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Home My WebLink About204-2447. 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: Conductor Top Job Conductor Surface Intermediate Liner Liner 470 2670 4760 4760 5410 Structural 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: 13b. Pools active after work: 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 DSR-4/13/23 RBDMS JSB 041123 WCB 12-20-2023 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 X-16A Conductor Top Job Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-244 50-029-20684-01-00 N/A ADL 0028313 10766 Conductor Surface Intermediate Liner Liner 9050 80 2656 8114 2327 2327 10540 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 8837 33 - 113 32 - 2688 29 - 8143 7993 - 10320 10153 - 10766 2400 33 - 113 32 - 2687 29- 7090 6981 - 8656 8532 - 9050 None 470 2670 4760 4760 5410 10540 1490 5380 6870 6870 7240 10343 - 10584 4-1/2" 12.6# 13cr80 27 - 101638673 - 8877 Structural 4-1/2" Baker S3 Packers No SSSV Installed 9959, 8391 / 10106, 8498 Date: Stan Golis Sr. Area Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY 3/13/2023 Current Pools: PRUDHOE OIL Proposed Pools: Prudhoe 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 By Samantha Carlisle at 8:30 am, Feb 28, 2023 323-123 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2023.02.27 16:31:57 -09'00' Stan Golis (880) 10-404 DSR-2/28/23SFD 3/1/2023MGR03MAR23JLC 3/3/2023 3/3/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.03 13:24:42 -09'00' RBDMS JSB 030323 Conductor Top Job Well: X-16A PTD: 204244 API: 50-029-20684-01 Well Name: X-16A Permit to Drill Number: 204244 Well Type PAL API Number: 50-029-20684-01 Job Scope: Conductor top job Reg.Approval Req’d? Yes Current Status: Under Eval, Online Date Reg. Approval Rec’vd: Estimated Start Date: 2/27/2023 Estimated Duration: 2 day Regulatory Contact: Abbie Barker First Call Engineer: Oliver Sternicki Second Call Engineer: Ron Phillips Brief Well Summary: The X-16 surface casing leak was originally identified in May 2004 during RWO screening. In May 2008 a rig workover performed a casing cut and pull on the 9-5/8” casing and cemented the 13-3/8” x 9-5/8” annulus to surface to repair the SC leak. In 2014 there were some incidences of cellar bubbling which were remedied with extended OA bleeds. In July 2020 the well began exhibiting rapid IAxOA communication. A CMIT-TxIA passed to 2590 psi on 8/3/2020. The IAxOA repressurization was repaired with an OA welllock squeeze job on 8/9/2020. The OA was reported by operations to have sustained outer annulus casing pressure over NOL at ~1088 psi on 05/28/2021 when the well was SI. OA MOASP was increased to 1600 psi in 6/23/2021 due to rapid OA repressurization when the well is shut-in. The increased OA MOASP was to allow operations more time to react to increases in OA pressure due to shut-in events. Beginning in October 2022 intermittent slight bubbling was reported in the surface casing by conductor annulus with 0% LELs detected 1’ above the source. Diagnostic bleeding of the IA and OA pressure have not had a measured effect on the bubbling rate, but the bubbling seems to slow or disappear when the well is shut-in. Top of cement in the surface casing by conductor annulus was measured at 96” on 2/24/2023. Current Status: X-16 is currently under evaluation and online. Scope of Work: Conductor top job with cement or WellLock (or similar) to repair conductor bubbling. Procedure: Sundry Work 1 DHD Fill SC x Conductor annulus with Cement or wellock (or similar). 2 DHD Monitor SC x Conductor annulus for continued bubbling. intermittent slight bubbling was reported in the surface casing by conductor annulus Conductor Top Job Well: X-16A PTD: 204244 API: 50-029-20684-01 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: February 27, 2023Subject: Changes to Approved Sundry Procedure for Well X-16ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:204-244 6.API Number:50-029-20684-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028313 Property Designation (Lease Number):10. N/A 8. PBU X-16A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Re-squeeze OA Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 10766 Effective Depth MD: 13cr80 11. 6/20/2021 Commission Representative: 15. Suspended Contact Name:Aras Worthington Contact Email:Aras.Worthington@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 4-1/2" Baker S3 Packer Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9050 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9959, 8391 10106, 8498 Date: Liner 613 4-1/2" 10153 - 10766 8532 - 9050 8430 7500 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 32 - 2688 32 - 2687 14. Estimated Date for Commencing Operations: BOP Sketch 33 - 113 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S3 Packer 10343 - 10584 8673 - 8877 4-1/2" 12.6#27 - 10163 Production 10540 8837 10540 None 33 - 113 470 13-3/8" 9-5/8" Contact Phone:907.564.4763 Date: 4760 80 149020" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2656 5380 Intermediate 8114 29 - 8143 29 - 7090 2327 7" 7993 - 10320 6981 - 8656 7240 5410 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2400 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. No SSSV Installed No SSSV Installed By Samantha Carlisle at 10:52 am, Jun 08, 2021 321-284 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.07 19:35:20 -08'00' Stan Golis (880) DSR-6/8/21DLB 06/09/2021 X MGR16JUN21 10-404 dts 6/16/2021 JLC 6/17/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.17 10:58:52 -08'00' RBDMS HEW 6/21/2021 RWO Procedure WELL:X-16A PTD:204-244 Well Name:X-16A API Number:50-029-20684-01 Current Status:Shut in, Under Eval Estimated Start Date:6/20/2021 Permit to Drill Number:204-244 Well Integrity Engineer:Aras Worthington 907-564-4763 (O)907-440-7692 M Ops Engineer:Wyatt Rivard 907-777-8356 (O) BHSP:3,280psi @ 8800’ SSTVD (7/23/2012) Max. Anticipated Surface Pressure:2,400psi (Based on 0.1 psi/ft. gas gradient) Brief Well Summary: X-16A is a gas-lifted producer. The OA was fully cemented during a RWO in 2008. A CMIT-TxIA and an MITT both passed to 2590 psi and 2700 psi respectively on 8/3/2020. The well exhibited rapid IAxOA communication in July of 2020. A WellLock squeeze of ~25 gallons was pumped on 8/9/2020. The OA showed no signs of re-pressurization until May of 2021 when the well was SI and the OA broke MOASP @ ~1100 psi OAP on 5/28/2021. Objective: Re-squeeze the cemented OA with WellLock to eliminate the OA re-pressurization. Procedure: 1. ND OA Gate Valve, NU OA Integral. 2. Bleed Annuli, Prep OA, WellLock OA top job squeeze to 3000 psi per standard practices. 3. POP Under Evaluation and monitor OA for re-pressurization. 4.Re-squeeze OA with WellLock if necessary. 5. ND OA Integral, NU OA Gate Valve. RWO Procedure WELL:X-16A PTD:204-244 Wellbore Schematic Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:204-244 6.50-029-20684-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10766 10540 8837 9959, 10106 none 10540 8391, 8498 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 33 - 113 33 - 113 1490 470 Surface 2656 13-3/8" 32 - 2688 32 - 2687 5380 2670 Intermediate 8114 9-5/8" 29 - 8143 29 - 7090 6870 4760 Liner 2327 7" 7993 - 10320 6981 - 8656 7240 5410 Perforation Depth: Measured depth: 10343 - 10584 feet True vertical depth:8673 - 8877 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13cr80 27 - 10163 27 - 8540 9959 8391Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Packer Liner 613 4-1/2" 10153 - 10766 8532 - 9050 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Fill OA with 18gal of WellLock with 3% H1 hardener. Pump 2gal of WellLock into OA, no backpressure. Squeeze 5gal of WellLock in to OA, walking squeeze pressure up to 2,500psi for 6hrs. For final 2hrs of squeezing bump started at 2,500psi and ended at 2,000psi in 30min. Leave CNG hose accumulator on OA to continue squeezing overnight. Accumulator started at 1,830psi. Used a total of 25gal of WellLock. Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 22613606655145 63051827 1097 1693 209 254 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Aras Worthington aras.worthington@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907-564-4763 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9050 Sundry Number or N/A if C.O. Exempt: 320-290 4-1/2" Baker S-3 Packer 10106 8498 Junk Packer Printed and Electronic Fracture Stimulation Data 5 OA Squeeze Operations shutdown Change Approved Program 5 OA at surface Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028313 PBU X-16A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations No SSSV Installed By Samantha Carlisle at 2:59 pm, Aug 26, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.08.26 14:26:17 - 08'00' Stan Golis DSR-8/27/2020MGR02SEP2020 RBDMS HEW 8/27/2020 SFD 9/1/2020 ACTIVITY DATE SUMMARY 8/1/2020 ***WELL S/I ON ARRIVAL*** RAN 4.5" BRUSH, 3.80" GAUGE RING TO X NIPPLE @ 9,983' MD. LRS LOADS IA & TBG W/ CRUDE. ATTEMPTED TO SET PX PLUG BODY @ 9,983' MD (failed). ***CONTINUED ON 8/2/2020 WSR*** 8/1/2020 T/I/O= 1265/1225/350 Temp= S/I LRS Unit 76- Assist Slickline with L&T. Loaded IA with 5 bbl 50/50 and 310 bbls crude. Loaded TBG with 200 bbls crude. Slickline unabe to set plug. Continue job on next day. Slickline in control of well upon departure. IA OA OTG. Final Whp's=185/390/350 8/2/2020 T/I/O=200/410/330 Temp= S/I LRS Unit 76 - Assist Slickline w/ L&T. Pumped 10.8 bbls crude down TBG to assist SL setting plug. MIT-TxIA PASSED to 2564/2649 psi. Pressured up TxIA to 2667/2754 psi with 44.5 bbls crude. 1st 15 min T/IA lost 74/75 psi. 2nd 15 min T/IA lost 29/30 psi for a total loss of 103/105 psi in 30 min. Bled IA down and TBG tracked. bled back 7 bbls. SV WV= closed. SSV MV IA OA= open. Final Whp's= 850/650/330 8/2/2020 ***CONTINUED FROM 8/1/2020 WSR*** SET 4-1/2" PX PLUG BODY & PRONG @ 9,983' MD. SET 4-1/2" SLIP STOP CATCHER @ 3,335' SLM. PULLED RK-LGLV FROM ST #5 @ 3,199' SLM/ 3,214' MD. SET RK-LGLV (16/64", 1500#) IN ST #5 @ 3,200' SLM/ 3,214' MD. PULLED 4-1/2" SLIP STOP CATCHER @ 3,200' SLM (empty). ***JOB CONTNUED ON 8/3/2020 WSR*** 8/3/2020 T/I/O= 700/750/315 Temp= S/I LRS Unit 76- Assist Slickline: MIT-T. Pressured up TBG to 2726 psi with 3.5 bbls crude. TBG lost 576 psi in 5 min. Slickline R&R SO (ST#4). Pre AOGCC MIT-T Passed to 2571 psi. Pressured up TBG to 2754 psi with 2.85 bbls crude. 1st 15 min TBG lost 128 psi. 2nd 15 min TBG lost 55 psi for a total loss of 183 psi in 30 min. Bled TBG to 567 psi and recovered 2.85 bbls. AOGCC CMIT-TxIA Passed to 2590/2672 psi. (Witnessed by Matt Herrera ) Pressured up T/IA to 2664/2745 psi with 7.3 bbls crude. 1st 15 min T/IA lost 51/51 psi. 2nd 15 min T/IA lost 23/22 psi for a total loss of 74/73 psi in 30 min. Bled IAP to 700 psi and recovered 5.1 bbls. AOGCC MIT-T Passed to 2697 psi. (Witnessed by Matt Herrera) Pressured up TBG to 2758 psi with .6 bbls crude. 1st 15 min TBG lost 46 psi. 2nd 15 min TBG lost 15 psi for a total loss of 62 psi in 30 min. Bled TBG to 590 psi and recovered 2 bbls. Tags hung. SW WV= closed. SSV MV IA OA= open. Pad op notified upon departure. Final Whp's=590/660/316 8/3/2020 ***JOB CONTINUED FROM 8/2/20 WSR*** MADE 1 ATTEMPT TO MIT-T (failed). SET 4-1/2" SLIP STOP CATCHER @ 5,701' SLM. PULLED ST #4 RK-SO @ 5,589' MD. SET ST #4 RK-SO (20/64") @ 5,589' MD. PULLED 4-1/2" SLIP STOP CATCHER @ 5,701' SLM (empty). LRS PERFORMS PASSING CMIT-TxIA AND MIT-T TO 2500PSI. ***CONTINUE ON 8/4/2020 WSR*** Daily Report of Well Operations PBU X-16A Daily Report of Well Operations PBU X-16A 8/4/2020 ***JOB CONTINUED FROM 8/3/2020*** PULLED PRONG & PX PLUG BODY @ 9,983' MD. ***WELL LEFT S/I ON DEPARTURE*** 8/5/2020 T/I/O = SSV/240/300. Temp = SI. Strap TOC in OA (pre Wellock). ALP = 1580 psi, AL SI @ casing valve. OA cemented to surface. Bled OAP to BT from 300 psi to 0 psi in 3 min, all gas. OA TOC = 66" (12.6 gallons). Nipple down both gate valve & comp OA blind flange, pull 3" McEvoy VR plug from Comp OA. NU 3" integral's on both working side & companion side of OA for upcoming Wellock treatment (gate valve left in well house). SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:00 8/9/2020 Objective: WellLock Squeeze OA Fill OA with 18gal of WellLock with 3% H1 hardener. Pump 2gal of WellLock in to OA, no backpressure. Squeeze 5gal of WellLock in to OA, walking squeeze pressure up to 2,500psi for 6hrs. For final 2hrs of squeezing bump started at 2,500psi and ended at 2,000psi in 30min. Leave CNG hose accumulator on OA to continue squeezing overnight. Accumulator started at 1,830psi. Used a total of 25gal of WellLock. ***Job Complete*** 8/10/2020 T/I/O = SSV/240/1310. Temp = SI. WHPs (post Well Lock). ALP = 1590 psi, SI @ CV. OA cemented to surface. OAP decreased 720 psi overnight. WH temp = 67°, adjust heater trunk. Well Lock sample not setup. Heater in well house working properly, tree cap bled to 0 psi. SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:30 8/12/2020 T/I/O = SSV/240/1300. Temp = SI. WHPs (post Well Lock). ALP = 1580 psi, SI @ CV. OA cemented to surface. IAP unchanged, OAP decreased 10 psi overnight. WH temp = 90°, adjust heater trunk. Well Lock sample is setting up, firm but able to be indented. Heater in well house working properly. SV, WV, SSV = C. MV = O. IA, OA = OTG. 01:30 8/12/2020 T/I/O = SSV/240/1240. Temp = SI. WHPs (Post Wellock). ALP = 1580 psi, SI @ CV. OAP decreased 60 psi since 01:30 this morning. WH temp = 84°. Heater working. Wellock sample is very firm but not rock hard. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:50 8/13/2020 T/I/O = SSV/240/1060. Temp = SI. WHPs (post Well Lock). ALP = 1580 psi, SI @ CV. OA cemented to surface. IAP unchanged, OAP decreased 180 psi overnight. WH temp = 68°,adjust heater trunk. Heater in well house working properly. Well Lock sample is mostly setup, unable to indent. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:00 8/14/2020 T/I/O = SSV/240/1160. Temp = SI. WHPs (Post Wellock). AL SI @ casing valve (1600 psi). Wellock sample is set up. Wellhead temp = 98*. Opened wellhouse door slightly. Heater in wellhouse. SV, WV, SSV = C. MV = O. IA, OA = OTG. 8/14/2020 T/I/O = SSV/240/1180. Temp = SI. WHPs (post Well Lock). ALP = 1600, SI @ CV. OA cemented to surface. IAP unchanged, OAP increased 120 psi overnight. WH temp = 96°, adjust heater trunk and open both doors. Heater in well house working properly. Well Lock sample is mostly setup. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:30 Daily Report of Well Operations PBU X-16A 8/15/2020 ***WELL S/I ON ARRIVAL*** (HES E-Line Plug and Adperf) SET 4-1/2" QUADCO CIBP AT 10,540' MD. PERFORATE 10,482.7' - 10,515.2' W/ 2-7/8" MAXFORCE, 6 SPF, 60 DEG PHASE GUN. ALL LOGS CORRELATED TO BAKER HUGHES RPM LOG DATED 11-SEP-2013. ***WELL LEFT S/I ON DEPARTURE*** 8/17/2020 T/I/O = SSV/220/940. Temp = SI. Assist WS (RU OA CV). ALP = 1590 psi, SI @ CV. OA cemented to surface. Bled OAP to 0 psi and RD hardline from OA. Installed VR plug & tapped blind flange w/ Alemite fitting and OA CV. Both VR profiles are operational. SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:30 8/17/2020 T/I/O = SSV/220/950. Temp = SI. WHPs (post Well Lock). ALP = 1590 psi, SI @ CV. OA cemented to surface. IAP unchanged, OAP decreased 210 psi since 08/14/2020. Well Lock is fully cured. WH temp = 45°. Heater in well house is working properly. Both well house doors partially ajar. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:15 8/19/2020 T/I/O = SSV/200/0. Temp = SI. Well POP (Post Wellock). AL SI @ casing valve (1600 psi). Final IA FL @ 5589' (#4, S/O). Pop'ed well for ops. No pressure seen on OA during job. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:20 8/24/2020 T/I/O = 300/1300/0. Temp = 168°. WHPs (Eval IAxOA). SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:15. 8/24/2020 T/I/O = 290/1300/0. Temp = 166°. WHPs (Eval IA x OA). ALP = 1300 psi, online. OA cemented to surface. SV = C. WV, SSV, MV = O. IA, OA = OTG. 05:00 10482.7 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 'Re, RE I ?' 16J -,,Z' P.I. Supervisor "t FROM: Matt Herrera Petroleum Inspector Section: 5 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Cody Fenstermaker Casing/Tubing Data (depths are MD): Conductor: 20"x30" 0. D. Shoe@ Surface: 13 3/8" 0. D. Shoe@ Intermediate: 9 5/8" 0. D. Shoe@ Liner: T' 0. D. Shoe@ Liner: 41/2" 0. D. Shoe@ Tubing: 41/2" O.D. Tail@ Plugging Data: Test Data: DATE: August 3, 2020 SUBJECT: Plug Verification PBU X -16A Hilcorp North Slope LLC PTD 2042440; Sundry 320-290 10N Range: 14E Meridian: Umiat NA Total Depth: 10766 ft MD Lease No.: ADL 028313 2745 - Suspend: NA P&A: NA OA 317 320 320 Casing Removal: 113 Feet Csg Cut@ Feet ?689 Feet Csg Cut@ Feet 3143 Feet Csg Cut@ Feet 0320 Feet Csg Cut@ Feet 0766 Feet Csg Cut@ Feet 0163 Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth (Top) MW Above Verified Annulus N/A - PrPti-t Initial 15 min 30 min Result Tubing 588 2664 2613 2590 IA 656 2745 - 2694- 2672 - P OA 317 320 320 320 Prat—,t Initial 1.5 min 30 min Result Tubing 2256 2758 2712 2697 IA 683 724 753 761 P OA 318 318 317 316 Remarks: PBU X -16A is a gas -lift producer diagnosed with IAxOA communication. OA was fully cemented during RWO in 2008. Welllock OA top job squeeze completed. Tubing tail plug set at 9983 ft MD for MITT and CMIT-IA. Both pressure tests passed. Attachments: NONE rev. 11-28-18 2020-0803_Plug_Verification_PBU_X-16A_mh By Jody Colombie at 8:16 am, Jul 10, 2020 320-290 MGR10JUL20 DSR-7/10/2020 X DLB 7/10/20 7/13/2020 dts 7/13/2020 JLC 7/13/2020 10-404 RBDMS HEW 7/16/2020 3a. MIT-T, CMIT T x IA to 2500 psi. Passing CMIT T x IA required before put on production. 24 hour notice to AOGCC for opportunity to witness. BAIUGHES PRINT DISTRIBUTION LIST a GE company COMPANY BP Exploration Alaska Inc. WELL NAME X -16A FIELD Prudhoe Bay Unit COUNTY North Slope BHI DISTRICT Alaska 204244 31344 ase sign and return one copy of this transmittal form to: Exploration (Alaska)Inc. :rotechnical Data Center, 1-112-1 E. Benson Blvd. :horage, Alaska 99508 or AKGDMINTERNAL@bp.com LOG TYPE RPM:PNC3D-CO LOG DATE September 11, 2019 AUTHORIZED BY DirkZeijlemaker EMAIL Dirk.zeiilemakera@.bakerhuahes.com TODAYS DATE October 18, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEX MILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V RP North Slope. EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Burka & Barbara Glassmaker 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 3-344 700 G Street Anchorage, AK 99501 3 Exxon Mobil, Alaska Attn: Lynda M. Yaskell and/or Lisa Boggs 3201 C Street, Suite 505 Anchorage, AK 99503 FIELD 1 FINAL CD/DVD FINAL PRELIMLOGS (las, tills, PDF, META, I SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES 4 4 V OCT 2 2 2019 AOGCC i 4State of Alaska - AOGCC 1 1 Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas *** 1 Attn: Garret Brown 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 6 RP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Attn: David Itter 0 1] TOTALS FOR THIS PAGE: 0 1 4 0 0 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, September 3, 2017 2:28 PM To: AK, OPS EOC Specialists;AK, OPS GC1 Field O&M TL;AK, OPS GC3 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad CX;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Boman,Wade; Glasheen, Brian P;Von Tish, Douglas B; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Tempel, Joshua;Worthington, Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer X-16 (PTD#2042440)Well barriers confirmed All, Producer X-16( PTD#2042440)was made under evaluation on 8/21/17 for having sustained inner annulus casing pressure above NOL. The well was brought online 8/31/17 and a passing warm TIFL was performed on 9/2/17. The well now demonstrates two competent barriers and is reclassified as Operable. Please respond if in conflict, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO From: , WO Well Integrity Engineer Sent: Wednes•. august 23, 2017 3:27 PM To: AK, GWO Well Inte• Engineer; AK, GWO SUPT Well Integrity; AK, OPS GC3&PCC OSM; AK, OPS GC3 Facility OTL; AK, OPS GC3 Field OTL; AK, 0• C3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; A , e'S PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS EOC Specialists; AK, OPS Well Pad CX; Boman, Wade; 'Regg, James : IA) (jim.regg@alaska.gov)'; AK, OPS GC1 Field O&M TL; AK, OPS PCC Ops Lead Cc: AK, GWO DHD Well Integrity; AK, GWO Projects We egrity; AK, GWO Completions Well Integrity; AK, OPS FF Well Ops Comp Rep; Bronga, Jaime; Glasheen, Brian P; Hibbert, Mic :-1 Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Wort' .ton, Aras 3; 'chris.wallace@alaska.gov'; Von Tish, Douglas B; AKIMS App User Subject: UNDER EVALUATION: Producer X-16 (PTD #2042440) High Inner Ann h Pressure Over NOL All, 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, August 23, 2017 3:27 PM To: AK, GWO Well Integrity Engineer;AK, GWO SUPT Well Integrity;AK, OPS GC3&PCC OSM;AK, OPS GC3 Facility OTL;AK, OPS GC3 Field OTL;AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS EOC Specialists;AK, OPS Well Pad CX; Boman,Wade; Regg,James B (DOA);AK, OPS GC1 Field O&M IL;AK, OPS PCC Ops Lead Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep; Bronga,Jaime; Glasheen, Brian P; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Worthington,Aras J;Wallace, Chris D (DOA); Von Tish, Douglas B;AKIMS App User Subject: UNDER EVALUATION: Producer X-16 (PTD#2042440) High Inner Annulus Pressure Over NOL All, Producer X-16(PTD#2042440)was reported to have sustained inner annulus casing pressure above NOL on 8/21/17. The pressures were reported to be TBG/IA/OA=SSV/2450/270psi. