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Home My WebLink About204-190Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/21/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260121 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 16RD 50133205540100 207125 12/3/2025 AK E-LINE PPROF T41253 BRU 211-35 50283201890000 223050 11/7/2025 AK E-LINE Perf T41254 BRU 213-26 50283201920000 223069 11/23/2025 AK E-LINE Perf T41255 BRU 213-26T 50283202040000 225038 11/4/2025 AK E-LINE Perf T41256 BRU 241-34S 50283201980000 224077 11/9/2025 AK E-LINE Perf T41257 BRU 241-34T 50283201810000 220052 11/6/2025 AK E-LINE Perf T41258 BRU 244-27 50283201850000 222038 12/13/2025 AK E-LINE Perf T41259 BRU 244-27 50283201850000 222038 12/19/2025 AK E-LINE StripGun T41259 GP ST 17586 9 50733204480000 193062 11/13/2025 AK E-LINE Perf T41260 IRU 241-01 50283201840000 221076 12/21/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/30/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/16/2025 AK E-LINE Plug T41261 IRU 241-01 50283201840000 221076 11/26/2025 AK E-LINE Plug/Perf T41261 KALOTSA 01 50133206570000 216132 11/19/2025 AK E-LINE Perf T41262 KBU 31-18 50133206490000 215024 11/8/2025 AK E-LINE Drift/PPROF T41263 KU 12-17 50133205770000 208089 11/14/2025 AK E-LINE StimGun T41264 LRU C-01RD 50283200610100 201168 11/27/2025 AK E-LINE RCT/Perf T41265 MPI 2-32 50029220840000 190119 12/10/2025 AK E-LINE LDL T41266 MPI 2-38 50029220900000 190129 12/5/2025 AK E-LINE LDL T41267 MPU H-16 50029232270000 204190 12/3/2025 AK E-LINE CBL T41268 MPU H-16 50029232270000 204190 11/19/2025 AK E-LINE TubingCut T41268 MPU I-14 50029232140000 204119 11/13/2025 AK E-LINE CBL T41269 NCIU A-06A 50883200260100 225071 11/28/2025 AK E-LINE Perf/Plug T41270 NCIU A-08 50883200280000 169063 12/2/2025 AK E-LINE GPT T41271 NCIU A-19 50883201940000 224026 12/16/2025 AK E-LINE GPT T41272 NCIU A-19 50883201940000 224026 12/12/2025 AK E-LINE GPT/Perf/Plug T41272 NCIU A-19 50883201940000 224026 12/17/2025 AK E-LINE Perf T41272 NCIU A-21A 50883201990100 225075 12/30/2025 AK E-LINE PPROF T41273 OP19-T1N 50029234910000 213068 11/19/2025 AK E-LINE TubingPunch T41274 T41268MPU H-16 50029232270000 204190 12/3/2025 AK E-LINE CBL MPU H-16 50029232270000 204190 11/19/2025 AK E-LINE TubingCut Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:35 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU D-10 50283202080000 225082 12/9/2025 AK E-LINE Perf T41275 SCU 322C-04 50133101040100 215217 12/4/2025 AK E-LINE TubingPunch T41276 SRU 222-33 50133207150000 223100 12/7/2025 AK E-LINE Plug T41277 SU 43-10 50133207390000 225107 11/26/2025 AK E-LINE CBL T41278 TBU A-12RD 50733200760100 171029 11/29/2025 AK E-LINE Perf T41279 TBU D-24A 50733202240100 174064 12/2/2025 AK E-LINE TubingPunch T41280 TBU D-24A 50733202240100 174064 11/21/2025 AK E-LINE TubingPunch T41280 TBU M-10 50733205880000 209154 11/15/2025 AK E-LINE Perf T41281 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:51 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Reservoir Abandonment 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,967' N/A Casing Collapse Conductor N/A Surface 2,090psi Intermediate 4,790psi Liner 7,500psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 5,580 MD/ 3,813 TVD, 6,054 MD/ 3,977 TVD & 6,320 MD/ 4,036 TVD and N/A Erik Nelson Erik.Nelson@hilcorp.com 907-564-5277 6,460' Perforation Depth MD (ft): 9,905' See Schematic 3,658' See Schematic 4-1/2" 4,056'4-1/2" 112' 20" 10-3/4" 7-5/8" 4,182' 4-1/2"3,723' 6,516' MD N/A 8,430psi 3,580psi 6,890psi 3,139' 4,063' 4,010' 4,182' 6,516' Length Size Proposed Pools: 112' 112' 12.6# / L-80 / TSH 521 TVD Burst 6081' 8,430psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 204-190 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23227-00-00 Hilcorp Alaska LLC C.O 477B AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 11/30/2025 7-5/8" x 4.5" Tri Point, 7-5/8" x 4.5" LTC Hyd Iso & Baker ZXP LTP and N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT H-16 MILNE POINT SCHRADER BLUFF OIL N/A 4,006' 9,967' 4,006' 1,105 N/A Perforate Reppair Well Exploratory Stratigraphic Development Service BOP Test Mechanical Integrity Test No Wellbore schematic Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.11.25 17:11:48 - 09'00' Taylor Wellman (2143) 325-728 By Grace Christianson at 8:11 am, Nov 26, 2025 DSR-11/26/25TS 11/26/25 10-404 MGR28NOV2025 * BOPE test to 2500 psi. 24 hour notice to AOGCC. * CBL to be performed and provided to AOGCC on 7-5/8" casing to determine zonal isolation. * Additional 10-403 required for jet pump production or if well to be put on injection. * AOGCC will require 24 hour notification for opportunity to witness MIT-IA to 3500 psi if well to be put on injection. 11/28/25 Well Name: MPU H-16 API Number: 50-029-23227-00-00 Current Status: SI JP Prod Rig: Doyon 14 Estimated Start Date: 30 Nov 2025 Estimated Duration: 7 days Regulatory Contact: Tom Fouts Permit to Drill Number: 204-190 First Call Engineer: Erik Q. Nelson (907) 777 8353 (O) (907) 903 7407 (C) Second Call Engineer: Taylor Wellman (907) 777 8449 (O) (907) 947 9533 (C) Current Bottom Hole Pressure (BHP): 1484 psi @ 5513-ft MD (3787-ft TVD) 28 Aug 2025 DH Gauge | 7.5 EMW (8.5 KWF) Max Potential Surface Pressure (MPSP): 1105 psi Gas Column Gradient (0.1 psi/ft) Max Deviation: Relevant to Wellwork 94.7° @ 8689-ft MD (OB Lateral) H-16 94.5° @ 8295-ft MD (OA Lateral) H-16L1 Max Dogleg: Relevant to Wellwork 11.5°/100-ft @ 8931-ft MD (OB Lateral) H-16 16.6°/100-ft @ 6233-ft MD (OA Lateral) H-16L1 Min ID: Relevant to Wellwork 3.760-in ID XN-nipple pro le at 6065-ft MD RKB: 20.00-ft (Nabors 4ES) Brief Well Summary: MPU H-16 was drilled in 2004 and completed as a dual lateral Schrader Blu OA and OB producer. It produced with an ESP until 2019 when ASR worked the well over to add perforations into the Schrader N- sand. The Schrader Blu N-sands were covered with screens and a sliding sleeve was run above the upper production packer so MPU H-16 could be lifted with a reverse circulation jet pump. The well has been online until June 2025 when it was shut-in for ongoing surface work at H-Pad. An attempt was made to plug and abandon the OA and OB laterals in this well via coiled tubing (Sundry #325-571) but we were only able to access the lower OB lateral to lay in cement. Notes Regarding Current Wellbore Condition: This Change of Procedure (COP) anticipates that Doyon 14 is able to work through Approved Sundry# 325-709 Step #35, thus completing the following major steps: - Removal of the entirety of the previous 4-½ completion to the WLEG - Installation and con rmation of the Baker Hughes Lateral Re-entry Diverter Submission of this COP details running a 3-½ injector straddle completion in lieu of the 7-5/8 Cast Iron Bridge Plug (CIBP) prescribed in Sundry# 325-709s Conditions of Approval (COA). Well: MPU H-16 PTD: 204-190 API: 50-029-23227-00-00 Date: 25 November 2025 Objective: Place cement across the lower ~75% of the OA lateral as measured from the toe (TOC planned ot be 6700- ft MD). H-16s laterals crosscut the planned redevelopment pattern for a line drive (injector, producer, injector) for the Schrader Blu formation. This COP procedure details the below outline of the scope of this project: - Run 3-½ Injector Straddle Upper Completion - Cleanout upper OA lateral (planned to be performed with Coiled Tubing) - Lay cement in upper OA from oat shoe (9903-ft MD) to +/- 6700-ft MD using Coiled Tubing The future disposition of this well will be as an Schrader Blu injector. A separate 10-403 Application for Sundry Approval will be submitted for this well requesting to convert it to an Service (i.e. Injector) well and is not included in this COP. RWO Procedure (Sundried Work): Previously Approved work under Sundry# 325-709 thru Step #35 completed 3-½ Upper Straddle Completion: 36) Ensure handling equipment is on-hand for running 3-½, 9.3# L80 EUE 8rd completion 37) MU Spooler to run TEC Wire 38) MU Straddle Pkr Assy: a) 3-½ WLEG - +/- 6120-ft MD b) 3-½ XN-nipple pro le (2.750- in ID) w/ RHC pro le installed c) 7-5/8 x 3-½ DLH Packer (Hyd Set STR) w/ 10-ft X-over pups Target set depth at +/- 6100- ft MD d) 3-½ X-over pup e) X jts 3-½, 9.3# L80 EUE 8rd tbg f) 3-½, 9.3# L80 EUE 8rd tbg w/ (2) 3-½ x (1 or 1-½) GLMs w/ DGVs installed g) 3-½ X-nipple pro le (2.813- in ID) Leave Empty h) X jts 3-½, 9.3# L80 EUE 8rd tbg i) 7-5/8 x 3-½ DLH Packer (Hyd Set STR) w/ 10-ft X-over pups Target set depth at +/- 5500- ft MD j) 5 (15-ft) PBR k) 5 Mule Shoe l) 5 Seal Unit m) 5 10-ft Spacer n) 5 Seal Unit o) 5 Anchor Latch p) 3-½ X-over pup q) (1) full jt 3-½, 9.3# L80 EUE 8rd tbg r) 4-½ Baker Hughes Zenith Gauge Carrier w/ 10-ft x-over handling pups * CBL required on 7-5/8" IC before tubing to be placed in hole. - mgr Well: MPU H-16 PTD: 204-190 API: 50-029-23227-00-00 Date: 25 November 2025 s) (1) full jt 3-½, 9.3# L80 EUE 8rd tbg t) 3-½ Sliding Sleeve w/ 10-ft handling pups sleeve run in closed position u) XXX jts 3-½, 9.3# L80 EUE 8rd tbg to surface v) X-over to tbg hgr NOTE: Run 3-½ cross coupling clamps every jt for the 1 st 10 jts then every other jt to surface on the TEC wire 39) Spot 55 bbls 8.5 #/gal CI brine on backside of straddle pkr completion from WLEG to above PBR 40) Drop ball/rod assy to set both pkrs simultaneously per Tripoint Alaska Completion Supervisors instructions 41) Shear out of PBR and space out accordingly 42) PU and MU the tbg hgr. Make nal splice of the TEC wire to the penetrator and dummy o any additional control line ports if necessary. NOTE: Use caution when landing the tbg hgr so as to avoid damaging the TEC wire or penetrator. 43) Land tbg hgr and record PUW and SOW on tbg tally 44) RILDS and lay down landing jt 45) Perform MIT-IA (3500 psi) for 30-min and chart 46) Set BPV. ND BOPE. Set CTS Plug. 47) NU tbg head adapter. PT tbg hgr void to 500/5000 psi. 48) NU new 3-1/18 5M tree. PT tree 500/5000 psi. 49) Pull CTS plug and BPV 50) Secure tree and cellar 51) RDMO Doyon 14 Post-RWO Wellwork: 52) MIRU Slickline and LRS 53) RIH to shift Sliding Sleeve open 54) Pump diesel FP (100 bbls) down IA taking returns from the tbg in order FP well to 2500-ft TVD (2883-ft MD) 55) Shift Sliding Sleeve closed. MIT-IA w/ diesel to 3500 psi for 30-min and chart. 56) Retrieve ball/rod assy from XN-nipple pro le 57) Bullhead 26 bbls diesel FP down tbg 58) RDMO slickline and LRS At this point MPU H-16 the well is ready for the follow-on Coiled Tubing P&A of the upper OA lateral according to the previously Approved Sundry# 325-709 Attachments: 1) Current Wellbore Schematic 2) Proposed Wellbore Schematic 3) Doyon 14 BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 11/18/2025 SCHEMATIC Milne Point Unit Well: MPU H-16 Last Completed: 9/14/2016 PTD: 204-190 13 14 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4Surface 45.5 / L-80 / BTC 9.950 Surface 4,182 7-5/8"Intermediate 29.7 / L-80 / BTC-MOD 6.875 Surface 6,516 4-1/2Liner A12.6 / L-80 / IBT 3.958 6,1829,905 4-1/2Liner B12.6 / L-80 / IBT 3.958 6,3099,967 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TSH 521 3.958 Surface 6,081 LINER DETAIL 4-1/2OA Slotted Lnr 12.6 / L-80 / IBT 3.958 6,2048,779 4-1/2OA Slotted Lnr 12.6 / L-80 / IBT 3.958 8,9459,859 4-1/2OB Slotted Lnr 12.6 / L-80 / IBT 3.958 6,5248,839 4-1/2OB Slotted Lnr 12.6 / L-80 / IBT 3.958 9,1739,922 JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 5,452Hal Sliding Sleeve XD 2 5,513 Baker BHPG 3,787 TVD 3 5,5807-5/8 X 4.5" Tri Point packer 4 5,646X-Nipple w/ RHC Plug 5 5,707 250 Micron Screens w/ Centralizer - 337 6 6,0547-5/8" x 4-1/2" LTC HYD ISOLATION PACKER 7 6,069 4-1/2 LTC X-Nipple w/ WLEG Btm @ 6,081 8 6,177 Baker Hook Wall, Hanger above 7 Window 9 6,194 Baker Hook Wall, Hanger below 7 Window 10 6,309Baker Tie Back Sleeve 11 6,320Baker ZXP Liner Top Packer 12 6,326 Baker 7 x 5 HMC Liner Hanger 13 9,859 OA Lateral Btm Baker 4-1/2 Pack-off Bushing 14 9,922 OB Lateral Btm Baker 4-1/2 Pack-off Bushing OPEN HOLE / CEMENT DETAIL 20"Cmt w/ 260 sx of Arcticset I in 42 Hole 10-3/4"Cmt w/ 560 sx PF L, 475 sx Class G in 13-1/2 Hole 7-5/8Cmt w/ 598 sx Class G in 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 500 MD Max Wellbore Angle = 82.4 deg @ 6,515 MD 69.0 deg @ 5,859 MD WELLHEAD Tree 4-1/6 5M Wellhead FMC Tubing Hanger, 11 x 4-1/2 EUE TCII GENERAL WELL INFO API: 50-029-23227-00-00 Drilled and Cased by Doyon 14 11/01/2004 ESP Completion by Nabors 4ES 2/16/2005 ESP Completion by ASR#1 9/14/2016 Convert to JP by ASR#1 12/15/2019 Perf Add & Jet Pump Completion by ASR 3/3/2023 LATERAL WINDOW DETAIL Top of OA Window @ 6,182 MD; Bottom @ 6,194 MD; Angle @ top of window is 76 deg PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Schrader N 5,726 5,764 3,866 3,88038 2/28/2023 Open Schrader N 5,798 5,902 3,892 3,929104 2/28/2023 Open Schrader N 5,922 6,012 3,936 3,96690 2/28/2023 Open _____________________________________________________________________________________ Revised By: GP 11/25/2025 3-1/2 Inj. Comp. PROPOSED Milne Point Unit Well: MPU H-16 Last Completed: 9/14/2016 PTD: 204-190 14 15 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4Surface 45.5 / L-80 / BTC 9.950 Surface 4,182 7-5/8"Intermediate 29.7 / L-80 / BTC-MOD 6.875 Surface 6,516 4-1/2Liner A12.6 / L-80 / IBT 3.958 6,1829,905 4-1/2Liner B12.6 / L-80 / IBT 3.958 6,3099,967 Tubing DETAIL 3-1/2Tubing 9.3# / L-80 / EUE 8rd Surface LINER DETAIL 4-1/2OA Slotted Lnr 12.6 / L-80 / IBT 3.958 6,2048,779 4-1/2OA Slotted Lnr 12.6 / L-80 / IBT 3.958 8,9459,859 4-1/2OB Slotted Lnr 12.6 / L-80 / IBT 3.958 6,5248,839 4-1/2OB Slotted Lnr 12.6 / L-80 / IBT 3.958 9,1739,922 JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 3-1/2 Sliding Sleeve 2 B.H. Gauge w/ TEC Wire 3 7-5/8 x 3-1/2 HYD Set Retrievable Packer 4 3-1/2 GLM 5 3-1/2 GLM 6 7-5/8 x 3-1/2 HYD Set Retrievable Packer 7 3-1/2 XN Nipple, ID = 2.750 8 3-1/2 WLEG 9 6,177 Baker Hook Wall, Hanger above 7 Window 10 6,194 Baker Hook Wall, Hanger below 7 Window 11 6,309Baker Tie Back Sleeve 12 6,320Baker ZXP Liner Top Packer 13 6,326 Baker 7 x 5 HMC Liner Hanger 14 9,859 OA Lateral Btm Baker 4-1/2 Pack-off Bushing 15 9,922 OB Lateral Btm Baker 4-1/2 Pack-off Bushing OPEN HOLE / CEMENT DETAIL 20"Cmt w/ 260 sx of Arcticset I in 42 Hole 10-3/4"Cmt w/ 560 sx PF L, 475 sx Class G in 13-1/2 Hole 7-5/8Cmt w/ 598 sx Class G in 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 500 MD Max Wellbore Angle = 82.4 deg @ 6,515 MD 69.0 deg @ 5,859 MD GENERAL WELL INFO API: 50-029-23227-00-00 Drilled and Cased by Doyon 14 11/01/2004 ESP Completion by Nabors 4ES 2/16/2005 ESP Completion by ASR#1 9/14/2016 Convert to JP by ASR#1 12/15/2019 Perf Add & Jet Pump Completion by ASR 3/3/2023 LATERAL WINDOW DETAIL Top of OA Window @ 6,182 MD; Bottom @ 6,194 MD; Angle @ top of window is 76 deg PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Schrader N 5,726 5,764 3,866 3,88038 2/28/2023 Open Schrader N 5,798 5,902 3,892 3,929104 2/28/2023 Open Schrader N 5,922 6,012 3,936 3,96690 2/28/2023 Open WELLHEAD Tree 3-1/8 5M Wellhead FMC Tubing Hanger, 11 x 3-1/2 EUE GID Kill Line Ram Size: 2-7/8" X 5" VBR Ram Size: Blind Rams Top of Cellar Box Choke Line 2-7/8" X 5" VBR Doyon 14 13 5/8" 5000# 13 5/8" 5000# HYDRIL 13 5/8" 5000# 13 5/8" 5000# Mud Cross HYDRIL HYDRIL 13 5/8" 5000# 13 5/8" 5000# Hydril "GK" 11", 5000# 13 5/8" 5000# 11", 5000# 11", 5000# 11", 5000# 11", 5000# 11", 5000# HCRHCR 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Reservoir Abandonment 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,967' N/A Casing Collapse Conductor N/A Surface 2,090psi Intermediate 4,790psi Liner 7,500psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT H-16 MILNE POINT SCHRADER BLUFF OIL N/A 4,006' 9,967' 4,006' 1,105 N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 11/19/2025 7-5/8" x 4.5" Tri Point, 7-5/8" x 4.5" LTC Hyd Iso & Baker ZXP LTP and N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 204-190 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23227-00-00 Hilcorp Alaska LLC C.O 477B Length Size Proposed Pools: 112' 112' 12.6# / L-80 / TSH 521 TVD Burst 6,081' 8,430psi MD N/A 8,430psi 3,580psi 6,890psi 3,139' 4,063' 4,010' 4,182' 6,516' 112' 20" 10-3/4" 7-5/8" 4,182' 4-1/2"3,723' 6,516' 9,905' See Schematic 3,658' See Schematic 4-1/2" 4,056'4-1/2" 5,580 MD/ 3,813 TVD, 6,054 MD/ 3,977 TVD & 6,320 MD/ 4,036 TVD and N/A Erik Nelson Erik.Nelson@hilcorp.com 907-564-5277 6,460' Perforation Depth MD (ft): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.11.18 15:50:41 - 09'00' Taylor Wellman (2143) 325-709 By Grace Christianson at 8:32 am, Nov 19, 2025 SFD 11/19/2025 mgr DSR-11/19/25 mgr * BOPE test to 2500 psi. 24 hour notice to AOGCC. * Approved to leave SB N-sand without cement with a tested CBP/CIBP above top perforation and KWF above plug for 45 days to allow future utility decision. No kill string required for 45 days. * 90 days granted for future utility determination to return the well to operability or suspend with approved reservoir plug. MGR20NOV25 10-404 JLC 11/20/2025 11/20/25 - - - - - - - - - - - - - 24 hour notice to AOGCC. - mgr Prep for possible packer gas when milling packer. - mgr * Prep for possible packer gas when milling packer. - mgr - - * Well to be left with CBP or CIBP just above top of perforations and KWF above the plug. No kill string required for 45 days. Dry hole tree to be installed. - mgr _____________________________________________________________________________________ Revised By: TDF 11/18/2025 SCHEMATIC Milne Point Unit Well: MPU H-16 Last Completed: 9/14/2016 PTD: 204-190 13 14 TD =9,967(MD) / TD = 4,006(TVD) 2000 7-5/888 7 8 & 9 10-3/444 1011 12 OA Lateral PBTD =9,967(MD) / PBTD = 4,006(TVD) OB Lateral 1 3 5 4 2 6 Orig. KB Elev.:70.25/ Orig. GL Elev.: 36.2000 RKB Hanger: 20.00 (Nabors 4ES) TOC @ 6,460 CTM 10/7/2025 Tubing Cut #1: ±6,046 Tubing Cut #2: ±5,702 Tubing Cut #3: ±5,578 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 92 /H-40 / Welded N/A Surface 112' 10-3/4Surface 45.5 / L-80 /BTC 9.950 Surface 4,182 7-5/8"Intermediate 29.7 / L-80 /BTC-MOD 6.875 Surface 6,516 4-1/2Liner A12.6 / L-80 / IBT 3.958 6,182 9,905 4-1/2Liner B12.6 / L-80 / IBT 3.958 6,309 9,967 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TSH 521 3.958 Surface 6,081 LINER DETAIL 4-1/2OA Slotted Lnr 12.6 / L-80 / IBT 3.958 6,204 8,779 4-1/2OA Slotted Lnr 12.6 / L-80 / IBT 3.958 8,945 9,859 4-1/2OB Slotted Lnr 12.6 / L-80 / IBT 3.958 6,524 8,839 4-1/2OB Slotted Lnr 12.6 / L-80 / IBT 3.958 9,173 9,922 JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 5,452Hal Sliding Sleeve XD 2 5,513Baker BHPG 3,787 TVD 3 5,5807-5/8 X 4.5" Tri Point packer 4 5,646X-Nipple w/ RHC Plug 5 5,707250 Micron Screens w/ Centralizer -337 6 6,0547-5/8" x 4-1/2" LTC HYD ISOLATION PACKER 7 6,0694-1/2 LTC X-Nipple w/ WLEG Btm @ 6,081 8 6,177Baker Hook Wall, Hanger above 7 Window 9 6,194Baker Hook Wall, Hanger below 7 Window 10 6,309Baker Tie Back Sleeve 11 6,320Baker ZXP Liner Top Packer 12 6,326Baker 7 x 5 HMC Liner Hanger 13 9,859OA Lateral Btm Baker 4-1/2 Pack-off Bushing 14 9,922OB Lateral Btm Baker 4-1/2 Pack-off Bushing OPEN HOLE / CEMENT DETAIL 20"Cmt w/260 sx of Arcticset I in 42 Hole 10-3/4"Cmt w/ 560 sx PF L,475 sx Class Gin 13-1/2 Hole 7-5/8Cmt w/ 598 sx Class Gin 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 500 MD Max Wellbore Angle = 82.4 deg @ 6,515 MD 69.0 deg @ 5,859 MD WELLHEAD Tree 4-1/6 5M Wellhead FMC Tubing Hanger, 11 x 4-1/2 EUE TCII GENERAL WELL INFO API: 50-029-23227-00-00 Drilled and Cased by Doyon 14 11/01/2004 ESP Completion by Nabors 4ES 2/16/2005 ESP Completion by ASR#1 9/14/2016 Convert to JP by ASR#1 12/15/2019 Perf Add & Jet Pump Completion by ASR 3/3/2023 LATERAL WINDOW DETAIL Top of OA Window @ 6,182 MD; Bottom @ 6,194MD; Angle @ top of window is 76 deg PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Schrader N5,726 5,7643,8663,88038 2/28/2023 Open Schrader N5,798 5,902 3,892 3,929104 2/28/2023 Open Schrader N5,922 6,012 3,936 3,96690 2/28/2023 Open _____________________________________________________________________________________ Revised By: TDF 11/18/2025 PROPOSED Milne Point Unit Well: MPU H-16 Last Completed: 9/14/2016 PTD: 204-190 6 7 TD =9,967(MD) / TD = 4,006(TVD) 20 7-5/8 1 & 2 10-3/4 34 5 LateralRe-Entry Diverter @± 6,194 PBTD =9,967(MD) / PBTD =4,006(TVD) OB Lateral Orig. KB Elev.:70.25/ Orig. GL Elev.: 36.20 RKB Hanger: 20.00 (Nabors 4ES) TOC @ 6,460 CTM 10/7/2025 2 TOC @ 6,700 CTM Future CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4 Surface 45.5 / L-80 / BTC 9.950 Surface 4,182 7-5/8" Intermediate 29.7 / L-80 / BTC-MOD 6.875 Surface 6,516 4-1/2 Liner A 12.6 / L-80 / IBT 3.958 6,182 9,905 4-1/2 Liner B 12.6 / L-80 / IBT 3.958 6,309 9,967 LINER DETAIL 4-1/2 OA Slotted Lnr 12.6 / L-80 / IBT 3.958 6,204 8,779 4-1/2 OA Slotted Lnr 12.6 / L-80 / IBT 3.958 8,945 9,859 4-1/2 OB Slotted Lnr 12.6 / L-80 / IBT 3.958 6,524 8,839 4-1/2 OB Slotted Lnr 12.6 / L-80 / IBT 3.958 9,173 9,922 JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 6,177 Baker Hook Wall, Hanger above 7 Window 2 6,194 Baker Hook Wall, Hanger below 7 Window 3 6,309 Baker Tie Back Sleeve 4 6,320 Baker ZXP Liner Top Packer 5 6,326 Baker 7 x 5 HMC Liner Hanger 6 9,859 OA Lateral Btm Baker 4-1/2 Pack-off Bushing 7 9,922 OB Lateral Btm Baker 4-1/2 Pack-off Bushing OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42 Hole 10-3/4" Cmt w/ 560 sx PF L, 475 sx Class G in 13-1/2 Hole 7-5/8 Cmt w/ 598 sx Class G in 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 500 MD Max Wellbore Angle = 82.4 deg @ 6,515 MD 69.0 deg @ 5,859 MD GENERAL WELL INFO API: 50-029-23227-00-00 Drilled and Cased by Doyon 14 11/01/2004 ESP Completion by Nabors 4ES 2/16/2005 ESP Completion by ASR#1 9/14/2016 Convert to JP by ASR#1 12/15/2019 Perf Add & Jet Pump Completion by ASR 3/3/2023 LATERAL WINDOW DETAIL Top of OA Window @ 6,182 MD; Bottom @ 6,194 MD; Angle @ top of window is 76 deg PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Schrader N 5,726 5,764 3,866 3,880 38 2/28/2023 Open Schrader N 5,798 5,902 3,892 3,929 104 2/28/2023 Open Schrader N 5,922 6,012 3,936 3,966 90 2/28/2023 Open WELLHEAD Tree 4-1/6 5M Wellhead FMC Tubing Hanger, 11 x 4-1/2 EUE TCII Kill Line Ram Size: 2-7/8" X 5" VBR Ram Size: Blind Rams Top of Cellar Box Choke Line 2-7/8" X 5" VBR Doyon 14 13 5/8" 5000# 13 5/8" 5000# HYDRIL 13 5/8" 5000# 13 5/8" 5000# Mud Cross HYDRIL HYDRIL 13 5/8" 5000# 13 5/8" 5000# Hydril "GK" 11", 5000# 13 5/8" 5000# 11", 5000# 11", 5000# 11", 5000# 11", 5000# 11", 5000# HCRHCR Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251016 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 2-36 50029220140000 190024 9/17/2025 BAKER SPN T40994 END 2-74 50029237850000 224024 9/22/2025 HALLIBURTON PATCH T40995 KU 12-17 50133205770000 208089 9/23/2025 YELLOWJACKET TEMP-CALIPER T40996 KU 24-7RD 50133203520100 205099 9/24/2025 YELLOWJACKET TEMP-CALIPER T40997 M-25 50733203910000 187086 8/31/2025 YELLOWJACKET CALIPER T40998 MPC-22A 50029224890100 195198 10/4/2025 READ CaliperSurvey T40999 MPF-61 50029225820000 195117 9/27/2025 READ CaliperSurvey T41000 MPU H-16 50029232270000 204190 10/6/2025 HALLIBURTON COILFLAG T41001 NIK SI17-SE2 50629235120000 214041 9/23/2025 HALLIBURTON IPROF T41002 NS-19 50029231220000 202207 9/8/2025 HALLIBURTON COILFLAG T41003 NS-19 50029231220000 202207 9/15/2025 HALLIBURTON COILFLAG T41003 ODSN-26 50703206420000 211121 10/7/2025 HALLIBURTON MFC24 T41004 PBU 01-25A 50029208740100 225056 9/13/2025 BAKER MRPM T41005 PBU 01-25A 50029208740100 225056 9/13/2025 HALLIBURTON RBT-COILFLAG T41005 PBU 01-31A 50029216260100 225070 9/22/2025 BAKER MRPM T41006 PBU 01-31A 50029216260100 225070 9/23/2025 HALLIBURTON RBT-COILFLAG T41006 PBU 05-09A 50029202540100 199014 9/18/2025 READ ArcherVIVID T41007 PBU 07-16A 50029208560100 201153 9/20/2025 HALLIBURTON RBT T41008 PBU 07-23C 50029216350300 225043 7/4/2025 BAKER MRPM T41009 PBU 13-24B 50029207390200 224087 9/18/2025 HALLIBURTON RBT T41010 PBU 15-11C 50029206530300 210163 9/6/2025 HALLIBURTON RBT T41011 PBU 15-49C 50029226510300 215129 9/10/2025 HALLIBURTON RBT T41012 PBU H-07B 50029202420200 225064 9/30/2025 HALLIBURTON RBT-COILFLAG T41013 PBU P19 L1 50029220946000 212056 10/3/2025 HALLIBURTON RBT T41014 PBU S-14A 50029208040100 204071 9/25/2025 HALLIBURTON RBT T41015 PBU V-105 50029230970000 202131 9/30/2025 HALLIBURTON RMT3D T41016 Please include current contact information if different from above. MPU H-16 50029232270000 204190 10/6/2025 HALLIBURTON COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.20 13:17:06 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Reservoir Abandonment 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,967'N/A Casing Collapse Conductor N/A Surface 2,090psi Intermediate 4,790psi Liner 7,500psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT H-16 MILNE POINT SCHRADER BLUFF OIL N/A 4,006' 9,967' 4,006' 662 N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/3/2025 7-5/8" x 4.5" Tri Point, 7-5/8" x 4.5" LTC Hyd Iso & Baker ZXP LTP and N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 204-190 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23227-00-00 Hilcorp Alaska LLC C.O 477B Length Size Proposed Pools: 112' 112' 12.6# / L-80 / TSH 521 TVD Burst 6,081' 8,430psi MD N/A 8,430psi 3,580psi 6,890psi 3,139' 4,063' 4,010' 4,182' 6,516' 112' 20" 10-3/4" 7-5/8" 4,182' 4-1/2"3,723' 6,516' 9,905' See Schematic 3,658' See Schematic 4-1/2" 4,006'4-1/2" 5,580 MD/ 3,813 TVD, 6,054 MD/ 3,977 TVD & 6,320 MD/ 4,036 TVD and N/A Erik Nelson Erik.Nelson@hilcorp.com 907-564-5277 9,967' Perforation Depth MD (ft): Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Scott Pessetto (9864) DN: cn=Scott Pessetto (9864) Date: 2025.09.19 11:43:30 - 08'00' Scott Pessetto (9864) 325-571 By Grace Christianson at 3:16 pm, Sep 19, 2025 SFD 9/23/2025 if the contingency plan in case the OA lateral can't be entered is done post work well status will be suspended, form required will be a 10-407, and the suspension expiration date will apply. 10-404 September 30, 2030 SFD 9/29/2025 * AOGCC witness slick line tag and pressure test of TOC ~5535' MD if contingency reservoir abandonment. CMIT T x IA to 1500 psi. 24 hour notice. MGR01OCT25 DSR-9/24/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.10.02 10:59:05 -08'00'10/02/25 RBDMS JSB 100625 ®ôīīϙbÍıôϡ aϙFϱ͕͐IϙbŪıæôŘϡ ͔͏ϱ͏͑͘ϱ͖͑͒͑͑ϱ͏͏ϱ͏͏ ŪŘŘôĲťϙťÍťŪŜϡ IϙVϙŘĺîŪèôŘ ĖČϡ ĺĖīôîϙŪæĖĲČ (ŜťĖıÍťôîϙťÍŘťϙ"Íťôϡ ͐͏ϯ͒ϯϙ͑͏͔͑(ŜťĖıÍťôîϙ"ŪŘÍťĖĺĲϡ ͒ϙ"ÍƅŜ ôČŪīÍťĺŘƅϙĺĲťÍèťϡ ĺıϙ>ĺŪťŜ ôŘıĖťϙťĺϙ"ŘĖīīϙbŪıæôŘϡ ͑͏͓ϱ͐͘͏ >ĖŘŜťϙÍīīϙ(ĲČĖĲôôŘϡ (ŘĖħϙϟϙbôīŜĺĲ ϼ͘͏͖Ͻϙ͔͕͓ϙϳϙ͔͖͖͑ϙϼiϽ ϼ͘͏͖Ͻϙ͘͏͒ϙϳϙ͖͓͏͖ϙϼϽ ôèĺĲîϙÍīīϙ(ĲČĖĲôôŘϡ ÍƅīĺŘϙ®ôīīıÍĲ ϼ͘͏͖Ͻϙ͖͖͖ϙ ϳϙ͓͓͗͘ϙϼiϽ ϼ͘͏͖Ͻϙ͓͖͘ϙϳϙ͔͒͒͘ϙϼϽ ŪŘŘôĲťϙĺťťĺıϙFĺīôϙŘôŜŜŪŘôϙϼFϽϡ ͓͓͐͗ϙŕŜĖϙЬϙ͔͔͐͒ϱċťϙa"ϙϼ͖͖͒͗ϱċťϙ«"Ͻ ͑͗ϙŪČϙ͑͏͔͑ϙиϙ͖ϟ͔ϙ(a®ϙϼ͗ϟ͔ϙX®>Ͻ aÍƄϙĺťôĲťĖÍīϙŪŘċÍèôϙŘôŜŜŪŘôϙϼaϽϡ ͕͕͑ϙŕŜĖ @ÍŜϙĺīŪıĲϙ@ŘÍîĖôĲťϙϼ͏ϟ͐ϙŕŜĖϯċťϽ aÍƄϙ"ôŽĖÍťĖĺĲϡ ôīôŽÍĲťϟťĺϟ®ôīīſĺŘħ ͓͘ϟ͖еϙЬϙ͕͗͗͘ϱċťϙa"ϙϼiϙ[ÍťôŘÍīϽϙFϱ͕͐ ͓͘ϟ͔еϙЬϙ͔͗͑͘ϱċťϙa"ϙϼiϙ[ÍťôŘÍīϽϙFϱ͕͐[͐ aÍƄϙ"ĺČīôČϡ ôīôŽÍĲťϟťĺϟ®ôīīſĺŘħ ͐͐ϟ͔еϯ͐͏͏ϱċťϙЬϙ͗͒͐͘ϱċťϙa"ϙϼiϙ[ÍťôŘÍīϽϙFϱ͕͐ ͕͐ϟ͕еϯ͐͏͏ϱċťϙЬϙ͕͑͒͒ϱċťϙa"ϙϼiϙ[ÍťôŘÍīϽϙFϱ͕͐[͐ aĖĲϙI"ϡ ôīôŽÍĲťϟťĺϟ®ôīīſĺŘħ ͒ϟ͖͕͏ϱĖĲϙI"ϙ³bϱĲĖŕŕīôϙŕŘĺƱīôϙÍťϙ͕͏͕͔ϱċťϙa" Xϡ ͑͏ϟ͏͏ϱċťϙϼbÍæĺŘŜϙ͓(Ͻ ŘĖôċϙ®ôīīϙŪııÍŘƅϡ aϙFϱ͕͐ϙſÍŜϙîŘĖīīôîϙĖĲϙ͑͏͏͓ϙÍĲîϙèĺıŕīôťôîϙÍŜϙÍϙîŪÍīϙīÍťôŘÍīϙèēŘÍîôŘϙīŪƯϙiϙÍĲîϙiϙŕŘĺîŪèôŘϟϙϙIťϙ ŕŘĺîŪèôîϙſĖťēϙÍĲϙ(ϙŪĲťĖīϙ͑͏͐͘ϙſēôĲϙϙſĺŘħôîϙťēôϙſôīīϙĺŽôŘϙťĺϙÍîîϙŕôŘċĺŘÍťĖĺĲŜϙĖĲťĺϙťēôϙèēŘÍîôŘϙbϱ ŜÍĲîϟϙϙēôϙèēŘÍîôŘϙīŪƯϙbϱŜÍĲîŜϙſôŘôϙèĺŽôŘôîϙſĖťēϙŜèŘôôĲŜϙÍĲîϙÍϙŜīĖîĖĲČϙŜīôôŽôϙſÍŜϙŘŪĲϙÍæĺŽôϙťēôϙŪŕŕôŘϙ ŕŘĺîŪèťĖĺĲϙŕÍèħôŘϙŜĺϙaϙFϱ͕͐ϙèĺŪīîϙæôϙīĖċťôîϙſĖťēϙÍϙŘôŽôŘŜôϙèĖŘèŪīÍťĖĺĲϙĤôťϙŕŪıŕϟϙϙēôϙſôīīϙēÍŜϙæôôĲϙ ĺĲīĖĲôϙŪĲťĖīϙVŪĲôϙ͑͏͔͑ϙſēôĲϙĖťϙſÍŜϙŜēŪťϱĖĲϙċĺŘϙĺĲČĺĖĲČϙŜŪŘċÍèôϙſĺŘħϙÍťϙFϱÍîϟ bĺťôŜϙôČÍŘîĖĲČϙŪŘŘôĲťϙ®ôīīæĺŘôϙĺĲîĖťĖĺĲϡ -aIϱIϙťĺϙ͔͕͒͑ϙŕŜĖϙϳϙÍŜŜôîϙĺĲϙ͏͒ϯ͏͘ϯ͔͑ iæĤôèťĖŽôϡ īÍèôϙèôıôĲťϙÍèŘĺŜŜϙťēôϙīĺſôŘϙѹ͖͔҇ϙĺċϙôÍèēϙīÍťôŘÍīϙÍŜϙıôÍŜŪŘôîϙċŘĺıϙťēôϙťĺôϟϙϙFϱ͕͐ЍŜϙīÍťôŘÍīŜϙèŘĺŜŜèŪťϙťēôϙ ŕīÍĲĲôîϙŘôîôŽôīĺŕıôĲťϙŕÍťťôŘĲϙċĺŘϙÍϙīĖĲôϙîŘĖŽôϙϼĖĲĤôèťĺŘϠϙŕŘĺîŪèôŘϠϙĖĲĤôèťĺŘϽϙċĺŘϙťēôϙèēŘÍîôŘϟϙϙ -[ÍƅϙĖĲϙèôıôĲťϙĖĲϙťēôϙiϙīÍťôŘÍīϙċŘĺıϙѷ͕͗͏͏ϙϳϙ͑͑͘͘ϱċťϙa" -[ÍƅϙĖĲϙèôıôĲťϙĖĲϙťēôϙiϙīÍťôŘÍīϙċŘĺıϙѷ͕͖͏͏ϙϳϙ͔͗͘͘ϱċťϙa" ®ôīīϡ aϙFϱ͕͐ "ϡ ͑͏͓ϱ͐͘͏ Iϡ ͔͏ϱ͏͑͘ϱ͖͑͒͑͑ϱ͏͏ϱ͏͏ "Íťôϡ ͐͗ϙôŕϙ͑͏͔͑ o IċϙťēôϙiϙīÍťôŘÍīϙèÍĲĲĺťϙæôϙôĲťôŘôîϙĖĲťĺϠϙŪīīēôÍîϙèôıôĲťϙŽĖÍϙċŪīīæĺŘôϙŕŪıŕĖĲČϙťĺϙĖŜĺīÍťôϙťēô èēŘÍîôŘϙċĺŘıÍťĖĺĲϟ ŘôϱĖČϙiŕôŘÍťĖĺĲŜϙϼŪĲîŘĖôîϙĺŘϙbĺĲϱŪĲîŘĖôîϙ®ĺŘħϽϡ īĖèħīĖĲôϙ ͐Ͻ ŪīīϙVϙċŘĺıϙ͔͓͔͑ϱċťϙa" ͑Ͻ ēĖċťϙ"ϙèīĺŜôîϟϙϙaIϱIϙťĺϙ͐͏͏͏ϙŕŜĖϙťĺϙèĺĲƱŘıϙèīĺŜôî ͒Ͻ "ŘĖċťϙťĺϙîôŽĖÍťĖĺĲ ®iϙŘĺèôîŪŘôϙϼŪĲîŘĖôîϙĺŘϙbĺĲϱŪĲîŘĖôîϙ®ĺŘħϽϡ ĺĖīϙŪæĖĲČ ͐Ͻ aIϙϟϙϙϙ(ϙÍèèĺŘîĖĲČīƅϙſĖťēϙŘôŜŕôèťϙťĺϙťēôϙèĺĖīϙſôôħīƅϙiϙťôŜťĖĲČ ͑Ͻ IFϙſϯϙ͐ϟ͖͔ЋϙèĺĖīϙſĖťēϙîŪÍīϙ«ϠϙèĺĖīϙîĖŜèĺĲĲôèťϠϙıôıĺŘƅϙ@ϯ[ϠϙÍĲîϙĤôťϙŜſĖŘīϙĲĺƏƏīôϙ ͒Ͻ ťϙѷ͔͔͏͏ϱċťϙa"ϙèĺıôϙĺĲīĖĲôϙſĖťēϙŕŪıŕŜϙſēĖīôϙťÍħĖĲČϙŘôťŪŘĲŜϙťĺ ϙċĺŘıÍťĖĺĲϟϙϙôČĖĲϙ>iϯϙ>īŪƯϱĲϱ ŜťŪƯϙťĺϙ"ϟ ÍϽ ĲťĖèĖŕÍťĖĲČϙťĺϙæôϙôĲťôŘĖĲČϙĖĲťĺϙťēôϙīĺſôŘϙiϙīÍťôŘÍī æϽ iæťÍĖĲϙèĺĲťĖĲŪĺŪŜϙŜĖĲČīôϙŕÍŜŜϙċŘĺıϙ͕͔͐͑ϙϳϙ͕͓͏͏ϱċťϙa"ϙĖċϙŕĺŜŜĖæīô èϽ ôŘċĺŘıϙϙſôĖČēťŜϙÍŜϙŜôôĲϙƱťϙæƅϙ®a ͓Ͻ ϙťĺϙѷ͕͔͐͑ϱċťϙa"ϟϙϙôŘċĺŘıϙîĺſĲϙīĺČϙťĺϙѷ͕͓͏͏ϱċťϙa"ϟ ͔Ͻ iiFϙťĺϙŜŪŘċÍèôϙÍĲîϙîĺſĲīĺÍîϙıôıĺŘƅϙ@ϯ[ ÍϽ ĺıŕÍŘôϙťēôϙ͑ϙīĺČČĖĲČϙŘŪĲŜϙſϯϙ@ϯ[ϙťĺϙŽôŘĖċƅϙſēĖèēϙīÍťôŘÍīϙ æôĖĲČϙôĲťôŘôîϙϼiϙĺŘϙiϽϙÍĲîϙ ſēôťēôŘϙæĺťēϙŘŪĲŜϙſôŘôϙèĺĲŜĖŜťôĲťϟϙϙĺĲťÍèťϙi(ϙÍĲîϙ@ôĺϙXÍťĖôϙŪēĲÍϙ ϼħÍťēÍŘĖĲôϟèŪĲēÍЬēĖīèĺŘŕϟèĺıϙĺŘϙϼ͘͏͖Ͻϙ͗͏͑ϙϳϙ͏͏͖͗ϽϙťĺϙèĺĲƱŘıϙſēĖèēϙīÍťôŘÍīϙſÍŜϙôĲťôŘôîϟϙϙ æϽ ĺĲťĖĲČôĲèƅϧϙϙϼIċϙôĲťŘƅϙĖĲťĺϙťēôϙiϙϼŪŕŕôŘϙīÍťôŘÍīϽϽϙ ĖϽ aϙÍħôŘϙēƅîŘÍŪīĖèϙĺŘĖôĲťĖĲČϙFϙſϯϙīĺČČĖĲČϙťĺĺīŜϙÍĲîϙŘôϱÍťťôıŕťϙŪĲťĖīϙÍæīôϙťĺϙôĲťôŘϙĖĲťĺϙ ťēôϙiϙīÍťôŘÍīϙϼīĺſôŘϙīÍťôŘÍīϽ ĖĖϽ ôèĺĲƱČŪŘôϙFϙťĺϙıÍťèēϙťēôϙèĺĲƱČŪŘÍťĖĺĲϙťēÍťϙôĲťôŘôîϙĖĲťĺϙťēôϙiϙīÍťôŘÍīϙÍĲîϙIFϙſϯϙ >iϙFϙÍĲîϙŕôŘċĺŘıϙ>iϯϙ>īŪƯϱĲϱŜťŪƯϙťĺϙ"ϙĺċϙťēôϙiϙīÍťôŘÍī ͕Ͻ aϙèôıôĲťĖĲČϙFϙÍĲîϙIFϙťĺϙôĲťôŘϙĖĲťĺϙťēôϙiϙīÍťôŘÍīϟϙϙiĲèôϙÍťϙ"ϠϙıĖƄϙ͓͖ϟ͔ϙææīŜϙĺċϙèôıôĲťϙ ÍĲîϙŕŪıŕϙîĺſĲϙťēôϙèĺĖīϙťÍħĖĲČϙŘôťŪŘĲŜϙťĺϙċĺŘıÍťĖĺĲϟϙϙiĲèôϙèôıôĲťϙĖŜϙÍťϙťēôϙĲĺƏƏīôϙīÍƅϙĖĲϙ èôıôĲťϙ͐ϡ͐ϙċŘĺıϙ"ϙťĺϙѷ͕͔͘͏ϱċťϙa"ϙÍŜϙŕôŘϙ(ϙıÍĲŪÍīϙŘôèĺııôĲîÍťĖĺĲŜϟ bi(ϡϙϙiϙ[ÍťôŘÍīϙ«ĺīŪıôϡϙϼ͑͑͘͘ϙϳϙ͕͗͏͏ϙѱϙ͒͐͑͑ϱċťϙa"ϽϙƄϙ͏ϟ͏͔͐͑ϙæŕċϙѱϙ ͓͖ϟ͔ϙææīŜ ͖Ͻ iiFϙÍĲîϙèĖŘèŪīÍťôϙÍŜϙĲôôîôîϙťĺϙèīôÍŘϙèĺĖīϙÍĲîϙŘôŕīÍèôϙŕĖŕôϙîĖŜŕīÍèôıôĲťϟϙϙ®iϙťĺϙŘôÍèēϙ èĺıŕŘôŜŜĖŽôϙŜťŘôĲČťēϟ ͗Ͻ aϙèôıôĲťĖĲČϙFϙſϯϙÍħôŘϙēƅîŘÍŪīĖèϙĺŘĖôĲťĖĲČϙFϟϙϙIFϙÍĲîϙĺ ŘĖôĲťϙÍŜϙĲôôîôîϙťĺϙôĲťôŘϙťēôϙiϙ īÍťôŘÍīϟ bi(ϡϙϙiϙĖĲϙťēôϙiϙīÍťôŘÍīϙŜēĺŪīîϙæôϙÍťϙѷ͕͗͏͏ϱċťϙa" ÍϽ IċϙôĲťŘƅϙĖĲťĺϙťēôϙiϙīÍťôŘÍīϙĖŜϙŪĲÍèēĖôŽÍæīôϙŜôôϙЊ ĺĲťĖĲČôĲèƅϧϙIċϙŪŕŕôŘϙiϙīÍťôŘÍīϙèÍĲĲĺťϙæôϙ ôĲťôŘôîЋϙÍťϙťēôϙôĲîϙĺċϙťēĖŜϙŕŘĺèôîŪŘôϙϙ ͘Ͻ iĲèôϙÍťϙ"ϠϙıĖƄϙ͓͗ϙææīŜϙĺċϙèôıôĲťϙÍĲîϙŕŪıŕϙîĺſĲϙťēôϙèĺĖīϙťÍħĖĲČϙŘôťŪŘĲŜϙťĺϙċĺŘıÍťĖĺĲϟϙϙ iĲèôϙèôıôĲťϙĖŜϙÍťϙťēôϙĲĺƏƏīôϙīÍƅϙĖĲϙèôıôĲťϙ͐ϡ͐ϙċŘĺıϙ"ϙťĺϙѷ͕͖͏͏ϱċťϙa"ϙÍŜϙŕôŘϙ(ϙıÍĲŪÍīϙ ŘôèĺııôĲîÍťĖĺĲŜϟ ®ôīīϡ aϙFϱ͕͐ "ϡ ͑͏͓ϱ͐͘͏ Iϡ ͔͏ϱ͏͑͘ϱ͖͑͒͑͑ϱ͏͏ϱ͏͏ "Íťôϡ ͐͗ϙôŕϙ͑͏͔͑ ÍϽ iϙ[ÍťôŘÍīϙ«ĺīŪıôϡϙϼ͔͗͘͘ϙϳϙ͕͖͏͏ϙѱϙ͔͒͐͘ϱċťϙa"ϽϙƄϙ͏ϟ͏͔͐͑ϙæŕċϙѱϙ͓͗ϙææīŜ ͐͏Ͻ iiFϙÍĲîϙèĖŘèŪīÍťôϙÍŜϙĲôôîôîϙťĺϙèīôÍŘϙèĺĖīϙÍĲîϙŘôŕīÍèôϙŕĖŕôϙîĖŜŕīÍèôıôĲť ͐͐Ͻ "aiϙĺĖīϙĲĖťϟ ĺĲťĖĲČôĲèƅϧϙϙIċϙŪŕŕôŘϙiϙīÍťôŘÍīϙèÍĲĲĺťϙæôϙôĲťôŘôî ͐Ͻ "aiϙĺĖīϙŪĲĖť (ϱ[ĖĲô ͑Ͻ ϙ([ϙŪĲĖťϙÍĲîϙϙ(ϟϙ ͒Ͻ ôťϙ͓ϱΫЋϙIĲťôŘŽôĲťĖĺĲīôŜŜϙгϙÍťϙѷ͔͕͏͏ϱċťϙa" ͓Ͻ "aiϙ(ϱ[ĖĲôϙ >ŪīīæĺŘô ͔Ͻ ϙèôıôĲťôŘŜϟϙ(ŜťÍæīĖŜēϙĖĲĤôèťĖŽĖťƅϙĖĲťĺϙťēôϙèēŘÍîôŘϙŜÍĲîŜϟϙϙ ͕Ͻ ŪīīēôÍîϙ͕͑ϙææīŜϙϼ͔͏҇ϙôƄèôŜŜϽϙĺċϙ͔͐ϟ͗ŕŕČϙèôıôĲťϙťēŘĺŪČēϙťēôϙèôıôĲťϙŘôťÍĖĲôŘ bi(ϡϙϙ®ôЍīīϙīĖħôīƅϙſÍĲťϙťĺϙèĺĲŜĖîôŘϙÍîîĖĲČϙ[aϙťĺϙÍϙŜŕôèĖƱôîϙŕĺŘťĖĺĲϙĺċϙťēôϙƱŘŜťϙŕÍŘťϙĺċϙťēĖŜϙ èôıôĲťϙŜīŪŘŘƅ «ĺīŪıôώôèťĖĺĲ ĺŕώ"ôŕťēώϼa"Ͻώ ĺťťĺıώ"ôŕťēώϼa"Ͻ [ôĲČťē ϼċťϽ ÍŕÍèĖťƅώϼæŕċϽ «ĺīŪıô ϼææīŜϽ ͓ϱ͐ϯ͑ГώŜèŘôôĲŜ ͔͕͏͏͔͖͏͖͐͏͖͏ϟ͏͔͐͑͐ϟ͕͒ ͖ϱ͔ϯ͗ГώƄώ͓ϱ͐ϯ͑ГώŜèŘôôĲŜ ͔͖͏͖ ͕͏͐͑ ͒͏͔ ͏ϟ͏͕͑ ͖ϟ͒͘ ͓ϱ͐ϯ͑ГώťŪæĖĲČώťÍĖī ͕͏͔͓͕͏͕͔͐͘͏ϟ͏͔͐͑͏ϟ͑͒ ͖ϱ͔ϯ͗ГώèÍŜĖĲČ ͕͏͕͘ ͕͒͑͏ ͔͑͐ ͏ϟ͏͓͔͘ ͐͐ϟ͔͑ ͓ϱ͐ϯ͑ГώiώīÍťôŘÍī ͕͖͖͕͔͐͗͏͕͖͒͏ϟ͏͔͐͑͐͏ϟ͑͒ ͓ϱ͐ϯ͑ГώiώīÍťôŘÍī ͕͒͑͏ ͕͔͘͏ ͕͒͏ ͏ϟ͏͔͐͑ ͘ϟ͔͗ ĺťÍī ͓͐ϟ͐͐ ͖Ͻ "ŘĺŕϙèôıôĲťϙŘôťÍĖĲôŘϙîÍŘťϙſϯϙ͐ϙææīϙĺċϙèôıôĲťϙīôċťϟϙϙēÍŜôϙſϯϙ͔͏ϙææīŜϙĺċϙŕŘĺîŪèôîϙſÍťôŘϙÍĲîϙ͓͒ϙ ææīŜϙĺċϙîĖôŜôīϟϙϙīĺſϙîĖŜŕīÍèôıôĲťϙŘÍťôϙťĺϙѴ͑ϙæŕıϙÍĲîϙæŪıŕϙťēôϙŕīŪČϟ ͗Ͻ "aiϙèôıôĲťôŘŜ ťťÍèēıôĲťŜϡ ͐Ͻ ŪŘŘôĲťϙ®ôīīæĺŘôϙèēôıÍťĖè ͑Ͻ ŘĺŕĺŜôîϙ®ôīīæĺŘôϙèēôıÍťĖè ͒Ͻ ϙi * If reservoir suspension, AOGCC to witness tag and pressure test (slick line tag) CMIT T x IA to 1500 psi. _____________________________________________________________________________________ Revised By: RJL 7/24/2 024 SCHEMATIC Milne Point Unit Well: MPU H-16 Last Completed: 9/14/2016 PTD: 204-190 13 14 TD = 9,967’ (MD) / TD = 4,006’(TVD) 20” 7-5/8” 7 8 &9 10-3/4” 1011 12 “OA” Lateral PBTD = 9,967’(MD) / PBTD =4,006’(TVD) “OB” Lateral 1 3 5 4 2 6 Orig. KB Elev.: 70.25’/ Orig. GL Elev.: 36.20’ RKB – Hanger: 20.00’ (Nabors 4ES) CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / L-80 / BTC 9.950 Surface 4,182’ 7-5/8" Intermediate 29.7 / L-80 / BTC-MOD 6.875 Surface 6,516’ 4-1/2” Liner “A” 12.6 / L-80 / IBT 3.958 6,182’ 9,905’ 4-1/2” Liner “B” 12.6 / L-80 / IBT 3.958 6,309’ 9,967’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TSH 521 3.958 Surface 6,081’ LINER DETAIL 4-1/2” OA Slotted Lnr 12.6 / L-80 / IBT 3.958 6,204’ 8,779’ 4-1/2” OA Slotted Lnr 12.6 / L-80 / IBT 3.958 8,945’ 9,859’ 4-1/2” OB Slotted Lnr 12.6 / L-80 / IBT 3.958 6,524’ 8,839’ 4-1/2” OB Slotted Lnr 12.6 / L-80 / IBT 3.958 9,173’ 9,922’ JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 5,452’ Hal Sliding Sleeve XD 2 5,513’ Baker BHPG – 3,787’ TVD 3 5,580’ 7-5/8 X 4.5" Tri Point packer 4 5,646’ X-Nipple w/ RHC Plug 5 5,707’ 250 Micron Screens w/ Centralizer - 337’ 6 6,054’ 7-5/8" x 4-1/2" LTC HYD ISOLATION PACKER 7 6,069’ 4-1/2” LTC X-Nipple w/ WLEG – Btm @ 6,081 8 6,177’ Baker Hook Wall, Hanger above 7” Window 9 6,194’ Baker Hook Wall, Hanger below 7” Window 10 6,309’ Baker Tie Back Sleeve 11 6,320’ Baker ZXP Liner Top Packer 12 6,326’ Baker 7” x 5” HMC Liner Hanger 13 9,859’ OA Lateral Btm Baker 4-1/2” Pack-off Bushing 14 9,922’ OB Lateral Btm Baker 4-1/2” Pack-off Bushing OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 560 sx PF “L”, 475 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 598 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD Max Wellbore Angle = 82.4 deg @ 6,515’ MD 69.0 deg @ 5,859’ MD WELLHEAD Tree 3-1/8” 5M Cameron Wellhead FMC Tubing Hanger, 11” x 2-7/8” EUE Top & Btm GENERAL WELL INFO API: 50-029-23227-00-00 Drilled and Cased by Doyon 14 – 11/01/2004 ESP Completion by Nabors 4ES – 2/16/2005 ESP Completion by ASR#1 – 9/14/2016 Convert to JP by ASR#1 – 12/15/2019 Perf Add & Jet Pump Completion by ASR – 3/3/2023 LATERAL WINDOW DETAIL Top of “OA” Window @ 6,182’ MD; Bottom @ 6,194’ MD; Angle @ top of window is 76 deg PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Schrader “N” 5,726’ 5,764’ 3,866’ 3,880’ 38 2/28/2023 Open Schrader “N” 5,798’ 5,902’ 3,892’ 3,929’ 104 2/28/2023 Open Schrader “N” 5,922’ 6,012’ 3,936’ 3,966’ 90 2/28/2023 Open _____________________________________________________________________________________ Revised By: TDF 9/19/2 025 PROPOSED Milne Point Unit Well: MPU H-16 Last Completed: 9/14/2016 PTD: 204-190 14 15 TOC @ ± 6,700’ TOC @ ± 6,800’TD =9,967’(MD) / TD = 4,006’(TVD) 20” 7-5/8” 8 9 & 10 10-3/4” 1112 13 “OA” Lateral PBTD =9,967’ (MD) / PBTD =4,006’(TVD) “OB” Lateral 1 3 6 5 2 7 Orig. KB Elev.: 70.25’/ Orig. GL Elev.: 36.20’ RKB – Hanger: 20.00’ (Nabors 4ES) 4 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / L-80 / BTC 9.950 Surface 4,182’ 7-5/8" Intermediate 29.7 / L-80 / BTC-MOD 6.875 Surface 6,516’ 4-1/2” Liner “A” 12.6 / L-80 / IBT 3.958 6,182’ 9,905’ 4-1/2” Liner “B” 12.6 / L-80 / IBT 3.958 6,309’ 9,967’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TSH 521 3.958 Surface 6,081’ LINER DETAIL 4-1/2” OA Slotted Lnr 12.6 / L-80 / IBT 3.958 6,204’ 8,779’ 4-1/2” OA Slotted Lnr 12.6 / L-80 / IBT 3.958 8,945’ 9,859’ 4-1/2” OB Slotted Lnr 12.6 / L-80 / IBT 3.958 6,524’ 8,839’ 4-1/2” OB Slotted Lnr 12.6 / L-80 / IBT 3.958 9,173’ 9,922’ JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 5,452’ Hal Sliding Sleeve XD 2 5,513’ Baker BHPG –3,787’ TVD 3 5,580’ 7-5/8 X 4.5" Tri Point packer 4 ±5,600’ 4-1/2” Interventionless CCR 5 5,646’ X-Nipple w/ RHC Plug 6 5,707’ 250 Micron Screens w/ Centralizer - 337’ 7 6,054’ 7-5/8" x 4-1/2" LTC HYD ISOLATION PACKER 8 6,069’ 4-1/2” LTC X-Nipple w/ WLEG –Btm @ 6,081 9 6,177’ Baker Hook Wall, Hanger above 7” Window 10 6,194’ Baker Hook Wall, Hanger below 7” Window 11 6,309’ Baker Tie Back Sleeve 12 6,320’ Baker ZXP Liner Top Packer 13 6,326’ Baker 7” x 5” HMC Liner Hanger 14 9,859’ OA Lateral Btm Baker 4-1/2” Pack-off Bushing 1 9,922’ OB Lateral Btm Baker 4-1/2” Pack-off Bushing OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 560 sx PF “L”, 475 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 598 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD Max Wellbore Angle = 82.4 deg @ 6,515’ MD 69.0 deg @ 5,859’ MD WELLHEAD Tree 3-1/8” 5M Cameron Wellhead FMC Tubing Hanger, 11” x 2-7/8” EUE Top & Btm GENERAL WELL INFO API: 50-029-23227-00-00 Drilled and Cased by Doyon 14 –11/01/2004 ESP Completion by Nabors 4ES –2/16/2005 ESP Completion by ASR#1 –9/14/2016 Convert to JP by ASR#1 –12/15/2019 Perf Add & Jet Pump Completion by ASR –3/3/2023 LATERAL WINDOW DETAIL Top of “OA” Window @ 6,182’ MD; Bottom @ 6,194’ MD; Angle @ top of window is 76 deg PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Schrader “N” 5,726’ 5,764’ 3,866’ 3,880’ 38 2/28/2023 Open Schrader “N” 5,798’ 5,902’ 3,892’ 3,929’ 104 2/28/2023 Open Schrader “N” 5,922’ 6,012’ 3,936’ 3,966’ 90 2/28/2023 Open _____________________________________________________________________________________ Revised By: TDF 9/24/2025 CONTINGENCY Milne Point Unit Well: MPU H-16 Last Completed: 9/14/2016 PTD: 204-190 14 15 TD =9,967’(MD) / TD = 4,006’(TVD) 20” 7-5/8” 8 9 & 10 TOC Calculated @ ±3,835’ 10-3/4” 1112 13 “OA” Lateral PBTD =9,967’ (MD) / PBTD =4,006’(TVD) 11 “OB” Lateral 1 3 6 5 2 7 Orig. KB Elev.: 70.25’/ Orig. GL Elev.: 36.20’ RKB – Hanger: 20.00’ (Nabors 4ES) 4 TOC Calculated @ ±5,535’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / L-80 / BTC 9.950 Surface 4,182’ 7-5/8" Intermediate 29.7 / L-80 / BTC-MOD 6.875 Surface 6,516’ 4-1/2” Liner “A” 12.6 / L-80 / IBT 3.958 6,182’ 9,905’ 4-1/2” Liner “B” 12.6 / L-80 / IBT 3.958 6,309’ 9,967’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TSH 521 3.958 Surface 6,081’ LINER DETAIL 4-1/2” OA Slotted Lnr 12.6 / L-80 / IBT 3.958 6,204’ 8,779’ 4-1/2” OA Slotted Lnr 12.6 / L-80 / IBT 3.958 8,945’ 9,859’ 4-1/2” OB Slotted Lnr 12.6 / L-80 / IBT 3.958 6,524’ 8,839’ 4-1/2” OB Slotted Lnr 12.6 / L-80 / IBT 3.958 9,173’ 9,922’ JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 5,452’ Hal Sliding Sleeve XD 2 5,513’ Baker BHPG –3,787’ TVD 3 5,580’ 7-5/8 X 4.5" Tri Point packer 4 ±5,600’ 4-1/2” Interventionless CCR 5 5,646’ X-Nipple w/ RHC Plug 6 5,707’ 250 Micron Screens w/ Centralizer - 337’ 7 6,054’ 7-5/8" x 4-1/2" LTC HYD ISOLATION PACKER 8 6,069’ 4-1/2” LTC X-Nipple w/ WLEG –Btm @ 6,081 9 6,177’ Baker Hook Wall, Hanger above 7” Window 10 6,194’ Baker Hook Wall, Hanger below 7” Window 11 6,309’ Baker Tie Back Sleeve 12 6,320’ Baker ZXP Liner Top Packer 13 6,326’ Baker 7” x 5” HMC Liner Hanger 14 9,859’ OA Lateral Btm Baker 4-1/2” Pack-off Bushing 1 9,922’ OB Lateral Btm Baker 4-1/2” Pack-off Bushing OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 560 sx PF “L”, 475 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 598 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD Max Wellbore Angle = 82.4 deg @ 6,515’ MD 69.0 deg @ 5,859’ MD WELLHEAD Tree 3-1/8” 5M Cameron Wellhead FMC Tubing Hanger, 11” x 2-7/8” EUE Top & Btm GENERAL WELL INFO API: 50-029-23227-00-00 Drilled and Cased by Doyon 14 –11/01/2004 ESP Completion by Nabors 4ES –2/16/2005 ESP Completion by ASR#1 –9/14/2016 Convert to JP by ASR#1 –12/15/2019 Perf Add & Jet Pump Completion by ASR –3/3/2023 LATERAL WINDOW DETAIL Top of “OA” Window @ 6,182’ MD; Bottom @ 6,194’ MD; Angle @ top of window is 76 deg PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Schrader “N” 5,726’ 5,764’ 3,866’ 3,880’ 38 2/28/2023 Open Schrader “N” 5,798’ 5,902’ 3,892’ 3,929’ 104 2/28/2023 Open Schrader “N” 5,922’ 6,012’ 3,936’ 3,966’ 90 2/28/2023 Open New Plugback Esets 7/26/2024 Well Name API Number PTD Number ESet Number Date CD2-09 PB1 50-103-20496-70-00 204-129 T39280 2-22-2006 CD2-10 PB1 50-103-20473-70-00 203-195 T39281 2-22-2006 CD2-28 PB1 50-103-20435-70-00 202-217 T39282 2-22-2006 CD2-40 PB1 50-103-20464-70-00 203-126 T39283 2-22-2006 CD2-43 PB1 50-103-20474-70-00 203-197 T39284 10-29-2004 Kasilof South 1 PB1 50-133-20520-70-00 202-256 T39285 5-16-2006 E-20AL1 PB1 50-029-22561-70-00 204-055 T39286 2-22-2006 F-57A PB1 50-029-22747-70-00 203-167 T39287 2-22-2006 G-18 PB1 50-029-23194-70-00 204-020 T39288 2-22-2006 H-16 PB2 50-029-23227-71-00 204-190 T39289 1-27-2005 I-17L1 PB1 50-029-23212-70-00 204-099 T39290 2-22-2006 S-01 PB1 50-029-23141-70-00 203-034 T39291 2-22-2006 S-08 PB1 50-029-23168-70-00 203-123 T39292 8-29-2003 S-18 PB1 50-029-23133-70-00 202-242 T39293 2-22-2006 06-23B PB1 50-029-20808-70-00 204-087 T39294 2-22-2006 07-14B PB1 50-029-20339-70-00 203-142 T39295 2-22-2006 15-38A PB1 50-029-22496-70-00 203-016 T39296 2-22-2006 C-16A PB1 50-029-20438-70-00 203-084 T39297 2-22-2006 D-28B PB1 50-029-21556-70-00 209-089 T39298 8-20-2012 E-01A PB1 50-029-20166-70-00 203-033 T39299 2-22-2006 K-03B PB1 50-029-21011-72-00 204-115 T39300 2-22-2006 NK-62A PB1 50-029-22852-70-00 203-047 T39301 2-22-2006 S-102L1 PB1 50-029-22972-70-00 203-156 T39302 10-26-2005 W-09A PB1 50-029-21947-70-00 204-102 T39303 2-22-2006 H-16 PB2 50-029-23227-71-00 204-190 T39289 1-27-2005 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Jet Pump Completion Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,967 feet N/A feet true vertical 4,006 feet N/A feet Effective Depth measured 9,967 feet 5,580 & 6,320 feet true vertical 4,006 feet 3,813 & 4,036 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / TSH 521 6,081' 3,984' 7-5/8" x 4.5" Tri Point Packers and SSSV (type, measured and true vertical depth)Baker ZXP LTP N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Operations Manager Contact Phone: 7,500psi 7,500psi 3,580psi 6,890psi 8,430psi 8,430psi 6,516' 4,063' Burst N/A Collapse N/A 2,090psi 4,790psi Liner 3,723' 3,658' Casing Conductor 4,010' 4,006' 9,905' 9,967' 6,516' 4,182'Surface Intermediate Liner 20" 10-3/4" 7-5/8" 112' 4,182' measured TVD 4-1/2" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-190 50-029-23227-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025906 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT H-16 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 406 Gas-Mcf MD 112' 0 Size 112' 3,139' 402 2156284 0 00 238 322-677 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Brian Glasheen Brian.Glasheen@hilcorp.com 907-564-5277 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.03.29 06:44:47 -08'00' David Haakinson (3533) Perforate 322-677 Pull Tubing Sundry Number WCB 11-29-2023 MILNE PT UNIT H-16 204-190 MILNE POINT / SCHRADER BLUFF OIL Jet Pump Completion RBDMS JSB 033023 DSR-3/29/23 _____________________________________________________________________________________ Revised By: TDF 3/27/2023 SCHEMATIC Milne Point Unit Well: MPU H-16 Last Completed: 9/14/2016 PTD: 204-190 13 14 TD =9,967’(MD) / TD = 4,006’(TVD) 20” 7-5/8” 7 8 &9 10-3/4” 1011 12 “OA” Lateral PBTD =9,967’(MD) / PBTD =4,006’(TVD) “OB” Lateral 1 3 5 4 2 6 Orig. KB Elev.: 70.25’/ Orig. GL Elev.: 36.20’ RKB – Hanger: 20.00’ (Nabors 4ES) CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / L-80 / BTC 9.950 Surface 4,182’ 7-5/8" Intermediate 29.7 / L-80 / BTC-MOD 6.875 Surface 6,516’ 4-1/2” Liner “A” 12.6 / L-80 / IBT 3.958 6,182’ 9,905’ 4-1/2” Liner “B” 12.6 / L-80 / IBT 3.958 6,309’ 9,967’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TSH 521 3.958 Surface 6,081’ LINER DETAIL 4-1/2” OA Slotted Lnr 12.6 / L-80 / IBT 3.958 6,204’ 8,779’ 4-1/2” OA Slotted Lnr 12.6 / L-80 / IBT 3.958 8,945’ 9,859’ 4-1/2” OB Slotted Lnr 12.6 / L-80 / IBT 3.958 6,524’ 8,839’ 4-1/2” OB Slotted Lnr 12.6 / L-80 / IBT 3.958 9,173’ 9,922’ JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 5,452’ Hal Sliding Sleeve XD 2 5,513’ Baker BHPG – 3,787’ TVD 3 5,580’ 7-5/8 X 4.5" Tri Point packer 4 5,646’ X-Nipple w/ RHC Plug 5 5,707’ 250 Micron Screens w/ Centralizer - 337’ 6 6,054’ 7-5/8" x 4-1/2" LTC HYD ISOLATION PACKER 7 6,069’ 4-1/2” LTC X-Nipple w/ WLEG – Btm @ 6,081 8 6,177’ Baker Hook Wall, Hanger above 7” Window 9 6,194’ Baker Hook Wall, Hanger below 7” Window 10 6,309’ Baker Tie Back Sleeve 11 6,320’ Baker ZXP Liner Top Packer 12 6,326’ Baker 7” x 5” HMC Liner Hanger 13 9,859’ OA Lateral Btm Baker 4-1/2” Pack-off Bushing 14 9,922’ OB Lateral Btm Baker 4-1/2” Pack-off Bushing OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 560 sx PF “L”, 475 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 598 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD Max Wellbore Angle = 82.4 deg @ 6,515’ MD 69.0 deg @ 5,859’ MD WELLHEAD Tree 3-1/8” 5M Cameron Wellhead FMC Tubing Hanger, 11” x 2-7/8” EUE Top & Btm GENERAL WELL INFO API: 50-029-23227-00-00 Drilled and Cased by Doyon 14 – 11/01/2004 ESP Completion by Nabors 4ES – 2/16/2005 ESP Completion by ASR#1 – 9/14/2016 Convert to JP by ASR#1 – 12/15/2019 Perf Add & Jet Pump Completion by ASR – 3/3/2023 LATERAL WINDOW DETAIL Top of “OA” Window @ 6,182’ MD; Bottom @ 6,194’ MD; Angle @ top of window is 76 deg PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Schrader “N” 5,726’ 5,764’ 3,866’ 3,880’ 38 2/28/2023 Open Schrader “N” 5,798’ 5,902’ 3,892’ 3,929’ 104 2/28/2023 Open Schrader “N” 5,922’ 6,012’ 3,936’ 3,966’ 90 2/28/2023 Open Well Name Rig API Number Well Permit Number Start Date End Date MP H-16 Wells Group 50-029-23227-00-00 204-190 2/21/2023 3/3/2023 2/17/2022 - Friday No operations to report. 2/15/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/16/2022 - Thursday No operations to report. Wells Group pumped Well Kill, Set BPV and Installed CTS. Began Crane work, spot Mudboat and Heaters. Set Wellhouse and Stairs, N/d Tree, Inspected Lift Threads and serviced Hanger. Cont Trucking eq. from H Pad. N/u BOP Stack and Torque same, Spot in Pits, Fly on Rig Floor, Lay out and connect Koomey Lines, Disconnect Pusher Shack and Camps and prep for haul to H- pad. Note: Slow working conditions with High Winds. No operations to report. 2/18/2022 - Saturday No operations to report. 2/21/2023 - Tuesday 2/19/2023 - Sunday No operations to report. 2/20/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP H-16 ASR 50-029-23227-00-00 204-190 2/23/2023 3/3/2023 2/24/2022 - Friday Shut down for phase weather conditions. monitor well. IA and tubing dead. P/U M/U landing joint. BOLDS. Hanger offseat at 36K. Pull up to 90K, 95K, pull up to 100K 5 times., 105K five times, 115K 3 times. sting weight came down to 88K. observer packer gas at surface. Close annular and pump 185 BBls of 8.4 source water down IA @ 3 BPM 120psi never catching fluid. Shut down pump. Monitor well. IA on Vac , tubing Static. Pulled up on tubing , packer not fully released. pull up to 123K string weight went to 31K. begin to monitor well. Monitor well for 30 min. IA dead, tubing dead. started pulling pipe. fluid started coming over tubing. shut TIW. Checked IA, Static. during the process of shutting TIW fluid did escape containment. Contact Enviro, OE, and Milne point Supervisors. installed gauged on tubing. tubing had 430 psi. Environmental showed up and assessed the release. approx. 30 gal. hands started helping the clean up process. Plan was made to pump 1.5 times tubing volume @ 4 BPM with the rig pump. and pump 1.5 times IA volume @5 BPM with Little Red simultaneously. mobilize little red and more fluid to location. Pump 1.5 times tubing volume @ 4 BPM @ 460 psi with the rig pump. and pump 1.5 times IA volume @5 BPM @ 200psi with Little Red simultaneously. SD pump Tbg/IA on Vac. R/d LRS. R/u Kelly and monitored Tbg through Choke, after monitoring 50 mins observed gas flowing through the gas buster, IA was static, bleed off gas head through the choke. Once tbg was static pumped 1.5 times Tbg vol (80bbls) @ 4bpm/100psi while monitoring IA at the choke no returns.SD pump T/IA=0/0. Monitored Well for flow, T/IA=0/0. Tested the backup FOSV 250-2500psi and charted for 5mins- good test. (Will use to replace current FOSV used for Well Control). Crew change. PJSM and walk through bare pipe shut-in drill. Check fluids. Continued monitoring Well T/IA=0/0. T/IA=0/0, Pulled Hanger to Rig Floor, PUW=46k w/no drag, Cut Tech- wire and L/d Landing Jt and Hanger. Thread Tech-wire to spooler. POOH L/d 3-1/2" Jet Pump Completion f/5949' t/4400', Tubing and Tech-wire pulling clean. Spooling Wire and Removing Clamps, Pumping Double Pipe Displacement every 15 Jts w/8.4ppg SW. 2/22/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/23/2022 - Thursday Tested BOPE per approved sundry as following: Annular 250-2500psi, Rams 250-5000psi, Valves 250-2500psi. Chart Low/High for 5mins. 2 F/P Recorded on K-2 High Test and Upper Kelly Valve, greased and cycled valves and sequential testing was good. Preformed Koomey Drawdown, Test Fire & Gas Detection and Rig Inspection all good. Test conducted with 3-1/2" and 4-1/2" Test Jt. Note: tested blind and pipe ram to 5000psi for new stack. AOGCC witness waived by Brian Bixby on 2/21/23 04:36hrs. L/d Testing eq. Blow lines dry. C/o handling eq. to Pull 3-1/2" completion. PJSM, Crew change. Check fluids and serviced rig. Note wind speeds gusting 40+ creating slow working conditions. Filled pits with 8.4ppg SW. Hung Sheave and Spot Spooler Unit for Tech Wire. Check IA static. P/u Tee Bar backed out CTS plug. Check BPV and observed pressure on Tbg. Pumped 55bbls (tbg vol) down Tbg @ 3bpm/120psi. Check Tbg on Vac, Pulled BPV. R/d Elevators, Swapped out the short bails with longer bails to make room for X-over and TIW to clear the Swivel valve. R/u elevators. Phase 2 condition, wait on weather before pulling hanger and completion. P/U M/U landing joint. BOLDS. Hanger offseat at 36K. Pull up to 90K, 95K, pull up to 100K 5 times., 105K five times, 115K 3 times. sting weight came down to 88K. observer packer gas at surface. Close annular and pump 185 BBls of 8.4 source water down IA @ 3 BPM 120psi never catching fluid. Shut down pump. Monitor well. IA on Vac , tubing Static. Pulled up on tubing , packer not fully released. pull up to 123K string weight went to 31K. begin to monitor well. Monitor well for 30 min. IA dead, tubing dead. started pulling pipe Pulled Hanger to Rig Floor, PUW=46k w/no drag, Cut Tech- wire and L/d Landing Jt and Hanger. Thread Tech-wire to spooler. POOH L/d 3-1/2" Jet Pump Completion f/5949' t/4400', Pump 1.5 times tubing volume @ 4 BPM @ 460 psi with the rig pump. and pump 1.5 times IA volume @5 BPM @ 200psi with Little Red simultaneously. SD pump Tbg/IA on Vac. R/d LRS. R/u Kelly and monitored Tbg through Choke, after monitoring 50 mins observed gas flowing through the gas buster, IA was static, bleed off gas head through the choke. Once tbg was static pumped 1.5 times Tbg vol (80bbls) @ 4bpm/100psi while monitoring IA at the choke no returns.SD pump T/IA=0/0. Monitored Well for flow, T/IA=0/0. Check BPV and observed pressure on Tbg. Pumped 55bbls (tbg vol) down Tbg @ 3bpm/120psi. Check Tbg on Vac, Pulled BPV. R/d Elevators, Swapped out the short bails with longer bails to make room for X-over and TIW to clear the Swivel valve. R/u elevators. Phase 2 condition, wait on weather before pulling hanger and completion. Well Name Rig API Number Well Permit Number Start Date End Date MP H-16 ASR 50-029-23227-00-00 204-190 2/23/2023 3/3/2023 Hilcorp Alaska, LLC Weekly Operations Summary POOH L/d 3-1/2" Jet Pump Completion f/4400' t/4,090, Tubing and Tech-wire pulling clean. Spooling Wire and Removing Clamps, Pumping Double Pipe Displacement every 15 Jts w/8.4ppg SW. Crew preform Kick while POOH drill. drill time 3 min 30 sec. crew preformed AAR on rig floor. Continued POOH w/ 3-1/2 EUE and jet pump completion. from 4,090' to 3,139'. Troubleshoot Hydraulic issues with the carriage. continue monitoring the well. Pumping 10 BPH while trouble shooting rig. POOH L/d 3-1/2" Jet Pump Completion f/3139' t/surface, Tubing and Tech-wire pulling clean. Spooling Wire and Removing Clamps, Pumping Double Pipe Displacement every 15 Jts w/8.4ppg SW. Visually Inspect Packer all good. Cleaned and Cleared Rig Floor, MIRU AK EL, P/u and assembly Tool String 6.60" GR/JB, 2x Weight Bars, 3-1/8" CCL. 19' offset f/CCL t/GR. RIH and set down at ~5600'. Clean up, P/u 5000' and RIH w/more speed and set down again ~5600'. POOH, JB was full of debris (some small chucks of metal and rubber). RBIH w/same Toolstring and set down @ 5600' (Inc 66degs), Trying working down no joy. POOH, L/d Tools Junk Basket clean. C/o Handling eq. Rack and Tally Completion Jewelry and 1st 56 jts of 3-1/2" WS. PU/MU Lower Completion as designed: 4-1/2" WLEG, 4-1/2" Pup, 4-1/2" XN Nipple Loaded w/Standing Valve at report time. 2/25/2022 - Saturday MIT-IA to 3600psi for 30 charted min. good test. bleed off and blow down fluid lines. Clear pits of all 8.4 ppg SW. Take on 9.0 ppg Brine. rig up top start displacing well over to 9.0 ppg brine. Displace well from 8.4ppg SW to 9.0ppg brine pumping down tubing taking returns to flow back tank. pumped a total of 275 BBLs @ 3 BPM 400psi. Swivel out of joint. Blow down all fluid lines. top pits off with 9.0 brine. POOH with 3-1/2 workstring and packer running tool. from 6,050' to surface. Lay down bumper sub, pups, and packer running tool. Cleaned and Cleared Rig Floor, M/u Landing Jt and Test Plug w/TWC, Landed Plug and RILDS, N/d Birdbath, Riser and Flow Spool, N/u 7-1/16" Shooting Flange. R/u EL PCE, Pressure Test 300psi low and 2000psi high, good low test but the Line Pack off leaking on the High Test, , Began Troubleshooting, Installed New Grease Head, PT 300psi/2000psi-good test. Pulled TWC. P/u and assembly 90' of 2-7/8" Perf Guns 6spf GR/CCL to TS = 14.8' RIH t/6030', making correlation pass at report time. 2/26/2023 - Sunday Cont P/u Lower Completion as designed: 4-1/2" WLEG, 4-1/2" Pup, 4-1/2" XN Nipple Loaded w/Standing Valve, 4-1/2" Pup Jt, 7-5/8" x 4-1/2" Hyd Iso Pkr, 5" PBR, Running Tool, XO Sub's, 4-3/4" Bumper Jar, OX t/Wk. String. RIH w/Lower Completion P/u 3-1/2" 9.3# NC31 WS t/2200', Running speed under 60fpm per Tri-point Packer Rep. PUW=18k. Maintained 10bph hole fill w/8.4ppg SW. Crew Change PJSM, Check fluids and serviced Rig. Cont RIH w/Lower Completion P/u 3-1/2" 9.3# NC31 WS f/2200 t/6,077 (EOT), Running speed under 60fpm per Tri-point Rep. Maintaining 10bph hole fill w/8.4ppg SW. Slow Trip due Ice hanging up the Drift in the Work-string. R/u AK E-line, M/u 1-11/16" CCL, Rollers, GR, 2xWeight Bars and Rollers. RIH, couldn't make it down to Log completion Jewelry. Logged up across the Marker Jt and Tie-in Log, sent Log to Town to confirm Correlation depth. Packer on depth @ 6,050'. POOH R/d EL. K/u to Tbg, Installed Tarps to winterize Power Swivel. R/u Test eq. Pumped 13bbls of 8.4ppg SW down Wk String and Set Pkr per Tripoint setting procedure as following: Pressured up to 3800psi- held for 30mins to set packer, bleed off and pulled 20k over and set 20k down, Picked up to neutral wt. Pressured back up to 3,800psi held for 5mins. Bleed off pressure. Packer set @ 6050' EOT @ 6077'. Filled IA with 54bbls, pressure up to 3600psi, charting Test at report time. 2/27/2023 - Monday POOH L/d 3-1/2" Jet Pump Completion f/4400' t/4,090, Tubing and Tech-wire pulling clean. Spooling Wire and Removing Clamps, Pumping Double Pipe Displacement every 15 Jts w/8.4ppg SW. Crew preform Kick while POOH drill. drill time 3 min 30 sec. POOH L/d 3-1/2" Jet Pump Completion f/3139' t/surface, Tubing and Tech-wire pulling clean. Spooling Wire and Removing Clamps, Pumping Double Pipe Displacement every 15 Jts w/8.4ppg SW. Visually Inspect Packer all good Maintained 10bph hole fill w/8.4ppg SW POOH with 3-1/2 workstring and packer running tool. from 6,050' to surface Cont P/u Lower Completion as designed: 4-1/2" WLEG, 4-1/2" Pup, 4-1/2" XN Nipple Loaded w/Standing Valve, 4-1/2" Pup Jt, 7-5/8" x 4-1/2" Hyd Iso Pkr, 5" PBR, Running Tool, XO Sub's, 4-3/4" Bumper Jar, OX t/Wk. String. RIH w/Lower Completion Pressured up to 3800psi- held for 30mins to set packer, bleed off and pulled 20k over and set 20k down, Picked up to neutral wt. Pressured back up to 3,800psi held for 5mins. Bleed off pressure. Packer set @ 6050' EOT @ 6077'. Filled IA with 54bbls, pressure up to 3600psi, charting Test at report time. Clear pits of all 8.4 ppg SW. Take on 9.0 ppg Brine. rig up top start displacing well over to 9.0 ppg brine. Displace well from 8.4ppg SW to 9.0ppg brine pumping down tubing taking returns to flow back tank. pumped a total of 275 BBLs @ 3 BPM 400psi MIT-IA to 3600psi for 30 charted min. good test. Continued POOH w/ 3-1/2 EUE and jet pump completion. from 4,090' to 3,139'. New lower packer holding - passing MIT-IA. -WCB MIRU AK EL Cont RIH w/Lower Completion P/u 3-1/2" 9.3# NC31 WS f/2200 t/6,077 (EOT), Running speed under 60fpm per Tri-point Rep. Maintaining 10bph hole fill w/8.4ppg SW. Well Name Rig API Number Well Permit Number Start Date End Date MP H-16 ASR 50-029-23227-00-00 204-190 2/23/2023 3/3/2023 Hilcorp Alaska, LLC Weekly Operations Summary Correlate guns on depth. Place guns to fire perfs. Perforate from 5,922 to 6,012. w/ 2.75" 6 SPF, 60 degree phasing, 15 gram wt. Monitor well. Start constant hole fill. Well on vacuum. POOH with E-line. pumping continuous hole fill. Loss of .5 BBLs on the POOH. Lay down perf guns. All shots fired. Close blinds and circulate top of hole monitoring well. total loss after first perf 1BBL. Put together next guns in pipe shed. Pick up and make up 104' of perf guns. RIH and correlate on depth. Perf 104' section F/ 5,798 - 5,902. W/ 2.75" 6 SPF, 60 degree phasing, 15 gram wt. Well on vacuum. Monitor well. via continuous hole fill. POOH with E-line. pumping continuous hole fill. Loss of 5 BBLs on the POOH. Lay down perf guns. All shots fired. Close blinds and circulate top of hole monitoring well. total loss after first perf 1BBL. Put together next guns in pipe shed. Pick up and make up 38' of perf guns. RIH and correlate on depth. Perf 40' section from 5,726' - 5,764'. W/ 2.75" 6 SPF, 60 degree, phasing 15 gram wt. Well on vacuum. Monitor well. via continuous hole fill. POOH with E-line. pumping continuous hole fill. Loss of 5 BBLs on the POOH. Lay down perf guns. All shots fired. Close blinds and circulate top of hole monitoring well. R/D E- line PCE, sheave & equipment. N/D shooting flange & N/U flow spool & riser on BOPE. Monitor well. Engage landing JT into WL hanger. BOLDS. Pull False hanger. B/O & L/D. Well on vacuum. P/U & M/U Jet pump completion, Snap latch seal assy. XO pup. t/ 13.5# TSH 625 250 micron screens x8, XO pup, JT, XN, JT tri point perm PKR, JT, & BHPG. Run tech line to Down hole gauge & terminate. Test & secure w/ canon clamps. M/U 1 JT & sliding sleeve & cont. T/ RIH w/ jet pump completion on 4- 1/2" 12.6# L-80 TSH 521 pipe. F/ 604' T/ 1,217' 2/28/2023 - Tuesday Perf 40' section from 5,726' - 5,764'. Perforate from 5,922 to 6,012 Well on vacuum. Monitor well. via continuous hole fill. POOH with E-line. pumping continuous hole fill. Loss of 5 BBLs on the POOH. Lay down perf guns. All shots fired. Close blinds and circulate top of hole monitoring well. R/D E- line Perf 104' section F/ 5,798 - 5,902. P/U & M/U Jet pump completion, Snap latch seal assy. XO pup. t/ 13.5# TSH 625 250 micron screens x8, XO pup, JT, XN, JT tri point perm PKR, EL shot perfs after lower completion was set. The above perf depths are correctly shown on the new WBS, below. -WCB Well Name Rig API Number Well Permit Number Start Date End Date MP H-16 ASR 50-029-23227-00-00 204-190 2/23/2023 3/3/2023 3/3/2022 - Friday RAN 3.68" CENT, 2'x1-7/8" STEM, 4-1/2" 42BO (keys down) DOWN TO XD SS @ 5,439' SLM (5,452' MD), MADE 10 PASSES THROUGH CLEAN, 42BO PIN NOT SHEARED, SLEEVE IS OPEN. PULLED BALL & ROD FROM 5,620' SLM, ALL PINS & ROLLERS RECOVERED. PULLED 4-1/2" RHC FROM X-NIP @ 5,626' SLM (5,646' MD), ALL PACKING & PINS RECOVERED. PULLED 4-1/2" CAT STANDING VALVE FROM XN @ 6,049' SLM (6,069' MD), ALL PACKING RECOVERED. RAN 3" JET PUMP (serial: HC-00015, ratio: 12B, oal: 85") W/ SCREEN & SETIN XD SS @ 5,439' SLM (5,452' MD), GOOD PULL TEST, SHEARED OFF CLEANPicked up 11 x 4-1/2 TC-II tubing hanger, terminate 1/4¿ tech line, land off with no issues, RILDS to 450 ft/lbs, rig set packer, set 4¿ H BPV, release rig, nipple up tree adapter. tested THA to 500 / 5000 psi for 10 mins, all tests good, Pulled BPV with dry rod. 3/1/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue to RIH w/ 4-1/2" TSH 521 and jet pump completion F/ 1,217' to 6,045' testing tech wire every 1,000'. Pumping continuous hole fill. Obtain parameters, P/U wt = 65k. S/O wt = 31k. Snap into latching tieback w/ 10K dw. Unlatch w/ 85k P/U wt = 20k over. Engage latch to verify depth. Snap in w/ 10 k dw. P/U to 95k seals not unlatching. Work pipe F/ 28K to 100K x3. Cont. to work pipe F/ 28k T/ 110K & 120K. Possible debris in latch from perfs. Sand / gun debris. Line up to reverse circ & pull to max. Obtain Rig foreman approval for max pull. & vendor approval to shut annular on tech line. Work pipe f/ 28K to 147K x3. W/ 147K pulled on latch. Shut annular, reverse circ at 2.5 BPM w/ 230 psi. Taking returns to gas buster. Shut pumps down. Open annular. Work pipe f/ 28k to 145k. seal latch aasy. free at 145k . P/U = 65K. Decision made to land completion. Measure & prep for space out. Obtain more space out pups to aid in landing completion in tieback w/ minimal compression. Service rig, Perform fluid checks. Pull Joints # 140- 136. Removing longer joints to replace w/ shorter spares. RIH w/ joints # 136 - 138, Space out Pups x8 & JT # 139. RIH to 4' off top of tieback. Rig up to reverse. Reverse circulate at 2.5 3/2/2022 - Thursday Finish reverse circulating pump a total of 50 bbls. Up weight 65K down weight 31K. land hanger with 6K compression. 25K on hanger bowl. RILDS. Reverse circulate in 125 BBLs of 9.0 ppg brine with 1% corrosion inhibitor. Shut down pumps and blow fluid lines dry. Drop ball and rod. Pressure up to 3900psi to set packer and hold for 5 min. After 5 min tubing started to bleed down. Pressure back up to 3900 psi. Pressure continued to bleed. Bled tubing down to 1000 psi. Pressure up to 3700 psi for the MIT-IA and held for 30 min. Good test. Bleed off pressure and blow lines dry. Install BPV. Begin RDMO. Offload upright tanks to vac truck for well kill on MPU H-15. Suck out pits to save fluid for H-15. B/D all fluid lines & drain gas buster. N/D flow spool & riser off BOPE, Hoist & set on floor. N/D cellar drip pan. N/D flow line, fluid lines & interconnects. Remove pipe shed & catwalk. Clear rig floor of 3rd party equip. Lay over derrick & set on head ache rack. Raise jacks prep rig to be move, Remove accumulator lines from BOPE. Mobilize rig to A-pad for maintenance. Spot in crane. Remove floor & fly on transport trailer. Remove BOPE from wellhead. Rig down pits & stage on location. Remove equipment from well to allow for well work & well well on H-15. Install tree on tubing spool w/ wellhead Rep. Simops: cont. rig maintenance on A-pad. Rig released. No operations to report. No operations to report. 3/4/2022 - Saturday No operations to report. 3/7/2023 - Tuesday 3/5/2023 - Sunday No operations to report. 3/6/2023 - Monday Drop ball and rod. Pressure up to 3900psi to set packer and hold for 5 min. After 5 min tubing started to bleed down. Pressure back up to 3900 psi. Pressure continued to bleed. Bled tubing down to 1000 psi. Pressure up to 3700 psi for the MIT-IA and held for 30 min. Good test. PULLED BALL & ROD FROM 5,620' SLM PULLED 4-1/2" RHC FROM X-NIP @ 5,626' SLM (5,646' MD), ALL PACKING & PINS RECOVERED. PULLED 4-1/2" CAT STANDING VALVE FROM XN @ 6,049' SLM (6,069' MD), ALL PACKING RECOVERED. RAN 3" JET PUMP (serial: HC-00015, ratio: 12B, oal: 85") W/ SCREEN & SETIN XD SS @ 5,439' SLM (5,452' MD Continue to RIH w/ 4-1/2" TSH 521 and jet pump completion F/ 1,217' to 6,045' testing tech wire every 1,000'. Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 03/03/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230303 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 212-35T 50283200970000 198161 2/19/2023 AK E-LINE Perf BRU 232-26 50283200770000 184138 2/14/2023 AK E-LINE Perf END 1-29 50029216690000 186181 2/16/2023 AK E-LINE Perf MPU H-16 50029232270000 204190 2/28/2023 AK E-LINE Perf Please include current contact information if different from above. MPU H-16 50029232270000 204190 2/28/2023 AK E-LINE Perf 1 Regg, James B (OGC) From:Alaska NS - ASR - Well Site Managers <AlaskaNS-ASRWellSiteManagers@hilcorp.com> Sent:Saturday, February 25, 2023 9:46 AM To:DOA AOGCC Prudhoe Bay Subject:BOPE use report for 2/24/2023 I am writing to report the use of our BOPE to prevent the flow of fluids on 2/24/2023 at 11:30 am. Detail of the event are below. Our plan is to test the BOP component used before exiting or entering the well. Date, Time of BOPE Use: 2/24/2023, 11:30 AM Well/Location/PTD Number: MPU H-16/ H-16/ 2041900 Rig Name : ASR : Rig operator/ Integrated well services Contact: Aaron Haberthur (907)-685-1266 Operations Summary, including events leading up to BOPE use: 1.All fluid is 8.4 ppg source water. Feb 24, 2023 1.01:00 – 03:30 Before pulling BPV observed slight gas under BPV. Rigged up to pump and pumped a tubing volume (55 BBLs). Tubing went on a vac. 2.03:30 – 7:30 Shut down for weather before pulling hanger. Monitoring well. Both IA and tubing dead. 3.07:30 – 09:00 Pick up and make up landing joint with FOSV installed on top. Backed out lock down screws. Worked pipe. Pumped 20 BBLs down backside while working to release packer. Worked up to 115K packer released showing 88K hanging weight. Monitored well and observed packer gas at surface as planned in sundry. 4.09:00 – 10:15 As planned in sundry, closed annular to pump. Pumped 185 BBLs down IA. Shut down pump. Monitor well. IA on a vac, tubing dead. Opened the annular to monitor IA at surface. 5.10:15 – 10:45 Pulled up and packer was not fully released. Pulled up to 123K packer released and hanging weight was 31K. 6.10:45 – 11:20 Monitored the Well. Tubing dead, IA dead. Blowing down fluid lines as we monitored the tubing with the FOSV on tubing. Monitored IA with BOPs open watching down the well. 7.11:20 – 11:30 Rig up Baker Centerlift to pull tech wire. 8.11:30 – Started pulling up while keeping FOSV on tubing and hydrocarbons started to come from the tubing. Shut the FOSV. IA still static. During the process of shutting FOSV approx. 30 gal was released out of containment 9.11:30 - Started making notifications. OE, environmental, Milne point supervisors. 10.Tubing has 430 psi on it. Environmental estimates 30 gal on the pad. 11.Rig up ASR’s rig pump to pump down tubing and utilize Little Red Services to pump down IA. Pump 8.4 ppg source water down the tubing, 1.5 times tubing volume @ 4 BPM. Simultaneously pump down the IA, 1.5 times IA volume @ 5 BPM. BOPE Used: FOSV. Reason for BOPE Use: Hydrocarbons flowing from tubing. Actions Taken/To Be Taken (including the date used BOPE was tested): FOSV used was last tested 2/23/2023. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Milne Point Unit H-16PTD 2041900     J. Regg 2 We tested the spare FOSV placed it on the tubing in place of the FOSV valve used to control flow. We also tested the FOSV used. Both FOSVs passed pressure test 250psi low, 2500psi high as per approved sundry 2/25/2023. ASR DSM’s Hilcorp DSM: 907‐685‐1266 Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.  STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:ASR 1 DATE:2/23/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2041900 Sundry #322-677 Operation:Drilling:Workover:x Explor.: Test:Initial:x Weekly:Bi-Weekly:Other: Rams:250/5000 Annular:250/2500 Valves:250/2500 MASP:1288 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 FP Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 11" 5M P Pit Level Indicators P P #1 Rams 1 2 7/8" x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16" 5M P Time/Pressure Test Result HCR Valves 1 2 1/16" 5M P System Pressure (psi)2975 P Kill Line Valves 3 2 1/16" 5M FP Pressure After Closure (psi)1900 P Check Valve 0 NA 200 psi Attained (sec)15 P BOP Misc 0 NA Full Pressure Attained (sec)48 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 / 2237 PSI P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 23 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:2 Test Time:7.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2-20-23/6:47pm Waived By Test Start Date/Time:2/23/2023 15:00 (date)(time)Witness Test Finish Date/Time:2/23/2023 22:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Hilcorp Tested w/3-1/2" & 4-1/2" test joint. 2 F/P recorded, K2 fail on High Test and Upper Kelly Valve on Low Test. Cycled Valves and the sequential testing was good. New Blinds and Pipe Rams were tested to 5000psi. Bottle Precharge - 1000 psi C.Greub / J. Werlinger Hilcorp Alaska LLC A.Haberthur / W. Hudgens MPU H-16 Test Pressure (psi): askans-asr-toolpushers@hilcorp.co ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022)2023-0223_BOP_Hilcorp_ASR1_MPU_H-16          J. 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ĂŬĞƌϳ͟ǆϱ͟,D>ŝŶĞƌ,ĂŶŐĞƌ ϭϯ ϵ͕ϴϱϵ͛ K>ĂƚĞƌĂůƚŵĂŬĞƌϰͲϭͬϮ͟WĂĐŬͲŽĨĨƵƐŚŝŶŐ ϭϰ ϵ͕ϵϮϮ͛ K>ĂƚĞƌĂůƚŵĂŬĞƌϰͲϭͬϮ͟WĂĐŬͲŽĨĨƵƐŚŝŶŐ KWE,K>ͬDEdd/> ϮϬΗ ŵƚǁͬϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϰϮ͟,ŽůĞ ϭϬͲϯͬϰΗ ŵƚǁͬϱϲϬƐǆW&͞>͕͟ϰϳϱƐǆůĂƐƐ͞'͟ŝŶϭϯͲϭͬϮ͟,ŽůĞ ϳͲϱͬϴ͟ ŵƚǁͬϱϵϴƐǆůĂƐƐ͞'͟ŝŶϵͲϳͬϴ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϱϬϬ͛D DĂǆtĞůůďŽƌĞŶŐůĞсϴϮ͘ϰĚĞŐΛϲ͕ϱϭϱ͛D ϲϵ͘ϬĚĞŐΛϱ͕ϴϱϵ͛D t>>, dƌĞĞ ϯͲϭͬϴ͟ϱDĂŵĞƌŽŶ tĞůůŚĞĂĚ &DdƵďŝŶŐ,ĂŶŐĞƌ͕ ϭϭ͟ǆϮͲϳͬϴ͟hdŽƉΘƚŵ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϮϮϳͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇŽǇŽŶϭϰʹϭϭͬϬϭͬϮϬϬϰ ^WŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϮͬϭϲͬϮϬϬϱ ^WŽŵƉůĞƚŝŽŶďǇ^ZηϭʹϵͬϭϰͬϮϬϭϲ ŽŶǀĞƌƚƚŽ:WďǇ^ZηϭʹϭϮͬϭϱͬϮϬϭϵ >dZ>t/EKtd/> dŽƉŽĨ͞K͟tŝŶĚŽǁΛϲ͕ϭϴϮ͛D͖ŽƚƚŽŵΛϲ͕ϭϵϰ͛D͖ŶŐůĞΛƚŽƉŽĨǁŝŶĚŽǁŝƐϳϲĚĞŐ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ ^ĐŚƌĂĚĞƌ͞E͟ цϱ͕ϳϮϲ͛ цϱ͕ϳϲϲ͛ цϯ͕ϴϲϲ͛ цϯ͕ϴϴϭ͛ цϰϬ &ƵƚƵƌĞ WĞŶĚŝŶŐ ^ĐŚƌĂĚĞƌ͞E͟ цϱ͕ϳϵϴ͛ цϱ͕ϵϬϮ͛ цϯ͕ϴϵϮ͛ цϯ͕ϵϮϵ͛ цϭϬϰ &ƵƚƵƌĞ WĞŶĚŝŶŐ ^ĐŚƌĂĚĞƌ͞E͟ цϱ͕ϵϮϮ͛ цϲ͕ϬϭϮ͛ цϯ͕ϵϯϲ͛ цϯ͕ϵϲϲ͛ цϵϬ &ƵƚƵƌĞ WĞŶĚŝŶŐ DŝůŶĞWŽŝŶƚ ^ZZŝŐϭKW %23( Εϰ͘ϰϴΖ Εϰ͘ϱϰΖ Ϯ͘ϬϬΖ ϱϬϬϬη ϮͲϳͬϴΗǆϱΗsZ ϱϬϬϬη ůŝŶĚ ^͕ϭϭϱDyϳϭͬϭϲϱD;/ĨEĞĞĚĞĚͿ ϮϭͬϭϲϱD<ŝůů>ŝŶĞsĂůǀĞƐ ϮϭͬϭϲϱDŚŽŬĞ>ŝŶĞsĂůǀĞƐ ,ZDĂŶƵĂůDĂŶƵĂůDĂŶƵĂů ^ƚƌŝƉƉŝŶŐ,ĞĂĚ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon L1 Plug Perforations Ll Fracture Stimulatc Pull Tubing Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulat Alter Casing L1 Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair We[] Re-enter Susp Well ❑ Other: FCO w/ Nitrogen Q 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ ment Develo Stratigraphic❑ Ex p loralo ry❑ Service ❑ 204-190 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-23227-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025906 MILNE PT UNIT H-16 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT/ SCHRADER BLUFF OIL 11. Present Well Condition Summary: Total Depth measured 9,967 feet Plugs measured N/A feet true vertical 4,006 feet Junk measured N/A feet Effective Depth measured 9,967 feet Packer measured 5,337 feet true vertical 4,006 feet true vertical 3,710 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 4,182' 10-3/4" 4,182' 3,139' 3,580psi 2,090psi Intermediate 6,516' 7-5/8" 6,516' 4,063' 6,890psi 4,790psi Liner 3,723' 4-1/2" 9,905' 4,010' 8,430psi 7,500psi Liner 3,658' 4-1/2" 9,967' 4,006' 8,430psi 7,500psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3#/ L-80 / EUE 8rd 5,981' 5,956' Packers and SSSV (type, measured and true vertical depth) 7-5/8" x 3-1/2" FH NIA See Above NIA 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 108 94 2,146 2,602 231 Subsequent to operation: 140 23 2,121 2,473 228 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby Certify that the foregoing IS true and Correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 320-034 Authorized Name: Chad HelgesonContact Name: David Haakinson Authorized Title: Operations Manager Contact Email: dhaakinsonk�hilcom cora i Authorized Signature: Date: 3/5/2020 Contact Phone: 777-8343 Form 10-004 Revised 4/2017RBDM5 _fA'/mAR 0 9 2020 Submit Original Only Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP H-16 CFU 50-029-23227-00-00 204-190 2/16/2020 2/17/2020 2/12/2020- Wednesday - No operations to report. 2/13/2020 -Thursday - No operations to report. 2/14/2020- Friday No operations to report. 2/15/2020 - Saturday No operations to report. 