downlink for GR, Tie-in log f/ 14450' - 14340' 12:25 - 12:35 0.17 DRILL P PROD1 RIH to 14511' 12:35 - 13:35 1.00 DRILL P PROD1 Downlink for RES, TF at HS, Madd Pass log f/ 14511' to btm at 14650', 2.6 bpm, 3750 psi, PVT 317 bbls 13:35 - 14:00 0.42 DRILL P PROD1 Downlink - TF 90L, pump rate fluctuating f/ pump # 2, switched to # 1 pump and repeat downlink. Rig electrician to troubleshoot. Card in SCR replaced. 14:00 - 19:00 5.00 DRILL P PROD1 Directionally Drill 2.5 bpm, 3750 psi, WOB 3 -4K, ROP 30 - 60, ECD 11.71 ppg 19:00 - 19:15 0.25 DRILL P PROD1 Wiper to window. 19:15 - 23:33 4.30 DRILL P PROD1 Directionally drill 2.47 bpm @ 3840 psi, FS = 3600 psi ,WOB 4K, ROP 36 ECD 11.7 Drill to 14912. Down link to orient to 90R. Pump #2 racing swap to pump #1. 23:33 - 00:00 0.45 DRILL P PROD1 Short trip 3/23/2006 00:00 - 04:45 4.75 DRILL P PROD1 Directionally drill 2.45 bpm @ 3860 psi, FS = 3450 psi, Up Wt 32K, Dn Wt 7K , WOB 2-3K,ROP 40-60. Drill to 15,100. 04:45 - 05:00 0.25 DRILL P PROD1 Wiper to window. 05:00 - 05:25 0.42 DRILL P PROD1 Log tie-in. -2' correction. 05:25 - 05:55 0.50 DRILL P PROD1 RIH to btm , no problems with open hole on wiper trip 05:55 - 09:45 3.83 DRILL P PROD1 Directionally drill 2.4 bpm @ 3550 psi, Up Wt 32K, Dn Wt 7K , WOB 2-3K, ROP 40-60, ECD 11.89 ppg, PVT 297 bbls 09:45 - 10:25 0.67 DRILL P PROD1 Wiper thru window to 14460', shut down pumps, Troubleshoot #2 pump and # 3 SCR assignment, 10 min, still investigating 10:25 - 11:00 0.58 DRILL P PROD1 RIH to btm, no problems with openhole 11:00 - 14:50 3.83 DRILL P PROD1 Directionally drill 2.5 bpm @ 4000 psi, FS 3650 psi, TF at 265, Up Wt 32K, Dn Wt 7K , WOB 2 - 3K, ROP 80, ECD 11.87 ppg, PVT 291 bbls, still experiencing difficulty w/ sporadic pump Printed: 4/14/2006 11:13:05 AM BP EXPLORATION Page 4 of 7` Operations Summary Report Legal Well Name: P2-36 Common Well Name: P2-36 Spud Date: Event Name: REENTER+COMPLETE Start: 3/7/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 3/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 3/23/2006 11:00 - 14:50 3.83 DRILL P PROD1 pressure or pump dropping off line, electrician is troubleshooting. Problem appears to be in a Halls Effect Transducer in SCR #2. Searching for spare on slope, part will be placed on order first thing in the morning if need be. 14:50 - 15:20 0.50 DRILL P PROD1 Wiper thru window to 14460' 15:20 - 15:50 0.50 DRILL P PROD1 RIH to btm, no problems with openhole 15:50 - 20:00 4.17 DRILL P PROD1 Directionally drill 2.6 bpm @ 3800 psi, TF at 90, Up Wt 32K, Dn Wt 7K , WOB 2 - 4K, ROP 85, ECD 11.93 ppg, PVT 283 bbls. Drill to 15,545'. 20:00 - 20:45 0.75 DRILL P PROD1 Wiper to 14551 20:45 - 21:15 0.50 DRILL P PROD1 Tie - in log correction +11'. 21:15 - 21:45 0.50 DRILL P PROD1 RIH tag TD at 15554.6' 21:45 - 00:00 2.25 DRILL P PROD1 Directionally drill 2.4 bpm @ 3800 psi, TF at 120, Up Wt 32K, Dn Wt 7K , WOB 2 - 4K, ROP 70, ECD 11.93 ppg, PVT 276 bbls. Drill to 15596 3/24/2006 00:00 - 02:45 2.75 DRILL P PROD1 Swapping mud and directionally drill 2.54 bpm @ 3800 psi,FS= 3400 psi. TF at 180, Up Wt 33K, Dn Wt 7K , WOB 2 - 4K, ROP 70, ECD 11.67 ppg, Drill to 15700. 02:45 - 04:15 1.50 DRILL P PROD1 Wiper to the window. 04:15 - 07:30 3.25 DRILL P PROD1 Directionally drill 2.54 bpm @ 3800 psi, FS= 3400 psi. TF at 180 and 270, Up Wt 33K, Dn Wt 7K , WOB 2 - 4K, ROP 70 - 95, ECD 11.55 ppg, 07:30 - 09:00 1.50 DRILL P PROD1 Wiper to the window. 09:00 - 12:15 3.25 DRILL P PROD1 Directionally drill 2.64 bpm @ 4200 psi, FS= 3400 psi. TF at 270 and 90, Up Wt 33K, Dn Wt 7K , WOB 2 - 4K, ROP 60 - 95, ECD 11.53 ppg, 12:15 - 13:00 0.75 DRILL P PROD1 Wiper to the window. No hole problems 13:00 - 13:20 0.33 DRILL P PROD1 Tie-in pass f/ 14555' to RA tags, +10' correction 13:20 - 14:15 0.92 DRILL P PROD1 RIH to btm, no hole problems 14:15 - 16:55 2.67 DRILL P PROD1 Directionally drill 2.55 bpm @ 4000 psi, FS= 3575psi. TF at 59 - 85R, Up Wt 33K, Dn Wt 7K , WOB 3-5K, ROP 60 - 100, ECD 11.68 ppg, PVT 244 bbls 16:55 - 18:30 1.58 DRILL P PROD1 Wiper to the window 18:30 - 22:45 4.25 DRILL P PROD1 Directionally drill 2.61 bpm @ 3950 psi, FS= 3575psi. TF at 45L, Up Wt 33K, Dn Wt 7K , WOB 3-5K, ROP 60 - 100, ECD 11.58 ppg, PVT 238 bbls. Drill to 16272. TD called by Geo. 22:45 - 23:30 0.75 DRILL P PROD1 POH 2.65 bpm at 3650 psi. Up Wt 36K. 23:30 - 23:50 0.33 DRILL P PROD1 Log tie-in. Correction = +6'. 23:50 - 00:00 0.17 DRILL P PROD1 RIH 3/25/2006 00:00 - 01:00 1.00 DRILL P PROD1 RIH 2.67 bpm @ 3725 psi. Dn Wt 7K.D Set down at 16245. Sticky Pull 70 K break back to 38K. After three attempts to work to bottom decided to call this good. Will start MAD pass at 16235. 01:00 - 06:30 5.50 DRILL P PROD1 MADD pass/ tie-in w/ +6 correction to window 06:30 - 07:00 0.50 DRILL P PROD1 RIH, tagged up at 16230' 07:00 - 10:15 3.25 DRILL P PROD1 POH to BHA, lay in liner running pill, flagged EOP for liner on Btm at 14185' and at the window at 12449' 10:15 - 12:00 1.75 DRILL P PROD1 POH w/ BHA, LD Drlg BHA, Dn Load MWD Tools, cleared floor and pipeshed 12:00 - 15:30 3.50 CASE P RUNPRD Held PJSM for M/U &RIH with chrome 3-1/2" x 2-7/8" completion liner. RU handling tools, hoist Baker tools to the rig floor Printed: 4/14/2006 11:13:05 AM $P EXPLORATION Page 5 of T Operations Summary Report.. Legal Well Name: P2-36 Common Well Name: P2-36 Spud Date: Event Name: REENTER+COMPLETE Start: 3/7/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 3/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 3/25/2006 12:00 - 15:30 3.50 CASE P RUNPRD M/U 2-7/8" STL rotating guide shoe, 2 float collars, 1 shoe jt & landing collar. M/U 23jts of 2-7/8" STL 6.16# L-80 liner and 35jts of 2-7/8" STL 6.16# L-80 13Cr80 liner, Chrome XO, 8jts of 3-1/2" STL 8.81# 13Cr80 liner, XN nipple & 2 - 3-1/2" 13CR80 pup jts. M/U Chrome BKR deploy sleeve & CTLRT. OAL -2045.38'. 15:30 - 17:20 1.83 CASE P RUNPRD M/U dart catcher. Load wiper dart, launch/chase dart with mud & pig CT. Dart bumped on catcher @ 72.8bbls PU Inj, cut off SLB CTC, Install Baker CTC, Pull test to 35k & pressure test to 3500psi. 17:20 - 20:00 2.67 CASE P RUNPRD RIH with liner assy. RIH to flag at window corrected -.7' Up Wt 46K ,Dn Wt 10K. Continue to RIH Tag 16232' Up Wt 54K 20:00 - 21:00 1.00 CASE P RUNPRD Lauch 5/8" steel ball and circulate to running tool.@ 2.18 bpm 3070 psi. Reduce rate to .6 bpm 1410 psi at 52 bbl into diplacement. Ball on seat at 61.2 bbls Theoritical 84.6 bbl. Seat sheared at 4278 psi. PU 40K. Circulate 2bpm at 2880 psi. 21:00 - 22:45 1.75 CASE N WAIT RUNPRD Wait on Vac truck to bring brine to change over well. No dirty trucks available Waiting on two clean with brine so we can displace to the tiger tank. 22:45 - 00:00 1.25 CASE P RUNPRD Draw down pit levels inpreparation of swapping to brine by shipping returns to the tiger tank. 3/26/2006 00:00 - 02:45 2.75 CASE P RUNPRD Circulate 2.6 bpm at 3516 initial circulating rate and pressure. Post swap 2.6 bpm at 2200 psi. 02:45 - 03:00 0.25 CASE P RUNPRD PJSM for cement job. 03:00 - 04:15 1.25 CEMT P RUNPRD Pressure test lines to 4000 psi and batch up 27 bbl G latex cement w/ 3% magnesium oxcide. Pump 3 bbl H2O, 24.4 bbl cement 2.58 bpm @ 2760 psi. Incert dart and suck back Iines.Launch dart with 300 psi. Displace cenent with 30 bbl double slick bio . PU liner wiper plug at 72.6 bbl actual.72.8 bbl calculated. Latch landing collar 84.2 bbl calculated 84.9 bbls. Lost 1.6bb1 to the formation. CIP at 04:09 Hrs on 3/26/2006 Top of FS at 16230' 1st(Btm) FC at 16229' 2nd(Top) FC at 16228' LC at 16196' BOT Liner Deployment Sleeve at 14186' 2 7/8" tbg and accessories was drifted to 2.347'; 3 1/2" tbg and accessories was drifted to 2.867" 04:15 - 07:30 3.25 CEMT P RUNPRD POH, LD running tool 07:30 - 10:40 3.17 EVAL P LOWER1 PJSM on P/U &RIH MCNL tools & 1-114" CHS tbg. R/U floor for running logging/cleanout BHA. P/U logging/cleanout BHA with 2.30" D331 mill, 2-1/8" straight motor, XO, 2jts of 1-1/4" CSH tbg, MCNL/CCUGR logging tool carrier, XO, lower MHA, 64jts of 1-1 /4" CSH tbg, XO & upper MHA. M/U Injector. 10:40 - 12:40 2.00 EVAL P LOWER1 RIH with mill, motor &MCNL/GR/CCL to 13500' Printed: 4/14/2006 11:13:05 AM BP EXPLORATION Page 6 of ? Operations Summary Report Legal Well Name: P2-36 Common Well Name: P2-36 Spud Date: Event Name: REENTER+COMPLETE Start: 3/7/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 3/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From -To ..Hours Task Code NPT Phase Description'of Operations 3/26/2006 12:40 - 14:30 1.83 EVAL P LOWER1 Log do from 13500' to PBTD at 16195' w/ 1.4 bpm 1660 psi, cement cuttings in returns, pumped 20 bbl hi vis sweep 14:30 - 15:20 0.83 EVAL P LOWERI Log up from PBTD at 13500' at 60 fpm w/ 1.45 bpm, 1410 psi, cement cuttings in returns 15:20 - 16:00 0.67 EVAL LOWER1 RIH to btm 16:00 - 16:50 0.83 EVAL P LOWER1 POH to 13949' while laying in pert pil, PVT 146 bbls, completion fluid contaminated with cement returns 16:50 - 19:00 2.17 EVAL N WAIT LOWER1 Wait on Vac Trk w/ 300 bbls of 9.7 ppg to replace dirty fluid in hole and low pit volume. No Vac Trks available. 19:00 - 21:30 2.50 EVAL P LOWER1 POH to CSH. Drop 5/8" ball to open circ sub. 21:30 - 23:00 1.50 EVAL P LOWERI Strandback CSH 33 stands. 