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1. DHD: Cold TIFL—Failed 2. Slickline: C/O GLVs 3. DHD: Warm TIFL 4. Well Integrity Engineer:Additional diagnostics as needed Please respond with any questions, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering SCANNED AUG 3 0 ?U!7 Office 907-659-8110 Cell 907-980-0552 Harmony 4530 1 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~O Y- - ~-4M- Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 D Rescan Needed II 11111111111 111111 RJ5CAN v6 Color Items: o Greyscale Items: DIGITAL DATA ~kettes, No..d- D Other, NolType: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: BY: ~ Date: D Other:: 151 Mf 1111111111111111111 Project Proofing BY: ~ Is/ mP S/ø Scanning Preparation BY: Date: = TOTAL PAGES (Count does not include cover sheet) 151 Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES BY: G Maria") Date: 4-/ I ~/ t) 7 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES "' 11111111111" 11/ NO 151 VV\ P NO BY: Maria Date: 151 "' 11111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned "' 1111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS ~I~~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated ~' aS aS OnS. CofYtrfts$SIO Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension C~nchorage Change Approved Program ~ Operat. Shutdown ~ Perforate Q , Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development T' - Exploratory 204-2440' 3. Address: P.O. Box 196612 Stratigraphic Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20684-01-00 7. KB Elevation (ft): 9. Well Name and Number: 68.6 KB - PBU X-16A 8. Property Designation: 10. Field/Pool(s): ADLO-028313 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10766 - feet Plugs (measured) None true vertical 9049.97- feet Junk (measured) None Effective Depth measured 10679 - feet true vertical 8966.95 - feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" 91.5# H-40 Surtace - 110 Surface - 110 1490 470 Surface 2689 13-3/8" 72# L-80 Surface - 2689 Surface - 2689 4930 2670 Intermediate 10191 9-5/8" 47# L-80 Surface - 10191 Surface - 8560 6870 4760 Liner 2327 7" 26# L-80 7993 - 10320 6981 - 8656 7240 5410 Liner 613 4-1/2" 12.6# 13CR-80 10153 - 10766 8532 - 9050 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _, _ _ Tubing: (size, grade, and measured depth) 4-1 /2" 12.6# 13CR-80 SURFACE - 10045' 4-1/2" 12.6# 13CR-80 10045' - 10163' Packers and SSSV (type and measured depth) 7" Baker ZXP Mech Top Packer 7993' 7"X4-1/2" BKR S-3 PKR 9959' 7"X4-1/2" BKR S-3 PKR 10106' 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 298 5881 1986 349 Subsequent to operation: 622 12252 3823 300 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory #~ Development ~'- Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil - Gas WAG GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature Phone 564-4944 Date 3/19/2009 ,~, ~~ Form 10-404 vised Q4/2d06 ~ ~_ ~~ ~ ~,,;~ ?~. ~: ~~ ~- ~~~ `~ ~~~~ ~ Submit Original Only `~~".~ ~ t~'`~1 ~~ l X-16A 204-244 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base X-16A 3/2/05 PER 10,538. 10,568. 8,834.71 8,862.05 X-16A 2/5/08 BPS 10,149. 10,151. 8,529.47 8,530.93 X-16A 4/28/08 BPP 10,133. 10,135. 8,517.79 8,519.25 X-16A 4/28/08 BPS 10,133. 10,135. 8,517.79 8,519.25 X-16A 5/20/08 BPP 10,149. 10,151. 8,529.47 8,530.93 X-16A 3/15/09 APF 10,343. 10,368. 8,673.21 8,692.32 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE F X-16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/14/2009'`**WELL SHUT-IN ON ARRIVAL**' RIGGED UP ON WELL, PT. WAITING ON LRS TO FREEZE !PROTECT FLOWLINE, PUMP ON TBG. ~"**JOB CONTINUED ON 15-MAR-09*** Assist E-line with Loading tubing and freeze protect flowline. ***Job continued on 3-15-09**" 3/15/20091***JOB CONTINUED FROM 14-MAR-09"*" RAN 25' X 3.38" HSD 6SPF 60 DEG PHASED PJ3406 GUN AND SHOT 10343'-10368' DEPTH CORRECTED TO MWD LOG ATTACHED TO JOB PACKET, SPUD DATE 12-21-04. PIECED TOGETHER JEWELRY INFO FROM LINER TALLY, ORIGINAL ;COMPLETION TALLY AND NEW WORK-OVER TUBING TALLY. TIE- IN PASS LABELED FOR FUTURE REFERENCE. ALL SHOTS FIRED ON GUN, DSO NOTIFIED WELL READY TO POP AND OF VAVLE PLACEMENT. FINAL PRESSURES 950/600/0. ~"*"JOB COMPLETE*** FLUIDS PUMPED BBLS 1 diesel 1 Total 07/28/08 C] G ~~rh~~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .leh # N0.4799 Company: State of Alaska Ataska Oil & Gas Cons Gomm .,,~~y~ ~U~ ~ '~ 2~t18 Attn: ChristineMahnken „s, r U 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Lea Dpscrietinn Data RL Cnlnr CD G-29A 12096905 MEM PROD PROFILE 07/18/08 1 P7-04 12017505 PROD PROFILE 07/17/08 1 1 L-219 11999028 FLUID DENSITY LOG 07/16/08 1 1 L-205 11999021 USIT 06/17/08 1 1 X-16A 11978465 RST 06/03/08 1 1 K-14A 11628804 MCNL 11/15/07 1 1 rLCNAC MVI~rvVVVLCVUC IS Cl, C1Y1 riT .>I171V11V1a AIVV IYt1UM1V11VCa VIVt l:VN7 CAl:t1 I V: BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9 503-28 8 ATTN: Beth / Received by: /~/ ~°~ -~~~. ~, - STATE OF ALASKA A OIL AND GAS CONSERVATION COM ION it ~~~ ~ ~ ~QQ$ REPO T OF SUNDRY WELL OPE~IONS '~` 1. Operations Performed: /,- ,3 ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension - 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ~ ^ Exploratory 204-244 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20684-01-00 7. KB Elevation (ft): 68 6' 9. Well Name and Number: P BU X-16A - 8. Property Designation: 10. Field /Pool(s): _ ADL 028313 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 10766 ~ feet true vertical 9050 - feet Plugs (measured) None Effective depth: measured 10679 -feet Junk (measured) None true vertical 8967 - feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2689' 13-3/8" 2689' 2689' 4930 2670 Intermediate 10191' 9-5/8" 8143' 7090' 6870 4760 Production Liner 2327' 7" 7993' - 10320' 6981' - 8656' 7240 5410 Liner 613' 4-1/2" 10153' - 10766' 8532' - 9050' 8430 7500 e~i~,~I~t~E~ JUL ~ ~ 2008 Perforation Depth MD (ft): 10538' - 10568 Perforation Depth TVD (ft): 8835' - 8862' 4-1/2", 12.6# 13Cr80 10163' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker'S-3' packer; 9959'; 7" x 4-1/2" Baker'S-3' packer 10106' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 10050', dress stub to 10051'. Cut and pull 9-5/8" casing from 2083'. Run 9-5/8" tieback, cement w/ 122 Bbls Class'G' 685 cu ft / 585 sx . Run com letion w/ overshot to 10049'. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 558 9,701 3,497 700 300 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 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: Contact Paul Chan, 564-5254 308-159 Printed Name Terrie Hubble Title Drilling Technologist J~ Prepared By Name/Number: Signatur Phone 564-4628 Date v , eyrie Hubble, 564-4628 Form 10-404 Revised 04/2006 ~ ., Submit Original Only n R ~ ~ ~ -~~ A ~ t __ S ~~~.:~~~~ ~~ ~o~B ~~,~ r~ Digital Well File J Well: X-16 Well History Page 1 of 2 Well Date Summary X-16A 4/26/2008 T/I/O=SSV/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (FAIL). Pre RWO. PPPOT-T: External Alemite check installed. Stung into test void (2000 psi), Bled to 0 psi. Pumped d void to 5000 psi for 30 min test, lost 200 psi in through void until clean fluid returns achieved. Pressure 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. Functioned LDS, all moved freely. PPPOT-IC: External Alemite check installed. Stung into test void (200 psi), Bled to 0 psi. Pumped id returns achieved. Pressured void to 3500 psi for 30 min test, lost 1000 psi in fl l u ean through void until c 5 min. Attempt to re-energize secondary YB sea1, unable to get plastic to move (temp). Bled void to 0 psi. The stuck pins will need to be cut ht but moving ti . g Functioned LDS, 3 stuck pins (flagged), the rest were off and drilled. Will re-MIT IC packoff after LDS drill out. X-16A 4/26/2008 ***WELL SHUT IN ON ARRIVAL***{pre rwo] DRIFTED TO TOP OF 4 1/2 PLUG ~ 10115' SLM W/ 3 80" CENT & S. BAILER femotvl PULLED P PR NG & 4 1/2" PX PLUG BODY FROM TT ~ 10151 MD. [packing intact] *** -**LEFT WELL S/I, TURNED WELL OVER TO PAD-OP TBG & IA FL (pre EL). AL line SI C~? casing valve. ALP = 0 psi. TBG FL p X-16A 4/27/2008 ~ 5879 (305 bb )}lA FL ~ 36~, 4/27/2008 BG with 150 bbls crude (RWO Prep) -Pumped 150 bbls 110"' crude down a / / X-16A 10 400/80 s~ TBG. FWHP X-16A 4/28/2008 asetl ontinue'pump~g with JumpePln e. PtumOped ~ ns IN/ ~ cr 5Q / e incre ee pressu o ude down 5 bb u ped P 6.5 bbls to reach test pressure, Tubing lost 340/300, IA lost 40!20. Noticed Surface casing leak, Call in to PE's MIT Tubing 1500 psi Fail. Pumped 3 bbls crude down Tubing to reach test pressure. Tubing lost 80 psi in Bleed back Tubing FWHP's= i in 30 mins 140 ' . ps s for a total loss of 15 min's, 60 psi in 2nd 15 min 300!360!0 ***Annulus casing valves open to gauges, Master, IA valves tagged on departure.*** X-16A 4(28/2008 ***WELL SHUT IN ON ARRIVAL*** INITIAL WHP 250/50/0 CORRELATE TO TUBING SUMMARY DATED 111/2005, SET HLS FASDRILL PLUG MID ELEMENT 1 LRS TOyPT PLUG, RD FROM WELL TO GO TO NORTHSTAR. FINAL WHP 250/50/0 ***JOB NOT COMPLETE*** X-16A 4/29/2008 T/I/0=440/360Nac. Temp=Sl. Assist FB w/OMIT-TxIA &circ-out, SC leak (RWO prep). A/LP=O psi. OA bleed during pumping operations to mitigate Staged Vac truck, maintained stinger in flutes & an open SC leak. No events occurred. Final T/110=300/360Nac. X-16A 4(29!2008 ***WELL SHUT IN ON ARRIVAL*** INITIAL T/I/0=350/400/0. SET HES 3.66" FASDRILL PLUG AT 10125', FIVE FEET ABOVE X NIPPLE. M SO PLUG WAS SET AT 10123.7 WHEN NORMAL LOGGING TOOL STUCK COMING OFF BOTTO TENSION WAS REACHED. PRESSURE TESTED LUG TO 2100 PS{ FOR 30 MINUTES. CUT FULL JOINT ABOVE THE BAKER S-3 PACKER. TUBING AT 10053' IN THE MIDDLE F THE FI WELL LEFT SHUT IN. FINAL T(I/0= 620/0/400. ***JOB COMPLETE*** X-16A 4/30/2008 T/IA/OA= SSV/270/0 Temp=Sl PPPOT-IC (PASS) (Post RWO & LDS drill-out) PPPOT-IC RU HP bleed tool onto IC test void 0 psi, pressure was relieved through SBS there is an d void until clean returns achieved, closed SBS h Fl " e us test port. Internal check still installed into 1 3500! 15 minutes, 3500/30 minutes. Bleed void to 0 psi through r 30 minute test i f 0 , o ps pressured to 350 SBS to 0 psi RD test equipment. *** Internal check still installed *** X-16A 5/2!2008 T/Il0=360118010. Temp=Sl. Assist FB w/ CMIT-TxIA &circ, SC leak (RWO prep). Full bore started circ out at 0001 hrs. OAP started to rise immediately after pumping began, and fluid started to fill up the flute at the 7 O'clock position. An open bleed was started on the OA after pressure began to build, resulting in (10 bbls) of fluid over an 8 hr period. Approixmately ten gallons of fluid was vacumed out of the flute over an 8 hr period. Change out with day crew. X-16A 5/2!2008 T/I/0=360110/0 Temp= S/I Circ out (RWO Prep) *** Job continued on 5-3-08 WSR*** X-16A 5/3/2008 *** Job continued from 5-2-08 WSR*'* Circ-out, CMIT TxIA PASSED to 3500 psi. (Pre-RWO) Pumped 5 bbls neat methanol, 959 bbls 1 % KCI and 150 bbls diesel down Tbg taking returns up IA to open top 6/19/2008 http://digitalwellfile.bpweb.bp.com/Wllnfo/Reports/ReportViewer.aspx BP EXPLORATION Operations Summary Report Page 1 of 9 Legal Well Name: X-16 Common Well Name: X-16A Spud Date: 4/20/1982 Event Name: WORKOVER Start: 5/10/2008 End: 5/23/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/23/2008 Rig Name: NABORS 4ES Rig Number: Date ~ From - To Hours ', Task Code NPT 5/10/2008 19:00 - 20:30 1.501 RIGD P 20:30 - 00:00 5/11/2008 00:00 - 05:30 05:30 - 07:00 07:00 - 07:30 07:30 - 09:00 09:00 - 11:00 11:00 - 12:00 12:00 - 14:30 14:30 - 16:30 16:30 - 17:00 17:00 - 18:00 18:00 - 19:30 19:30 - 21:30 21:30 - 22:30 22:30 - 00:00 5!12/2008 00:00 - 12:00 12:00 - 14:00 14:00 - 15:00 15:00 - 15:30 15:30 - 18:00 3.50 RIGU N WAIT 5.50 MOB N WAIT 1.50 MOB N WAIT 0.50 MOB P 1.50 RIGU P 2.00 RIGD P 1.001 WHSUR I P Phase Description of Operations PRE Held PJSM. Raised beaver slide. Scoped down and lowered derrick. Disconnected rig modules. Prepared for rig move. Notified AOGCC (J. Jones) of upcoming X-16A BOPE test at 18:30 hrs 5/10/2008. PRE Waited on site preparation prior to moving on X-16A. PRE Continued waiting on site preparation prior to moving on X-16A. Heavy equipment arrived on location at approximately 01:00 hrs to grade and level area around well. PRE Wait on truck to move rig components. Crew change. Pre-tour operational and HSE meeting. PRE Move rig and components from X-17. PRE Spotted sub, pits and pipe shed. Moved satellite camp. PRE PJSM. Rig up. Raise and scope derrick. Rig up and pressure test circulating lines. Accept rig ~ 11:00-hrs. DECOMP PU lubricator and make up to swab valve. P!T lubricator to 2.50 KILL P DECOMP Finish rigging up Tiger tank and circulating lines. Test high level alarm on Tiger tank. PJSM -Reviewed kill well procedure with crew. Returned tank #73081 to service. T/I/O = 0/0/0. 2.00 KILL P DECOMP Kill well, by circulating 120E seawater down tubing at 6.0-bpm at 670-psi taking returns from I/A to Tiger tank. Monitoring O/A pressure while circulating. 0.50 KILL P DECOMP Moitor well. Well is dead. 1.00 WHSUR P DECOMP Cameron wellhead tech. d rod set TWC and verify 100% travel for full engagement in hanger profile. P/T TWC from above and below to 3500-psi for 10-charted minutes in both directions. 1.50 WHSUR P DECOMP Held crew change and performed pre-tour checks of PVT equipment and derrick. ND production tree and tubing head adapter flange. Functioned lock down screws. 2.00 BOPSU P DECOMP NU BOPE. Installed choke and kill lines. Installed flow nipple. 1.00 BOPSU P DECOMP Held weekly safety meeting with all night rig personnel. Discussed Safety Alerts, rig performance statistics,. and recent incidents. Aired individuals' safety concerns. 1.50 BOPSU P DECOMP Tested BOPE to 250 si low / 3500 si hi h. BOPE test witnessed by J. Jones, AOGCC Petroleum Inspector. 12.00 BOPSU P DECOMP Continued testing BOPE to 250 psi low 13500 psi high. Tested VBR with 3-1/2" and 4-1/2" test joints. Tested annular with 3-1/2" test joint. Repair 4-way blind ram control valve on Koomey unit. BOPE test witnessed by J. Jones, AOGCC. 2.00 PULL P DECOMP Pull TWC. Ri u 4-1/2" tubin handlin a t.: Single joint compensator w/single joint elevators and double stack hydraulic pipe tongs. Circ. migrated diesel from I/A. Makeup landing joint with TIW valve and XO to 4-1/2" TCII tubing hanger threads. 1.00 PULL P DECOMP Weekly HSE meeting all crew. Reviewed past weeks ADW HSE events, current rig scorecard and IADC incidents pertaining to 4ES operations. 0.50 PULL P DECOMP BOLDS. Screw landing joint into tubing hanger. Unland tubing hanger with 120K P/U wt. Hoist hanger to floor. Break out and lay down tubing hanger. 2.50 PULL P DECOMP POH w/4-1/2" 13Cr80 VAM To com letion. Using double stack tongs, single joint compensator and elevators to break Printed: 6/10/2008 11:46:50 AM BP EXPLORATION Page 2 of 9 Operations Summary Report Legal Well Name: X-16 Common W ell Name: X-16A Spud Date: 4/20/1982 Event Nam e: WORKO VER Start : 5/10/2008 End: 5/23/2008 Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 5/23/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/12/2008 15:30 - 18:00 2.50 PULL P DECOMP out and lay down jts. 1 x 1 to pipe shed. VAM USA representative on rig floor inspecting pin ends of each joint, re-doping pin end and applying thread protectors before laying each joint down. VAM USA rep. inspecting box ends of joints in pipe shed re-doping and applying box end thread protectors before removing pipe to outside storage. 18:00 - 00:00 6.00 PULL P DECOMP Held crew change and performed pre-tour checks of PVT equipment and derrick. Resumed POH, LD 4-1/2" 12.6#, 13Cr80 VAM Top tubing. VAM USA personnel preparing threads for re-running. 90 jts LD at 00:00 hrs. Minor thread galling visible on few joints. 5/13/2008 00:00 - 12:00 12.00 PULL P DECOMP Continued POH, LD 4-1/2" 12.6#, 13Cr80 VAM Top tubing. VAM USA personnel preparing threads for rerunning. Held D1 drill at 00:30 hrs. Actual hole fill within 1 bbl of calculated pipe displacement. 197 joints POH ~ 07:30-hrs. BOP drill at 10:00-hrs. Recovered total of 235 joints, 5 each of 4-1/2" GLM's, 2 each of X nipple assemblies and two spaceout pups. Layed down cut joint. Cut joint length = 20.30'. Cut flare O.D. = 4.85" Found 7 joints with bad pins and four joints with bad couplings. VAM USA rep wi{I attempt to repair bad pins and bad couplings will be replaced. final count on rerunnable joints = 234. One bad joint (#76) due to small I. D. amount of pitting on pin end. 12:00 - 14:00 2.00 PULL P DECOMP RD 4-1/2" handling equipment and cleared rig floor. Installed wear ring. 14:00 - 15:00 1.00 CLEAN P DECOMP RU 3-1/2" handling equipment and hydraulic pipe spinner. 15:00 - 18:00 3.00 CLEAN N WAIT DECOMP Waited for delivery of 7" fishing tools. 18:00 - 19:30 1.50 CLEAN P DECOMP Held crew change and performed pre-tour checks of PVT equipment and derrick. PU dress-off BHA #1: washover shoe, 4 x washpipe ext, dress off mill, boot basket, 7" scraper, float sub, 9 x DC, spaced 9-5/8" scraper. 19:30 - 00:00 4.50 CLEAN P DECOMP RIH with dress off BHA #1, picking up 3-1/2" DP from pipe shed. 5/14/2008 00:00 - 04:30 4.50 CLEAN P DECOMP Continued RIH with dress off BHA #1, picking up 3-1/2" DP from pipe shed. Tagged 4-1/2" tubing stub at 10,050' DPM. 04:30 - 06:30 2.00 CLEAN P DECOMP LD 1 jt DP, PU 10' DP pup and kelly. Established parameters: PU 156k Ib, SO 121 k Ib, Rot 135k Ib, 4 bpm, 750 psi, 70 rpm, 180a, 4000 Ib-ft. Dressed off 4 1/2" tubing stump to 10,051' . Swallowed Tubing Stump down to 10,069' DPM. 06:30 - 09:00 2.50 CLEAN P DECOMP Pump a 40 bbl Hi-Vis sweep and circulated back to surface with sea water at 5.6 bpm/1080 psi. Recovered a small amount of fines. Monitor OAP = 0 psi. 09:00 - 09:30 0.50 CLEAN P DECOMP Set back Kelly and lay down 10' Pup Joint. 09:30 - 14:00 4.50 CLEAN P DECOMP Start to trip out with 3 1/2" Drill Pipe. Stand back in Derrick. Stop to lay down 9 5/8" Casing Scraper and XOs. Continue standing back remaining 3 1/2" Drill Pipe. 14:00 - 16:00 2.00 CLEAN P DECOMP Stood back 4-3/4" drill collars. LD dress off BHA #1. Cleared and cleaned rig floor. 16:00 - 18:00 2.00 EVAL P DECOMP MIRU SWS E-line service. Spotted logging unit and barricaded sensitive areas on pad and rig. RU line wiper. RIH to log with ~~ USIT. 18:00 - 19:30 1.50 EVAL P DECOMP Held crew change and performed pre-tour checks of PVT system and derrick. Logged with USIT from 3100' to surface. Printed: 6/10/2008 11:46:50 AM BP EXPLORATION Page 3 of 9 Operations Summary Report Legal Well Name: X-16 Common Well Name: X-16A Spud Date: 4/20/1982 Event Name: WORKOVER Start: 5/10/2008 End: 5/23/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/23/2008 Rig Name: NABORS 4ES Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations 5/14/2008 18:00 - 19:30 1.50 ~EVAL P DECOMP TOC indicated t 214 ' - '. Consulted with RWO 19:30 - 22:00 2.501 DHB P 22:00 - 22:30 ~ 0.50 ~ DHB ~ P 22:30 - 00:00 I 1.501 DHB I P 5/15/2008 100:00 - 00:30 I 0.501 DHB I P 00:30 - 02:00 ~ 1.501 FISH ~ P 02:00 - 04:00 2.00 FISH P 04:00 - 05:00 1.00 FISH P 05:00 - 06:00 1.00 FISH P 06:00 - 11:30 5.50 FISH P 11:30 - 13:00 I 1.501 FISH I P 13:00 - 13:30 0.50 FISH P 13:30 - 14:30 1.00 FISH P 14:30 - 15:00 0.50 FISH P 15:00 - 18:00 3.00 FISH P Engineer, inferred 9-5/8" casing cut depth at about 2080', and RBP setting depth at about 2190', avoiding casing collar. RDMO SWS E-line service. TIEB1 MU 9-5/8" 47# HES RBP. RIH on 3 stands 4-3/4" DC, 20 stands 3-1/2" DP and 1 single. Set RBP at 2187' COE, 2183' fishin neck de th. Disengaged from RBP and verified set. LD 1 jt and POH 1 stand 3-1/2" DP. TIEB1 MU head pin and RU to pump down DP. Closed annular BOP. TIEB1 Dum ed 2200 Ib 20/40 mesh river sand down DP and onto RBP. Circulated 14 bbls seawater at 1 bpm and 30 psi. Allowed sand to settle. TIEB1 Continued allowing sand to settle on RBP. RIH and tagged sand at 2131', or 52' sand on RBP. TIEBi POH with RBP running tool, standing back 3-1/2" DP. LD RBP running tool. TIEB1 PU 9-5/8" casin cuttin BHA #2:, 8-1/4" multi string cutter, XOs, 9 x 4-3/4" DC. RIH on 3-1/2" DP. Held D1 drill. TIE61 RU line from cellar to open top tank. MIRU LRS pump truck and diesel carrier. Spotted and RU vac trucks. Located casing collars. TIEB1 Correlate Drill Pipe tally with USIT Log. Re-locate casing collars. Begin cut at 05:25 hrs at 2083' DPM (2070' log depth which is 5-ft below casin collar on to at 2065'). Initial parameters as follows: 60 RPMs at 60 Amps = 1200 fUlbs torque. Bring pump on line at 2 bpm/100 psi. increase pump rate at 3 bpm/250 psi, 4 bpm/450 psi, 5 bpm/700 psi, 6 bpm/1050 psi. Completed cut at 05:41 hrs. Sawa 400 psi pressure drop. Continue rotating at cut depth for an additional 15 minutes. Stop rotation. Pick up 3-ft inside casing. Drop back down to tag cut and saw a 400 pis pressure decrease. Indication of a ositive cut has been made. TIEB1 Be in cleanin Arctic Pack from 9 5/8" x 13 3/8" Ann , hot Sea Water. Initial circulations at 5 bpm/1000 psi. Initial returns 80% diesel with slugs of Arctic Pack. Saw some returns in cellar then it quit. Pump 50 bbls of hot diesel behind the 9 5/8" csg and let soak for 30 minutes. Displace to slop tank with hot sea water. Pump a second diesel sweep and also let soak for 30 minutes. Displace well bore and annulus with a comple circulation using hot sea water. Return clean. TIEB1 Set back Kelly. Trip out with 3 1/2" Drill Pipe and Drill Collars. Stand back in derrick. TIEB1 Lay down MS Cutter (BHA #2). Inspected cutter blades. Observed expected normal wear pattern. TIEBi Rig up handling equipment to pull 9 5/8" casing. BOLDS. TIEB1 Make-up Double Spear. TIEBi Plant Spear in Casing. Attempt to pull Casing Hanger free. Work up to 215K. Apply steam to well head and double check lock down pins. Hanger broke free with 250 K pulled. Continue to pull Hanger to Rig Floor at 106K. LD spear and casing hanger. POH, LD 1 jt 9-5/8" casing. Printed: 6/10/2008 11:46:50 AM • • BP EXPLORATION Page 4 of 9 Operations Summary Report Legal Well Name: X-16 Common Well Name: X-16A Spud Date: 4/20/1982 Event Name: WORKOVER Start: 5/10/2008 End: 5/23/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/23/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code' NPT Phase ', Description of Operations 5/15/2008 18:00 - 00:00 6.00 FISH P TIEBi Held crew change and performed pre-tour checks of PVT equipment and derrick. Bermed casing staging area with Herculite. POH and LD 9-5/8" casino. Casino covered with Arctic Pack solids. No visible internal or external corrosion. High break-out torque required, up to 40k Ib-ft. Some joints visibly deformed by tongs. 