2/16/2020 -Sunday - MU Cleanout BHA, stab on well. PT to 350/3500 psi. T/1/0 = 226/48/0 psi. RIH with 2.28" OD 1SN. At 4,500' ctmd start N2 down coil at 700 scf/m. (N2 at 100 deg). Start commingling N2 with 90 degree SLK 1%. Continue RIH to 5123'. With 6 bbls water pumped coil pressured up to 4000 psi. Bleed back N2 and water from coil to tanks. Pump 13 bbls 60/40 into coil before pressuring up. Cover reel house and apply heat to thaw. No success after 3 hours. POOH. Check BHA and found no ice. Re-cover reel house and apply heat and allow to thaw over night. Return tomorrow to resume operations. 2/17/2020 - Monday - T/1/0 = 135/354/7. Pump thru coil to verify it is clear of ice. Good. RIH with 2.28" OD 1SN. Perform nitrified FCO from the TT to 9,931' ctmd. Cleaned out in 500' bites pumping 1.2 bpm SLK 1% and 1,000 scf/m N2 and gel sweeps with every bite. Maintained positive WHP throughout. Freeze protect well with 26 bbls of 60/40 methanol. RDMO. Job complete. 2/18/2020 -Tuesday No operations to report. THE STATE OfALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU H-16 Permit to Drill Number: 204-190 Sundry Number: 320-034 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaskc.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, J 4e M. Price hal DATED this Oday of January, 2020. RBDMS�',AN 2 4 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS vn nnc s,� 9an F7RV1: &a .,aL ,a"2 L�t JAN 2 1 2020 orc/�q1a:1�11 Z .3 z o A V C 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well p ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: FCO w/ Nitrogen❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ Stratigraphic ❑ Service E] 204-190 " 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23227-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 477.05 Will planned perforations require a spacing exception? Yes ❑ No ❑ MILNE PT UNIT H-16 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0026906 t MILNE POI NT / SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,967' 4,006' 9,967' 4,006' 933 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 4,182' 10-3/4" 4,182' 3,139' 3,580psi 2,090psi Intermediate 6,516' 7-5/8" 6,516' 4,063' 6,890psi 4,790psi Liner 3,723' 4-1/2" 9,905' 4,010' 8,430psi 7,500psi Liner 3,658' 4-1/2" 9,967' 4,006' 8,430psi 71500P si Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 2-7/8" 6.5# / L-80 / EUE 8rd 5,916' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7-5/8" x 3-1/2" FH and N/A 5,337(MD) / 3,710(TVD) and N/A 12. Attachments: Proposal Summary ✓ Wellbore schematic El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 2/1/2020 Commencing Operations: OIL ✓ WINJ ❑ E]WDSPL E] Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: David Haakinson Authorized Title: Operations Manager Contact Email: dhaakinson IICOr .Com Contact Phone: 777-8343 Authorized Signature: Date: 1/8/2020 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative maywitness Sundry Number: Z Oq / / Uh�-1{�est ❑ Location Clearance Plug Integrity F1 BOP Test ❑ Mechanical Integrity -fest El Other: RBDMS!% 1 JAN 2 4 2020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes No Subsequent Form Required: IQ --LI Dtl ) APPROVED Approved by: � COMMISSIONER THE COMMISSION Date: 1//r r 2a� zo ! R I G I brft Form and Form o3 Revis 4/zc pproved application is valitl for 12 months from the date of appro u e t Duplicate �AoI/", IH.A i16 K Hilemp Alaska, LLQ CT Cleanout Well: MPU H-16 1/20/2020 Well Name: MPU H-16 API Number: 50-029-23227-00 Current Status: Online [JP Producer] Well Service Unit: Coiled Tubing Estimated Start Date: February 20, 2020 Estimated Duration: 3 Days Reg.Approval Req'std? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 204-190 First Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) Second Call Engineer: Ian Toomey 1 (907) 777-8434 (0) (907) 903-3987 (M) AFE: WeIIEZ Entry Required: Yes Current Bottom Hole Pressure: Maximum Expected BHP: Max. Anticipated Surface Pressure: MIN ID: Max Inc. (Within Work Interval): Max DLS: 1,244 psi @ 3,699' TVD 6.46 PPGE IDownhole Gauge 12/22/19 1,250 psi @ 3,699' TVD 6.50 PPGE 130 -day PBU Extrapolation 933 psi Gas Column Gradient (0.1 psi/ft) 2.75" @ 5,360' MD XN Nipple 930 in both Laterals 16.6°/100 ft @ 6,233' MD in OA Lateral 11.5°/100 ft @ 8,931' MD in OB Lateral Brief Well Summary: Milne Point producer H-16 was drilled in 2004, and completed as a dual lateral Schrader Bluff OA and OB producer. The well is known to be a solids producer. Due to the fact that the well has never received a fill cleanout, combined with historical ESP wear, a jet pump completion was installed in a December 2019 RWO. A lateral entry module was never installed on the well and thus it is only expected that a single lateral will be cleaned out. Well -work Objective: Perform Nitrified Foam Cleanout of either OA or OB Lateral Notes Reparding the Well & Design: • A RWO was completed on the well in December 2019 to install a jet pump completion and allow for a CTU FCO. • Due to the low reservoir pressure, nitrogen is required to remove solids from the well. • A LEM system was never installed in the well and thus only a single lateral can be cleaned out without an/ Irientation tool. o For this work, only one lateral FCO is planned. It is not known which lateral will be entered. o Note: The laterals have never been entered since the 2004 initial completion. • The 7-5/8" production casing passed a MIT -IA to 2,500 psig on 12/14/19. Part 1: Slick -line Procedure (Non Sundry Operation) 1. Freeze protect tubing and annulus. Pump 91 bbls of diesel down tubing. Hookup surface jumper between Tubing and Inner -Annulus and allow fluids to U-tube. �Q 2. MIRU Slickline Unit. PT PCE. 3. Pull jet purr from XD Sliding Sleeve @ 5,314' MD. l 4. 1 XD�SSD Sliding Sleeve @ 5,314' MD to closed position. mF 5. RDMO Slickline Unit. 0 flilcorn Alaska. LG CT Cleanout Well: MPU H-16 1/20/2020 Part 2: Nitrified Coiled Tubing Procedure 1. MIRU Coiled Tubing Unit and spot auxiliary equipment. Fill tanks with 8.4 ppg source water and 1% KCI (by weight). 2. If BOPE test not completed in last 7 -days, perform BOPE test to 2,500 psig High, 250 psig Low. 3. MU BHA including 2.0" coiled tubing, DBPV, jars, hydraulic disconnect, and jet nozzle. Additional BHA changes may be dictated by the on-site company man. 4. RIH to 7-5/8" casing window. Take extreme caution while progressing through the lateral windows from 6,150' MD to 6,400' MD. a. Document any tags or weight changes and their respective depths. 5. RIH to tag depth, attempt to determine which lateral has been entered. Begin jetting solids and attempt to take returns to surface tanks. a. Start increasing Nitrogen rate to achieve 1:1 returns. b. It is estimated that 600 scf/min will be needed for full returns, 6. Cleanout lateral to a hard tag, attempting to reach a PBTD of cleanout lateral to PBTD of either 9,905' (OA Lateral) or 9,967 (OB Lateral). —=> 'AA,�, j fy✓i{- (\ �j't S�j Q 1 a. Circulate out fill using 8.4 ppg 1% KCI and mix with Nitrogen. L If a surfactant foamer is available, a foam FCO is preferred. b. Take 150-300' bites and perform wiper trips after each successive bite. Send frequent 5 bbl gel sweep at a minimum after each 600' of hole is cleaned out. i. A minimum pump rate of 0.8 bbl/min combined with Nitrogen at a rate of 600 scf/min is anticipated to give the best hole cleaning results. c. If foam is used, utilize de-foamer for returns in Kill Tank. It is best to inject the defoamer in the line prior to entry to the tank. d. Lubes maybe necessary for weight transfer near TD. e. Once target depth is achieved, pump final sweep and chase out of hole, jetting to surface. While POOH, at 2,500' swap to diesel or 60/40 methanol and lay in 22 bbls of diesel freeze protect. 8. RD CTU and auxiliary equipment. 9. Turn well over to operations Part 3: Slick -line Procedure (Non Sundry Operation) 1. MIRU Slickline Unit. PT PCE. 2. Shift XD SSD Sliding Sleeve @ 5,314' MD to open position. S 3. Run 2.813" Jet Pump and install in sliding sleeve @ 5,314' MD. a. The current size recommendation is a 98; however, this may change based on the results of the ' FCO. C4. Turn well over to operations and return to production. Attachments: 1. Coil BOPE Schematic 2. Nitrogen Operations Procedure 3. Nitrogen & Foam Flow Diagram Coil Tubing BOP Milne Point Unit Revised: 1/8/2020 To injection head 2.00" Stripper Lubricator elind 1/16 isiv Blind Shear Shear O� Kill Po slip Pipe Crossover spool 4 1/16 15M X 4 1/16 10M Crossover spool 4 1/16 IOM X 4 1/16 5M Pu mp-I n Sub 4 1/16 5M S i to c'_*p Valve, Swab, WKM-M, 41/16 5M FE Valve, Upper Master, Baker, // 41/165M FE ( , w/Hydraulic Valve, Lower Master, WKM-M, 4 1/16 5M FE Tubing Adapter, 4 1/16 5M Slip Pipe Kill Port Plug Valve Plug Valve 2"/10K 2"/10K Manual Manual lanual Gate Manual Gate 21/85M 21/85M Ja�4eip1��6 1502 Union STANDARD WELL PROCEDURE I ilrorpAla.ka.LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets. 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 01/08/2020 FINAL v1 Page 1 of 1 gl /w c OO 9 Wa LL� mG m z o �a p 6 VO > > a c5 T O � mo i•••• •da 2 i.•• .? W 7 L7 fA U W gl /w c OO W Y Wa LL� mG m m n STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JAN 0 7 2020 1. Operations Abandon LJ Plug Perforations U Fracture Stimulatc Pull Tubing ✓ Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulat❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair We❑ Re-enter Susp Well ❑ Other: Convert to Jet Pump ❑✓ 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Stratigraphic❑ Exploratory ❑ Service ❑ 204-190 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-23227-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025906 MILNE PT UNIT H-16 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11. Present Well Condition Summary: Total Depth measured 9,967 feet Plugs measured N/A feet true vertical 4,006 feet Junk measured N/A feet Effective Depth measured 9,967 feet Packer measured 6,320 feet true vertical 4,006 feet true vertical 4,036 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 4,182' 10-3/4" 4,182' 3,139' 3,580psi 2,090psi Intermediate 6,516' 7-5/8" 6,516' 4,063' 6,890psi 4,790psi Liner 3,723' 4-1/2" 9,905' 4,010' 8,430psi 7,500psi Liner 3,658' 4-1/2" 9,967' 4,006' 8,430psi 7,500psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / L-80 / EUE 8rd 5,981' 5,956' 5,337MD Packers and SSSV (type, measured and true vertical depth) 7-5/8" x 3-1/2" FH N/A 3,710MD N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 65 33 211 200 202 Subsequent to operation: 187 17 569 2,456 210 14. Attachments (required per20 MC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ✓ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-534 Authorized Name: Chad Helgeson Contact Name: David Haakinson�/� Authorized Title: Operations Manager Contact Email: dh aakinsonCo)hilcor0.com nsr, Authorized Signalur 'rh �. l^� Date: 1/6/2020 Contact Phone: 777-8343 M Form 10-404 Revised 4/2017 f.li •�O BDMS- � JAN 10 2020 Submit Original Only nSCHEMATIC Hilcotn Alaeku, LLC Orig. KB Elev.: 70.25'/Orig. GL Bev.: 36.2ff WELLHEAD Tree 3-1/8" 5M Cameron Wellhead FMC Tubi ng Hanger, Btm 11" x 2-7/8" EUE Top & Btm TD=9,967' (MID)/TD=4,006'W/D) PBTD =9,96T(MD) / PBTD=4,006'PW) Milne Point Unit Well: MPU H-16 Last Completed: 9/14/2016 PTD: 204-190 OPEN HOLE / CEMENT DETAIL 20" Cmtw/ 260 sx of Arcticset I in 42" Hole 10-3/4" Cmt w/ 560 sx PF "L", 475 sx Class "G" in 13-1/2" Hole 7-5/8" Cmt w/ 598 sx Class "G" in 9-7/8" Hole CASING DETAIL Type Wt/ Grade/ Conn ID Top Btm Conductor 92/H-40/Welded N/A Surface 112' Surface 45.5 / L-80 / BTC 9.950 Surfacej4,182'Intermediate 8,839' OB Slotted Lnr 29.7/L-80/BTL-MOD 6.875 Surface,516'Liner"A" 9,922' 6,320' 12.6/L-80/IBT 3.958 6,182',905'Liner"B" 9,859' OA Lateral Btm Baker 41/2- Pack -off Bushing 12.6/L-80/IBT 3.958 6,309',967' TUBING DETAIL Tubing 9.2/L-80/EUE Srd 3.992 Surface 5,981' LINER DETAIL OA Slotted Lnr 12.6/L-80/IBT 3.958 6,204 8,779' OA Slotted Lnr 12.6 / L-80 /IBT 3.958 8,945' 9,859' OBSlotted Lnr 12.6/L-80/IBT 3.958 6,524' 8,839' OB Slotted Lnr 12.6/L-80/IBT 3.958 9,173' 9,922' WELL INCLINATION DETAIL KOP @ 500' MD Max Wellbore Angle = 82.4 deg @ 6,515' MD 69.0 deg @ 5,859' MD LATERAL WINDOW DETAIL Window @ 6,182' MD; Bottom @ 6,194' MD; Angle @ top of window is 76 deg JEWELRY DETAIL Depth Item (Depths based on Nabors 4ES RKB) 2,390' 3-1/2" SLB GLM w/ shear Vlv 2Kpsi IA to tbg BK latch 5,314' XD SSD Sliding Sleeve 5,324' Lower Suction Gauge 5,337' Tri -Point 7-5/8" x 3-1/2" FH Retrievable Packer 5,360' 3-1/2" XN Nipple 2.813' ID 2.75" no-go 5,949' WLEG- Bottom @5,981' 6,177' Baker Hook Wall, Hanger above 7"Window 6,194' Baker Hook Wall, Hanger below 7" Window 6,309' Baker Tie Back Sleeve 6,320' Baker ZXP Liner Top Packer 6,326' Baker 7"x5" HMC Liner Hanger 9,859' OA Lateral Btm Baker 41/2- Pack -off Bushing 9,922' OB Lateral Btm Baker 4-1/2" Pack -off Bushing GENERAL WELL INFO API: 5D-029-23227-00-00 Drilled and Cased by Doyon 14-11/01/2004 ESP Completion by Nabors 4ES - 2/16/2005 ESP Completion by ASR#1 - 9/14/2016 Convert to 1P by ASR#1 - 12/15/2019 Revised By: TDF 1/6/2020 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP H-16 ASR#1 50-029-23227-00-00 204-190 12/11/2019 12/15/2019 12/11/2019- Wednesday MIRU. Set in tool skid and sub conex. Hook up BOPE Lines, Torque up the stack, Begin winterization of rig and Pump. Safty MTG, Crew change. Cont. Winterize the rig and pump lines, NU flow spool and run 6" Flow line. lay down containment5pot in the Cat walk and Pipe Racks. Spot in tioga/jet heaters Heaters load 40 BBIs of test water into pits. make up 2-7/8" and 3.5" test mandrills,run Glycol lines. Spot in Baker Spooler. Start BOPE Test as per sundry with 2-7/8" - 3.5" Test mandrills 250psi/low 2,500psi/high on all equipment. 12/12/2019 - Thursday After finishing with the BOPE test went to Blow out Lines found that one of the Jet heaters had went down we had to thaw out Aux pump lines. spot in new heaters . Hang Sheave while thaw out the Lines. Had 50 PSI on the IA Bleed off, Pull Blanking Sub Bleed Pressure off of the BPV. Pull BPV make up landing int. BOLDS, unland tbg @50k, cont. pulling @ 45k. Run eat trace and ESP cable over sheave and tie on to the spooler. POOH 103 JNTS 2-7/8" 6.5# EUE tbg with Both heat trace and ESP +- 3507HR. Cont. POOH with 2-7/8" 6.5# EUE tbg/ ESP Cable 650'/Hr. Lay Down ESP Equipment. Start Swapping over to 3.5" 10.37# Work string 12/13/2019 - Friday Cont. clear floor, c/o handling eq. r/d sheave. P/U 7-5/8" test packer assy. - mule shoe, xo, 7-5/8" EA Retrivomatic packer, pup jt, xo =19.96'. TIH w/ assembly, p/u 3-1/2" wk string. t/ 5,364', up wt 44k, do wt 26k,. Set packer @ 5364', filled annulus, took 30 bbls, tested casing t/2,650psi for 30 min good. Release PKR, Let Elements relax while check Fluids on all equipment. POOH With 3.5" 10.37# Work string and Test PKR 133 Jnts, Lay Dow PKR. Change over to 3.5" EUE 9.2# Completion equipment rack and tally BHA,. Make Up BHA Mule shoe +jnt, 19 jnts 3.5" EUE 9.2# TBG, Pup, XN Nipple, Pup, Pup, Tri -Point 7-5/8" x 3-1/2" Retrievable Packer, Pup,Pup,3-1/2" Schlumberger Lower Suction gauge Tie in and Test Tech Line, Pup, 3.5" XD SSD Sliding Sleeve,Pup 12/14/2019 -Saturday Test Gauge connections t/5,400 psi good, test communication to Gauge, good. Had issues with SLB cannon clamp running tools, ended up getting backup set from Prudhoe. RIH w/ 3-1/2" completion t/1012', installing clamps every otherjt. Cont. RIH w/ 3-1/2" completion t/2,555'; installing clamps every otherjt. Cont. RIH w/ 3-1/2" completion t/4030', installing clamps every otherjt. Safety MTG, Service and inspect rig and equipment, Crew change. Cont. RIH w/ 3-1/2" completion t/5,942', installing clamps every otherjt. PU and MU TBG hanger ( 3.5" TC -II threads on top) Terminate Tech. line with SLB and land tbg. PU/42K SO/26K. EOT @ 5,980.63' Top of Tri -Point PKR @ 5,337.78', XN-Nipple @ 5,361.21'. Sprung a Hydraulic Leak in the side pack. A O-ring on one of the High Pressure transducer. Reverse Spot 15 BBIs of PKR Fluid with 165 BBIs of 8.3# Source Water. Drop 1.3" Ball and Rod. RU to Fill Tbg and Set Tri -Point Packer took 5 BBIs to fill tbg. 4. Pressure up the Tubing slowly to 2,500psi with the chart running. Hold a couple minutes at 2,500psi then bring up to 3,o00PSl. Hold for 20 Minutes to note that the Packer is set. 5. Lock in TBG pressure @ 1,600psi.6. Fill and Pressure up the IA to 2,500psi Chart for 30 Minutes, good. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number 1 Start Date End Date MP H-16 ASR#1 50-029-23227-00-00 204-190 12/11/2019 12/15/2019 12/15/2019 -Sunday Bleed down tubing observe valve shear in GLM, cont. bleed down, r/u LRS & rev circulate 100 bbls diesel for freeze protect, blow down & r/d LRS. Pull landingjt, crossover stayed in hole, make attempts to retrieve, no joy, suck out stack, m/u connection w/ JB weld & let set, retrieve xo w/landingjt. set BPV. RDMO, blow down circulating lines, bleed down accumulator, prep rig floor for r/d, (slips, tongs, tools & subs), layover mast, clear floor, move aux eq. to E -pad. Crew Change Service and inspect rig and equipment. Crane Operations, Load accumulator hoses, load Mud pump and tie down. Fly the work floor and load on trailer, NO and load BOPE on trailer to Bring over to E-10, NU 11" 5M Cameron Well Head Test 500/1 -ow 5,000/High Good, Pull BPV, All Checks on SLB Gauge Good. 12/16/2019 - Monday No operations to report. 12/17/2019 -Tuesday No operations to report. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU H-16 Permit to Drill Number: 204-190 Sundry Number: 319-534 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, "'t - Price Chair DATED this�day of November, 2019. 3BDMS'`�"'' NOV 2 7 2019 RECEIVE® NOV 2 0 2019 STATE OF ALASKA l/Z'6ll 0 L ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC+APPLICATION FOR SUNDRY APPROVALS gn nnc os onn 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑v Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Convert to Jet Pump ❑� 2. Operator Name: 4. Current Well Class: • 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ Stratigraphic ❑ Service ❑ 204-190 1 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23227-00-00 1 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 477.05 Will planned perforations require a spacing exception? Yes ❑ No ❑ IVA I MILNE PT UNIT H-16 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025906 MILNE POINT/ SCHRADER BLUFF OIL 1 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,967' 4,006' 9,967' 4,006' 933 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 4,182' 10-3/4" 4,182' 3,139' 3,580psi 2,090psi Intermediate 6,516' 7-5/8" 6,516' 4,063' 6,890psi 4,790psi Liner 3,723' 4-1/2" 1 9,905' 4,010' 8,430psi 7,500psi Liner 3,658' 4-1/2" 9,967' 1 4,006' 8,430psi 7,500psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 2-7/8" 6.5# / L-80 / EUE 8rd 5,916' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): ZXP Liner Top and N/A 6,320(MD) / 4,036(TVD) and N/A 12. Attachments: Proposal Summary v Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Rr Exploratory ❑ Strati ra hic g p ❑ Development R] Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 12/1/2019 Operations: OIL WINJ ❑ ElWDSPL E] GAS ❑ WAG ❑ GSTOR ❑ Suspended ElCommencing SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: David Haakinso Authorized Title: Operations Manager Cfvk ontact Email: dhaakinson hK Or .corn Contact Phone: 777-8343 Authorized Signature: Date: 11/20/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that representative may witness Sundry Number: Plug Integrity 71 BOP Test 7Q Mechanical Integrity Test ❑ Location Clearance ❑ Other: "ase) �?J<.' /J G/ le5- Z-S'-odPs: finrJs Tst' 113aMS t` NOV 2 7 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑/ Spacing Exception Required? Yes El No CSubsequent Form Required: lv ,,... o APPROVED BYa�' Approved by\\�Z COMMISSIONER THE COMMISSION Date: l Submit Form and F03 Re isetl 4 17 Approved application is valid for 12 months from the date of approval. p�� Mach ants in Duplicate ` c1 *6 ants in K IIiluorn Alaska. LL RWO — ESP to JP Conversion Well: MPU H-16 11/20/19 Well Name: MPU H-16 API Number: 50-029-23227-00 Current Status: S/I — ESP Failure Rig: ASR #1 Estimated Start Date: December 1, 2019 Estimated Duration: 5 Days Reg.Approval Req'std? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 204-190 First Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE: WelIEZ Entry Required: Yes Current Bottom Hole Pressure: Maximum Expected BHP: Max. Anticipated Surface Pressure: Original RKB: Max Inc. (Within Work Interval): Max DLS: BPV Type: 1,296 psi @ 3,930' TVD 1,326 psi @ 3,930' TVD 933 psi 20' (Nabors 4ES Completion) 73° @ 6,012' MD 6.7/100 ft @ 5,722' MD 2.5" CIW "H" 6.34 PPGE I Downhole Gauge 10/7/19 6.49 PPGE 160 -day PBU Extrapolation Gas Column Gradient (0.1 psi/ft) Brief Well Summary: Milne Point producer H-16 was drilled in 2004, and completed as a dual lateral Schrader Bluff OA and OB producer. The well was last worked over in September 2016 and has been a stable 250 BOPD producer until early September 2019, when it appears that the ESP lost efficiency. The well is known to be a solids producer. Due to the fact that the well has never received a fill cleanout, combined with historical ESP wear, a jet pump completion is proposed to offer better economics. A lateral entry module was never installed on the well and thus it is only expected that a single lateral will be cleaned out. Notes Regarding the Well & Design: • The 7-5/8" production casing passed a MIT to 1,600 psig on 9/12/16. Offset Injector Support: 51 7 days prior to RWO o H-15: Online, injecting 720 BWPD 0 1-02: Online, injecting 750 BWPD 0 1-16: Shut-in RWO Objective: 1. Pull ESP completion 2. Cleanout Run and Test Packer run. 3. Run anew 3-1/2" tubing completion with jet pump jewelry 4. Obtain passing MIT -IA Pre -Rig Procedure 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services Pump. Setup reverse out skid, returns tank, and additional upright tanks as needed. 4. Pressure test lines to 3,000 psi. 5. Bullhead 8.3 ppg source water down tubing to formation. a. Tubing volume to top of OA lateral: 53 bbls 6. Bullhead 8.3 ppg source water down the IA to formation. n fliloocu Alaska, M RWO — ESP to JP Conversion Well: MPU H-16 11/20/19 7. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 8. RD Little Red Services Pump and reverse out skid. 9. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD crane. a. Make scribe mark on tree for orientation for re -installation. b. Function test all prior to arrival of AOGCC inspectors. 10. NU BOPE house. Spot mud boat. WorkoverProcedure: 11. MIRU ASR #1 Workover rig, ancillary equipment and lines to returns tank. 12. Pull BPV after confirming zero surface wellhead pressure. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 8.3 ppg source -water priZrr2o pulling BPV. Set TWC. 13. Test BOPE to 250psi Low/ 2,500 psi High annular to 250psi Low/1,00Q'psi H�hold each ram/valve and ` test for 5 -min). Record accumulator pre -charge pressures and chart tests. i a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. 1X b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures perthe Sundry Conditions of approval. d. Test VBR rams on 2-7/8" & 3-1/2" testjoints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 14. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 15. Bleed any pressure off casing to returns tank. Pull TWC. 16. RU spoolers to pull heat trace and #2 ESP cable. 17. MU 2-7/8" landing joint and BOLDS. 18. Unseat hanger and pull over string weight on tubing and confirm free. a. The 2016 RWO (ASR #1) PU weight was 46 Klbs with a slack -off weight of 26 Klbs. b. Once hanger becomes free check for flow to insure well is dead. LD Tubing hanger. c. Contingency: (If a rolling test was conducted.) RWO — ESP to JP Conversion Well: MPU H-16 11/20/19 I3ilcora Alaska. LL i. MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 19. Pull the 2-7/8" tubing from ±5,932' MD. a. Total Clamp Count: L 506 Dual Clamps ii. 94 Collar Clamps iii. 4 Pump Protectolizers iv. 2 Flat Guards v. 45 Cross Collar Clamps vi. 4 Pump Clamps vii. 1 Band b. Send tubing to G&I for cleaning and disposal. C. Inspect XN Nipple and 2 GLMs. Clean and plan to re -stock in materials inventory. i. Note condition of pipe in report. Denote depths of any external corrosion, solids, or scale. ii. Photograph and file pictures. 20. MU 7-5/8" casing scraper assembly and TIH to ±6,050' MD. 21. Reciprocate from ±5,300' to ±5,350' and circulate 2x bottoms up from ±5,350' MD. 22. POOH and lay down casing scraper BHA assembly. 23. PU serviced 7-5/8" test packer and RIH to ±5,340' MD. 24. Pressure Test 7-5/8" casing to 2,500 psig for 30 minutes. [ kp a. If pressure test fails, begin moving up -hole and testing in intervals to determine possible leak point. 25. POOH w/ test packer and lay down equipment. 26. Call out Baker Hughes to run downhole gauges on completion. 27. PU 3-1/2" tubing completion and space out as followed: a. WLEG b. —20 joints of 3-1/2" tubing c. Pup Joint: 3-1/2" L-80 tubing d. 3-1/2" XN Nipple (2.75" ID) w/ RHC plug body e. Pup Joint: 3-1/2" L-80 tubing f. Retrievable Packer (7-5/8" x 3-1/2" Packer) @ ±5,340' MD g. Pup Joint: 3-1/2" L-80 tubing h. Suction Gauge i. Pup Joint: 3-1/2" L-80 tubing o f j. 3-1/2" XD Sliding Sleeve (Closed Position) @ ±5,300' MD ��f r k. Pup Joint: 3-1/2" L-80 tubing I. —94 joints of 3-1/2" tubing m. 3-1/2" GLM with SOV set at 2,000 psig IA to T @ ±2,380' MD n. —75 joints 3-1/2" L-80 tubing o. Tubing hanger H Hil.am Alaska, LU RWO — ESP to JP Conversion Well: MPU H-16 11/20/19 28. Run tubing completion in hole, spacing out to set packer @ ±5,340' MD 29. Prior to seating overshot, reverse circulate 12 bbls of 1% CRW (or equivalent corrosion inhibitor) source water, followed by 175 bbls of untreated source water down IA. a. This will spot corrosion inhibited fluid between packer and sliding sleeve. 30. Obtain pick-up and slack -off weights and note band/clamp summary. 31. Land the tubing hanger. Terminate downhole gauge wire. 32. Drop ball and rod and allow to fall on seat in RHC plug body in XN nipple. 33. Increase the tubing pressure and test the tubing to 3,000 psig. 34. Set packer per packer setting procedure. 35. Bleed down the tubing to 1,500 psig. 36. Pressure IA up to 2,800 psig and perform a Charted MIT -IA for a minimum target pressure of 2,500 psi for 30 min (charted). a. 37. Bleed tubing pressure to shear out the shear -out GLV in the GLM at±2,380' MD. 38. Pump 94 bbls of diesel down the IA and U-tube to the tubing to, freeze protect the well. 39. Bleed tubing and inner -annulus pressures to zero. 40. RILDS and LD landing joint. 41. Set BPV. 42. Test tubing hanger void to 500 psig low/ 5000 psig high. 43. RD Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. Post WorkoverProcedure: 44. RD mud boat. RD BOPE house. 45. RU crane. ND BOPE. Pull BPV. Set TWC. 46. NU 3-1/8" 5,000# tree and adapter flange and test to 500 psi low/5,000 psi high. 47. Pull TWC. RD crane. 48. Move returns tank and rig mats. 49. Turn well over to wells team for post rig slickline work. 50. RU Slickline a. Pull Ball & Rod from XN-Nipple b. Set Catcher in XN-Nipple c. Pull SOV from GLM @ ±2,380' MD d. Set DV in GLM @ ±2,380' MD e. Shift open XD Sliding Sleeve �S f. Install je pump in XD sliding sleeve. I�LLr, Citt g. RD Slickline. h. Turn well over to operations. Attachments: 1. As -built Schematic 2. Proposed Schematic 3r to H IIiI"n, Mask,,, LLQ 3. BOP Schematic RWO— ESP to JP Conversion Well: MPU H-16 11/20/19 H Hilcom Alaska. I SCHEMATIC Milne Point Unit Well: MPU H-16 Last Completed: Proposed PTD: 204-190 WELLHEAD OPEN HOLE/ CEMENT DETAIL Wellhead FMC Tubing Hanger, 20" Curt w/ 26o sx of Arcticset l in 42' Hole On& KB Elew.: 70.25'/Orig. GL Elev.: 36.20' 11" x 2-7/8" EUE Too & etm 10-3/4" Cmt w/ 560 sx PF "L", 475 sx Class "G" in 13-1/2" Hole RKB-Hanger: 20.00' (Nabors 4ES) 17-5/8" Cmt w/ 598 sx Class "G" In 9-7/8" Hole 10-3/4- 41 889 10 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 92/H-40/Welded N/A Surface 112' 10-3/4" Surface 45.5/L-80/BTC 9.794 Surface 4,182' 7-5/8" Intermediate 29.7/L-80/BTC-MOD 6.151 Surtace 6,516' 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 6,182' 9,905' 4-1/2" Liner "B" 12.6 / L-80 / IBT 3.833 6,309' 9,967' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE Srd 2.441 Surf 5,916' LINER DETAIL 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 6,204' 8,779' 4-1/2" 1 OA Slotted Lnr 12.6/L-80/IBT 1 3.833 8,945' 9,859' 4-1/2" OB Slotted Lnr 12.6 / L-80 / IBT 3.833 6,524' 8,839' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 9,173' 9,922' WELL INCLINATION DETAIL KOP @ 500' MD Max Wellbore Angle= 82.4 deg @ 6,515' MD 69.0 deg @ 5,859' MD LATERAL WINDOW DETAIL Top of "OA" Window @ 6,182' MD; Bottom @ 6,194' MD; Angle @ top of window is 76 deg JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 159' ST2:2-7/8" GLM 2.875" x 1" KBMM w/ Dual Screen Orifice 2 3,500' Heat Trace (3,500'spool) 3 5,663' mmy Valve ST 1: 2-7/8" GLM 2.875" x I" KBIPacking 4 5,808' 2-7/8" XN Profile (2.205" No-Goore ID)5 5,861.6' Discharge Head-FPHVDIS 6 5,862' Pump-119LEX105XD H6 7 5,886' Gas Separator-GRSFrXAR H6 8 5,890' Upper Ta ndem Seal-GSB3DB 59 5,897' Lower Ta ndem Seal-GSB3 DB SB 30 5,904' Motor - CLS" MSP3-250 11 5,912' Phoenix XT -150 Sensor 12 5,914' Centralizer-Bottom@5,916' 13 6,177 Baker Hook Wall, Hanger above 7- Window 14 6,194' Baker Hook Wall, Hanger below 7" Window 15 6,309' Baker Tie Back Sleeve 16 6,320' Baker ZXP Liner Top Packer 17 6,326' Baker7"x5"HMC Liner Hanger 18 9,859' OA Lateral Btm Baker 4-1/2" Pack -off Bushing 19 1 922' OB Lateral Btm Baker 4-1/2" Pack -off Bushing 'CK Lateral 16 15 } 17 19 "OB" LalerJ 7-5/8' TD=9,%7 (MD)/TD=4,O06'(TVD) PBTD=9,967 (M)) / PBTD=4,0D6'(TVD) GENERAL WELL INFO API: 50-029-23227-00-00 Drilled and Cased by Doyon 14-11/01/2004 ESP Completion by Nabors 4ES - 2/16/2005 ESP Completion by ASRpl-9/14/2016 Revised By: TDF 9/26/2016 n coru Alusku. LI.0 Qig. KB Elev.: 70.25/ Odg. GL Bev.: 36.2(Y RKB- Hanger: 20.00 (Nabors 4ES) PROPOSED WELLHEAD Tree 3-1/8" SM Cameron Wellhead FMCTubing Hanger, Top 11" x 2 WE & Btm Milne Point Unit Well: MPU H-16 Last Completed: 9/14/2016 PTD: 204-190 OPEN HOLE/ CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42" Hole 10-3/4" Cmt w/ 560 sx PF "L", 475 sx Class "G" in 13-1/2" Hole 7-5/8" 1 Cmt w/ 598 sx Class "G" in 9-7/8" Hole CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92/H-40/Welded N/A Surface 112' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 4,182' 7-5/8" Intermediate 29.7/L-80/BTC-MOD 6.875 Surface 6,516' 4-1/2" Liner"A" 12.6/L-80/HIT 3.958 6,182' 9,905' 4-1/2" Liner "B" 12.6 / L-80 / IBT 3.958 6,309' 9,967' TUBING DETAIL 3-1/2" Tubing 9.2/L-80 /EUE 8rd 3.992 Surface ±5,987' LINER DETAIL 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.958 6,204' 8,779' 4-1/2" OA Slotted Lnr 12.6 / L-80 /IBT 3.958 8,945' 9,859' 4-1/2" OB Slotted Lnr 12.6 / L-80 / IBT 3.958 6,524' 8,839' 4-1/2" OB Slotted Lnr 12.6 / L-80 / IBT 3.958 9,173' 9,922' WELL INCLINATION DETAIL ROP @ 500' M D ax Wellbore Angle= 82.4 deg @ 6,515' MD 69.0 deg @ 5,859' MD LATERAL WINDOW DETAIL Top of "OA" Window @ 6,182' MD; Bottom @ 6,194' MD; Angle @ top of window is 76 deg JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 ±2,380' 3-1/2" Gas Lift Mandrel 2 ±5,300' XD Sliding Sleeve 3 ±5,324 Lowers ction Gauge 4 ±5,340' Retrievable Packer(? -5/8" x 3 5 ±5,365' XN Nipple 6 ±5,985' WLEG- Bottom @ ±5,987' 7 6,177' Baker Hook Wall, Hanger above 7" Window 8 6,194' Baker Hook Wali, Hanger below 7" Window 9 6,309' Baker Tie Back Sleeve 10 6,320' Baker ZXP Liner Top Packer 11 6,326' Baker 7"x5" HMC Liner Hanger 12 9,859' OA Lateral Btm Baker 4-1/2" Pack -off Bushing 13 9,922' OB Lateral Btm Baker 4-1/2" Pack -off Bushing "Cl4"Lateral 9 i 10. 11 13 "OB'lateral 7-5/8 TD=9,%7 (MJ)/TD=4,006'M) PBTD =9,967 (ND) / PBTD = 4,OW(TVD) GENERAL WELL INFO API: 50-029-23227-00-00 Drilled and Cased by Doyon 14-11/01/2004 ESP Completion by Nabors 4ES- 2/16/2005 FSP Completion by ASR#1-9/14/2016 Revised By: TDF 11/14/2019 Milne Point ASR Rig 1 BOPE 2019 11" BOPE Updated 5/14/2018 2-7/8" x 5" VBR lind ,es STATE OF ALASKA RECEIVED AL411,A OIL AND GAS CONSERVATION COMION Or, 2016 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U mown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well Q Re-enter Susp Well❑ Other: ESP Changeout Q 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Exploratory ❑ 204-190 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-23227-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 MILNE PT UNIT SB H-16 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 9,967 feet Plugs measured N/A feet true vertical 4,006 feet Junk measured N/A feet Effective Depth measured 9,967 feet Packer measured 6,320 feet true vertical 4,006 feet true vertical 4,036 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 4,182' 10-3/4" 4,182' 3,139' 3,580psi 2,090psi Intermediate 6,516' 7-5/8" 6,516' 4,063' 6,890psi 4,790psi Liner 3,723' 4-1/2" 9,905' 4,010' 8,430psi 7,500psi Liner 3,658' 4-1/2" 9,967' 4,006' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic (��f r NNED True Vertical depth See Attached Schematic 1 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 5,916' 3,934' Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 380 0 Subsequent to operation: 193 51 293 180 153 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Developments Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-439 Contact Stan Porhola Email sporhola(c�hilcorp.com Printed Name Bo York Title Operations Engineer Signature / e•: w•> Phone 777-8345 Date 10/17/2016 r 7z --a / Form 10-404 Revised 5/2015 td RBDMS G lAL 121St�bmit •Original Only • H . O Milne Point Unit Well: MPU H-16 SCHEMATIC Last Completed: Proposed rlr�Alaska.i.u; PTD: 204-190 WELLHEAD OPEN HOLE/CEMENT DETAIL Wellhead FMC Tubing Hanger, 20" Cmt w/260 sx of Arcticset I in 42"Hole Orig.KB Elev.:70.25'/Orig.GL Elev.:36.20 --. 11 x 2-7/8"EUE Top&Btm 10-3/4" Cmt w/560 sx PF"L",475 sx Class"G"in 13-1/2"Hole RKB Hanger:20.00(Nabors 4ES) 7-5/8" Cmt w/598 sx Class"G"in 9-7/8"Hole `, _i. tri, CASING DETAIL o 20" ' Size Type WV Grade/Conn Drift ID Top Btm 120" Conductor 92/H40/Welded N/A Surface 112' ,y 10-3/4" Surface 45.5/L-80/BTC 9.794 Surface 4,182' s: rt 44, 4. 7-5/8" Intermediate 29.7/L-80/BTC-MOD 6.151 Surface 6,516' t,; r:,' 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 6,182' 9,905' a °..04 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 6,309' 9,967' ", TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 5,916' "4« LINER DETAIL '44-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 6,204' 8,779' «+ 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 8,945' 9,859' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 6,524' 8,839' a. «. 4-1/2" OB Slotted Lnr 12.6/L-80/18T 3.833 9,173' 9,922' WELL INCLINATION DETAIL 103/4'iib AV KOP @ 500'MD Max Wellbore Angle=82.4 deg @ 6,515'MD 69.0 deg @ 5,859'MD LATERAL WINDOW DETAIL Top of"OA"Window @ 6,182'MD;Bottom @ 6,194'MD;Angle @ top of window is 76 deg JEWELRY DETAIL No Depth Item(Depths based on Nabors 4ES RKB) 1 159' ST 2:2-7/8"GLM 2.875"x 1"KBMM w/Dual Screen Orifice 2 3,500' Heat Trace(3,500'spool) 3 5,663' ST 1:2-7/8"GLM 2.875"x 1"KBMM w/Dummy Valve 4 5,808' 2-7/8"XN Profile(2.205"No-Go Packing Bore ID) 5 5,861.6' Discharge Head-FPHVDIS 3 6 5,862' Pump-119LEX10 SXD H6 7 5,886' Gas Separator-GRSFTXAR H6 8 5,890' Upper Tandem Seal-GSB3DB SB/SB PFSA y ;a 9 5,897' Lower Tandem Seal-GSB3DB SB/SB PFSA 1, Y 4 b'` 10 5,904' Motor-CL5"MSP3-250 t" 11 5,912' Phoenix XT-150 Sensor 12 5,914' Centralizer-Bottom @ 5,916' 11 1+ Ir 6 13 6,177' Baker Hook Wall,Hanger above 7"Window s.< 14 6,194' Baker Hook Wall,Hanger below 7"Window ' ii r 7 15 6,309' Baker Tie Back Sleeve 4 16 6,320' Baker ZXP Liner Top Packer 8&9 17 6,326' Baker 7"x 5"HMC Liner Hanger 'Y a k 18 9,859' OA Lateral Btm Baker 4-1/2"Pack-off Bushing 10 19 9,922' OB Lateral Btm Baker 4-1/2"Pack-off Bushing 1 F GENERAL WELL INFO 14: 11 1API:50-029-23227-00-00 l, 12 to Drilled and Cased by Doyon 14-11/01/2004 4,t,,, a;13 i ESP Completion by Nabors 4ES-2/16/2005 t; ':1'''.14 18 ESP Completion by ASR#1-9/14/2016 15,`< Ai 16t 17 19 Ar- "OB"Latera 7-5/8" TD=9,967'(MD)/TD=4,006'(TVD) PBTD=9,967'(MD)/PBTD=4,006'(TVD) Revised By:TDF 9/26/2016 41110 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP H-16 ASR#1 50-029-32270-00-00 204-190 9/9/16 9/14/16 Daily Operations: 9/7/2016-Wednesday No activity to report. 