23:00 - 23:45 0.75 EVAL P LOWERI LD logging BHA 23:45 - 00:00 0.25 EVAL P LOWER1 MU nozzel and swizzel stick and flush BOP stack. 3/27/2006 00:00 - 00:40 0.67 EVAL P LOWER1 Jet stack 00:40 - 02:00 1.33 BOPSU P LOWER1 Test Liner lap using 9.7 ppg brine to 2113 psi. with .2 bbl of volume.bled off to 1802 in 15 min .Bumped back up to with .1 bbl 2067 psi bleed to 1864 in 30 min .Lost 203 psi allowed 206 psi Passed. Time Pressure 1:09 2067 1:20 1967 1:22 1952 1:25 1937 1:29 1908 1:33 1882 1:39 1864 Pass 1:40 1849 1:43 1838 1:50 1813 02:00 - 02:30 0.50 PERFO P LOWER1 PU 54 guns and 15 stands of CSH.PJSM for picking up perforating guns and blanks. 02:30 - 04:30 2.00 PERFO P LOWER1 PU 54 2" 6SPF guns and blanks. 04:30 - 05:15 0.75 PERFO P LOWER1 PU 15 stands of 1-1 /4" CSH. 05:15 - 08:20 3.08 PERFO P LOWERI RIH with perforating assy to 16196', pump 5 bbls pert pill, Wt check @ 16000', Up - 46k; Run-in - 10k. Pull to P/U wt & correct CTD to 16199' (PBTD as per MCNL log). PUH & position btm shot @ 16190'. R/U sonogram detector to the wellhead for shot detection. 08:20 - 09:05 0.75 PERFO P LOWER1 RIH to16199'. Load & launch 5/8" AL ball w/10 bbls of pert pill followed by 9.7 ppg brine. PUH & position btm shot @ 16190'. Chase ball @ 2bpm/2450psi. Slow to 0.94 bpm/500psi @ 52 bbls. Ball on seat after 70.5 bbls away. S/D pumps & RBIH to 16199'. PUH very slowly & ramp up to 2805psi with btm shot @ 16190.7'. Observe guns fire with good pressure drop indication & sonogram detection. Perforated interval = 15050' - 15200', 15250' - 15500", 16100' - 16190' 09:05 - 09:35 0.50 PERFO P LOWERI POOH with pert gun assy @ 68 fpm pumping down the CT @ 1.4 bpm & 700 psi. POOH to 14000'. Printed: 4/14/2006 11:13:05 AM BP EXPLORATION Page 7 of 7 .Operations Summary Report Legal Well Name: P2-36 Common Well Name: P2-36 Spud Date: Event Name: REENTER+COMPLETE Start: 3/7/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 3/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 3/27/2006 09:35 - 09:50 0.25 PERFO P LOWER1 S/D pump &flowcheck welt -well stable. 09:50 - 12:05 2.25 PERFO P LOWER1 POOH to pert gun assy@ 60fpm pumping down the CT @ 1.45bpm & 480psi. 12:05 - 12:25 0.33 PERFO P LOWER1 S/D pump &flowcheck well -well stable. 12:25 - 13:20 0.92 PERFO P LOWER1 S/B injector. R/B 15 stands of 1-1/4" CSH. 3/4 hrs 13:20 - 17:20 4.00 PERFO P LOWER1 R/U to L/D perf guns, PJSM for LD perf guns, L/D 54 jts of pert guns & blanks, all shots fired, load out spent pert guns & blanks. 17:20 - 15:45 22.42 WHSUR P POST M/U check valve, X/O & nozzle. M/U injector. 15:45 - 20:30 4.75 WHSUR P POST RIH nozzle to 5250', PT Little Red to 4000 psi. O.K. Circ diesel to nozzle @ 2.47bpm/ 1630 psi. 82 bbls POH, shut well in w/ 400 psi below swab valve, Secured well, LD BHA 1 hr 20:30 - 22:00 1.50 WHSUB N WAIT POST Wait on N2. 22:00 - 22:30 0.50 WHSUR P POST PJSM for N2 blowdown. PJSM on handling and pickling CT w/ bleach and corrision inhibited pill. 22:30 - 00:00 1.50 WHSUR P POST Pump 16 bbls of bleach, 60bbls of fresh water, 15bbls of corrosion inhibitor & 5 bbls of McOH. 1.25 hr. P!T N2 lines OK, Blow down CT with N2 3/28/2006 00:00 - 00:30 0.50 WHSUR P POST Blow down CT with N2 00:30 - 03:30 3.00 WHSUR P POST ND BOP, offload pits, test tree cap Back off well to staging area. PU Injector, cut CTC, prep for pulling coil across and secure, pulled cable back to reel house. Prep CT reel for CT swap 03:30 - 13:00 9.50 WHSUR P POST RELEASED RIG AT 0730 HRS, 03/28/2006. Moved rig off of P2 to make room for Nordic 2. Cut off 1000 ft of coil. Prep for reel swap while waiting for Nordic 2 to complete rig move. All further information will be on NK-61A DIMS reports. Printed: 4/14/2006 11:13:05 AM ~P Alaska ~ ~R r by Baker Hughes INTEQ Survey Report »TEs Company:. BP'Amot~ :- Date: 4/12/2006 Time: 12:27:22 Page: t Field: Point McIntyre Co-ordiiilate(NE) Reference: Well' P2-36, True North Site::: Pt MaC 2 Vertical (TVD}Reference: 51:36 5/21/1997 11:55 46.6 Wells P2-36 Section (V5) Reference: Well (O.OON,0.O OE,99.54Azi) Wellpath: P2-36A SurveyCalcahttioc Method: Minimum Gurvature Db: Orade Field: Point McIntyre North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: ~gm2005 Site: Pt Mac 2 TR-12-14 UNITED STATES :North Slope Site Position: Northing: 59951 40.76 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 Convergenee: 1.34 deg Well: P2-36 Slot Name: 36 P2-36 Well Position: +N/-S 3012.93 ft Northing: 5998311.46 ft Latitude: 70 24 2.131 N +E/-W" 6789.17 ft Easting : 681590.37 ft Longitude: 148 31 19.035 W Positron Uncertainty: 0.00 ft Wellpath: P2-36A Drilled From: P2-36 Tie-on Depth: 14465.00 ft Current Datum: 51:36 5/21 /1997 11:55 Height 46.60 ft Above System Datum: Mean Sea Level Magnetic Data: 1/17/2006 Declination: 24.76 deg Field Strength: 57616 nT Mag Dip Angle: 80.97 deg Vertical Section: Depth From (TVD) +N/-S +FJ-W Direction ft ft ft deg 34,50 0.00 0.00 99.54 Survey Program tar Definitive Wellpath Date: 1/17/2006 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 115.00 14465.00 3 : Gyrodata cont.casing m/s ( GYD-CT-CMS Gyrodata cont.casing Ms 14493.00 16272.00 MWD (14493.00.16272.00) MWD MWD -Standard Annotation MD 1'VD ft ft 14465.00 9002.65 TIP 14493.00 9018.99 KOP 16272.00 9033.59 TD Survey: MWD Start Date: 3/24/2006 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Intl Azim TVD SyaTVD N/S EIW MapN MapE VS DLS Tool` ft deg deg R ft ft ft ft ft ft deg/1OOft 14465.00 54.31 96.62 9002.65 8956.05 -1875.60 10492.58 5996691.49 692124.78 10658.32 0.00 MWD 14493.00 54.29 96.36 9018.99 8972.39 -1878.17 10515.17 5996689.47 692147.42 10681.03 0.76 MWD 14493.00 54.29 96.36 9018.99 8972.39 -1878.17 10515.17 5996689.47 692147.42 10681.03 0.00 MWD 14516.88 58.12 95.67 9032.27 8985.67 -1880.25 10534.91 5996687.88 692167.20 10700.83 16.22 MWD 14544.60 66.83 94.96 9045.07 8998.47 -1882.52 10559.36 5996686.20 692191.70 10725.32 31.50 MWD 14576.62 75.40 94.23 9055.42 9008.82 -1884.94 10589.53 5996684.52 692221.92 10755.48 26.85 MWD 14617.70 85.25 96.28 9062.32 9015.72 -1888.65 10629.80 5996681.78 692262.27 10795.81 24.48 MWD 14654.32 95.88 97.59 9061.96 9015.36 -1893.07 10666.10 5996678.25 692298.66 10832.34 29.25 MWD 14688.82 96.75 94.23 9058.16 9011.56 -1896.60 10700.20 5996675.55 692332.83 10866.55 10.00 MWD 14717.79 98.35 92.50 9054.36 9007.76 -1898.29 10728.87 5996674.56 692361.53 10895.10 8.10 MWD 14750.82 98.82 92.17 9049.42 9002.82 -1899.62 10761.50 5996674.02 692394.18 10927.51 1.73 MWD 14780.76 98.17 96.17 9045.00 8998.40 -1901.77 10791.03 5996672.59 692423.75 10956.98 13.39 MWD 14811.65 97.37 100.77 9040.82 8994.22 -1906.28 10821.29 5996668.82 692454.12 10987.57 14.98 MWD 14842.19 96.07 104.98 9037.25 8990.65 -1913.04 10850.85 5996662.78 692483.$3 11017.84 14.34 MWD 14876.84 94.22 108.33 9034.14 8987.54 -1922.93 10883.91 5996653.70 692517.11 11052.08 11.01 MWD BP Alaska ~ sus by Baker Hughes INTEQ Survey Report INTEQ CompaAy: BP AmOCO Date: 4/12/2006 Time: 12:27:22 Page: 2 Field; Point MGntyre Co-ordiaatc(NE) Reference: -' Weil' P2-36, True North Site:: Pt MaC 2 Venicat (TVD) Reference: 51:36.5/21/1997 11:55 46.6 We1L `R2-36 `Section (VS) Reference: Well (O.OON,O.OOE,99.54Azi) Wellpath: P2-36A Survey Gknlation'Method: Mininwm Curvature I)b: OraGe Survey MD Ioel Azim TVD Sys TVD N/S EIW 'MapN MnpE ; VS DLS Tooi S deg deg _ ft; ft ft ft ft ft' ft dt'.g/100ft 14903.95 91.79 112.03 9032.72 8986.12 -1932.26 10909.31 5996644.98 692542.74 11078.68 16.31 MWD 14949.94 90.63 119.34 9031.74 8985.14 -1952.18 10950.72 5996626.08 692584.61 11122.82 16.09 MWD 14981.72 89.06 119.46 9031.83 8985.23 -1967.78 10978.41 5996611.15 692612.67 11152.71 4.95 MWD 15011.72 90.14 117.21 9032.04 8985.44 -1982.02 11004.81 5996597.56 692639.41 11181.10 8.32 MWD 15051.77 90.84 112.55 9031.70 8985.10 -1998.86 11041.13 5996581.61 692676.12 11219.71 11.77 MWD 15081.82 90.81 109.71 9031.26 8984.66 -2009.69 11069.16 5996571.46 692704.40 11249.14 9.45 MWD 15116.72 89.62 106.22 9031.13 8984.53 -2020.46 11102.35 5996561.51 692737.84 11283.66 10.57 MWD 15151.79 89.03 102.95 9031.55 8984.95 -2029.28 11136.28 5996553.51 692771.98 11318.59 9.47 MWD 15186.82 89.06 99.67 9032.13 8985.53 -2036.15 11170.62 5996547.48 692806.47 11353.59 9.36 MWD 15216.73 90.91 97.62 9032.14 8985.54 -2040.65 11200.19 5996543.70 692836.14 11383.50 9.23 MWD 15251.72 89.98 95.18 9031.87 8985.27 -2044.55 11234.96 5996540.65 692870.99 11418.43 7.46 MWD 15286.84 90.51 91.41 9031.72 8985.12 -2046.57 11270.01 5996539.48 692906.08 11453.33 10.84 MWD 15316.92 90.29 88.39 9031.51 8984.91 -2046.51 11300.09 5996540.27 692936.15 11482.98 10.07 MWD 15347.12 89.13 85.85 9031.66 8985.06 -2045.00 11330.25 5996542.52 692966.26 11512.47 9.25 MWD 15387.02 87.16 82.64 9032.95 8986.35 -2041.00 11369.92 5996547.48 693005.82 11550.94 9.44 MWD 15416.72 87.56 79.73 9034.32 8987.72 -2036.45 11399.23 5996552.73 693035.01 11579.09 9.88 MWD 15446.72 87.93 80.49 9035.50 8988.90 -2031.30 11428.76 5996558.60 693064.40 11607.36 2.82 MWD 15477.08 86.94 83.22 9036.86 8990.26 -2027.01 11458.78 5996563.62 693094.31 11636.25 9.56 MWD 15513.25 87.37 87.98 9038.65 8992.05 -2024.24 11494.79 5996567.27 693130.24 11671.31 13.20 MWD 15547.86 86.92 92.47 