5/16/2008 00:00 - 01:30 1.50 FISH P TIEB1 Continued POH, LD 9-5/8" casing. Recovered total of 53 jts 9-5/8" casing and 5.32' cut piece. Photos of cut on S-drive. About 1/3 of joints required 40k Ib-ft break-out torque. About 1/3 of joints visibly deformed during break-out. 01:30 - 03:30 2.00 FISH P TIEB1 RD casing handling equipment. Cleared and cleaned rig floor of significant amount of Arctic Pack solids. 03:30 - 05:00 1.50 FISH P TIE61 PU 9-5/8" casin dress-off BHA #3: washover shoe, wash pipe ext, dress off mill, boot basket, 13-3/8" scraper, XOs, float sub, 9 x 4-3/4" DC. 05:00 - 08:00 3.00 FISH P TIEB1 RIH with 9-5/8" casing dress-off BHA #3 on 3-1/2" DP from derrick. 08:00 - 09:00 1.00 FISH P TIE61 Pick-up Kelly. Tag top of 9 5/8" Casing Stump at 2,083' DPM. Swallowed 4' with no problem. Dress off stump to approx 2,083.5'. (PUW = 60K, SOW = 40K, RW = 50K, Amps = 80/1,700 ft/Ibs of torque, RPMs = 75, Pump Rate = 4 bpm/100 psi. 09:00 - 11:00 2.00 FISH P TIEB1 Mix and pump a 20 bbl Hi-Vis sweep. Displace back to surface with hot sea water to clean up well bore. 11:00 - 12:00 1.00 FISH P TIEB1 Set back Kelly. Trip out with 3 1/2" Drill Pipe and Drill Collars. Standing back in Derrick. 12:00 - 13:30 1.50 FISH P TIE61 Lay down 9 5/8" casing dress-off tools. (Also break out Double Spear). 13:30 - 15:00 1.50 BOPSU P TIEB1 Ni le down BOP Stack., 15:00 - 17:00 2.00 WHSUR P TIEB1 Cameron Serviceman re-tap all threads in Casing Head. Replace all lock down pins and packing gland nuts. 17:00 - 18:00 1.00 BOPSU P TIEB1 NU BOPE. Installed test plug. 18:00 - 20:00 2.00 BOPSU P TIEB1 Held crew change and performed pre-tour checks of PVT equipment and derrick. Continued NU BOPE. Tested BOPE break to 250 si low / 3500 si hi h. AOGCC waived their right to witness the test...J. Jones. Pulled test plug. 20:00 - 22:30 2.50 CASE P TIEB1 RIH with 3 stands 4-3/4" DC and 5 stands 3-1/2" DP. PUMU 13-3/8" RTTS and XO. Continued RIH with 5 stands DP and 20' in on single. 22:30 - 00:00 1.50 CASE P TIEB1 Circulated the long way 3 bpm and 120 psi. Set RTTS at 500'. Tested below RTTS to 2000 si for 15 minutes ood test. Pumped down annulus, established LLR above RTTS: 1/4 bpm at 500 psi. Pumped 1.4 bbls down annulus with seawater and arctic ack returns to cellar. Pum ed cellar contents to o' ~en to tank.. m 5/17/2008 00:00 - 01:30 1.50 CASE P TIE61 Released RTTS. LD 1 single. POH, stood back 3-1/2" DP. LD RTTS. Stood back remaining DP and 4-3/4" DC. 01:30 - 02:30 1.00 CASE P TIEB1 Cleared and cleaned rig floor. 02:30 - 04:00 1.50 CASE P TIEB1 Held PJSM. RU to run 9-5/8" tieback casing. RU torque turn equipment and false bowl. 04:00 - 10:45 6.75 CASE P TIEB1 PUMU Bowen Casing Patch overshot. Bakerlocked connection to ES cementer. RIH with 9-5/8" 47# L-80 Hydril 563 Cond "B" tieback casing. Ran 1 free centralizer per joint. Optimum MU Printed: 6/10/2008 11:46:50 AM BP EXPLORATION Operations Summary Report Page 5 of 9 Legal Well Name: X-16 Common Well Name: X-16A Spud Date: 4/20/1982 Event Name: WORKOVER Start: 5/10/2008 End: 5/23/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/23/2008 Rig Name: NABORS 4ES Rig Number: Date From - To Hours ~ Task Code NPT Phase Description of Operations 5/17/2008 04:00 - 10:45 6.75 CASE P TIE61 torque 15,200 Ib-ft. 10:45 - 11:00 0.25 CASE P TIE61 String weight = 100 K. Tag and swallow top of 9 5/8" Casing stump at 2,083' with Casing Patch. Pull 20 K over for initial set. Stack out. Pulled to 250 K (150K over). Slack off to 200 K (100 K over) and maintain for cementing operations. 11:00 - 11:45 0.75 CASE P TIE61 Pressure test Casin at 2,000 six 30 minutes. Good test. Shear open ES Cementer at 3,100 psi. 11:45 - 13:00 1.25 CASE P TIEB1 Bring Rig Pump on line and circulate well bore with warm Sea Water while rigging up Cementers, choke maniford and lines. Spot Vac Trucks. 13:00 - 14:00 1.00 CASE N SFAL TIE61 Stop operation. Had a 20 gal spill into the secondary containment when a large slug of Arctic Pack caused the cuttings bin to overflow. 5700 and Supervisor were notified. All others level "0" notifications were also made. Mess was cleaned up. 14:00 - 15:00 1.00 CEMT P TIEB1 Continue with rigging up for cementing operations. 15:00 - 15:15 0.25 CEMT P TIE61 PJSM with all. Discussed HSE matters and planned cementing operations. 15:15 - 15:30 0.25 CEMT P TIEB1 Bring Rig pump back on line with warm Sea Water and pump 50 bbls to flush any remaining Arctic Pack from Well. A small amount was recovered. 15:30 - 16:45 1.25 CEMT P TIE61 Continue with rig up. Install wiper plug in cement head. Make up cement head to 9 5/8" casing. Hook up lines. 16:45 - 17:00 0.25 CEMT P TIEB1 Prime up. Pressure test cement line to 4,500 psi. Good. 17:00 - 19:30 2.50 CEMT P TIEB1 Bring DS pump on line with 9.8 Brine at 5.0 bpm at 200 psi. Pumped a total of 50 bbls. Start cement. Bring weight up to 15.5 ppg at 3.0 bpm/70 psi. 25 bbls away, density at 15.82 ppg, 4.9 bpm/230 psi. 50 bbls away, density st 15.9 ppg, 4.9 bpm/240 psi. 100 bbls away, density 15.8 ppg, 5.0 bpm/220 psi. End cement at 139 bbls away (out of mix water ? 150 bbls of pumpable cement had been ordered), density 15.7 ppg. Shut down. Drop wiper plug. Flag tripped. Start 9.8 ppg Brine to displace cement at 4. pm. Increase rate to 6.0 bpm. 100 bbls displaced at 6.0 bpm/615 psi. 125 bbls displaced at 5.9 bpm/930 psi. 136 bbls displaced starting to get some Artic Pack and lead cement returns to slop tank. 140 bbls displaced. Slow rate to 2 bpm/590 psi. No returns in cellar from 13 3/8" surface leak. Clean cement returns. Start closing choke. At -50% closed saw pressure climb to 650 psi for very short time then it fell back to 590 psi. No returns in cellar. 149 bbls dis laced reduce rate to 1 b m. Plug down with 153.6 bbls total displacement. Let pressure climb. ES cementer closed at 1587 si. Let pressure climb to 2150 psi. Hold for 5 minutes. Release pressure slowely. No flowback. CIP at 18:37 hrs 5/17/2008. Estimate 2-3 bbls cement squeezed into 13-3/8" surface leak. 19:30 - 21:00 1.50 CEMT P TIEB1 RD SWS cementing equipment. Blew down lines. RD casing handling equipment. RU diaphragm pump and sucked 9.8 ppg brine out of top casing joint. 21:00 - 22:00 1.00 BOPSU P TIE61 Split stack at tubing spool. PU BOPE and spool. Cement top level with OA valve in casing head. Notified RWO engineer of cement top. 22:00 - 00:00 2.00 WHSUR P TIEBi Set casing slips with 100k Ib overpull. RILDS. RU Wachs Printed: 6/10/2008 11:46:50 AM • BP EXPLORATION Page 6 of 9 Operations Summary Report Legal Well Name: X-16 Common W ell Name: X-16A Spud Date: 4/20/1982 Event Nam e: WORKO VER Start: 5/10/2008 End: 5/23/2008 Contractor Name: NABOR S ALASK A DRI LLING I Rig Release: 5/23/2008 Rig Name: NABOR S 4ES Rig Number: i Date From - To Hours' Task Code NPT Phase Description of Operations 5/17/2008 22:00 - 00:00 2.00 WHSUR P TIEB1 cutter and cut 9/5/8" casing. LD 22.33' cut piece. 5/18/2008 00:00 - 03:00 3.00 WHSUR P TIEB1 NU new tubing spool with YBT secondary seal. Tested casing ackoff to 3800 si for 30 minutes. Notified Well Tie-In Team for survey crew. 03:00 - 04:30 1.50 BOPSU P TIEB1 NU BOPE. 04:30 - 05:00 0.50 CASE P TIEB1 PU cut casing joint, landing pup, and XO. Break apart and LD same. 05:00 - 06:00 1.00 BOPSU P TIEB1 Set test lu .Tested BOPE bre k to 250 psi low / 3500 psi high. BOPE test witness waived by C. Scheve, AOGCC. 06:00 - 06:30 0.50 CASE P TIEB1 Service Rig. Check PVT alarms. 06:30 - 07:00 0.50 CASE P TIEB1 Install Wear Bushing (ID = 9 1/16"). 07:00 - 08:00 1.00 CASE P TIEB1 Make u BHA #4 as follows: 8 1/2" Bit, 9 5/8" Csg Scraper, 2 ea Boot Baskets, XO, XO, Oil Jar, 9 ea 4 3/4" drill Collars, Circ Sub. 08:00 - 08:45 0.75 CASE P TIEB1 Trip in easy with BHA #4. Stay several joints above ES Cementer. 08:45 - 09:30 0.75 CASE P TIE61 Swap well over to warm Sea Water. 09:30 - 13:00 3.50 CASE P TIEB1 Continue to wait on Cement (compressive strenght at 12:21 hrs = 500 psi.). Hold weekly safety meeting with crew. Also cut and slip drilling line while WOC. 13:00 - 16:30 3.50 CEMT P TIEB1 Continue to Trip in. Tagged cement at 2,032' DPM. Pick up Kelly. PUW = 45K, SOW = 43K, RW = 50K, RPMs = 73, Pump rate = 4 bpm/175 psi, torque = 1800 fUlbs, WOB = 5K. Drill soft cement. Found hard cement at 2,058' (8') above ES Cementer. Drill out ES Cementer. Returns =cement pieces, small wiper ruber pieces, and fine aluminum pieces. Continue down to 2,120'. 16:30 - 17:30 1.00 CEMT P TIEB1 Mix and pump a 20 bbl Hi-Vis sweep. Circulate back to surface and clean up well. 17:30 - 18:30 1.00 CEMT P TIEB1 Ri u test um .Pressure test 9 5/8" casin after drill out._ Open OA. Pressure up on 9 5/8" casing to 1000 psi. Increase to 2.000 nsi. Increase to 3.500 nsi and test for 30 minutes. rlecora on cnart. uH remains o en. ivo now. rsocK Bona test. Close OA valve. Bleed off pressure. 18:30 - 19:30 1.00 CEMT P TIEB1 Trip out with 3 1/2" Drill Pipe and BHA #4. 19:30 - 21:00 1.50 CEMT P TIEB1 Lay down BHA #4. Clear and clean floor. 21:00 - 22:00 1.00 CEMT P TIEB1 Make u BHA #5 as follows: 7 7/8" x 8 1/2" Reverse Circulating Junk Basket, Boot Basket, Boot Basket, XO, XO, Oil Jar, 9 ea 4 3/4" Drill Collars, Circ sub. 22:00 - 23:00 1.00 CEMT P TIE61 Trip in with BHA #5 and 3 1/2" Drill Pipe. Pick up Kelly. 23:00 - 00:00 1.00 CEMT P TIEB1 Drop ball and wash with RCJB from 2125' - 2140' at 5.0 bpm/1000 psi. 5/19/2008 00:00 - 01:00 1.00 CEMT P TIE61 Trip out with RCJB run #1. 01:00 - 02:30 1.50 CEMT P TIEB1 Lay Down RCJB and clean out. Recovered 2 gals of rubber, small aluminum pieces, and a dozen large pieces of aluminum from the ES cementer. 02:30 - 03:30 1.00 CEMT P TIEB1 Hold weekly Safety Meeting with night crew. 03:30 - 04:00 0.50 CEMT P TIEB1 Make u RCJB for run #2. 04:00 - 05:30 1.50 CEMT P TIEB1 Trip in with RCJB run #2 and 3 1/2" Drill Pipe. Tag TOS at 2,140'. Pick up Kelly. 05:30 - 07:30 2.00 CEMT P TIEB1 Pick up Kelly. Washed down to 2,150'. Mix and pump a 20 bbl Hi-Vis sweep. Circulate sweep back to surface. 07:30 - 08:00 0.50 CEMT P TIEB1 Set back Kelly. Trip out with 3 1/2" Drill Pipe and BHA. Printed: 6/10/2008 11:46:50 AM BP EXPLORATION Operations Summary Report Page 7 of 9 Legal Well Name: X-16 Common W ell Name: X-16A Spud Date: 4/20/1982 Event Nam e: WORKO VER Start : 5/10/2008 End: 5/23/2008 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 5/23/2008 Rig Name: NABOB S 4ES Rig Number: Date i From - To '. Hours Task ', Code' NPT Phase Description of Operations 5/19/2008 08:00 - 09:00 1.00 CEMT P TIEB1 Lay down RCJB and clean out. Recovered several small pieces of rubber and several small chunks of aluminum. Clean out Boot Baskets. Recovered sand and fine cuttings from drilling up the ES Cementer. 09:00 - 09:30 0.50 CEMT P TIEB1 Clear and clean Rig floor. 09:30 - 10:30 1.00 BOPSU P TIEB1 Pull Wear Bushing. Install Test Plug. Rig up test equipment. 10:30 - 15:00 4.50 BOPSU P TIEB1 Perform week) BOPE test er BP and AOGCC re uirements at 250/3500 psi. Good test. The state's right to witness the test was waived by C. Sheeve. 15:00 - 16:00 1.00 BOPSU P TIE61 Rig down test equipment. Pull Test Plug. Install Wear Bushing (9 1/16" ID). 16:00 - 18:00 2.00 CASE P TIEB1 Pick u Halco Retrievin Tool and tri in with 3 1/2" Drill Pi e from Derrick. 18:00 - 19:30 1.50 CASE P TIEB1 Mix and reverse in with a 30 bbl Hi-Vis sweep. Clean remaining sand down to Halco RBP at 2,183'. 19:30 - 20:30 1.00 CASE P TIE61 Release Halco RBP and tri out with 3 1/2 Drill Pi e. 20:30 - 21:00 0.50 CASE P TIEB1 La down RBP and runnin t 21:00 - 21:30 0.50 CLEAN P DECOMP Clear and clean rig floor. Rig up to handle 2 7/8" PAC Drill Pi e. 21:30 - 23:30 2.00 CLEAN P DECOMP Make up BHA #6 as follows: 3.750" Bladed Junk Mill, XO, 22 Jts 2 7/8" PAC Drill Pipe, XO, Bumper Sub, 9 ea 4 3/4" Drill collars, Circ Sub. 23:30 - 00:00 0.50 CLEAN P DECOMP Start to trip in with BHA #6 and 3 1/2" drill Pipe. 5/20/2008 00:00 - 03:30 3.50 CLEAN P DECOMP Continue to trip in with 3 1/2" Drill Pipe from Derrick. Enter 4 1/2" Tubing Stump with no problems. Tag upper Fas-Drill Plug at 10 108' DPM. 03:30 - 06:00 2.50 CLEAN P DECOMP Pick up Kelly. Start drilling up Fas-Drill Plugs. Both Plugs have move down to the XN-Nipple at 10, 131' DPM. RMPs = 75. Pump rate = 1.7 bpm. Present fluid loss = 1 bpm. 06:00 - 08:00 2.00 CLEAN P DECOMP Unable to make much progress. Can not got out of tailpipe. Also have 40K overpull in one spot and a 5 - 10K over pull in a second spot. Discuss plan forward with Ancherage Engineering staff. 08:00 - 12:30 4.50 CLEAN P DECOMP Trip out with 3 1/2" Drill Pi a and BHA #6 12:30 - 15:30 3.00 CLEAN P DECOMP reak down BHA, inspect mill and send pictures to town. Mill has all the classic characteristics of havin ecountered colla sed / dama ed tubin .Excessive side wear with a sharply tapered and worn nose. Plan is to go in with a 3.5" OD mill. 15:30 - 16:30 1.00 CLEAN P DECOMP M/U 3 1/2" milling BHA &RIH w/ same. 16:30 - 18:00 1.50 CLEAN P DECOMP RIH w/ BHA on 3 1/2" DP. 18:00 - 18:30 0.50 CLEAN P DECOMP Crew change. Service rig. Check PVT alarms. Inspect derrick. 18:30 - 21:00 2.50 CLEAN P DECOMP Con't to RIH w/milling assy on 3 1/2" DP. 21:00 - 22:30 1.50 CLEAN P DECOMP P/U kelly & break circulation. 3 BPM ~ 470 psi. RIH & tag up ~ 10131'. Rotate & mill down to 10139'. Milled - 30 min ~ 10139' & mill fell thru. P/U Wt = 160K, S/O Wt = 115K, Rot Wt = 132K. WOB = 3-12K, Torq = 3.5K Ft-Ibs. Increased circulating rate to 6 BPM r~ 1400 psi. while milling. 22:30 - 23:30 1.00 CLEAN P DECOMP Set back kelly. RIH w/ stands of DP & tag up ~ 10,570'. 23:30 - 00:00 0.50 CLEAN P DECOMP P/U kelly & break circulation. Begin washing & reaming from 10570'. 5/21/2008 00:00 - 01:00 1.00 CLEAN P DECOMP Con't to Wash & ream from 10570 to 10676'. 103 stands, + double DP, + 19' Kelly, + BHA. P/U Wt = 166K, S/O Wt = Printed: 6/10/2008 11:46:50 AM BP EXPLORATION Operations Summary Report Legal Well Name: X-16 Common Well Name: X-16A Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date From - To ~ Hours I', Task Code NPT 5/21/2008 00:00 - 01:00 1.00 CLEAN P 01:00 - 02:00 I 1.00 I CLEAN I P 02:00 - 06:00 4.00 CLEAN P 06:00 - 06:30 0.50 CLEAN P 06:30 - 13:30 7.00 CLEAN P 13:30 - 15:00 1.50 CLEAN P 15:00 - 15:30 0.50 CLEAN P Start: 5/10/2008 Rig Release: 5/23/2008 Rig Number: Page 8 of 9 Spud Date: 4/20/1982 End: 5/23/2008 Phase Description of Operations DECOMP 116K, Rot Wt = 135K. 6 BPM ~ 1800 psi. 60 RPMs, WOB = 2-6K. DECOMP Make short trip from 10676' to 10163'. Ran back to 10676'. No problems or overpull. Went back to bottom w/ no fill. DECOMP H I PJSM. POOH & UD 3 1/2" DP. DECOMP Service rig, check PVT system, crown o matic, OK. DECOMP PJSM. Continue to POOH & UD 3 1/2" DP. DECOMP PJSM. LD drill collars, PAC pipe & BHA. Inspect mill, no significant wear on mill. In gauge. DECOMP PJSM. Pull wear ring. Continuous hole fill, well taking 10 - 15- 15:30 - 16:30 1.00 CLEAN P DECOMP Clear & clean rig floor. 16:30 - 18:00 1.50 BUNCO RUNCMP R/U Torque Turn equip. R/U floor to run tubing. 18:00 - 18:30 0.50 BUNCO RUNCMP Crew change. Inspect derrick. Check PVT alarms. Service rig. 18:30 - 19:30 1.00 BUNCO RUNCMP Finish R/U floor. Load jewelry in pipe shed & tag jts for GLMs. Hold PJSM & review running order w/ all hands. 19:30 - 20:30 1.00 BUNCO RUNCMP P/U tail pipe assys & backer-lok all connections below packer. M/U & check S-3 packer assy. 20:30 - 00:00 3.50 BUNCO RUNCMP RIH w/ 4 1/2" 12.6# 13Cr-80 Vam To c Torque turn all connections to 4440 ft-Ibs. Used Jet Lube Seal Guard thread compound on all connections, Changed out 1 bent jt (#13). RIH w/ 64 jts 5/22/2008 00:00 - 09:00 9.00 BUNCO RUNCMP Con't to RIH w/ 4 1/2" 12.6#, 13Cr-80, Vam Top tubing. Torque turn all connections to 4440 ft-Ibs. Used Jet Lube seal Guard thread compound on all connections. 09:00 - 09:30 0.50 BUNCO RUNCMP Service rig, check crown o matic, PVT system, OK. 09:30 - 13:00 3.50 BUNCO RUNCMP Continue in hole. M/U Jt # 234. Up wt 125K, down wt 88K. Observe 1st set of shear pins on overshot shear approximately 38' in on #234. Make up # 235 and tag fill with approximately 7' of tubing stub swallowed. Attempt to reverse out fill. Back side pressures up to 1000 psi, no returns. Elect to mix Hi vis sweep. 13:00 - 14:30 1.50 BUNCO RUNCMP Mix 40 bbls Hi vis sweep and pump down tubing ~ 3 bpm / 350 psi, taking returns to pits. Pump 175 bbls. 14:30 - 16:00 1.50 BUNCO RUNCMP PJSM. Reverse circulate out sweep ~ 3 bpm / 300 psi. Formation sand in returns. 16:00 - 17:30 1.50 BUNCO RUNCMP PJSM. UD jts # 235, 234 and 233, make up 19.53' of space out pups. M/U Jt # 233. Make up tubing hanger. 17:30 - 21:30 4.00 BUNCO RUNCMP R/U & displace IA w/ 155 bbls of 120 degree seawater ~ 3 BPM, 220 psi. Follow w/ 540 bbls of 120 degree Inhibited seawater ~ 3 BPM, 220 psi. 21:30 - 22:30 1.00 BUNCO RUNCMP Land com letion. P/U Wt = 125k, S/O Wt = 88K. RILDS. UD landing jt & X-over. Drop Rod/Ball & allow to fall. 22:30 - 00:00 1.50 BUNCO RUNCMP R/U & pressure up on tubing to 2300 si & set Baker S-3 pac er, con't to pressure u to 3500 si & test tubin for m _min. test Ok. Bleed off tubin~q~ressure to 1500 psi & SI. Pressure up on annulus & test IA to 3500 psi for 30 min. Test Ok. Bleed down tubing to -1000 psi & DCR sheared. Bleed TP & IA to 0 psi. Pump thru both ways to insure good shear. Charted entire setting & test procedure. 