9/8/2016-Thursday No activity to report. 9/9/2016- Friday Move Rig & Equipment from F pad to H-16, Spot Mud Boat& Mud Pits on H-16, Spot office trailer&Change house, Rig up Little Red Services, Kill Well,Attempt to Circulate down tubing with 8.5 PPG 70 bbls Seawater, no returns, Bullhead 200 bbls of 140 degree seawater down back side @ 80 psi. Install BPV, Rig Little Red down. Nipple down production tree, Inspect tubing hanger threads, Nipple up BOPS, (AOGCC was notified of right to witness BOP Test on 9/08/2016 @ 14:26 Hrs.) ASRC Crane Assisted in Setting Well Enclosure, Install Rig Floor, Spotted Cat Walk,Tool Pusher Shack, Rig up Accumulator Lines to Bop Stack (Sundry Meeting with Crew MPH-16 Procedure} Hilcorp ASR Rig 1 Arrived on Location @ 0300 hrs. Backed Rig in over Well, Raise and Pin Derrick. Electricians Connected Fire and Gas Alarms and Bump Tested. 9/10/2016-Saturday Attempted to pull BPV, Gas was observed below BPV, Pumped 30 bbls of seawater down tubing through BPV, Set TWC. Rig up for BOP Test, Repair Work on Accumulator on Actuator Valve.Test BOP per AOGCC Requirements,Tested with 2.875" Test Joint to 250/2,500 PSI Test Annular to 250/1,500 psi. Performed Accumulator test.Test was witnessed by AOGCC Johnnie Hill. Pull TWC, Install Landing joint in Hanger, Back out LDS, Pull Tubing Hanger at 46K pick up weight, Lay down Hanger& landing joint.TOOH, laying down 2-7/8" Tubing and 3,465' of heat trace. Currently 121 Joints out @ 2,138'. 9/11/2016-Sunday Service Rig, Check fluids on Equipment. Continue to TOOH laying down 2-7/8" Tubing. Break& lay down ESP Assembly, Note: about 2' of formation sand was observed on the discharge head. Rig down Elephant Trunk, Clean & Clear Rig Floor of ESP Equipment &Tools, Load &tally 190 Joints of New 2-7/8"Tubing on Racks. Make up 6-3/4" bit, 7-5/8" Casing scraper& bit sub &XO &TIH with 2-7/8" Tubing to 6,177 ft. Reciprocate Casing From 6,080' to 6,115' & 6,147'to 6,177'. 3 Times Each @ 6,177'. P/U/W=33K S/O/W=17K.Trouble Shoot ASR Rig Equipment, Greased Top Drive Tracking Bearings and Carrier Tracking. Trip out of the Hole Lay down 2-7/8". 9/12/2016- Monday Continue to TIH Picking up 2-7/8"Tubing & Halliburton 7.5/8" Champ Packer F/ 1,400' to 6,100'. Set 7-5/8" Halliburton C5 Champ Packer COE @ 6,115' Fill Backside with 50 bbls of Seawater, Close Rams &Test Casing to 16,00 psi. Charted for 30 minutes, bleed off pressure, Open Pipe Rams, release Packer. TOOH, Laying down 2.875"Tubing 7-5/8" Champ IV Storm packer. Make up and Service ESP Completion Pump Assembly.TIH W/ESP Completion Assembly, Check Cable Every 2,000' to 2,581'. S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP H-16 ASR#1 50-029-32270-00-00 204-190 9/9/16 9/14/16 Daily Operations: p E rt. et 9/13/2016-Tuesday Service rig, Check fluid in all equipment.TIH with ESP Assembly& 2-7/8" tubing with Heat trace. (Total Joints Ran 181) (Dual Clamps= 506) (Collar Clamps=94)( Pump Clamps=4) ( Cross Clamps=45)(Protectorlizers=4) (Flat Guard =2)(Bands=1). Make up Tubing Hanger Align Penetrator's with Flow Line, Install field connector for heat trace & ESP cable. Land Tubing Hanger Run in LDS Break out lay down Landing Joint P/U/W=46k S/O/W=26k. Well Head Rep Installed TWC Valve in Hanger. Prep Rig Floor and Derrick, Blow down and Disconnect Kill and Choke Lines, N/D Bop Stack To Four Bolts, Disconnect Accumulator Hoses From Bop, Northern Energy Hauling Misc. Rig Equipment to MPI-03, Electricians out t/ location t/disconnect rig fire and gas system. • 111 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP H-16 ASR#1 50-029-23227-00-00 204-190 9/9/16 9/14/16 Daily Operations: 9/14/2016 -Wednesday Lay Derrick over, Move Rig to I Pad, Remove Rig Floor& Well Cover&transport to I Pad.;Nipple Down BOPs Nipple up Production tree, Test Hanger void to 500/5000 psi.;Pull BPV, Release Rig from MPH-16 @ 1200 Hrs. 9-14-16, turn well over to Production. 9/15/2016-Thursday No activity to report. 9/16/2016- Friday No activity to report. 9/17/2016-Saturday No activity to report. 9/18/2016 -Sunday No activity to report. 9/19/2016- Monday No activity to report. 9/20/2016-Tuesday No activity to report. ' • „\�' /2 THE STATE Alaska Oil and Gas of ASKA Conservation Commission :x,1,.4 }£t 333 West Seventh Avenue r GOVERNOR BILL WALKER �..r . ""'Anchorage, Alaska 99501-3572 Main: 907.279.1433 °4bALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager �� SE? 2.05 Hilcorp Alaska, LLC S� 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU H-16 Permit to Drill Number: 204-190 Sundry Number: 316-439 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P/4"-.4'251 — Cat P. Foerster Chair DATED this I day of September, 2016. RBDMS LV SEP - 1 2016 • • RECEIVED STATE OF ALASKA a G 2 6 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 31, 6 APPLICATION FOR SUNDRY APPROVALS OGGC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well Q Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program El Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Changeout Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC Exploratory ❑ Development 0 , 204-190 0 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23227-00-00 ' 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 477.05 ' Will planned perforations require a spacing exception? Yes ❑ No Q / MILNE PT UNIT SB H-16 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 ' MILNE POINT/SCHRADER BLUFF OIL* 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,967' 4,006' " 9,967' ` 4,006' • 875 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 4,182' 10-3/4" 4,182' 3,139' 3,580psi 2,090psi Intermediate 6,516' 7-5/8" 6,516' 4,063' 6,890psi 4,790psi Liner 3,723' 4-1/2" 9,905' 4,010' 8,430psi 7,500psi Liner 3,658' 4-1/2" 9,967' 4,006' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 5,920' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ZXP Liner Top and N/A . 6,320(MD)/4,036(TVD)and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development Qr Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/8/2016 Commencing Operations: OIL Q . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porholafl Email sporholal.V hilcorp.com Printed Name Bo York Title Operations Manager Signature Phone 777-8345 Date 8/25/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 31Le — y5 Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 'ZcOD est E,Cir f,tar Y'(Lu'SSU►2.g. 44— Sbk Post Initial Injection MIT Req'd? Yes 0 No 01 Spacing Exception Required? Yes ❑ No L� Subsequent Form Required: 10 -40 4 RBDMS LvSEP - 1 2016 i ' APPROVED BY Approved by-( 4,1% ia` (�vj�L./ --- COMMISSIONER THE COMMISSION Date:9._/.... /42/6. Gi4,41sta sis% ib Submit Form and Form 10-403 Revised 171/ 015 Ila 12 months from the date of approval. Attachments in Duplicate • Well Prognosis Well: MPU H-16 Hilcorp Alaska,LLQ Date:8/24/2016 Well Name: MPU H-16 API Number: 50-029-23227-00 Current Status: SI Oil Well [ESP] Pad: Milne Point H-Pad Estimated Start Date: September 8th, 2016 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 204-190 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,275 psi @ 4,000' TVD (Last BHP measured 8/24/2016) Maximum Expected BHP: 1,275 psi @ 4,000' TVD (No new perfs being added, EMW=6.13 ppg) MPSP: 875 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: .SS et-kW MPU H-16 was drilled in 2004 using Doyon 14 and completed as a dual-lateral in the Schrader Bluff OA and OB sands with an ESP completion. The ESP was replaced using Nabors 4ES in February 2005. The well is currently in-active (ESP has failed). Notes Regarding Wellbore Condition • Casing tested to 2,500 psi down to 6,315' MD(7-5/8"float collar) on 10/21/2004. 4e Co ' POPS . PPrG i - ¶ 1,50-r mow., .- - . t-Asa $133116 Objective: Pull failed ESP (failed August 2016),test the 7-5/8" production casing and run a new ESP. / Brief RWO Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD Crane. 1 9. NU BOPE house. Spot mud boat. WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. • • • Well Prognosis Well: MPU H-16 Hilcorp Alaska,LD Date:8/24/2016 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg sea water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/ 1,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test.-./ c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8"test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure f conduct a rolling test, Test the rams and annular with the pump continuing to pump, (monitor ./ the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection,etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg sea water as needed. 15. MU landing joint or spear and recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 16. POOH and lay down the 2-7/8" tubing. Tubing will be replaced (entire string). Salvage the top 65 joints of tubing for cleaning and inspection.Junk all remaining tubing and jewelry. 17. Lay down failed ESP. Collect samples of any solids and test for scale. 18. RIH with 7-5/8" 29.7#scraper assembly to^'6,177' MD (OA window) on 2-7/8" tubing. Circulate the well clean. 19. If needed, spot sized salt pill to control losses. POOH and LD tubing. 20. PU 7-5/8" 29.7#test packer and RIH to—6,100' MD. ✓21. Pressure test casing to 1,500 psi for 30 charted minutes. POOH and LD test packer and tubing. 22. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP at±5,900' MD. 23. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. • 41, Well Prognosis Well: MPU H-16 Hilcorp Alaska,LL) Date:8/24/2016 24. Set BPV. 25. Rig down ASR#1. Post-Rig Procedure: 26. RD mud boat. RD BOPE house. Move to next well location. 27. RU crane. ND BOPE. 28. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 29. RD crane. Move 500 bbl returns tank and rig mats to next well location. 30. Replace gauge(s) if removed. 31. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. FWD Circ to Kill Tank Flow Diagram 6. REV Circ to Kill Tank Flow Diagram 7. Bleed to Pits Flow Diagram 8. Blank RWO MOC Form . • • Milne Point Unit 11 Well: MPU H-16 SCHEMATIC Last Completed: 2/16/2005 Hamra Alaska,LLC PTD: 204-190 WELLHEAD OPEN HOLE/CEMENT DETAIL Orig.KB Elev.:70.25'/Orig.GL Elev.:36.20' FMC Tubing Hanger, 20" Cmt w/260 sx of Arcticset I in 42"Hole Wellhead RKB-Hanger:20.00'(Nabors 4ES) 11"x 2-7/8"EUE Top&Btm 10-3/4" Cmt w/560 sx PF"L",475 sx Class"G"in 13-1/2"Hole L 7-5/8" Cmt w/598 sx Class"G"in 9-7/8"Hole to 20 2* 1 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm r 20" Conductor 92/H-40/Welded N/A Surface 112' 10-3/4" Surface 45.5/L-80/BTC 9.794 Surface 4,182' . 7-5/8" Intermediate 29.7/L-80/BTC-MOD 6.151 Surface 6,516' 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 6,182' 9,905' is 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 6,309' 9,967' Y 2 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 5,920' - LINER DETAIL _' g t 4- 1/2" OA Solid Liner 12.6/L-80/IBT 3.833 6,182' 6,204' 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 6,204' 8,779' 4-1/2" OA Solid Liner 12.6/L-80/IBT-Mod 3.833 8,779' 8,945' 10-3/4"* -118i.' O 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 8,945' 9,859' 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 9,859' 9,905' 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 6,309' 6,524' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 6,524' 8,839' 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 8,839' 9,173' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 9,173' 9,922' 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 9,922' 9,967' "' V') JEWELRY DETAIL .) s No Depth Item(Depths based on Nabors 4ES RKB) 1 139' ST 3:2-7/8"GLM 2.875"x 1"KBMM(BK-DGLV Set 8/23/16) 2 2,104' ST 2:2-7/8"GLM 2.875"x 1"KBM M(BK-DGLV Set 2/16/05) 3 3,465' Heat Trace(3,000'spool) 4 5,684' ST 1:2-7/8"GLM 2.875"x 1"KBMM(BK-DGLV Set 2/16/05) 4 5 5,836' 2-7/8"XN Profile(2.205"No-Go Packing Bore ID) 6 5,859' Discharge Head 7 5,860' Centrilift ESP:GC2200 122 Stages :- ,', 8 5,881' Gas Separator 44 5 ii, 9 5,886' Tandem Seal Section :a t* 10 5,900' Single ESP Motor(152 HP each;re-rated 110 HP) ,;:6 11 5,918' Phoenix MS-1 Sensor w 6 fin Centralizer-Bottom @ 5,920' 14 I t" 12 6,177' Baker Hook Wall,Hanger above 7"Window iot " 13 6,194' Baker Hook Wall,Hanger below 7"Window ilii ;r 8 14 6,309' Baker Tie Back Sleeve i » ' 15 s 6,320' Baker ZXP Liner Top Packer 9 16 6,326' Baker 7"x 5"HMC Liner Hanger 91 afte - ;.,, 17 9,859' OA Lateral Btm Baker 4-1/2"Pack-off Bushing Alli. 3 10 18 9,922' OB Lateral Btm Baker 4-1/2"Pack-off Bushing '<11 LATERAL WINDOW DETAIL Top of"OA"Window @ 6,182'MD;Bottom @ 6,194'MD;Angle @ top of window is 76 deg , ,, 12 -43 13 WELL INCLINATION DETAIL a 17 ,,,, KOP @ 500'MD , pq"Lateral Max Wellbore Angle=82.4 deg @ 6,515'MD ' 14 V• 44.* 69.0 deg @ 5,859'MD 15`Nff 16 "OB"Lateral 18 GENERAL WELL INFO 7-5/8" API:50-029-23227-00-00 TD=9,967'(MD)/TD=4,006'(TVD) Drilled and Cased by Doyon 14-11/01/2004 PBTD=9,967'(MD)/PETD=4,006'(TVD) ESP Completion by Nabors 4ES-2/16/2005 Downhole Revised:8/23/2016 Revised By:STP 8/24/2016 • 0 Milne Point Unit II Well: MPU H-16 PROPOSED Last Completed: Proposed -flacon,:1laska.L1PTD: 204-190 WELLHEAD OPEN HOLE/CEMENT DETAIL Orig.KB Elev.:70.25'!Orig.GL Elev.:36.20' FMC Tubing Hanger, 20" Cmt w/260 sx of Arcticset I in 42"Hole Wellhead 11"x 2-7 8"EUE Top&Btm 10-3/4" Cmt w/560 sx PF"L",475 sx Class"G"in 13-1/2"Hole RKB-Hanger:20.00'(Nabors 4ES) / � • 7-5/8" Cmt w/598 sx Class"G"in 9-7/8"Hole F CASING DETAIL 1 Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 92/H-40/Welded N/A Surface 112' s 10-3/4" Surface 45.5/L-80/BTC 9.794 Surface 4,182' 7-5/8" Intermediate 29.7/L-80/BTC-MOD 6.151 Surface 6,516' 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 6,182' 9,905' 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 6,309' 9,967' ; TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 5,900' LINER DETAIL I Y kXl 2 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 6,182' 6,204' 4 e. 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 6,204' 8,779' a 4-1/2" OA Solid Liner 12.6/L-80/IBT-Mod 3.833 8,779' 8,945' 10.3/4",>, ii; 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 8,945' 9,859' 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 9,859' 9,905' 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 6,309' 6,524' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 6,524' 8,839' 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 8,839' 9,173' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 9,173' 9,922' 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 9,922' 9,967' JEWELRY DETAIL No Depth Item(Depths based on Nabors 4ES RKB) 1 150' ST 2:2-7/8"GLM 2.875"x 1"KBMM(BK-SOGLV Proposed) 2 3,400' Heat Trace(3,500'spool) 3 5,660' ST 1:2-7/8"GLM 2.875"x 1"KBMM(BK-Dummy Valve Proposed) 4 5,816' 2-7/8"XN Profile(2.205"No-Go Packing Bore ID) 3 5 5,839' Discharge Head 6 5,840' Centrilift ESP:FLEX10 7 5,861' Gas Separator 8 5,866' Tandem Seal Section 9 5,880' Single ESP Motor(100 HP) 1 1 10 5,898' Phoenix XT-150 Sensor w 6 fin Centralizer-Bottom @ 5,900' L f 5 11 6,177' Baker Hook Wall,Hanger above 7"Window 6 [ 1 7 12 6,194' Baker Hook Wall,Hanger below 7"Window 13 6,309' Baker Tie Back Sleeve 14 6,320' Baker ZXP Liner Top Packer 15 6,326' Baker 7"x 5"HMC Liner Hanger I' ) 8 16 9,859' OA Lateral Btm Baker 4-1/2"Pack-off Bushing 17 9,922' OB Lateral Btm Baker 4-1/2"Pack-off Bushing I 9 in, is LATERAL WINDOW DETAIL Top of"OA"Window @ 6,182'MD;Bottom @ 6,194'MD;Angle @ top of window is 76 deg 11 12 16 WELL INCLINATION DETAIL r A- KOP @ 500'MD ii "0A Lateral Max Wellbore Angle=82.4 deg @ 6,515'MD 69.0 deg @ 5,859'MD 14,4.. 15 17 GENERAL WELL INFO "0Lateral 7-5/8" 6' A API:50-029-23227-00-00 Drilled and Cased by Doyon 14-11/01/2004 TD=9,967'(MD)/TD=4,0000 VD) ESP Completion by Nabors 4ES-2/16/2005 PBTD=9,967'(MD)/PBTD=4,0061WD) Downhole Revised:Proposed Revised By:STP 8/24/2016 • ! . Et Milne Point ASR Rig 1 BOPE Ifileorp%tax.LU: 11" BOPE , Stripping Head 1 3.98' '— Ji Shaffer 11"- 5000 Iii iii ifl fit It Am II-- Arimil III 1111.11 IV II CI t, -U P _� °@ VBR or Pipe Rams 4.54 i Ift Y,o,'3 INC 11"- •� _� � 5000 �= Blind r,s Ilio1I11 11 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves i 111 i r: f—s— - 2.00 ifir'—p ' cif r it �i: - p. Jro C i ( -_' i i * 1 rif j _I & i `J" Manual Manual Manual HCR Updated 8/19/2015 • 0 MPU H-16 • EXISTING TREE/WELLHEAD Wellhead/Tree Milne Point Unit Hilcorp Alaska,LLC tyt Mik_ {it III 111 4'J4 i `. >4C� 2 9/16" CIW 5M Swab Valve o 0 g, III 2 9/16" CIW 5M Wing Valve 0 2 9/16" CIW 5M SSV ,.r with Cameron actuator K /11 I1 `� , p = -6/..._ 2 9/16" CIW 5M Master Valve o © 0,n, 11 Ali fit • 11"x 2 9/16"FMC 5M r ! 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Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 ,hyf QED FEB I 2012 Mr. Tom Maunder a0(* 1 / 0 Alaska Oil and Gas Conservation Commission t-- I/ (a 9 333 West 7 Avenue Anchorage, Alaska 99501 `r 1 Subject: Corrosion Inhibitor Treatments of MPH -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPH -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPH -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPH -01 1900860 50029220610000 Dust Cover NA NA NA 6.8 9/4/2011 MPH -02 1900870 50029220620000 Sealed Conductor NA NA NA NA NA MPH -03 1900880 50029220630000 Sealed Conductor NA NA NA NA NA MPH-04 1900890 50029220640000 Sealed Conductor NA NA NA NA NA MPH -05 1950980 50029225720000 1.3 NA 1.3 NA 11.9 8/17/2011 MPH -06 1951150 50029225800000 0.2 NA 0.2 NA 5.1 10/9/2011 MPH -07A 2020240 50029225970100 6 NA 6 NA 59.5 10/31/2009 MPH -08B 2010470 50029228080200 1.2 NA 1.2 NA 17.0 9/4/2011 MPH -09 1971650 50029228040000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -10 1971490 50029227950000 1.2 NA 1.2 NA 11.9 10/31/2009 MPH -11 1971630 50029228020000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -12 1971700 50029228070000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -13A 2021670 50029228180100 0.8 NA 0.8 NA 8.5 8/17/2011 MPH -15 2051590 50029232840000 0.5 NA 0.5 NA 5.1 8/17/2011 - QA• MPH -16 2041900 50029232270000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -17 2070660 50029233580000 1.3 NA 1.3 NA 13.6 8/17/2011 MPH -18 2041740 50029232240000 18.6 NA Need top job MPH -19 2071360 50029233710000 0.1 NA 0.1 NA 2.6 9/4/2011 • • k-' q.. MICROFILMED 03/0'1/2008 DO NOT PLACE .,~~, ~:.. t~f~br. ~, ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs InsertslMicrofilm Marker.doc I Dec:.../ DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Permit to Drill 2041900 Well NamelNo. MILNE PT UNIT SB H-16 Operator BP EXPLORATION (ALASKA) INC >,,~ !f..{ b~ ~ ~ API No. 50-029-23227-00-00 MD 9967./ TVD 4006...... Completion Date 11/1/2004 Completion Status 1-01L Current Status 1-01L UIC N -----~~----~---~-_.~--~--~-~--_. -~~----._---_._-_.~~_._---_.~._--~---_._._-~-~._-,._.-._-,.__.._~--- -_._--_.._---------~,_..~-,~.._~,------~--~----_.--,.------,-~------,-_..._--_..._~~"._--~-_._~._---_._-------'-"--"--'--'-'~-- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ----_._---",.~----_._-_.~--- ~._--_.__.~-_._-- _..-."----_._~----~--- -~--_._- --~--_._-_._-- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, Photo GYRO, GYRO, ABI, IFR I CASANDRA Well Log Information: (data taken from Logs Portion of Master Well Data Maint Logl Electr . Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments 'ED D Tap --1'2936 Gamma Ray 67 7320 11/25/2004 -------.--.-.-, I Rpt I h936 LIS Verification 67 7320 Open 11/25/2004 PB 1, 4 RUNS, 2ND67- i 3076, 3RD 3076-4145, i I 4TH 4145-6488 I ED D Lis ,..12937 Gamma Ray 67 8826 1/27/2005 GRlEWR4/ABIIROP/PWD, I PB2 I I LIS Verification 67 GR/EWR4/ABI/ROP/PWD, I I Rpt ~2937 8826 1/27/2005 ] PB2 I .. , ] ] ED D ...1'2938 Gamma Ray 67 9425 1/27/2005 GR/EWR4/ABI/PWD/ROP I Rpt I I ED .,....-12938 LIS Verification 67 9425 1/27/2005 GRlEWR4/ABIIPWD/ROP i I D Tap V12959 Gamma Ray 67 9911 Open 1/27/2005 GRlEWR4/ABIIROP/PWDI I A2959 MWD I I Rpt LIS Verification 67 9911 Open 1/27/2005 GRlEWR4/ABIIROP/PWDI I I MWD I I ED C Lis ví3525 I nd uction/Resistivity 112 9967 Open 2/22/2006 ROP DGR EWR plus I . I i Graphics 1 PB 1 ROP I I I I DGR EWR 112-7376 plus I I Graphics 1 PB 2 ROP DGR I I EWR 112 -8882 plus Graphics 1 PB 3 ROP DGR I I EWR 112-9482 plus \ L Graphics J Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Permit to Drill 2041900 MD 9967 TVD 4006 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Analysis Received? ~ Comments: DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Well Name/No. MILNE PT UNIT SB H-16 Operator BP EXPLORATION (ALASKA) INC Completion Date 11/1/2004 Completion Status 1-01L Current Status 1-01L Daily History Received? ~ Q)/N Formation Tops com;';.n~ RoVlewe~ -,;., ~~ ~ ~~ ....... API No. 50-029-23227-00-00 UIC N ---,--_._---,- "~~-~~--_.- ~ ~ N\v ;.~~ Date: . . . . WELL LOG TRANSMITTAL c9D+- ¡q D To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 Febmary 16, 2006 {~5 RE: MWD Fonnation Evaluation Logs MPH-16 + PBl + PB2 + PB3, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, SpenyDrilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPH-16 + PBI + PE2 + PB3: LAS Data & Digital Log Images: 50-029-23227-00, 70, 71, 72 1 CD Rom ~fì '519 ø rOltJ dotf- (70 . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 24, 2004 RE: MWD Formation Evaluation Logs MPH-16 PB1, AK-MW-3330703 1 LIS formatted Disc with verification listing. API#: 50-029-23227-70 ~\'J- ~7~ PLEASE ACKNOWLEDGE RECEIPf BY SIGNING A COPY OF THE TRANSMI'ITAL LETTER TO TIlE ATTENTION OF: Sperry -Sun 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 99649-6612 Date: . at} <!-/9 0 . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 24, 2004 RE: MWD Formation Evaluation Logs MPH-16 PB3, AK-MW-3330703 1 LIS formatted Disc with verification listing. API#: 50-029-23227-72 *\},~)~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITI'AL LEITER TO THE ATTENTION OF: Sperry-Sun 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 99649-6612 ])ate:~ Sign . . . dot/-r90 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 24, 2004 RE: MWD Formation Evaluation Logs MPH-16, AK-MW-3330703 1 LIS formatted Disc with verification listing. API#: 50-029-23227-00 11 I ~ q Ç9 !)LEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun 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 99649-6612 Date:# \~~-c:K l '~Q -G" ") \C\S-\~D ~d-\S) J04-\~'O . . MPH-15i ~ Mile Area of Review (11/09/2005): Five wells penetrate the Schrader Bluff OAlOB sands within a 1/4-mile of the MPH-15 OAlOB injection intervals, and based upon this review, it is our conclusion that the off-set wells have sufficient mechanical integrity to be within the proposed injection patter of this well. Included in this AOR is the following listed data: I. Cementing Data - No unusual issues were note in the well to well review of the associated cement jobs. II. Injector Well Data - Both injection wells within this AOR have bond logs indicating good mechanical isolation capabilities. III. MPH-15 Injector Planning Data - TIFF files detailing the planned injector objectives. A diagram showing the locations of these wellbores is included in this packet. The following table(s) provides information on the production/injection casing cement jobs and FIT's (if available) for each proximate well. C t" D emen mg ata: Csg Shoe Well Type Size Depth Cement FIT (TVDss) (lb/gal EMW) MPI-02 injector 7" 4213 391 sxs Class "G" - MPI-03 producer 7" 4192 307 sxs Class "G" - MPI-05 injector 768 sxs Permafrost "E", 314 sxs Trinity - 5-1/2" 4338 Lite-Water, 250 sxs Permafrost "E" MPI-15* producer 7" 3975 84 sxs Class "E", 189 sxs Class "G" 11.8 MPH-16* producer 7-5/8" 3993 598 sxs Class "G" 12.5 -.... Vf>~ *have laterals through OA and DB sands; cased with 4.5" slotted liners ... STATE OF ALASKA ALASKA. AND GAS CONSERVATION coessl..·.·etV E·..··· D REPORT OF SUNDRY WELL OPERAT . . !1fiQ"¡;;; MA 11 't.\) J 1. Operations Performed: A\alka Oii & o Abandon a Repair Well o Plug Perforations o Stimulate An.~r o Alter Casing a Pull Tubing o Perforate New Pool o Waiver o Time Extension o Change Approved Program o Operation Shutdown o Perforate o Re-Enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. a Development o Exploratory 204-190-00 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23227-00-00 7. KB Elevation (ft): KBE = 70.25' 9. Well Name and Number: MPH-16 8. Property Designation: 10. Field I Pool(s): ADL 025906 Milne Point Unit I Schrader Bluff 11. Present well condition summary Total depth: measured 9967 feet true vertical 4006 feet Plugs (measured) N/A Effective depth: measured 9967 feet Junk (measured) N/A true vertical 4006 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 4147' 10-3/4" 4182' 3139' 5210 2480 Intermediate Production 6484' 7-5/8" 6516' 4063' 6890 4790 Liner 3658' 4-1/2" 6309' - 9967' 4006' 8430 7500 Perforation Depth MD (ft): Slotted 6524' - 9922' Perforation Depth TVD (ft): Slotted 4064' - 4009' 2-7/8", 6.5# L-80 5920' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Ft î 4 Z005 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: a Daily Report of Well Operations o Exploratory a Development o Service a Well Schematic Diagram 16. Well Status after proposed work: a Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing IS true and correct to the best or my Knowledge. I Sundry Number or NIA if C.O. Exempt: Contact Walter Quay, 564-4178 Printed Name Sandra Stewman Title Technical Assistant S~,v~ 0 'i'\-y ~ Phone ç(pL( - q 1- C) 0 Prepared By Name/Number: - Date O"~ - 10 Ú ') Sondra Stewman, 564-4750 Form 10-404ffevised 04/2004 /.'\ l Submit Ori inat Onl RIGI~J¡~L 9 y ~ 2-9/16" - 5M FMC Wellhead: 11" x 7-1/16" S.C Gen SA, w 2-7/8" FMC Tb .,3" LH Acme on top and 2-7/8" EU 8rd on bottom. 2.5" CIW BPV Profile 20' x 34" insulated, 215 lIft A-53 D:I[] 103/4" 45.5 ppf L-80 BTRC (Drift ID = 9.794, cap. = .0961 bpI) 10 3/4" HOWCO Float Shoe 14182' I 75/8" 29.7 ppf. L-80, 8TRC-mod casing (Drift ID = 6.750", cap = 0.0459 bpf) 2-7/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf) KOP @ 500' +60 degree from 2850' Max hole angle = 69 degree @ 5722' Window in 7 5/8" Casing @ 6182' - 6194' Well Angle @ window = 76° Baker Hook Wall Hanger inside 7-518" Window 16.70· Baker Hook Wall Hanger outside 7-518" Window 6.15· Baker Tie Back Sleeve 6309' Baker ZXP Liner Top Packer 6320' Baker 7-5/8" x 5" HMC Liner Hanger 6326' Baker 190-47 Seal Bore Extension 6334' 7-5/8" Weatherford Float Collar 6431' 7-5/8" Weatherford Float Shoe 6515' DATE 10/31/04 02115/05 REV. BY Lee Hulme Lee Hulme COMMENTS Drilled and completed by Doyon 14 Replace ESP Nabors 4ES MPH-16 OA Lateral Ori9. KB elev. = 70.50' (Doyon 14) ori.-LDS. elev.= 30.03' (Doyon 14) Cameo 2-7/8" x1" KBMM Gas lift mandrel 139' Cameo 2-7/8" x1" KBMM Gas lift mandrel 2104' Centrilift Heat Trace 3465' Cameo 2-7/8" x1" KBMM Gas lift mandrel 5684' HES XN-Nipple (2.205" id) 5836' Phoenix MS-1 Pressure Head 5859' ESP Pump, 122 Sl9, GC2200 GPMTAR 1:1 I 5860' 5881' I 5886' I Gas Separator Model - GRSFTXAR H6 Tandem Seal Section, Model - GSB3 DB UTIL TAB HSN PFSAlPSA Motor. 152 KMH 2325 volt I 40 amp 5900' I Phoenix MS-1 w/6 fin Centralizer 5913' I Phoenix Sensor Depth = 3933' TVD ~\o\-\eÀ (tQ\<1i -8'ìlul') i(~:P133' -<1 l{~) 89 jts. - 41/2" 12.6# L-80, IBT Slotted Liner (62&4' 8779') & (8945' 9859') 6 1/8" Hole td @ 9915' HES 4112""V" Float Shoe 9905' 6 1/8" Hole td @ 9931' HES 41/2""YO Float Shoe 9967' 87 its. - 41/2", 12.6# L-80, IBT 08 Lower Lateral Slotted Liner (6524' - 8839') & (9173' - 9922') .MJ.LliE PO[t.lT UN II. WI;LL--MEt1-16 API NO: 50-029-23227-00-öro API NO' 50-029-23227-"Oå-<¿;)'Ù BP EXPLORATION (AK) PJSM. Scope down & lower derrick. Rig down rig components. Wait on trucks. Replace main winch on rig floor. PJSM. Move rig from MP 1-19 pad to MP H-16. PJSM. Rig up on MP H-16. Raise & scope up derrick. Rig accepted @ 16:00 hrs, 02/13/2005. PJSM. Take on heated seawater. Rig up hardlìne to tiger tank. Install secondary valve on I/A. PJSM. Pull BPV, OA = 150 psi, TBG=450 psi Pressure test lines. Bleed Gas off fA and tubing. Circulate 35 bbls down tubing. Bullhead 75 bbls down tubing. Circulate 400 bbls down tubing up lA, clean returns. Shut-down and monitor 30 min, both tbg and IA on vac Install TWC, Bullhead 10 bbls down IA at 4 bpm and 80 psi. PJSM. Begin to nipple down tree, found 100 psi on IA. Bleed to tank. All Gas. Continue to bleed to tank and monitor. All gas. Will bleed of to o psi, builds up 50 psi in 30 minutes. Rig up E trunk and drain hoses. Rig up lubricator and pull TWC. 60 psi on tubing. Rig up tree and to circ Circulate 100 bbls at 5 bpm. Hit fluid level in tubing at -28 bbls. Returns mostly gas and crude. After shutting down tubing on vac and IA had 30 psi. IA bleeding down slowly giving up gas, oil and seawater. IA did bleed to 0 psi after 10 mintutes. Circulating seawater at 5 bpm, thick crude returns. Out of fluid. Wait on 125 degree seawater. PJSM. Pump (10) bbls down tubing @ 5 bpm, no indication of returns, not even air. Bullhead 200 bbls down I/A @ 5 1/2 bpm, 150 psi. Monitor well. Tubing & IIA on vacuum. Set two way check valve. PJSM. N/D tree. PJSM. NIU adapter flange & BOPE. Install secondary annulus valve. PJSM. Conduct full BOPE test, 350 low pressure, 3500 psi high pressure,S minutes charted on each test. Witnessing of test waived by AOGCC rep John Crisp. Testing of BOP components witnessed by Company Man. No failures. PJSM. Pick up lubricator, pull two way check, lay down lubricator. PJSM. MU landing joint, back out LDS, and pull hanger to floor. Up wt = 42K. Pull tubing and ESP cable,double displacing every 5 stands. Continue to pull tubing, ESP cable and ESP out of hole. Lay down pump. Rig down sheave, rig up double sheave, change out ESP reel in spooler, ready new pump. Shoot fluid level at 650'. Found twisted off shaft in old ESP and shaft frozen inside gas separator. RUNCMP MU flat guards. RUNCMP MU and service pump assembly with Phoenix sensor. RUNCMP Test MLE. Clear and clean rig floor. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-16 MPH-16 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From-To Code NPT 2/13/2005 00:00 - 03:00 3.00 RIGD P PRE 03:00 - 09:00 6.00 RIGD P PRE 09:00 - 13:30 4.50 MOB P PRE 13:30 - 16:00 2.50 RIGU P PRE 16:00 - 18:30 2.50 KILL P DECOMP 18:30 - 23:00 4.50 KILL P DECOMP 23:00 - 23:30 0.50 WHSUR P DECOMP 23:30 - 00:00 0.50 WHSUR P DECOMP 2/14/2005 00:00 - 02:30 2.50 KILL P DECOMP 02:30 - 03:00 0.50 WHSUR P DECOMP 03:00 - 04:00 1.00 KILL P DECOMP 04:00 - 04:45 0.75 KILL P DECOMP 04:45 - 05:30 0.75 KILL P DECOMP 05:30 - 07:30 2.00 KILL P DECOMP 07:30 - 08:30 1.00 KILL P DECOMP 08:30 - 09:30 1.00 WHSUR P DECOMP 09:30 - 11:00 1.50 WHSUR P DECOMP 11:00 -14:00 3.00 BOPSU P DECOMP 14:00 - 17:00 3.00 BOPSU P DECOMP 17:00 - 18:30 1.50 BOPSU P DECOMP 18:30 - 19:00 0.50 PULL P DECOMP 19:00 - 00:00 5.00 PULL P DECOMP 2/15/2005 00:00 - 02:00 2.00 PULL P DECOMP 02:00 - 04:30 2.50 RUNCO RUNCMP 04:30 - 06:30 06:30 - 09:00 09:00 - 10:00 2.00 RUNCO 2.50 RUNCO 1.00 RUNCO Page 1 of 2 Start: 2/13/2005 Rig Release: 2/16/2005 Rig Number: Spud Date: 10/14/2004 End: Description of Operations Printed: 2/2312005 11 :55:44 AM .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-16 MPH-16 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/13/2005 Rig Release: 2/16/2005 Rig Number: Spud Date: 10/14/2004 End: 2/15/2005 Date From - To Hours Task Code NPT Phase 10:00 - 11:30 11:30 - 12:30 12:30 - 18:00 18:00 - 19:00 19:00 - 00:00 2/16/2005 00:00 - 01 :30 01 :30 - 02:00 02:00 - 07:30 07:30 - 08:30 08:30 - 10:00 10:00 - 11 :30 11:30 - 12:00 5.50 RUNCMP RIH from derrick with 2.875" EUE to 2,627'. RUNCMP RU to run heat trace. Pull cable through sheave, attach to tubing and test. RUNCMP Continue to RIH 2.875' EUE from derrick with EST and heat trace. RUNCMP PJSM with WSL's. Check cables and flush pump. Make up additional flat guards. RUNCMP Continue to RIH 2.875' EUE from derrick with ESP and heat trace. RUNCMP Continue to RIH 2.875" EUE from derrick with ESP and heat trace. RUNCMP PU and MU tubing hanger. RUNCMP Install penetrators and make uplsplice ESP and heat trace connectors. RUNCMP Land hanger. RILDS. Set TWC and test same. Drain and blow down lines. WHDTRE ND BOPE. Test spool and DSA. WHDTRE Nipple up adapter flange and tree. Test both to 5,000 psi. Good test. WHDTRE Pull TWC. Set BPV. Secure tree and cellar. 1.50. BOPSU P 1.50 I WHSUR P 0.50 WHSUR P Rig Released from well work at 12:00 hours. Printed: 2/2312005 11 :55:44 AM A STATE OF ALASKA a ALAS~IL AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska nil R'(~ rn. r .. Revision· '21f6Jt)4'Ma'ffV4b~B~~SIOIì RECEIVED DEC 2 1 2004 -R- . ¡" 1a. Well Status: 181 Oil DGas D Plugged D Abandoned o Suspended DWAG 1 b. Well Class: 20AAC 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 Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 11/1/2004 204-190 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 10/14/2004 50- 029-23227-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 10/25/2004 MPH-16 2969' NSL, 4003' WEL, SEC. 34, T13N, R10E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 3555' NSL, 2148' WEL, SEC. 33, T13N, R10E, UM (OB) KBE = 70.25' Milne Point Unit I Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 671' NSL, 3956' WEL, SEC. 33, T13N, R10E, UM (OB) 9967 + 4006 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 556641 y- 6010120 Zone- ASP4 9967 + 4006 Ft ADL 025906 TPI: x- 553211 y- 6010681 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: .. N/A MD Total Depth: x- 551431 y- 6007785 Zone- ASP4 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DYes 181 No NI A MSL 1800' (Approx.) 21. Logs Run: MWD , GR , RES, Photo GYRO, GYRO, ABI , IFR / CASANDRA 22. CASING, LINER AND CEMENTING RECORD CASING SETTING EPTH r..-1D SETTING DEPTHT\lD HOLE ~u~~:ci SIZE WT. ·PER FT. GRADE BOTTOM I BOTTOM SIZE ,.. rop lOP 20" 92# H-40 Surface 112' Surface 112' 42" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# L-80 35' 4182' 35' 3139' 13-1/2" 560 sx PF 'L', 475 sx Class 'G' 7-5/8" 29.7# L-80 32' 6516' 32' 4063' 9-7/8" 598 sx Class 'G' 4-1/2" 12.6# L-80 6309' 9967' 4034' 4006' 6-314" Uncemented Slotted Liner 23. Perforations op'en to Production (MD + TVD of Top and 24. ..,. ,,... ...... Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 2-7/8", 6.5# x 12.6#, L-80 5922' N/A MD TVD MD TVD 25. " ..... .CEMENTS::hlll:I':""¡:ETÇ. 6524' - 8839' 4064' - 3983' ..~.~, 9173' - 9922' 3993' - 4009' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 87 Bbls of Diesel. 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): November 24, 2004 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF W A TER-BBL CHOKE SIZE I GAS-OIL RATIO 11/29/2004 12 TEST PERIOD .. 597 312 48 522 Flow Tubing Casing Pressure CALCULATED .. OIL-BBL GAs-McF W A TER-BBL OIL GRAVITy-API (CORR) Press. 24-HoUR RATE 1195 624 97 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 RBDMS BFL JAN 0 'ì 2005 Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TUZC MA MB1 MB2 MC NA NB NC NE NF OA TSBC 08 OB(2) SBA5 4774' 5195' 5213' 5334' 5637' 5724' 5790' 5880' 5935' 6064' 6183' 6293' 6480' 9186' 9341' 3468' 3644' 3653' 3708' 3834' 3866' 3889' 3921' 3941' 3980' 4009' 4031' 4059' 3995' 4012' None 30. List of Attachments: ing is true and correct to the best of my knowledge. I Signed Son Title Technical Assistant Date / 2 ~ I fp-GY1 MPH-16 Well Number Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 Walter Quay, 564-4178 204-190 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. 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 __A STATE OF ALASKA . ALAS~ AND GAS CONSERVATION COM - ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ./; n II¡ 1a. Well Status: a Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 a Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 11/1/2004 , 204-190 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 10/14/2004 ' 50- 029-23227-00-00 4a. Location of Well (Governmental Section): 7. Date T.o. Reached 14. Well Name and Number: Surface: 10/25/2004 MPH-16 2969' NSL, 4003' WEL, SEC. 34, T13N, R10E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 3555' NSL, 2148' WEL, SEC. 33, T13N, R10E, UM (OB) KBE = 70.25' Milne Point Unit 1 Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 671' NSL, 3956' WEL, SEC. 33, T13N, R10E, UM (OB) 9967 + 4006 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 556641 ' y- 6010120· Zone- ASP4 ' 9967 + 4006 ' Ft ADL 025906 ---.- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 553211 y- 6010681 Zone- ASP4 Total Depth: x- ---- N/A MD 551431 y- 6007785 - Zone- ASP4 1B. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost aYes DNa N/A MSL 1800' (Approx.) 21. Logs Run: MWD , GR , RES, Photo GYRO, GYRO, ABI , IFR 1 CASANDRA 22. CASING, liNER AND CEMENTING RECORD CASING SETTING EPTH MD SETTING JEPTH TVD HOLE ,l),MO\JNr SIZE WT. PER FT. GRADE lOP . BOTTOM TOÞ IBOTTOM SIZE ,i PULLED 20" 92# H-40 Surface 112' Surface 112' 42" 260 sx Arctic Set (Aoorox.) 10-3/4" 45.5# L-BO 35' 4182' 35' 3139' 13-1/2" 560 sx PF 'L', 475 sx Class 'G' 7-5/8" 29.7# L-BO 32' 6516' 32' 4063' 9-7/8" 598 sx Class 'G' 4-1/2" 12.6# L-80 6309' 9967' 4034' 4006' 6-314" Uncemented Slotted Liner 23. Perforations op'en 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) 4-1/2" Slotted Liner 2-7/8",6.5# x 12.6#, L-80 5922' N/A MD TVD MD TVD 6524' - 8839' 4064' - 3983' 25. ACID, FRACTURE, CEMENTSQUE.EZE,eTc. 9173' - 9922' 3993' - 4009' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 87 Bbls of Diesel. 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF WATER-BSl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD .... Flow Tubing Casing Pressure CALCULATED .... OIL-Bsl GAs-McF W A TER-BSl OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 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". --".-~~~..".~\ RBDMS BFl DEC 0 6 2004 I CQMt'Lc ¡ iON _ I --r. I None . .~ (;p\Í/; t/', \ LU:2~-\ ORt('i\\1 ^ L ..~', .- -J!¡\"/~\ ~--, Grt- Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS 29. RMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TUZC MA MB1 MB2 MC NA NB NC NE NF OA TSBC 08 OB(2) SBA5 4774' 5195' 5213' 5334' 5637' 5724' 5790' 5880' 5935' 6064' 6183' 6293' 6480' 9186' 9341' 3468' 3644' 3653' 3708' 3834' 3866' 3889' 3921' 3941' 3980' 4009' 4031' 4059' 3995' 4012' None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Leak-Off Test Summary and a Well Service Report. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,,--~-'~-"'" Sond~tewman MPH-16 Well Number Title Technical Assistant Date l L- 01 ~Ol( 204-190 Permit No. / 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: Sandra Sfewman, 564-4750 Wa/ferQuay, 564-4178 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 ~ 2-9/16" - SM FMC Wellhead: 11" x 7-1/16" S.C Gen SA, w 2-7/8" FMC Tb .,3" LH Acme on top and 2-7/8" EU 8rd on bottom, 2.5" CIW BPV Profile 20" x 34" insulated, 215 !tift A-53 r=J:ili 103/4" 45.5 ppf l-80 BTRC (Drift 10 = 9.794, cap. = .0961 bpf) 103/4" HOWCO Float Shoe I 4182' I 75/8" 29.7 ppf, l-80. BTRC-mod casing (Drift ID ,,6.750", cap" 0.0459 bpf) 2-7/8" 6.5 ppf, l-80 Brd eue tbg. (drift id "2.347"' cap = .00592 bpf) KOP @ 500' +60 degree from 2850· Max hole angle = 69 degree @ 5722' Window in 75/B" Casing @ 6182' - 6194' Well Angle @ window = 76· Baker Hook Wall Hanger inside 7-5/8" Window 16.70' Baker Hook Wall Hanger outside 7-5/8" Window 6.15' Baker Tie Back Sleeve 6309' Baker ZXP Liner Top Packer 6320' Baker 7-5/8" x 5" HMC Liner Hanger 6326' Baker 190-47 Seal Bore Extension 6334' 7·5/8" Weatherford Float Collar 6431' 7-5/8" Weatherford Float Shoe 6515' DATE 10/31/04 REV. BY Lee Hulme MPH-16 OA lateral Orig. KB elev. = 70.50' (Doyon 14) orie-lDS. elev.= 30.03' (Doyon 14) Cameo 2-7/8·' xi"· K8MM Gas lift mandrel 149' Camco 2-7/8" x1" KBMM Gas lift mandrel 2114' Camco 2-7/8'· x1·· KBMM Gas lift mandrel 5694' HES XN-Nipple (2.205'· id) 5846' ESP Pump. 159 stg. GC1150 GPMTAR 1:1 5867' Tandem Intake - Gas Separator Model - GRSFTXAR H6 Tandem Seal Section. I Model - GSB3 D8 UT/L T IL H6 PFS AFLAS / HSN Motor, 133 KMH 2205 volt I 37 amp 5885' 5890' I 5904· PumpMate w/6 fin centralizer 5916· 89 jts. - 41/2" 12.6# L-80, IBT Slotted liner (6204'-8779') & (8945'-9859') 61/8" Hole td @ 9915' HES 41/2" "V·' Float Shoe 9905' 6 1/8" Hole td @ 9931' HES 4 1/2" 'YO Float Shoe 9967 ' 87 jts. - 41/2", 12.6# l-80. IBT OB lower Lateral Slotted Liner (6524' _ 8839') & (9173' - 9922') COMMENTS MILNE POINT UNIT WELL MPH·16 API NO: 50-029-23227-00 API NO: 50-029-23227-01 ap EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/13/2004 10/14/2004 10/15/2004 10/16/2004 10/17/2004 Page 1 of 7 BP Operations Summary Report MPH-16 MPH-16 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 From-To Hours Task 20:00 - 21 :00 21 :00 - 22:30 22:30 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 08:00 08:00 - 10:30 10:30 - 11 :00 11 :00 - 11 :30 11 :30 - 12:00 12:00 - 12:30 12:30 - 13:30 13:30 - 21:00 21 :00 - 22:30 22:30 - 00:00 00:00 . 00:00 00:00 . 04:00 04:00 . 05:00 05:00 - 07:00 07:00 - 08:00 08:00 - 10:00 10:00 - 12:00 12:00 - 14:30 14:30 - 16:30 16:30 - 17:30 17:30 . 00:00 00:00 - 03:00 03:00 - 04:30 04:30 - 05:30 05:30 - 06;00 06:00 - 08:00 08:00 - 09:00 09:00 - 10:00 10:00 - 12:00 12:00-14:30 14:30 - 16:00 16:00 -17:00 17:00 - 23:00 23:00 - 23:30 1.00 MOB 1.50 MOB 0.50 MOB 0.50 MOB 0.50 MOB 1.50 RIGU 6.50 RIGU 2.50 RIGU 0.50 DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL 1.00 DRILL 7.50 DRILL 1.50 DRILL 1.50 DRILL 24.00 DRILL 4.00 DRILL 1.00 DRILL 2.00 DRILL 1.00 DRILL 2.00 DRILL 2.00 DRILL 2.50 DRILL 2.00 DRILL 1.00 DRILL 6.50 DRILL 3.00 DRILL 1.50 CASE 1.00 CASE 0.50 CASE 2.00 CASE 1.00 CASE 1.00 CASE 2.00 CASE 2.50 CASE 1.50 CASE 1.00 CASE 6.00 CASE 0.50 CASE cOdelNPT P i P i P I P ! P ¡ P ! I I ¡ I I P P P P P P P P N P P P P P P P Start: Rig Release: Rig Number: Phase PRE PRE PRE PRE PRE PRE PRE PRE SURF I IDFAL I I SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF N DFAL SURF N DFAL SURF N DFAl SURF N DFAl SURF P SURF P SURF P SURF P SURF P SURF P SURF P SURF P SURF P SURF P SURF P SURF P SURF P SURF P SURF 10/8/2004 11/1/2004 Spud Date: 10/14/2004 End: 11/1/2004 .. Descriptiòn of Operations Skid rig floor to moving position Move off MPH-18, move to MPH-16 Herculite rockwasher position Skid rig floor to Drilling position Rigging up floor and spot rockwasher Nipple up Diverter and Diverter lines, Rig accept @ 00:01 10/14/2004 load pipe shed, Picking up 4" drill pipe and standing in derrick Picking up BHA #1 Diverter test, the right to witness test was wavier by John Crisp AOOGC Pre spud meeeting Fill stack and check for leaks Drill, 112' to 166' Stand back 5 hoop, make up 8" flex collars Drill 166' to 611' with 70 rpms, 420 gpm, 1200 psi, run gyros every 100ft. last gyro to be run 700 ft. Four missed runs with gyro surveys. Drill from 611' to 757' with 70 RPMs, 420 gpm, 1200 psi. last survey run at 700'. AST 2.47 ART 3.57 Drill 757' to 2624' with 80 rpms, 500 gpm, 2250 psi, AST 14.61, ART 2.34 Hydrates encountered @ 1875 to 2100', mud cut from 9.6 to 7.9 Drill 2624' to 2912' with 80 rpms, 500 gpm, 2500 psi Circ two bottoms up with 500 gpm, 2500 psi, 80 rpms Pumping out to HWDP with full drilling rate RIH to bottom, wash last stand to bottom Drill 2912' to 3121' with 80 rpms,500 gpm, 2500 psi, 1000 psi increase in pump pressure oft bottom, possible mech. failure, pump pressure 3780 psi with 440 gpm Pumping out to BHA Stand back BHA, found two alien head screws in jets. from mud motor, lay down MWD and mud motor PIU new mud motor, MWD, RIH with BHA, surface test MWD Trip to bottom, washed last stand to bottom Drilling 3121' to 3769' with 80 rpms, 525 gpm, 2700 psi, AST 3.61, ART 3.96 Drill 3769' to 4190' TD, with 80 rpms, 550 gpms, 3100 psi Circ, Two bottoms up with 80 rpms, 550 gpm 3100 psi Pump out to 3,000' with full drtlling rate Rih, wash last stand to bottom Circ. Three bottoms up with 80 rpms, 550 gpm, 3100 psi Pump out to 2800' with full drilling rate Change out saver sub on top drive Pump out to HWDP with full drilling rate Stand back HWDP and lay down flex dc and MWD and motor Clear rig floor Rig up to run 103/4 csg, PJSM Picking up 103/445# L-80 btc csg, total of 100 jts , P/U 250K, Slo 130K, shoe 4182, float 4095, (had trouble getting thru base of permafrost) Lay down franks tool and rig up cement head Printed: 111812004 8:35:04 AM BP Operations Summary Report Page 2 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-16 MPH-16 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 10/8/2004 11/1/2004 Spud Date: 10/14/2004 End: 11/1/2004 Date Frorn ~To Gode NPT Phase DescriptiÓI1...of()perations 10/17/2004 23:30 - 00:00 0.50 CASE P SURF ! Circ and thin mud for cement job. 10/18/2004 00:00 - 01 :30 1.50 CASE P SURF I Circ and thin mud for cement job, 378 gpm, 300 psi, PJSM on I cementing 01 :30 - 04:30 3.00 CEMT P SURF I Cement with Schlumberger with 5 bbls water, test lines 3500 ¡PSi, 10 bbls water, 15 bbls CW100, 75 bbls 10.6 Mud push, ) drop bottom plug, 560 sxs ASL 438 bbls Yield 4.44 mixed at i 10.7, tail with 475 sxs. Class G, 99 bbls pumped 8 bbls min. I yield 1.17 mixed at 15.8, drop top plug, kicked out with 30 bbls ,water, displace with rig pump 7 bbls min. 394 bbls, full retums I thru out job, bump plug with 1750 psi, float held, 275 bbls good cement to surface 04:30 - 06:00 1.50 CASE P SURF Flush stack, laying down cement head, landing jt. 06:00 - 07:00 1.00 CASE P SURF ! Nipple down Diverter 07:00 - 08:00 1.00 CASE P SURF I Nipple up starting head, test seal to 1000 psi for 10 min. 08:00 - 10:00 2.00 CASE P SURF . Nipple up BOPS 10:00 - 15:00 5.00 CASE P SURF ¡Test BOPS and Manifold to 250- 3500 psi 5 min. per test, i Hydrill 250-2500 psi 5 min. per test, witness by Jeff Jones I AOOGC, install wear ring 15:00 - 18:00 3.00 CASE P SURF I Picking up BHA # 3, suface test MWD 18:00 - 19:30 1.50 CASE P SURF ,Trip in to 4060' 19:30 - 21 :00 1.50 CASE P SURF I Circ, one drill pipe vol., Test csg to 2000 psi for 30 min. 21:00 - 22:00 1.00 CEMT P SURF Drill cement and shoe track, drill new hole to 4210' with 60 I rpms, 424 gpm, 1850 psi 22:00 - 22:30 0.50 CASE P SURF Circ, bottoms up 22:30 - 23:30 1.00 CASE P SURF I Pump hi vis sweep, displace well with new 10.5 LSND mud 23:30 - 00:00 0.50 DRILL P INTi Fit test with 10.5 mud wt. 325 psi, = 12.5 EMW, holding pressure bleed to 180 psi in 10 min. 10/19/2004 00:00 - 00:30 0.50 DRILL P INT1 Finish Fit test with 10.5 mud wt. 325 psi, = 12.5 EMW, holding pressure bleed to 180 psi in 10 min., blow down choke lines 00:30 - 00:00 23.50 DRILL P INTi Drill 4210' to 6310' with 80 rpms, 500 gpms, 3500 psi, AST 8.13, ART 7.01 10/20/2004 00:00 - 02:00 2.00 DRILL P INT1 Drill 6310' to 6525' TD with 80 rpms, 500 gpms, 3600 psi 02:00 - 04:00 2.00 DRILL P INT1 Circ, Three bottoms up with 100 rpms. 500 gpm, 3600 psi 04:00 - 06:00 2.00 CASE P INTi Pumping out to csg shoe @ 4182, with full drilling rate 06:00 - 07:00 1.00 CASE P INT1 Circ, one bottoms up, with 500 gals min., 2600 psi 07:00 - 08:30 1.50 CASE P INT1 Cut and slip drilling line, service top drive 08:30 - 09:00 0.50 CASE P INT1 RIH to 6525', wash last stand to bottom 09:00 - 11 :30 2.50 CASE P INT1 Circ Three bottoms up with 500 gpm, 3600psi, 100 rpms 11 :30 - 13:30 2.00 CASE P INTi Pumping out to csg shoe @ 4182, with full drilling rate 13:30 - 14:30 1.00 CASE P INT1 Circ one bottoms up with 500 gpms, 40 rpms 2900 psi 14:30 - 15:30 1.00 CASE P INTi Poh to HWDP 15:30 - 18:00 2.50 CASE P INTi Lay down BHA 18:00 . 18:30 0.50 CASE P INT1 Clear rig floor 18:30 - 20:00 1.50 CASE P INT1 PJSM, Pull wear ring, install test plug, install 7 5/8 rams, test door seals to 1500 psi 20:00 - 21:00 1.00 CASE P INT1 PJSM, Rig up to run casing 21 :00 - 00:00 3.00 CASE P INT1 Picking up 7 5/8 29# L-80 Btc csg, change out tongs, to 2200' 10/21/2004 00:00 - 02:00 2.00 CASE P INT1 Picking up 7 5/8 29# L-80 Btc csg, to 4150' 02:00 - 02:30 0.50 CASE P INTi Circ, casing volume of 191 bbls 02:30 - 04:30 2.00 CASE P INTi Picking up 7 5/8 29# L-80 Btc csg, to 6515' land csg. with shoe @ 6515 float 6431' total of 158 jts run, P/U wt 225k, 5/0 wt 115K, Circ wts P/U 200K, Slo 100 04:30 - 05:00 0.50 CASE P INn Rig down Franks tool and rig up cement head Printed: 111812004 8:35:04 AM BP Operations Summary Report Page 3 of 7 Legal Well Name: MPH-16 Common Well Name: MPH-16 Spud Date: 10/14/2004 Event Name: DRILL+COMPLETE Start: 1 0/8/2004 End: 11/1/2004 Contractor Name: DOYON DRILLING INC. Rig Release: 11/1/2004 Rig Name: DOYON 14 Rig Number: Date From -To Code NPT Phase t-- DescriptiÖriç>fþþerations 10/21/2004 05:00 - 07:00 2.00 CASE P INT1 I Circ and reciprocate csg for two csg volumes 598 bbls., 6 bbls min. 600 psi 07:00 - 08:30 1.50 CEMT P INT1 I Cement with Schlumberger 5 bbls water, test lines to 3000 I psi,25 bbls CW-100, 30 bbls mud push Mixed @ 11.5, drop i bottom plug, 123 bbls 598 sxs. class G yield 1.16 mixed @ : 15.8, drop top plug, displace with 295 bbls oil mud 10.5, pump ! plug with 1800 psi, Reciprocate csg thru out job, displace 6 bbls min 800 psi, float held 08:30 - 09:30 1.00 CEMT P INT1 Blow down Schlumberger, close hydrill inject 34 bbls water down 10 3/4 X 7 5/8 annulus 09:30 - 10:30 1.00 CASE P INT1 Void 7 5/8 landing it., flush stack, install pack off and test same to 5000 psi for 10 min. 10:30 - 11 :30 1.00 CASE P INT1 I Change out top rams to 2 7/8 X 5' 11 :30 - 12:00 0.50 CASE P INT1 ! Change out Bails and lay down Csg equipment 12:00 - 13:30 1.50 CASE P INT1 ¡ Test top rams 250-3500 psi 5 min. per test, rig down test ¡equipment. 13:30 - 16:00 2.50 CASE P INT1 i Picking up BHA # 4, surface test MWD 16:00 - 19:00 3.00 CASE P INT1 I IRIH to 6315' 19:00 - 20:30 1.50 CASE P INT1 I Circ one drill pipe volume, Test Csg to 2500 psi for 30 min. 20:30 - 21 :30 1.00 CEMT P INT1 I Drill Cement and shoe track and new hole to 6545' with 70 I rpms, 272 gpm, 2900 psi 21 :30 - 22:30 1.00 CEMT P INT1 ICirc bottoms up for FIT, 272 gpm,2900 psi, 70 rpms 22:30 - 23:00 0.50 CEMT P INn I Fit test with 10.5 Mud WI. 420 psi, 4063 TVD= 12.5 EMW 23:00 - 00:00 1.00 DRILL P PROD1 ID"UOg 6545' to 6600' w;th 70 opms, 275 gpm, 3100 "", ECD 11.5, AST .35, ART .03 10/22/2004 00:00 - 08:30 8.50 DRILL P PROD1 Drilling 6600' to 7376' with 70 rpms, 275 gpm, 3100 psi, ECD 11.6 08:30 - 09:30 1.00 STKOH P PROD1 Pumped out to 6937' , cut trench 6937 to 6947', side track well @6947' 09:30 - 00:00 14.50 DRilL P PROD1 Drilling 6947' to 8,231 with 70 rpms, 275 gpms, 3200 psi, ECD 11.9, AST 5.4, ART 8.27 10/23/2004 00:00 - 04:00 4.00 DRILL P PROD1 Drilling 8,231 to 8662' with 80 rpms, 275 gpms, 3200 psi, ECD up to 12.6 04:00 - 06:00 2.00 DRILL P PROD1 Circ. to lower ECD and make mad pass ECD 12.5 drop to 12.0 06:00 - 07:00 1.00 DRILL P PROD1 Poh to 8390', Mad pass 8388' to 8348', RIH 8662' 07:00 - 09:00 2.00 DRILL P PROD1 Drilling 8662' to 8882' with 80 rpms, 275 gpms, 3200 psi 09:00 - 10:00 1.00 STCTPL P PROD1 Circ tor sidetrack 10:00 - 11 :30 1.50 STKOH P PROD1 Pump out to 8040, cut trench from 8094' to 8104' 11 :30 - 00:00 12.50 DRILL P PROD1 Drilling 8094' to 9192 with 100 rpms, 275 gpm, 3400 psi, cross fault @ 8824', AST 7.86, ART 6.42 ECD 12.2 10/24/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Circ, one bottoms up with 292 gpm, 3600 psi, 110 rpms to clean up hole ECD 12.5 dropping to 12.2 01 :00 . 01 :30 0.50 DRILL P PROD1 Drill 9194' to 9244 with 275 gpms,34oo psi, 100 rpms 01 :30 - 02:00 0.50 DRILL P PROD1 Circ. with 292 gpm, 3600 psi, 110 rpms, Talking to town., 362 ft of none pay from 8824' to 9186', back in ()"B 9,186' 02:00 - 05:00 3.00 DRILL P PROD1 Drill 9244' to 9479' with 275 gpms,34oo psi, 100 rpms ECD 12.3, went out top of ()"B 05:00 - 05:30 0.50 STKOH P PROD1 Circ. with 292 gpm, 3600 psi, 110 rpms, Talking to town. 05:30 . 07:00 1.50 STKOH P PROD1 POH to 9204' for side track, Circ and cut trench 9245 to 9269', side track well @ 9245' 07:00 . 08:00 1.00 STKOH P PROD1 Time drill 9255' to 9289' 08:00 - 10:00 2.00 DRILL P PROD1 Drill 9289' to 9396 with 275 gpms,34oo psi, 100 rpms Printed: 111812004 8:35:04 AM 11 :30 - 15:00 : 15:00 - 19:00 ! 19:00 - 20:00 i 20:00 - 23:00 10/25/2004 ¡ 23:00 - 00:00 100:00 - 01 :00 i 01 :00 - 02:30 i 02:30 - 04:00 i 04:00 - 04:30 ! 04:30 - 13:30 113:30 - 16:00 I : 16:00 - 19:30 ! 19:30 - 20:30 122:30 - 23:30 I 123:30 - 00:00 00:00 - 00:30 00:30 - 03:30 I I I 103:30 - 04:30 I' 04:30 - 05:00 05:00 - 06:30 106:30 - 07:30 I 107:30 _ 08:30 10/26/2004 08:30 - 10:30 10:30 - 11:00 11:00 - 13:00 13:00 - 15:00 15:00 - 18:00 /18:00 - 18:30 18:30 - 23:30 10/2712004 23:30 - 00:00 00:00 - 01 :30 01 :30 - 02:30 02:30 - 03:00 03:00 - 04:00 04:00 - 05:00 BP Operations Summary Report 3.50 DRILL N DFAL PROD1 Legal Well Name: MPH-16 Common Well Name: MPH-16 Event Name: DRILL+COMPLETE Start: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: Date JFrom - To Hours TaSk CódeNPT Phase 10/24/2004 ! 10:00 - 11 :30 1.50 DRILL N DFAL PROD1 4.00 DRILL 1.00 DRILL N N DFAL PROD1 DFAL PROD1 3.00 DRILL N DFAL PROD1 1.00 DRILL 1.00 DRILL 1.50 DRILL 1.50 DRILL 0.50 DRILL 9.00 DRILL 2.50 DRILL 3.50 CASE 1.00 CASE 1.00 CASE 0.50 CASE 0.50 CASE 3.00 CASE N N P N P P P P P P P P P DFAL DFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DFAL 1.00 CASE 0.50 CASE 1.50 CASE 1.00 CASE P P P P PROD1 PROD1 PROD1 PROD1 1.00 CASE P PROD1 2.00 CASE P 0.50 CASE P 2.00 STWHIP P PROD1 PROD1 PROD2 2.00 STWHIP P PROD2 3.00 STWHIP P 0.50 STWHIP P PROD2 PROD2 5.00 STWHIP P PROD2 0.50 STWHIP P 1.50 STWHIP P 1.00 STWHIP P PROD2 PROD2 PROD2 0.50 STWHIP P 1.00 DRILL P 1.00 DRILL P PROD2 PROD2 PROD2 Page 4 of 7 10/8/2004 11/1/2004 Spud Date: 10/14/2004 End: 11/1/2004 Description Bit stuck, @ 9396 worked and jarred free, pump pressure increase 500 psi over normal, motor not acting right Pumping out of hole to 6515' csg shoe with 2 bbls min., 1420 psi Poh 6515' to BHA I Standing back BHA, lay down MWD and motor, motor had parted a pin, 7 ft up from bit. bit and bottom of motor was pulled out of hole by drive shaft of motor. Picking up BHA #5, with new bit, motor and MWD, Surface test MWD, Abi not working, no backup Rih to 4108 Rih to 6505' Service top drive, cut and slip drilling line RIH to 9300', wash last stand to bottom Circ due to high ECD 12.7 dropped to 12.1 Drill 9396' to 9967' with 80 rpms, 275 psi, 3500 psi Circ for liner, with 275 gpms, 3600 psi. 80 rpms Pumping out to csg shoe @ 6515 with full drilling rate Circ bottoms up @ csg shoe POH to BHA, Laying down BHA Rig up to pickup 4.5 liner PJSM on picking up liner Picking up 4.5, 12.6# L-80 slotted liner, 74 Slotted jts, 13 Solid jts, 3606 ft total, baker Seal bore,Baker HMC hanger, Baker ZXP liner top packer RIH to 6450, break circ. Circ 1 DP Vol - 3 bpm @ 450 psi - 30 bbls pumped Can't RIH from 6450' to 9667' Break circ - drop ball - pump to seat - set hanger with 1800 psi - set packer with 3450 psi - Test backside to 1500 psi - 5 mins - Good test - Release from hanger - Function top rams CBU 1 X- 5 bpm - 800 psi - Recip pipe - Flow check - Well static - Pump dry job POOH from 6261' to Baker running tool Service break running tool Pick up 31/2" HWT - 4 314" DC's - Flush same - Stand back in derrick - PJSM - Pick up - Make up - Whipstock to MWD - Orient - Con't RIH with BHA - Surface Test MWD Con't RIH from 875' to 6320' Orient Whipstock 21 degree to left of high side - Set anchor - Shear off Milling window from 6182' TOW to 6194' BOW - Drill new hole from 6194' to 6208' - Pump sweep @ 6190' - 6208' - PP 2190- 275 gpm - WOM 2 to 3 - RPM 80 to 95 - TQ 4 - PU 118 - SO 93 - ROT 100· Flow check - Well Static - Pump dry job POOH with milling assy from 6190' to 5143' POH with milling assy from 5143' to 875' Stand back 4314" DC's - 3 1/2 HWT - LD MWD and milling tools Clear rig floor - Lay down Baker tools Flush BOP's - Function BOP's - Flush flowline Make up bit - motor - MWD - Orient - Surface test MWD Printed: 111812004 8:35:04 AM BP Operations Summary Report Page 5 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-16 MPH-16 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 10/8/2004 11/1/2004 Spud Date: 10/14/2004 End: 11/1/2004 Date From - To Hours Task Code NPT Phase Description of Operations 10/27/2004 105:00 - 07:00 2.00 DRILL P PROD2 RIH from 270' to 6111' - Fill pipe every 25 stds 07:00 - 07:30 0.50 DRILL P PROD2 Rig service - Top drive service - Blocks 1 Crown 07:30 - 08:00 i 0.50 DRILL P PROD2 Orient motor - Exit window - Set Drlg parimeters - RIH to 6208' I I ¡ 08:00 - 00:00 16.00 DRILL P PROD2 Directional Drill OA Lateral from 6208' to 7836' - WOB x - RPM I 60 to 70 - TO on 4 - off 3 - GPM 275 - PP on 3320 - off 3160- ¡ I PU 130 - SO 80 - ROT 105 10/28/2004 ¡ 00:00 - 02:30 2.50 DRILL P PROD2 Directional Drill from 7836' to 8123' - WOB 2 to 6 - RPM 60 to 70 - TO on 4 - off 3 - GPM 275 - PP on 3450 - off 3324 - PU 132 - SO 80 - ROT 105 02:30 - 04:00 1.50 DRILL P PROD2 CBU 2 X - GPM 300 - PP 3320 - RPM 85 - TO 4 04:00 - 05:30 1.50 DRILL P PROD2 Pump out of the hole from 8,123' to 6,150' at full drilling rate - Slight packing off from 6650' to 6296' - Pull without pump from 6296' to 6108' through window - No problems .05:30 - 06:30 1.00 DRILL P PROD2 Circulate Bottoms Up While Rotating And Reciprocating Drill i String - 275 gpm, 60 RPM 106:30 - 07:30 1.00 DRILL P PROD2 Orient Mud Motor And Slide Thru Whipstock Window With No I Problem - RIH From 6,170' To 8,027' - As Precaution Wash I Last Stand To Bottom From 8,027' To 8,123' 107:30 - 22:00 14.50 DRILL P PROD2 Drilled 6 3/4' Directional Hole By Rotating And Sliding From 8,123' To 9,179' WOB Rotating 4,000# - 5,000#, RPM 60, Motor RPM 208, Torque Off Bottom 4,000 ft Ilbs - On Bottom 5,000 ft Ilbs, Pump Rate 272 gpm, SPP Off Bottom 3360 psi, On Bottom 3,460 psi. String Weight Up 145,000#, String Weight Down 52,000#, String Weight Rotating 100,00#. 22:00 - 23:00 1.00 DRILL P PROD2 CBU 1 X - Circulate hole clean - Not able to slide - 275 gpm - 3360 ICP - FCP 3250 - RPM 80 23:00 - 00:00 1.00 DRILL P PROD2 Directional Drill from 9179' to 9243' - WOB 4 to 5 - RPM 60- TO on 6 - off 4 - GPM 275 - PP on 3360 - off 3250 - PU 140- SO 60 - ROT 100 10/29/2004 00:00 - 08:30 8.50 DRILL P PROD2 Directional Drill from 9243' to 9915' - TD OA Lateral- WOB 3 to 6 - RPM 60 - TO on 5 - off 4 - GPM 275 - PP on 3410 - off 3380 - PU 135 - SO 65 - ROT 100 08:30 - 10:30 2.00 CASE P PROD2 CBU 2 X - GPM 275 - PP 3560 - RPM 65 - TO 5 10:30 - 12:00 1.50 CASE P PROD2 Flow check - Well Static· Pump out from 9915' to 8028' - Pump at drlg rate 12:00 - 13:30 1.50 CASE P PROD2 CBU 1 X - GPM 275 - PP 3480 - RPM 65 - TO 5 13:30 - 14:30 1.00 CASE P PROD2 RIH from 8028' to 9820' - Wash from 9820' to 9915' 14:30 - 17:00 2.50 CASE P PROD2 CBU 3 X - GPM 275 - PP 3490 - RPM 65 - TO 5 17:00 - 20:30 3.50 CASE P PROD2 Pump out from 9915' to 6297' - Pull without pump from 6393' to 6101' through window - No problems 20:30 - 22:00 1.50 CASE P PROD2 CBU - 1 X - GPM 275 - RPM 40 - TO 4.5 - PP 3000 - Lot of sand over shakers - Flow check - Well static - Pump dry job 22:00 - 00:00 2.00 CASE P PROD2 POH from 6101' to 1200' 10/30/2004 00:00 - 00:30 0.50 CASE P PROD2 Con't POH from 1200' to BHA @ 270' 00:30 - 01:30 1.00 CASE P PROD2 Stand back Flex DC's - HWT - lD jars - LD MWD - Flush motor - Break bit - LD motor 01 :30 - 02:30 1.00 CASE PROD2 Clear rig floor of BHA tools 02:30 - 03:30 1.00 CASE P PROD2 PU Baker retrieving tool for pulling WS - Make up MWD - Orient - Can't RIH with Retieving BHA - Surface test MWD - 6.7 bpm - @ 1500 psi 03:30 - 05:00 1.50 CASE P PROD2 RIH with Retrieving assy from 750' to 6100' 05:00 - 05:30 0.50 CASE P PROD2 Break Circ - Orient Hook to 21 degree left of high side - latch onto Whip stock - pull free - PU 118 . S) 94 - Flow check - Well Printed: 11/812004 8:35:04 AM BP Operations Summary Report Page 6 of 7 Legal Well Name: MPH-16 Common Well Name: MPH-16 Spud Date: 10/14/2004 Event Name: DRILL+COMPLETE Start: 10/8/2004 End: 11/1/2004 Contractor Name: DOYON DRILLING INC. Rig Release: 11 /1 /2004 Rig Name: DOYON 14 Rig Number: From - To Hour~ask l Code NPT Phase Description of Operations 10/30/2004 05:00 . 05:30 0.50 I CASE I P PROD2 static 05:30 - 06:00 0.50 I CASE P PROD2 CBU - GPM 275 - PP 2250 - Flow check - Pump dry job 06:00 . 09:30 3.50, CASE i P PROD2 POH with Whip stock 09:30 - 11 :00 1.501 CASE Ip PROD2 LD MWD - Retrieval tool and whipstock assembly 11 :00 - 12:00 1.00ICASE IP PROD2 Clear rig floor 12:00 - 15:00 3.00 CASE ! P PROD2 PJSM - Pick up 4 1/2" slotted liner - Total 84 jts 41/2" slotted I I 12.6# L-80 IBT liner - 4 jts 41/2" 12.6# L-80 IBT solid liner - 1 4 I I 1/2" 12.6# L-80 IBT Bent jt with float shoe - Total jts ran 89 15:00 - 15:30 0.50 CASE !P PROD2 Make up Baker hook wall hanger - Liner running tool - PU 80 - I SO 77 15:30 - 19:00 3.50 CASE !P PROD2 RIH with liner on 4" dp from 3738' to 6182' - work liner through I window - Three attempts to exit window - PU 112 - SO 92 - I Con't RIH with liner - Work centralizers through window on i stands 37 through 44 - stands 47,49,50,51, 58, and 59 I 19:00 - 20:30 1.50 CASE !p PROD2 Hook hanger @ 6194' shoe @ 9905' - Pick up release hook- I RIH with hanger to 6204' shoe at 9915' - Pull back to 6174' I I hanger depth shoe depth 9885' - rehook hanger @ 6194' shoe I 9905' - Break circulation 3 bpm @ 580 psi - Drop 29/32 ball - Pump ball 3 bpm @ 580 psi 300 strokes - Slow to 1.5 bpm @ I 290 psi for 236 strokes - Ball on seat - Pressure up to 3700 psi Ip - Bleed off presure to zero - Pick up to confirm released off liner - (SPM's directed by Baker Rep) - Liner released 20:30 - 21 :00 0.50 CASE PROD2 Rig up pump in sub - Cement line - Test pump - (For shear out of ball and seat) 21 :00 - 21 :30 0.50 CASE P PROD2 Pump to 4000 psi with rig pump - Shut down - Switch to test pump - Con't pressure up to shear out ball and seat at 4400 psi - Ball sheared 21 :30 - 22:00 0.50 CASE P PROD2 CBU 1 X - Flow check - Well static - Pump dry job 22:00 - 00:00 2.00 CASE P PROD2 POH with Baker liner running tool From 6015' to BHA @ 750' 10/31/2004 00:00 - 00:30 0.50 CASE P PROD2 Service break Baker running tool - LD running tool - Clear rig floor 00:30 - 01 :00 0.50 CASE P PROD2 Make up circ sub - RIH with DC's - HWT 01 :00 - 02:00 1.00 CASE P PROD2 PJSM - Cut drlg line - Rig service 02:00 - 03:00 1.00 CASE P PROD2 RIH with circ sub to 6170' 03:00 - 04:00 1.00 CASE P PROD2 Rig up to displace - PJSM on displacing Oil base mud 04:00 - 05:00 1.00 CASE P PROD2 Displace oil base mud with: 15 bbls LVT-2oo 20 bbls Viscosified 10.5 brine 20 bbls water with 1 drum Safe Surf "0" 20 bbls Viscosified 10.5 brine 304 bbls 10.5 brine with 2 drums Corrosion Inhibitor Pump at 9.5 bpm @ ICP 3000 - FCP 2100 - RPM 110 - TQ 5 05:00 - 08:30 3.50 CASE P PROD2 Lay down 4" drill pipe 08:30 - 10:30 2.00 CASE P PROD2 Run remaining 4" dp in hole from derrick 10:30 - 15:30 5.00 CASE P PROD2 Lay down 4" drill pipe - 31/2" HWT - 4 314" DC's - Pull Wear ring· Clear rig floor 15:30 - 16:00 0.50 CASE P PROD2 Rig up Power tongs - Slips - Elevators - Centrilift equipment - SpooIer for ESP cable 16:00 - 19:00 3.00 CASE P PROD2 PJSM - Make up ESP pump - Service pump - Test 19:00 - 00:00 5.00 CASE P PROD2 PJSM - Pick up and run 2 7/8" Completion - Break circulation 1 bpm @ 1410 psi I test ESP cable every 2000' - Total jts ran 130 Depth 4056' 11/112004 00:00 - 02:00 2.00 RUNCO RUNCMP Can't running 2 7/8" ESP completion from 4056' to 5888' - Printed: 11/812004 8:35:04 AM Page 7 of 7 BP Operations Summary Rep.ort Start: Rig Release: Rig Number: Phase of Operations RUNCMP Break circulation at 1 bpm @ 1410 psi I test ESP cable every 2000' - Pick up landing joint - Make up landing joint to FMC tubing hanger and tubing hanger to string - Total joints 2 7/8" EUE 8rd ran 183 - Total LaSalle clamps ran 100 - 5 each protectolizers - 3 each flat guards - PU 82 - SO 70 - Block weight 50 Rig up circ line - Break circ - Pump 10 bbls to clear debri from tubing 1 bpm @ 1500 psi - Rig dwn circ lines Make up ESP cable to hanger and test RIH with completion string from 5888' to 5922' - Land tubing hanger - AILDS - Test TWC to 1000 psi - Bleed off pressure - Back out landing joint Nipple down BOP's Nipple Up Tubing Head Adapter And 2 9/16" 5M Production Tree Test Tubing Hanger - Pack Off - And Production Tree To 5,000 Psi. (Test Good) Pull TWC And Install BPV Hold PJSM With Little Red Hot Oil Services - Freeze Protect Tubing And IA Down To 500 Feet - Final Tubing Pressure At 600 Psi. And IA Pressure At 400 Psi. Secure Well Head And Production Tree - Remove Secondary Annulus Valve - Vacuum Out Celler Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPH-16 MPH-16 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 From-To Hours Task cOd.i NPT 00:00 - 02:00 2.00 RUNCO i 11/1/2004 02:00 - 02:30 0.50 RUNCMP 02:30 - 04:00 RUNCMP 04:00 - 05:00 RUNCMP 05:00 - 06:30 1.50 BOPSU P RUNCMP 06:30 - 08:00 1.50 WHSUR P RUNCMP 08:00 - 08:30 0.50 WHSUR P RUNCMP 08:30 - 09:30 1.00 WHSUR P RUNCMP 09:30 - 11 :00 1.50 WHSUR P RUNCMP 11 :00 - 12:00 1.00 WHSUR I P RUNCMP 10/8/2004 11/1/2004 Spud Date: 10/14/2004 End: 11/1/2004 Release Doyon Rig 14 From Well Work On MPH-16 At 12:00 Hours On 11-1-2004 Printed: 11/812004 8:35:04 AM WELL SERVICE REPORT WELL MPH-16 DATE 11/2/2004 AFE MSD337410 JOB SCOPE NEW WELL POST DAILY WORK FREEZE PROT KEY PERSON LRS-BRENNY TOM MINID 0" UNIT LRS 62 DAY SUPV HULME NIGHT SUPV UNKNOWN TTL SIZE 0" DEPTH OFT DAILY SUMMARY Freeze protecte"<Tií:ibing and TA· Pumped 19 bbls diesel down tubing and 6ir5bls diesel (jowntfiëTÃ. SPM set u added to indicate the status of the SPM's in the well. Init Tba. IA OA -> I TIME I COMMENT Final Tba. IA-~Õ-Ä -> I I FLUID SUMMAR1._..~..~... 87 bbls diesel I I I I I I ~~·~<N_'_W~,~_~,~~~.- SERVICE COM~ß~Y:.SERVICE DAILY COST ~~~.~ CUMUL TOTAL LITTLE RED $0 $705 WAREHOUSE ~-~,~_~,~~-_w $0 $3,570 TOTAL FIELD ESTIMATE: $0 $4,275 Legal Name: MPH-16 Common Name: MPH-16 Test Date 10/18/2004 10/21/2004 Test Type FIT FIT Test Depth (TMD) 4,210.0 (It) 6,515.0 (It) Test Depth (TVD) 3,142.0 (It) 4,063.0 (It) AMW --~~_.- 10.50 (ppg) 10.50 (ppg) Suñace Pressure 325 (psi) 420 (psi) Leak Off Pressure (BHP) 2,039 (psi) 2,636 (psi) Page 1 of 1 EMW ---.----... 12.49 (ppg) 12.49 (ppg) Printed: 11/8/2004 8:34:57 AM Halliburton Sperry-Sun Milne Point Unit BPXA MPH-16 . Job No. AKZZ3330703, Surveyed: 25 October, 2004 Survey Report 10 November, 2004 Your Ref: API 500292322700 Surface Coordinates: 6010120.38 N, 556641.19 E (70· 26' 17.8695" N, 210· 27' 42.6435" E) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 70.25ft above Mean Sea Level . spe..........y-sui! DRILLING seRVices A Halliburton Company Survey Ref: svy1496 Halliburton Sperry-Sun Survey Report for MPH-16 Your Ref: API 500292322700 Job No. AKZZ3330703, Surveyed: 25 October, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9218.21 82.200 208.720 3928.63 3998.88 1612.17 S 4935.75 W 6008470.76 N 551717.83 E 5164.76 Tie On Point 9245.00 81.450 208.470 3932.44 4002.69 1635.46 S 4948.44 W 6008447.38 N 551705.32 E 2.948 5185.82 Window Point 9249.85 81.320 208.430 3933.17 4003.42 1639.67 S 4950.72 W 6008443.15 N 551703.06 E 2.802 5189.63 9283.44 83.070 209.380 3937.73 4007.98 1668.80 S 4966.81 W 6008413.90 N 551687.20 E 5.916 5216.17 9313.93 85.920 210.550 3940.65 4010.90 1695.09 S 4981.97 W 6008387.50 N 551672.24 E 10.097 5240.71 . 9352.17 89.940 211.780 3942.04 4012.29 1727.79 S 5001.74 W 6008354.65 N 551652.72 E 10.993 5272.07 9383.84 90.060 211.680 3942.04 4012.29 1754.72 S 5018.39 W 6008327.59 N 551636.27 E 0.493 5298.24 9412.73 89.810 211.720 3942.07 4012.32 1779.30 S 5033.57 W 6008302.90 N 551621.27 E 0.876 5322.11 9449.74 89.940 209.890 3942.15 4012.40 1811.09 S 5052.53 W 6008270.97 N 551602.56 E 4.957 5352.35 9481.69 90.120 207.950 3942.13 4012.38 1839.05 S 5067.98 W 6008242.89 N 551587.33 E 6.098 5377.84 9508.60 90.860 206.340 3941.90 4012.15 1863.00 S 5080.25 W 6008218.85 N 551575.23 E 6.584 5398.79 9545.00 90.680 204.650 3941.41 4011.66 1895.85 S 5095.92 W 6008185.88 N 551559.82 E 4.669 5426.47 9576.17 90.740 204.160 3941.03 4011.28 1924.23 S 5108.80 W 6008157.40 N 551547.16 E 1.584 5449.77 9602.92 89.880 201.780 3940.88 4011.13 1948.86 S 5119.24 W 6008132.70 N 551536.90 E 9.460 5469.33 9635.49 88.770 199.960 3941 .27 4011.52 1979.29 S 5130.84 W 6008102.18 N 551525.53 E 6.545 5492.30 9668.47 87.530 198.680 3942.33 4012.58 2010.39 S 5141.74 W 6008070.99 N 551514.87 E 5.402 5514.92 9698.57 87.470 198.250 3943.64 4013.89 2038.92 S 5151.27W 6008042.40 N 551505.56 E 1.441 5535.22 9730.93 87.470 198.040 3945.07 4015.32 2069.64 S 5161.33 W 6008011.60 N 551495.72 E 0.648 5556.91 9768.11 89.880 197.260 3945.93 4016.18 2105.05 S 5172.60 W 6007976.10 N 551484.72 E 6.813 5581.61 9794.64 90.250 197.570 3945.90 4016.15 2130.37 S 5180.54 W 6007950.73 N 551476.98 E 1.819 5599.16 9828.97 92.590 196.290 3945.05 4015.30 2163.20 S 5190.54 W 6007917.82 N 551467.23 E 7.769 5621.64 . 9891.35 94.450 195.270 3941.22 4011.47 2223.11 S 5207.47 W 6007857.78 N 551450.76 E 3.399 5661.48 9967.00 94.450 195.270 3935.35 4005.60 2295.87 S 5227.33 W 6007784.87 N 551431.45 E 0.000 5709.22 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. 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 and calculated along an Azimuth of 246.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9967.00f1., The Bottom Hole Displacement is 5709.29f1., in the Direction of 246.289° (True). 10 November, 2004 - 13:35 Page 2 of 3 DrillQuest 3.03.06.006 Milne Point Unit Comments Measured Depth (ft) 9218.21 9245.00 9967.00 Halliburton Sperry-Sun Survey Report for MPH-16 Your Ref: AP/500292322700 Job No. AKZZ3330703, Surveyed: 25 October, 2004 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3998.88 4002.69 4005.60 1612.17 S 1635.46 S 2295.87 S Survey tool program for MPH-16 From Measured Vertical Depth Depth (ft) (ft) 0.00 534.00 0.00 533.95 Comment 4935.75 W Tie On Point . 4948.44 W Window Point 5227.33 W Projected Survey To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 534.00 9967.00 533.95 CB-SS-GYRO (MPH-16PB1) 4005.60 MWD+IIFR+MS (MPH-16PB1) . 10 November, 2004 - 13:35 Page 3 of 3 DrillQuest 3.03.06.006 . Halliburton Sperry-Sun Milne Point Unit BPXA MPH-16PB1 Job No. AKZZ3330703, Surveyed: 22 October, 2004 Survey Report 2004 10 November, Your Ref: API 500292322770 Surface Coordinates: 6010120.38 N, 556641.19 E (70· 26' 17.8695" N, 210· 27' 42.6435" E) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Survey Ref: svy1485 Kelly Bushing Elevation: 70.25ft above Mean Sea Level 5pe..........y-5u., DAILLING seAVlces A Halliburton Company Halliburton Sperry-Sun Survey Report for MPH-16PB1 Your Ref: API 500292322770 Job No. AKZZ3330703, Surveyed: 22 October, 2004 BPXA Milne Point Unit 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) (O/100ft) 0.00 0.000 0.000 -70.25 0.00 O.OON O.OOE 6010120.38 N 556641.19 E 0.00 CB-88-GYRO 112.00 0.000 0.000 41.75 112.00 O.OON 0.00 E 6010120.38 N 556641 .19 E 0.000 0.00 174.00 0.800 177.000 103.75 174.00 0.438 0.02 E 6010119.95 N 556641.22 E 1.290 0.16 261.00 1.150 178.000 190.74 260.99 1.918 0.08 E 6010118.47 N 556641.29 E 0.403 0.70 . 351.00 0.800 172.000 280.72 350.97 3.448 0.20 E 6010116.95N 556641.42 E 0.405 1.21 440.00 0.600 126.000 369.72 439.97 4.338 0.67 E 6010116.06 N 556641.89 E 0.648 1.15 534.00 1.600 66.000 463.70 533.95 4.088 2.26 E 6010116.32N 556643.49 E 1 .489 -0.41 MWD+IIFR+M8 649.62 4.380 40.540 579.16 649.41 0.07 8 6.61 E 6010120.36 N 556647.80 E 2.607 -6.01 747.26 4.640 36.970 676.49 746.74 5.92 N 11.41 E 6010126.39 N 556652.55 E 0.392 -12.83 844.15 5.840 29.160 772.98 843.23 13.36 N 16.17 E 6010133.86 N 556657.26 E 1 .438 -20.20 939.78 6.500 12.020 868.06 938.31 22.90 N 19.67 E 6010143.43 N 556660.68 E 2.037 -27.28 1036.53 10.580 358.930 963.73 1033.98 37.14 N 20.64 E 6010157.68 N 556661.55 E 4.645 -33.96 1133.50 13.740 351.070 1058.52 1128.77 57.43 N 18.69 E 6010177.95 N 556659.44 E 3.672 -40.43 1230.02 16.410 344.540 1151.71 1221.96 81.90 N 13.27 E 6010202.38 N 556653.84 E 3.274 -45.43 1323.63 19.710 334.160 1240.72 1310.97 108.86 N 2.86 E 6010229.26 N 556643.22 E 4.911 -46.89 1420.40 22.230 327.330 1331.09 1401.34 138.97 N 14.14 W 6010259.24 N 556626.00 E 3.624 -43.61 1517.48 22.910 327.290 1420.73 1490.98 170.33 N 34.26 W 6010290.44 N 556605.63 E 0.701 -37.98 1613.20 23.710 328.740 1508.64 1578.89 202.46 N 54.32 W 6010322.42 N 556585.34 E 1.028 -32.72 1706.80 26.110 328.690 1593.53 1663.78 236.14 N 74.79 W 6010355.95 N 556564.61 E 2.564 -27.72 1802.35 29.640 327.190 1677.98 1748.23 273.98 N 98.53 W 6010393.60 N 556540.59 E 3.766 -21.43 1898.99 34.390 327.020 1759.90 1830.15 316.98 N 126.35 W 6010436.39 N 556512.44 E 4.916 -13.50 . 