9040.38 8993.78 -2024.37 11529.35 5996567.97 693164.79 11705.41 13.02 MWD 15579.82 85.22 96.43 9042.57 8995.97 -2026.84 11561.13 5996566.27 693196.62 11737.16 13.46 MWD 15616.13 85.80 100.81 9045.41 8998.81 -2032.27 11596.91 5996561.72 693232.52 11773.34 12.13 MWD 15654.33 86.33 104.82 9048.04 9001.44 -2040.72 11634.06 5996554.17 693269.86 11811.38 10.56 MWD 15688.94 86.79 103.38 9050.11 9003.51 -2049.14 11667.57 5996546.57 693303.56 11845.82 4.36 MWD 15712.70 88.23 100.59 9051.15 9004.55 -2054.07 11690.79 5996542.21 693326.89 11869.53 13.20 MWD 15754.91 88.30 97.03 9052.42 9005.82 -2060.53 11732.47 5996536.77 693368.72 11911.72 8.43 MWD 15787.32 88.64 92.93 9053.29 9006.69 -2063.34 11764.74 5996534.74 693401.04 11944.00 12.69 MWD 15816.72 87.97 89.71 9054.16 9007.56 -2064.01 11794.12 5996534.78 693430.42 11973.09 11.18 MWD 15846.72 86.92 87.02 9055.50 9008.90 -2063.16 11824.07 5996536.36 693460.35 12002.48 9.62 MWD 15876.72 86.40 85.72 9057.25 9010.65 -2061.26 11853.96 5996538.98 693490.18 12031.65 4.66 MWD 15906.92 92.32 84.83 9057.58 9010.98 -2058.78 11884.04 5996542.20 693520.19 12060.90 19.82 MWD 15937.72 91.55 84.73 9056.54 9009.94 -2055.98 11914.70 5996545.74 693550.77 12090.67 .2.52 MWD 15966.82 90.66 87.78 9055.98 9009.38 -2054.08 11943.73 5996548.35 693579.74 12118.98 10.92 MWD 15996.72 89.92 90.60 9055.83 9009.23 -2053.65 11973.62 5996549.49 693609.61 12148.39 9.75 MWD 16032.12 91.00 94.31 9055.55 9008.95 -2055.17 12008.98 5996548.84 693644.99 12183.51 10.91 MWD 16061.72 90.81 96.83 9055.08 9008.48 -2058.04 12038.43 5996546.68 693674.51 12213.03 8.54 MWD 16091.72 92.07 99.78 9054.32 9007.72 -2062.37 12068.11 5996543.07 693704.27 12243.01 10.69 MWD 16127.06 94.25 103.59 9052.38 9005.78 -2069.52 12102.65 5996536.77 693738.98 12278.27 12.41 MWD 16156.53 96.07 104.28 9049.73 9003.13 -2076.58 12131.14 5996530.40 693767.63 12307.53 6.60 MWD 16186.87 98.33 102.17 9045.92 8999.32 -2083.47 12160.44 5996524.23 693797.08 12337.56 10.15 MWD 16272.00 98.33 102.17 9033.59 8986.99 -2101.23 12242.77 5996508.48 693879.83 12421.71 0.00 MWD WELLHEAD= FMC ACTUATOR = BAKER C KB. ELEV = 47.55' BF. ELEV = 15.05' KOP = 1020' Max Angle = 59 @ 7998' Datum MD = 14168' Datum TVD = 8800' SS 9-518" CSG, 40#, L-80, ID = 8.835" ~~ 7203, Minimum ID = 3.813" @ 2227' 4-112" CAMCO SSSVN 7", 26#, L-80 X 7", 29#, 13-CR CSG XO 13570' 7" MARKER JT (19') 13804' ITOP OF BAKER TIEBACK SLV ~~ 13992, 4-1/2" TBG, 12.6#, 13-C R, .0152 bpf, ID = 3.958" 13997' TOP OF BAKER TI~ACK SLV ~ 14001' 7" X 4-1/2" BKR HMC LNR HANGER, ID = 3.938" 1400T 7" CSG, 29#, 13-CR-80, ID = 6.184" 14141 Top of Cement 14186' TOP OF 3-1/2" 13cr80 LNR 14186' 3.5" XN Nip 2.75" Iq~ 14205' PERFORATION SUMMARY REF LOG: SS MWD/GR of 10/16!97 ANGLE AT TOP PERF: 54 @ 14464' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 15050 - 15200 Oon 03%27.'06 2" 6 15250 - 15500 Opn 03/27106 2" 6 16100 - 16190 Opn 03/27/06 PBTD --1 14685• 4-1/2" LNR, 12.6#, 13-C R, .0152 bpf, D = 3.958" 14770 P2-36A DRLG DRAFT • SAF OTES: 4-1/2" CHROME TBG & LNR IN WELL. 7" CHROME CSG FROM 13570' TO 14770'. 2227' ~-~ 4-112" CAMCO BAL-O SSSVN, ID = 3.813" ~ ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LTCH PORT DATE 1 5504 4020 55 KBG-2-LS DMY INT 0 07104/05 2 8236 5517 57 KBG-2-LS DOME INT 16 08/21/05 3 9701 6309 57 KBG-2-LS "DMY INT 0 08/12/05 4 10796 6920 56 KBG-2-LS DMY INT 0 10/01/97 5 11679 7417 55 KBG-2-LS SO INT 20 08/21/05 6 13067 8210 58 KBG-2-LS DMY INT 0 10/01/97 7 13915 8681 55 KBG-2-LS '"DMY INT 0 08/12/05 '"DMY HAS EXTENDED PACKING 13942' 7" X 4-112" BKR S-3 PKR, ID = 3.875" 13975 4-1 /2" HES X NIP, 10 = 3.813" 13986' 4-1 /2" HES X NIP, ID = 3.813" 13~ 998' ~~ 4-112" WLEG, ~ = 3.958" 13998' 7" X 4-1 /2" BKR ZXP PKR, ID = 4.760" 13995' ~MD TT LOGGED 09/25/98 14192' ~'-~ 4-1/2" HES X NIP, ID = 3.813" -~ 14439' ~~ 4-1/2" HES X NIP, ID = 3.813" 14450' 3-1/2 x 2-7/8 X-over 16232' Bottom of crated liner 0 0 0 0 0 0 0 3-1/2" X 2-7/8" 13G80 solid liner 16232' 14$47' ~~ 4-1/2" HES CBP DATE REV BY COMMENTS DATE REV BY COMMENTS 10102197 ORIGINAL COMPLETION 07/04/05 DTRlTLH GLV GO 10!06/01 CH/KAK CORRECTIONS 08/20/05 KSB/TLH GLV GO (08/12/05) 05/20/02 JAF/KK SET CIBP 08/21/05 DTR/PJC GLV GO 05!06/03 SRB/KK PERF CORRECTIONS 03/27/06 R.Bordes Side Track -Liner 04/12/04 JPKlPG GLV VERIFICATION 02!15/05 RMWPJC GLV GO PONJT MCM1T1'RE UNff WELL: PZ-36 PERMIT No: 1971600 API No: 50-029-22801-00 SEC 14, T12N, R14E 273' SNL & 1348' EWL, BP Exploration (Alaska) Re: P? 36 Okay to POP ~K~ ,-~ Z~~ `°~ Z,Z- Subject: Rc: P2- ~GOkay to POP From: James Re.g~~ <jimreu~~ci~adznin.slate.ak.us Date: Fri, U7 Apr ?006 1O:~?:08 -Ou00 To: "NS[_1, ~AD~~' Nell It~te~,rity Cngineer" <NSL`f~DtiV~~'elllntc~~ritvEn~~incer~ciRP.cor1~== CC: "E~.ndc~iro~k, Robert ti's"' <-E:ndebrlZ\~~~~i-13P.ci~m=-, "Rossber~~, R Steven" ~~~_Stel~cn.R~:~sshcr~~~'ci~[3P.com=~. "Parker. R..~~n~ire~~~~ ~ ~'~ndre~~~.Parkcr'ci13P.con~=~ "NSU.:~\~)~1' ~\'<11 Operations Supervisor" ~ ~NSI_L4D~~"til'cllOpcrationsSupcrvison~i:I~P.com>, "NSLI, ;~I)\~' ~~~;'I ~[~cch'~ ~NSC~.AI)~1'~1~I~f~crh rr [~P.~~~~n~ "(.PE,. (~P11.A \rr~i ~1~r" (.PBGP~I~i.~~,l.~it'I3P.com~_ "NSLr. AI)\1~ ~V`L ~~ C`oinpleti~~n ~upcrvis~~r" V~~l ! ~I)1\ \1'I ~~(_"~,n~~~Icti~~nSupereisor(c_i;':BP.com>, "GPB, ~~~ell~, Upt l~.n~~" ~GPB\1'cI1sU~~t~~.n~~~'i~-lil'.cun~-_ "l~l'I~. (_)~~lin~iz,i~i~~n Engr" ~~(;PI;(lE,«mi~ator~Ln~r'~r 13P.c~u1~~. "p,i<<~c(; t{~irrv K' ~I-i~irrv.Ln~~c1(c 13P.coi~i >. ~~~iPh. ~i<<s Li[i l i~~~r" (~PBC_iasl~if'tEn_r ~r 13P.~om=>. ~~«;~~n«. <rilbert S (F~ :<<nn \Iobill" ~ ~,..~.°n~~__~,';i'I~I'.~~nm~~, :1~1min ~LUG~`~' Prudhoe Bay ~,«,~,cc ~~rudho~~ h,l~~~l ~~dn~i~~.st~~~~..~l:.u~> ___ I3C'(': Cath~rinc P Foer~lcr eathv focrsl~r'~r~~ulmin.sl,itc.~~l:.u~ Thank you for the email notice and returning my call this morning. As we discussed, go ahead with your plans to test P2-36A without the K-valve to develop input for the proper sizing of the K-valve. Please call if your testing goes beyond 7 days. This authorization is, of course, contingent upon a properly functioning SSV. Production well P2-36A (1-Oil completion) requires the installation of both a SSV and SSSV according to CO 317B. It is interesting that the pool rules (specifically Rule 8) establish the SSSV requirement without reference to the type of control -contradicts 20 AAC 25.265 (Automatic Shut-In Equipment) which requires the installation of a "surface controlled subsurface safety valve system capable of preventing an uncontrolled flow, unless another type of subsurface valve with that capability is approved by the commission." There is no information in CO 317B or the pool rule application suggesting a reason for the difference. >From my understanding, there exists legitimate concern about the proper set up of subsurface controlled subsurface safety valves. The models used to "size" the valve can result in significant errors because of the variability and uncertainty of inputs (mechanical configuration of valve; fluid flow composition; pressures), resulting in the device not providing the intended (required) level of protection. nformation about the sizing model, valve specs, trip pressure determined from model and testing, and any other info you believe helps establish suitability of the K-valve should satifsy our requirements. A Commission inspector should witness the closing test depending on their work load. As mentioned on the phone, we would like to make sure all your K-valve installations reflect our approval. There are apparently not many installed. Providing similar information for those in service would be appreciated so we can accomplish the alternate compliance approval allowed in 20 AAC 25.265. I'll leave it to you to develop a timeline for providing inventory/info. Future installations should follow the process we are using for P2-36A. I suppose it is possible that there was some blanket authorization for the installation of K-valves issued by the Commission in the past, but I do not find any guidance in our files allowing such for Prudhoe Bay Unit fields. If you have something that would change what's been outlined here, I'd appreciate a copy. Jim Regg AOGCC 1 of 2 - 4/7/2006 10:42 AM Re: P2-36 Okay to POP ,. NSU, ADW Well Integrity Engineer wrote: Hi Rob. It's okay to POP P2-36 post-CTD and get a flow test to determine K-Valve sizing Johnny: Jim Regg requested we provide information on the K-Valve such as sizing procedure and valve data. This is to maintain compliance with AOGCC regulation 25.265.a.2. Jim will send an email detailing what sort of information is required. Please call with any questions. Later, Joe 659-5102 2 of 2 4/7/2006 10:42 AM • „~ ~ ~a~a„m., ~a ,,, ~ ~~ ALASSA OIL A1~TD GAS C011T5ERQATIOI~T COMI~'IISSIOI~T Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, PBU P2-36A BP Exploration (Alaska), Inc. Permit No: 206-022 Surface Location: 273' FNL, 1348' FWL, SEC. 14, Bottomhole Location: 2384' FNL, 3995' FWL, SEC Dear Mr. McLaughlin: T12N, R14E, UM . 18, T12N, R14E, UM Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). ~~~ Daniel T. Seamount Jr. Commissioner DATED this day of February, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA AND GAS CONSERVATION CO ISSION PERMIT TO DRILL 20 AAC 25.005 FEB 0 2 2Q06 Alaska Oil & Gas Cons. Commission ia. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development Oil Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU P2-36A -~- 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 17250 TVD 9021ss 12. Field /Pool(s): Prudhoe Bay Field /Point 4a. Location of Well (Governmental Section): Surface: 273' FNL 1348' FWL SEC 14 T12N R14E UM 7. Property Designation: ADL 034627 McIntyre Pool , , . , , , Top of Productive Horizon: 2156' FNL, 1278' FWL, SEC. 18, T12N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: March 7, 2006 ~ Total Depth: 2384' FNL, 3995' FWL, SEC. 18, Ti2N, Rf4E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 3500' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 681590 y- 5998311 Zone- ASP4 10. KB Elevation (Height above GL): 47.55' feet 15. Distance to Nearest Well Within Pool 1320' 16. Deviated Wells: Kickoff Depth: 14495 feet Maximum Hole Angle: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4250 Surface: 3353 ~ 18. asing rogram: Size Specffications Setting Depth To Bottom uantity o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/8" 3-t/2• x 2-7/8• 6.2# / 6.16# L-80 STL 3025' 14225' 8815' 17250' 9021' 9 sx Class 'G' 19. PRESENT W ELL CONDITION SUMM ARY (To tie completed for Redri11 AND Re-entry Operations) Total Depth MD (ft): 14770 Total Depth TVD (ft): 9178 Plugs (measured): 14547 Effective Depth MD (ft): 14547 Effective Depth TVD (ft): 9050 Junk (measured): None Casin Len th Size Cement Volume MD TVD r n r 110' 20" Driven 110' 110' 7170' 9-5/8" 1766 sx Coldset III, 593 sx Class 'G' 7204' 4967' 14110' 7" 36 sx Class 'G' 14142' 8813' P r 777' 4-1/2" 36 sx Class 'G' 13993' - 14770' 8727' - 9178' Perforation Depth MD (ft): 14464' - 14540' Perforation Depth TVD (ft): 9002' - 9046' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer Prepared By Name/Number: Si nature ti' ~,/~,,, Phone 564-4387 Date 2 d-'6 Terrie Hubble, 56a-4628 Commission Use Only Permit To Drill Number: ~, ..p ~, Z. API Number: 50- 029-22801-01-00 Permit~proval Date: 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: ~ f?S ~ ~ ~ ~~` ~D L}DOD ~~',~„ APPROVED BY A roved B a"~ 16~ THE COMMISSION Date ~GREC~ IVED Form 10-401 Revised 06/2004 ~,• ,f ~'~~ ~ ~~ ~ ~ ~~ ~,,,, S~ubmi~ln Duplicate i BP Point McIntyre P2-36A CTD Sidetrack CTD Sidetrack Summary Pre-Rig Work: 1. O AC-LDS; AC-PPPOT-IC, T 2. S Remove K-valve 3. C Drift./ Clean out tubing and liner with 3.8" mill and motor to the CIBP - 14,547' 4. E Set IBP at 13960' 5. O MIT-T, IA, and OA. 6. S Pul1IBP 7. S Caliper the tubing and liner 8. S Run dummy whipstock drift 9. E Set the bottom of the 4-I/2" WS at 14505'. Reference Log: GR/CCL Log of 12/6/97 10. C Cement squeeze perforations - 15.8 ppg cmt (-10 bbl) 11. O Install accumulator for TRSSSV 12. O Bleed gas lift and production flowlines down to zero and blind flange 13. O Remove wellhouse, level pad The pre CTD work is slated to begin on Februa 10; 2006... ~ ~ s I n - tt_ n l a.~ ~ c~.( . Rig Work: 1. MIRU and test BOPE to 250 psi low and~si high. 2. Mill 3.8" window at 14495' and 10' of openhole. Swap the well to Flo-Pro. 3. Drill Build: 4.125" OH, 130' (40 deg/100 planned) 4. Drill Lateral: 4.125" OH, 2625' horizontal (12 deg/100 planned) -include resistivity 5. Run 31/z" x 2 7/8" solid/slotted liner a ing TOL at 14225' ~ 6. Pump primary cement job to TOL, 6 1 of 15.8 ppg liner cmt planned 7. Cleanout run to mill baffle plate 8. Cleanout liner and MCNL/GR/CCL log 9. Test liner lap to 2000 psi. 10. Freeze protect well, RDMO Post-Rig Work 1. Install well house. Hook up flow line. Mud Program: • Well kill: 9.6 pp ri e • Milling/drillin : 9. ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • 31h" x 2 7/8" chrome cemented liner - 14225'MD to 14850'MD • 2-7/8" L-80 slotted liner - 14850' to 17250' MD / • A minimum of 6 bbls 15.8 ppg cement will be used for liner cementing. Casing/Liner Information 9 5/8", L-80 40#, Burst 5750; collapse 3090 psi 7", 13-Cr-80, 29#, Burst 8160; collapse 7020 psi 4 I/z", 13-Cr, 12.6#, Burst 8431; collapse 7500 psi Well Control: • BOP diagram is attached. ~-D4O ~,,lG/~" • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to psi. ` • The annular preventer w~e tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 94 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 3500' ft. from unit boundry • Distance to nearest well within pool -1320' ft to P2-11 Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole GR/CCL log will be run. Hazards • The maximum recorded H2S level on P2 pad i 145 m . • Lost circulation risk is low. Reservoir Pressure • Res. press. is estimated to be 4250 psi at 8973'ss (9.1 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 3353 psi. ~ TREE= 4-1/16" CMJ WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV - 47.55' BF. ELEV = 15.05' KOP = 1020' Max Angle = 59 @ 7998' Datum MD = 14168' Datum TVD = 8800' SS / S NOTES: 4-1/2" CHROM E TBG 8~ LNR IN WELL. 7" CHROM E CSG FROM 13570' TO 14770'. 2227' 4-1/2" CAMCO BAL-O SSSVN, ID = 3.813" 9-5/8" CSG, 40#, L-80, ID = 8.835" ~ 7203' Minimum ID = 3.813" @ 2227' 4-1/2" CAMCO SSSVN 7", 26#, L-80 X 7", 29#, 13-CR CSG XO 13570' 7" MARKER JT (19') 13804' LTOP OF BAKER TIEBACK SLV I 13992' 4-1/2" TBG, 12.6#, 13-C R, .0152 bpf, ID = 3.958" 13997' ~TOPOFBAKERTIEBACKSLV i-1 14001, 7" X 4-1/2" BKR HMC LNR HANGER, ID = 3.938" 14007' 7" CSG, 29#, 13-CR-80, ID = 6.184" ~~ 14141' PERFORATION SUMMARY REF LOG: SS NNVD/GR of 10/16/97 A NGLE AT TOP PERF: 54 @ 14464' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 14464 - 14494 O 07/09/01 2-7/8" 6 14510 - 14540 O 07/09/01 3-318" 6 14561 - 14591 C 12/06/97 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LTCH PORT DATE 1 5504 4020 55 KBG-2-LS DMY INT 0 07/04/05 2 8236 5517 57 KBG-2-LS DOME INT 16 08/21/05 3 9701 6309 57 KBG-2-LS *"'DMY INT 0 08!12/05 4 10796 6920 56 KBG-2-LS DMY INT 0 10/01/97 5 11679 7417 55 KBG-2-LS SO INT 20 08/21/05 6 13067 8210 58 KBG-2-LS DMY INT 0 10/01/97 7 13915 8681 55 KBG-2-LS "*DMY INT 0 08/12/05 "`DMY HAS IXTENDED PACKING 13942' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 13975' 4-1/2" HES X NIP, ID = 3.813" 13986' 4-1/2" HES X NIP. ID = 3.813" 13998' I~ 4-1/2" WLEG, ID = 3.958" 13998' 7" X 4-1/2" BKR ZXP PKR, ID = 4.760" 13995' ELMD TT LOGGED 09/25/98 14192' ~~ 4-1/2" HES X NIP, ID = 3.813" 14439' i-i 4-1/2" HES X NIP, ID = 3.813" 14547' ~~ 4-1/2" HES CIBP PBTD 14685' 4-1/2" LNR, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 14770' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/02/97 ORIGINAL COMPLETION 07/04/05 DTR/TLH GLV C/O 10/06/01 CH/KAK CORRECTIONS 08/20/05 KSB/TLH GLV GO (08/12/05) 05/20/02 JAF/KK SET CIBP 08/21/05 DTR/PJC GLV C/O 05!06/03 SRB/KK PERF CORRECTIONS 04/12/04 JPK/PG GLV VERIFICATION 02/15/05 RMH/PJC GLV GO POINT MCINTYRE UNIT WELL: P2-36 PERMfr No: 1971600 API No: 50-029-22801-00 SEC 14, T12N, R14E 273' SNL & 1348' EWL, BP Exploration (Alaska) WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 47.55' BF. ELEV = 15.05' KOP = 1020' Max Angle = 59 @ 7998' Datum MD = 14168' Datum TV D = 8800' SS P2-36A~ Proposed CTD Sidetrack O 9-5/8" CSG, 40#, L-80, ID = 8.835" 11 7203• Minimum ID = 3.813" @ 2227' 4-1/2" CAMCO SSSVN 7", 26#, L-80 X 7", 29#, 13-CR CSG XO 13570' 7" MARKER JT (19') - ~TOPOFBAKERTIEBACKSLV ~• 4-1/2" TBG, 12.6#, 13-CR .0152 bpf, ID = 3.958" ~TOPOFBAKERTIE~ACKSLV ~--~ 14001, 7" X 4-1/2" BKR HMC LNR HANGER, ID = 3.938" 14007' 7" CSG, 29#, 13-CR-80, ~ = 6.184" 14141 Top of Cement 14225' TOP OF 3-1/2" 13cr80 LNR 14225' 3.5" XN Nip 2.75" I 14235' PERFORATION SUMMARY REF LOG: SS MWDlGR of 10/16/97 ANGLE AT TOP PERF: 54 @ 14464' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 14464 - 14494 isolated proposed 2-7/8" 6 14510 - 14540 isolated proposed 3-3/8" 6 14561 - 14591 isolated proposed PBTD 4-1/2" LNR 12.6#, 13-CR, .0152 bpf, ID = 3.958" ~ 4-1/2" CAMCO BAL-O SSSVN, ID= 3.813" ~ ~ GAS LIFT MANDRELS ST MD TVO DEV TYPE VLV LTCH PORT DATE 1 5504 4020 55 KBG-2-LS DMY INT 0 07/04/05 2 8236 5517 57 KBG-2-LS DOME INT 16 08/21/05 3 9701 6309 57 KBG-2-LS "'DMY WT 0 08/12/05 4 10796 6920 56 KBG-2-LS DMY INT 0 10/01/97 5 11679 7417 55 KBG-2-LS SO NVT 20 08/21/05 6 13067 8210 58 KBG-2-LS DMY INT 0 10/01/97 7 13915 8681 55 KBG-2-LS '"DMY INT 0 08/12/05 °oM r nns tx t tnutu rA~run~ -3942' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 13975' ~4-1/2" HES X NIP, ID = 3.813" 13986 4-1/2" HES X NIP, ID = 3.813" 13~ 998' I-1 4-1/2" WLEG, ID = 3.958" 13998' 7" X 4-1 /2" BKR ZXP PKR, ID = 4.760" 13995' ELMD TT LOGGED 09/25/98 4-1 /2" HES X NIP, ID = 3.813" 14439' 4-1/2" HES X NIP, ID = 3.813" 14490' 3-1/2 ®2-7/8~ 14850' -{Bottom of crated liner 3-1/2" X 2-7/8" 13Cr80 bonzai liner 14495' Mechanical Whipstock 14547' ~~ 4-1/2" HES CIBP / ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 10/02/97 ORIGINAL COMPLETION 07/04/05 DTR/TLH GLV GO 10/06/01 CH/KAK CORRECTIONS 08/20/05 KSB/TLH GLV GO (08/12/05) 05/20/02 JAF/KK SET CIBP 08/21/05 DTR/PJC GLV GO 05/06/03 SRB/KK PERF CORRECTIONS 04/12/04 JPK/PG GLV VERIFICATION 02/15/05 RMWPJC GLV GO POINT MCIMY RE UNIT WELL: P2-36 PERMIT No: 1971600 API No: 50-029-22801-00 SEC 