5/23/2008 00:00 - 01:00 1.00 BUNCO RUNCMP Set TWC w/ d rod. Pressure up & test TWC from above w/ 3500 psi & from below w/ 1000 psi. Each test 10 min. 01:00 - 02:30 1.50 BOPSU P RUNCMP N/D BOPE. Printed: 6/10/2008 11:46:50 AM Printed: 6/10/2008 11:46:50 AM BP EXPLORATION Page 1 of 2 Casing Report -Actual Data for CAS ING PATCH. Legal Well Name: 01-17B Report #: 1 Spud Date: 3/13/1978 Common Well Name: 01-17B Start: 4/21/2008 Report Date: 4/25/2008 Event Name: WORKOVER End: Date Landed: 4/25/2008 General Information String Type: CASING PATCH Permanent Datum: MEAN SEA LEVEL Hole Size: (in) Hole TMD: (ft) Hole TVD: (ft) KB-Datum: 73.00 (ft) Water TMD: (ft) Str Wt on Slips: (Ib) Ground Level: (ft) CF Elevation: 73.00 (ft) Liner Overlap: (ft) Max Hole Angle: 27.00 (°) Circ Hours: (hr) Mud Lost: (bbl) KB to Cutoff: 2,900.83 (ft) Days From Spud: (days) Caging Flange 1 Wellhead Manufacturer: Model: Top Hub/Flange: (in) / (psi) Hanger Model: Packoff Model: BTM Hub/Flange: (in) / (psi) Actual TMD Set: 8,691.00 (ft) Integ ral Casin g Detail Item Size Weight ~ Grade Drift Threads JTS Length Top THD Manufacturer I Cond. Max OD ! Min lD Comp. Name (in) (Ib/ft) ~ (in) (ft) (ft) (in) ~ (in) LINER TOP PACKER 9.625 1 17.91 2,900.83 BAKER LINER HANGER 9.625 1 9.30 2,918.74 BAKER CASING JOINTS 7.000 26.00 L-80 BTC-M 139 5,655.80 2,928.04 SUMITOMO LANDING COLLAR 7.000 1 8,583.84 BAKER CASING JOINTS 7.000 26.00 L-80 BTC-M 1 40.98 8,583.84 SUMITOMO FLOAT COLLAR 7.000 L-80 BTC-M 1 1.00 8,624.82 HALLIBURTON MARKER JOINT 7.000 L-80 BTC-M 1 19.80 8,625.82 CASING PUPJOINT 7.000 L-80 BTC-M 1 7.84 8,645.62 CROSS-OVER (DIAM) 7.000 BTC-M 1 1.41 8,653.46 CASING PUPJOINT 5.500 L-80 IBT-M 2 11.63 8,654.87 LANDING COLLAR 5.500 1 8,666.50 BAKER CASING PUPJOINT 5.500 L-80 IBT-M 1 9.40 8,666.50 GUIDE SHOE 8.250 L-80 IBT-M 1 15.10 8,675.90 8,691.00 • Printed: 6/10/2008 11:47:07 AM Printed: 6/10/2008 11:47:07 AM • • BP EXPLORATION Page 1 of 3 Cementing Report Legal Well Name: 01-17B Spud Date: 3/13/1978 Common Well Name: 01-17B Report #: 1 Report Date: 4/25/2008 Event Name: WORKOVER Start: 4/21/2008 End: Cement Job Type: Primary Primary Squeeze O en Hole S ueeze Casing '~ Plug Hole Size: 8.681 (in) Hole Size: Hole Size: Hole Size: TMD Set: 8,691.0 (ft) SO TMD: (ft) TMD Set: Top Set: (ft) Date Set: 4/25/2008 SO Date: Date Set: BTM set: (ft) Csg Type: CASING PATCH SO Type: Csg Type: Plug Date: Csg Size: 7.000 (in) SO TMD: Plug Type: SO Date: Drilled Out: Cmtd. Csg: CASING PATCH Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: DOWELL SCHLUMBERGER Pipe Movement Rot Time Start: Time End: RPM: Init Torque: (ft-Ibf) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Rec Time Start: Time End: SPM: Stroke Length: (ft) Drag Up: (Ib) Drag Down: (Ib) Stage No: 1 of 1 Type: PRIMARY CEMENT Start Mix Cmt: 15:12 Disp Avg Rate: 4.00 (bbl/min) Returns: 90% Returns Volume Excess %: 20.00 Start Slurry Displ : 15:16 Disp Max Rate: 4.00 (bbl/min) Total Mud Lost: (bbl) Meas. From: EST. GAUGE HOLE Start Displ: 16:05 Bump Plug: Y Cmt Vol to Surf: 10.00 (bbl) Time Circ Prior End Pumping: 17:00 Press Prior: (ft) To Cementing: 1.00 End Pump Date: 4/25/2008 Press Bumped: 4,200 (psi) Ann Flow After: N Mud Circ Rate: 424 (gpm) Top Plug: Y Press Held: 5 (min) Mixing Method: ON-THE-FLY Mud Circ Press: 1,618 (psi) Bottom Plug: N Float Held: Y Density Meas By: DENSOMETER Mud Data Type: WATER/BRINE Density: 9.60 (ppg) Visc: 28 (s/qt) PV/YP: (cp)/ (Ib/100ft2) Gels 10 sec: (Ib/100ftz) Gels 10 min: (Ib/100ftz) Bottom Hole Circulating Temperature:140 (°F) Bottom Hole Static Temperature: 190 (°F) Displacement Fluid Type:BRINE Density: 9.60 (ppg) Volume: 250.00 (bbl) Stage No: 1 Slurry No: 1 of 2 Slurry Data Fluid Type: SPACER Descript ion: SPACER WATER Class: SPACER Purpose: SPACER Slurry Interval: (ft) To: (ft) Cmt Vol: (sk) Density: 11.00 (ppg) Yield: (fts/sk) Mix Water: () Water Source: Slurry Vo120.0 (bbl) Water Vol: (bbl) Other Vol: (bbl) Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (psi) Printed: 6/10/2008 11:47:17 AM • BP EXPLORATION Cementing Report Page 2 of 3 Legal Well Name: 01-176 Spud Date: 3/13/1978 Common Well Name: 01-17B Report #: 1 Report Date: 4/25/2008 Event Name: WORKOVER Start: 4/21/2008 End: Stage No: 1 Slurry No: 2 of 2 Slurry Data Fluid Type: CEMENT Description: TAIL SLURRY Class: G-CLASS Slurry interval: 2,900.0 (ft) To: 8,691.0 (ft) Cmt Vol: (sk) Density: 15.80 (ppg) Yield: 1.160 (ft3/sk) Water Source: Lake Slurry Vo1:175.0 (bbl) Water Vol: (bbl) Other Vol: (bbl) Test Data Time Temp Thickening Time: 4.44 Temperature:80 (°F) Compressive Strength 1:6.28 (°F) Free Water: (%) Temperature: (°F) Compressive Strength 2: 7.17 (°F) Fluid Loss: 27.0 (cc) Temperature:140 (°F) Fluid Loss Pressure: 1,000 (psi) Trade Name D-46 D-65 D-167 D-153 B-155 D-186 Casing Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Stage No: 1 Slurry No: 2 of 2 -Additives - - Tvpe ~ Concentration ! Units ANTI FOAM DISPERSANT FLUID LOSS ANTISETTLING RETARDER ACCELERATOR Shoe Test Purpose: PRODUCTIO Mix Water: Q Foam Job: N Pressure 500 (psi) 1,000 (psi) Conc. ~ Units Liner Top Test Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Log/Survey Evaluation CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Liner Lap: Pos Test: (ppge) Tool: N Neg Test: (ppge) Tool: N Hrs Before Test: Cement Found on Tool: N Interpretation Summary Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Remarks Circulate with 9.6 brine, returns ~ 95 degrees. PJSM w/SLB cementers. -Switch to SLB Pumps. Pressure test lines to 4500 psi. -Pump 20 bbls 11 ppg mud push, followed by 175 bbls of 15.8 ppg Class G Cement. -Switch to rig pumps, drop plug and displace with rig pumps. -Bump plug on calculated strokes. WT WT WT WT WT GAUSX Printed: 6/10/2008 11:47:17 AM r~ Printed: 6/10/2008 11:47:17 AM C, BP EXPLORATION Page 1 of 2 Cementing Report Legal Well Name: 06-22 Spud Date: 9/15/1982 Common Well Name: 06-22 Report #: 1 Report Date: 5/5/2008 Event Name: WORKOVER Start: 4/21/2008 End: 5/12/2008 Cement Job Type: Primary Primary ' ~ Squeeze Open Hole.. Squeeze Casing _' _Plu Hole Size: (in) Hole Size: Hole Size: Hole Size: TMD Set: 7,510.0 (ft) SO TMD: (ft) TMD Set: Top Set: (ft) Date Set: 5/5/2008 SO Date: Date Set: BTM set: (ft) Csg Type: TIEBACK LINER 1 SO Type: Csg Type: Plug Date: Csg Size: 7.000 (in) SO TMD: Plug Type: SO Date: Drilled Out: Cmtd. Csg: OPEN HOLE Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: DOWELL SCHLUMBERGER Pipe Movement Rot Time Start: Time End: RPM: Init Torque: (ft-Ibf) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Rec Time Start: Time End: SPM: Stroke Length: (ft) Drag Up: (Ib) Drag Down: (Ib) Stage No: 1 of 1 Type: PRIMARY CEMENT Start Mix Cmt: 10:18 Disp Avg Rate: 5.00 (bbl/min) Returns: To slop tank Volume Excess %: 18.00 Start Slurry Displ : 10:20 Disp Max Rate: 6.00 (bbl/min) Total Mud Lost: (bbl) Meas. From: EST. GAUGE HOLE Start Displ: 11:00 Bump Plug: N Cmt Vol to Surf: (bbl) Time Circ Prior End Pumping: 11:45 Press Prior: (ft) To Cementing: 0.25 End Pump Date: 5/5/2008 Press Bumped: (psi) Ann Flow After: N Mud Circ Rate: 230 (gpm) Top Plug: N Press Held: (min) Mixing Method: ON-THE-FLY Mud Circ Press: 840 (psi) Bottom Plug: N Float Held: N Density Meas By: DENSOMETER Mud Data Type: Density: (ppg) Visc: (s/qt) PV/YP: (cp)/ (Ib/100ft2) Gels 10 sec: (Ib/100ft2) Gels 10 min: (Ib/100ft2) Bottom Hole Circulating Temperature: (°F) Bottom Hole Static Temperature: (°F) Displacement Fluid Type: Density: (ppg) Volume: (bbl) Stage No: 1 Slurry No: 1 of 1 Slurry Data Fluid Type: CEMENT Descripti on: LEAD SLURRY Class: G-CLASS Purpose: FILLER SLUR Slurry Interval: 2,365.0 (ft) To: 7,496.0 (ft) Cmt Vol: 709 (sk) Density: 15.80 (ppg) Yield: 1.160 (ft3/sk) Mix Water: 5.09 Q Water Source: Slurry Vo1:161.0 (bbl) Water Vo1:86.00 (bbl) Other Vol: ( bbl) Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (psi) Printed: 6/10/2008 11:47:29 AM Printed: 6/10/2008 11:47:29 AM TREE _ 4" CM/ WELLHEAD= MCEVOY ACTUATOR= OTIS KB. ELEV = 67.97 BF.ELEV = 39.47 KOP = 8143 Max Angle = 66.4 @ 10483' Datum MD = 10575' Datum TV D = 8800' SS DRLG DRAFT 13-3/8" CSG, 72#, L-80, ID = 12.347" 2688' 4 1/2" 12.6# 13cr80 Vam Top ID 3.958 I~ 10045' WHIPSTOCK (12/24/04) ~ 8143' BKR CIBP (05-24-04) $167' PERFORATION SUMMARY REF LOG: ANADRILL LWD (12/31104) ANGLEATTOPPERF: 25° @ 10538' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10538 - 10568 O 03/05/05 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 10191' X ~ 16 A I SAFETY NOTES: 4-112" CHROME TUBING & LINER Surface TOP OF CEMENT 2103' 4-1/2" HES X NIPPLE, ID= 3.813" 2580' 9-5/8" DV PKR GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 5 3214 3212 S MMG Do RK 16 06101 /08 4 5589 5284 40 MMG SO RK 20 06/01/08 3 7869 6891 43 MMG DMY RK 0 05/20/08 2 9322 7940 45 KBG-2 DMY RK 0 05/20/08 1 9870 8327 44 KBG-2 DMY RK 0 05120/08 MILLOUT WINDOW (X-16A) 8143' - 8159' 8010' 7" x 9-5/8" ZXP MECHANICAL LNR TOP PKR, ID = 3.300" 9938' 4-1/2" HES 'X' NIPPLE, ID= 3.813" gg5g' 7-5/8" x 4-1/2" BAKER S-3 PKR ggg3' 4-1/2" HES 'X' NIPPLE. ID = 3.813" 10045' UNIQUE MACHINE OVERSHOT 10085' 4-1/2" HES X NIP, ID = 3.813" 10106' 7" x 4-112" BKR S-3 PKR, ID = 3.875' 10130' 4-1/2" HES X NIP, ID = 3.813" 10151' 4-1/2" HES XN NIP, ID = 3.725" 10163' 4-1/2" WLEG ~~~ 10168' 5" x 7" ZXP LNR TOP PKR/ HANGER a-v2" TBG, 12s#, 10163' ~ 13CR VAM TOP, .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80, 10320' 0383 bpf, ID - 6.276" I 10679' I 4-1/2" LNR, 12.6#, 13CR VAM TOP, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 05109/82 ORIGINAL COMPLETION 06109/04 JDMIKA SUSPENDED RWO 01103105 N7 ES SIDETRACK X-16A 05/23/08 N4ES RWO 06/07/08 KSB/TD GLV GO (6/1/08) PRUDHOE BAY UNfT WELL: X-16A PERMff No: 1811720 API No: 50-029-20684-01 SEC 5, T10N, R14E BP Exploration (Alaska) r 05/20/08 ~chlumb~rg~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh !k NO.4712 y,~ tt i~ Company: State of Alaska ~~~~ J~~ ~ j: ~~{~~ Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 i ,.,. ne .,.:.. MPB-04A 12021150 MEM PROD PROFILE 04/17/08 1~ 1y MPG-13 12021151 MEM INJECTION PROFILE =C 04/18/08 1 1 Z-26A 11978454 MEM GLS 'aUCo -p 04/23/08 1 1 Z-29 11978453 MEM GLS _ 04/22/08 1 1 Y-36 12005204 MEM GLS ~/ 02/12/08 1 1 4-14A/S-37 12031471 _ PRODUCTION PROFILE W/FSI - 04/12!08 1 1 Y-07A 11966254 SCMT ! OS/02/08 1 1 02-01 B 11966257 LDL ~ (p 05/10/08 1 1 X-16A 11975771 USIT L . ~ 05/14/08 1 1 07-26 12061688 USIT - 05/16!08 1 1 05-34 11966251 USIT 04/13/08 1 1 05-23A 118966257 USIT ~ 05!13/08 1 1 S-33 11962596 USIT 04/15/08 1 1 V-223 12061688 CH EDIT PDC GR (USIT `~ - / 03/23/08 1 V-220 40016600 OH MWD/LWD EDIT ab _ 03/03/08 2 1 4-14A/S-37 40016545 OH MWD/LWD EDIT app.-U ( f 02/18/08 2 1 OS-22B f 1628800 MCNL 10/22/07 1 1 05-136 12021140 MCNL S 01/31/08 1 1 Z-10 12066520 RST (~~ 04/10/08 1 1 D-10 11975766 RST 04/25/08 1 1 --..__ .._...... .. ~~.....~ ..~...... .... .,............,..v na.. vn~~uvaa vrvc a.vr i cr~a.n ~ v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 - Date Delivered: 'a ,~, Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • ~\ • • ~_ :Mfg ~~ ~ ~ ~ ~ ~ ~ , " L f sf ~~ ~ ~ ~ , '` ` SARAH PALIN, GOVERNOR ,~ yy pp r°-~ j 4LL>•-7~ OII/ ta1sL li~-7 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATI011T COMl-II5SIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 °~ ~ 1.,~ ' ~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU X-16A Sundry Number: 308-159 Dear Mr. Reem: ~'~"~~~~~ MAY ~ ~ 200 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. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 3a day of April, 2008 Encl. ~~ REG~I!/ C.~ ' ~~ ~'~~ STATE OF ALASKA ~~-,da t s ~ ~ ~' ALA OIL AND GAS CONSERVATION COM~ION b ~( APPLICATION FOR SUNDRY 20 AAC 25.280 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extensiyi~ChOfa9@ ®Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 204-244 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20684-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU X-16A~ Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028313 ~ 68.6' ~ Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10766 9050 - 10679 8967 10151 None asin Len th Size MD TVD Bursf Colla se Structural Cond ct r 110' 20" x 30" 110' 110' Surface 2689' 13-3/8" 2689' 2689' 4930 2670 Intermediate 10191' 9-5/8" 8143' 7090' 6870 4760 Pr duction Liner 2327' 7" 7993' - 10320' 6981' - 8656' 7240 5410 Liner 613' 4-1/2" 10153' - 10766' 8532' - 9050' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10538' - 10568 8835' - 8862' 4-1/2", 12.6# 13Cr80 10163' Packers and SSSV Type: 7" x 4-1/2" Baker'S-3' packer Packers and SSSV MD (ft): 10106' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: May 12, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan, 564-5254 Printed Nam avid Reem Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date yl~'~p~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: g.. 1 Conditions of approval: Notify Commission so that a representative may witness lam-Q~c~c~ 1 l~~ - C"~ Cp ^ Plug Integrity ^ BOP Test ^ Mec hanical Integrity Test ^ Location Clearance ` Other: ~~OQc~c ~~ ~ '~ES`~ 1 Subsequent Fo equired: APPROVED BY A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Rev se~'' x_06 / ~~~~~~ APPROVAL ~~~ APR 2 5 ~,~~ ' ion ~~. t~~l` ~1 ~ ~Q08 Submit In Duplicate • by cr,~,y X-16A Expense Rig Workover Scope of Work: Pull 4-~/z" 13Cr-80 completion, cut and pull 9 s/" casing, run and cement to surface 9 5/" casing, run 4-'/z" 13Cr80 "stacker-packer" completion. MASP: 2370 psi Well Type: Producer Estimated Start Date: May 12, 2008 Production Engineer: AI Schmoyer Intervention Engineer: Paul Chan Pre-Rig Work Request: S 1 Pull TTP at 10151' MD. Drift thru 4-~h" tubin for tubin cut and settin FasDrill. E 2 Set 4-~/z" HES composite plug at 10135' MD, in the middle of the pup joint in the tailpipe. CMIT T x IA to 3500 psi. Power Jet cut 4-~/z" 13Cr-80 tubing at 10053' MD, in the middle of the first full 'oint above the Baker S-3 acker. Reference tubin tall dated 1/1/05. F 3 Circulate well with kill wei ht fluid and diesel thru the cut. W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 5 Set a BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE with 3-'h" x 6" VBR pipe rams. Pressure test to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-~h" tubing string to the cut. 3. Run USIT log to determine top of cement in 9-5/8' x 13-3/8" annulus. 4. Set retrievable bridge plug 100' below the top of cement and pressure test to 1500 psi for 15 minutes. 5. Cut and pull 9-5/a" casing from above the top of cement. Note: Pipe rams will not be changed to 9- 5/8" as the well has two tested barriers (FasDrill plug and RBP) to the reservoir. 6., Run and fully cement new 9 5/8' casing to surface. 7. rRun 4-'h" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at --9950' MD. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. n ~~ o~ ~- ~ wag ~ ~ ~ ~ 1~- ~r~~-. t~ = a" ci WEILHEAD= MCEVOY ACTUATOR = ®OTIS KB. ELEV = 67.97 BF. ELEV = 39.47 KOP = 8143 Max Angle = 66.4 @ 10483' Datum MD = 10575' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" C Minimum ID = 3.725" @ 10151' 4-1 /2" HES XN NIPPLE X ~ 16A ~Y NOTES: ***4-1/2" CHROMETBG ~ LNR"*' 2102' 4-1/2" HES X NIPPLE, ID = 3.813" 2580' 9-5/8" DV PKR GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3024 3202 5 MMG DMY RK 0 01/28/06 4 5621 5309 40 MMG DMY RK 0 01/28/06 3 7870 6892 43 MMG DMY RK 0 01/05/06 2 9366 7971 46 MMG DMY RK 0 01/05/06 1 10017 8433 43 MMG DMY RK 0 01/05/06 M ILLOUT WINDOW (X-16A) 8143' - 8159' 8010' 7" x 9-5/8" ZXP MECHANICAL LNR TOP PKR, ID = 3.300" WHIPSTOCK (12/24/04) BKR CIBP (05-24-04) I 8143' I 9-5/8" CSG, 47#, L-80, ID = 8.681" ~--L ~ PERFORATION SUMMARY REF LOG: ANA DRILL LWD (12/31/04) ANGLE AT TOP PERF: 2S° @ 10538' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10538 - 10568 C 03/05/05 4-1/2" HES X NIP, ID = 3.813" I ~' 7" x 4-1 /2" BKR S-3 PKR, ID = 3.875' 10130' 4-1/2" HES X NIP, ID = 3.813" 10151' 4-1 /2" HES XN NIP, ID = 3.725" 10151' 4-1/2"? PXN PLUG (02/05/08) 10163' 4-1/2" WLEG 10168' S" x 7" ZXP LNR TOP PKR/ HANGER 4-1/2" TBG, 12.6#, 1--~ 01s3' I \ 13CR VAM TOP, .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80, 10320' .0383 bpf, ID = 6.276" PBTD I-1/2" LNR, 12.6#, 13CRVAMTOP, I-{ 1 .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 05/09/82 ORIGINAL COMPLETION 09/22/06 RDW/PAG WANER SFTY NOTE DELETED 06/09/04 DM/KA SUSPENDED RWO 11/17/06 PJC DATUM MD CORRECTION 01/03/05 N7ES SIDETRACK X-16A 03/16/08 TTR/TLH PXN PLUG SET (03/10/08) 03/05/05 JNA/PJC PERFS 01/28/06 RMWPJC GLV GO 09/17/06 PGS/PJC DRLG DRAFT CORRC-CTIONS PRUDHOE BAY UNff WELL: X-16A PB~Mff No: 1811720 AR No: 50-029-20684-01 SC-C 5, T10N, R14E BP Exploration (Alaska) ~~ - d„ ~n WELLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 67.97 BF. ELEV = 39.47 KOP = 8143 Max Angle = 66.4 @ 10483' Datum MD = 10575' Datum TV D = 8800' SS X-1 C~ Proposed Complyion Surface TOP OF CEMENT ~;: 2102' 4-1/2" HES X NIPPLE, ID = 3.813" 25$0' 9-5/8" DV PKR GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347" ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 4 3 2 1 MILLOUT WINDOW (X-16A) 8143' - 8159' WHIPSTOCK (12/24/04) ~ $143' BKR CIBP (OS-24-04) ~~ $167' 9-5/8" CSG, 47#, L-80, ID = 8.681" H 10191' PERFORATION SUMMARY REF LOG: ANADRILL LWD (12/31/04) ANGLE AT TOP PERF: 25° @ 10538' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10538 - 10568 C 03/05/05 8010' 7" x 9-5/8" ZXP MECHANICAL LNR TOP PKR, ID = 3.300" 4-1/2" HES'X' NIPPLE, ID = 3.813" -9950 7-5/8" x 4-1/2" BAKER S-3 PKR 4-1/2" HES'X' NIPPLE, ID= 3.813" UNIQUE MACHINE OVERSHOT 10085' 4-1/2" HES X NIP, ID = 3.813" 10106' 7" x 4-1/2" BKR S-3 PKR, ID = 3.875' 10130' 4-1 /2" HES X NIP, ID = 3.813" 10151' 4-1/2" HES XN NIP, ID = 3.725" 10163' 4-1/2" WLEG 10168' S" x 7" ZXP LNR TOP PKR/ HANGER 4-1/2" TBG, 12.6#, 10163' ~ 13CR VAM TOP, .0152 bpf, ID = 3.958" " 7" LNR, 26#, L-80~ 10320' .0383 bpf, ID = 6.276" I PBTD I 4-1/2" LNR, 12.6#, 13CR VAM TOP, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 05/09/82 ORIGINAL COMPLETION 09/22/06 RDW/PAG WAIVERSFTY NOTE DELETED 06/09/04 DM/KA SUSPEND® RWO 11/17/06 PJC DATUM MD CORRECTION 01/03/05 N7ES SIDETRACKX-16A 03/16/08 TTR/TLH PXN PLUG SET (03/10/08) 03/05/05 JNA/PJC PERFS 01/28/06 RMN/PJC GLV GO 09/17/06 PGS/PJC DRLG DRAFT CORRECTIONS PRUDHOE BAY UNff WELL: X-16A PERMIT No: 1811720 API No: 50-029-20684-01 SEC 5, T10N, R14E BP Exploration (Alaska) Nabors 4ES X-17 RWO • • Maunder, Thomas E (DOA) From: Chan, Paul (PRA) [Paul.Chan@bp.com] Sent; Monday, Apri! 28, 2008 3:53 PM To: Maunder, Thomas E (DOA) Subject: RE: Nabors 4ES X-17 RWO Tom. Here are the intermediate steps that were not in the writeup. Page 1 of 2 RIH with 8='t5i~ bit, boot baskets, 9:'yi± scrag on drill collars and jars. Place boot baskets below scraper in BHA. Control drill the ES-Cementer and closing plug. Test 9="yip casing to 3500 psi for 30 charted minutes. Control drill to minimize debris size on top of sand plug. Seawater can now be used. Pump 20 bbl sweeps as needed to clean hole. CBU with final hi-vis sweep. POOH. RIH with reverse circulating junk basket to top of RBP and circulate clean. POOH. RiH with RBP retrieving tool and reverse ofF of RBP. Latch and unseat RBP. Circulate bottoms up and POOH with RBP. PU ~3='u i° bladed junk mill and wseven joints of 2-7/bit PAC drillpipe, bumper sub (no oil jars), and collars on drillpipe to drill up FasDrill plug. RIH to top of stub and establish PU, SO, and rotating parameters. Mill up the Fasdriil plug per Halliburton recommended practice. Once plug lets go, expect well to go on a vacuum. Push plug out the end of the tubing tail. POOH double displacing with seawater and LDDP. This will also be what wi{I be doing on X-16A ~~~ -~- ~-~,~ thanks Paul Chan Intervention Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 Cfax) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, April 28, 2008 2:07 PM To: Baca, Hank; Chan, Paul (PRA) Cc: Reem, David C Subject: RE; Nabors 4ES X-17 RWO Hank or Paul, Not sure which of you should get this. I am reviewing the sundry application and have a couple of questions. 1. It seems there are a couple of steps missing between 6 and 7 of your procedure. 4/28/2008 Nabors 4ES X-17 RWO • 2. Will the rig drill out the composite bridge plug? If so, is that done prior to current step 7? Thanks in advance, Tom Maunder, PE AOGCC Page 2 of 2 From: Chan, Paul (PRA) [mailto:PauLChan@bp.com] Sent: Monday, April 28, 2008 1:18 PM To: Maunder, Thomas E (DOA) Subject: Nabors 4ES X-17 RWO Tom Nabors 4ES is picking up and running completion on 4-42 RWO {no sundry required for this tubing swap} and are about 3 days ahead of schedule. The rig is planning to move to X-17 Wednesday rooming. The X-17 Sundry app was submitted on Friday. Would it be possible to have the X-17 sundry approved by tomorrow? Sincerely Paul Chan Intervention Engineer BP Alaska/Wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) 4/28/2008 • • R.~c~-. tiC- _ -• ~ 03/0112048 DO NOT PLACE Ygl? ~~. r ~~ ,. . ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertslMicrofilm Marker.d~oc STATE OF ALASKA • ~~ ~`*~~~ ALA~A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS F~~ ~ ~ ~~` 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ ~S~(~~~r >~>~ PLUG;,' ~!H Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver[] Time Extension ~tlChar~~ Change Approved Program ~ Operat. Shutdown[] Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 204-2440 - 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-20684-01-00 7. KB Elevation (ft): 9. Well Name and Number: 68.6 KB PBU X-16A 8. Property Designation: 10. Field/Pool(s): ADLO-028313 , PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10766 - feet Plugs (measured) None true vertical 9049.97 feet ~((~~ FE,Jym~(rr~a~y~q~1 None ~s tt~j ~~ff tt~jttlltt~~ Effective Depth measured 10679 - feet true vertical 8966.95 ' feet Casing Length Size MD TVD Burst Collapse Conductor 110 20"x30" Surface - 110 Surface - 110 Surface 2689 13-3/8" 72# L-80 Surface - 2689 Surface - 2689 5380 2670 Production 10191 9-5/8" 47# L-80 Surface - 10191 Surface - 8631 6870 4760 Liner 1319 7" 26# L-80 9676 - 10995 8523 - 9261 7240 5410 Perforation depth: Measured depth: C 10538 - 10568 _ True Vertical depth: 8834.71 - 8862.05 = _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR SURFACE - 10163' 0 0 - Packers and SSSV (type and measured depth) 7" Baker ZXP Mech Top Packer 8010 7"X4-1/2" S-3 PKR 10106 5"X7" ZXP LNR TOP PKR 10168 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ~` ~~ ~~~ ~ d ~~o~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ' Development ~` Seance Daily Report of Well Operations X 16. Well Status after proposed work: Oil ' Gas WAG ~~' GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb e ~ Title Data Management Engineer Signature Phone 564-4944 Date 2ti3/2008 Form 10-404 Plevised 04/2006 ~~ ~ ~~ O~ Submit Original Only ~- • • X-16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY AGTIVITYDAT6 " SUMMARY 1/31/2008 T/I/O = 1910/1600/0 Temp = SI. Bleed IAP to CLP, ensure GL line is isolated (secure). A/L is connected w/ 1630 psi on it, SI at casing valve. Bled ALP to 'CLP from 1630 psi to 120 psi. IA FL @ 252'. Bled IAP from 1600 psi to 10 psi in ',45 mins to DHD OT tank all gas: ~Teec)~monitor for 30 min, no change in `pressures. Post IA FL ~ 180'. Final WHPs = 1900/10/0. "*Note"* F/L is blinded off m.._ . _ _ _ _. _,. _ ___ .... __, _, _ _....__ ____ ti _~ 2/1/2008 TIO = SSV/60/0. Temp = SI. WHPs post IA bleed (secure). AL casing SI, ALP increased 30 psi to 150 psi. IAP increased 50 psi, OAP unchanged overnight. 