1994.98 34.610 323.590 1839.01 1909.26 361.67 N 157.29 W 6010480.84 N 556481.16 E 2.037 -3.41 2089.95 39.100 321.120 1914.99 1985.24 406.71 N 192.11 W 6010525.62 N 556445.99 E 4.978 10.08 2186.12 42.150 319.110 1987.97 2058.22 454.73 N 232.28 W 6010573.33 N 556405.46 E 3.451 27.25 2282.02 43.150 316.180 2058.51 2128.76 502.72 N 276.06 W 6010620.99 N 556361.32 E 2.318 47.72 2377.81 45.050 312.100 2127.31 2197.56 549.09 N 323.90 W 6010666.99 N 556313.12 E 3.566 72.57 2471.07 48.110 308.760 2191.42 2261.67 592.96 N 375.48 W 6010710.48 N 556261.22 E 4.186 101.84 2567.60 50.970 305.680 2254.06 2324.31 637.34 N 433.97 W 6010754.41 N 556202.39 E 3.830 137.22 2663.80 54.180 304.090 2312.52 2382.77 681.01 N 496.64 W 6010797.60 N 556139.39 E 3.585 176.71 2758.95 56.570 303.800 2366.58 2436.83 724.73 N 561.59 W 6010840.82 N 556074.11 E 2.524 218.27 2856.84 61.250 302.370 2417.11 2487.36 770.45 N 631.82 W 6010886.01 N 556003.54 E 4.942 263.83 2952.55 62.160 302.730 2462.48 2532.73 815.79 N 702.86 W 6010930.81 N 555932.16 E 1.007 310.28 3048.31 60.740 304.100 2508.25 2578.50 862.11 N 773.07 W 6010976.59 N 555861.60 E 1.944 355.58 3134.25 60.610 304.770 2550.34 2620.59 904.48 N 834.86 W 6011018.49 N 555799.48 E 0.696 394.80 3235.85 62.480 302.470 2598.75 2669.00 953.91 N 909.25 W 6011067.36 N 555724.72 E 2.711 442.65 10 November, 2004 - 13:30 Page 2 of 5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for MPH-16PB1 Your Ref: AP/500292322770 Job No. AKZZ3330703, Surveyed: 22 October, 2004 BPXA Milne Point Unit 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) (0/100ft) 3328.95 62.510 301.780 2641.75 2712.00 997.82 N 979.18W 6011110.74 N 555654.46 E 0.658 488.67 3425.47 61.660 298.700 2686.94 2757.19 1040.78 N 1052.84 W 6011153.13 N 555580.47 E 2.954 538.50 3521.86 58.310 297.140 2735.15 2805.40 1079.87 N 1126.57 W 6011191.66 N 555506.45 E 3.747 589.95 3618.18 57.670 295.980 2786.21 2856.46 1116.39 N 1199.62 W 6011227.63 N 555433.12 E 1.218 641.83 . 3711.37 59.880 294.850 2834.52 2904.77 1150.58 N 1271.60W 6011261.27 N 555360.89 E 2.588 693.68 3808.01 60.240 294.490 2882.75 2953.00 1185.53 N 1347.70 W 6011295.64 N 555284.53 E 0.493 748.98 3903.71 60.320 294.830 2930.20 3000.45 1220.21 N 1423.23 W 6011329.74 N 555208.73 E 0.320 803.88 3999.38 60.810 294.340 2977.21 3047.46 1254.87 N 1499.00 W 6011363.83 N 555132.71 E 0.679 859.00 4095.49 59.960 293.670 3024.71 3094.96 1288.87 N 1575.32 W 6011397.24 N 555056.12 E 1.072 914.90 4132.09 59.740 293.690 3043.09 3113.34 1301.58 N 1604.31 W 6011409.73 N 555027.04 E 0.603 936.21 4186.64 58.340 290.270 3071.16 3141.41 1319.09 N 1647.67 W 6011426.92 N 554983.55 E 5.957 968.70 4283.78 58.590 284.190 3122.00 3192.25 1343.59 N 1726.69 W 6011450.82 N 554904.34 E 5.340 1030.92 4379.04 59.630 279.160 3170.93 3241.18 1360.11 N 1806.71 W 6011466.72 N 554824.20 E 4.660 1097.31 4475.49 59.350 278.500 3219.89 3290.14 1372.86 N 1888.82 W 6011478.86 N 554742.00 E 0.657 1167.13 4572.06 59.490 274.760 3269.04 3339.29 1382.46 N 1971.38 W 6011487.82 N 554659.36 E 3.337 1238.65 4666.83 60.710 273.930 3316.28 3386.53 1388.68 N 2053.30 W 6011493.42 N 554577.40 E 1 .495 1310.96 4763.45 61.280 271.710 3363.13 3433.38 1392.83 N 2137.69 W 6011496.93 N 554492.98 E 2.094 1386.36 4859.77 60.210 267.540 3410.22 3480.47 1392.30 N 2221.70 W 6011495.76 N 554408.98 E 3.937 1463.32 4955.55 60.080 263.460 3457.91 3528.16 1385.78 N 2304.48 W 6011488.62 N 554326.25 E 3.697 1541.60 5051.19 60.840 259.600 3505.08 3575.33 1373.52 N 2386.76 W 6011475.73 N 554244.07 E 3.600 1621.75 5147.49 61.630 256.330 3551.43 3621.68 1355.91 N 2469.30 W 6011457.50 N 554161.66 E 3.087 1704.32 . 5243.58 62.400 252.030 3596.54 3666.79 1332.78 N 2550.91 W 6011433.74 N 554080.23 E 4.032 1788.28 5339.78 62.730 247.250 3640.88 3711.13 1303.08 N 2630.92 W 6011403.44 N 554000.45 E 4.423 1873.46 5435.98 63.970 241 .570 3684.06 3754.31 1265.94 N 2708.41 W 6011365.71 N 553923.24 E 5.432 1959.35 5531.12 66.560 237.580 3723.87 3794.12 1222.17 N 2782.88 W 6011321.38N 553849.11 E 4.681 2045.18 5627.46 68.550 233.410 3760.67 3830.92 1171.73N 2856.22 W 6011270.38 N 553776.15 E 4.502 2132.70 5721.83 69.330 226.710 3794.61 3864.86 1115.22 N 2923.68 W 6011213.36 N 553709.12 E 6.676 2217.32 5819.18 68.950 224.700 3829.28 3899.53 1051.70 N 2988.79 W 6011149.35 N 553644.50 E 1.968 2302.63 5914.31 68.880 224.700 3863.50 3933.75 988.61 N 3051.23 W 6011085.78 N 553582.54 E 0.074 2385.33 6011.59 72.980 223.900 3895.28 3965.53 922.82 N 3115.42 W 6011019.51 N 553518.85 E 4.286 2470.73 6106.87 76.310 223.480 3920.51 3990.76 856.39 N 3178.87 W 6010952.60 N 553455.90 E 3.521 2555.72 6203.04 76.440 222.440 3943.16 4013.41 787.99 N 3242.57 W 6010883.72 N 553392.73 E 1.060 2641.73 6298.50 80.700 222.960 3962.08 4032.33 719.24 N 3306.01 W 6010814.49 N 553329.81 E 4.494 2727.65 6392.95 81.890 221.920 3976.37 4046.62 650.35 N 3369.01 W 6010745.12 N 553267.34 E 1.665 2813.22 6463.14 82.270 221.170 3986.04 4056.29 598.31 N 3415.11 W 6010692.74 N 553221.63 E 1.189 2876.51 10 November, 2004 . 13:30 Page 3 of 5 Drl11Quest 3.03.06.006 Halliburton Sperry-Sun Survey Report for MPH·16PB1 Your Ref: AP/S00292322770 Job No. AKZZ3330703, Surveyed: 22 October, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6530.58 82.450 220.790 3995.01 4065.26 547.85 N 3458.95 W 6010641.94 N 553178.18 E 0.619 2937.07 6580.48 87.100 219.620 3999.55 4069.80 509.91 N 3491.01 W 6010603.76 N 553146.40 E 9.607 2981.80 6627.15 90.560 218.450 4000.51 4070.76 473.67 N 3520.40 W 6010567.30 N 553117.30E 7.826 3023.38 6676.41 92.900 215.900 3999.02 4069.27 434.45 N 3550.14 W 6010527.85 N 553087.85 E 7.024 3066.51 . 6723.13 94.450 212.500 3996.02 4066.27 395.89 N 3576.35 W 6010489.10 N 553061.94 E 7.984 3106.13 6771.38 94.320 208.060 3992.33 4062.58 354.36 N 3600.60 W 6010447.38 N 553038.00 E 9.179 3145.18 6815.63 93.030 206.720 3989.50 4059.75 315.15 N 3620.91 W 6010408.02 N 553017.99 E 4.199 3179.68 6868.35 92.720 206.390 3986.85 4057.10 268.05 N 3644.45 W 6010360.74 N 552994.81 E 0.858 3220.34 6916.07 91.670 205.580 3985.02 4055.27 225.19 N 3665.34 W 6010317.72 N 552974.24 E 2.778 3256.86 6965.43 93.580 204.630 3982.76 4053.01 180.54 N 3686.26 W 6010272.92 N 552953.66 E 4.321 3294.14 7011.77 94.140 204.520 3979.64 4049.89 138.49 N 3705.49 W 6010230.73 N 552934.75 E 1.231 3328.80 7061.18 93.710 204.440 3976.26 4046.51 93.63 N 3725.92 W 6010185.71 N 552914.67 E 0.885 3365.71 7105.43 94.080 205.800 3973.26 4043.51 53.66 N 3744.66 W 6010145.60 N 552896.23 E 3.178 3399.09 7154.07 95.260 207.070 3969.30 4039.55 10.25 N 3766.24 W 6010102.03 N 552874.98 E 3.558 3436.46 7201.99 95.190 206.480 3964.93 4035.18 32.35 S 3787.74 W 6010059.26 N 552853.81 E 1.235 3473.43 7250.79 95.190 206.850 3960.52 4030.77 75.78 S 3809.55 W 6010015.66 N 552832.33 E 0.755 3511.02 7298.33 95.190 206.640 3956.22 4026.47 118.06 S 3830.85 W 6009973.22 N 552811.35 E 0.440 3547.68 7376.00 95.190 206.640 3949.19 4019.44 187.20 S 3865.54 W 6009903.82 N 552777.19 E 0.000 3607.48 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. 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 and calculated along an Azimuth of 246.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7376.00ft., The Bottom Hole Displacement is 3870.07ft., in the Direction of 267.227° (True). 10 November, 2004 - 13:30 Page 4 of 5 Drfl/Quest 3.03.06.006 Halliburton Sperry-Sun Survey Report for MPH·16PB1 Your Ref: API 500292322770 Job No. AKZZ3330703, Surveyed: 22 October, 2004 BPXA Milne Point Unit Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7376.00 4019.44 187.20 S 3865.54 W Projected Survey . Survey tool program for MPH-16PB1 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 534.00 0.00 533.95 534.00 7376.00 533.95 CS-SS-GYRO 4019.44· MWD+IIFR+MS I. 10 November, 2004·13:30 Page 5 of 5 DrillOuest 3.03.06.006 · ;. Survey Ref: svy1492 Halliburton Sperry-Sun Milne Point Unit BPXA MPH-16PB2 Job Ho. AKZZ3330703, Surveyed: 23 October, 2004 Survey Report 10 November, 2004 Your Ref: API 500292322771 Surface Coordinates: 6010120.38 H, 556641.19 E (70026' 17.8695" H, 210027' 42.6435" E) Grid Coordinate System: HAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 70.25ft above Mean Sea Level Spe..........y-sul'1 i D seRVices A Halliburton Company Halliburton Sperry-Sun Survey Report for MPH-16PB2 Your Ref: API 500292322771 Job No. AKZZ3330703, Surveyed: 23 October, 2004 BPXA Milne PoInt Unit 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) (0/100ft) 6916.07 91.670 205.580 3985.02 4055.27 225.19 N 3665.34 W 6010317.72 N 552974.24 E 3256.86 Tie On Point 6937.00 90.990 204.570 3984.54 4054.79 206.24 N 3674.21 W 6010298.70 N 552965.52 E 5.816 3272.67 Window Point 6963.73 90.120 203.290 3984.28 4054.53 181.81 N 3685.05 W 6010274.19 N 552954.86 E 5.790 3292.52 7011.08 90.120 201.120 3984.18 4054.43 137.97 N 3702.95 W 6010230.22 N 552937.30 E 4.583 3326.69 . 7060.66 90.000 200.930 3984.13 4054.38 91.69 N 3720.73 W 6010183.81 N 552919.87 E 0.453 3361.76 7105.62 90.000 201.010 3984.13 4054.38 49.71 N 3736.82 W 6010141.70N 552904.10 E 0.178 3393.54 7160.28 90.490 201.660 3983.89 4054.14 1.20 S 3756.71 W 601009064 N 552884,60 E 1 .489 3432.41 7202.57 92.350 201.450 3982.85 4053.10 40.52 S 3772.24 W 6010051.21 N 552869.37 E 4.426 3462.60 7251.43 91.670 201.720 3981.13 4051.38 85.93 S 3790.20 W 6010005.67 N 552851.75 E 1 .497 3497.47 7298.65 90.740 202.280 3980.14 4050.39 129.70 S 3807.89 W 6009961.76 N 552834.40 E 2.299 3531.43 7352.63 91.600 202.730 3979.04 4049.29 179.56 S 3828.55 W 6009911.75 N 552814.12 E 1.798 3570.58 7394.99 93.210 204.150 3977.26 4047.51 218.39 S 3845.38 W 6009872.79 N 552797.58 E 5.066 3601.76 7443.86 93.090 204.050 3974.57 4044.82 262.93 S 3865.31 W 6009828.10 N 552777. 99 E 0.319 3638.08 7489.98 92.650 206.280 3972.26 4042.51 304.62 S 3884.89 W 6009786.27 N 552758.72 E 4.922 3672.92 7537.37 92.530 206.000 3970.12 4040.37 347.12 S 3905.75 W 6009743.61 N 552738.19 E 0.642 3709.26 7586.28 92.040 205.980 3968.17 4038.42 391.04 S 3927.16 W 6009699.52 N 552717.11 E 1.003 3746.70 7632.04 91.730 204.970 3966.67 4036.92 432.33 S 3946.84 W 6009658.08 N 552697.75 E 2.308 3781.46 7682.79 91.110 205.140 3965.41 4035.66 478.29 S 3968.32 W 6009611.96 N 552676.62 E 1.267 3819.78 7729.76 93.210 205.660 3963.64 4033.89 520.69 S 3988.45 W 6009569.41 N 552656.81 E 4.606 3855.42 7777.29 92.900 205.800 3961.11 4031.36 563.45 S 4009.06 W 6009526.50 N 552636.53 E 0.715 3891.63 7827.17 92.410 205.070 3958.80 4029.05 608.44 S 4030.46 W 6009481.34 N 552615.47 E 1.761 3929.48 . 7872.33 91.300 204.650 3957.33 4027.58 649.40 S 4049.43 W 6009440.25 N 552596.81 E 2.628 3963.47 7921.26 90.860 204.320 3956.41 4026.66 693.92 S 4069.71 W 6009395.57 N 552576.87 E 1.124 4000.10 7968.63 90.680 203.370 3955.78 4026.03 737.24 S 4088.86 W 6009352.11 N 552558.05 E 2.041 4035.22 8015.98 91.110 203.380 3955.04 4025.29 780.70 S 4107.64 W 6009308.51 N 552539.60 E 0.908 4070.05 8064.79 90.680 206.970 3954.27 4024.52 824.86 S 4128.40 W 6009264.19 N 552519.18 E 7.407 4106.98 8113.07 89.690 208.140 3954.12 4024.37 867.66 S 4150.73 W 6009221 .22 N 552497.17 E 3.174 4144.79 8160.97 91.600 210.810 3953.58 4023.83 909.35 S 4174.29 W 6009179.35 N 552473.92 E 6.853 4183.27 8209.91 89.260 214.000 3953.21 4023.46 950.66 S 4200.51 W 6009137.84 N 552448.02 E 8.083 4224.03 8257.39 87.100 216.830 3954.72 4024.97 989.33 S 4228.01 W 6009098.96 N 552420.82 E 7.495 4264.88 8306.89 86.970 221 .240 3957.28 4027.53 1027.72 S 4259.14 W 6009060.34 N 552389.98 E 8.901 4308.93 8353.81 87.470 224.520 3959.56 4029.81 1062.06 S 4291.02 W 600902576 N 552358.36 E 7.063 4352.02 8401.96 90.370 228.080 3960.46 4030.71 1095.31 S 4325.82 W 6008992.25 N 552323.82 E 9.535 4397.33 8445.59 94.450 231.800 3958.63 4028.88 1123.35 S 4359.17 W 6008963.95 N 552290.68 E 12.649 4439.21 8498.93 94.200 237.210 3954.60 4024.85 1154.22 S 4402.45 W 6008932.75 N 552247.63 E 10.124 4491.31 10 November, 2004 - 13:33 Page 2 of 4 Dri/lQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for MPH·16PB2 Your Ref: API 500292322771 Job No. AKZZ3330703, Surveyed: 23 October, 2004 BPXA Milne Point Unit 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) (0/100ft) 8546.66 93.640 237.520 3951.34 4021.59 1179.90 S 4442.55 W 6008906.77 N 552207.73 E 1.340 4538.39 8591.42 94.940 237.760 3947.99 4018.24 1203.79 S 4480.26 W 6008882.59 N 552170.21 E 2.953 4582.55 8641.74 97.240 237.890 3942.65 4012.90 1230.44 S 4522.61 W 6008855.63 N 552128.06 E 4.578 4632.07 8693.77 101.130 237.830 3934.35 4004.60 1257.76 S 4566.09 W 6008827.98 N 552084.79 E 7.477 4682.91 . 8734.82 102.120 237.260 3926.08 3996.33 1279.33 S 4600.02 W 6008806.15 N 552051.02 E 2.769 4722.68 8789.09 101.930 237.530 3914.77 3985.02 1307.93 S 4644.73 W 6008777.21 N 552006.53 E 0.599 4775.16 8882.00 101.930 237.530 3895.57 3965.82 1356.74 S 4721.42 W 6008727.82 N 551930.21 E 0.000 4865.07 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. 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 and calculated along an Azimuth of 246.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8882.00fl., The Bottom Hole Displacement is 4912.49fl., in the Direction of 253.968° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment I. 6916.07 6937.00 8882.00 4055.27 4054.79 3965.82 225.19 N 206.24 N 1356.74 S 3665.34 W 3674.21 W 4721.42 W Tie On Point Window Point Projected Survey 10 November, 2004 . 13:33 Page 3 of 4 DrillQuest 3.03.06.006 Milne Point Unit Survey tool program for MPH-16PB2 From Measured Vertical Depth Depth (ft) (ft) 0.00 534.00 0.00 533.95 To Measured Vertical Depth Depth (ft) (ft) 534.00 8882.00 533.95 3965.82 Halliburton Sperry-Sun Survey Report for MPH-16PB2 Your Ref: API 500292322771 Job No. AKZZ3330703, Surveyed: 23 October, 2004 BPXA Survey Tool Description CB-SS-GYRO (MPH-16PB1) MWD+IIFR+MS (MPH-16PB1) . . 10 November, 2004 - 13:33 Page 4 of 4 DrillQuest 3.03.06.006 . . Survey Ref: svy1494 Halliburton Sperry-Sun Milne Point Unit BPXA MPH-16PB3 Job No. AKZZ3330703, Surveyed: 23 October, 2004 Survey Report 10 November, 2004 Your Ref: API 500292322772 Surface Coordinates: 6010120.38 N, 556641.19 E (70· 26'17.8695" N, 210· 27' 42.6435" E) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 70.25ft above Mean Sea Level Halliburton Sperry-Sun Survey Report for MPH-16PB3 Your Ref: AP/500292322772 Job No. AKZZ3330703, Surveyed: 23 October, 2004 BPXA Milne Point Unit 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) (O/100ft) 8064.79 90.680 206.970 3954.27 4024.52 824.86 S 4128.40 W 6009264.19 N 552519.18 E 4106.98 Tie On Point 8094.00 89.390 206.390 3954.26 4024.51 850.96 S 4141.51 W 6009237.99 N 552506.26 E 4.842 4129.57 Window Point 8113.64 88.520 206.010 3954.61 4024.86 868.58 S 4150.18 W 6009220.31 N 552497.73 E 4.834 4144.66 8160.43 92.220 206.680 3954.31 4024.56 910.50 S 4170.94 W 6009178.23 N 552477.28 E 8.036 4180.68 . 8214.85 94.080 211.480 3951.32 4021.57 957.97 S 4197.34 W 6009130.56 N 552451.25 E 9.447 4224.10 8257.13 93.090 215.260 3948.67 4018.92 993.21 S 4220.55 W 6009095.15 N 552428.31 E 9.225 4259.63 8307.29 92.590 220.020 3946.19 4016.44 1032.86 S 4251.13 W 6009055.26 N 552398.02 E 9.530 4303.71 8351.01 92.350 223.700 3944.30 4014.55 1065.39 S 4280.28 W 6009022.51 N 552369.13 E 8.427 4343.56 8401.73 94.200 229.060 3941 .40 4011.65 1100.31 S 4316.92 W 6008987.31 N 552332.75 E 11.163 4391.24 8447.34 92.350 232.860 3938.80 4009.05 1128.98 S 4352.28 W 6008958.37 N 552297.61 E 9.254 4435.20 8494.51 93.830 237.490 3936.25 4006.50 1155.88 S 4390.93 W 6008931.19 N 552259.17 E 10.291 4481 .45 8543.58 93.890 239.410 3932.95 4003.20 1181.49 S 4432.65 W 6008905.25 N 552217.64 E 3.906 4529.98 8592.13 93.710 239.260 3929.73 3999.98 1206.20 S 4474.32 W 6008880.23 N 552176.16 E 0.482 4578.10 8642.25 93.460 238.980 3926.60 3996.85 1231.87 S 4517.25 W 6008854.23 N 552133.43 E 0.748 4627.76 8689.38 94.700 239.230 3923.24 3993.49 1256.01 S 4557.59 W 6008829.79 N 552093.27 E 2.684 4674.43 8738.30 94.450 238.490 3919.34 3989.59 1281.23 S 4599.33 W 6008804.26 N 552051.73 E 1.592 4722.82 8784.93 93.150 238.730 3916.25 3986.50 1305.46 S 4639.04 W 6008779.72 N 552012.20 E 2.835 4768.96 8834.56 94.010 236.310 3913.15 3983.40 1332.06 S 4680.83 W 6008752.81 N 551970.62 E 5.166 4817.94 8885.32 92.900 233.320 3910.09 3980.34 1361.25 S 4722.23 W 6008723.30 N 551929.43 E 6.273 4867.64 8930.70 90.370 228.750 3908.80 3979.05 1389.77 S 4757.49 W 6008694.52 N 551894.40 E 11 .506 4911.45 8978.29 87.470 225.640 3909.70 3979.95 1422.09 S 4792.39 W 6008661.93 N 551859.74 E 8.934 4956.48 . 9026.58 88.150 222.010 3911.54 3981.79 1456.90 S 4825.80 W 6008626.87 N 551826.60 E 7.642 5001.16 9075.92 86.360 219.210 3913.90 3984.15 1494.31 S 4857.87 W 6008589.22 N 551794.81 E 6.730 5045.68 9122.23 85.550 215.100 3917.17 3987.42 1531.11 S 4885.77 W 6008552.20 N 551767.19 E 9.024 5086.13 9167.42 82.510 211.580 3921.87 3992.12 1568.65 S 4910.47 W 6008514.48 N 551742.78 E 10.259 5123.96 9218.21 82.200 208.720 3928.63 3998.88 1612.17 S 4935.75 W 6008470.76 N 551717.83 E 5.614 5164.76 9267.21 86.600 208.340 3933.41 4003.66 1655.01 S 4959.03 W 6008427.75 N 551694.87 E 9.013 5203.45 9314.24 90.990 206.780 3934.40 4004.65 1696.68 S 4980.78 W 6008385.92 N 551673.44 E 9.906 5240.27 9362.50 91.540 202.700 3933.34 4003.59 1740.49 S 5000.97 W 6008341.95 N 551653.59 E 8.529 5276.53 9412.01 93.270 198.740 3931.26 4001.51 1786.75 S 5018.47 W 6008295.57 N 551636.44 E 8.722 5311.33 9482.00 93.270 198.740 3927.26 3997.51 1852.92 S 5040.92 W 6008229.23 N 551614.49 E 0.000 5358.76 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. 10 November, 2004 -13:34 Page 2 of 3 DrillQuest 3.03.06.006 ~ Halliburton Sperry-Sun Survey Report for MPH-16PB3 Your Ref: API 500292322772 Job No. AKZZ3330703, Surveyed: 23 October, 2004 BPXA Milne Point Unit The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 246.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9482.00ft., The Bottom Hole Displacement is 5370.67ft., in the Direction of 249.818° (True). Comments . Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8064.79 8094.00 9482.00 4024.52 4024.51 3997.51 824.86 S 850.96 S 1852.92 S 4128.40 W 4141.51 W 5040.92 W Tie On Point Window Point Projected Survey Survey tool program for MPH-16P83 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 534.00 0.00 533.95 534.00 9482.00 533.95 CB-SS-GYRO (MPH-16PB1) 3997.51 MWD+IIFR+MS (MPH-16PB1) . 10 November, 2004 - 13:34 Page 3 of 3 DrillQuest 3.03.06.006 ~1f , 1fŒ (ID~ . p lL ~ ® FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. ORAND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPH-16 BP Exploration (Alaska) Inc. Permit No: 204-190 Surface Location: 2969' NSL, 4003' WEL, SEC. 34, T13N, RlOE, UM Bottomhole Location: 731' NSL, 3904' WEL, SEC. 33, TI3N, RI0E, UM (OB) Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. BP Exploration (Alaska) Inc. assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to . ess any required test. Contact the Commission's petroleum field inspector at (907) 659- 7 ager). Sin r BY ORDER 9F THE COMMISSION DATED this-þ' day of October, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. I STATE OF ALASKA . RECEIVED Y ALASKA AND GAS CONSERVATION COMMISSION ..... ...' .. ' .(;hVl s- PERMIT TO DRILL SEP 2 4 2004 20 MC 25.005 Alaska Oil & Gas Cans. Gommission 1a. Type of work _Drill o Redrìll rb. Current Well Class o Exploratory _ Develop~n"8~ta~ Multiple Zone ORe-Entry o Stratigraphic Test o Service o Developmenr Single Zone 2. Operator Name: 5. Bond: IS Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 MPH·16 3. Address: 6. Proposed Depth: , 12. Field I PooI(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 9931' TVD 4000' Milne Point Unit 1 Schrader Bluff 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 025906 j / 2969' NSL, 4003' WEL, SEC. 34, T13N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 3756' NSL, 1952' WEL, SEC. 33, T13N. R10E, UM (OB) 10107104 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 731' NSL, 3904' WEL, SEC. 33, T13N, R10E, UM (OB) 2560 700' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation KBE= 15. Dista,nce to Nearest Well Within po~~ Surface: x- 556641 " y- 6010120 - Zone- ASP4 (Height above GL): 70.5' feet t>lX) ~awayfrom MPI-03 .",,~ 16. Deviated Wells: Kickoff Depth: tlO,~O' feet.ÞP, 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 94 3é~1t;~;I Downhole: 2104 Surface: 1970 I !tGaslng f'rQ9~m: $þecffications Tr,~ttinQl.¥p~~()1 :011'1 lc.f;, ~..; Size ., _"",,01 """,. Hole Casino Weìoht Grade Couolina Lenath MD TVD MD TVD (includin staoe data) 42" 20" 92# H-40 Welded 112' Surface Surface 112' 112' 260 sx Arctic Set Approx. ) 13-1/2" 10-3/4" 45.5# L-80 BTC-M 2769' Surface Surface 2769' 2318' 302 sx PF 'L', 263 sx Class 'G' 9-7/8" 7-5/8" 29.7# L-80 BTC-M 6488' Surface Surface 6488' 4085' 588 sx Class 'G' 6-3/4" 4-1/2" 12.6# L-80 BTC 3443' 6488' 4085' 9931' 4000' Uncemented Slotted Liner 19. PRESENTWr;LL CONDITION SUMMARY (To be completed for R.edrill ANQRe..el'\wYQperatic:)[}$) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): IEffective Depth TVD (ft): Junk (measured): ;i'!i;'iA/,j AA !'Ai'i; ;'..;, ;;"';,)' A; """';';)"0).").,, .d;AS,A; };';ii' ..,; CnnrllJr.tnr Production Liner Perforation Depth MD (ft): IPerfOration Depth TVD (ft): 20. Attachments IS Filing Fee, $100 o BOP Sketch IS Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis ¡g¡ Property Plat o Diverter Sketch o Seabed Report IS Drilling Fluid Program IS 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Walter Quay, 564-4178 Printed Nam~heY Title Senior Drilling Engineer Sionature A ",",L/1 - ' Prepared By Name/Number: Phone .5: tv '-1- s-ø {} -5 Date r¡ /Z·3/tJC(_ Sandra 564-4750 ?i \~,x?X. xx. :Z5·.·.··i'i>... .xii,"; XX )X: ',;/i;?iii,''' ,;>;;;;;.'\",,; 'i>:ii/i'i;;, .;>;..: ,,> > Permit To Drill 4- ~. I J/l'PI Number: Permit APpr~i~ ' It I ~ee cover letter for Number: ;2.0' -/ 0 50-C:ø.1,232..:Z:7-eú Date: /0 ~ b L/ other requirements Conditions of Approval: Samples Required DYes !)ZJ' No Mud Log Required DYes ~No Hydrogen Sulfide Measures DYes 5('No Directional Survey Required ~Yes D No Othero 7>\)~"\ /, ~ s\- c... '> \> \c.."",~ð " 0{)? ~c;.\-\'<'..~\~{.J.. \ '=- \ \..-\.~4'i ~ I Date /OßJðÇ?./ Anoraved Bv. Jl~ ~ APPROVED BY -- , .. ! \ J 1\ I THE COMMISSION =orm 10-401 ReVised 0672ðó4 - ! I \iI-\ L SlIbmj( In Duþlicate '.<:'1 . . ¡Well Name: IMPH-16 Drill and Complete Plan Summary MPH·16 Well PrOQram I Type of Well (service I producer I injector): I Schrader Bluff Multi-Lateral Producer Surface Location: 2,969' FSL, 4,003' FEL, SEC. 34, T13N, R10E (As Built) E=556641 N=6010120 Target Location: 3756' FSL, 1952' FEL, SEC. 33,T13N, R10E Top OB E=553405 N=6010884 Z= 3965' TVD SS Target Location: 731' FSL, 3904' FEL, SEC. 33, T13N, R10E BHL OB Well TD E=551482 N=6007845 Z=3930' TVD SS Target Location: 3036' FSL, 2399' FEL, SEC. 33 , T13N, R10E Top OA E=552965 N=6010161 Z= 3940' TVD SS Target Location: 731' FSL, 3904' FEL, SEC. 33, T13N, R10E BHL OA Well TD E=551482 N=6007845 Z=3865' TVD SS Distance to Property line 700' Distance to nearest pool 3701' from MPi-03 7 Mud Program: 13-1/2" Surface Hole 0 - 4250' : LSND Densit PV YP API FL H 8.6 - 9.4 10 - 25 30-50 NC-8 8.5 - 9.5 9-7/8" Intermediate Hole 4240' - 5728' : LSND Densit PV YP API FL H Chlorides MBT 9.5 8 - 15 26 - 32 6 - 8 9.0 - 9.5 < 1500 < 25 9-7/8" Intermediate Hole 5728' - 6488' : LSND D PV YP API FL H Chlorides MBT 10.5 8 - 15 26 - 32 6 - 8 9.0 - 9.5 < 1500 < 25 I / 6-3/ OB Production Hole 6488'-- 9931' : MOBM Density(ppg PV YP HTHP Oil:Water Electrical Ratio Stability 10.5 ¡ 15 -26 20 - 22 < 8 80:20 550 - 900 6- Production Hole 6135-- 9910' : MOBM Density (ppg PV YP HTHP Oil:Water Electrical Ratio Stability 15 -26 20 - 22 < 8 80:20 550 - 900' . . MPH-16 Well Program I LCM Restrictions: Yes. Use CaC03 as LCM Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU lR. Cement Pro ram: Casin Size 10-3/4"45.5 Ibltt L-80 BTC Surface Casin Lead Slurry to surface. Excess 150% over gauge hole. To of tail cement 1000' MD above casin shoe. Total Cement Volume: 294 bbl Wash S acer Lead Tail Tern Casin Size 7-5/8" 29.7 Ib/tt L-80 BTC-M Intermediate Casin Basis Top ot tail slurry 500' MD above TUZC. 40% excess over Total Cement Volume: 122 bbl Wash 25-bbl water Basis S acer Tail Tern 15-bbl water 8 . . MPH-16 Well Program E I r p va ua Ion rogram: 13-1/2" Section Open Hole: MWD/GR Photo Gryo IFR/CASANDRA Sperry InSite Cased Hole: N/A 9-7/8" Section Open Hole: MWD/GR/RES ,/ IFR/CASANDRA Sperry InSite Cased Hole: N/A 6-3/4" Section Open Hole: MWD/GR/RES/ABI / IFR/CASANDRA Sperry InSite Cased Hole: N/A Formation Markers: Formation Tops MDrkb TVDrkb (ft) Pore Pressure Estimated EMW (ft) (psi) (lb/gal)* BPRF 1894 1820 759 8.35 TUZC 4780 3448 1466 8.35 UQnu-MA 5226 3667 1561 8.35 Ugnu-MB1 5249 3677 1566 8.35 Ugnu-MB2 5153 3632 1585 8.35 UQnu-MC 5646 3844 1638 8.35 SBF2-NA 5728 3875 2037 ( 10.3 SBF1-NB 5823 3908 2055 10.3 SBE4-NC 5902 3935 2069 10.3 SBE2-NE 5957 3954 2079 ( 10.3 SBE1-NF 6093 3999 2103 '\,J 0.3 TSBD-Top OA 6212 4031 1595 7.75 TSBC-Base OA 6304 4053 1604 7.75 TSBB-Top OB 6459 4081 1616 7.75 SBA5-Base OB 6606 4101 1624 7.75 .' ./ 9 . . MPH-16 Well Program c IT b" p aSln~ U Ing rogram Hole Size Csgl WtlFt Grade Conn Length Top Bottom Tbg O.D. MD I TVDrkb MD I TVDrkb 42-in 20-in* 92# H-40 Welded 112' 0' 112' / 112' 13.5-in 10.75-in 45.5# L-80 BTC-M 4,250' 0' 4,250' / 3,170' 9.875-in 7.625-in 29.7# L-80 BTC-M 6,488' 0' 6,488 I 4,085' 6.75-in 4.5-in 12.6# L-80 BTC 3,443' 6,488/ 4,085' 9,931 '/4,000' OB Slotted 6.75-in 4.5-in 12.6# L-80 BTC 3,775' 6,135'/4,010' 9,910'/3,935' OA Slotted Recommended Bit Program: BHA Hole Size Depth (MD) Bit Type Nozzle/Flow rate 1 13.5" 0' - 4,250' Hughes MXC1 2 9.875" 4,250 - 6,488' Smith XR+iVC 3(OB) 6.75" 6,488' -9,931' Hycalog OS 146 4(OA) 6.75" 6,135 ' -9,910' Hycalog OS 146 10 . . MPH-16 Well ProQram Well Control: Intermediate/Production hole: · Maximum anticipated BHP: 2,1 04-psi @ 3,928-ft TVDrkb - SBE1-NF · Maximum surface pressure: 1,970 psi @ surface (Based on BHP and a full column of gas from TD @ O.l-psi/ft) · Planned BOP test pressure: 3,OOO-psi. For this well, approval is sought to change the BOP testing interval from 7 to 14 days. An FIT to l2.5-lb/gal at the 1O-3/4"shoe. 52-bbl with 1O.8-lb/gal mud. MOBM in Weill/Laterals · Integrity test: Kick tolerance: · Planned completion fluid: Drilling Hazards & Contingencies: · Hydrates have been encountered on H-Pad wells, but are not expected to be a major problem. / Lost Circulation ..............We donºte2<.e~?t losses while drilling this well. (. Expected Pressures -.----..................................................'.. "0 ......---....... ........... ................._._._~ ) . On 2002 drilling, possible over-pressure was encountered in drilling H-13A. Gas cut mud and oil ) (I at the shakers, requiring 9.8 ppg mud was encountered in the Schrader Bluff. The planned MW (.. in this Schrader Bluff interval is >10.3 ppg and should take care of this issue./) ----..... ' ".-' , Pad òãia--Sheêt .--------.... ......-"".... ......~ · Please Read the I-Pad Data Sheet thoroughly. Breathing · Not expected or predicted. Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Faults · Three fault intersections are prognosed for this well. These are in the SV (-3,169' MD), the MB1 5,270' MD), OA (8,000' MD) and in the OB & OA Laterals (-8,700' MD). Hydrogen Sulfide · MPH Pad is not designated as an HzS Pad. I-Pad wells <2-ppm HzS reported. Latest samplings: o MPH-07 <2 6/27/04 o MPH-09 <2 6/27/04 o MPH-13A <2 6/27/04 / Anti-collision Issues · MPH-16 passes the Major Risk Criteria. The closest issue is MPI-13 at 700' with a 30' center to center distance. Distance to Nearest Property · MPH-16 is 700 ft from the nearest Milne Point property line. Distance to Nearest Well Within Pool · MPH-16 is 600' from the Schrader Bluff sand penetration in MPI-03. 11 '" . . MPH-16 Well Program DRILL & COMPLETION PROCEDURE Pre-Rig Operations Drillina 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 1. The 20" conductor is installed. 2. NU Diverter MIRU Doyon 14, NO Tree/NU BOP. Function Test Diverter, PU 4" DP. - ~,.~."- ........ Drill 13.5" surface hole. Run and cement 10.75" surface casing. NO diverter, install wellhead and NU/Test BOP. Drill 9.875" intermediate hole. Run and cement 7-5/8" intermediate casing. Displace to MOBM. Drill 6-3/4" OB horizontal production hole." Run 4.5" slotted liner. Run whipstock and mill window for OA lateral. Drill 6-3/4" OA horizontal production hole. Retrieve whipstock. Run 4.5" slotted liner and hang off in 7.625" casing RU and Run 2.875" ESP Completion. dO'--\ - \ ~ \ NO BOP/NU Tree Freeze Protect With Diesel. RDMO Doyon 14. T~'7 ~\1,,:;A \ ~ 12 · MPH-16 Proposed TREE: 2-9/16" 5M WELLHEAD: FMC Gen 5 System 11", 5M Tubing Head: FMC 11" X 2.875" 9.2 PPG Versapro MOBM below Completion Baker ZXP Liner Top Packer & HMC Hanger @ -6,250' MD DATE 09/132004 w. Quay I 112' Camco 2 7/8" X 1" side pocket KBMM GLM -200' 2-7/8" 6.5 ppf, L-80, EUE production tubing (Drift ID = 2.347", cap = 0.00579 bpf) Camco 2 7/8" x 1" sidepocket KBMM GLM -2000' 10-314",45.5# L-80 BTC Csg Casing ID 9.950" Casing Drift 9.794" Camco 2 718" x 1" sidepocket KBMM GLM 2 Jts above ESP 2 7/8" XN Nipple. 1 Jt above ESP Centrilift ESP Baker Hookwall Hanger Window in 7-518" casing@ 6,135' M Well Inclination @ Window = 74° 7-518",29.7#, L- ·;STC-M Casing Drift: 6.75" Casing ID: 6.875" 6·3/4" 08 Lateral I 6,488'-9,931'1 ' Proposed Multi-lateral Milne Point WELL: MPH-16 API NO: 50-029- 50-029- 50-029- I I , I L _ _ ___ __ __ _ _ _ ___ _ _ ___ __ ___ ___ __ __ ___, I I I I I I I I I I I I , I I I I I , I , I , , \ \ I I , I I I I I I I I I I I I I I , I I I : I \ I I , , I I I , I I I , I I I I I I I I I I I I I I I I I I I I , I , I I I , I - - - ---- --- -- - - --- -- -- ---- ----,./) 15·40·59" ~ ... z '!! :5 CI "- -~- I H-14. H-13. I':=~~: H-10. H-9. I .. H-18 .. H-17 1 .. H-16 Á H-15 3D' (TYP)'fT T · H-4 · H-5 · H-3 · H-6 · H-2 · H-8 · H-1 · H-7 MPU H-PAD MQ.IES 1. DATE OF SURVEY: JULY 24, 2004. 2. REFERENCE FIELD BOOK MP04-02 pp.17-21. 1. ALASKA STATE PLANE COORDINATES (ASP.) ARE ZONE 4 ALASKA, NAD 27. 2. PAD SCALE FACTOR IS 0.99990364 3. HORIZONTAL CONTROL IS BASED ON MPU H-PAD MONUMENTS H-1 AND H-2 VICINITY MAP N.T.S. LEGEND -+ AS-BUILT WELL CONDUCTOR . EXISTING WELL CONDUCTOR SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JULY 24, 2004. LOCA TED WITHIN PROTRACTED SECTION 34, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.s.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS H-15 y= 6,010,091.32 N= 1,409.85 70"26'17.584" 70.4382178" 2,940' FSL X= 556,633.05 E= 879.91 149"32'17.602" 149.5382228" 35.8 4,011' FEL H-16 Y= 6,010,120.38 N= 1,440.03 70"26'17.869" 70.4382969" 2,969' FSL - X= 556,641.19 E= 879.89 149"32'17.356" 149.5381544" 36.2 4,003' FEL ' H-17 y= 6,010,149.22 N= 1,470.03 70"26'18.153" 70.4383758" 2,997' FSL X= 556,649.44 E= 880.04 149"32'17.108" 149.5380856" 35.7 3,995' FEL H-18 Y= 6,010,178.19 N= 1,500.11 70"26'18.437" 70.4384547" 3,026' FSL X= 556,657.51 E= 879.97 149"32'16.865" 149.5380181" 35.6 3,986' FEL ~, DRAWN: HACKLEMAN bp CHECKED: BP EXPLORATION JACOBS DATE: 7-27-04 DR^\\1NG: SHEET: f"RB04 MPH 01-00 MILNE POINT UNIT H-PAD ~ ffi~[J][~o JOB NO: SCALE: AS-BUlL T CONDUCTORS KYoH JJ [JfØNE(~lINDlAIIDSUIM:'I'CI!S WELLS MP H-15. H-16. H-17, H-18 1 OF 1 1IO'I'1[51 ftRE\IŒD lAN[ I" = 150· BY CHK AHCHORM::£. ALASKA ,,~ o 7-27-04 ISSUED FOR INFORMATION NO. DATE REVlSfON SURVEY PROGRA..M Plan: MPH.16 WP06 (Plan Neo (MPH-16 )IMPH.16, Depth Fm Depth To SurveylPlan Tool Created By: Troy Jakabosky Date: 8/1 1/2004 ]4.30 1200.80 Planned: MPH-16 wPo6 V65 CB-GYRO.sS Checked: Date:_ 1200.80 99]1.92 Planned: MPH-16 WPO(; V65 MWD+IFR+MS Reviewed: Date:_ - WELL DETAIL') N"", +N/-S +Ð-W Noo1/;ng ""'ring Latitude Long- Slot PJanNeoCMPH_rf;\ 13936 1244..90 6(}1012038 556641.19 70"26'17.870N 149"32'17.3S6W NlA SECT/ON DETAILS True North INFORM.'" TlON MPH· REFERENCE Co-ordinate (NIE) Reference: Well CenlR': Plan Neo Vertical CTVD) Ref~: 34.3+36270.50 Section (VS) Reference: Slot - CO.OON.o.OOE) Measu~a~rano~~:::~ ::i;i;;~ Cuf\:~~O COMPANY DETAILS SP Amoco Calculation MetOOd: Minimum Curvature Error System: ISCWSA Scan Method: Tra... Cylinder Nonh Error Surface; Elliptica!+Casing Warnini MetOOd: Rules Based t () Northing Easting Shape 6011522.00 555858.00 Polygon 6011984.00 553919.00 Polygon 6010073.00 551358.00 Polygon See MD Ine 6008233.00 551987.00 Polygon 6009020.00 552295.00 Point I 34.30 0.00 6009171.00 551603.00 Polygon 2 600.80 0.00 6007845.00 551482.00 Point 3 850.80 5.00 6008680.00 551810.00 Point 4 1046.09 10.00 6009515.00 552620.00 Point 5 1810.58 32.93 6011349.00 553187.00 Polygon 6 1929.73 32.93 6010884.00 553405.00 Point 7 2861.56 60.62 6010883.68 553404.71 Polygon 8 4107.08 60.62 6010704.35 553227.68 Point 9 5781.02 70.00 10 6031.02 70.00 . I' " II 6156.01 75.00 ¡ I I I i 12 6231.06 75.00 , , 13 6356.08 80.00 ' 14 6488.58 80.00 15 6791.88 94.16 16 7789.80 94. I 6 17 7833.06 94.31 18 7888.44 94.30 19 8165.43 94.30 20 843ü.43 90.00 21 8530.69 88.14 22 8862.45 88. I 4 23 9024. I 5 90.00 , 1 24 9383.90 90.39 i! I ¡ II I' I i I 25 -' 9931.92 90.39 I . , i I I jl , i I ~dbiJ . J7L~, d 3J92I99',' T~DII II I I I I' ¡ I' ¡Start .ru~p range t Iii : I I I 'I I : i ' ~a1 DI'411 '. 6ûrl.b2' M, D.397$.5¡rvp I I II I I' I I ' I End ~mp arige., I ' I II 'I I Iii I' i i I' i j ',: Ii, I i I I 'I i I I Ii ,! I II ' ~nd Dif : þl~6'0l'lolQ. 4p,14.0,· D I ! ta~ Qi'11100· ¡ 6231,061 Mb. Oj5 ~'T'I'Di IEJ! q" . 6¡5/j.0~ ^'\D, 4 2.~5' rVp I ¡ I I I I I I' I I , I f'ak D" $/IÓO¡ 6488t158 Mp.4085J6·1JVQ I I I I n I : : I E~db"l ~79 8· DI4\01!12.ITYDJ' I I I I ' I ',I I JtJ oi;'~lIdo· 71ß91'~ 4ð2817 II I I I; I I Ehd b,rl. 1888«' D 4q2134 TVD ' i I II I Iii II IlsJrt¿,,111 ':8j6It4Jr.JD.¡4000t, I I ¡I I i I I I E4d "I i33.6~. /.D. 3992. I J ,I I I 1+ ! 1 I 1,111 ' m I 'I Ii III j ! I 11.,1 I I 'I! I II I 1 I II i I [ [,[ ¡ "t TARGET DETAILS +E/-W +N/-S TVD Name Targe MPH-16 TI MPH-16 T3 MPH-16 T4 MPH-16 T5 MPH-16 T6 - Size 10.750 7.625 4.500 FORMAj]ON'"r<Jp DETAILS No. TVDPath MDPath Fonnation I 1820.50 1893.63 BPRF 2 3447.50 4779.68 TUZC 3 3666.50 5225.53 Ugnu-MA 4 3677.50 5249.38 Ugnu-MBI e 5 3632.50 5153.01 Ugnu-MB2 6 3844.50 5646.22 Ugnu-MC 7 3874.50 5728.04 SBF2-NA 8 3907.50 5823.43 SBFI-NB 9 3934.50 5902.37 SBE4-NC 10 3953.50 5957.93 SBE2-NE II 3998.50 6093.23 SBEI-NF 12 4030.50 6211.75 TSBD-Top OA 13 4052.50 6303.63 TSBC-Base OA 14 4080.50 6459.45 TSBB-Top OB 15 4100.50 6606.48 SBA5-Base OB "' ~ 6400 7200 VSec 0.00 0.00 -4.32 -7.22 0.72 2.57 266.24 926.72 2256.54 2474.91 2585.70 2653.12 2766.57 2887.91 3144.14 3891.12 3923.92 3967.12 4186.50 4421.08 4518.78 4846.43 5002.10 5290.00 5639.21 CASING DETAILS MD Name 4240.25 103/4" 6488.80 7 518" 9931.00 4 1/2" . ,r --1 :-¡Mj>H1T wPot·, 1 :¡-,: j _.~ :;tr-" -T, ~h, - :;~;;~~¡. ,~,., i-+ . tPett '" :-. ;,j93t: ;:M-- ~;:;¡~ j ¡;; '" 1) '. It, 'fl88f-:¡ q",t~, :~7"J U "'T¡- --r-h-,., 5600 TFaee 0.00 0.00 0.00 314.03 0.00 0.00 -57.42 0.00 -100.78 0.00 0.56 0.00 0.00 0.00 -55.21 0.00 85.03 90.09 0.00 101.19 103.42 0.00 -81.89 -89.19 0.00 = DLeg 0.00 0.00 2.00 3.00 3.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 8.00 0.00 4.00 4.00 0.00 8.00 8.00 0.00 8.00 8.00 0.00 +E/-W No. TVD I 3170.50 2 4085.60 3 4000.51 0.00 0.00 0.00 7.17 124.63 152.00 -630.63 -1578.50 -2928.88 -3095.00 -3179.30 -3230.61 -3316.96 -3409.31 -3582.17 -4007.06 -4026.06 -4052.08 -4186.92 -4354.84 -4435.77 -4716.37 -4842.46 -5023.73 -5176.82 +N/-S 0.00 0.00 10.90 34.80 286.68 345.39 788.47 1317.16 1089.82 923.70 839.48 788.26 702.05 609.87 363.89 -536.14 -574.87 -623.57 -864.63 -1067.44 -1126.45 -1303.12 -1403.78 -1710.14 -2236.34 ! V~ 3·r~D ~- i ! TVD 34.30 600.80 850.48 1044.09 1750.80 1850.80 2493.23 3104.26 3892.99 3978.50 4016.07 4035.50 4062.55 4085.56 4101.12 4028.70 4025.50 4021.34 4000.56 3990.50 3992.13 4002.87 4005.50 4004.24 4000.50 ~ 1+ ¡ f- Azi 0.00 0.00 0.00 335.00 335.00 335.00 299.15 299.15 225.00 225.00 225.05 225.05 225.05 225.05 205.27 205.27 207.00 209.22 209.22 230.00 237.80 237.80 225.00 196.22 196.22 ~ 4800 " "" t ~o 4000 [800Mn] 1 2400 3200 Vertical Section at 246.640 MPH-16 Fault 2642.50 1407.66 -772.60 MPH-16 Fault 2 3686.50 1884.43 -2708.22 MPH-16 Fault 5 3957.50 -7.25 -5283.91 MPH-16 Fault 6 3979.50 -1852.15 -4668.84 MPH-16 T4 3990.50 -1067.44 -4354.84 MPH-16 Fault 4 3996.50 -911.17 -5045.74 MPH-16 T6 4000.50 -2236.34 -5176.82 MPH-16 T5 4005.50 -1403.78 -4842.46 MPH-16 T3 4025.50 -574.87 -4026.06 MPH-16 Fault 3 4034.50 1254.94 -3445.09 MPH-16 TI 4035.50 788.26 -3230.61 MPH-16 Geo Poly 4035.50 787.94 -3230.90 MPH-16 T2 4085.50 609.94 -3409.30 I ! I .1¡V1) , , ! i ¡' ! i ji I i Ii S(aniDif 3/!IOQ· . ~50f8rV¡D ! I ¡ i i i! ! : : i ': ' 1 i50!8' tv6 i : ¡ i ;' i i i I j . 