14, T12N, R14E 273' SNL & 1348' I BP Exploration (Alaska) SA OTES: 4-1/2" CHROM E TBG 8< LNR IN WELL. 7" CHROME CSG FROM 13570' TO 14770'. BP Alaska by Baker Hughes INTEQ Planning Report BAIQR ^ I~u~es INTEQ Company: BP Amoco ]Date: 1/17/2006 Time: 10:23:17 Psge: 1 Field: Point McIntyre Co-ordioate(NE) Reference: Well:: P2-36, True North Site: Pt Mac 2 Vertical (TVD) Refereuce: - 51:36 5/211199711:55 46.6 Well: P2-36 Seetiou (VS) Reference: W811(O.OON,O.OOE,99.54Azi) Wellpath: Pian 6, P2-37A Survey Calculatbu Method: Minimum Curvature Db: Oracle Field: Point McIntyre North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Madei: bggm2005 Site: Pt Mac 2 TR-12-14 UNITED STATES :North Slope Site Positlon: Northiug: From: Map Easting: 5995140.76 R 674873.98 ft Latitude: 70 Longitude: 148 23 32.530 N 34 37.934 W Position Uncertainty: 0.00 R North Reference: Tale Ground Level: 0.00 R Grid Couvergeuce: 1.34 deg Well: P2-36 Slot Name: 36 P2-36 Well Position: +N/-S 3012.93 ft Northing: 5998311.46 ft Latitude: 70 24 2.131 N +E/-W 6789.17 ft Eastiug : 681590.37 ft Longitude: 148 31 19.035 W Position Uncertainty: 0.00 ft Wellpath: Plan 6, P2-37A DrLled From: P2-36 Tie-ou Depth: 14465.00 ft Current Datum: 51:36 5/21/1997 11:55 Height 46.60 ft Above System Datum: Mean Sea Level ~ Magnetic Data: 1/17/2006 Decliuatiou: 24.76 deg Field Strength: 57616 nT Mag Dip Angle: 80.97 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ~, ft R ft deg 34.50 0.00 0.00 99.54 Plan: Plan #6 Date Composed: 1/17/2006 Version: 5 Principal: Yes Tied-to: From: Definitive Path Targets Map.. Map <-- Latitatle --> ~-- Longitude --> Nsme Description TVD +N/-S +E/-W Northing.. IEaatiug Deg Mia Sec " Deg Min Sec Dip. _ Dir. ft ft ft ft ft P2-36A Polygon 46.60 -2136.73 10431.06 5996428.97 692069.62 70 23 41.045 N 148 26 13.529 W -Polygon 1 46.60 -2136.73 10431.06 5996428.97 692069.62 70 23 41.045 N 148 26 13.529 W -Polygon 2 46.60 -2236.80 13519.04 5996403.97 695158.92 70 23 40.012 N 148 24 43.094 W -Polygon 3 46.60 -1836.49 13512.06 5996803.97 695142.22 70 23 43.949 N 148 24 43.277 W -Polygon 4 46.60 -1643.64 10434.65 5996921.97 692061.22 70 23 45.894 N 148 26 13.404 W P2-36A Faultl 46.60 -984.35 9445.11 5997556.97 691056.02 70 23 52.391 N 148 26 42.363 W -Polygon 1 46.60 -984.35 9445.11 5997556.97 691056.02 70 23 52.391 N 148 26 42.363 W -Polygon 2 46.60 -1458.79 11431.29 5997130.97 693053.02 70 23 47.698 N 148 25 44.204 W -Polygon 3 46.60 -1533.95 13618.25 5997108.97 695241.02 70 23 46.923 N 148 24 40.150 W -Polygon 4 46.60 -1458.79 11431.29 5997130.97 693053.02 70 23 47.698 N 148 25 44.204 W P2-36A Targetl 9032.60 -1942.23 10948.38 5996635.97 692582.03 70 23 42.951 N 148 25 58.369 W P2-36A Target2 9044.60 -1973.99 11390.76 5996614.96 693025.03 70 23 42.632 N 148 25 45.414 W P2-36A Target3 9066.60 -2107.30 13212.18 5996525.96 694849.03 70 23 41.291 N 148 24 52.074 W Annotation MD R TVD ft 14465.00 9002.65 TIP 14495.00 9020.16 KOP 14515.00 9031.57 End of 9 Deg/100' DLS 14611.02 9055.49 End of 40 Deg/100' DLS 14701.02 9048.92 5 14901.02 9035.85 6 14961.02 9033.58 7 15286.02 9038.60 8 15411.02 9044.31 9 15576.02 9050.02 10 15876.02 9056.11 11 BP Alaska by Baker Hughes INTEQ Planning Report s~ INTEQ Company: BP Amoco > Date: . 1/17!2006 Time:. 110:23:17 Page: 2 Field: Point McIntyre Co-ordinate(NE) Reference: We1L•' P2-36, True North - Site: Pt Mac 2 Vertkal_(1'VD) Reference: 5 1:36 5/21/199711:55 46.8 Well: P2-36 Section (VS) Reference: Well (O.OON.O.OOE,99.54Azi) Wellpat6: Plan fi, P2-37A Survey Calculation Method:. MinimumGurvature Db: Orate Annotation MD , TVD ft -ft 16176.02 9061.03 12 16476.02 9065.01 13 16776.02 9068.24 14 17076.02 9068.46 15 17250.00 9067.12 TD Plan Section Information MD inch Azim 'fVD +NiS +EJ-W DLS Build Turn TFO ...Target. ft deg deg tt ft ft deg/100ft deg/1OOft deg/100ft deg 14465.00 54.31 96.62 9002.65 -1875.60 10492.58 0.00 0.00 0.00 0.00 14495.00 54.29 96.34 9020.16 -1878.35 10516.79 0.76 -0.07 -0.93 264.89 14515.00 56.09 96.34 9031.57 -1880.17 10533.11 9.00 9.00 0.00 0.00 14611.02 94.50 96.34 9055.49 -1890.23 10623.70 40.00 40.00 0.00 0.00 14701.02 93.86 85.53 9048.92 -1891.69 10713.31 12.00 -0.71 -12.01 267.00 14901.02 93.52 109.58 9035.85 -1917.74 10909.70 12.00 -0.17 12.02 90.00 14961.02 90.81 116.25 9033.58 -1941.08 10964.89 12.00 -4.52 11.12 112.00 15286.02 87.49 77.38 9038.60 -1978.97 11281.35 12.00 -1.02 -11.96 265.00 15411.02 87.31 92.40 9044.31 -1967.88 11405.37 12.00 -0.14 12.01 91.00 15576.02 88.76 112.16 9050.02 -2002.78 11565.70 12.00 0.88 11.98 86.20 15876.02 88.99 76.15 9056.11 -2024.16 11859.95 12.00 0.08 -12.00 270.00 16176.02 89.19 112.16 9061.03 -2045.53 12154.22 12.00 0.06 12.00 90.00 16476.02 89.34 76.15 9065.01 -2066.91 12448.51 12.00 0.05 -12.00 270.00 16776.02 89.47 112.16 9068.24 -2088.29 12742.81 12.00 0.04 12.00 90.00 17076.02 90.45 76.17 9068.46 -2109.70 13037.12 12.00 0.33 -12.00 271.50 17250.00 90.42 97.05 9067.12 -2099.46 13209.83 12.00 -0.02 12.00 90.00 Survey MD Intl Azim Sys 1'VD N!S E/W MspN MapE - DLS VS ' TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 14465.00 54.31 96.62 8956.05 -1875.60 10492.58 5996691.49 692124.78 0.00 10658.32 0.00 MWD 14495.00 54.29 96.34 8973.56 -1878.35 10516.79 5996689.33 692149.04 0.76 10682.65 264.89 MWD 14500.00 54.74 96.34 8976.46 -1878.80 10520.83 5996688.98 692153.10 9.00 10686.71 0.00 MWD 14515.00 56.09 96.34 8984.97 -1880.17 10533.11 5996687.92 692165.40 9.00 10699.04 0.00 MWD 14516.86 56.83 96.34 8986.00 -1880.34 10534.65 5996687.78 692166.94 40.00 10700.59 360.00 P2-36A 14520.00 58.09 96.34 8987.69 -1880.63 10537.28 5996687.55 692169.58 0.00 10703.24 0.00 MWD 14530.00 62.09 96.34 8992.67 -1881.59 10545.89 5996686.81 692178.21 40.00 10711.89 0.00 MWD 14540.00 66.09 96.34 8997.04 -1882.58 10554.83 5996686.03 692187.17 40.00 10720.87 0.00 MWD 14542.41 67.05 96.34 8998.00 -1882.82 10557.03 5996685.84 692189.37 40.00 10723.07 0.00 P2-36A 14550.00 70.09 96.34 9000.77 -1883.60 10564.05 5996685.23 692196.41 40.00 10730.13 360.00 MWD 14560.00 74.09 96.34 9003.85 -1884.66 10573.51 5996684.41 692205.89 40.00 10739.63 0.00 MWD 14570.00 78.09 96.34 9006.25 -1885.73 10583.15 5996683.57 692215.56 40.00 10749.32 0.00 MWD 14580.00 82.09 96.34 9007.97 -1886.81 10592.94 5996682.72 692225.37 40.00 10759.15 0.00 MWD 14590.00 86.09 96.34 9009.00 -1887.91 10602.82 5996681.87 692235.28 40.00 10769.08 0.00 MWD 14600.00 90.09 96.34 9009.34 -1889.02 10612.75 5996681.01 692245.23 40.00 10779.06 0.00 MWD 14610.00 94.09 96.34 9008.97 -1890.12 10622.68 5996680.14 692255.19 40.00 10789.03 0.00 MWD 14611.02 94.50 96.34 9008.89 -1890.23 10623.70 5996680.06 692256.20 40.00 10790.05 0.00 MWD 14625.00 94.41 94.66 9007.81 -1891.57 10637.57 5996679.06 692270.10 12.00 10803.95 267.00 MWD 14650.00 94.24 91.66 9005.92 -1892.94 10662.46 5996678.29 692295.01 12.00 10828.72 266.87 MWD 14675.00 94.06 88.65 9004.11 -1893.01 10687.39 5996678.83 692319.94 12.00 10853.32 266.64 MWD 14701.02 93.86 85.53 9002.32 -1891.69 10713.31 5996680.77 692345.82 12.00 10878.67 266.43 MWD 14725.00 93.85 88.41 9000.70 -1890.43 10737.20 5996682.62 692369.67 12.00 10902.01 90.00 MWD 14750.00 93.84 91.42 8999.03 -1890.39 10762.14 5996683.26 692394.60 12.00 10926.60 90.19 MWD 14775.00 93.81 94.43 8997.36 -1891.66 10787.05 5996682.59 692419.53 12.00 10951.38 90.40 MWD 14800.00 93.78 97.43 8995.70 -1894.24 10811.86 5996680.62 692444.39 12.00 10976.27 90.60 MWD 14825.00 93.73 100.44 8994.07 -1898.12 10836.50 5996677.35 692469.12 12.00 11001.22 90.80 MWD 14850.00 93.67 103.45 8992.45 -1903.28 10860.90 5996672.78 692493.64 12.00 11026.14 90.99 MWD 14875.00 93.60 106.45 8990.87 -1909.71 10885.01 5996666.93 692517.89 12.00 11050.97 91.19 MWD 14901.02 93.52 109.58 8989.25 -1917.74 10909.70 5996659.50 692542.77 12.00 11076.66 91.38 MWD 14925.00 92.44 112.25 8988.00 -1926.29 10932.07 5996651.50 692565.34 12.00 11100.13 112.00 MWD 14950.00 91.31 115.03 8987.18 -1936.31 10954.95 5996642.05 692588.46 12.00 11124.36 112.14 MWD 14961.02 90.81 116.25 8986.98 -1941.08 10964.89 5996637.52 692598.51 12.00 11134.95 112.23 MWD BP Alaska by Baker Hughes INTEQ Planning Report BA ~R • I-~s INTEQ Company: BP Amoco Date: 1/17/2006 Tlme: 10:23:17 Page: 3 Field: Point MclMyre Co-ordinate(NE) References Weq: P2-36, True North Site: Pt Mac 2 Vertical (TVD) Reference: 5T : 3i3 5/21/19971.1:55. 46.6 Well: P2-36 Section (VS) Reference: Well (l).pON,0.00E,99.54Azi) Wellpath: Plan 6, P2-37A Snrvey Cakuiatlon Method: Minimum Curvature ` 1)bc Oracle Survey MD Incl Azim Sya TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg .deg ft ft ft ft ft deg/100ft $ deg 14975.00 90.66 114.58 8986.80 -1947.08 10977.51 5996631.83 692611.27 12.00 11148.39 265.00 MWD 15000.00 90.40 111.59 8986.56 -1956.88 11000.51 5996622.59 692634.49 12.00 11172.69 264.98 MWD 15025.00 90.14 108.60 8986.45 -1965.47 11023.98 5996614.57 692658.17 12.00 11197.27 264.95 MWD 15050.00 89.87 105.62 8986.45 -1972.82 11047.87 5996607.80 692682.23 12.00 11222.05. 