2/2/2008 T/I/O = SSV/60/0. Temp = SI. Monitor WHP's post bleed for secure. No change in IAP overnight. ALP decreased to 80 psi overnight. _.~_ .. ~.... _ __.__~ __._~..... „~ __..~ _,. __m_ _ . ,,._ „__ ~._. 2/4/2008 *""*WELL S/I ON ARRIVAL*"'"` (master &ssv closed) TAG XN NIPPLE C«~ 10151' SLM W/ 3.805" CENT ATTEMPT TO SET PXN PLUG BODY (see log for details) "*"CONT WSR ON 2-5-08''** .,..~ _...___ . _____~_ _........__ __ __ ~_ .~...,., ~e.._ ._ . ~.~__ , ,~._.__ __. a_~ ~____ 2/5/2008. "*"CONT FROM 2-4-08*** (secure well) c+nT w ru nvn~ n~ i ~~ n~nv iii vii ~nnn~ r ~ an . wni c+~ s~ i.., .r.~ ~~n~ G IN PLUG BODY C~ 10142' (1.75" F-NECK, 1.875" OD, 96" *""BPS 10149'*'* **"*LEFT WELL S/I, NOTIFIED PAD-OP OF WELL STATUS"""" (master &ssv closed on departure) FLUIDS PUMPED BBLS 1 diesel 1 Total J~ DATA SUBMITTAL COMPLIANCE REPORT 4/11/2007 Permit to Drill 2042440 Well Name/No. PRUDHOE BAY UNIT X-16A Operator BP EXPLORATION (ALASKA) INC ;.rk~'i API No. 50-029-20684-01-00 MD 10766/ TVD 9050 /' Completion Date 3/212005 Completion Status 1-01l Current Status 1-01l UIC N -------.- -~---- .~--_. ----~_.- REQUIRED INFORMATION -~,- Directional Survey ~ Mud log No Samples No DATA INFORMATION Types Electric or Other Logs Run: DIR I GR,DIR I GR I RES I NEU I DEN Well Log Information: (data taken from logs Portion of Master Well Data Maint Logl Electr e Data Digital Dataset Log Log Run Interval OHI Type MedlFrmt Number Name Scale Media No Start Stop CH Received Comments ~ ~...- l D Asc Directional Survey 8100 10766 1/27/2005 IIFR D Asc Directional Survey 8100 10766 2/3/2005 IIFR rz D Lis 13209 I nd u ction/Resistivity 7869 10733 Open 7/7/2005 GR EWR4 ABI PWD CNP ~t SlD ROP 13209 LIS Verification 7869 10733 Open 7/7/2005 GR EWR4 ABI PWD CNP I SlD ROP r C Lis 13376 Reservoir Saturation 10179 10637 Case 11/21/2005 Reservoir Saturation Tool RST-C/Sigma I GR/ CCl 01-March-2005 ~ og 13376 Reservoir Saturation Blu 10200 10604 Case 11/21/2005 Reservoir Saturation Tool RST-C/Sigma I GRI CCl .J.D C Lis 01-March-2005 13722 Induction/Resistivity 8143 10766 Open 2/22/2006 ROP DGR EWR SLD CTN plus Graphics e --- ---~- Well CoreslSamples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y & Chips Received? ~ Daily History Received? (i)N cY/N Formation Tops Analysis Received? y~ ----~-- -~~-_.. --~.._- .__.~ ~-~_._~- Comments: DATA SUBMITTAL COMPLIANCE REPORT 4/11/2007 Permit to Drill 2042440 Well Name/No. PRUDHOE BAY UNIT X-16A MD 10766 TVD 9050 Completion Date 3/2/2005 Completion Status 1-01L Current Status 1-01L ~~_.__.~.._- t;;; -~ Date: _ / í /Jp ~~~-----c ~-'~~.., Operator BP EXPLORATION (ALASKA) INC Compliance Reviewed By: API No. 50-029-20684-01-00 UIC N e e Well X-16 (PTD #2042440) Classified as Tr. - Cancel waiver . All, V-I'" A- The waiver for well X-16 has been cancelled. The waiver process relating to wells with surface casing leaks has been reviewed and the finding is that GPB will no longer waiver these types of wells. Lead Operator: Will you please ensure any waiver related signage is removed from the wellhouse. Please call with any questions. Andrea Hughes (Filling in for Joe Anders) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 1 of 1 9/25/2006 10:51 AM . . WELL LOG TRANSMITTAL JOtf--d+4- To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 \'?jÎdd RE: MWD Formation Evaluation Logs X-16A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 X-16A: LAS Data & Digital Log Images: 50-029-20684-01 1 CD Rom ~lh 2' I ~91D(p 11/17105 Schlumberger NO. 3602 Alaska Data & Consulting Services 2525 Gambe/! Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne PI. WII L D D t BL C J b # e 0 og I escrlptlon a e o or CD 02-30B 10980587 RST 07117105 1 1 PSI-07 10674389 RST 10127103 1 1 PSI-07 10679045 RST 12126103 1 1 L3-02 11072860 RST 06113105 1 1 X-16A .:)D4 - ';;4-4 10980531 RST 03101105 1 1 /357/1'> F-30 10987523 RST 06122105 1 1 W-31 10913021 RST 06130/05 1 1 Z-15 10980580 RST 07/10/05 1 1 C-30 10980583 RST 07/13/05 1 1 W-39A 10928650 MCNL 10116/05 1 1 18-31A 10942210 MCNL 04/28/05 1 1 H-02A 10928622 MCNL 04/05/05 1 1 05-24A 10928609 MCNL "(PRINT SENT 1/24/05) " 12/22/04 1 K-06A 11075903 MCNL 07/30105 1 1 L-03 10913041 OH LDWG EDIT FOR WIRELlNE DATA 08101105 2 1 1 8-02A 10889169 SCMT 09122104 1 H-05 10674407 CBL 01/21104 1 G-13A 10563175 SCMT 06117103 1 E-06A 11051045 SCMT 05/19/05 1 W-20 10672389 USIT 06/03104 1 MPF-87A 10708043 USIT 01108104 1 MPA-03 11058243 USIT 09/07/05 1 MPF-89 11051088 US IT 08117/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E, Benson Blvd, Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 A TTN: Beth R.",,,d by t;~ \ ð - Date Delivered: ~:rJ~Yí~\i V ~}\ I ôCO"Ç . . . . WELL LOG TRANSMITI' AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 July 7, 2005 RE: MWD Fonnation Evaluation Logs: X-16A, AK-MW-3454677 1 LDWG fonnatted Disc with verification listing. API#: 50-029-20684-01 jJÀOC{ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LEifER TO THE AlfENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:~ ¡- Signed: 1LJ (J/J~ I, :) ù ~(- ¡ G( vI fr'/ t .. STATE OF ALASKA . ALASKA'~\t AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Conmission ReCËIVI:r5 MAR 9 1 2005 1a. Well Status: 181 Oil DGas D Plugged D Aþandoned D Suspended DWAG 1b. Well Class: ¿OAAC 25.105 20AAC 25,110 181 Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic D Service 2. Operator Name: 5. Date Camp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 3/2/2005 204-244 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 12/25/2004 50- 029-20684-01-00 4a. Location of Well (Governmental Section): 7. Date 1.D. Reached 14. Well Name and Number: Surface: 12/30/2004 PBU X-16A 423' NSL, 461' EWL, SEC. 05, T10N, R14E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 2519' NSL, 4391' EWL, SEC. 05, T10N, R14E, UM 68.6' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2583' NSL, 4493' EWL, SEC. 05, T10N, R14E, UM 10679 + 8967 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+ TVD) 16. Property Designation: Surface: x- 666333 y- 5940563 Zone- ASP4 10766 + 9050 Ft ADL 028313 --- 11. Depth where SSSV set 17. Land Use Permit TPI: x- 670209 y- 5942745 Zone- ASP4 Total Depth: x- 670310 y- 5942811 Zone- ASP4 (Nipple) 2102' MD ----- - ----- -- ---~ ___ n____ ___ 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 181 Yes DNa N/ A MSL 1900' (Approx.) 21. Logs Run: DIR / GR, DIR I GR I RES I NEU I DEN 2. CASING, liNER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING I EPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOp BOTTOM TOp I BoTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu yds Concrete 13-318" 72# L-80 Surface 2689' Surface 2689' 17-1/2" 3460 cu ft Arcticset " 9-5/8" 47# L-80 Surface 8143' Surface 7090' 12-1/4" 1450 cu ft Class 'G', 130 cu ft AS I 7" 26# L-80 7993' 10320' 6981' 8656' 8-1/2" :>25 cu ft Class 'G' 4-1/2" 12.6#' L-80 10153' 10766' 8532' 9050' 6-1/8" 112 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 10163' 10106' MD TVD MD TVD 10538' - 10568' 8835' - 8862' 25.. ACID,· FRÁCTURE,<CEMENT SOQEEZE,E"fC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect w/ 160 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): March 3, 2005 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oil -BSl GAs-McF WATER-Bsl CHOKE SIZE I GAS-Oil RATIO 3/25/2005 4 TEST PERIOD ... 272 3,009 318 95.710 11,085 Flow Tubing Casing Pressure CALCULATED .. Oil -BSL GAs-McF WATER-BsL Oil GRAVITY-API (CORR) Press. 422 820 24-HoUR RATE 1,629 18,055 1,908 30.4 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ..~.. None ~. . .~~:i./~ .r\ \ '~p , ,tJ.; ( rl\ ¡ ^ ... ....... -, ~ \' " , . ' 4(bJf,lll) Lj 1-22: ()-S Form 1 0-407 Revised 12/2003 CONTINUEO'ON'REVERSE SIDE 28. GEOLOGIC MARKERS NAME MD Sag River 10313' Shublik A 10354' Shublik B 10390' Shublik C 10412' Sadlerochit 10442' Zone 4A 10578' Zone 3 1 0666' 29. RMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TVD 8651' None 8682' 8709' 8727' 8751' 8871' 8955' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ./¡ T· I T Terrie Hubble /11"1 ¡ It e echnical Assistant Date 03/3/ /OS PBU X-16A Well Number 204-244 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Phil Smith, 564-4897 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. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 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 12/24/2004 12/29/2004 FIT LOT 8,143.0 (ft) 10,320,0 (ft) 7,090.0 (ft) 8,656,0 (ft) 11.00 (ppg) 8.40 (ppg) 555 (psi) 371 (psi) 4,606 (psi) 4,148 (psi) EMW ---,._-~-- 12.51 (ppg) 9.23 (ppg) Printed: 1/4/2005 9:54:15 AM · BP Page Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-16 X-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 12/18/2004 1/2/2005 Spud Date: 4/20/1982 End: 1/2/2005 Phase 12/18/2004 21 :00 - 00:00 3.00 CONS N WAIT PRE Waiting on 2-ES to complete move to DS-5. 24 hrs estimated time on road. With current weather conditions, Security will not I allow two rigs moving simultaneously. Prepair rig floor to lay í down derrick. disconnect topdrive & bridle up. Blow down water I lines in pits, disconect all lines, except steam & lights. 12/19/2004 00:00 - 12:00 12.00 MOB N WAIT PRE i Waiting on 2-ES rig move. Rig move was suspended at 00:30 i due to weather conditions and drifting snow. I Prep rig, shop and Camp for move. Inspect fluid ends on mud i pumps, change oil in # 2 rig generator, clean rig. 12:00-21:00 9.00 MOB N WAIT PRE I Waiting on 2-ES rig move, due to weather conditions, repair ¡suction valves in mud pits.Perform routine maintenace on I topdrive and iron roughneck. install moving jeep to mud pits. 21 :00 - 00:00 3.00 MOB N WAIT PRE Blow down steam to pits and disconnect electrical cables. Pull pits from sub, move sub off well and position to lay down 12/20/2004 00:00 - 02:00 2.00 MOB N WAIT PRE I derrick. Notified Pad operator prior to moving sub off well. I Load shop and camp and position at entrance to pad, Wait on Security to complete 2-ES move. Roads and Pads cleared snow drifts from entrance to pad and Z-pad access road. 02:00 - 10:00 8.00 MOB P PRE I Move Camp, shop and pits from Z-pad to X-pad, 23 miles, modules on location at 9:30. Temporarily position camp, shop ¡and pits, until rig is spotted on well. PJSM, with Toolpusher and lay down derrick. 10:00 - 12:00 2.00 MOB P PRE I Prepair rig to pull off pad. 12:00 - 00:00 12.00 MOB P PRE Move sub from Z-Pad to X-Pad, Rig at J-Pad @ 00:00 12/21/2004 00:00 - 13:00 13.00 MOB P PRE I Continue moving Sub from Z-Pad to X-Pad, rig on X-Pad road I @ 03,30 rig 00 loeatloo at 04"5, lay mats and herculite for sub, sand location, spot sub. raise mast, set pit complex, Camp & Shop. 13:00 - 16:00 3.00 RIGU P PRE Accept Rig @ 13:00 Hrs. Take on water & Complete R/U. 16:00 - 16:30 0.50 WHSUR P DECOMP R/U DSM lubricator & Pull BPV. fA & OIA Pressures = O. 16:30 - 20:00 3.50 CLEAN P DECOMP Reverse 15.5 BBls diesel out of tubing. Switch lines & circulate out remainder of diesel. Complete full circulation with warm, clean seawater @ 5 BPM & 1400 psi. 20:00 - 20:30 0.50 WHSUR P DECOMP Install TWC and test from below to 1000 psi. 20:30 - 21 :30 1.00 WHSUR P DECOMP N/D tree, Check Hanger thread ( 11 rounds wI XO ). Function LOS. 21 :30 - 00:00 2.50 BOPSU P DECOMP N/U BOPE & C/O top rams to 2 7/8". 12/22/2004 00:00 - 00:30 0.50 BOPSU P DECOMP Complete C/O top pipe rams to 2 7/8". 00:30 - 06:00 5.50 BOPSU P DECOMP Test BOPE to 250 -low & 3500 - high; as per Permit to Drill, Witness of test waived by Jeff Jones, AOGCC. Rig down testing equipment & blow down all lines. 06:00 - 08:30 2.50 PULL P DECOMP Pull TWC. M/U XO's & jt of 4" DP, screw into Hanger. 08:30 - 10:30 2.00 PULL P DECOMP Pull Hanger to floor - P/U wt. == 75K. Circulate bottoms up @ 250 GPM & 1650 psi. 10:30 - 12:00 1 .50 PULL P DECOMP Monitor well, pump slug. Break down XO's, landing Jt & Hanger. UD same. 12:00 - 21 :00 9.00 PULL P DECOMP POH layng down 2 7/8" work string. Total of 260 Jts. Found plastic coated pipe over-torqued. Very difficult breaking connections. 21 :00 . 21 :30 0.50 PULL P DECOMP RID tubing equipment. 21 :30 - 22:30 1.00 BOPSU P DECOMP M/U test plug. Change out upper pipe rams to 3.5" X 6" Variables. Printed: 1/4/2005 9:54:22 AM BP EXPLORATION Summary Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-16 X-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 12/18/2004 1/2/2005 Spud Date: 4/20/1982 End: 1/2/2005 Test upper pipe rams to 250 psi - low and 3500 psi - high. Attempt test on lower rams - seal on test plug failed. 23:00 - 00:00 1.00 CASE P DECOMP UD test plug & R/U to test 9 5/8" casing. 12/23/2004 00:00 - 01 :00 1.00 CASE P DECOMP Test & Chart 9 5/8" casing to 3500 psi. for 30 minutes. RID test equipment & blow down lines. 01 :00 - 02:00 1.00 CLEAN P I DECOMP PJSM & R/U Schlumberger Slick Line. 02:00 - 04:30 2.50 CLEAN P DECOMP Run gauge ring I junk basket. Tagged up @ 8,111' (71 ft. high). POH with -900 Ibs drag, Junk basket half full of clabbered mud. 04:30 - 05:30 1.00 CLEAN P DECOMP RID Schlumberger Slick Line. 05:30 - 06:00 0.50 BOPSU P DECOMP Run test plug & test bottom pipe rams to 250 psi - low & 3500 psi - high. Install Wear Bushing. 06:00 - 06:30 0.50 CLEAN P DECOMP Service Top Drive & Crown. 06:30 - 08:30 2.00 CLEAN P DECOMP P/U, M/U & RIH with Clean out BHA. 08:30 - 19:00 10.50 CLEAN P DECOMP RIH picking up 4" DP from shed to 7,989'. 19:00 - 19:45 0.75 CLEAN P DECOMP M/U Top Drive & wash down from 7,989'. Tag Bridge plug @ I 8,167'. 19:45 - 21 :00 1.25 CLEAN P I DECOMP Pump spacer & displace wellbore wI 11.0 ppg LSND Mud. Pump @ 500 GPM & 1400 psi. Rotate @ 80 RPM w/3700 Wlb Torque. P/U Wt. = 160K, DN Wt. = 140k, ROT Wt. = 150K. 21 :00 - 00:00 3.00 CLEAN P DECOMP Pump slug, blow down & POH. 12/24/2004 00:00 - 01 :00 1.00 CLEAN P DECOMP POH to BHA. 01 :00 - 02:30 1.50 CLEAN P DECOMP Set back HWDP & DC's. UD Bit, Bit Sub & Mill. 02:30 - 06:00 3.50 STWHIP P WEXIT M/U Whipstock BHA. Orient & test MWD. Complete P/U BHA. 06:00 - 12:30 6.50 STWHIP P WEXIT RIH wI Whipstock BHA on 4" DP from Derrick to 8,120'. 12:30 - 13:00 0.50 STWHIP P WEXIT Orient Whipstock to 79 degrees left of highside. Set Whipstock trip anchor on bridge plug @ 8,167' & shear off milling assembly. 13:00 - 18:30 5.50 STWHIP P WEXIT Mill Window from 8,143' to 8,159'. Mill open Hole to 8,172'. Milled @ 500 GPM 11400 psi. with 100 RPM & 5K to 8K Torque. 18:30 - 19:45 1.25 STWHIP P WEXIT Pump "Super Sweep" & work mills through Window. Window clean & clear. 19:45 - 20:45 1.00 STWHIP P WEXIT RlU & perform FIT: 11 ppg mud wt. + 555 psi surface pressure @ 7090TVD = 12.5 ppg. EMW FIT. RID 20:45 - 00:00 3.25 STWHIP P WEXIT Pump slug & POH. 12/25/2004 00:00 - 00:30 0.50 STWHIP P WEXIT POH to HWDP. 00:30 - 03:00 2.50 STWHIP P WEXIT Stand back HWDP & DC's. UD MWD Tools ( Pulsar had failed). UD Baker Milling Assembly. 03:00 - 04:00 1.00 STWHIP P WEXIT Pull Wear Bushing. M/U jetting tool on 4" DP single. Function & flush BOP stack & wellhead. Install Wear Bushing. 04:00 - 07:00 3.00 STWHIP P WEXIT P/U & M/U 8 1/2" Directional Drilling Assembly. Orient & up-load MWD. 07:00 - 10:30 3.50 STWHIP P WEXIT RIH to top of Window @ 8,143'. 10:30 - 11 :00 0.50 STWHIP P WEXIT Take SPR's & Baseline ECD's - ( 500 gpm + 90 RPM = 11.56 ppg. ECD). Orient & slide through window with no problem. 11 :00 - 00:00 13.00 DRILL P LNR1 Directional Drill 8 1/2" Hole from 8,172' to 8,966'. 500 GPM wI 3350 psi on bottom & 3150 psi off bottom. Torque = 5K to 6K on bottom & 4K to 5K off bottom. Running 5k to 15K WOB. 50 to 90 RPM. Calculated ECD = 11.64 ppg. PWD- ECD averaging 11.75 ppg. P/U Wt. = 170K, Dn. Wt. = 145K, ROT Wt. = 155K. AST = 3.17 Hrs. ART = 5.77 Hrs. 12/26/2004 00:00 - 01 :00 1.00 DRILL P LNR1 Directional Drill 8 1/2" Hole from 8,966' to 9,020'. 500 GPM wI Printed: 1/412005 9:54:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12/26/2004 00:00 - 01 :00 01 :00 - 02:30 02:30 - 13:00 13:00 - 20:00 20:00 - 00:00 12/27/2004 00:00 - 06:30 06:30 - 07:30 07:30 - 09:00 09:00 - 11 :00 11:00-12:00 12:00 - 15:30 15:30 - 16:45 16:45 - 19:00 19:00 - 21 :00 21 :00 - 00:00 12/28/2004 00:00 - 01 :00 - To . X-16 X-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES 1.00 DRILL P LNR1 1.50 DRILL N RREP LNR1 10.50 DRILL P LNR1 7.00 DRILL N WAIT LNR1 4,00 DRILL P LNR1 6.50 DRILL P LNR1 1.00 DRILL P 1.50 DRILL P LNR1 LNR1 2.00 DRILL P LNR1 1.00 DRILL P 3.50 DRILL P LNR1 LNR1 1.25 DRILL P LNR1 2.25 DRILL P LNR1 2.00 DRILL P LNR1 3.00 DRILL P 1.00 DRILL P LNR1 LNR1 Start: Rig Release: Rig Number: Spud Date: 4/20/1982 End: 1/2/2005 12/18/2004 1/2/2005 3450 psi on bottom and 3200 psi off bottom. Torque = 5K to 6K on bottom & 4K to 5K off bottom. Running 12k to 15K WOB. 50 to 90 RPM. Calculated ECD = 11.60 ppg. PWD- ECD averaging 11.66 ppg. P/U Wt. = 170K, On. Wt. = 155K, ROT Wt. = 155K. Replace API ring gasket on flange under pulsation dampner on pump #1. Torque tight and put back into service. Circulated with #2 pump while repairing. Standing back 1 stand every 30 minutes. Run back to bottom when pump back on line. Directional Drill 8 1/2" Hole from 9,020' to 9,638'. 500 GPM wi 3700 psi on bottom and 3500 psi off bottom. Torque = 6K to 7K on bottom & 5K to 6K off bottom. Running 10k to 15K WOB. 50 to 90 RPM. Calculated ECD = 11.60 ppg. PWD- ECD averaging 11.9 ppg. P/U Wt. = 180K, Dn. Wt. = 158K, ROT Wt. = 163K. AST =1.24 Hrs. ART =3.99 Hrs. Wait on weather. Phase 3 throughout Slope. Stop drilling. Circulate around 20 bbl high vis sweep. Work pipe full stand. Circulate at 250 GPM, 1156 psi, rotate at 25 RPM, 4600 TQ. POH and lay down one joint of drill pipe every hour. No hole problems. When Security announced Phase 2: RIH with singles to TD, precautionary wash down last 30'. No Drag, No Fill. Directional Drill 81/2" Hole from 9,638' to 9,921'. 500 GPM wI 3745 psi on bottom and 3550 psi off bottom. Torque = 6K to 7K on bottom & 5K to 6K off bottom. Running 10K WOB. 90 RPM. Calculated ECD = 11.65 ppg. PWD- ECD averaging 11.85 ppg. P/U Wt. = 180K, On. Wt. = 150K, ROT Wt. = 163K. ART =3.63 Hrs, Directional Drill 8 1/2" Hole from 9,921' to 10,320'. 500 GPM wI 3950 psi on bottom and 3750 psi off bottom. Torque = 6K to 7K on bottom & 5K to 6K off bottom. Running 10K WOB. 90 RPM. Calculated ECD = 11.60 ppg. PWD- ECD @ 10,320' = 11.77 ppg. P/U Wt. = 195K, Dn. Wt. = 165K, ROT Wt. = 170K. AST = 0,34 Hrs. ART = 4.69 Hrs Circulate Bottoms up for samples, as per Geologist request. TD in Sag River confirmed, Circulate High-Vis sweep - surface to surface. Wiper trip to window @ 8,143', Pulled with very little drag and no swabbing. Service Top Drive. Install repaired mud manifold. POH to 7,851' & confirm depth wI Sperry Sun. MAD pas RIH from 7,900' to 8,172" @ 2 FPM. RIH to 10,305'. Precautionary wash to TD @ 10,320. No Drag, No Fill. Circulate Hi-Vis Sweep. @ 500 GPM & 3700 psi. With 90 RPM. Small increase in cuttings when sweep to surface. Spot lube Pill in open hole, Drop Sperry Sun ESS Tool. POH to window @ 8,143'. Stop and take surveys @ 9,966', 9,586', & 9,481' to satisfy J.O.R.P.S. requirements. Hole in excellent shape - No Drag & No Swabbing. Pump slug. POH standing back 4" DP. POH to HWDP. Printed: 1/412005 9:54:22 AM · EXPLORATION mmary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-16 X-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 12/18/2004 1/2/2005 Spud Date: 4/20/1982 End: 1/2/2005 12128/2004 01 :00 - 04:30 3.50 DRILL P LNR1 Stand back HWDP. UD Jar, 9 ea. steel DC's, 3 ea. NM Flex DC's. Retrieve ESS. Down Load MWD/LWD & UD same. Break out Bit & UD Motor. 04:30 - 06:00 1.50 CASE P LNR1 R/U to run 7" Drilling Liner. 06:00 - 10:00 4.00 CASE P LNR1 Run 56 Jts., 7",26#, 1-80, BTC- M, Liner. M/U Baker 'HMC hanger & ZXP Packer Assy. + one Jtt 4" DP. Circulate liner I volume. 10:00 - 15:00 5.00 CASE P LNR1 RIH wI Liner on 4" DP filling every ten stands to 8010, 160k up 125k dn. 15:00 - 16:00 1.00 CASE P LNR1 CBU @ 8 bpm/1225 psi 16:00 - 16:30 0,50 CASE P LNR1 BID, P/U single & cmt. head. UD on skate. 16:30 - 18:00 1.50 CASE P LNR1 Cont. TI H to 10,306, no problems, no losses - full displacement. 18:00 - 18:45 0.75 CEMT P LNR1 R/U cement head, manifold, & lines, establish eirc. 2 bpm 575 psi. RIH & tag bottom @ 10,320' 18:45 - 19:15 0.50 CEMT P LNR1 Circulate - Stage pumps up to 6 BPM 11400 psi. No losses 19:15 - 19:30 0.25 CEMT P LNR1 Switch over to Dowell Schlumberger. Pump 5 bbls, 12 ppg. MudPush & test lines to 4000 psi. 19:30 - 21:00 1.50 CEMT N CEMT LNR1 Dowell had hydraulic line failure in unit when turning pumps back on, Unable to continue and / or repair unit. Sent another unit from yard, Hooked up same and primed pumps. Circulated @ 2 BPM I 470 psi while waiting - no losses. :00 - 21 :45 0.75 CEMT P LNR1 Continue with Cement job. Pump 15 Bbls, 12 ppg MudPush, followed by 40 Bbls, 194 sx, 15.8 ppg, 'G' Slurry wi 1.16 cU.ft!sk yield, All pumped @ 4 to 5 BPM. Drop DP Wiper Dart & chase with 5 Bbls water to clear cement lines. Switch back to Rig & displace with 163 Bbls of 11.1 ppg. old mud. Pumped at 7 BPM & slowed down to 3 BPM to pick up liner wiper plug and again prior to bumping plug. Bumped plug wI 2000 psi. No losses while cementing & displacing - 100% returns. CIP @ 21 :45 Hrs. 21 :45 - 22:00 0.25 CASE P LNR1 Pressure up to 3500 psi. to set 'HMC' Liner hanger. Set down to check set. Bleed pressure & check floats - OK. Rotate 15 turns to right. Pressure up to 1000 psi and pull out of packer sleeve, When pressure bleeds: Run up pumps to 6 BPM and pump 30 Bbls mud. Slow pumps to 1.5 BPM and set down 50K to set 'ZXP' Packer. Repeat set down while rotating. Good surface indication of set. 7" Casing shoe @ 10,320'. TOL @ 7,992' 22:00 - 23:30 1.50 CEMT P LNR1 Pick up 15' & circulate Bottoms up @ 500 GPM & 3100 psi. No Cement to surface. 