7S· MŒ 185(!8·TVÓ i ; ~ , r ' i: i ii I I I' I I I I 1 ¡! ! i ! ¡ r . 2861.5 'MD.:2493þ' ,frVD ! ! i i I ¡ ! I 600 I 800 100· 200, - I !iF l o - I !r - - 80 240v- - - 60 - - 320 I 400 c ;f o ~ .c Q. è) " u £: ~ 2 f- COMPANY DETAILS 01 BP Amoco C.alcularioo Melhod: Minimum Curvature Error System: ISCWSA Scan Method: Tr~v Cylinder ~urth Eryur Suñace: Elhphcal" Casmg - Warrull2Method: Rules Based FORMATION TOP DETAILS No. TVDPath MDPath Formation I 1820.50 1893.63 BPRF 2 3447.50 4779.68 TUZC 3 3666.50 5225.53 Ugnu-MA 4 3677.50 5249.38 Ugnu-MBI 5 3632.50 5153.01 Ugnu-MB2 6 3844.50 5646.22 Ugnu-MC 7 3874.50 5728.04 SBF2-NA 8 3907.50 5823.43 SBFI-NB 9 3934.50 5902.37 SBE4-NC 10 3953.50 5957.93 SBE2-NE II 3998.50 6093.23 SBEI-NF 12 4030.50 6211.75 TSBD- Top OA 13 4052.50 6303.63 TSBC-Base OA 14 4080.50 6459.45 TSBB-Top OB 15 4 100.50 6606.48 SBA5-Base OB SURVEY PROGRAM Plan: MPH-J6 WP06 (Plan Neo (MPH-16 )/MPH.16: Deplh Fm Depth To SIII'VeyIPIan Tool Created By: Troy Jakabosky Dale: 8/11/2004 34.30 1200.110 Planned: MPH-16 WPQ6 V65 CB..QYRO_SS WELL DETAILS 1200.: 9931.92 Planned: MPH-16 WPQ6 V65 MWD+fFR+MS ~ "N/-S +fj-W Northing Eurin. Latilude Lonaitude " Neo (MPH_Ir> \ 1139.36 1244.90 60101203 556641 70"26'17.870N 149<'32'17J56W Ni. True North INFORM.>\ TlON MPH- 'CE Well Centre: Plan Neo 34.3+36.270.50 Slot - (O.CION,O.OOE) 34.3+36.2 70.50 MinimumCurvarure CO<Irdinate (N/E) Reference: Vertical (TVD) Reference: Section (VS) Reference: Measu~~~~~~C::t SECTION DETAILS +N/-S +E/-W DLeg TFaee VSec Targe 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 10.90 0.00 2.00 0.00 -4.32 34.80 -7.!7 3.00 314.Q3 -7.22 286.68 -124.63 3.00 0.00 0.72 345.39 -152.00 0.00 0.00 2.57 788.47 -630.63 4.00 -57.42 266.24 1317.16 - I 578.50 0.00 0.00 926.72 1089.82 -2928.88 4.00 -100.78 2256.54 923.70 -3095.00 0.00 0.00 2474.91 839.48 -3179.30 4.00 0.56 2585.70 788.26 -3230.61 0.00 0.00 2653.12 MPH-16 Tl 702.05 -3316.96 4.00 0.00 2766.57 609.87 -3409.31 0.00 0.00 2887.91 363.89 -3582.17 8.00 -55.21 3144.14 -536.14 -4007.06 0.00 0.00 3891.12 -574.87 -4026.06 4.00 85.Q3 3923.92 MPH-16 T3 -623.57 -4052.08 4.00 90.09 3967.12 -864.63 -4186.92 0.00 0.00 4186.50 -1067.44 -4354.84 8.00 101.19 4421.08 MPH-16 T4 -1126.45 -4435.77 8.00 103.42 4518.78 -1303.12 -4716.37 0.00 0.00 4846.43 -1403.78 -4842.46 8.00 -81.89 5002.10 MPH-16 T5 -1710.14 -5023.73 8.00 -89.19 5290.00 -2236.34 -5176.82 0.00 0.00 5639.21 MPH-16 T6 .~ - CASING DETAILS No. TVD MD Name Size I 3170.50 4240.25 103/4·' 10.750 2 4085.60 6488.80 75/8·' 7.625 3 4000.51 9931.00 4 1/2" 4.500 I 34.30 0.00 0.00 34.30 2 600.80 0.00 0.00 600.80 3 850.80 5.00 0.00 850.48 4 1046.09 10.00 335.00 1044.09 5 1810.58 32.93 335.00 1750.80 6 1929.73 32.93 335.00 1850.80 7 2861.56 60.62 299.15 2493.23 8 4107.08 60.62 299.15 3104.26 9 5781.02 70.00 225.00 3892.99 10 6031.02 70.00 225.00 3978.50 II 6156.01 75.00 225.05 4016.07 12 6231.06 75.00 225.05 4035.50 13 6356.08 80.00 225.05 4062.55 14 6488.58 80.00 225.05 4085.56 I ' " 15 6791.88 94.16 205.27 4101.12 I I I I I 16 7789.80 94.16 205.27 4028.70 ' I ' I I 17 7833.06 94.31 207.00 4025.50 i I I I I I 18 7888.44 94.30 209.22 4021.34 I I I I I I 19 8165.43 94.30 209.22 4000.56 I I I I I 20 8430.43 90.00 230.00 3990.50 ' 'ngedt 11' 21 8530.69 88.14 237.80 3992.13 L , , 22 8862.45 88.14 237.80 4002.87 I :- stait, Qir ¡j0(H,,60ß LQ2! ¡.jDj397 SrVDI I', I I ',', i 'I' 23 9024.15 90.00 225.00 4005.50 i ! : Sia, pJmp Tange¿t i i I I I I ¡ I I I ' i 24 9383.90 90.39 196.22 4004.24 ' I ~I I, IE 'd D'·j ¡'7hl i ¡ MD 8' j ,¡.¡, , , . 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II ~I(" 3 1.92' Mþ_ , : i ' 1-: -j TVD Azi Ine MD Sec TARGET DETAILS TVD +N/-S +E/-W Northing Easting Shape 2642.50 1407.66 -772.60 6011522.00 555858.00 Polygon 3686.50 1884.43 -2708.22 6011984.00 553919.00 Polygon 3957.50 -7.25 -5283.91 6010073.00 551358.00 Polygon 3979.50 -1852.15 -4668.84 6008233.00 551987.00 Polygon 3990.50 -1067.44 -4354.84 6009020.00 552295.00 Point 3996.50 -911.17 -5045.74 6009171.00 551603.00 Polygon 4000.50 -2236.34 -5 t 76.82 6007845.00 551482.00 Point 4005.50 -1403.78 -4842.46 6008680.00 551810.00 Point 4025.50 -574.87 -4026.06 6009515.00 552620.00 Point 4034.50 t254.94 -3445.09 6011349.00 553187.00 Polygon 4035.50 788.26 -3230.61 6010884.00 553405.00 Point 4035.50 787.94 -3230.90 6010883.68 553404.71 Polygon 4085.50 609.94 -3409.30 6010704.35 553227.68 Point Name MPH-16 Fault I MPH-16 Fault 2 MPH-16 Fault 5 MPH-16 Fault 6 MPH-16 T4 MPH-16 Fault 4 MPH-16 T6 MPH-16 T5 MPH-16 TJ MPH-16 Faull 3 MPH-16 TI MPH·16 Geo Poly MPH-16 T2 . ;¿¿~ "I ,,~.~ I ~ '/~ -.../'1-11 " /' , .. ., ~-i f f- :E ::+=1: LI 2400 -1---,'--- 200 In o 200 200ft/in] West(-)/East(+) -2400 wI!> I: L' 400b.s', il I -3600 Iff '" ,--,- :.1, ·IITøtalDepth j9 j ! MJ,'HHwPQ61! i .j--!._L_L' 'J.; -4800 , i : IMP1 , I" rr ~þuLI~ i ,n¡ t?1--- ~. -I ~ - I - 240u- -240u- -6000 - 20u- 20' I c ¢? o o ~ ;- ~ 1: ~ ~ 15 o '" . . BP BP Planning Report Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 4 Well Centre bggm2004 Site: M pt H Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6008971.91 ft 555404.91 ft Latitude: 70 26 Longitude: 149 32 North Reference: Grid Convergence: 6.665 N 53.895 W True 0.43 deg Well: Plan Neo ( MPH-16 ) Slot Name: Well Position: +N/-S 1139.36 ft Northing: 6010120.38 ft Latitude: +E/-W 1244.90 ft Easting: 556641.19 ft Longitude: Position Uncertainty: 0.00 ft 70 26 17.870 N 149 32 17.356 W Casing Points 1893.63 1820.50 BPRF 0.00 0.00 4779.68 3447.50 . TUZC 0.00 0.00 5225.53 3666.50 Ugnu-MA 0.00 0.00 5249.38 3677.50 Ugnu-MB1 0.00 0.00 5153.01 3632.50 Ugnu-MB2 0.00 0.00 5646.22 3844.50 Ugnu-MC 0.00 0.00 5728.04 3874.50 SBF2-NA 0.00 0.00 5823.43 3907.50 SBF1-NB 0.00 0.00 5902.37 3934.50 SBE4-NC 0.00 0.00 5957.93 3953.50 SBE2-NE 0.00 0.00 6093.23 3998.50 SBE1-NF 0.00 0.00 6211.75 4030.50 TSBD-Top OA 0.00 0.00 6303.63 4052.50 TSBC-Base OA 0.00 0.00 6459.45 4080.50 TSBB-Top OB 0.00 0.00 6606.48 4100.50 SBA5-Base OB 0.00 0.00 Targets MPH-16 Fault 1 2642.50 -772.60 6011522.00 555858.00 70 2631.713 N 149 32 40.037 W -Polygon 1 2642.50 -772.60 6011522.00 555858.00 70 2631.713 N 149 32 40.037 W -Polygon 2 2642.50 -858.36 6011027.00 555776.00 70 26 26.851 N 149 32 42.553 W -Polygon 3 2642.50 -1119.64 6010334.00 555520.00 70 26 20.054 N 149 32 50.220 W -Polygon 4 2642.50 -858.36 6011027.00 555776.00 70 26 26.851 N 149 32 42.553 W MPH-16 Fault 2 3686.50 1884.43 -2708.22 6011984.00 553919.00 70 26 36.398 N 149 33 36.865 W -Polygon 1 3686.50 1884.43 -2708.22 6011984.00 553919.00 70 26 36.398 N 149 33 36.865 W -Polygon 2 3686.50 1347.20 -2555.28 6011448.00 554076.00 70 2631.115 N 149 33 32.369 W -Polygon 3 3686.50 832.28 -2180.14 6010936.00 554455.00 70 26 26.052 N 149 33 21.352 W -- ----.-.-.---.---,-'.---- -..--,-.,..-----.. -- --..---.-----.-------- -- --..-'.---'.-'---',-------- ------...-------------,,-------,- --._-.-----_._---~--,- . BP BP Planning Report . -Polygon 4 MPH-16 Fault 5 -Polygon 1 -Polygon 2 MPH-16 Fault 6 -Polygon 1 -Polygon 2 MPH-16 T4 MPH-16 Fault 4 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 MPH-16 T6 MPH-16 T5 MPH-16 T3 MPH-16 Fault 3 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 MPH-16 T1 MPH-16 Geo Poly -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 -Polygon 10 MPH-16 T2 Plan Section Information 3686.50 3957.50 3957.50 3957.50 3979.50 3979.50 3979.50 3990.50 3996.50 3996.50 3996.50 3996.50 3996.50 1347.20 -2555.28 -7.25 -5283.91 -7.25 -5283.91 1088.10 -3731.39 -1852.15 -4668.84 -1852.15 -4668.84 -2968.50 -4904.35 -1067.44 -4354.84 -911.17 -5045.74 -911.17 -5045.74 -1223.64 -4594.06 -2085.76 -3802.51 -1223.64 -4594.06 6011448.00 554076.00 6010073.00 551358.00 6010073.00 551358.00 6011180.00 552902.00 6008233.00 551987.00 6008233.00 551987.00 6007115.00 551760.00 6009020.00 552295.00 6009171.00 551603.00 6009171.00 551603.00 6008862.00 552057.00 6008006.00 552855.00 6008862.00 552057.00 70 2631.115 N 70 26 17.780 N 70 26 17.780 N 70 26 28.562 N 70 25 59.640 N 70 25 59.640 N 70 25 48.659 N 70 26 7.359 N 70 26 8.892 N 70 26 8.892 N 70 26 5.821 N 70 25 57.347 N 70 26 5.821 N 149 33 32.369 W 149 34 52.443 W 149 34 52.443 W 149 34 6.892 W 149 34 34.357 W 149 34 34.357 W 149 34 41.246 W 149 34 25.156 W 149 34 45.435 W 149 34 45.435 W 149 34 32.174 W 149 34 8.932 W 149 3432.174 W 4000.50 -2236.34 -5176.82 6007845.00 551482.00 70 25 55.858 N 149 34 49.255 W 4005.50 -1403.78 -4842.46 6008680.00 551810.00 70 26 4.048 N 149 34 39.460 W 4025.50 -574.87 -4026.06 6009515.00 552620.00 70 26 12.205 N 149 34 15.515 W 4034.50 4034.50 4034.50 4034.50 4034.50 4035.50 4035.50 4035.50 4035.50 4035.50 4035.50 4035.50 4035.50 4035.50 4035.50 4035.50 4035.50 4085.50 1254.94 -3445.09 1254.94 -3445.09 931.04 -3068.50 497.60 -2622.74 931.04 -3068.50 6011349.00 553187.00 6011349.00 553187.00 6011028.00 553566.00 6010598.00 554015.00 6011028.00 553566.00 70 26 30.204 N 70 26 30.204 N 70 26 27.020 N 70 26 22.759 N 70 26 27.020 N 149 33 58.490 W 149 33 58.490 W 149 33 47.431 W 149 33 34.341 W 149 33 47.431 W 788.26 -3230.61 6010884.00 553405.00 70 2625.615 N 149 3352.187 W 787.94 956.36 1054.99 550.93 -698.42 -1315.79 -2469.03 -2472.75 -1586.19 -1075.22 866.21 -3230.90 -3110.02 -3322.79 -3718.17 -4350.54 -5102.62 -5485.03 -4995.70 -4659.72 -3988.56 -2959.48 6010883.68 553404.71 6011053.00 553524.30 6011150.00 553310.80 6010643.00 552919.30 6009389.00 552296.50 6008766.00 551549.20 6007610.00 551175.60 6007610.00 551664.90 6008499.00 551994.10 6009015.00 552661.30 6010964.00 553675.50 70 26 25.612 N 70 26 27.269 N 70 26 28.238 N 70 26 23.279 N 70 26 10.988 N 70 26 4.912 N 70 25 53.567 N 70 25 53.534 N 70 26 2.255 N 70 26 7.284 N 70 26 26.383 N 149 3352.196 W 149 33 48.650 W 149 33 54.897 W 149 34 6.496 W 149 34 25.036 W 149 34 47.096 W 149 34 58.293 W 149 34 43.935 W 149 34 34.094 W 149 34 14.407 W 149 33 44.230 W 609.94 -3409.30 6010704.35 553227.68 70 26 23.861 N 149 33 57.430 W 0.00 0.00 10.90 34.80 286.68 345.39 788.47 1317.16 1089.82 923.70 839.48 788.26 0.00 0.00 0.00 -7.17 -124.63 -152.00 -630.63 -1578.50 -2928.88 -3095.00 -3179.30 -3230.61 34.30 600.80 850.80 1046.09 1810.58 1929.73 2861.56 4107.08 5781.02 6031.02 6156.01 6231.06 0.00 0.00 5.00 10.00 32.93 32.93 60.62 60.62 70.00 70.00 75.00 75.00 0.00 0.00 0.00 335.00 335.00 335.00 299.15 299.15 225.00 225.00 225.05 225.05 34.30 600.80 850.48 1044.09 1750.80 1850.80 2493.23 3104.26 3892.99 3978.50 4016.07 4035.50 0.00 0.00 2.00 3.00 3.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 0.00 0.00 2.00 2.56 3.00 0.00 2.97 0.00 0.56 0.00 4.00 0.00 0.00 0.00 0.00 -12.80 0.00 0.00 -3.85 0.00 -4.43 0.00 0.04 0.00 0.00 0.00 0.00 314.03 0.00 0.00 -57.42 0.00 -100.78 0.00 0.56 0.00 MPH-16 T1 _._._.__~___,.__. ____ ____.__ ______.,___ ____ _'___.'_n._____ _________,_.__,.._,.___,___..__,__ __' __.___,._______.____ .___m_____'.____,._'. ___ -- -_._._-_.~----~-.~---- ---_.__._-~---- . . BP BP Planning Report 6356.08 80.00 225.05 4062.55 702.05 -3316.96 4.00 4.00 0.00 0.00 6488.58 80.00 225.05 4085.56 609.87 -3409.31 0.00 0.00 0.00 0.00 6791.88 94.16 205.27 4101.12 363.89 -3582.17 8.00 4.67 -6.52 -55.21 7789.80 94.16 205.27 4028.70 -536.14 -4007.06 0.00 0.00 0.00 0.00 7833.06 94.31 207.00 4025.50 -574.87 -4026.06 4.00 0.34 4.00 85.03 MPH-16 T3 7888.44 94.30 209.22 4021.34 -623.57 -4052.08 4.00 -0.01 4.01 90.09 8165.43 94.30 209.22 4000.56 -864.63 -4186.92 0.00 0.00 0.00 0.00 8430.43 90.00 230.00 3990.50 -1067.44 -4354.84 8.00 -1.62 7.84 101.19 MPH-16 T4 8530.69 88.14 237.80 3992.13 -1126.45 -4435.77 8.00 -1.85 7.78 103.42 8862.45 88.14 237.80 4002.87 -1303.12 -4716.37 0.00 0.00 0.00 0.00 9024.15 90.00 225.00 4005.50 -1403.78 -4842.46 8.00 1.15 -7.92 -81.89 MPH-16 T5 9383.90 90.39 196.22 4004.24 -1710.14 -5023.73 8.00 0.11 -8.00 -89.19 9931.92 90.39 196.22 4000.50 -2236.34 -5176.82 0.00 0.00 0.00 0.00 MPH-16 T6 Survey 34.30 0.00 0.00 34.30 -36.20 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 50.00 0.00 0.00 50.00 -20.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO·SS 75.00 0.00 0.00 75.00 4.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 100.00 0.00 0.00 100.00 29.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO·SS 125.00 0.00 0.00 125.00 54.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 150.00 0.00 0.00 150.00 79.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 175.00 0.00 0.00 175.00 104.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 200.00 0.00 0.00 200.00 129.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 225.00 0.00 0.00 225.00 154.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO·SS 250.00 0.00 0.00 250.00 179.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO·SS 275.00 0.00 0.00 275.00 204.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 300.00 0.00 0.00 300.00 229.50 0.00 0.00 0.00 6010120.38 556641.19 CB·GYRO-SS 325.00 0.00 0.00 325.00 254.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 350.00 0.00 0.00 350.00 279.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 375.00 0.00 0.00 375.00 304.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 400.00 0.00 0.00 400.00 329.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 425.00 0.00 0.00 425.00 354.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 450.00 0.00 0.00 450.00 379.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 475.00 0.00 0.00 475.00 404.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 500.00 0.00 0.00 500.00 429.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 525.00 0.00 0.00 525.00 454.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 550.00 0.00 0.00 550.00 479.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 575.00 0.00 0.00 575.00 504.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 600.00 0.00 0.00 600.00 529.50 0.00 0.00 0.00 6010120.38 556641.19 CB-GYRO-SS 600.80 0.00 0.00 600.80 530.30 0.00 0.00 0.00 6010120.38 556641.19 Start Dir 2/100 625.00 0.48 0.00 625.00 554.50 0.10 0.00 2.00 6010120.48 556641.19 CB-GYRO-SS 650.00 0.98 0.00 650.00 579.50 0.42 0.00 2.00 6010120.80 556641.19 CB-GYRO-SS 675.00 1.48 0.00 674.99 604.49 0.96 0.00 2.00 6010121.34 556641.18 CB-GYRO-SS 700.00 1.98 0.00 699.98 629.48 1.72 0.00 2.00 6010122.10 556641.18 CB-GYRO-SS 725.00 2.48 0.00 724.96 654.46 2.69 0.00 2.00 6010123.07 556641.17 CB-GYRO-SS 750.00 2.98 0.00 749.93 679.43 3.88 0.00 2.00 6010124.26 556641.16 CB-GYRO-SS 775.00 3.48 0.00 774.89 704.39 5.29 0.00 2.00 6010125.67 556641.15 CB-GYRO-SS 800.00 3.98 0.00 799.84 729.34 6.92 0.00 2.00 6010127.30 556641.14 CB-GYRO-SS 825.00 4.48 0.00 824.77 754.27 8.77 0.00 2.00 6010129.15 556641.12 CB-GYRO-SS 850.00 4.98 0.00 849.69 779.19 10.83 0.00 2.00 6010131.21 556641.11 CB-GYRO-SS 850.80 5.00 0.00 850.48 779.98 10.90 0.00 2.00 6010131.28 556641.11 Start Dir 3/100 875.00 5.53 354.57 874.58 804.08 13.12 -0.11 3.00 6010133.49 556640.98 CB-GYRO-SS 900.00 6.12 349.99 899.45 828.95 15.63 -0.46 3.00 6010136.00 556640.62 CB·GYRO-SS . . BP BP Planning Report 925.00 6.74 346.23 924.29 853.79 18.36 -1.04 3.00 6010138.73 556640.01 CB-GYRO·SS 950.00 7.38 343.12 949.10 878.60 21.33 -1.85 3.00 6010141.69 556639.18 CB-GYRO·SS 975.00 8.05 340.50 973.88 903.38 24.51 -2.90 3.00 6010144.87 556638.10 CB-GYRO·SS 1000.00 8.72 338.29 998.61 928.11 27.93 -4.19 3.00 6010148.27 556636.79 CB-GYRO·SS 1025.00 9.41 336.40 1023.30 952.80 31.56 -5.71 3.00 6010151.89 556635.24 CB-GYRO·SS 1046.09 10.00 335.00 1044.09 973.59 34.80 -7.17 3.00 6010155.12 556633.75 CB·GYRO-SS 1050.00 10.12 335.00 1047.94 977.44 35.42 -7.46 3.00 6010155.74 556633.46 CB-GYRO-SS 1075.00 10.87 335.00 1072.52 1002.02 39.54 -9.38 3.00 6010159.85 556631.51 CB-GYRO-SS 1100.00 11.62 335.00 1097.04 1026.54 43.96 -11.44 3.00 6010164.25 556629.41 CB-GYRO-SS 1125.00 12.37 335.00 1121.49 1050.99 48.67 -13.64 3.00 6010168.94 556627.18 CB·GYRO-SS 1150.00 13.12 335.00 1145.88 1075.38 53.67 -15.97 3.00 6010173.92 556624.81 CB·GYRO-SS 1175.00 13.87 335.00 1170.19 1099.69 58.95 -18.44 3.00 6010179.19 556622.31 CB·GYRO-SS 1200.00 14.62 335.00 1194.42 1123.92 64.53 -21.03 3.00 6010184.74 556619.67 CB·GYRO-SS 1225.00 15.37 335.00 1218.57 1148.07 70.39 -23.77 3.00 6010190.58 556616.89 MWD+IFR+MS 1250.00 16.12 335.00 1242.63 1172.13 76.54 -26.63 3.00 6010196.70 556613.98 MWD+IFR+MS 1275.00 16.87 335.00 1266.60 1196.10 82.97 -29.63 3.00 6010203.11 556610.93 MWD+IFR+MS 1300.00 17.62 335.00 1290.48 1219.98 89.68 -32.77 3.00 6010209.80 556607.75 MWD+IFR+MS 1325.00 18.37 335.00 1314.25 1243.75 96.68 -36.03 3.00 6010216.78 556604.43 MWD+IFR+MS 1350.00 19.12 335.00 1337.93 1267.43 103.96 -39.42 3.00 6010224.03 556600.98 MWD+IFR+MS 1375.00 19.87 335.00 1361.49 1290.99 111.52 -42.95 3.00 6010231.56 556597.40 MWD+IFR+MS 1400.00 20.62 335.00 1384.95 1314.45 119.36 -46.60 3.00 6010239.37 556593.68 MWD+IFR+MS 1425.00 21.37 335.00 1408.29 1337.79 127.48 -50.39 3.00 6010247.46 556589.84 MWD+IFR+MS 1450.00 22.12 335.00 1431.51 1361.01 135.87 -54.30 3.00 6010255.82 556585.86 MWD+IFR+MS 1475.00 22.87 335.00 1454.61 1384.11 144.54 -58.35 3.00 6010264.46 556581.75 MWD+IFR+MS 1500.00 23.62 335.00 1477.58 1407.08 153.48 -62.51 3.00 6010273.37 556577.52 MWD+IFR+MS 1525.00 24.37 335.00 1500.42 1429.92 162.70 -66.81 3.00 6010282.55 556573.15 MWD+IFR+MS 1550.00 25.12 335.00 1523.13 1452.63 172.18 -71.23 3.00 6010292.00 556568.66 MWD+IFR+MS 1575.00 25.87 335.00 1545.69 1475.19 181.93 -75.78 3.00 6010301.71 556564.04 MWD+IFR+MS 1600.00 26.62 335.00 1568.12 1497.62 191.95 -80.45 3.00 6010311.69 556559.29 MWD+IFR+MS 1625.00 27.37 335.00 1590.39 1519.89 202.23 -85.25 3.00 6010321.94 556554.42 MWD+IFR+MS 1650.00 28.12 335.00 1612.52 1542.02 212.78 -90.17 3.00 6010332.45 556549.42 MWD+IFR+MS 1675.00 28.87 335.00 1634.49 1563.99 223.59 -95.21 3.00 6010343.22 556544.30 MWD+IFR+MS 1700.00 29.62 335.00 1656.30 1585.80 234.66 -100.37 3.00 6010354.24 556539.05 MWD+IFR+MS 1725.00 30.37 335.00 1677.96 1607.46 245.98 -105.65 3.00 6010365.53 556533.69 MWD+IFR+MS 1750.00 31.12 335.00 1699.44 1628.94 257.56 -111.05 3.00 6010377.07 556528.20 MWD+IFR+MS 1775.00 31.87 335.00 1720.76 1650.26 269.40 -116.57 3.00 6010388.86 556522.59 MWD+IFR+MS 1800.00 32.62 335.00 1741.90 1671.40 281.49 -122.20 3.00 6010400.90 556516.86 MWD+IFR+MS 1810.58 32.93 335.00 1750.80 1680.30 286.68 -124.63 3.00 6010406.08 556514.40 End Dir : 1810 1825.00 32.93 335.00 1762.90 1692.40 293.78 -127.94 0.00 6010413.16 556511.04 MWD+IFR+MS 1850.00 32.93 335.00 1783.89 1713.39 306.10 -133.68 0.00 6010425.43 556505.20 MWD+IFR+MS 1875.00 32.93 335.00 1804.87 1734.37 318.42 -139.43 0.00 6010437.70 556499.36 MWD+IFR+MS 1893.63 32.93 335.00 1820.50 1750.00 327.60 -143.71 0.00 6010446.85 556495.01 BPRF 1900.00 32.93 335.00 1825.85 1755.35 330.74 -145.17 0.00 6010449.98 556493.53 MWD+IFR+MS 1925.00 32.93 335.00 1846.83 1776.33 343.06 -150.92 0.00 6010462.25 556487.69 MWD+IFR+MS 1929.73 32.93 335.00 1850.80 1780.30 345.39 -152.00 0.00 6010464.57 556486.58 Start Dir 4/100 1950.00 33.38 333.76 1867.77 1797.27 355.38 -156.80 4.00 6010474.53 556481.71 MWD+IFR+MS 1975.00 33.94 332.27 1888.58 1818.08 367.73 -163.09 4.00 6010486.83 556475.33 MWD+IFR+MS 2000.00 34.52 330.82 1909.25 1838.75 380.09 -169.79 4.00 6010499.14 556468.54 MWD+IFR+MS 2025.00 35.12 329.41 1929.78 1859.28 392.47 -176.90 4.00 6010511.45 556461.33 MWD+IFR+MS 2050.00 35.73 328.05 1950.15 1879.65 404.85 -184.42 4.00 6010523.78 556453.72 MWD+IFR+MS 2075.00 36.36 326.73 1970.36 1899.86 417.24 -192.35 4.00 6010536.11 556445.69 MWD+IFR+MS 2100.00 37.00 325.44 1990.41 1919.91 429.63 -200.68 4.00 6010548.43 556437.27 MWD+IFR+MS . . BP BP Planning Report 2125.00 37.65 324.19 2010.29 1939.79 442.02 -209.42 4.00 6010560.75 556428.44 MWD+IFR+MS 2150.00 38.32 322.99 2030.00 1959.50 454.40 -218.55 4.00 6010573.07 556419.21 MWD+IFR+MS 2175.00 39.00 321.81 2049.52 1979.02 466.77 -228.08 4.00 6010585.36 556409.59 MWD+IFR+MS 2200.00 39.69 320.67 2068.85 1998.35 479.13 -238.01 4.00 6010597.65 556399.58 MWD+IFR+MS 2225.00 40.39 319.56 2087.99 2017.49 491.47 -248.32 4.00 6010609.91 556389.17 MWD+IFR+MS 2250.00 41.11 318.49 2106.93 2036.43 503.79 -259.02 4.00 6010622.14 556378.38 MWD+IFR+MS 2275.00 41.83 317.44 2125.66 2055.16 516.09 -270.11 4.00 6010634.35 556367.20 MWD+IFR+MS 2300.00 42.56 316.43 2144.18 2073.68 528.36 -281.57 4.00 6010646.53 556355.64 MWD+IFR+MS 2325.00 43.30 315.44 2162.49 2091.99 540.59 -293.41 4.00 6010658.67 556343.71 MWD+IFR+MS 2350.00 44.05 314.48 2180.57 2110.07 552.79 -305.63 4.00 6010670.78 556331.40 MWD+IFR+MS 2375.00 44.80 313.55 2198.43 2127.93 564.95 -318.22 4.00 6010682.84 556318.72 MWD+IFR+MS 2400.00 45.57 312.63 2216.05 2145.55 577.06 -331.17 4.00 6010694.85 556305.68 MWD+IFR+MS 2425.00 46.34 311.75 2233.43 2162.93 589.13 -344.48 4.00 6010706.82 556292.28 MWD+IFR+MS 2450.00 47.12 310.88 2250.56 2180.06 601.14 -358.15 4.00 6010718.73 556278.52 MWD+IFR+MS 2475.00 47.90 310.04 2267.45 2196.95 613.11 -372.18 4.00 6010730.58 556264.40 MWD+IFR+MS 2500.00 48.69 309.22 2284.08 2213.58 625.01 -386.55 4.00 6010742.38 556249.94 MWD+IFR+MS 2525.00 49.48 308.42 2300.46 2229.96 636.85 -401.27 4.00 6010754.10 556235.13 MWD+IFR+MS 2550.00 50.28 307.63 2316.57 2246.07 648.63 -416.33 4.00 6010765.76 556219.98 MWD+IFR+MS 2575.00 51.09 306.87 2332.41 2261.91 660.33 -431.73 4.00 6010777.35 556204.50 MWD+IFR+MS 2600.00 51.90 306.12 2347.97 2277.47 671.97 -447.46 4.00 6010788.87 556188.68 MWD+IFR+MS 2625.00 52.72 305.39 2363.25 2292.75 683.53 -463.51 4.00 6010800.30 556172.54 MWD+IFR+MS 2650.00 53.54 304.67 2378.26 2307.76 695.01 -479.89 4.00 6010811.65 556156.08 MWD+IFR+MS 2675.00 54.36 303.97 2392.97 2322.47 706.40 -496.58 4.00 6010822.92 556139.31 MWD+IFR+MS 2700.00 55.19 303.28 2407.39 2336.89 717.71 -513.59 4.00 6010834.10 556122.22 MWD+IFR+MS 2725.00 56.02 302.61 2421.51 2351.01 728.93 -530.90 4.00 6010845.19 556104.82 MWD+IFR+MS 2750.00 56.85 301.95 2435.33 2364.83 740.05 -548.51 4.00 6010856.18 556087.13 MWD+IFR+MS 2775.00 57.69 301.30 2448.85 2378.35 751.08 -566.42 4.00 6010867.07 556069.14 MWD+IFR+MS 2800.00 58.54 300.67 2462.05 2391.55 762.01 -584.61 4.00 6010877.86 556050.86 MWD+IFR+MS 2825.00 59.38 300.04 2474.95 2404.45 772.84 -603.10 4.00 6010888.54 556032.30 MWD+IFR+MS 2850.00 60.23 299.43 2487.52 2417.02 783.55 -621.86 4.00 6010899.11 556013.46 MWD+IFR+MS 2861.56 60.62 299.15 2493.23 2422.73 788.47 -630.63 4.00 6010903.96 556004.65 End Dir : 2861 2875.00 60.62 299.15 2499.82 2429.32 794.18 -640.86 0.00 6010909.59 555994.38 MWD+IFR+MS 2900.00 60.62 299.15 2512.08 2441.58 804.79 -659.88 0.00 6010920.06 555975.28 MWD+IFR+MS 2925.00 60.62 299.15 2524.35 2453.85 815.40 -678.91 0.00 6010930.52 555956.18 MWD+IFR+MS 2950.00 60.62 299.15 2536.61 2466.11 826.01 -697.93 0.00 6010940.99 555937.07 MWD+IFR+MS 2975.00 60.62 299.15 2548.88 2478.38 836.62 -716.96 0.00 6010951.45 555917.97 MWD+IFR+MS 3000.00 60.62 299.15 2561.14 2490.64 847.24 -735.98 0.00 6010961.92 555898.86 MWD+IFR+MS 3025.00 60.62 299.15 2573.41 2502.91 857.85 -755.01 0.00 6010972.39 555879.76 MWD+IFR+MS 3050.00 60.62 299.15 2585.67 2515.17 868.46 -774.03 0.00 6010982.85 555860.66 MWD+IFR+MS 3075.00 60.62 299.15 2597.94 2527.44 879.07 -793.06 0.00 6010993.32 555841.55 MWD+IFR+MS 3100.00 60.62 299.15 2610.20 2539.70 889.68 -812.09 0.00 6011003.78 555822.45 MWD+IFR+MS 3125.00 60.62 299.15 2622.47 2551.97 900.29 -831.11 0.00 6011014.25 555803.35 MWD+IFR+MS 3150.00 60.62 299.15 2634.73 2564.23 910.91 -850.14 0.00 6011024.72 555784.24 MWD+/FR+MS 3165.84 60.62 299.15 2642.50 2572.00 917.63 -862.19 0.00 6011031.35 555772.14 MPH-16 Fault 1 3175.00 60.62 299.15 2646.99 2576.49 921.52 -869.16 0.00 6011035.18 555765.14 MWD+IFR+MS 3200.00 60.62 299.15 2659.26 2588.76 932.13 -888.19 0.00 6011045.65 555746.03 MWD+IFR+MS 3225.00 60.62 299.15 2671.52 2601.02 942.74 -907.21 0.00 6011056.11 555726.93 MWD+IFR+MS 3250.00 60.62 299.15 2683.79 2613.29 953.35 -926.24 0.00 6011066.58 555707.83 MWD+IFR+MS 3275.00 60.62 299.15 2696.05 2625.55 963.97 -945.26 0.00 6011077.05 555688.72 MWD+IFR+MS 3300.00 60.62 299.15 2708.32 2637.82 974.58 -964.29 0.00 6011087.51 555669.62 MWD+IFR+MS 3325.00 60.62 299.15 2720.58 2650.08 985.19 -983.32 0.00 6011097.98 555650.52 MWD+IFR+MS 3350.00 60.62 299.15 2732.85 2662.35 995.80 -1002.34 0.00 6011108.44 555631.41 MWD+IFR+MS 3375.00 60.62 299.15 2745.11 2674.61 1006.41 -1021.37 0.00 6011118.91 555612.31 MWD+/FR+MS . . BP BP Planning Report 3400.00 60.62 299.15 2757.37 2686.87 1017.02 -1040.39 0.00 6011129.38 555593.20 MWD+IFR+MS 3425.00 60.62 299.15 2769.64 2699.14 1027.64 -1059.42 0.00 6011139.84 555574.10 MWD+IFR+MS 3450.00 60.62 299.15 2781.90 2711.40 1038.25 -1078.44 0.00 6011150.31 555555.00 MWD+IFR+MS 3475.00 60.62 299.15 2794.17 2723.67 1048.86 -1097.47 0.00 6011160.77 555535.89 MWD+IFR+MS 3500.00 60.62 299.15 2806.43 2735.93 1059.47 -1116.49 0.00 6011171.24 555516.79 MWD+IFR+MS 3525.00 60.62 299.15 2818.70 2748.20 1070.08 -1135.52 0.00 6011181.71 555497.69 MWD+IFR+MS 3550.00 60.62 299.15 2830.96 2760.46 1080.70 -1154.55 0.00 6011192.17 555478.58 MWD+IFR+MS 3575.00 60.62 299.15 2843.23 2772.73 1091.31 -1173.57 0.00 6011202.64 555459.48 MWD+IFR+MS 3600.00 60.62 299.15 2855.49 2784.99 1101.92 -1192.60 0.00 6011213.10 555440.37 MWD+IFR+MS 3625.00 60.62 299.15 2867.76 2797.26 1112.53 -1211.62 0.00 6011223.57 555421.27 MWD+IFR+MS 3650.00 60.62 299.15 2880.02 2809.52 1123.14 -1230.65 0.00 6011234.04 555402.17 MWD+IFR+MS 3675.00 60.62 299.15 2892.28 2821.78 1133.75 -1249.67 0.00 6011244.50 555383.06 MWD+IFR+MS 3700.00 60.62 299.15 2904.55 2834.05 1144.37 -1268.70 0.00 6011254.97 555363.96 MWD+IFR+MS 3725.00 60.62 299.15 2916.81 2846.31 1154.98 -1287.72 0.00 6011265.43 555344.86 MWD+IFR+MS 3750.00 60.62 299.15 2929.08 2858.58 1165.59 -1306.75 0.00 6011275.90 555325.75 MWD+IFR+MS 3775.00 60.62 299.15 2941.34 2870.84 1176.20 -1325.77 0.00 6011286.37 555306.65 MWD+IFR+MS 3800.00 60.62 299.15 2953.61 2883.11 1186.81 -1344.80 0.00 6011296.83 555287.54 MWD+IFR+MS 3825.00 60.62 299.15 2965.87 2895.37 1197.43 -1363.83 0.00 6011307.30 555268.44 MWD+IFR+MS 3850.00 60.62 299.15 2978.14 2907.64 1208.04 -1382.85 0.00 6011317.76 555249.34 MWD+IFR+MS 3875.00 60.62 299.15 2990.40 2919.90 1218.65 -1401.88 0.00 6011328.23 555230.23 MWD+IFR+MS 3900.00 60.62 299.15 3002.67 2932.17 1229.26 -1420.90 0.00 6011338.70 555211.13 MWD+IFR+MS 3925.00 60.62 299.15 3014.93 2944.43 1239.87 -1439.93 0.00 6011349.16 555192.03 MWD+IFR+MS 3950.00 60.62 299.15 3027.19 2956.69 1250.48 -1458.95 0.00 6011359.63 555172.92 MWD+IFR+MS 3975.00 60.62 299.15 3039.46 2968.96 1261.10 -1477.98 0.00 6011370.09 555153.82 MWD+IFR+MS 4000.00 60.62 299.15 3051.72 2981.22 1271.71 -1497.00 0.00 6011380.56 555134.71 MWD+IFR+MS 4025.00 60.62 299.15 3063.99 2993.49 1282.32 -1516.03 0.00 6011391.03 555115.61 MWD+IFR+MS 4050.00 60.62 299.15 3076.25 3005.75 1292.93 -1535.06 0.00 6011401.49 555096.51 MWD+IFR+MS 4075.00 60.62 299.15 3088.52 3018.02 1303.54 -1554.08 0.00 6011411.96 555077.40 MWD+IFR+MS 4100.00 60.62 299.15 3100.78 3030.28 1314.16 -1573.11 0.00 6011422.42 555058.30 MWD+IFR+MS 4107.08 60.62 299.15 3104.26 3033.76 1317.16 -1578.50 0.00 6011425.39 555052.89 Start Dir 4/100 4125.00 60.49 298.34 3113.06 3042.56 1324.67 -1592.18 4.00 6011432.79 555039.15 MWD+IFR+MS 4150.00 60.31 297.21 3125.41 3054.91 1334.80 -1611.41 4.00 6011442.77 555019.85 MWD+IFR+MS 4175.00 60.15 296.07 3137.83 3067.33 1344.53 -1630.81 4.00 6011452.35 555000.38 MWD+IFR+MS 4200.00 59.99 294.93 3150.30 3079.80 1353.86 -1650.36 4.00 6011461.53 554980.76 MWD+IFR+MS 4225.00 59.85 293.79 3162.83 3092.33 1362.78 -1670.07 4.00 6011470.31 554960.98 MWD+IFR+MS 4240.25 59.76 293.09 3170.50 3100.00 1368.02 -1682.16 4.00 6011475.46 554948.85 103/4" 4250.00 59.71 292.64 3175.41 3104.91 1371.30 -1689.92 4.00 6011478.67 554941.07 MWD+IFR+MS 4275.00 59.58 291.50 3188.05 3117.55 1379.40 -1709.91 4.00 6011486.62 554921.02 MWD+IFR+MS 4300.00 59.47 290.34 3200.73 3130.23 1387.09 -1730.03 4.00 6011494.16 554900.84 MWD+IFR+MS 4325.00 59.36 289.19 3213.45 3142.95 1394.37 -1750.29 4.00 6011501.28 554880.53 MWD+IFR+MS 4350.00 59.27 288.03 3226.21 3155.71 1401.23 -1770.66 4.00 6011507.99 554860.11 MWD+IFR+MS 4375.00 59.18 286.87 3239.00 3168.50 1407.67 -1791.15 4.00 6011514.27 554839.57 MWD+IFR+MS 4400.00 59.11 285.71 3251.82 3181.32 1413.69 -1811.75 4.00 6011520.14 554818.93 MWD+IFR+MS 4425.00 59.04 284.55 3264.67 3194.17 1419.29 -1832.45 4.00 6011525.57 554798.19 MWD+IFR+MS 4450.00 58.99 283.38 3277.54 3207.04 1424.46 -1853.25 4.00 6011530.59 554777.35 MWD+IFR+MS 4475.00 58.94 282.21 3290.43 3219.93 1429.21 -1874.14 4.00 6011535.17 554756.43 MWD+IFR+MS 4500.00 58.91 281.05 3303.34 3232.84 1433.52 -1895.11 4.00 6011539.33 554735.43 MWD+/FR+MS 4525.00 58.89 279.88 3316.25 3245.75 1437.41 -1916.16 4.00 6011543.06 554714.35 MWD+IFR+MS 4550.00 58.87 278.71 3329.17 3258.67 1440.87 -1937.28 4.00 6011546.35 554693.21 MWD+IFR+MS 4575.00 58.87 277.54 3342.09 3271.59 1443.89 -1958.47 4.00 6011549.22 554672.00 MWD+IFR+MS 4600.00 58.88 276.38 3355.02 3284.52 1446.49 -1979.71 4.00 6011551.65 554650.74 MWD+IFR+MS 4625.00 58.90 275.21 3367.93 3297.43 1448.65 -2001.01 4.00 6011553.65 554629.43 MWD+IFR+MS . . BP BP Planning Report 4650.00 58.93 274.04 3380.84 3310.34 1450.37 -2022.35 4.00 6011555.21 554608.08 MWD+IFR+MS 4675.00 58.97 272.87 3393.74 3323.24 1451.66 -2043.73 4.00 6011556.34 554586.70 MWD+/FR+MS 4700.00 59.02 271.71 3406.61 3336.11 1452.52 -2065.14 4.00 6011557.04 554565.28 MWD+IFR+MS 4725.00 59.08 270.55 3419.47 3348.97 1452.94 -2086.57 4.00 6011557.29 554543.84 MWD+IFR+MS 4750.00 59.15 269.38 3432.30 3361.80 1452.93 -2108.03 4.00 6011557.12 554522.39 MWD+IFR+MS 4775.00 59.24 268.22 3445.11 3374.61 1452.48 -2129.50 4.00 6011556.51 554500.93 MWD+IFR+MS 4779.68 59.25 268.01 3447.50 3377.00 1452.35 -2133.52 4.00 6011556.34 554496.91 TUZC 4800.00 59.33 267.07 3457.88 3387.38 1451.60 -2150.97 4.00 6011555.46 554479.47 MWD+IFR+MS 4825.00 59.43 265.91 3470.61 3400.11 1450.28 -2172.44 4.00 6011553.98 554458.01 MWD+IFR+MS 4850.00 59.54 264.76 3483.30 3412.80 1448.53 -2193.91 4.00 6011552.06 554436.56 MWD+/FR+MS 4875.00 59.67 263.61 3495.95 3425.45 1446.34 -2215.36 4.00 6011549.71 554415.12 MWD+IFR+MS 4900.00 59.80 262.46 3508.55 3438.05 1443.72 -2236.79 4.00 6011546.93 554393.71 MWD+IFR+MS 4925.00 59.94 261.31 3521.10 3450.60 1440.67 -2258.20 4.00 6011543.72 554372.33 MWD+IFR+MS 4950.00 60.10 260.17 3533.59 3463.09 1437.19 -2279.57 4.00 6011540.07 554350.99 MWD+/FR+MS 4975.00 60.26 259.04 3546.03 3475.53 1433.27 -2300.90 4.00 6011536.00 554329.69 MWD+IFR+MS 5000.00 60.43 257.90 3558.40 3487.90 1428.93 -2322.19 4.00 6011531.49 554308.44 MWD+IFR+MS 5025.00 60.61 256.77 3570.70 3500.20 1424.16 -2343.42 4.00 6011526.56 554287.24 MWD+/FR+MS 5050.00 60.80 255.65 3582.93 3512.43 1418.96 -2364.60 4.00 6011521.20 554266.11 MWD+/FR+MS 5075.00 61.01 254.53 3595.09 3524.59 1413.34 -2385.71 4.00 6011515.42 554245.05 MWD+IFR+MS 5100.00 61.22 253.41 3607.17 3536.67 1407.29 -2406.74 4.00 6011509.22 554224.06 MWD+IFR+MS 5125.00 61.43 252.30 3619.16 3548.66 1400.82 -2427.70 4.00 6011502.59 554203.15 MWD+/FR+MS 5150.00 61.66 251.19 3631.07 3560.57 1393.94 -2448.58 4.00 6011495.55 554182.33 MWD+IFR+MS 5153.01 61.69 251.06 3632.50 3562.00 1393.08 -2451.08 4.00 6011494.67 554179.84 Ugnu-MB2 5175.00 61.90 250.09 3642.89 3572.39 1386.64 -2469.36 4.00 6011488.09 554161.61 MWD+IFR+MS 5200.00 62.15 248.99 3654.62 3584.12 1378.92 -2490.04 4.00 6011480.21 554140.99 MWD+IFR+MS 5225.00 62.40 247.90 3666.25 3595.75 1370.79 -2510.62 4.00 6011471.93 554120.47 MWD+IFR+MS 5225.53 62.41 247.87 3666.50 3596.00 1370.61 -2511.06 4.00 6011471.75 554120.04 Ugnu·MA 5249.38 62.66 246.84 3677.50 3607.00 1362.46 -2530.59 4.00 6011463.45 554100.57 Ugnu-MB1 5250.00 62.66 246.81 3677. 