264.94 MWD 15075.00 89.61 102.63 8986.56 -1978.92 11072.11 5996602.30 692706.61 12.00 11246.96 264.94 MWD 15100.00 89.34 99.64 8986.79 -1983.75 11096.64 5996598.07 692731.25 12.00 11271.95 264.95 MWD 15125.00 89.08 96.65 8987.13 -1987.29 11121.38 5996595.13 692756.07 12.00 11296.94 264.98 MWD 15150.00 88.82 93.66 8987.59 -1989.53 11146.27 5996593.49 692781.00 12.00 11321.86 265.02 MWD 15175.00 88.57 90.67 8988.16 -1990.48 11171.25 5996593.15 692805.99 12.00 11346.64 265.07 MWD 15200.00 88.31 87.68 8988.84 -1990.12 11196.23 5996594.12 692830.96 12.00 11371.22 265.14 MWD 15225.00 88.07 84.69 8989.63 -1988.46 11221.16 5996596.38 692855.84 12.00 11395.53 265.22 MWD 15250.00 87.82 81.70 8990.53 -1985.50 11245.97 5996599.94 692880.56 12.00 11419.50 265.32 MWD 15275.00 87.59 78.70 8991.53 -1981.25 11270.58 5996604.79 692905.06 12.00 11443.07 265.43 MWD 15286.02 87.49 77.38 8992.00 -1978.97 11281.35 5996607.33 692915.78 12.00 11453.32 265.54 MWD 15300.00 87.46 79.06 8992.62 -1976.12 11295.02 5996610.52 692929.37 12.00 11466.32 91.00 MWO 15325.00 87.41 82.07 8993.74 -1972.02 11319.66 5996615.21 692953.90 12.00 11489.94 90.93 MWD 15350.00 87.37 85.07 8994.88 -1969.22 11344.47 5996618.61 692978.63 12.00 11513.95 90.79 MWD 15375.00 87.34 88.07 8996.03 -1967.73 11369.40 5996620.71 693003.51 12.00 11538.28 90.66 MWD 15400.00 87.32 91.07 8997.19 -1967.54 11394.37 5996621.50 693028.47 12.00 11562.87 90.52 MWD 15411.02 87.31 92.40 8997.71 -1967.88 11405.37 5996621.43 693039.48 12.00 11573.78 90.38 MWD 15425.00 87.43 94.07 8998.35 -1968.67 11419.31 5996620.98 693053.43 12.00 11587.66 86.20 MWD 15450.00 87.63 97.07 8999.43 -1971.09 11444.17 5996619.16 693078.34 12.00 11612.57 86.12 MWD 15475.00 87.84 100.06 9000.42 -1974.81 11468.87 5996616.04 693103.12 12.00 11637.55 85.99 MWD 15500.00 88.06 103.06 9001.31 -1979.82 11493.34 5996611.63 693127.71 12.00 11662.51 85.88 MWD 15525.00 88.29 106.05 9002.10 -1986.10 11517.52 5996605.94 693152.03 12.00 11687.40 85.77 MWD 15550.00 88.52 109.04 9002.80 -1993.63 11541.35 5996598.99 693176.03 12.00 11712.15 85.67 MWD 15576.02 88.76 112.16 9003.42 -2002.78 11565.70 5996590.43 693200.60 12.00 11737.68 85.59 MWD 15600.00 88.76 109.28 9003.94 -2011.26 11588.11 5996582.50 693223.21 12.00 11761.19 270.00 MWD 15625.00 88.76 106.28 9004.48 -2018.90 11611.91 5996575.45 693247.19 12.00 11785.92 270.06 MWD 15650.00 88.77 103.28 9005.02 -2025.27 11636.08 5996569.67 693271.50 12.00 11810.81 270.13 MWD 15675.00 88.78 100.28 9005.55 -2030.37 11660.54 5996565.16 693296.08 12.00 11835.78 270.19 MWD 15700.00 88.80 97.28 9006.08 -2034.19 11685.24 5996561.95 693320.86 12.00 11860.77 270.26 MWD 15725.00 88.82 94.28 9006.60 -2036.70 11710.11 5996560.04 693345.78 12.00 11885.71 270.32 MWD 15750.00 88.84 91.28 9007.11 -2037.91 11735.07 5996559.43 693370.76 12.00 11910.53 270.38 MWD 15775.00 88.86 88.28 9007.61 -2037.82 11760.06 5996560.14 693395.74 12.00 11935.16 270.44 MWD 15800.00 88.89 85.28 9008.10 -2036.41 11785.01 5996562.15 693420.65 12.00 11959.53 270.50 MWD 15825.00 88.92 82.28 9008.58 -2033.70 11809.86 5996565.46 693445.42 12.00 11983.58 270.56 MWD 15850.00 88.96 79.28 9009.04 -2029.69 11834.53 5996570.07 693469.99 12.00 12007.25 270.62 MWD 15876.02 88.99 76.15 9009.51 -2024.16 11859.95 5996576.22 693495.26 12.00 12031.40 270.67 MWD 15900.00 89.00 79.03 9009.93 -2019.01 11883.36 5996581.94 693518.54 12.00 12053.63 90.00 MWD 15925.00 89.00 82.03 9010.37 -2014.89 11908.01 5996586.65 693543.08 12.00 12077.26 89.95 MWD 15950.00 89.01 85.03 9010.80 -2012.08 11932.84 5996590.06 693567.84 12.00 12101.29 89.90 MWD 15975.00 89.02 88.03 9011.23 -2010.57 11957.79 5996592.18 693592.74 12.00 12125.64 89.84 MWD 16000.00 89.03 91.03 9011.66 -2010.36 11982.79 5996592.99 693617.72 12.00 12150.25 89.79 MWD 16025.00 89.04 94.03 9012.08 -2011.46 12007.75 5996592.50 693642.71 12.00 12175.06 89.74 MWD 16050.00 89.06 97.03 9012.49 -2013.87 12032.63 5996590.69 693667.63 12.00 12199.99 89.69 MWD 16075.00 89.08 100.03 9012.90 -2017.58 12057.35 5996587.59 693692.43 12.00 12224.98 89.64 MWD 16100.00 89.10 .103.03 9013.29 -2022.58 12081.84 5996583.19 693717.03 12.00 12249.96 89.59 MWD 16125.00 89.13 106.03 9013.68 -2028.85 12106.03 5996577.51 693741.37 12.00 12274.86 89.55 MWO 16150.00 89.16 109.03 9014.05 -2036.38 12129.87 5996570.56 693765.38 12.00 12299.61 89.50 MWD 16176.02 89.19 112.16 9014.43 -2045.53 12154.22 5996562.00 693789.95 12.00 12325.15 89.45 MWD 16200.00 89.19 109.28 9014.77 -2054.01 12176.64 5996554.07 693812.57 12.00 12348.66 270.00 MWD 16225.00 89.19 106.28 9015.13 -2061.64 12200.44 5996547.02 693836.55 12.00 12373.40 270.04 MWD 16250.00 89.20 103.28 9015.48 -2068.02 12224.61 5996541.23 693860.86 12.00 12398.29 270.08 . MWD 16275.00 89.20 100.28 9015.83 -2073.12 12249.08 5996536.73 693885.44 12.00 12423.27 270.13 MWD 16300.00 89.21 97.28 9016.17 -2076.94 12273.78 5996533.51 693910.23 12.00 12448.26 270.17 MWD 16325.00 89.23 94.28 9016.51 -2079.45 12298.65 5996531.60 693935.15 12.00 12473.20 270.21 MWD 16350.00 89.24 91.28 9016.85 -2080.66 12323.61 5996531.00 693960.14 12.00 12498.02 270.25 MWD BP Alaska by Baker Hughes INTEQ Planning Report ~a~ ~iiEs 1NTEQ Company: BP Amoco Date: 1/17/2006 Time. 10:23:17 Page: 4 pYeld: Point McIntyre Co-ordtnate(NE) Reference: We11: P2-36, Tru® North Site: Pt Mac 2 Vertical (TVD) Reference: 51:36 5/2:1/1997 11:55 46.6 Well: P2-36 Seetioa(VS) Reference: Well-(O.OON,O.OOE,99.54Azi) Welipath: Plan 6, P2-37A Survey Caknlation Method: Minimum Curvature Db: Orade Survey MD Ind Azim SysTVD N/S E/W MapN MapE DLS VS TFO Toole ft deg deg ft ft R ft tt degl100R ft deg 16375.00 89.26 88.28 9017.17 -2080.57 12348.61 5996531.70 693985.12 12.00 12522.65 270.29 MWD 16400.00 89.27 85.28 9017.49 -2079.16 12373.57 5996533.71 694010.03 12.00 12547.03 270.33 MWD 16425.00 89.29 82.28 9017.81 -2076.45 12398.41 5996537.03 694034.81 12.00 12571.09 270.37 MWD 16450.00 89.32 79.28 9018.11 -2072.45 12423.09 5996541.63 694059.37 12.00 12594.76 270.41 MWD 16476.02 89.34 76.15 9018.41 -2066.91 12448.51 5996547.78 694084.65 12.00 12618.91 270.44 MWD 16500,00 89.34 79.03 9018.69 -2061.76 12471.92 5996553.50 694107.93 12.00 12641.14 90.00 MWD 16525.00 89.35 82.03 9018.98 -2057.65 12496.58 5996558.21 694132.48 12.00 12664.78 89.97 MWD 16550.00 89.35 85.03 9019.26 -2054.83 12521.41 5996561.63 694157.23 12.00 12688.80 89.93 MWD 16575.00 89.36 88.03 9019.54 -2053.32 12546.36 5996563.75 694182.14 12.00 12713.16 89.90 MWD 16600.00 89.36 91.03 9019.82 -2053.11 12571.36 5996564.56 694207.12 12.00 12737.77 89.86 MWD 16625.00 89.37 94.03 9020.10 -2054.22 12596.33 5996564.06 694232.11 12.00 12762.58 89.83 MWD 16650.00 89.39 97.03 9020.37 -2056.63 12621.21 5996562.26 694257.04 12.00 12787.52 89.80 MWD 16675.00 89.40 100.03 9020.63 -2060.34 12645.93 5996559.15 694281.84 12.00 12812.51 89.77 MWD 16700.00 89.41 103.03 9020.89 -2065.33 12670.42 5996554.75 694306.44 12.00 12837.49 89.73 MWD 16725.00 89.43 106.03 9021.15 -2071.60 12694.61 5996549.07 694330.78 12.00 12862.39 89.70 MWD 16750.00 89.45 109.03 9021.39 -2079.13 12718.45 5996542.12 694354.79 12.00 12887.14 89.67 MWD 16776.02 89.47 112.16 9021.64 -2088.29 12742.81 5996533.57 694379.36 12.00 12912.68 89.64 MWD 16800.00 89.54 109.28 9021.84 -2096.77 12765.23 5996525.63 694401.98 12.00 12936.20 271.50 MWD 16825.00 89.62 106.28 9022.03 -2104.40 12789.03 5996518.58 694425.96 12.00 12960.94 271.52 MWD 16850.00 89.71 103.28 9022.17 -2110.78 12813.20 5996512.79 694450.28 12.00 12985.83 271.55 MWD 16875.00 89.79 100.28 9022.28 -2115.88 12837.67 5996508.29 694474.86 12.00 13010.81 271.56 MWD 16900.00 89.87 97.28 9022.36 -2119.70 12862.37 5996505.07 694499.65 12.00 13035.80 271.58 MWD 16925.00 89.95 94.28 9022.40 -2122.22 12887.24 5996503.16 694524.57 12.00 13060.74 271.59 MWD 16950.00 90.04 91.29 9022.40 -2123.43 12912.21 5996502.55 694549.56 12.00 13085.57 271.59 MWD 16975.00 90.12 88.29 9022.36 -2123.34 12937.21 5996503.25 694574.55 12.00 13110.20 271.59 MWD 17000.00 90.20 85.29 9022.29 -2121.94 12962.17 5996505.26 694599.46 12.00 13134.58 271.59 MWD 17025.00 90.29 82.29 9022.19 -2119.23 12987.02 5996508.56 694624.24 12.00 13158.64 271.58 MWD 17050.00 90.37 79.29 9022.04 -2115.23 13011.69 5996513.16 694648.81 12.00 13182.31 271.57 MWD 17076.02 90.45 76.17 9021.86 -2109.70 13037.12 5996519.31 694674.09 12.00 13206.47 271.55 MWD 17100.00 90.45 79.05 9021.67 -2104.56 13060.53 5996525.02 694697.37 12.00 13228.71 90.00 MWD 17125.00 90.45 82.05 9021.47 -2100.45 13085.19 5996529.73 694721.92 12.00 13252.34 90.02 MWD 17150.00 90.45 85.05 9021.28 -2097.64 13110.03 5996533.14 694746.68 12.00 13276.37 90.05 MWD 17175.00 90.44 88.05 9021.08 -2096.13 13134.98 5996535.25 694771.58 12.00 13300.73 90.07 MWD 17200.00 90.44 91.05 9020.89 -2095.94 13159.97 5996536.06 694796.57 12.00 13325.35 90.09 MWD 17225.00 90.43 94.05 9020.70 -2097.05 13184.94 5996535.55 694821.56 12.00 13350.16 90.12 MWD 17250.00 ~ 90.42 97.05 9020.52 -2099.46 13209.83 5996533.74 694846.49 12.00 13375.10 90.14 3.5 • Q ~. _ t ---'~--'~ -~----.-. -r -~ - ~` ~ ' z s I ( a - 1 1 ~ +-- a - i . ~ f r _ ...r .. a . _ ~ ~ ~ i k r , .. _ .. ........4...../..._. .... ~ F Y ~ , .~.. ...~... ..r..... a ,..... .... ~ .. ... __._._t _......}_..__--~ ................ ... 1..........___....... ` ., S + - ~ t.'- T 1 _ _ 1 j - ~' A ~ h ~ =A ~~St~~ 'r ~ ~ ---F- ~ _. t# 1 d a ~ ~ t. t _ _'- t f g g a $ &~ . ~ ~ i ~.. __ x _. .. .. ... ..r ~ ...~ . -_~ V -_+.. ~. _. f... .