23:30 - 00:00 0.50 CEMT P LNR1 Service rig. Change filter on hydraulic unit. 12/29/2004 00:00 - 01 :00 1.00 CEMT N RREP LNR1 Replace filter & valve on Rig main Hydraulic Unit. 01 :00 - 04:30 3.50 CEMT P LNR1 POH check & UD C-2 running tool. 04:30 - 09:00 4.50 DRILL P PROD1 Clear & Clean floor. P/U 6 1/8 BHA. upload tool, hold pjsm on nukes 09:00 - 13:00 4.00 DRILL P PROD1 TIH to 10,192'.' 13:00 - 14:00 1.00 CASE P PROD1 R/U & test liner to 3500 psi, hold 30 min. rId-bId 14:00 - 14:30 0.50 DRILL P PROD1 RIH to 10,205' drlg. cement stringers to 10,225' 14:30 - 15:30 1.00 DRILL P PROD1 drlg good hard cement @ 10,225 to LC-10234, drl-Ic, cmt, float 15:30 - 17:45 2.25 DRILL P PROD1 displace hole to 8.4 ppg flo-pro, 100 bbl H20 then 40 bbl ep pill, then 8.4 ppg flo-pro until 8.4 ppg mud around. 17:45 - 18:00 0.25 DRILL P PROD1 drlgf/10,315 to shoe @ 10,320, drill 20' of new hole to 10,340' Printed: 1/4/2005 9:54:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1~2t./j:!:"930 119:30 - 22:00 I I I i 122:00 - 00:00 I 1213012004 100,00 - 08'30 i I I I 108:30 - 10:45 110:45 - 11 :00 1111:00-11:30 11 :30 - 11:45 111:45-14:30 ! 114:30 - 15:15 15:15 - 20:00 20:00 - 00:00 . ORATION ummary Report X-16 X-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: Spud Date: 4/20/1982 End: 1/2/2005 12/18/2004 1/2/2005 12/31/2004 00:00 - 01 :30 01 :30 - 03:45 PROD1 CBU 275 GPM-1500 psi, 50 rpm-3100 tq, 180k up 160k dn, 170k rot. PROD1 Pull up into shoe, rlu & attempt FIT to 720 psi 10.0 EMW, psi bled off perform surface checks and isolation tests attempt FIT again to 720 psi, 10ppg EMW. Chart indicated a 9.2 ppg. Leak Off. Called and discussed wI ODE. Called Lou Grimaldi, AOGC representative, explained situation and received verbal permission to proceed w/drilling per plan wlout remediation PROD1 Directional drill 6 1/8" hole from 10,340 to 10,384, 275GPM @ 1700 psi., up wt. 180 k dn wt. 160k rot. 170k, torque=3500 art = .75 Hrs., ast", ,65 Hrs. PROD1 Directional drill 6 1/8" hole from 10,384 to 10,766 - TD as per Program & Geologist, 290 GPM @ 1800 psi., up wt. 185 k, dn wt. 165 k, rot. wt 170k, torque on =3750, torque off = 3400, WOB = 15k, RPM = 50, Losses < 5 Bbls I Hr AST '" 2.3 Hrs. ART = 2.93 Hrs, Circulate Hi-Vis weighted sweep. 290 GPM @ 1600 psi. 10% increase in cuttings, Wiper to above 7" shoe @ 10,288'. No excess drag. Service Top Drive & draw-works Run back to bottom - Hole in excellent shape - no fill. Circulate Hi-Vis, weighted Sweep. Spot Lube Pill across open hole. Pump @ 290 GPM & 1600 psi. Drop ESS. Pull up and survey @ 10,670' & 10,625'. to meet J.O,R.P,S. requirements. Pump slug & POH to HWDP. UD HWDP, Jars, Flex NIM DC's & ESS Tool. Hold PJSM & pull & UD Nuclear sources. Drain Motor, break off bit & download MWD data. UD mud motor & MWD. Clear floor. R/U to run 4.5" Production Liner. M/U & RIH w/2 Float Jts of 4.5", 12.6#,L-80, IBT-M Liner = XIO JT #3. Fill pipe & check floats. Continue running wI Torque-Turn, 4,5", 12.6#, 13Cr, VAM-TOP Liner. Fill every 5 Jts. Total 14 Jts. Centralize as per program. Checked floats. M/U Baker 4.5" X 7", 'HMC' Liner Hanger & 'ZXP Liner Top Packer assembly w/ running tool. M/U XO, 15' DP Pup jt.+ 1st stand of 4" DP. UD top single for cement head. M/U Top Drive & circulate 1.5 X Liner volume. RIH with 4.5" Production Liner on 4" DP, filling every 10 stands, to 20' above 7" shoe @ 10,300' Circ. String Volume @ 6 BPM 1600 psi. Picked up cement head and single and placed on skate. Performed spill drill 1 min. 30 sec. Check up wt 175k & dn wt 150K. Depth 10,300. TIH, took 15K to 20K @ 10,706' Attempt to pump - packed off, Pull up to 10,600' & established circulation break circulation slowly and kept working pipe to TD @ 10,766'. Circulate while batch mixing 20 bbls of slurry. Pump 5 Bbls CW-100 & test line to 3500 psi. Did not reciprocate due to light wt of liner and probability of rotating free of short liner during reciprocation. Continue with Cement job. Pump remaining 5 bbls. CW-100 1.50 DRILL P 2,50 EV AL P 2.00 DRILL P 8.50 DRILL P 2.25 DRILL P PROD1 0.25 DRILL P PROD1 0.50 DRILL P PROD1 0.25 DRILL P PROD1 2.75 DRILL P PROD1 0.75 DRILL P PROD1 4.75 DRILL P PROD1 4.00 DRILL P PROD1 1.50 CASE P RUNPRD 2.25 CASE P RUNPRD 03:45 - 04: 15 0.50 CASE P RUNPRD 04:15 - 04:30 0.25 CASE P RUNPRD 04:30 - 05:00 0.50 CASE P RUNPRD 04:45 - 10:30 5.75 CASE P RUNPRD 10:30 - 11 :00 0.50 CASE P RUNPRD 11 :00 - 12:00 1.00 CASE P RUNPRD 12:00 - 13:15 1.25 CASE P RUNPRD 13:15 - 15:00 1.75 CEMT P RUNPRD Printed: 1/4/2005 9:54:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12/31/2004 1/1/2005 ! 15:00 - 15:45 I I ! I I I i 15:45 - 17:00 I i 17:00 - 18:00 ! ! 18:00 - 19:00 i 19:00 - 00:00 i 00:00 - 02:30 ! 02:30 - 03:30 I I 03:30 - 05:30 I I 05:30 - 06:00 06:00 - 06:30 06:30 - 21 :30 . Start: Rig Release: Rig Number: 12/18/2004 1 /2/2005 Spud Date: 4/20/1982 End: 1/2/2005 X-16 X-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES ~-T~ H0LJ'r~1 Tas~ 113:15-15:00 i 1,75icEMT P I I I ¡ I I i i I . I 1 I I i I 0.751 CASE P I I I 1.251 CEMT P I 1.001 CEMT P I I 1.00¡ CEMT 5.00 i CEMT I 2.50 i CEMT 1.00 I CEMT 2.00 I RUNCO I 0.50 I RUNCO 0.50 RUNCO 15.00 RUNCO RUNPRD RUNPRD RUN PRO RUNPRD P P P RUNPRD RUNPRD RUNPRD RUNPRD RUNCMP RUNCMP RUNCMP RUNCMP 21 :30 - 22:30 I 1.00 RUNCO RUNCMP 22:30 - 23:15 0.75 RUNCO RUNCMP 23:15 - 00:00 0.75 RUNCO RUNCMP 1/2/2005 00:00 - 02:30 2.50 RUNCO RUNCMP 02:30 - 03:30 1.00 RUNCO RUNCMP 03:30 - 05:30 2.00 RUNCO RUNCMP 05:30 - 06:00 0.50 BOPSU P WHDTRE 06:00 - 07:30 1.50 BOPSU P WHDTRE 07:30 - 09:00 1.50 WHSUR P WHDTRE 09:00 - 09:30 0.50 WHSUR P WHDTRE 09:30 - 10:15 0.75 WHSUR P WHDTRE 10:15 -11:30 1.25 WHSUR P WHDTRE then pump 15 Bbls, 9.6 ppg MudPush, followed by 20 Bbls, 96 SX, 15.8 ppg, 'G' Slurry wI 1.17 cu,ft/sk yield. All pumped @ 3.5 to 4 BPM. Drop DP Wiper Dart & open 'Tee' to wash cement lines with 5 Bbls water. Switch back to Rig & displace with 109 Bbls of 8.4 ppg. old mud. Pumped at 6 BPM & slowed down to 2 BPM to pick up liner wiper plug and again prior to bumping plug. Bumped plug wI 2000 psi. No losses while cementing & displacing - 100% returns. CIP @ 14:45 Hrs. Cotinue pressuring up to 3500 psi to set 'HMC' Liner Hanger. Slack off 20k to confirm set. Bleed pressure to check floats - OK. Rotate 15 turns to right & pressure to 1000 psi. Pull up out of sleeve and when pressure bleeds: circulate 15 bbls @ 3 BPM I 540 psi. Set down 65 K to set ZXP Packer. Repeat set down while rotating @ 15 RPM. Good indication of set. Circulate bottoms up. Displace well bore to seawater. Approximately 30 Bbls cement contaminated mud to surface. Break off cement head & lay down same. Lay down DP single. Blow down all lines, Slip & cut 150 ft of drilling line. POH laying down all DP, POH UD all 4" DP. UD C-2 running Tool. Clean rig floor, pull wear ring and make dummy run wI tubing hanger R/U to run 4.5", 13Cr Completion. CIO bails & Elevators, R/U compensator, R/U Tongs & Computer. Load shed and arrange all completion equipment. Inspect completion equipment and verify run order. Test 4.5" Liner & Lap to 3500 psi. fo 30 minutes. PJSM on tubing running Run 236 Jts. 4.5" 12.60#, 13CR, VAM TOP TBG. up wt. 138K, dn. wt. 115K. P/U jts 237 & 238, tag in tie back extension @ 10,164' MD UD Jts & M/U space out pups to set WLEG @ 10,163' CIO elevators, UD compensator, P/U Tbg. Hanger & Landing jt. Reverse Circ. Seawater wlcorrosion inhibitor at 50 SPM and 50 PSI Reverse circulate 296 Bbls corrosion inhibited Seawater to packer displacing wI 171 Bbls clean Seawater. Land Tubing Hanger. R.I.L.D.S. Drop ball I rod assy. R/U to test. Pressure tubing to 3500 psi to set Baker S-3 Packer. Hold & chart for 30 minute test. Bleed tubing to 1600 psi & pressure annulus to 3500 psi. Hold & chart for 30 minute packer test. Bleed annulus then bleed tubing. Pressure annulus to 2400 psi to shear OCR valve. Pump 5 Bbls each way to insure full shear. Blow down all test lines and RID test equipment. Set TWC & test from below to 1000 psi. N/D BOPs N/U Tree and test Adaptor, Tree and Pack Off to 5000 psi. R/U DSM and pull TWC PJSM on Freeze Protecting and U- Tube, R/U to Freeze Protect Pump 160 bbls. of diesel down annulus Printed: 1/4/2005 9:54:22 AM Legal Well Name: Common Well Name: Event Name; Contractor Name; Rig Name: . BP EXPLORA TtO Operations Summa X-16 X-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Page Start: 12/18/2004 Rig Release: 1/2/2005 Rig Number: Spud Date: 4/20/1982 End; 1/2/2005 1/2/2005 11 :30 - 13:00 13:00 - 15:00 1,50 WHSUR P 2.00 WHSUR P OTHCMP RID Stabbing Board, allow diesel to U-tube WHDTRE Set BPV & Test t/1000 psi, RID Hot Oil, Secure Well RELEASE RIG @ 15:00 HRS, 01/02/2005 Printed: 1/4/2005 9:54:22 AM . . X -16A Prudhoe Bay Unit 50-029-20684-01-00 204-244 Accept: Spud: Release: Ri: 12/21/04 12/25/04 01/02/05 Nabors 7ES POST RIG WORK 02115/05 ASSIST DSM TO PULL BPV. BPV OOH. PULLED BALL & ROD FROM RHC-M PLUG BODY AT 10,134' SLM. PULLED RK-DGLV'S FROM STA'S 4 AT 5614' SLM & #5 AT 3188' SLM. SET GENERIC RK-LGLV IN STA# 5 & RK-OGLV IN STA# 4. PULLED RHC-M PLUG BODY FROM 10,137' SLM. TAG WI 3.5" CENT & S.B. AT 10,529' SLM. SAMPLE BAILER EMPTY. TAG W/2 7/8" DMY GUN & S.B. AT 10,529' SLM. WORK TO 10,531' SLM. SAMPLE OF WHAT APPEARS TO BE SAND & CEMENT. TAG WI 5' 2.25" DD BAILER AT 10,530 SLM. SAMPLE OF WHAT APPEARS TO BE SAND & DRILLING MUD. 02126/05 MIRU. SPOT UNIT AND SUPPORT EQUIPMENT, RIG UP HARD LINE. RIH WITH 3.0" JSN. TAGGED FILL AT 10548' CTMD. CLEAN OUT TO 10664' CTMD, HARD TD. CIRCULATE BOTTOMS UP WITH FLOPRO SWEEPS. CHANGE WELLBORE OVER TO DIESEL WHILE POOH AT 80%. RIG DOWN. SECURE WELL. NOTIFIED PAD OPERATOR OF WELL STATUS. JOB COMPLETE. 03/01/05 LOGGED RST SIGMA FROM 10605'-10200'. FIELD PICK GOC AT 10508'. TD TAGGED AT 10617'. JOB COMPLETE. 03/02105 PERFORATED INTERVAL 10538' - 10568' WITH 3-3/8" HSD, 6 SPF PJ HMX GUNS IN TWO RUNS. JOB COMPLETE. . . DEFINITIV Halliburton Sperry-Sun North Slope Alaska BPXA X-16A Job No. AKMW3454677, Surveyed: 30 December, 2004 Survey Report 17 January, 2005 Your Ref: API 500292068401 Surface Coordinates: 5940563.00 N, 666333.00 E (700 14' 37.7736" N, 148039' 23.2998" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 68. 60ft above Mean Sea Level Survey Ref: svy4473 spear"'r"'Y-su1'1 Jj.A;ILL.ING S EFtVIC:ES A Halliburton Company Halliburton Sperry-Sun Survey Report for X-16A Your Ref: API 500292068401 Job No. AKMW3454677, Surveyed: 30 December, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 8100.20 43,180 58.600 6990.42 7059.02 1230,54 N 2562.62 E 5941849.80 N 668867.84 E 2840.16 Tie On Point MWD Magnetic 8143.00 42,920 58.390 7021.70 7090.30 1245.81 N 2587,53 E 5941865,61 N 668892.41 E 0.694 2869,32 Window Point 8247.52 44.790 48.460 7097.16 7165.76 1288.94 N 2645.47 E 5941910.00 N 668949.39 E 6,816 2940.75 8342,50 44.500 44.400 7164,75 7233,35 1334.91 N 2693.81 E 5941957.04 N 668996.70 E 3.019 3005.05 8436.88 44.060 54.250 7232.40 7301.00 1377.77 N 2743.65 E 5942000.98 N 669045.58 E 7.297 3069.19 . 8487.81 44,330 55.080 7268.91 7337.51 1398.30 N 2772.61 E 5942022,15 N 669074.08 E 1.254 3104.41 8532,14 44.150 53.960 7300.67 7369.27 1416.25 N 2797.80 E 5942040.65 N 669098.86 E 1.809 3135,08 8628.50 43,710 50.610 7370.08 7438.68 1457.13N 2850.67 E 5942082.68 N 669150,82 E 2.455 3200.98 8724.24 42.880 54,580 7439.78 7508.38 1497,01 N 2902.79 E 5942123.70 N 669202.05 E 2.972 3265.74 8818.95 43.470 57.180 7508.85 7577.45 1533.35 N 2956.43 E 5942161.21 N 669254.88 E 1.979 3330.18 8914.80 43,710 59,690 7578.28 7646,88 1567.93 N 3012.74 E 5942197,03 N 669310.40 E 1.823 3396.13 9008.10 43.280 59,660 7645.96 7714.56 1600.36 N 3068,17 E 5942230,67 N 669365,11 E 0.461 3460.30 9101.92 42.530 58.300 7714.68 7783.28 1633.27 N 3122.90 E 5942264.78 N 669419.10 E 1.270 3524.09 9200.07 44.780 59.160 7785,69 7854,29 1668.42 N 3180.82E 5942301.21 N 669476.22 E 2,371 3591,73 9297,69 45.040 60,360 7854.83 7923.43 1703.13 N 3240,36 E 5942337.22 N 669534,98 E 0.908 3660.60 9393.24 46,170 61.380 7921,68 7990.28 1736.36 N 3299.99 E 5942371.76 N 669593.87 E 1.407 3728.86 9481.40 45.800 61.320 7982.93 8051,53 1766,76 N 3355.63 E 5942403,38 N 669648,83 E 0.423 3792,26 9586,98 45.400 61.460 8056.80 8125.40 1802.88 N 3421.86 E 5942440.95 N 669714.24 E 0.391 3867.69 9681.76 45,140 59,970 8123,51 8192.11 1835.81 N 3480.58 E 5942475.17 N 669772.22 E 1.150 3935.00 9777.79 44.250 60.420 8191.77 8260.37 1869,38 N 3539.19 E 5942510.03 N 669830,07 E 0.984 4002,51 9873,63 43.720 59.680 8260.73 8329,33 1902.61 N 3596.86 E 5942544.52 N 669887.00 E 0.770 4069.04 9966.47 43.090 59.320 8328.18 8396.78 1934.99 N 3651.83 E 5942578,10 N 669941.24 E 0.729 4132.78 . 1 0062.28 43.670 60,170 8397,82 8466.42 1968.14N 3708.67 E 5942612.50 N 669997.33 E 0.859 4198.53 10157.70 42.980 59.530 8467.23 8535,83 2001.02 N 3765.28 E 5942646.62 N 670053.21 E 0.857 4263.96 10249.15 42,030 58.440 8534,65 8603.25 2032.85 N 3818.24 E 5942679.62 N 670105.45 E 1.314 4325.67 10317.44 41.940 59.070 8585.41 8654,01 2056,55 N 3857.29 E 5942704,17 N 670143.97 E 0.631 4371.28 10356.11 40.070 59.440 8614,59 8683.19 2069.52 N 3879.10 E 5942717.62 N 670165.48 E 4,876 4396.62 10388.00 38.890 59.760 8639.21 8707.81 2079.78 N 3896.58 E 5942728,26 N 670182.74 E 3.755 4416,88 10416.93 37.260 61.010 8661.98 8730,58 2088.60 N 3912.09 E 5942737.42 N 670198,05 E 6,232 4434.72 10451,86 33,170 63,390 8690,51 8759.11 2098,01 N 3929,89 E 5942747,22 N 670215.64 E 12.349 4454.85 10483.62 29.310 66,350 8717,67 8786.27 2105.02 N 3944,79 E 5942754,56 N 670230.38 E 13.076 4471,29 10511,26 26.630 66.200 8742.07 8810.67 2110.24N 3956.66 E 5942760.04 N 670242.12 E 9,699 4484.22 10547.24 24.930 65,030 8774.47 8843,07 2116.69 N 3970.91 E 5942766,80 N 670256.23 E 4.932 4499.83 10575,94 22,070 59.680 8800.79 8869.39 2121.97N 3981.05 E 5942772,30 N 670266.25 E 12.423 4511.26 10608.21 18.540 52.970 8831.06 8899,66 2128.12 N 3990.38 E 5942778.66 N 670275.45 E 13.088 4522.39 17 January, 2005 - 14:51 Page 2 of 3 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for X-16A Your Ref: API 500292068401 Job No. AKMW3454677, Surveyed: 30 December, 2004 North Slope Alaska Measured True Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 10704.07 17.350 48.060 8922,26 8990.86 10766.00 17.350 48,060 8981.37 9049.97 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 2146.85 N 2159.20 N 4013.18 E 4026.92 E 5942797.89 N 5942810.54 N All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference, Northings and Eastings are relative to Well Reference, Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 61.900° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10766.00ft., The Bottom Hole Displacement is 4569.27ft., in the Direction of 61,800° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~) ~) Comment 8100.20 8143.00 10766,00 7059.02 7090.30 9049,97 1230.54 N 1245.81 N 2159.20 N Tie On Point Window Point Projected Survey 2562.62 E 2587.53 E 4026,92 E Survey tool proøram for X-16A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0,00 8100.20 0.00 7059,02 8100.20 10766,00 7059.02 BP High Accuracy Gyro - BOSS GYRO (X-16) 9049.97 MWD Magnetic (X-16A) 670297.83 E 670311.29 E BPXA Dogleg Vertical Rate Section (0/100ft) 2.007 4551.33 0,000 4569.26 Projected Survey Comment . . 17 January, 2005 - 14:51 Page 3 of 3 Dri/lQuest 3.03.06.008 TREE =' 4" CrN WELLHEAD: MCEVOY ACTUA TOR: OTIS KB. ELEV : 67,97' ,__,_,~_,_,_"_",,^,""""H_,^,,,,,_~_,_,,,=-.,,,_,,,,.=_·_,_,~,=,,, BF. ELEV : 39.47' KOP: Window 8143 Max Angle'" 48 @ 6500' Datum MD : DatumTVD: X-~A Actual ~NOTES: FROM DRLG - DRAFT 2102' 14-1/2" x NIP, 10: 3.813" 113-3/8" CSG, 72#, L-80, ID: 12.347" I GAS LIFT MANDRELS ST MD TVD DEV TYÆ VALVE LA TCH 5 3204 3200 5 4 1/2" X 1 1/2" MMG OCR RKP 4 5621 5308 40 4 1/2" X 1 1/2" MMG Dummy RK 3 7870 6890 43 4 1/2" X 1 1/2" MMG Dummy RK 2 9366 7970 46 41/2" X 1" KBG-2 Dummy BK 1 10017 8433 43 4 1/2" X 1" KBG-2 Dummy BK Minimum ID = 3.725" @ 10151' 4-1/2" HES "XN" NIPPLE 14 1/2" 12.6# 13Cr80 BTC-M (3.958" ID 17" 26# L-80 Drilling Liner (6,276" ID) H 7992' 1- 8143' H 95/8" Window I I I 3-IBP(01/19/04) TOP OF 7" LNR l-f 4-1/2" TBG, 12,6#, L-80, 0,0152 bpf, ID - 3,958" -f I 9-5/8" CSG. 47#. L-80, ID = 8.681" 1-1 9676' 9706' 10191' 10775' H3-3/8" HSD PERF GUN - 06/06/90 I l.!:ê:æJ-- 10952' I 7" LNR, 26#, L-80, 0,0383 bpI, ID = 6.276" 1-1 10995' 1 IPBTD H 10,679' I 14 1/2" 12,6# 13Cr80 Liner TD H 10,766' DA TE REV BY 05/09/82 06/09/04 JDM/KA 12/05/04 PGS 01/02/05 AM COMMENTS ORIGINAL COM PLETION SUSPENDED RWO PROPOSED SIDETRACK w p-O Actual sidetrack/completion DATE REV BY COMMENTS PRUDHOE BAY UNrT WELL: X-16A PERMrT No: XXXXXX API No: 50-029-20684-01 SEC 5, T10N, R14E, 461' FSL & 461' FWL BP Exploration (Alas ka) . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well X-16A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,100.20' MD 8,143.00' MD 10,766.00' MD (if applicable) 24-Jan-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ Fh )J-~ f Signed /,.;;.7/ J (J/U /~! }-w J:JJ'1/ ! Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachmen!(s) :z rJ<{ - ~ L(e¡ . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well X-16A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,100.20' MD 8,143.00' MD 10,766.00' MD . (if applicable) 18-Jan-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ;¿?~,) fYJeIJJU£ Signed ,,) / ,A " ( /// ¡.' j , lj-t~\~~/ , . AÚ, "I I 1 Î' UA It I ,-d Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ;z tJL( ~ }-.If L( · ~1r~1rŒ (ID~ ~~~~æ~ -- AI,ASIiA OIL A1Q) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay X-16A BP Exploration (Alaska) Inc. Permit No: 204-244 Surface Location: 423' NSL, 461' EWL, SEC. 05, TI0N, RI4E, UM Bottomhole Location: 2557' NSL, 4478' EWL, SEC. 05, TI0N, RI4E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission t witness any required test. Contact the Commission's petroleum field inspector at (907) 659 60 (pager). el DATED this 1:- day of December, 2004 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .. \¡.JG I\- i l/7/Z001 . STATE OF ALASKA . RECEIVeD ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL DEC oS 2004 20 MC 25.005~ska Oil & Gas Cons. Conwnission 1a. Type of work o Drill II Redrill r b. Current Well Class o Exploratory II Development1!tl::hcØlltiPle Zone ORe-Entry o Stratigraphic Test o Service o Developmen as Ingle Zone 2. Operator Name: 5. Bond: 1m Blanket o Single Well 11, Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU X-16A ./ 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 10767 TVD 9054 Prudhoe Bay Field I Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: / ADL 028313 423' NSL, 461' EWL, SEC. 05, T10N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2481' NSL, 4335' EWL, SEC. 05, T10N, R14E, UM December 16, 2004 / Total Depth: / 9. Acres in Property: 14. Distance to Nearest Property: 2557' NSL, 4478' EWL, SEC. 05, T10N, R14E, UM 2560 18,465 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 666333 y- 5940563 Zone- ASP4 (Height above GL): Plan 68 feet X-03A is 1,159' away 16. Deviated Wells: Kickoff Depth: 8100 feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.0?y Maximum Hole Angle: 44 degrees Downhole: 3250 Surface: 2370 1~..~a$ingF'rogram: Sètting[)t)þth , ",' iii>i Size ,....,. Top ..., '.'. ...>···....···.·..·".<Bottom ···········lc.t'·' Hole Casina Weiaht Grade Couplina Lenath MD TVD MD TVD (includin staa e data) 8-1/2" 7" 26# L-80 BTC-M 2376' 7950' 6950' 1 0326' 8658' 281 cu ft Class 'G' 6-1/8" 4-1/2" 12.6# 13Cr80 VAM Top 591' 10176' 8551' 10767' 9054' 107 cu ft Class 'G' 19. PRESENTWEI..L CONDITIONSlIMMARY (To be COO1pletadf()r.RêdtiIIAI'JPRe~eotrY.Qper'åtiol1$) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 11010 9273 8182 & 10110 8182 7119 10775 ii. >.">?> i·J,:¡~íig;!¡tI 'i .. >·y\Sigliíiiiii:.. "i< ii ii?: :::i:i:M~ i x: li¥q·: Structural Conductor 110' 20" x 30" 8 cu vds Concrete 110' 110' 2689' 13-3/8" 3460 cu ft Arcticset /I 2689' 2689' IntArmArli;:¡tA 10191 ' 9-5/8" 1450 cu ft Class 'G', 130 cu ft AS I 10191' 8631' Production Liner 1319' 7" 335 cu ft Class 'G' 9676' - 10995' 8253' - 9261' Perforation Depth MD (ft): All Below IBP & Cement IPerfOration Depth TVD (ft): All Below IBP & Cement 20. Attachments 1m Filing Fee, $100 o BOP Sketch 1m Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 1m Drilling Fluid Program 1m 20 MC 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 Phil Smith, 564-4897 Printed Name Bill Isaacson Title Senior Drilling Engineer L ~Jl. L\- 11./&/0'1 Prepared By Name/Number: Signature Phone 564-5521 Date Terrie Hubble, 564-4628 ii. :i X >i "'>:i .··y..~nl~ :: I ii::i. i,,:.,..i >,"'i ',..X::?i... :i >i> Permit To Drill . ÇlJ API Number: Permit AP~~A I See cover letter for Number: 2cJQ- Z 50- 029-20684-01-00 Date: / :'. of;/' other requirements Conditions of Approval: Samples Required D Yes ~No Mud Log Required ~es ~o . ~ Sulfide Mea,","" prves lJ No Directional Survey Required es D No Other: T€~t- P,;;,O¡)f' C;L')O ¡I).sf. ~proJed. p<,'W~o [J Uj I "-(~."n~f" ßOJf I':. (~~ ¡ r\ ¡ A L APPROVED BY Date 1v/1í tJcf Aooroved Bf .11 U I I \I THE COMMISSION Form 10-401 ~ed' &4 - Sóbmit(n DuplIcate · . ¡Well Name: IX-16A Drill and Complete Plan Summary 1 Type of Well (service I producer I injector): I Horizontal Sidetrack Producer /' Surface Location: X = 666,333 Y = 5,940,563 Estimated 424'FSL 460' FWL Sec. 5, T10N, R14E Umiat Target Location: X = 670,154.0 Y = 5,942,706, TVDss 8589' Ivishak Zone 4A 2798' FNL 945' FEL Sec. 5, T10N, R14E Umiat Bottom Hole Location: X = 670,295.0 Y = 5,942,786.0 TVDss 8986' 2722' FNL 802' FEL Sec. 5, T10N, R14E Umiat 1 AFE Number: 1 PBD4P2285 I I Estimated Start Date: 112/16/04 / I Rig: I Nabors 9ES / 1 Operating days to complete: 115.0 [M[] 10,767' I 1 TVD: 19054' I @0 39.5' 1 I KB: 128.5' I I KBE: 168.0' 1 Well Design (conventional, slim hole, etc.): J Two String Horizontal Sidetrack I Objective: 1 Ivishak Zone 4A Formation Markers Formation Tops (wp08) MD TVD TVDss Comments CM3 6153 -6085 ABOVE KICKOFF CM2 (Geo unit for KOP) 6671 -6603 " CM1 8640 7450 -7382 THRZ 8987 7699 -7631 BHRZ 9220 7866 -7798 JKU 9240 7880 -7812 T JF** Absent TJE 9349 7958 -7890 T JD** 9843 8312 -8244 TJC 9850 8317 -8249 TJB 10,057 8465 -8397 TJA 10,187 8558 -8490 TSGR 10,326 8658 -8590 TSHU 10,364 8686 -8618 TSAD 10,448 8756 -8688 PGOC 10,547 8848 -8780 3250 PSI @ 8800' TVD = 7.1 ppg EMW Z4A 10,589 8888 -8820 Z3 10,661 8958 -8890 TD 8640 7450 -7382 TD Criteria: Unless Z4a is wet, drill to planned -8913 TVDSS. This will allow PBTD to be at -8900 TVDSS (top Z3). If top of Z4a is wet, well will be TD'd early. 11, V -it X-16A Permit to Drill Page 1 . Directional - Anadrill wp09 . KOP: 18100' MD Maximum Hole Angle: _430 in the 8-1/2" intermediate section (from KOP to section TD) _440 in the 6-1/8" section (at 7" shoe, droppinQ to 140 throuQh reservoir) Close Approach Wells: All wells pass major risk criteria for this well plan. The nearest well is 1119' ctr-ctr with 28' allowable deviation. Survey Program: MWD Standard Nearest Property Line: 18,465' to the nearest PBU property line Nearest Well within Pool: X-03A at 1159' center to center at planned TD. ram WtlFt Grade Conn Length Top Btm / / MD/TVD MD/TVD 8-1/2" 7" 26# L-80 BTC-M 2376' 7950'/6950' 10,326'/8,658' /' 6-1/8" 4-1/2" 12.6# 13Cr-80 V AM To 591' 10,176'/8551 ' 10,767/9054' Tubin 4-1/2" 12.6# 13Cr-80 V AM To -10,140' GL 10,176'/8551 ' FloPro YP 25-35 APIFI 9-9.5 Lo ram 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GR Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - over entire interval, samples described Drilling: Dir/GRlRes/Neu/Den Open Hole: None Cased Hole: None Cement Pro ram Casin Size 7" 26#, L-80 Intermediate Liner Basis: Lead: None Tail: Based on 80' sh~track and 1000' of 7" X 8-1/2" open hole with 40% excess. Tail TOC: 9326' MD, Total Cement Volume: Tail 50 bbls, 281 ft3, 42 acks Class G @ 15.8 ppg, 1 1 3/sack X-16A Permit to Drill Page 2 . . Size 4.5" 12.6#, L-80 Production Liner Lead: None Tail: Based on 80' shoe track, 440' of 4-1/2" X 6-1/8" open hole with 40% excess, 150' 4-1/2" X 7" Liner Lap, and 200' of 7" X 4" DP exceJS. Tail TOC: 10,176' MD (Top of Liner) \ Total Cement Volume: Tail 19 bbls, 107 ft ,9 sacks Class G @ 15.8 ppg, .1 t3/sack Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP Maximum surface ressure Kick tolerance Planned BOP test pressure Production Interval Maximum antici ated BHP Maximum surface ressure Kick tolerance Planned BOP test pressure ¥- Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilli g operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the No h Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for dispo al. Historv X-16 expense RWO preparation work included a tempo ary cement plug across the perforated producing interval. The cement was to stop any fluid losses and t help in repairing the damaged 7" production liner. The cement plug was tested to 2000 psi prior to the RW . While retrieving the 4-1/2" tubing during the RWO, cem nt and fill was found around the tubing and GLM. After numerous attempts to recover the tubing and GLM down to the packer top, operations were suspended until this rig side track could be performed. X-16A Permit to Drill Page 3 . . Sidetrack and Complete Procedure Summary Current Condition: ,/ Well P&A'd with cement top at 10,100' in liner and tested to 2000 psi 05109104 ,/ Drifted tubing with 2.25" bailer to 9048'. Found cement stringers as high as 7300'. 5111104 ,/ CTV clean out to 10,110' with 3.8" mill 5115104 ,/ Attempted tubing jet cut at 9542' after cleaning out the stringers 5118104 ,/ Tubing hanger screws cycled and 9 518" packoff tested to 4000 psi. 5123104 ,/ RWO could not fish tubing below 8204' due to extensive cement in the tubing x casing annulus. June 2004. Left well with: o Cast iron bridge plug set at 8182' and tested to 2000 psi. o 2 718" kill string in tubing hanger down to 8138' o Freeze protected with 135 bbls diesel, V-tubed, installed BPV Scope Pre-RiQ Work: 1. Check IA and OA casing pressures and bleed to zero if necessary. 2. Remove well house if re-installed after June workover. 3. Level the pad as necessary. 4. Confirm the BPV has not been pulled from the tubing hanger and report well condition on the handover form to the 9ES rig supervisor. Ria Operations: 1. MI I RU Nabors rig 9ES. Pull BPV. 2. Circulate out diesel freeze protection and displace e, ell to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to OOpsi. Pull TWC. 4. R/U. Pull 2 7/8" kill string from the well. // 5. RIH wi 8112" gauge ring I junk basket to CIBP. 6. Pressure-test the 9 5/8" casin to 3,500 si for 30 minutes. Record test. 7. P and RIH with 95/8" Baker bottom-trip anchor whip stock assembly. and set on bridge plug. Shear off of whip stock. 8. Displace the well to 11.0 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 9. Mill window in 9 5/8" casing at ± 8,100' MD, plus approximately 20' beyond middle of window. /" Circulate well bore clean. 10. Pull up into 9 5/8" casing and conduct an FIT to 12.5 ppg EMW. POOH. 11. M/U 8 112" Dir/GR drilling assembly. RIH, kick off and drill the 8 1/2" intermediate section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. 12. Run and cement a 7",26.0#, L-80 iæt diate drilling liner. /'''~ 13. Test the 9 5/8" casing X 7" liner to , 0 si for 30 minutes. Record the test. 14. M/U 6 1/8" Dir/GR/Neu/Den/Res as mbly. RIH to the landing collar. 15. Drill out the 7" liner float equipment and cement to the shoe. 16. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 17. Drill out the 7" shoe plus drill -20' new formation; pull up into the shoe and conduct an FIT to 10.0ppg EMW. Drill ahead to planned TD. 18. Circulate, short trip, spot liner running pill, drop ESS, POOH. 19. Run and cement a 4 W, 12.6#, 13Cr-80 solid production liner. POOH UD all drill pipe. / 20. R/U and run 41/2",12.6#, 13Cr-80 completion tubing. Land the tubing RILDS. 21. Set a TWC and test to 1000 psi 22. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. 23. Reverse circulate inhibited seawater to the packer depth. Set packer and individually test the tubing and annulus to 3,500psi 30 minutes. Record each test. Tlt S 10 ,- 4î..?j a,ppltlJt:L t. Orient whip stock, as desired, ' / X-16A Permit to Drill Page 4 . . 24. Shear the DCK valve and freeze protect the well to -2,100'. Secure the well. 25. Rig down and move off. Post-RiQ Work: 1. Install well house and instrumentation 2. MI / RU slick-line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 3. Perforate as per X-Pad production engineer. X-16A Drilling Program Job 1: MIRU Hazards and Contingencies Þ- X-16 is positioned on the end of the well row, closest to the NE entrance to the pad. The closest well, NK-17, is on 110' center to the west. No well houses will require removal or shut-in for the rig move onto X-16. Þ- DS1&designated as an H2S site review the H2S SOP and prepare an H2S contingency * planCftr'the rig. Ensure all proper H2S detection equipment is in place and all visitors to the site wear H2S monitors. Recent H2S data from the pad is as follows: #1 Closest SHL #2 Closest SHL #1 Closest BHL #2 Closest BHL Well Name X-17 X-18 X-15A X-02 The maximum on the pad is X-OS at 150 ppm measured 12/01/01./ ~ Post Permit to Drill in the dog house and camp prior to spud ~ POST H2S Contingency plan in the doghouse as per SOP. Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP .:. "Hydrogen Sulfide" SOP Job 2: De-complete Well Hazards and Contingencies Þ- Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP Job 4: Window Mill Hazards and Contingencies Þ- Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP X-16A Permit to Drill Page 5 . . Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies » The intermediate section will kick off in the Colville CM2 and TD at the top of Sag River. Since X- 16A will kick off and maintain ±44° inclination, 11.0 ppg mud weight will be adequate to maintain wellbore stability though the Kingak shale to interval TD. Follow all shale drilling practices to minimize potential problems. » Zonation in the Kingak (T JA-F) is problematic and is incorrect. Current zonation, with the absence of T JF, implies faulting but when the full Kingak section is compared with nearby wells, faulting of any significance can be ruled out. X-16's Kingak section is 700' TVD (1000' MD). For comparison, nearby X-17 has a Kingak thickness of 795', X-07 has 796', X-15 has 778', X-02 logged 767' and X-04's Kingak is 827' thick. Three miles to the NW, well A-01 has a Kingak thickness of 770'. This comparison suggests only minimal faulting at X-16 in the Kingak, if any at all. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. » KICK TOLERANCE: In the worst-case scenario of 8.4 ppg pore pressure at the Sag River depth, a fracture gradient oL.,1~ ppg at the 9-5/8" casing window, and 11.5 ppg mud in the hole, the kick tolerance is irfini~~ \.:::::/ Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" Job 6: Install 7" Intermediate Liner Hazards and Contingencies » Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. » Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies » Plan for a single bit run in this interval and prepare to drop an ESS prior to POH. If zone 3 chert results in a bit trip requirement, change out MWD and do not drop the ESS. » KICK TOLERANC· In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a fracture gradie of .5 ppg at the 7" casing shoe, and 8.5 ppg mud in the hole, the kick tolerance is In Ini\liY." cY' X-16A Permit to Drill Page 6 . . Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies );> Differential sticking is a concern. The 8.5 ppg mud will be -650psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. );> Reduce losses as much as feasible prior to cement job and pump excess cement as per loss rate. Evaluate alternative cement options based upon conditions. Hydraulic set packer may be required if losses exist prior to running liner. );> Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" .:. "Use of 13-Cr Tubulars" .:. "Running and Handling 13-Cr" .:. Schlumberger Cement Program Job 12: Run Completion Hazards and Contingencies );> Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP .:. "Use of 13-Cr Tubulars" .:. "Running and Handling 13-Cr" Job 13: ND/NUlRelease Ria Hazards and Contingencies );> No wells will require well house removal or shut-in for the rig move off of X-16A. See MIRU section for nearest well. Reference RP .:. "Freeze Protecting an Inner Annulus" RP X-16A Permit to Drill Page 7 TRÈE = WELLHEA D = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lV D = . X -1 6 / ~FEfY Nom, 4"CIW MCEVOY OTIS 67,97' 39.4 7' 48 @ 6500' 8182' 7132' SS 13-3/8" CSG, 72#, L-80, ID = 12,347" I I 2-7/8",6.5#,L-80,EUE8rdKILLSTRING I 8138' 14-1/2" X 3-112" XO, 10 = 2,867" I 3-1/2" X 2-7/8" XO, 10 = 2.347" 2580' 19-5/8" DV PKR I Minimum ID = 3.80" @ 9672' 4-1/2" OTIS XN NIPPLE I TOP OF 7" LNR I 4-1/2" TBG, 12.6#, L-80, 0,0152 bpf. 10 = 3.958" I 9-5/8" CSG, 47#, L-80, ID = 8.681" I PERFORATION SUMMARY REF LOG: BHCS ON 05/05/82 ANGLE AT TOP PERF: 40 @ 10428' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2-7/8" 4 10428 - 10503 S 06/03/90 3-3/8" 4 10473 - 10503 S 05/09/04 3-3/8" 4 10503 - 10518 S 05/09/04 3-3/8" 4 10528 - 10545 S 05/09/04 3-3/8" 4 10555 - 10575 S 05/09/04 3-3/8" 4 10585 - 10610 S 06/03/90 I PBTD I 10952' 7" LNR, 26#, L-80, 0.0383 bpf, 10= 6.276" 10995' DA TE REV BY COMMENTS 05/09/82 ORIGINAL COM PLETION 06/09/04 JDM/KA SUSPENDED RWO 07113/02 JClKAK CORRECTIONS 01/19/04 CAO/KK SET IBP 05109/04 JAF/KAK P & A 05/16/04 JAF/KAK MILL XN NIP DA TE REV BY COMMENTS 9515' ~4-1/2" SLIDING SLEEVE, ID = 3,812" I 9568' 4-1/2" BAKER PBR SEAL ASSY 9585' 3" IBP(01/19/04) 9588' 9-5/8" x 4-1/2" BOT, PKR, ID = 3.813" 9642' 4-1/2" OTIS X NIP, ID = 3.813" 9672' 4-1/2" OTIS XN, NIP, MILLED 10 = 3.80" 9706' 14-1/2" TBG TAIL, ID = 3.958" I 9696' H ELMDTTDATENOT AVAILABLE I 10501' -1 MARKER JOINT I 10775' 13-3/8" HSD PERF GUN - 06/06/90 I PRUDHOE SA Y UNrr WELL: X-16 ÆRMrr No: "1811720 API No: 50-029-20684-00 SEC5, T10N, R14E SP Exploration (Alaska) x~ 6A Proposed .AfETYNOTES, TREE = WELLHEAD = A CTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TV D = 4" CrN MCEVOY OTIS 67,91' 39.4 l' 8100' 53 @ 10,325' 10764' 8981' SS 113-3/8" CSG, 72#, L-80, ID = 12,347" I Minimum ID = 3.725" @ ##' 4-1/2" OTIS XN NIPPLE 141/2" 12,6# 13080 BTG-M (3,958" 10 IT' 26# L-80 Drilling Liner (6.276" ID) H 7940' 1- 3" IBP (01/19/04) TOP OF 7" LNR 1-; 9676' 4-1/2" TBG, 12.6#, L-80, 0,0152 bpI, ID = 3.958" -; 9706' I 9-S/8"CSG,47#.L-80,ID=8,681" 1-1 10191' 10775' H 3-3/8" HSO ÆRF GUN - 06106/90 I ~-; 10952' I 7" LNR, 26#. L-80, 0,0383 bpI, ID = 6.276" 1-1 10995' I DA TE REV BY 05/09/82 06/09/04 JDM/KA 12105/04 PGS COMMENTS ORIGINAL COMPLETION SUSPENDED RWO PROPOSED SIDETRACK w p-O 2100' -l4-1/2" X NIP, 10=3,813" PORT OA TE ST MO TVO 4 3202 3200 3 5610 5300 2 7951 6950 1 9448 8080 4.5" x 1,5" 4,5" x 1,5" 4.5" x 1,5" 8100' H9 5/8" Window /10,116' H41/2"XNipple(3.813"ID) I I 10,131' H 7" x 4 1/2" Baker S-3 Packer I I 10,151' H41/2"XNiPPle(3.813"ID) I I 10,166' 1-/41/2" XN Nipple (3.725" 'D) I I 10,180' H41/2"WLEG I I 1 0,17 5' l-t 4 1/2" Hanger I liner top packer I I 10,325' H 7" 26# L-80 (6.276" 10) 0,383 bpf I /' PBID 141/2" 12.6# 13Cr80 Liner ID 10,687' 10,767' DATE REV BY COMMENTS PRUDHOE BAY UNrr WELL: X-16A ÆRMrr No:ltoooo< API No: 50-029-20684-01 SEC 5, T10N, R14E, 461' FSL & 461' FWL BP Exploration (Alaska) X-16A (P9) Proposal Schlumberger Report Date: Client: Field: Structure 1 Slot: Well: Borehole: UWIIAPI#: Survey Name 1 Date: Tort I AHD I DDII ERD ralio: Grid Coordinate System: Location LallLong: Location Grid HIE YIX: Grid Convergence Angle: Grid Scale Factor: December 2, 2004 BP Exploration Alsaska Prudhoe Bay Unit - WOA S udY X-PAD/X-16 -blllty ~;~~ X-16A Feasl 500292068401 X-16A (P9) 1 December 2, 2004 114.818' 14624.43 ft 15.800 1 0,511 NAD27 Alaska State Planes, Zone 04, US Feet N 70,24382599, W 148.65647216 N 5940563,000 ftUS, E 666333,000 ftUS +1.26447379' 0,99993143 Survey 1 DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed 1 Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Totel CO" Mag North -> True North: Local Coordinates Referenced To: Minimum Curvature 1 Lubinski 57,950' N 0.000 ft, E 0.000 ft Rotary Table 67.97 ft relative to MSL 39.47 ft relative to MSL 24.935' 57622.717 nT 80.815' December 25, 2004 BGGM 2004 True North +24.935' Well Head . Comments Tie-In Survey Top Whipstock Base Whipstock KOP Cry 4/100 End Cry 8221.37 43.70 50.41 7078,82 7146.79 2908.58 2982.48 1279.85 2630,31 4,00 O.OOG 0.45 -5.76 5941900.63 668934.62 N 70.24732158 W 148.63522322 Cry 4/100 8596.46 43.70 50.41 7350.00 7417.97 3165.47 3241.62 1445.00 2830.00 0.00 88.57G 0.00 0.00 5942070.13 669130.61 N 70.24777255 W 148.63360973 8600.00 43.70 50.61 7352.56 7420.53 3168.30 3244.07 1446.69 2832.28 4,00 88.42G 0.10 5.79 5942071.73 669132.47 N 70.24777680 W 148.63359447 GM1 8640.74 43.77 52.97 7382.00 7449.97 3195.90 3272.23 1463.98 2854.02 4.00 86.72G 0.17 5.78 5942089.63 669154.20 N 70.24782436 W 148.63341566 8700.00 43.96 56.38 7424.73 7492,70 3237.28 3313.29 1487.84 2887.90 4.00 84.26G 0.31 5.75 5942114.10 669187.16 N 70,24788917 W 148.63314504 End Cry 8760.97 44.25 59.86 7468.52 7536.49 3279.30 3355.72 1510.11 2923.54 4.00 O.OOG 0.49 5.70 5942137.29 669222,68 N 70.24795033 W 148.632_ Top HRZ 8987.83 44.25 59.86 7631.00 7698.97 3437.53 3514.03 1589.61 3060.44 0.00 O.OOG 0.00 0.00 5942219.78 669357.79 N 70.24816736 W 148.6317 Base HRZ 9220.99 44.25 59.86 7798.00 7865.97 3600.15 3676.74 1671.31 3201.15 0.00 O.OOG 0.00 0.00 5942304.56 669496.65 N 70.24839040 W 148.63061097 JKU 9240,53 44.25 59.86 7812.00 7879,97 3613.78 3690.38 1678.16 3212.95 0.00 O.OOG 0,00 0.00 5942311.67 669508.30 N 70.24840910 W 148.63051566 Kingak IT JE 9349.43 44.25 59.86 7890.00 7957.97 3689.73 3766.38 1716.32 3278.67 0.00 O.OOG 0.00 0.00 5942351.27 669573.15 N 70.24851328 W 148,62998465 TJD 9843,68 44.25 59.86 8244.00 8311,97 4034.45 4111.28 1889.51 3576.94 0.00 O.OOG 0.00 0.00 5942530.99 669867.51 N 70.24898606 W 148.62757461 TJG 9850.66 44.25 59.86 8249.00 8316.97 4039.32 4116.16 1891.96 3581.16 0.00 O,OOG 0.00 0.00 5942533.53 669871.67 N 70.24899273 W 148.62754057 TJB 10057.29 44.25 59,86 8397,00 8464.97 4183.44 4260.36 1964.37 3705.86 0.00 O.OOG 0,00 0.00 5942608.66 669994.73 N 70.24919038 W 148.62653295 TJA 10187,14 44.25 59.86 8490.00 8557.97 4274.00 4350.97 2009.87 3784.22 0.00 O.OOG 0.00 0.00 5942655.88 670072.06 N 70.24931458 W 148.62589977 10305.16 44.25 59.86 8574.53 8642,50 4356.32 4433.33 2051,36 3855,83 0.00 -48.10G 0.00 0.00 5942698.79 670142,36 N 70.24942747 W 148.62532422 10305.36 44,26 59.85 8574,68 8642.65 4356.46 4433.47 2051.42 3855.95 4.00 O.OOG 2,67 -4.27 5942698.87 670142.47 N 70,24942766 W 148,62532326 X-16A Tgt 1 Sag 10325.36 44.26 59,85 8589.00 8656,97 4370.41 4447.43 2058.30 3867.63 0.00 O.OOG 0.00 0.00 5942706.00 670154.00 N 70.24944679 W 148.62522573 Sag River 10326.74 44.26 59.85 8589.99 8657.96 4371.37 4448.39 2058.79 3868.47 0.00 O.OOG 0.00 0.00 5942706.64 670155.21 N 70.24944811 W 148.62521898 7" Gsg PI 10326,76 44.26 59.85 8590.00 8657.97 4371.38 4448.40 2058.79 3868.48 0.00 O.OOG 0.00 0.00 5942706.65 670155.22 N 70.24944813 W 148.62521892 Drp 13/100 10345.36 44.26 59.85 8603.32 8671.29 4384.36 4461.39 2065.31 3879.70 0.00 180.00G 0.00 0.00 5942713.41 670166.30 N 70,24946593 W 148.62512819 WellDesign Ver 3.1 RT -SP3.03-HF5.00 Bld( do31 rt-546 ) X-161X-16\Plan X-16AIX-16A (P9) Generated 12/2/2004 4:02 PM Page 1 of 2 Comments Latitude Longüude N 70.24948466 W 148.62503271 N 70.24951474 W 148.62487933 Sadlerochit N 70.24955440 W 148.62467705 N 70,24958443 W 148.62452370 PGOC N 70.24961002 W 148,62439293 End Orp 10565.71 15.61 59.96 8792,29 8860.26 4493,12 4570.21 2119.92 3973.84 13.00 O,OOG -13.00 0.13 5942770.08 670259.20 N 70.24961498 W 148.62436754 X-16A Tgt 2 (Poly) 10573.71 15.61 59.96 8800.00 8867.97 4495.27 4572.36 2121.00 3975.70 0.00 O.OOG 0.00 0.00 5942771.20 670261.04 N 70.24961792 W 148,62435248 Top Z4A 10594.48 15.61 59.96 8820,00 8887.97 4500.86 4577.95 2123.80 3980.54 0.00 O.OOG 0.00 0.00 5942774,10 670265.81 N 70.24962556 W 148.62431338 10667.16 15.61 59,96 8890.00 8957.97 4520.41 4597,52 2133.59 3997.47 0.00 O.OOG 0.00 0.00 5942784.27 670282.52 N 70.24965228 W 148.6241. Top Z3 10667.17 15.61 59.96 8890.01 8957.98 4520.41 4597.52 2133.59 3997.48 0.00 O,OOG 0.00 0.00 5942784.27 670282.53 N 70.24965229 W 148.6241 TO /4-112" Lnr 10767,16 15.61 59.96 8986.31 9054,28 4547.31 4624.43 2147.06 4020.77 0.00 O.OOG 0.00 0.00 5942798.25 670305.52 N 70.24968906 W 148.62398824 Leaal Description: Surface 424 FSL 4820 FEL S5 T10N R14E UM Tie-In 424 FSL 4819 FEL S5 nON R14E UM X-16A Tgt 1 Sag 2481 FSL 944 FEL S5 nON R14E UM BHL 2570 FSL 791 FEL 55 nON R14E UM NorthinG (Y) IftUSI 5940563.00 5940563.14 5942706.00 5942798.25 Eastlnll (XI IftUSI 666333.00 666333.39 670154.00 670305.52 . WellOesign Ver 3. 1 RT-SP3.03-HF5.00 Bld( do31rt-546 ) X-16IX-16\Plan X-16AIX-16A (P9) Generated 12/2/2004 4:02 PM Page 2 of 2 6800 7200 7600 FS Deœmb!!r25,2004 576Z0nT TVORa!: Bay -WOA STRUCTURE X-PAD NAD27 Alaskð $ìaoo P!¡¡nes, Zona 04, us Foot Nor\l1ír¡g 594Q56J.OOtìU$ Grj(Cru\V: +1.26447379· Eal1til1g; 600333.00fìUS Scale-Fact: 0.9$99314292 Miscellaneous Skit· X-II> Plan X-16A(PS) 2400 2800 3600 4000 4400 6800 7200 7600 £ Õ 0 ::t: g 8000 8000 ~ II (J) ~ (j) 0 ¡::: 8400 8400 8800 9200 8800 9200 X-16 2400 2800 3600 4000 4400 Vertical Section (ft) Azim "57,95", Scale" 1(in):400(ft) Origin" 0 N/-S, 0 E/-W X-16A (P9) STRunURE X-PAD NAD27 ßGGM2004 Djp 80$15" Oat;) Oecembm25.2004 Mag Dee +24.9350 fS 57622.7r1T 2400 2700 3000 mo 1437.774 W148392:L300 Northing Eas~r19 666333.00 JlUS Slot' X-i6 Plan X-16A(P9) TVOREf.: SrvyDate 3300 3600 3900 4200 4500 1200 2400 2400 2100 2100 ^ ^ ^ z iE' Õ <::> 1800 1800 ~ ~ ~ II (1) ro () CI) CI) V 1500 1500 V V 1200 2400 2700 3000 3300 3600 «< W Scale = 1 (in}:300(ft) E 3900 4200 4500 . . BP Alaska Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 8100.00 to 10767.16 ft Maximum Radius: 10000.