~1 . .. _ .. ___ ___ : __ i....._.. ~_._. __ . _ . - - _.1...__....~ .~L ......r.... ..._._._.___-r--_ : ~-.~u___... .. ......................_._............_....-J.......-l.. __._.... ..._.. .. t F i 1 ~ ._.. t.:' __.. .. 1 t ... ~. ... .i..... 1 _. .. _.....__. 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'__. -::. x~ d 0 C ~ • urements are ser i ~_ of bag 1 P2-36 BAG 7 1/16" 5000 psi. bttm of slips of pipes cross Blind/Shears 2 3/8" combi ram/slips Mud Cross of blind/shears variable bore pipe 3 1/2"-2 3/8" of nines/cline 2 3/8" combi ram/slips TOTs 7 1/16" 5000psi Mud Cross 7 1/16" 5000psi TOTs ~ 7 1 /16" 5000psi Flow Tee TERRIE L RUBBLE BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 PAY TO THE OF)pER OF First National Bank Alaska _ Anchorage, AK 99507 MEMO ~~~~~~ 89-6/1252 2rJ2 DATE ~~~~~~~~ s ICS: a° ~:L252OOO6O~:99L4~~~6227~~~1556~~' 0252 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~__~~-~ U 2 ~ ~~(-~/ 1 PTD# Zc~ - O 2 Z-- Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(fj, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/25/06 C:\j ody\transmittal_checklist • • ^^ ~ y , , , ° o. , y y ~ ~ ~ ~ ~ ~ ~ ~ , N ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ C I ~ ~ ~ ~ ~ ~ ~ i . ~ p ~ ~ ; a ~ ~I ~ ~ ; ~ i ¢ ~ •~;; o. ° o: .Q ~ , E N ~ O O. ~ O. ~ ~ ~ ~ ~ Y ~ ~ ~ ~ ~ O~ ~ ~ ~ ~ ~ ~ ~ fn, ~ U x' (n~ ~~ F-, ~ ~ `~, y N tll' N y~ y~ tlh N, N, N, VA UL M~ y y, N, N, d, N, N: y, y. N, N, y, ~ N, ¢, ¢, ¢: ¢,. ~ .. ¢, ¢, ¢, ¢, O, y' y y' N, N, N, y' y: y, y~ y y' N, ¢, N, N, N, N. N, y. ~ N, ¢, O, ~ ¢: ~ ¢: ¢, , ¢, Q . >~, , ~, ~', }, ~', ~-, >~, ~', }, ~, ~', ~, }, Z, Z: Z, Z, Z.. Z, Z. Z. 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N ~ _ •~ ~ U o J c a U c a¢ I ~ O $ U U > ~ ¢ ~ I IL Q ?~ ~ p Q ~ > ¢ • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made io chronologically . organize this category of information. • tapescan.txt **'~* REEL HEADER **** MWD 09/07/08 BHI O1 LIS Customer Format Tape ~~`** TAPE HEADER **** MWD 06/03/25 ~+ , t~ffj r, y' a'~~~1 Z. ~riwid~w` .'~ ~ ~1_ ,. y 1100529 Ol 3.125" CTK *** LIS COMMENT RECORD *** ~ !!!!!!!!! !!!!!!!!!! Remark File Version 1.000 !!!!!!!!! !!!!!!!!!! Extract File: ldwg.las ~version rnformation VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame ~well znf ormation Block #MNEM.UNI T Data Type Information #-------- - ------------- ------------------------------- STRT.FT 14492.0000: Starting Depth STOP.FT 16283.5000: Ending ~epth STEP.FT 0.5000: Level Spacing Nu~~. -999.2500: absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: P2-36A FLD . FIELD: Point McIntyre LOC . LOCATION: 70 deg 24' 1.131"N 148 deg 31' 19.035"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: 25 Mar 2006 API . API NUMBER: 500292280101 ~Paramete r znformation Block #MNEM.UNI T Valu e Description #-------- - -------------- ----------- ------------------------------- SECT. 14 . Section TOWN.N T12N . Township RANG. R14E . Rdrlg2 PDAT. MSL . Permanent Datum EPD .F 0 . Elevation Of Perm. Datum LMF . DF . Log Measured from FAPD.F 46.6 . Feet Above Perm. Datum DMF . DF . Drilling Measured From EKB .F 0 . Elevation of Kelly Bushing EDF .F 46.6 . Elevation of Derrick Floor EGL .F 0 . Elevation of Ground Level CASE.F N/A . Casing Depth OS1 . DIRECTIONAL . Other S21'ViCes L1112 1 ~Remarks <1) All depths are Measure d Depths (MD) at the Bit unless otherwise noted. (2) All Gamma Ray and Resi stivity are Memory data. (3) Bak er Hughes INTEQ uti lized CoilTrak downhole tools and the Advantage surface system to log this well. Page 1 ~(~,-pc~o~ ~ `?535~ ~ ~ tapescan.txt (4) Tools ran in this string include BCPM (Bi-directional communications and Power Module), DPS (Drilling Performance Sub, downhole WoB and Pressure), DGS (~irectional and Gamma Sub), HOT <Hydraulic orienting 5ub with Near Bit znclination), and USMPR (Ultra Slim Multiple Propagation Resistivity) (5) Data presented here is final and has been depth adjusted to PoC <Primary ~epth Control) log provided by schlumberger GR CCNL dated 26 Mar 2006 per ~ave Boyer with BP Exploration (,4laska), Inc. (6) The sidetrack was drilled from P2-36 through a milled window in 7 5/8 inch cas~ng. Top of window 14493 feet MD (8977 feet Tv~ss) Bottom of window 14499 feet MD (8975 feet Tvo55) (7) The interval from 16277 feet to 16247 feet MD (8986 feet to 8983 feet Tvoss) was not logged due to sensor to bit offset at well T~. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP~VG -> Rate of Penetration, feet/hour ~,4C~x -> rtesistivity <AT)(LS)400kHZ-Compensated Borehole Corrected (OHMM) rtacHx -> Resistivity (aT)(~5)2MHZ-compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHZ-Compensated Borehole Corrected (OHMM) RPCHX -> Re5i5tivity (PD)(LS)2MHz-Compensated aorehole Corrected (OHMM) TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, 14496, 14501.1, 14497.8, 14503.4, 14500, 14504.7, 14502.3, 14508, 14506, 14510.2, 14509.8, 14514.9, 14512.9, 14517.8, 14518.9, 14525.1, 14524, 14530, 14527.3, 14532.6, 14529.5, 14535.1, 14536.6, 14543, 14540.2, 14546.4, 14545.2, 14549.9, 14547.9, 14552.6, 14549.5, 14554.6, 14564.2, 14566.7, 14568.2, 14571.1, 14578.4, 14585.5, 14592.1, 14603.8, 14595.4, 14607.6, 14610.9, 14623.3, 14623.7, 14635.9, 14640.3, 14654, 14657.6, 14670.9, 14669.7, 14680.6, 14696.7, 14701.3, 14725.2, 14733.4, 14727.8, 14736.5, 14737.6, 14748.7, 14741.2, 14753.6, 14742.9, 14755.6, 14749.6, 14762.2, 14774.4, 14787.1, 14806.6, 14813.5, 14808.4, 14815.7, 14810.9, 14819.1, 14826.2, 14832.9, 14832, 14840.2, 14857.1, 14861.7, 14860.2, 14865.1, 14862.4, 14867.9, 14865.3, 14873.5, 14868.4, 14878, 14883.7, 14891.1, 14887.5, 14894.8, DISPLACEMENT 5.09961 5.64648 4.73633 5.64648 4.18945 5.10059 4.91797 6.19336 6.01074 5.28223 5.64746 6.375 6.19336 4.73633 4.73633 5.09961 2.5498 2.91406 7.10352 11.6572 12.2041 12.3867 12.2041 13.6611 13.2969 10.9297 4.55371 8.19629 8.74316 11.1113 12.3857 12.751 12.5674 12.751 6.9209 7.28613 8.19629 6.73926 8.19629 4.55371 4.91797 5.46387 8.19727 9.6543 7.46777 7.28613 Page 2 14896.2, 14902.6, 14901.5, 14907.7, 14903.3, 14911, 14906.8, 14913.2, 14908.2, 14914.6, 14946.8, 14952.2, 14950.6, 14956.6, 14954.4, 14959.9, 15021.3, 15029.3, 15025.7, 15032.8, 15036.1, 15043.3, 15044.9, 15051.5, 15066.6, 15073.3, 15071.9, 15079.9, 15075.7, 15084.2, 15077.7, 15087.5, 15114.2, 15121.7, 15115.7, 15123.5, 15118, 15126.2, 15122.3, 15133.6, 15126, 15136.6, 15164, 15172.3, 15168.9, 15178.4, 15173.4, 15182.4, 15178.7, 15190.6, 15185.1, 15195.8, 15206.5, 15218.6, 15225.7, 15237.9, 15233.5, 15245.7, 15261.6, 15268.9, 15277.3, 15283.5, 15301.2, 15306.1, 15309.8, 15318.7, 15316.9, 15324.9, 15319.3, 15326.7, 15322, 15329.1, 15341.8, 15347.6, 15352.2, 15357.8, 15396, 15403.8, 15400, 15407.5, 15419.9, 15427, 15451.9, 15458.2, 15454.6, 15461.2, 15472.1, 15479, 15475.6, 15480.9, 15478.5, 15483.2, 15483.1, 15488.3, 15518.5, 15526.5, 15527.1, 15533.8, 15553.1, 15558.8, 15620, 15630.1, 15626.6, 15635.9, 15753.3, 15758.4, 15776.7, 15784.7, 15827.2, 15837.4, 15851.2, 15861.8, 15858.9, 15867.8, 15860.1, 15869.6, 15863, 15871.6, 15868.3, 15875.9, 15871.7, 15881.4, 15874.5, 15883.6, 15878.7, 15889.4, 15899.4, 15908.5, 15901.9, 15911.2, 15922.8, 15931.2, 15937.2, 15944.9, 15958.1, 15965.9, 15966.8, 15976.1, 15968.1, 15977.2, • tapescan.txt 6.375 6.19238 7.65039 6.375 6.375 5.46387 6.01074 5.46387 8.01465 7.10352 7.28613 6.55762 6.73926 8.01465 8.56152 9.83594 7.46777 7.83301 8.19629 11.293 10.5654 8.37891 9.47168 8.92578 11.8398 10.7471 12.0215 12.2031 12.2041 7.28613 6.19336 4.91797 8.9248 8.01465 7.46777 7.10352 5.8291 5.64648 7.83203 7.46875 7.10352 6.375 6.55664 6.9209 5.28223 4.73633 5.2832 8.01465 6.74023 5.64648 10.0186 9.29004 5.10059 8.01465 10.2002 10.5654 8.92578 9.47266 8.56055 7.65039 9.65332 9.10742 10.7461 9.10742 9.29004 8.37891 7.65039 7.83301 9.29004 9.10742 Page 3 ~ • i 15991.7, 16005.4, 16063.8, 16067.4, 16095.4, 16103.9, EOZ END ! BASE CURVE: GROH, Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER '~*** MWD .001 1024 tapescan.txt ! 13.6611 ! 3.64355 ! 8.56152 OFFSET CURVE: GRAX 189 records... 10 bytes 132 bytes '~'`* LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! rtemark File version 1.000 The data presented here is final and has been depth shifted to a Primary ~epth Control (POC) log provided by Schlumberger GR CCNL dated 26 Mar 2006 per Dave Boyer with BP Exploration (alaska), Inc. * FORMAT RECORD (TYPE# 64) ~ata record type is: 0 ~atum Frame Size is: 28 bytes ~og~ing direction is down (value= 255) optical ~o~ ~epth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] -vumber 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 5ize ~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 rtecords: 100 Tape File Start Depth = 14492.000000 Tape File End ~epth = 16283.500000 Tape File ~evel Spacing = 0.500000 Tape File ~epth Units = feet ~`~** FILE TRAILER **** Page 4 ~ tapescan.txt Tape Subfile: 2 113 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER *'`** MWD .001 1024 '~** LIS COMMENT RECORD *** !!!!!!!!!!!!!!! !!!! Remark File Version 1.000 rhis file conta ins the raw-unedited field data. * FORMAT RECORD (TYP E# 64) Data record type is: 0 Datum Frame Size is: 28 bytes ~ogying direction is down (value= 255) Optical Lo~ Depth Sc ale 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: 1 FRAME SPACE = 0. 