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 12/2/2004 Validated: No Planned From To Survey ft ft 99,57 7999.57 7999.57 9400.00 7999,57 10767.16 Version: Toolcode 9 Tool Name Survey #1 Boss Gyro (99.57-10999.57) (0) BOSS-GYRO Planned: Plan #9 V2 MWD Planned: Plan #9 V2 MWD+IFR+MS Sperry-Sun BOSS gyro multishot MWD - Standard MWD + IFR + Multi Station Casing Points 2688.43 2687.89 13.375 17.500 13 3/8" 8100,00 7058.71 9.625 12.250 95/8" 10326,75 8657.97 7.000 8.500 7" 10764,21 9051 .44 4.500 6.125 41/2" Summary PB X Pad Plan X-37 Plan X-37 VO Plan: X-3 Out of range PB X Pad X-01 Plan X-01a V1 Plan: X- Out of range PB X Pad X-01 X-01 V1 8115.52 9600.00 3587.48 128.90 3458.59 Pass: Major Risk PB X Pad X-02 X-02 V1 8126.49 8550.00 1267.84 640,70 627.14 Pass: Major Risk PB X Pad X-03A X-03A V11 10606.34 11850.00 1142.231107,02 35.21 Pass: Major Risk PB X Pad X-03 X-03 V1 8229.10 8800.00 1466.191108.99 357.19 Pass: Major Risk PB X Pad X-04 X-04 V1 Out of range PB X Pad X-05 X-05 V1 Out of range PB X Pad X-06 X-06 V1 Out of range PB X Pad X-07 X-07 V1 8100.00 9850.00 3836.57 750.39 3086.18 Pass: Major Risk PB X Pad X-08 X-08 V3 8100.00 10200.00 4494.11 646.91 3847.20 Pass: Major Risk PB X Pad X-08 X-08A V4 8768.64 11691.00 3085.99 316.29 2769.70 Pass: Major Risk PB X Pad X-09 X-09 V9 Out of range PB X Pad X-09 X-09B V23 Out of range PB X Pad X-09 X-09L 1 V4 Out of range PB X Pad X-10 X-10 V1 Out of range PB X Pad X-11A X-11A V1 Out of range PB X Pad X-11 X-11 V1 Out of range PB X Pad X-12 X-12 V1 Out of range PB X Pad X-13A X-13A V1 Out of range PB X Pad X-13 X-13 V1 Out of range PB X Pad X-14A X-14A V1 Out of range PB X Pad X-14 X-14 V2 Out of range PB X Pad X-15 X-15 V2 8108.96 8350.00 1337.04 597.33 739.72 Pass: Major Risk PB X Pad X-15 X-15A V3 9771,67 11344,00 1002.56 458.97 543.59 Pass: Major Risk PB X Pad X-16 X-16 V4 10675,56 10650.00 238.241193.75 -955.51 FAIL: Major Risk PB X Pad X-17 X-17 V1 8271.48 8800.00 2885.81 703.97 2181.84 Pass: Major Risk PB X Pad X-18 X-18 V1 Out of range PB X Pad X-19A X-19A V1 Out of range PB X Pad X-19BL 1 X-19BL 1 V11 Out of range PB X Pad X-19BPB1 X-19BPB1 V2 Out of range PB X Pad X-19B X-19B V5 Out of range PB X Pad X-19 X-19 V1 Out of range PB X Pad X-20 Plan #101 X-20Ai VO PI Out of range PB X Pad X-20 X-20 V1 Out of range PB X Pad X-20 X-20PB1 V3 Out of range PB X Pad X-21APB1 X-21APB1 V1 Out of range PB X Pad X-21A X-21A V1 Out of range PB X Pad X-21 X-21 V1 8100.00 9500.00 3593.62 330.55 3263.08 Pass: Major Risk PB X Pad X-22 X-22 V1 Out of range . . BP Alaska Anticollision Report PB X Pad X-22 X-22A V2 Out of range PB X Pad X-22 X-22PB 1 V2 Out of range PB X Pad X-23 X-23 V1 Out of range PB X Pad X-24A X-24A V1 8511.76 9850.00 2497.98 360.74 2137.24 Pass: Major Risk PB X Pad X-24 X-24 V1 8247.58 9300.00 2900.31 389.48 2510.83 Pass: Major Risk PB X Pad X-25 X-25 V1 Out of range PB X Pad X-26 X-26 V1 Out of range PB X Pad X-27 X-27 V1 8333.49 9400.00 4907.111082.59 3824.53 Pass: Major Risk PB X Pad X-28 X-28 V1 Out of range PB X Pad X-29 X-29 V1 Out of range PB X Pad X-30PB1 X-30PB1 V1 Out of range PB X Pad X-30 X-30 V1 Out of range PB X Pad X-31 X-31 V1 Out of range PB X Pad X-31 X-31L1 V3 Out of range PB X Pad X-32 X-32 V1 Out of range PB X Pad X-33PB 1 X-33PB1 V1 Out of range PB X Pad X-33 X-33 V2 Out of range PB X Pad X-34PB 1 X-34PB1 V1 Out of range PB X Pad X-34 X-34 V1 Out of range PB X Pad X-35 X-35 V1 Out of range PB X Pad X-35 X-35L 1 V6 Out of range PB X Pad X-36 X-36 V1 Out of range Prudhoe Bay PB X Pad X-16 Plan X-16A Field: Site: Well: Wellpath: n r--294 200 --100 --100 -200 -0 80 [deg] vs Centre to Centre Separation [100ft/in] Travelling Cylinder Azimuth (TFO+AZI -294 Well: X-16 Based on: Planned Program Vertical Depth: 8800.00 ft below Mean Sea Level Local +N/-S: 2152.45 ft Local +E/-W: 3680.65 ft Longitude: 148°37'36.260W Map E ft 669965.00 670650.00 670650.00 669965.00 Polygon 1 2 3 4 Site: PB X Pad . Drilling Target Con£.: 70% Description: Map Northing: 5942796.00 ft Map Easting : 669965.00 ft Latitude: 70014'58.934N Xft 2.21 692.69 684.20 -5.87 Target: X-16A Geo POlY. yft 99.98 338.82 -46.11 -265.95 Map N ft 5942896.00 5943150.00 5942765.00 5942530.00 2100 2500 2500 24-00 N 2300 2200 2100 2000 1900 1800 IlOO § C) C) C) C) C) D C) D D C) C) D C) D C) D D D C) C) C) C) C) C) ~ ~ LD r- OO 0- D N (T) ..3- Ln LD r- (T) (T) (T) (T) ..3- ..3- ..3- ..3- ..3- ..3- ..3- ..3- § ~ ~ ~ ~ . . C¿252000&O_ 499¡'.G~~7.¡SSG~ O¡GS OA~~ Cs::: $~ ~~ 165 89-6/1252 First National Bank Alaska AnChorage, AI( 99501 \ /' - . MEMo "Mastercard Cheek" JERRIE L HUBBLE p6 B~lfc'1s~'m"18: f/( INC 4NCHOFl4Gë, 4/( 9951-:"6612 . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ¡Jß/A, ~- /hA / PTD# 2oL-) ~2 YCJ . / ')¿ Development Service Exploration Stratigraphic CHECK WHAT ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI The permit is for a new wenboresegment of LATERAL existing well . Permit No, API No. . (If API num ber Production. should continue to be reported as last two. (2) digits a function' of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PH) records, data and logs acquired for the pilot hole must be clearly differentiated In both nabJe (name on permit plus PH) " and API number (SO - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTJON compliance with 20 AAC 25..05S~ Approvalto perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:J ception. (Company Name) assumes the liability of any protest 10 1he spacing ,eJception that may occur. DRY DITCH AU dry ditcb sample sets submitted to the SAMPLE Commission must be in no greater 1han 30' sample intervals from below tbe permafrost of from wbere samples are fint caught and ] 0' sample inter:vals through target zones. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT X-16A PTD#:2042440 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV I 1-01L GeoArea 890 Unit 11650 1 P~ermitfee attache~d ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yes ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 2 _Lease number appropriate_ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ _ ~ ~ ~ ~ ~ ~ ~ Yes ~ ~ _ ~ ~ ~ ~ _ ~ ~ ~ ~ _ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ _ ~ ~ ~ _ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 3 _U_nique welL nam~ ~and oumb.er ~ ~ _ ~ ~ _ _ _ _ ~ _ _ _ _ _ _ _ ~ _ ~ ~ ~ ~ _ _ _ _ _ _ _ _ _ _ ~ ~ ~ _ _ ~Y~es _ _ _ _ _ ~ ~ ~ _ ~ ~ ~ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ ~ _ _ ~ ~ _ _ _ _ _ _ _ _ ~ ~ _ _ _ ~ ~ _ _ _ _ _ _ _ _ _ _ _ ~ ~ _ _ 4 WellJocated in~a defiIJe~d~ppol ~ . ~ ~ ~ . ~ ~ Yes ~ ~ ~ ~ ~ . . . . ~ ~ _ . . . . . 5 Well JQcated proper distance from driJling uIJit bOUIJdary ~ . ~ ~ . . . . . _ ~ ~ _ ~ ~ ~ ~ ~ ~ ~ ~ Yes ~ . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . . . . _ . 6 Well JQcat~d proper _d[stance~ from QtlJer welJs. . . . Yes. . ~ ~ ~ ~ ~ ~ . ~ _ ~ . . . . . . . ~ ~ ~ ~ _ ~ . ~ _ . . . . . 7 .S.utficientacreage.aYaiLable in.drilliog unit ~ _ _ ~ _ ~ ~ ~ ~ ~ ~ ~ Yes ~ ~ ~ ~ . . ~ . . . ~ . 8 Jtd.eviated, is. well bore platincJu.ded . . . Yes ~ ~ ~ ~ _ ~ ~ . ~ ~ . . . . . . . ~ ~ ~ . ~ ~ . ~ ~ ~ ~ ~ ~ ~ ~ . . . 9 .Qperator onl}' affected party. . . . . . . . _ . . . ~ ~ ~ ~ ~ Yes _ . . . . . . ~ _ . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ _ . . . . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . . . . . . ~ ~ _ _ ~ ~ ~ ~ ~ ~ . . . 10 _Qperator lJas.apprppriate. b.ond inJorce . _ _ _ _ _ _ _ _ _ _ _ . . . . . . . . _ _ _ _ _ _ . . _ . _ _ _ Yes _ _ _ _ _ . _ _ . . . . _ _ _ _ _ _ _ _ _ _ ~ _ _ . . . . _ . _ _ _ _ _ _ _ . . _ . _ _ . _ _ _ _ _ . . . . . _ _ . . . _ _ . _ _ _ _ _ _ . . . . _ . 11 P.ermit can be [ssued witlJout COMervaJion order ~ _ _ _ ~ ~ ~ ~ ~ ~ . ~ . . . . . _ . . . ~ ~ ~ Yes ~ ~ ~ ~ . . . . . . . ~ ~ ~ ~ _ ~ ~ ~ ~ . ~ . . 12 P_ermit c.an be issued witlJQut admiIJistratille a'pprpvaJ ~ ~ . ~ . . . .. . ~ ~ _ _ _ ~ _ ~ ~ ~ ~ ~ ~ ~ Yes ~ . . ~ ~ ~ ~ ~ ~ _ ~ ~ ~ ~ ~ ~ ~ ~ . . . . ~ ~ ~ ~ _ ~ ~ . . _ . . . ~ _ ~ ~ ~ _ _ ~ ~ ~ ~ ~ ~ . . 12/6/2004 13 Can permit be approved before 15-day wait Yes 14 WellJQcated withiIJ area and.strataauthorized by Injectipo Order # (pullO# jn.c_omments) (For NA ~ ~ . . . . ~ ~ ~ ~ ~ ~ .. . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . .. . . . . ~ ~ _ ~ ~ ~ ~ ~ . ~ ~ . 15 AJlwelJs_withlnJl4ßlile.area_of reyiew id.eotified (F.or servic.ewellonl}'L _ _ _ _ _ _ _ . . _ _ _ _ _ .NA _ _ _ _ . . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . . . . . . . _ _ _ _ _ _ _ _ _ _ . . _ _ _ . . . _ _ _ _ . _ _ . . _ _ . . . _ _ . . _ _ _ _ _ . . . ~ 16 Pre-produ.ced injector; .duration. of pre-.productiolJ Less than 3 montlJs (For~se[\lice well QnJy) . ~NA ~ ~ ~ _ ~ ~ ~ ~ ~ . . . . ~ . . . ~ _ _ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . . . . . . ~ ~ _ ~ ~ ~ ~ ~ . . . 17 ACMPFïndingofConslstencyhas bee.nJssued.for.this project. . . ~ . ~ _ _ ~ ~ _ ~ ~ ~ ~ ~ ~ ~ NA . . . . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ . . . ~ ~ . . . . ~ ~ ~ . . . . Administration Appr RPC Date Engineering Appr Date WGA 12n 12004 Geology Appr RPC Date 12/6/2004 Geologic Commissioner: DTS Program DEV On/Off Shore On Well bore seg Annular Disposal - - - - - - - - - - - - - - - - 18 .C.onductor string provided ~ . . . . . . ~NA 19 Surface casing prQtects all known USDWs . . . _ . . . ~ ~ ~ ~ NA . . _ . . ~ ~ ~ ~ ~ ~ ~ ~ ~ _ _ ~ ~ ~ . . ~ 20 _CMT vol adeQuate.to circulate o~n ~colJd.uctor & SUJt csg .. ~ ~ ~ ~ ~ ~ _ _ _ ~ ~ ~ _ . . NA 21 _CMT vol adeQuate.to tie-lnJongstring tO~SJJrf csg~ . . . NA 22 _CMT wilJ coyer all kOQwnWQductiye horizons. ~ ~ . . . . . . .. ~ Yes ~ 23 .C.asing designs ad.eQua.te for C, T, B&. permafrost ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . . . ~ _ . . . . . . ~ ~ ~ ~ ~ Yes 24 AdequateJankageorreseryepit ~ ~ _. ~.. Yes . ~ ~ ~Nab.ors~9ES. ...... ~..... ~ ~ ~ ~ ~ ~ ~ ~ ~ ~. ~. 25 JtaJe-.drill, has.a. tOA03 for abandonment been apPJQved ~ ~ _ ~ _ ~ ~ ~ ~ ~ ~ ~ Yes . ~ ~ . ~ . . . . ~ ~ ~ ~ ~ _ ~ ~ ~ ~ ~ ~ ~ ~ ~ . . 26 Adequate."Ile!lbore separatio.n.pro'pose~L _ _ _ _ _ _ _ _ . _ . . . . . . _ _ _ _ _ _ _ _ _ . . . . . . . .Y_es _ _ _ _ _ . _ . . _ _ _ . _ _ _ _ _ _ _ _ _ . _ . . . . . _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . . . . . . _ _ . . _ _ _ _ _ _ _ _ . . . . . . . 27 Jfdiv~cter re(tuired, doeJ> it meet reguJations_ ~ . . . _ _ . _. . ~ ~ ~ ~NA ~ ~ ~ . ~ ~ ~ Sidetrack.. . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . . . .. . _ ~ ~ ~ ~ ~ ~ _ ~ ~ _ ~ ~ ~ ~ . . ~ ~ _ _ _ ~ ~ ~ ~ . . . 28 DriUiog fluid program schematic.& e(tuí'pJistadequate. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ . . . . _ . . . ~ ~ ~ ~ Yes Max MW.1LO_ppg. _ ~ ~ ~ ~ ~ ~ ~ ~ _ . . . . . ~ ~ ~ ~ ~ _ ~ . ~ ~ ~ . . . . . ~ . _ _ ~ _ ~ _ ~ ~ ~ . . . . . 29 .B.OP.EJ>,.doJhey meet reguJatiolJ ~ Yes. . . . . . . . . ~ . ~ _ . . ~ 30B~OPEpressrating ap.pro.priate;.testlo.(puJ psig lncommelJts) ~ ~ ~ ~ . _ _ . . . . ~ ~ ~ Yes _ Testto.350Q psLMSF' 2370 psi. . . _ . ~ ~ ~ ~ ~ ~ ~ _ _ _ ~ . . 31 Choke manifold complies w/APL ßF'-53 (May 84) ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ . . _ _ . ~ ~ ~ ~ ~ Yes ~ ~ . . . . . . 32 WQrk wiJI pcc.ur withput.operation .shutdO"lln_ . _ . . . . _ . ~ ~ ~ Yes _ . ~ . . . . 33 Js presence. Qf H2S gas. probable. ~ ~ ~ ~ ~ ~ ~ ~ ~ Yes. . 150ppm. 34 MeçlJanicaLcpodition _of wells within ~OR yer[fied (For. service welJ onl}') ~ ~ ~ ~ . _ . . . ~ NA . ~ ~ ~ ~ ~ . . . . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - 35 Permit can be issued w/o hydrogen sulfide meas.ureJ> . . . . . ~ No_ 36 D~ata.preseoted on pote.ntial pverpressuœzoneJ> . . _ ~ ~ ~ ~ ~ ~ ~NA 37 _S.eismic.analysis Qf J>lJaJlow gas~z.ooes~ . ~ ~ ~ ~ ~ _ ~ _ ~ ~ . . . . . . . .NA 38 _S_eabed .conditipn survey (if off-shore) ~ ~ ~ . ~ . . . . . . _ ~ . ~ NA ~ . . . . 39 _ Contact namelphone.for. "Ileekly progressreports [exploratpryonlYl ~ ~ ~ ~ _ ~ ~ NA ~ ~ ~ ~ ~ ~ . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: /?4A Date /<./7/~ D . e . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dr~ing Services LIS Scan utility . ~ a t/_~ c.-/~I $Revision: 3 $ LisLib $Revision: 4 $ Fri Jul 01 14:04:58 2005 I)ÀOq Reel Header Service name.... ........ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Previous Reel Name. ..... . UNKNOWN Comments... ........ ..... .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name....... .... .... . UNKNOWN Continuation Number..... .01 Previous Tape Name. . . . . . .UNKNOWN Comments................ .STS LIS writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA X-16A 50029206840100 BP Exploration (Alaska), Inc. Sperry Drilling Services 01-JUL-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003454677 P. SMITH D. FERGUSON MWD RUN 2 MW0003454677 P. SMITH D. FERGUSON MWD RUN 3 MW0003454677 B. HENNINGSE A. MADSEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 5 10N 14E 424 460 68.60 39.97 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 6.125 CASING SIZE (IN) 9.625 7.000 DRILLERS DEPTH (FT) 8143.0 10318.0 # REMARKS: . . 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK¡ MILL THE WINDOW¡ AND DRILL A BIT OF RAT HOLE. THE TOP OF THE WHIPSTOCK WAS AT 8143'MD/7090'TVD, AND THE BOTTOM WAS AT 8159'MD/7102'TVD. ONLY SROP DATA ARE PRESENTED. 4. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS¡ AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). RUN 3 ALSO INCLUDED AT-BIT INCLINATION (ABI) ¡ COMPENSATED THERMAL NEUTRON POROSITY (CTN)¡ AND STABILIZED LITHO-DENSITY (SLD). 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 15' DOWNHOLE PER E-MAIL INSTRUCTIONS RECEIVED FROM D.SCHNORR (SIS/BP) DATED 30 JUNE 2005. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1 - 3 REPRESENT WELL X-16A WITH API#: 50-029-20684-01-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10766'MD/9050'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" MUD WEIGHT: 8.4 PPG · . MUD SALINITY: 2800 PPM CHLORIDES FORMATION WATER SALINITY: 20000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name........... ..STSLIB.001 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .05/07/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FCNT NCNT NPHI FET RPD RPM RPS RPX PEF DRHO RHOB $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 7869.0 8158.0 10251.5 10252.5 10252.5 10294.5 10294.5 10294.5 10294.5 10294.5 10335.5 10335.5 10335.5 STOP DEPTH 10733.5 10781.0 10697.0 10697.0 10697.0 10740.5 10740.5 10740.5 10740.5 10740.5 10712.0 10712.0 10712.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------ BASELINE DEPTH 7869.0 10781.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: GR 7854.0 10766.0 BIT RUN NO 1 2 3 MERGED MAIN PASS. $ MERGE TOP 8143.0 8172.0 10320.0 MERGE BASE 8172.0 10320.0 10766.0 # Data Format Specification Record Data Record Type. .............. ...0 Data Specification Block Type.. ...0 Logging Direction...... ... ........Down Optical log depth units...... .....Feet Data Reference Point... .......... .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..... ................ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7869 10781 9325 5825 7869 10781 ROP MWD FT/H 0.09 390.11 104.942 5247 8158 10781 GR MWD API 13.05 551. 44 124.949 5730 7869 10733.5 RPX MWD OHMM 0.85 1955 40.5922 893 10294.5 10740.5 RPS MWD OHMM 0.96 2000 40.3513 893 10294.5 10740.5 RPM MWD OHMM 0.7 2000 141.387 893 10294.5 10740.5 RPD MWD OHMM 0.28 2000 145.087 893 10294.5 10740.5 FET MWD HOUR 0.39 64.84 7.06925 893 10294.5 10740.5 NPHI MWD PU-S 5.08 50.56 25.5421 890 10252.5 10697 FCNT MWD CNTS 119 3318 671.251 892 10251. 5 10697 NCNT MWD CNTS 14377 51654 27143.1 890 10252.5 10697 RHOB MWD G/CM 1.525 3.726 2.38713 754 10335.5 10712 DRHO MWD G/CM -0.265 1. 119 0.0691114 754 10335.5 10712 PEF MWD BARN 0.62 11.06 2.45306 754 10335.5 10712 First Reading For Entire File......... .7869 Last Reading For Entire File.......... .10781 File Trailer Service name.. .... ..... ..STSLIB.001 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation...... .05/07/01 Maximum Physical Record. .65535 File Type..... ......... ..LO Next File Name...........STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..05/07/01 Maximum Physical Record..65535 File Type.. .......... '" .LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ . 1 .5000 START DEPTH 8143.0 STOP DEPTH 8172.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TÒP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.... ............ . Down Optical log depth units.......... .Feet Data Reference Point.... ..........Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 23-DEC-04 Insite 66.37 Memory 8172.0 8143.0 8172.0 .0 .0 TOOL NUMBER 053519 8.500 8143.0 Water Based 11.00 62.0 8.5 1800 3.8 .000 .0 .000 .0 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT ROP MWDOI0 tp 4 o 4 FT FT/H 1 68 1 68 Name Service Unit DEPT FT ROP MWDOI0 FT/H Min 8143 0.09 Max 8172 8.68 Mean 8157.5 5.41746 Nsam 59 59 First Reading For Entire File.. ....... .8143 Last Reading For Entire File..... ..... .8172 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number...........l.0.0 Date of Generation..... ..05/07/01 Maximum Physical Record. .65535 File Type................ LO Next File Name......... ..STSLIB.003 Physical EOF File Header Service name.. ........ ...STSLIB.003 Service Sub Level Name... Version Number.... .......1.0.0 Date of Generation..... ..05/07/01 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 . 1 2 First Reading 8143 8143 Last Reading 8172 8172 header data for each bit run in separate files. 2 .5000 START DEPTH 7854.0 8172.5 STOP DEPTH 10288.5 10320.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 27-DEC-04 Insite 66.37 Memory 10320.0 8172.0 10320.0 42.9 46.2 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY TOOL NUMBER 103770 $ . # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE· AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.....O Logging Direction... .... ..... .... . Down Optical log depth units. ..........Feet Data Reference Point. .......... ...Undefined Frame Spacing...... .............. .60 .1IN Max frames per record............ . Undefined Absent value. .... ....... ......... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code . 8.500 8143.0 Water 11.00 53.0 9.2 2000 3.8 Based .000 .000 .000 .000 .0 158.0 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7854 10320 9087 4933 7854 10320 ROP MWD020 FT/H 0.92 285.15 107.678 4296 8172.5 10320 GR MWD020 API 27.87 390.21 134.828 4870 7854 10288.5 First Reading For Entire File........ ..7854 Last Reading For Entire File... ....... .10320 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation...... .05/07/01 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.004 Physical EOF . File Header Service name. ......... ...STSLIB.004 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation...... .05/07/01 Maximum Physical Record..65535 File Type............... .LO Previous File Name... ....STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI FET RPD RPM RPS RPX GR DRHO RHOB ROP PEF $ 4 . header data for each bit run in separate files. 3 .5000 START DEPTH 10236.5 10237.5 10237.5 10279.5 10279.5 10279.5 10279.5 10279.5 10289.0 10320.5 10320.5 10320.5 10320.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL·· CODE DGR SLD CTN EWR4 $ # STOP DEPTH 10682.0 10682.0 10682.0 10725.5 10725.5 10725.5 10725.5 10725.5 10718.5 10697.0 10697.0 10766.0 10697.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 30-DEC-04 Insite 66.37 Memory 10766.0 10320.0 10766.0 17.4 41. 9 TOOL NUMBER 87225 110059 10603685 156401 6.125 10318.0 Flo-pro 8.40 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: . . 55.0 9.2 2800 .0 1.100 65.0 .560 133.5 1. 400 65.0 .950 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction.............. ...Down Optical log depth units.......... .Feet Data Reference Point... ...........Undefined Frame Spacing....... ........... ...60 .1IN Max frames per record.. ...... .., ..Undefined Absent value................ ......-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10236.5 10766 10501. 3 1060 10236.5 10766 ROP MWD030 FT/H 2.63 390.11 98.348 892 10320.5 10766 GR MWD030 API 13.05 551. 44 69.0064 860 10289 10718.5 RPX MWD030 OHMM 0.85 1955 40.5922 893 10279.5 10725.5 RPS MWD030 OHMM 0.96 2000 40.3513 893 10279.5 10725.5 RPM MWD030 OHMM 0.7 2000 141.387 893 10279.5 10725.5 RPD MWD030 OHMM 0.28 2000 145.087 893 10279.5 10725.5 FET MWD030 HOUR 0.39 64.84 7.06925 893 10279.5 10725.5 NPHI MWD030 PU-S 5.08 50.56 25.5421 890 10237.5 10682 FCNT MWD030 CNTS 119 3318 671.251 892 10236.5 10682 NCNT MWD030 CNTS 14377 51654 27143.1 890 10237.5 10682 RHOB MWD030 G/CM 1.525 3.726 2.38713 754 10320.5 10697 DRHO MWD030 G/CM -0.265 1.119 0.0691114 754 10320.5 10697 PEF MWD030 BARN 0.62 11.06 2.45306 754 10320.5 10697 . . First Reading For Entire File......... .10236.5 Last Reading For Entire File.......... .10766 File Trailer Service name. ........ ....STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...05/07/01 Maximum Physical Record. .65535 File Type............. ...LD Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name. ........... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number......01 Next Tape Name.......... . UNKNOWN Comments..... .......... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.. ........ .... ..UNKNOWN Continuation Number.... ..01 Next Reel Name. ... ..... ..UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File