250 * 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 ~ata Records: 199 Tape File Start Depth = 14487.000000 Tape File End ~epth = 16275.000000 Tape File ~evel Spacing = 0.250000 Tape File Depth Units = feet ~~'~* FILE TRAILER ~**~ Tape subfile: 3 212 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes • '~**~ TAPE TRAILER **'~* Page 5 • MWD 06/03/25 1100529 O1 '~~`** REEL TRAILER *~** MWD 09/07/08 BHI O1 Tape Subfile: 4 Minimum record length Maximum record length tapescan.txt 2 records... 132 bytes 132 bytes 0 Tape subfile 1 is type: ~rs 0 Tape Subfile 2 is type: LIS DEPTH GR RPD RPS 14492.0000 -999.2500 -999.2500 -999.2500 14492.5000 -999.2500 -999.2500 -999.2500 14500.0000 82.6107 -999.2500 -999.2500 14600.0000 56.5955 5.7219 5.2962 14700.0000 56.3087 6.7000 6.7248 14800.0000 52.8612 5.5500 5.3204 14900.0000 48.2232 6.5513 6.1588 15000.0000 31.9879 6.0007 5.6426 15100.0000 44.9657 6.5678 6.3193 15200.0000 46.8000 6.1416 5.2936 15300.0000 45.8978 30.1976 32.2755 ROP -999.2500 -999.2500 -999.2500 15.2183 83.6374 57.3075 64.3808 62.6000 49.3400 51.9360 67.2495 Page 6 RAD -999.2500 -999.2500 -999.2500 6.1001 5.8201 5.4454 6.5131 6.1482 7.0791 8.0097 17.5971 ~ RAS -999.2500 -999.2500 -999.2500 6.0091 6.6906 5.9126 6.8748 6.2853 7.0931 6.5518 35.5864 ~ tapescan.txt 15400.0000 43.2875 67.1000 14.6348 18.4516 17.9195 15500.0000 55.3862 65.3148 10.5596 8.4349 6.7500 15600.0000 46.5759 67.4454 8.3471 7.6655 15700.0000 37.6027 79.1000 5.0881 5.9765 15800.0000 39.4675 94.8057 14.5090 16.4327 15900.0000 81.3633 102.6404 8.6924 7.8778 16000.0000 92.3122 249.7124 10.2635 9.3425 16100.0000 93.3015 108.0696 10.1290 9.0761 16200.0000 -999.2500 66.8000 19.3750 19.9480 16283.5000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 14492.000000 Tape File End ~epth = 16283.500000 Tape File ~evel Spacing = 0.500000 Tape File oepth units = feet 0 Tape Subfile 3 is type: ~IS DEPTH GR ROP RPD RPS 14487.0000 -999.2500 -999.2500 -999.2500 -999.2500 14487.2500 1404.8999 -999.2500 -999.2500 -999.2500 14500.0000 72.1000 -999.2500 5.7360 7.4640 14600.0000 49.0000 35.8000 6.1150 5.9030 14700.0000 56.7000 70.6000 6.7260 6.4320 14800.0000 47.3000 53.6000 5.6440 5.1790 14900.0000 43.9000 65.5000 6.8350 6.4450 15000.0000 31.3000 63.2000 6.0540 5.7040 15100.0000 43.1000 47.7000 6.1300 5.7350 15200.0000 36.4000 55.7000 Page 7 8.2716 4.9210 11.6350 9.9852 11.4915 11.5167 13.1710 -999.2500 RAD -999.2500 -999.2500 2.5200 5.8600 6.0740 5.7450 6.7570 6.3070 6.8750 8.2670 ~~ 20.5299 10.7257 9.3238 4.6717 14.2296 9.2321 11.4193 11.4468 19.5920 -999.2500 RAS -999.2500 -999.2500 6.6540 6.3830 7.1240 6.0360 7.6160 6.3950 6.3740 6.6560 ~ tapescan.txt 6.2030 5.2310 15300.0000 38.3000 65.0000 30.9660 32.4080 15400.0000 39.3000 66.9000 15.2000 13.9720 15500.0000 59.7000 73.4000 8.9690 7.5590 15600.0000 42.4000 55.6000 6.6840 5.6420 15700.0000 43.8000 53.8000 5.3590 6.6770 15800.0000 43.5000 87.0000 14.3960 16.7570 15900.0000 88.6000 76.9000 8.5820 8.0280 16000.0000 102.1000 106.6000 10.0390 9.1990 16100.0000 95.0000 113.8000 10.4500 9.4570 16200.0000 -999.2500 85.6000 - -999.2500 -999.2500 16275.0000 -999.2500 -999.2500 - -999.2500 -999.2500 Tape File Start ~epth = 14487.000000 Tape File End Depth = 16275.000000 Tape File ~evel Spacing = 0.250000 Tape File ~epth units = feet 0 Tape Subfile 4 is type: ~z5 Page 8 ~ 18.2030 37.4500 13.9660 17.8430 10.3390 10.7940 7.5020 7.8580 4.9860 4.3150 11.6610 14.2390 9.4840 8.8830 11.3110 11.2690 11.5360 11.6700 99.2500 -999.2500 99.2500 9 -999.2500 9 • **** REEL HEADER **** MWD 07/06/29 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 06/03/25 1100529 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 144.87.0000: Starting Depth STOP.FT 16272.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska) Inc. WELL. WELL: P2-36A FLD FIELD: Point McIntyre LOC LOCATION: 70 deg 24' 2.131"N 148 deg 31' 19.035"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: 25-Mar-06 API API NUMBER: 50029228010100 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 46.6 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F N/A Elevation of Kelly Bushing EDF .F 46.6 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth 051 DIRECTIONAL Other Services Line 1 Remarks (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 the string included BCPM (Bi-directional Communications and Power Module), a DPS (Drilling Performance Sub), Downhole WOB and Pressure, a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a near Bit Inclination and USMPR (Ultra Slim Multiple Propagation Resistivity) (5) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control) log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (6) This well was drilled from P2-36 through a milled window in 7 5/8" liner: Top of Window 14493.0 ft.MD (8977 ft.SSTVD) Bottom of Window 14499.0 ft.MD (8975 ft.SSTVD) (7) The interval from 16196 ft.MD to 16272 ft.MD (8998.0 ft.SSTVD to 8987.0 ft.SSTVD) was not logged due to bit to sensor offset at TD. MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MGJD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 60 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN P2-36A 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN P2-36A FN Point McIntyre , 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 ROPS ROPS ROPA RAD RAD RACLM RAS RAS RACHM RPD RPD RPCLM RPS RPS RPCHM * 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: 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 ROPS 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 Total Data Records: 100 o.o 0.0 0.0 0.0 0.0 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 14487.000000 Tape File End Depth = 16275.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 113 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------ WDFN P2-36A.xtf LCC 150 CN BP Exploration (Alaska) wN P2-36A FN Point McIntyre , 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 ROPA 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: 199 Tape File Start Depth = 14487.000000 Tape File End Depth = 16275.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** • • Tape Subfile: 3 212 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 06/03/25 1100529 01 **** REEL TRAILER **** MWD 07/06/29 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR ROPS RAD RAS RPD RPS 14487.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14487.5000 1380.8999 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14500.0000 72.1000 -999.2500 2.5200 6.6540 5.7360 7.4640 14600.0000 49.0000 35.8000 5.8600 6.3830 6.1150 5.9030 14700.0000 56.7000 70.6000 6.0740 7.1240 6.7260 6.4320 14800.0000 47.3000 53.6000 5.7450 6.0360 5.6440 5.1790 14900.0000 43.9000 65.5000 6.7570 7.6160 6.8350 6.4450 15000.0000 31.3000 63.2000 6.3070 6.3950 6.0540 5.7040 15100.0000 43.1000 47.7000 6.8750 6.3740 6.1300 5.7350 15200.0000 36.4000 55.7000 8.2670 6.6560 6.2030 5.2310 15300.0000 38.3000 65.0000 18.2030 37.4500 30.9660 32.4080 15400.0000 39.3000 66.9000 13.9660 17.8430 15.2000 13.9720 15500.0000 59.7000 73.4000 10.3390 10.7940 8.9690 7.5590 15600.0000 42.4000 55.6000 7.5020 7.8580 6.6840 5.6420 15700.0000 43.8000 53.8000 4.9860 4.3150 5.3590 6.6770 15800.0000 43.5000 87.0000 11.6610 14.2390 14.3960 16.7570 15900.0000 88.6000 76.9000 9.4840 8.8830 8.5820 8.0280 16000.0000 102.1000 106.6000 11.3110 11.2690 10.0390 9.1990 16100.0000 95.0000 113.8000 11.5360 11.6700 10.4500 9.4570 16200.0000 -999.2500 85.6000 11.7925 17.9405 18.5155 20.0775 16275.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 14487.000000 Tape File End Depth = 16275.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet CJ • i Tape Subfile 3 is type: LIS DEPTH GRAX ROPS RACL RACH RPCL RPCH 14487.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14487.2500 1404.8999 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14500.0000 72.1000 -999.2500 2.5200 6.6540 5.7360 7.4640 14600.0000 49.0000 35.8000 5.8600 6.3830 6.1150 5.9030 14700.0000 56.7000 70.6000 6.0740 7.1240 6.7260 6.4320 14800.0000 47.3000 53.6000 5.7450 6.0360 5.6440 5.1790 14900.0000 43.9000 65.5000 6.7570 7.6160 6.8350 6.4450 15000.0000 31.3000 63.2000 6.3070 6.3950 6.0540 5.7040 15100.0000 43.1000 47.7000 6.8750 6.3740 6.1300 5.7350 15200.0000 36.4000 55.7000 8.2670 6.6560 6.2030 5.2310 15300.0000 38.3000 65.0000 18.2030 37.4500 30.9660 32.4080 15400.0000 39.3000 66.9000 13.9660 17.8430 15.2000 13.9720 15500.0000 59.7000 73.4000 10.3390 10.7940 8.9690 7.5590 15600.0000 42.4000 55.6000 7.5020 7.8580 6.6840 5.6420 15700.0000 43.8000 53.8000 4.9860 4.3150 5.3590 6.6770 15800.0000 43.5000 87.0000 11.6610 14.2390 14.3960 16.7570 15900.0000 88.6000 76.9000 9.4840 8.8830 8.5820 8.0280 16000.0000 102.1000 106.6000 11.3110 11.2690 10.0390 9.1990 16100.0000 95.0000 113.8000 11.5360 11.6700 10.4500 9.4570 16200.0000 -999.2500 85.6000 11.7925 17.9405 18.5155 20.0775 16275.0000 -999.2500 -999.2500 -999.2500 -999.2500 • -999.2500 -999.2500 Tape File Start Depth = 14487.000000 Tape File End Depth = 16275.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet i Tape Subfile 4 is type: LIS