79 3607.29 1362.25 -2531.09 4.00 6011463.23 554100.07 MWD+/FR+MS 5269.04 62.87 245.98 3686.50 3616.00 1355.47 -2546.61 4.00 6011456.34 554084.61 MPH-16 Fault 2 5275.00 62.93 245.73 3689.21 3618.71 1353.30 -2551.45 4.00 6011454.13 554079.78 MWD+/FR+MS 5300.00 63.21 244.65 3700.54 3630.04 1343.94 -2571.68 4.00 6011444.62 554059.62 MWD+IFR+MS 5325.00 63.50 243.58 3711.75 3641.25 1334.19 -2591.78 4.00 6011434.72 554039.60 MWD+IFR+MS 5350.00 63.80 242.51 3722.84 3652.34 1324.03 -2611.75 4.00 6011424.41 554019.71 MWD+IFR+MS 5375.00 64.10 241.45 3733.82 3663.32 1313.48 -2631.58 4.00 6011413.71 553999.96 MWD+IFR+MS 5400.00 64.41 240.40 3744.68 3674.18 1302.54 -2651.26 4.00 6011402.62 553980.37 MWD+IFR+MS 5425.00 64.73 239.35 3755.42 3684.92 1291.21 -2670.79 4.00 6011391.14 553960.93 MWD+IFR+MS 5450.00 65.06 238.30 3766.02 3695.52 1279.49 -2690.16 4.00 6011379.28 553941.65 MWD+IFR+MS 5475.00 65.39 237.27 3776.50 3706.00 1267.39 -2709.36 4.00 6011367.03 553922.54 MWD+IFR+MS 5500.00 65.73 236.23 3786.84 3716.34 1254.91 -2728.39 4.00 6011354.41 553903.61 MWD+IFR+MS 5525.00 66.08 235.21 3797.05 3726.55 1242.05 -2747.25 4.00 6011341.41 553884.85 MWD+IFR+MS 5550.00 66.43 234.18 3807.12 3736.62 1228.83 -2765.92 4.00 6011328.05 553866.28 MWD+IFR+MS 5575.00 66.79 233.17 3817.04 3746.54 1215.24 -2784 .41 4.00 6011314.32 553847.90 MWD+IFR+MS 5600.00 67.16 232.16 3826.82 3756.32 1201.28 -2802.70 4.00 6011300.22 553829.71 MWD+/FR+MS 5625.00 67.53 231.15 3836.45 3765.95 1186.97 -2820.80 4.00 6011285.78 553811.73 MWD+IFR+MS 5646.22 67.86 230.30 3844.50 3774.00 1174.54 -2835.99 4.00 6011273.24 553796.63 Ugriu-MC 5650.00 67.91 230.15 3845.92 3775.42 1172.30 -2838.69 4.00 6011270.97 553793.96 MWD+/FR+MS 5675.00 68.30 229.16 3855.25 3784.75 1157.28 -2856.37 4.00 6011255.82 553776.39 MWD+/FR+MS 5700.00 68.69 228.17 3864.41 3793.91 1141.92 -2873.83 4.00 6011240.33 553759.05 MWD+IFR+MS 5725.00 69.09 227.19 3873.41 3802.91 1126.22 -2891.07 4.00 6011224.50 553741.93 MWD+IFR+MS 5728.04 69.14 227.07 3874.50 3804.00 1124.28 -2893.16 4.00 6011222.55 553739.86 SBF2-NA 5750.00 69.49 226.21 3882.26 3811.76 1110.18 -2908.09 4.00 6011208.33 553725.03 MWD+IFR+MS 5775.00 69.90 225.23 3890.93 3820.43 1093.81 -2924.88 4.00 6011191.84 553708.37 MWD+IFR+MS . . BP BP Planning Report 5781.00 70.00 225.00 3892.99 3822.49 1089.83 -2928.87 4.00 6011187.83 553704.41 Start Pump Tang 5781.02 70.00 225.00 3892.99 3822.49 1089.82 -2928.88 4.00 6011187.81 553704.40 End Dir : 5781 5800.00 70.00 225.00 3899.49 3828.99 1077.21 -2941.49 0.00 6011175.11 553691.88 MWD+IFR+MS 5823.43 70.00 225.00 3907.50 3837.00 1061.64 -2957.06 0.00 6011159.42 553676.43 SBF1-NB 5825.00 70.00 225.00 3908.04 3837.54 1060.59 -2958.11 0.00 6011158.38 553675.40 MWD+IFR+MS 5850.00 70.00 225.00 3916.59 3846.09 1043.98 -2974.72 0.00 6011141.64 553658.92 MWD+IFR+MS 5875.00 70.00 225.00 3925.14 3854.64 1027.37 -2991.33 0.00 6011124.90 553642.43 MWD+/FR+MS 5900.00 70.00 225.00 3933.69 3863.19 1010.76 -3007.94 0.00 6011108.17 553625.95 MWD+IFR+MS 5902.37 70.00 225.00 3934.50 3864.00 1009.18 -3009.52 0.00 6011106.58 553624.38 SBE4-NC 5925.00 70.00 225.00 3942.24 3871.74 994.15 -3024.55 0.00 6011091.43 553609.47 MWD+IFR+MS 5950.00 70.00 225.00 3950.79 3880.29 977.54 -3041.16 0.00 6011074.70 553592.98 MWD+/FR+MS 5957.93 70.00 225.00 3953.50 3883.00 972.27 -3046.43 0.00 6011069.39 553587.76 SBE2-NE 5969.62 70.00 225.00 3957.50 3887.00 964.50 -3054.20 0.00 6011061.56 553580.05 MPH-16 Fault 5 5975.00 70.00 225.00 3959.34 3888.84 960.92 -3057.78 0.00 6011057.96 553576.50 MWD+/FR+MS 6000.00 70.00 225.00 3967.89 3897.39 944.31 -3074.39 0.00 6011041.23 553560.02 MWD+IFR+MS 6025.00 70.00 225.00 3976.44 3905.94 927.70 -3091.00 0.00 6011024.49 553543.53 MWD+IFR+MS 6031.00 70.00 225.00 3978.49 3907.99 923.71 -3094.99 0.00 6011020.47 553539.58 End Pump Tange 6031.02 70.00 225.00 3978.50 3908.00 923.70 -3095.00 0.00 6011020.46 553539.56 Start Dir 4/100 6033.95 70.12 225.00 3979.50 3909.00 921.75 -3096.95 4.00 6011018.49 553537.63 MPH-16 Fault 6 6050.00 70.76 225.01 3984.87 3914.37 911.06 -3107.64 4.00 6011007.72 553527.02 MWD+IFR+MS 6075.00 71.76 225.02 3992.90 3922.40 894.32 -3124.38 4.00 6010990.86 553510.40 MWD+IFR+MS 6086.63 72.22 225.02 3996.50 3926.00 886.51 -3132.21 4.00 6010982.99 553502.64 MPH-16 Fault 4 6093.23 72.49 225.03 3998.50 3928.00 882.06 -3136.66 4.00 6010978.51 553498.23 SBE1-NF 6100.00 72.76 225.03 4000.52 3930.02 877.49 -3141.23 4.00 6010973.91 553493.69 MWD+IFR+MS 6125.00 73.76 225.04 4007.72 3937.22 860.58 -3158.17 4.00 6010956.86 553476.88 MWD+IFR+MS 6150.00 74.76 225.05 4014.51 3944.01 843.57 -3175.19 4.00 6010939.73 553459.99 MWD+IFR+MS 6156.01 75.00 225.05 4016.07 3945.57 839.48 -3179.30 4.00 6010935.60 553455.91 End Dir : 6156 6175.00 75.00 225.05 4020.99 3950.49 826.52 -3192.28 0.00 6010922.55 553443.03 MWD+IFR+MS 6200.00 75.00 225.05 4027.46 3956.96 809.46 -3209.37 0.00 6010905.36 553426.07 MWD+IFR+MS 6211.75 75.00 225.05 4030.50 3960.00 801.44 -3217.40 0.00 6010897.28 553418.10 TSBD-Top OA 6225.00 75.00 225.05 4033.93 3963.43 792.40 -3226.46 0.00 6010888.17 553409.11 MWD+IFR+MS 6227.20 75.00 225.05 4034.50 3964.00 790.89 -3227.97 0.00 6010886.66 553407.62 MPH-16 Fault 3 6231.06 75.00 225.05 4035.50 3965.00 788.26 -3230.61 0.00 6010884.00 553405.00 MPH-16 T1 6250.00 75.76 225.05 4040.28 3969.78 775.31 -3243.57 4.00 6010870.96 553392.13 MWD+IFR+MS 6275.00 76.76 225.05 4046.22 3975.72 758.16 -3260.76 4.00 6010853.68 553375.08 MWD+IFR+MS 6300.00 77.76 225.05 4051.73 3981.23 740.93 -3278.02 4.00 6010836.32 553357.96 MWD+IFR+MS 6303.63 77.90 225.05 4052.50 3982.00 738.42 -3280.53 4.00 6010833.79 553355.46 TSBC-Base OA 6325.00 78.76 225.05 4056.82 3986.32 723.64 -3295.34 4.00 6010818.90 553340.77 MWD+IFR+MS 6350.00 79.76 225.05 4061.48 3990.98 706.28 -3312.72 4.00 6010801.42 553323.52 MWD+IFR+MS 6356.08 80.00 225.05 4062.55 3992.05 702.05 -3316.96 4.00 6010797.15 553319.31 End Dír : 6356 6375.00 80.00 225.05 4065.84 3995.34 688.89 -3330.15 0.00 6010783.89 553306.23 MWD+IFR+MS 6400.00 80.00 225.05 4070.18 3999.68 671.50 -3347.57 0.00 6010766.37 553288.94 MWD+IFR+MS 6425.00 80.00 225.05 4074.52 4004.02 654.10 -3364.99 0.00 6010748.85 553271.65 MWD+IFR+MS 6450.00 80.00 225.05 4078.86 4008.36 636.71 -3382.42 0.00 6010731.32 553254.36 MWD+IFR+MS 6459.45 80.00 225.05 4080.50 4010.00 630.14 -3389.00 0.00 6010724.70 553247.83 TSBB-Top OB 6475.00 80.00 225.05 4083.20 4012.70 619.32 -3399.84 0.00 6010713.80 553237.07 MWD+IFR+MS 6488.24 80.00 225.05 4085.50 4015.00 610.11 -3409.07 0.00 6010704.52 553227.91 MPH-16 T2 6488.58 80.00 225.05 4085.56 4015.06 609.87 -3409.31 0.00 6010704.28 553227.67 Start Dir 8/100 6488.80 80.00 225.05 4085.60 4015.10 609.72 -3409.46 0.00 6010704.13 553227.52 75/8" 6500.00 80.52 224.29 4087.49 4016.99 601.86 -3417.22 8.15 6010696.22 553219.83 MWD+IFR+MS 6525.00 81.67 222.63 4091.36 4020.86 583.94 -3434.21 8.00 6010678.16 553202.98 MWD+IFR+MS 6550.00 82.83 220.98 4094.73 4024.23 565.47 -3450.72 8.00 6010659.58 553186.61 MWD+WR+MS . . BP BP Planning Report 6575.00 83.99 219.35 4097.60 4027.10 546.50 -3466.74 8.00 6010640.48 553170.73 MWD+IFR+MS 6600.00 85.15 217.71 4099.97 4029.47 527.03 -3482.24 8.00 6010620.89 553155.38 MWD+IFR+MS 6606.48 85.46 217.29 4100.50 4030.00 521.91 -3486.17 8.00 6010615.74 553151.49 SBA5-Base DB 6625.00 86.32 216.09 4101.83 4031.33 507.09 -3497.21 8.00 6010600.85 553140.57 MWD+IFR+MS 6650.00 87.50 214.46 4103.18 4032.68 486.71 -3511.62 8.00 6010580.36 553126.31 MWD+IFR+MS 6675.00 88.67 212.84 4104.01 4033.51 465.92 -3525.47 8.00 6010559.46 553112.62 MWD+IFR+MS 6700.00 89.85 211.23 4104.34 4033.84 444.73 -3538.73 8.00 6010538.17 553099.53 MWD+IFR+MS 6725.00 91.02 209.61 4104.15 4033.65 423.17 -3551.39 8.00 6010516.52 553087.03 MWD+IFR+MS 6750.00 92.20 207.99 4103.44 4032.94 401.27 -3563.42 8.00 6010494.54 553075.16 MWD+IFR+MS 6775.00 93.37 206.37 4102.23 4031.73 379.06 -3574.83 8.00 6010472.24 553063.93 MWD+IFR+MS 6791.88 94.16 205.27 4101.12 4030.62 363.89 -3582.17 8.00 6010457.02 553056.71 End Dir : 6791 6800.00 94.16 205.27 4100.53 4030.03 356.57 -3585.62 0.00 6010449.68 553053.31 MWD+IFR+MS 6825.00 94.16 205.27 4098.72 4028.22 334.02 -3596.27 0.00 6010427.05 553042.84 MWD+IFR+MS 6850.00 94.16 205.27 4096.90 4026.40 311.48 -3606.91 0.00 6010404.42 553032.36 MWD+IFR+MS 6875.00 94.16 205.27 4095.09 4024.59 288.93 -3617.56 0.00 6010381.80 553021.89 MWD+IFR+MS 6900.00 94.16 205.27 4093.27 4022.77 266.38 -3628.20 0.00 6010359.17 553011.42 MWD+IFR+MS 6925.00 94.16 205.27 4091.46 4020.96 243.83 -3638.85 0.00 6010336.55 553000.95 MWD+IFR+MS 6950.00 94.16 205.27 4089.65 4019.15 221.29 -3649.49 0.00 6010313.92 552990.48 MWD+IFR+MS 6975.00 94.16 205.27 4087.83 4017.33 198.74 -3660.13 0.00 6010291.30 552980.00 MWD+IFR+MS 7000.00 94.16 205.27 4086.02 4015.52 176.19 -3670.78 0.00 6010268.67 552969.53 MWD+IFR+MS 7025.00 94.16 205.27 4084.20 4013.70 153.64 -3681.42 0.00 6010246.04 552959.06 MWD+IFR+MS 7050.00 94.16 205.27 4082.39 4011.89 131.09 -3692.07 0.00 6010223.42 552948.59 MWD+IFR+MS 7075.00 94.16 205.27 4080.57 4010.07 108.55 -3702.71 0.00 6010200.79 552938.12 MWD+IFR+MS 7100.00 94.16 205.27 4078.76 4008.26 86.00 -3713.36 0.00 6010178.17 552927.65 MWD+IFR+MS 7125.00 94.16 205.27 4076.94 4006.44 63.45 -3724.00 0.00 6010155.54 552917.17 MWD+IFR+MS 7150.00 94.16 205.27 4075.13 4004.63 40.90 -3734.64 0.00 6010132.91 552906.70 MWD+IFR+MS 7175.00 94.16 205.27 4073.32 4002.82 18.36 -3745.29 0.00 6010110.29 552896.23 MWD+IFR+MS 7200.00 94.16 205.27 4071.50 4001.00 -4.19 -3755.93 0.00 6010087.66 552885.76 MWD+IFR+MS 7225.00 94.16 205.27 4069.69 3999.19 -26.74 -3766.58 0.00 6010065.04 552875.29 MWD+IFR+MS 7250.00 94.16 205.27 4067.87 3997.37 -49.29 -3777.22 0.00 6010042.41 552864.81 MWD+IFR+MS 7275.00 94.16 205.27 4066.06 3995.56 -71.84 -3787.87 0.00 6010019.79 552854.34 MWD+IFR+MS 7300.00 94.16 205.27 4064.24 3993.74 -94.38 -3798.51 0.00 6009997.16 552843.87 MWD+IFR+MS 7325.00 94.16 205.27 4062.43 3991.93 -116.93 -3809.16 0.00 6009974.53 552833.40 MWD+IFR+MS 7350.00 94.16 205.27 4060.61 3990.11 -139.48 -3819.80 0.00 6009951.91 552822.93 MWD+IFR+MS 7375.00 94.16 205.27 4058.80 3988.30 -162.03 -3830.44 0.00 6009929.28 552812.46 MWD+IFR+MS 7400.00 94.16 205.27 4056.99 3986.49 -184.57 -3841.09 0.00 6009906.66 552801.98 MWD+IFR+MS 7425.00 94.16 205.27 4055.17 3984.67 -207.12 -3851.73 0.00 6009884.03 552791.51 MWD+IFR+MS 7450.00 94.16 205.27 4053.36 3982.86 -229.67 -3862.38 0.00 6009861.40 552781.04 MWD+IFR+MS 7475.00 94.16 205.27 4051.54 3981.04 -252.22 -3873.02 0.00 6009838.78 552770.57 MWD+IFR+MS 7500.00 94.16 205.27 4049.73 3979.23 -274.77 -3883.67 0.00 6009816.15 552760.10 MWD+IFR+MS 7525.00 94.16 205.27 4047.91 3977.41 -297.31 -3894.31 0.00 6009793.53 552749.62 MWD+IFR+MS 7550.00 94.16 205.27 4046.10 3975.60 -319.86 -3904.96 0.00 6009770.90 552739.15 MWD+IFR+MS 7575.00 94.16 205.27 4044.29 3973.79 -342.41 -3915.60 0.00 6009748.27 552728.68 MWD+IFR+MS 7600.00 94.16 205.27 4042.47 3971.97 -364.96 -3926.24 0.00 6009725.65 552718.21 MWD+IFR+MS 7625.00 94.16 205.27 4040.66 3970.16 -387.51 -3936.89 0.00 6009703.02 552707.74 MWD+IFR+MS 7650.00 94.16 205.27 4038.84 3968.34 -410.05 -3947.53 0.00 6009680.40 552697.27 MWD+IFR+MS 7675.00 94.16 205.27 4037.03 3966.53 -432.60 -3958.18 0.00 6009657.77 552686.79 MWD+IFR+MS 7700.00 94.16 205.27 4035.21 3964.71 -455.15 -3968.82 0.00 6009635.15 552676.32 MWD+IFR+MS 7725.00 94.16 205.27 4033.40 3962.90 -477.70 -3979.47 0.00 6009612.52 552665.85 MWD+IFR+MS 7750.00 94.16 205.27 4031.58 3961.08 -500.24 -3990.11 0.00 6009589.89 552655.38 MWD+IFR+MS 7775.00 94.16 205.27 4029.77 3959.27 -522.79 -4000.76 0.00 6009567.27 552644.91 MWD+IFR+MS 7789.80 94.16 205.27 4028.70 3958.20 -536.14 -4007.06 0.00 6009553.87 552638.71 -Start Dir 4/100 7800.00 94.20 205.68 4027.95 3957.45 -545.32 -4011.43 4.00 6009544.66 552634.40 ·MWD+IFR+MS . . BP BP Planning Report 7825.00 94.28 206.68 4026.10 3955.60 -567.70 -4022.43 4.00 6009522.20 552623.57 MWD+IFR+MS 7833.06 94.31 207.00 4025.50 3955.00 -574.87 -4026.06 4.00 6009515.00 552620.00 MPH-16 T3 7850.00 94.31 207.68 4024.23 3953.73 -589.87 -4033.82 4.00 6009499.94 552612.36 MWD+IFR+MS 7875.00 94.31 208.68 4022.35 3951.85 -611.85 -4045.59 4.00 6009477.88 552600.75 MWD+IFR+MS 7888.44 94.30 209.22 4021.34 3950.84 -623.57 -4052.08 4.00 6009466.11 552594.36 End Dir : 7888 7900.00 94.30 209.22 4020.47 3949.97 -633.64 -4057.71 0.00 6009456.01 552588.80 MWD+IFR+MS 7925.00 94.30 209.22 4018.60 3948.10 -655.39 -4069.88 0.00 6009434.16 552576.80 MWD+IFR+MS 7950.00 94.30 209.22 4016.72 3946.22 -677.15 -4082.05 0.00 6009412.31 552564.80 MWD+/FR+MS 7975.00 94.30 209.22 4014.85 3944.35 -698.91 -4094.22 0.00 6009390.47 552552.79 MWD+IFR+MS 8000.00 94.30 209.22 4012.97 3942.47 -720.66 -4106.39 0.00 6009368.62 552540.79 MWD+IFR+MS 8025.00 94.30 209.22 4011.09 3940.59 -742.42 -4118.56 0.00 6009346.77 552528.79 MWD+IFR+MS 8050.00 94.30 209.22 4009.22 3938.72 -764.18 -4130.73 0.00 6009324.92 552516.78 MWD+IFR+MS 8075.00 94.30 209.22 4007.34 3936.84 -785.94 -4142.90 0.00 6009303.08 552504.78 MWD+IFR+MS 8100.00 94.30 209.22 4005.47 3934.97 -807.69 -4155.07 0.00 6009281.23 552492.78 MWD+IFR+MS 8125.00 94.30 209.22 4003.59 3933.09 -829.45 -4167.24 0.00 6009259.38 552480.77 MWD+IFR+MS 8150.00 94.30 209.22 4001.71 3931.21 -851.21 -4179.41 0.00 6009237.54 552468.77 MWD+IFR+MS 8165.43 94.30 209.22 4000.56 3930.06 -864.63 -4186.92 0.00 6009224.06 552461.36 Start Dir 8/100 8175.00 94.15 209.97 3999.85 3929.35 -872.93 -4191.63 8.00 6009215.72 552456.71 MWD+IFR+MS 8200.00 93.76 211.94 3998.13 3927.63 -894.32 -4204.46 8.00 6009194.24 552444.05 MWD+IFR+MS 8225.00 93.37 213.90 3996.57 3926.07 -915.26 -4218.02 8.00 6009173.20 552430.65 MWD+IFR+MS 8250.00 92.96 215.87 3995.19 3924.69 -935.74 -4232.30 8.00 6009152.61 552416.53 MWD+IFR+MS 8275.00 92.56 217.83 3993.99 3923.49 -955.72 -4247.27 8.00 6009132.52 552401.71 MWD+IFR+MS 8300.00 92.15 219.79 3992.96 3922.46 -975.18 -4262.93 8.00 6009112.94 552386.20 MWD+IFR+MS 8325.00 91.74 221.75 3992.11 3921.61 -994.11 -4279.24 8.00 6009093.90 552370.04 MWD+IFR+MS 8350.00 91.33 223.70 3991.44 3920.94 -1012.46 -4296.20 8.00 6009075.41 552353.22 MWD+IFR+MS 8375.00 90.92 225.66 3990.94 3920.44 -1030.23 -4313.77 8.00 6009057.51 552335.78 MWD+IFR+MS 8400.00 90.50 227.62 3990.63 3920.13 -1047.40 -4331.95 8.00 6009040.21 552317.74 MWD+IFR+MS 8425.00 90.09 229.57 3990.50 3920.00 -1063.93 -4350.70 8.00 6009023.54 552299.12 MWD+IFR+MS 8430.43 90.00 230.00 3990.50 3920.00 -1067.44 -4354.84 8.00 6009020.00 552295.00 MPH-16 T4 8450.00 89.64 231.52 3990.56 3920.06 -1079.81 -4370.00 8.00 6009007.51 552279.94 MWD+IFR+MS 8475.00 89.17 233.47 3990.82 3920.32 -1095.03 -4389.83 8.00 6008992.14 552260.23 MWD+IFR+MS 8500.00 88.71 235.41 3991.28 3920.78 -1109.57 -4410.16 8.00 6008977.46 552240.01 MWD+IFR+MS 8525.00 88.25 237.36 3991.95 3921.45 -1123.40 -4430.97 8.00 6008963.47 552219.30 MWD+IFR+MS 8530.69 88.14 237.80 3992.13 3921.63 -1126.45 -4435.77 8.00 6008960.38 552214.53 End Dir : 8530 8550.00 88.14 237.80 3992.75 3922.25 -1136.73 -4452.11 0.00 6008949.98 552198.27 MWD+IFR+MS 8575.00 88.14 237.80 3993.56 3923.06 -1150.05 -4473.25 0.00 6008936.50 552177.23 MWD+IFR+MS 8600.00 88.14 237.80 3994.37 3923.87 -1163.36 -4494.40 0.00 6008923.03 552156.19 MWD+IFR+MS 8625.00 88.14 237.80 3995.18 3924.68 -1176.67 -4515.54 0.00 6008909.56 552135.15 MWD+IFR+MS 8650.00 88.14 237.80 3995.99 3925.49 -1189.99 -4536.69 0.00 6008896.09 552114.11 MWD+IFR+MS 8675.00 88.14 237.80 3996.80 3926.30 -1203.30 -4557.83 0.00 6008882.61 552093.07 MWD+IFR+MS 8700.00 88.14 237.80 3997.61 3927.11 -1216.61 -4578.98 0.00 6008869.14 552072.03 MWD+IFR+MS 8725.00 88.14 237.80 3998.42 3927.92 -1229.93 -4600.12 0.00 6008855.67 552050.99 MWD+IFR+MS 8750.00 88.14 237.80 3999.23 3928.73 -1243.24 -4621.27 0.00 6008842.20 552029.95 MWD+IFR+MS 8775.00 88.14 237.80 4000.04 3929.54 -1256.55 -4642.41 0.00 6008828.72 552008.90 MWD+IFR+MS 8800.00 88.14 237.80 4000.85 3930.35 -1269.87 -4663.56 0.00 6008815.25 551987.86 MWD+IFR+MS 8825.00 88.14 237.80 4001.66 3931.16 -1283.18 -4684.70 0.00 6008801.78 551966.82 MWD+IFR+MS 8850.00 88.14 237.80 4002.47 3931.97 -1296.49 -4705.84 0.00 6008788.31 551945.78 MWD+IFR+MS 8862.45 88.14 237.80 4002.87 3932.37 -1303.12 -4716.37 0.00 6008781.60 551935.30 Start Dir 8/100 8875.00 88.29 236.81 4003.26 3932.76 -1309.90 -4726.93 8.00 6008774.74 551924.80 MWD+IFR+MS 8900.00 88.57 234.83 4003.95 3933.45 -1323.94 -4747.60 8.00 6008760.55 551904.24 MWD+IFR+MS 8925.00 88.86 232.85 4004.51 3934.01 -1338.69 -4767.78 8.00 6008745.65 551884.17 MWD+IFR+MS 8950.00 89.14 230.87 4004.95 3934.45 -1354.12 -4787.44 8.00 6008730.07 tS1864.63 MWD+IFR+MS . . BP BP Planning Report 8975.00 89.43 228.89 4005.26 3934.76 -1370.23 -4806.56 8.00 6008713.82 551845.64 MWD+IFR+MS 9000.00 89.72 226.91 4005.44 3934.94 -1386.99 -4825.10 8.00 6008696.92 551827.22 MWD+IFR+MS 9025.00 90.00 224.93 4005.50 3935.00 -1404.38 -4843.06 8.00 6008679.39 551809.40 MWD+IFR+MS 9050.00 90.03 222.93 4005.49 3934.99 -1422.38 -4860.41 8.00 6008661.26 551792.19 MWD+IFR+MS 9075.00 90.06 220.93 4005.47 3934.97 -1440.98 -4877.11 8.00 6008642.54 551775.63 MWD+IFR+MS 9100.00 90.09 218.93 4005.44 3934.94 -1460.15 -4893.16 8.00 6008623.25 551759.73 MWD+IFR+MS 9125.00 90.11 216.93 4005.40 3934.90 -1479.87 -4908.53 8.00 6008603.42 551744.52 MWD+IFR+MS 9150.00 90.14 214.93 4005.34 3934.84 -1500.11 -4923.20 8.00 6008583.07 551730.00 MWD+IFR+MS 9175.00 90.17 212.93 4005.28 3934.78 -1520.85 -4937.15 8.00 6008562.22 551716.21 MWD+IFR+MS 9200.00 90.20 210.93 4005.20 3934.70 -1542.06 -4950.37 8.00 6008540.91 551703.15 MWD+/FR+MS 9225.00 90.23 208.93 4005.10 3934.60 -1563.73 -4962.85 8.00 6008519.16 551690.84 MWD+IFR+MS 9250.00 90.25 206.93 4005.00 3934.50 -1585.81 -4974.56 8.00 6008496.98 551679.30 MWD+IFR+MS 9275.00 90.28 204.93 4004.88 3934.38 -1608.30 -4985.49 8.00 6008474.42 551668.54 MWD+IFR+MS 9300.00 90.31 202.93 4004.76 3934.26 -1631.14 -4995.63 8.00 6008451.50 551658.57 MWD+IFR+MS 9325.00 90.33 200.93 4004.62 3934.12 -1654.33 -5004.97 8.00 6008428.24 551649.41 MWD+IFR+MS 9350.00 90.36 198.93 4004.47 3933.97 -1677.83 -5013.49 8.00 6008404.68 551641.07 MWD+IFR+MS 9375.00 90.38 196.93 4004.30 3933.80 -1701.62 -5021.19 8.00 6008380.84 551633.55 MWD+IFR+MS 9383.90 90.39 196.22 4004.24 3933.74 -1710.14 -5023.73 8.00 6008372.30 551631.08 End Dir : 9383 9400.00 90.39 196.22 4004.13 3933.63 -1725.61 -5028.23 0.00 6008356.80 551626.70 MWD+IFR+MS 9425.00 90.39 196.22 4003.96 3933.46 -1749.61 -5035.21 0.00 6008332.75 551619.90 MWD+IFR+MS 9450.00 90.39 196.22 4003.79 3933.29 -1773.61 -5042.19 0.00 6008308.69 551613.10 MWD+IFR+MS 9475.00 90.39 196.22 4003.62 3933.12 -1797.62 -5049.18 0.00 6008284.64 551606.30 MWD+IFR+MS 9500.00 90.39 196.22 4003.45 3932.95 -1821.62 -5056.16 0.00 6008260.58 551599.50 MWD+IFR+MS 9525.00 90.39 196.22 4003.28 3932.78 -1845.63 -5063.15 0.00 6008236.53 551592.69 MWD+IFR+MS 9550.00 90.39 196.22 4003.11 3932.61 -1869.63 -5070.13 0.00 6008212.48 551585.89 MWD+IFR+MS 9575.00 90.39 196.22 4002.94 3932.44 -1893.63 -5077.11 0.00 6008188.42 551579.09 MWD+IFR+MS 9600.00 90.39 196.22 4002.77 3932.27 -1917.64 -5084.10 0.00 6008164.37 551572.29 MWD+IFR+MS 9625.00 90.39 196.22 4002.60 3932.10 -1941.64 -5091.08 0.00 6008140.31 551565.49 MWD+IFR+MS 9650.00 90.39 196.22 4002.43 3931.93 -1965.65 -5098.07 0.00 6008116.26 551558.69 MWD+IFR+MS 9675.00 90.39 196.22 4002.26 3931.76 -1989.65 -5105.05 0.00 6008092.21 551551.89 MWD+/FR+MS 9700.00 90.39 196.22 4002.08 3931.58 -2013.65 -5112.03 0.00 6008068.15 551545.09 MWD+IFR+MS 9725.00 90.39 196.22 4001.91 3931.41 -2037.66 -5119.02 0.00 6008044.10 551538.29 MWD+IFR+MS 9750.00 90.39 196.22 4001.74 3931.24 -2061.66 -5126.00 0.00 6008020.04 551531.49 MWD+IFR+MS 9775.00 90.39 196.22 4001.57 3931.07 -2085.67 -5132.99 0.00 6007995.99 551524.69 MWD+IFR+MS 9800.00 90.39 196.22 4001.40 3930.90 -2109.67 -5139.97 0.00 6007971.94 551517.89 MWD+IFR+MS 9825.00 90.39 196.22 4001.23 3930.73 -2133.68 -5146.95 0.00 6007947.88 551511.08 MWD+/FR+MS 9850.00 90.39 196.22 4001.06 3930.56 -2157.68 -5153.94 0.00 6007923.83 551504.28 MWD+IFR+MS 9875.00 90.39 196.22 4000.89 3930.39 -2181.68 -5160.92 0.00 6007899.77 551497.48 MWD+IFR+MS 9900.00 90.39 196.22 4000.72 3930.22 -2205.69 -5167.91 0.00 6007875.72 551490.68 MWD+IFR+MS 9925.00 90.39 196.22 4000.55 3930.05 -2229.69 -5174.89 0.00 6007851.67 551483.88 MWD+/FR+MS 9931.00 90.39 196.22 4000.51 3930.01 -2235.45 -5176.57 0.00 6007845.89 551482.25 41/2" ,9931.92 90.39 196.22 4000.50 _ 3930.00 -2236.34 -5176.82 0.00 6007845.00 551482.00 MPH-16 T6 SURVEY PROGRAM Depth Fm Depth To SurvcyIPJan Tool 34.30 1200.80 Planned: MPH-16 WP06 V6S CB-< ¡ 200.80 9931.92 Planned: MPH-16 WP06 V65 MWD+IFR+MS COMPANY DETAILS BP Amoco Ca1culation Method: Minimum Ûl!'V8tuR Error System: ISCWSA Scan Method: Trav Cylinder North Em>r Surface: Elliptical + Casing Wamìng Method: Rules Based ANTI-COLLISION SETTINGS 25.00 993!. 92 Plan: MPH-16 WP06 Interval To: Reference: Interpolation Method:MD Depth Range From: 34.30 MaxÎmum Range: 1189.76 Slot N/A Longitude 149~2'17.356W LaliNœ 70"26'17,ß70N EaSfing 556641 Northing 6O!0120Ji ...£j·W 1244.90 _N/oS 139.: "'"" MPH-16 NEO Rig: Ref. Datum: 34.3+36.2 10.Soft: V.Section Origin Origin ~=~D Angle +Nf-S +E/-W 246.64' 0.00 0.00 34.30 . LEGEND MPH~I (MPH-OI), Major Risk MPH-oI (Plan MPH-ola). Major Risk MPH-oI (Plan MPH-OlaLlj, Major Risk MPH-02 (MPH-02), Major Risk MPH-03 (MPH-03). Major R~ MPH-G4 (MPH..()4), Ma.fr R~ MPH-o$ (MPH-05). MajOr Risk MPH..()6 (MPH..()6), Major Risk MPH-07 (MPH-07). Majot Risk MPH-07 (MPH-07A), Major Risk MPH~(MPH.07ALIJ.. Major Risk MPH-07 (MPH-07ALIP81). MajŒ RiJik MPH-07 (MPH-07ALIP82j, Majer Ri1k MPH-07 (MPH..o7AP81). MAjor Risk MPH-08 (MPH-Og), Majot Risk MPH~ (MPH..o8A), Major Risk MPH-OS(MPH-o8AP8I). MAjor Risk MPH~ (MPH-088). Maj.:Jr Risk MPH..œ (MPH..œ8l]). Major Risk MPH-08 (MPH-OSBPBlJ, Major Risk MPH.Q9 (MPH.Q9). Major Risk MPH-IO(MPH-IO). Major Risk MPH-II (MPH-II). Ma,jor Risk MPH-12 (MPH-12). MajOr Risk MPH·IJ (MPH-J), Major Risk MPH·J (MPH-I3A). MajoI ~isk MPH-]~ (MPH-14), Major R!* Man Ouco (Chico), MaJOf Risk Man Groucho (Grouchoj, Major Risk PJan Hatpo (Harpo), Major Risk Plan Helix (Helix LI). MtjOf Risk Plan Helix (Helix W). Major Risk Plan Helix {Helix WI. Maj<:Jr Risk Plan Helix (Helix l4). Majar Risk Plan MPH-IS (Plan MPH-t8 Lt), Major Risk Plan MPH-IS (PIBn MPH·18 l2). Major Risk Plan MPH-18 (Plan MPH·\8). Major Risk Plan Noo( MPH-16) (MPH-16L1). NOERRORS Plan Smith (Smith), Ma.jox Ri~ ~~~1(;,t~T~~ì~~;:'Ri. MPI..()I (Plan MPI..()IAll). Major Risk MPI..()2 (MPI-02), Majoc Riù. MPI-OJ (MPI-03I, Majoc Risk MPI~A (MPI-04A). Majof Risk: MPI~ (MPI.{\4), Major Risk MP~ (MPI-04A). Major Risk MP..()4 (MPI.{\4AlI , Major Ritk MPI-04 (MPI-04APBt), Major Risk MP...()4 (MPI.{\4PBI), Majer RiH MPJ"()5 (MPI.o5). Majot Risk MPJ..()7 (MPI..07j. Major Rtsk MPJ-15 (MPI.15I, Major Rid!. MPI-15 (MPJ-lSLl), Major Risk MPf-15 (MPI-15PBlj, Major Risk ~=: ~~:::; ~(~~~tr-l~itl), Major Risk Plan MPI-17 Thor {Plan MPl-17 L2), Major Risk Plan MPI.17 Thor (pian MPI-17). M.jorR.ìsk Plan MP¡.17 toor{Rîg: MPI-I7), MajOrRlsIc MPH-16 MPH-16 WP06 - - - - - - ToMD 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 Colour - - S« MD 1 34.30 2 6(().80 J. 850.80 4 1046.1)) S UnO.58 6 1929.73 1 2861.56 8 4107.08 9 :1781.02 10 6031.02 11 6136.01 12 6231.06 I) 6336.08 14 6488.58 13 6791.88 16 7789.80 17 7833.06 18 7888.44 19 8165.43 20 8430.43 21 8530.69 22 8862.45 23 9024.15 24 9383.90 23 9931.92 ~ ~'" ~ '<:.><~:~ >~~'.',,> ~~K.,'.", "- ~ ','\. "'" o. [134 125 -104 '" ~ t/ :. ~) mt.' " '-J'Rji ::::~ .,ll. 1.:,·,;::1. . '-.. ~,.. "", ~ :t:. \ 1"' ~ \ \ ! \ \ ~ \ \ \ \ \ .6tIIi ~ \ 30 ~ ~. Sß '""9 "'. ~ B :2 E þ :2 ¡E á r iõ: 27 -84 -42 -42 1-63 1-63 1 1-21 -0 1-2 T...~ VS« 0,00 0.00 -432 -122 0,72 '" 266.24 926.72 22:16.34 2414,91 25115.70 2653.12 2766.:17 2m.91 3144.14 3891.12 3923.92 3967.12 4186.50 4421.œ 4518.78 4846.43 3002.10 3290.00 5639.21 TF'ace 0.00 0.00 0.00 ]t4.m om 0.00 -57.42 0.00 -100.78 0.00 0.56 0.00 0.00 0.00 -55.21 0.00 85.03 90.00 0.00 \01.19 103.42 0.00 -81.89 ..89.19 0.00 DL<,¡ 0.00 0.00 2.00 100 3.00 0.00 4.00 0,00 4.00 0.00 4.00 0.00 4.00 0.00 8.00 0.00 4.00 4.00 0.00 '.00 '.00 0.00 '.00 '.00 0,00 SECI10N DETAILS +toI1-S +f).W 0.00 0.00 OJ)() OIID 10.90 0.00 34.80 -7.17 236.68 _124.63 345.39 -152.00 m.4? -630.63 1317.16 -157850 1œ9.82 ·2928.88 923.70 -3095.00 839.48 -3179.30 788.26 -3230.61 702.05 -3316.96 609.87 -3409.3] 363.89 -3582.17 .536.14 -4OO1J.16 .374.g7 -4026.06 -623.57 4052.08 -864.63 -4186.92 -)067.44 -43$4.84 -)126.45 4435.77 -1303.12 -471637 -1403.78 -4842.46 -1710.J4 -5023.73 -223634 -5176.82 TVD 34.30 600.80 850.48 to<W.OO mo.w 1850.80 2493.23 310416 3892.99 3978.50 4016.07 4033.50 4062.55 4083.36 410\.12 4028.70 4023.:10 4021J4 4000.5. 3990.50 3992.n 4002.31 4005.30 4004.24 400050 ..,; 0.00 0.00 0.00 335.00 335.00 335.00 299.15 299.15 225.00 225.00 225.05 225.05 225.05 225.05 205.2.7 20527 207.00 209.22 2"'22 230.00 237.80 237,80 22$,00 196.22 t9622 .., 0.00 0.00 5.00 10.00 32.93 32.93 60.62 60.62 70.00 70.00 15.00 75.00 80.00 80.00 94.16 94.16 94.31 94JO 94JO 90.00 88.14 88.14 90.00 90,39 90.39 i 50 to Centre Separation [ft] y' / ./~- / "~ ~ /e 181 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre ,. .;;;,; ~>~~>-'- .2;.. ..~~<~~. ". .' '·i::.~ 21~i~ 1-84 -104 [125 134 . . BP Anticollision Report Company: Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Milne Point M Pt H Pad Plan Nee ( MPH-16 ) MPH-16 Date: 8/11/2004 Time: 15;54:49 Page: 1 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan Neo (MPH-16). True North 34.3+36.2 70.5 GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 34.30 to 9931.92 ft Maximum Radius: 1189.76 ft Reference: Error Model: Scan Method: Error Surface: Db: Oracle Plan: MPH-16 WP06 & NOT PLANNED I OGR ISCWSA Ellipse T rav Cylinder North Ellipse + Casing Casing Points Diameter in Hole Size in Name MD ft 4240.25 6488.80 9931.00 TVD ft 3170.50 4085.60 4000.51 10.750 7.625 4.500 12.250 9.875 6.750 103/4" 7 5/8" 4 1/2" Plan: MPH-16 WP06 Date Composed: Version: Tied·to: 6/28/2004 65 From Well Ref. Point Principal: Yes Summary <: Offset Wellpath > Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft M Pt H Pad MPH·01 MPH-01 V1 448.47 450.00 242.65 9.03 233.62 Pass: Major Risk M Pt H Pad MPH-01 Plan MPH-01a V1 Plan: 428.48 425.00 242.27 8.56 233.70 Pass: Major Risk M Pt H Pad MPH-01 Plan MPH-01aL 1 V2 Plan 428.48 425.00 242.27 8.66 233.61 Pass: Major Risk M Pt H Pad MPH-02 MPH-02 V1 621.38 625.00 184.89 16.47 168.42 Pass: Major Risk M Pt H Pad MPH-03 MPH-03 V1 814.15 825.00 114.28 18.42 95.86 Pass: Major Risk M Pt H Pad MPH-04 MPH-04 V1 635.68 625.00 61.39 12.81 48.58 Pass: Major Risk M Pt H Pad MPH-05 MPH-05 V1 656.62 650.00 89.79 12.58 77.21 Pass: Major Risk M pt H Pad MPH-06 MPH-06 V1 628.13 625.00 147.22 12.24 134.98 Pass: Major Risk M pt H Pad MPH-07 MPH-07 V1 554.49 550.00 269.37 10.13 259.24 Pass: Major Risk M Pt H Pad MPH-07 MPH-07A V12 574.49 575.00 269.61 10.42 259.20 Pass: Major Risk M Pt H Pad MPH-07 MPH-07AL1 V5 574.49 575.00 269.61 10.16 259.46 Pass: Major Risk M Pt H Pad MPH-07 MPH·07AL 1P81 V4 574.49 575.00 269.61 10.42 259.20 Pass: Major Risk M pt H Pad MPH-07 MPH-07AL 1P82 V6 574.49 575.00 269.61 10.42 259.20 Pass: Major Risk M Pt H Pad MPH-07 MPH-07AP81 V25 574.49 575.00 269.61 10.26 259.35 Pass: Major Risk M Pt H Pad MPH-08 MPH-08 V2 329.79 325.00 209.61 6.57 203.04 Pass: Major Risk M Pt H Pad MPH-08 MPH-08A V4 329.79 325.00 209.61 6.72 202.89 Pass: Major Risk M Pt H Pad MPH-08 MPH-08APB1 V3 329.79 325.00 209.61 6.72 202.89 Pass: Major Risk M Pt H Pad MPH-08 MPH-088 V5 329.79 325.00·209.61 6.72 202.89 Pass: Major Risk M pt H Pad MPH-08 MPH-088L 1 V16 329.79 325.00 209.61 6.72 202.89 Pass: Major Risk M Pt H Pad MPH-08 MPH-088P81 V1 329.79 325.00 209.61 6.72 202.89 Pass: Major Risk M Pt H Pad MPH-09 MPH-09 V3 433.47 425.00 239.53 8.28 231.25 Pass: Major Risk MPtHPad MPH-10 MPH-10V9 613.87 600.00211.1611.49199.67 Pass: Major Risk M Pt H Pad MPH-11 MPH-11 V6 662.92 700.00 187.81 12.21 175.60 Pass: Major Risk M pt H Pad MPH-12 MPH-12 V2 827.24 825.00 146.81 16.58 130.22 Pass: Major Risk M Pt H Pad MPH-13 MPH-13 V4 1065.77 1075.00 66.54 22.61 43.94 Pass: Major Risk M Pt H Pad MPH-13 MPH-13A V4 1060.75 1075.00 66.20 22.34 43.86 Pass: Major Risk M Pt H Pad MPH-14 MPH-14 V7 1102.02 1100.00 48.92 22.73 26.20 Pass: Major Risk M pt H Pad Plan Chico Chico V2 Plan: Chico W 648.46 650.00 123.97 14.18 109.79 Pass: Major Risk M PI H Pad Plan Graucho Groucho V1 Plan: Graue 1451.34 1425.00 117.10 28.74 88.37 Pass: Major Risk M Pt H Pad Plan Harpo Harpo V1 Plan: Harpo W 1290.43 1300.00 47.07 25.89 21.19 Pass: Major Risk M Pt H Pad Plan Helix Helix L1 V1 Plan: Heli 5209.53 11450.00 704.30 118.19 586.11 Pass: Major Risk M Pt H Pad Plan Helix Helix L2 V1 Plan: Heli 5085.95 7125.00 646.39 87.48 558.91 Pass: Major Risk M Pt H Pad Plan Helix Helix L3 V1 Plan: Heli 5245.44 9275.00 676.27 96.40 579.87 Pass: Major Risk M Pt H Pad Plan Helix Helix L4 V1 Plan: Heli 5438.90 13550.00 751.86 125.23 626.63 Pass: Major Risk M Pt H Pad Plan MPH-18 Plan MPH-18 L 1 VO Plan 573.48 575.00 61.20 13.24 47.96 Pass: Major Risk M Pt H Pad Plan MPH-18 Plan MPH-18 L2 VO Plan 573.48 575.00 61.20 13.20 47.99 Pass: Major Risk MPtHPad Plan MPH-18 PlanMPH-18V2Plan:W 573.48 575.00 61.20 13.40 47.79 Pass: Major Risk M PI H Pad Plan Neo (MPH-16) MPH-16 L 1 VO Plan: MPH 2800.00 2800.00 0.00 0.00 0.00 FAIL: NO ERRORS M Pt H Pad Plan Smith Smith V2 Plan: Smith W 423.46 425.00 123.52 10.01 113.51 Pass: Major Risk M pt H Pad Plan Trinity Trinity V1 Plan: Trìni 523.50 525.00 123.10 12.45 110.65 Pass: Major Risk M Pt I Pad MPI-01 Plan MPI-01A VO Plan: 8314.60 3900.00 1047.50 106.03 941.47 Pass: Major Risk M Pt I Pad MPI-01 Plan MPI-01AL 1 VO Plan 8314.60 3900.00 1047.50 105.87 941.63 Pass: Major Risk M Pt I Pad MPI-02 MPI-02 V1 4797.30 5250.00 784.15 143.16 640.99 Pass: Major Risk M Pt I Pad MPI-03 MPI-03 V1 9798.02 4375.00 637.16 129.69 507.47 Pass: Major Risk M Pt I Pad MPI-04A MPI-04A V1 6577.10 4700.00 612.70 115.86 496.84 Pass: Major Risk M pt I Pad MPI-04 MPI-04 V5 6579.93 4700.00 612.66 111.67 500.99 Pass: Major Risk ~~---~-~_._------._~---~.~._.--------_.._..__.._----~..._~-_.~----~_._-~_.-_. 149 36 00 Iff 8 o t;f 'i!"" q '" , I I 1493400 Iff 149 3200 Iff MPU H~16 1...01L Proposed 2041900 9/29/2004 TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 149 . DATE áI'~ (f,oLf 6~6;r~JrEW~ 'f3~$ ICO.OO_ D~<L _ _ _ _ _ _ - - - 0% -----OU[LARS First National Bank Alaska Anchorage, AK ~.9501 ~. b( ~ MEMO -ffi.lli:J {p IV { . "Mastercard Check" I: ~ 25 2000(;OI:'i'i ~L,..,(; 2 2 7"' ~ 5 5(;111 0 ~L,'i . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ff7 ~¿;( 4- /b . PTD# 2-0 t/ ---I r ¿) I Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS ~'CLUE'" APPLIES (OPTIONS) MULTI Tbe permit is for a new weJlbore segment of LATERAL existing well . Permit No, API No. . (If API number Production. sbould continue to be reponed as last two (2) digits a function ·of tbe original API number. stated are between 60-69) above. PILOT HOLE In accordance witb 20 AAC 25.005(1), an (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) .. and API Dumber (50 - 70/80) from records, data and logs acquired for we)) (name on permit). / SPACJNG Tbe permit is approved subject ·to fuD / EXCEPTION ,. compliance witb 20 AAC 25.0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:s cepdon. (Company Name) assumes tbe liability of any protest to tbe sp~~ way occur. d~ . i DRY DITCH AU dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater ·tban 30' ,. sample intervals from below tbe permafrost or from wbere samples are first caught and ] 0' sample hiter:va)s tbrougb target zones. S!) ¿¡.¿If·l:>f Field & Pool MILNE POINT, SCHRADER BLFF OIL· 525140 PTD#:2041900 Company BP EXPLORATION (ALASKA) INC Initial ClasslType 1 Permittee attache~. . . . . . . . . . . .. ........... Yes 2 .Leasenumber .appropriate. . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . 3 .U.nlque weltn.ame.ar1(j lJl!mb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WeIlJocatedin_a_d_efjne_d_pool_ _ _ _ _ _ .. _... _ _ _ _ Yes _ _ _MI.LNEPOJN1, SCHMOI;R. BI.FFOI!-.· 525J40,901lerned byC047Z _ _ _ . _. _ _. 5 WeJUocated prJ)per _dlstance_ from driJling unitb_oundary . . _ _ _ Yes _ . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ 6 WellJocated proper distance from otbeJ wells_ _ _ Yes. _ . _ _ SI='ACINGEXCEPTIONRE_QUJREQ _ _ . . _ _ _ _ _ . _ . . _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ 7 _S_uffjcientacreag.e_aYaitable in_dJillilJg unjt _ . _ . _ _ . _ _ _ _ _ ... No_ _ _ _ _ _ _ _ WHLopen. the pooJ '-ntheßamequarter·ql!arter~quar1eJ gOllernmentatsection.as existing weltMI='U l·03_ _ . 8 Jfdeviated, js weJlbore platJncluded _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ . . . . . _ . . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . 9 øperator only affected party _ _ _ . . . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ . _ _ _ _ _ _ _ _ . 10 _Operator has_apprJ)prlate_bond l.nJorce _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 Permit call be lSSl!ed wjtbout co.nserva.tÎ011 order _ _ . _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ . _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . _ _ _ . _ _ _ _ _ _ . _ _ Appr Date 12 Permitc_al1 be lSSl!ed wjtbout actministratille_apprJ)val . _ . . . _ _ _ _ _ _ No. . . . September 104 200.4~ reql!e$ted a waiyer_of sp_acil1g requiremelJts _ _ SFD 9/29/2004 13 Can permit be approved before 15-day wait Yes 14 WellJocated wlthin. area an.d strata authorlzed by.ll1jectiJ)1J Order # (putlO# in_cJ)lJ1m.el1t$).(for_ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 Allwells_withinJl4_mile_area_ofreyiewidel1tlfied(FJ)r~efVjcewellonlYL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 16 PJe·produ~ed injector; duration of pre·pro~uctiol1les~ th.m_ 3 mOl1ths_ (for_ser:.vlce well only) _ _ _NA _ _ _ _ . _ . . _ _ _ _ . . . _ _ _ _ _ _ _ _ . _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 17 ACMP_Fin.ding.ofCon_s'-stel1cy_h_asbeenj~sued.forJhisproiect _ _ _ _ _ _ _. _. _ _ _ _ _. _. _NA WelldrUledfJomexjstil1gpa_d_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ Administration Engineering Appr Date TEM 10/5/2004 1<tC}'"; \ ~ Geology Appr SFD Date 9/29/2004 Geologic Commissioner: ~r-s Well Name: MILNE PT UNIT SB H-16 DEV I PEND GeoArea 890 Program DEV On/Off Shore On Well bore seg Annular Disposal Unit 11328 ~ - - - - - - - - - 18 _C.ol1ductor strin.gpJovided . . . _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19 _S_urface_CÇl~ingpJotects alLknown. USDWs _ . .NA . _ ,ð.ll aquifers exer:npted,A.D_CFR1.47.102_(b)(3). _ _ _ _ _ _ _ _ _ _ _ _ _ 20 _CMTv_oladequ_ateJo circ_utate_o_n_cond_uctor.& SUJfC$g _ _ _ _ _ _ _ _ Yes. . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 21CMT vol adequateJo tie-lnJong .string to surf csg _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ No. . . . _ ,ð.ll hydrocarbon_z~)lJes.wilt be_cJ)vered_. _ _ _ _ _ _ _ _ _ _ _ _ 22 _CMTwill coyer_all klJown_pro.ductiYe horizons_ _ _ _ _ _ _ _ No. . . . _ _ _ _ Slotted Jil1er.completlol1 plal1n.ed.. _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23C.asil1g desigl1S adequa.te fJ)r C..1, B.&_permafr.ost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 .Adequate.tankage_oJ re.ser:.ve pit _ _ _ . . . _ _ _ _ _ _ _ _ _ . . _ . . _ . _ _ _ _ _ _ _ Yes _ . . . . _ _ Rig js_equippe_d_with steel_pits. _ No rese_rve_pjtplanlJe_d, All waste to.approve~_disposal wells.. 25 Jfare·d(ilt has a 10-403 for abandon.ment beel1 aPPJoved . _ . _ _ _ . _ . NA _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ 26 _Adequate.wellbore ~eparatjon-Pfoposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y_es _ _ _ _ _ _ _ prJ)ximlty analysis pertorme.d, Close apPJoache_sjctentjfied._ Gyros po_ssib1e._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jfdivecteueq_uired, does jt meet reguJations_ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ . _ _ _ _ _ Yes . _ . . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 28 _DrillilJgflujd_prog.ramschematic_&equipJistadequate_ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ yes.... _ _Bl:Il='expectectuptojO.3EMW.PlannedMWlO.5ppgjnSBan_djnterlJ1ediatehole._ _ _ _ _ _ _ _ __ 129 BOPE$,do_they meetreguJatiol1 _ . _ _ _ _ _ Y.es _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 130 _B_OPE_pressratil1g appropriate; _testto _(pu.t psig in_comments) _ _ _ _ _ Yes. . . _ M,A.SI=' calculate.dat 197.0 psi. 30QOpsiJest pœssure. proposed_. . H .day sched_ule_ requested. _ _ _ _ 31 Choke manifold compJies w/APLRp-53(May 84) Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 Work will occ.ur withoutoperation_shutdown. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes. . 33 Js pres.ence_ of H2S gas_ probable _ _ . _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ 34 MechanicaLcolJdjUol1 J){ wells within ,ð.OR yeritied (For service well onJy). . . . . . . _ . _ _ _ _ _ NA - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ _ MP Hp_ad is_n.ot knJ)WIJ to have 1:12S.Rig is eql!ipped wlth sensors an.d.alaJms. _ . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 35 Permit call be iSSl!ed wfo' hydrogen sulfide measures _ _ _ _ _ Yes. _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 36 _D_ata_PJeselJtedon_pote_ntialoveJpres_sure_zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes. _... _ . Expectedœservojrpre$sure i$ 10.3jn.N Sal1ds&7Jiil1 o Sands; pi alJnedmudweighti~10_.5 ppg._ _. _ _ _ _.. 37Selsmicanalysjs of sbaJlow gaszolJes . _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ Shallow by.drate_s_have_ beelJ encounterect on_I:I·Pad. di$cu_ssedJIJ Orimn9Hazards sectjon 38 .SeabedcondjtiJ)1J survey _(if off·sh_ore) _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ . . _ _ _ _ _ _ . . _ . _ _ _ _ . . . 39 _ Conta_ct l1amelphon.eJor_weekly progress_reports [exploratoryol1ly] . . . . NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ Date: Engineering Commissioner: /~/ÍJ Date Date 1018/9-- D D . e e 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 Drilling Services LIS Scan Utility . ;¿Otf-/?O $Revision: 3 $ LisLib $Revision: 4 $ Wed Nov 24 09:14:28 2004 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/24 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. . . . . . . . . . . . . . . . . . . . .04/11/24 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 Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003330703 T. MCGUIRE E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003330703 C.A. DEMOSKI D. GREEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 MW0003330703 C.A. DEMOSKI D. GREEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) ¥ ) ~ q š1 MPH-16 500292322700 B.P Exploration (Alaska) Inc. Sperry-Sun Drilling Services 24-NOV-04 MWD RUN 2 MW0003330703 T. MCGUIRE E. VAUGHN MWD RUN 3 MW0003330703 C.A. DEMOSKI E. VAUGHN MWD RUN 5 MW0003330703 C.A. DEMOSKI D. GREEN MWD RUN 6 MW0003330703 C.A. DEMOSKI D. GREEN MWD RUN 8 MW0003330703 C.A. DEMOSKI D. GREEN 34 l3N 10E 2969 4003 . . KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 70.25 36.20 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 13.500 9.875 6.750 CASING SIZE (IN) 20.000 10.750 7.625 DRILLERS DEPTH (FT) 112.0 4182.0 6515.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK, EXITING FROM MPH-16 PB3 AT 9245'MD/ 4002'TVD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 3 - 8 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 4 - 8 ALSO INCLUDED AT-BIT INCLINATION (ABI) AND PRESSURE WHILE DRILLING (PWD). 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 11/2/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 8 REPRESENT WELL MPH-16 WITH API#: 50-029-23227-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9967'MD/4006'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 (SEDP). SLIDE = NON-ROTATED INTERVALS. $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation. ......04/11/24 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 FET RPD RPM RPS RPX $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 67.5 112.5 4165.0 4165.0 4165.0 4165.0 4165.0 STOP DEPTH 9911.5 9966.5 9918.5 9918.5 9918.5 9918.5 9918.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 67.5 3121. 0 MWD 2 3121. 0 4190.0 MWD 3 4190.0 6525.0 MWD 4 6525.0 6937.0 MWD 5 6937.5 8094.0 MWD 6 8094.5 9245.0 MWD 7 9245.0 9396.0 MWD 8 9396 . 0 9966.5 $ # REMARKS: MERGED MAIN PASS. $ # 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 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67.5 9966.5 5017 19799 67.5 9966.5 ROP MWD FT/H 0.81 2682.94 177.339 19709 112.5 9966.5 GR MWD API 18.06 132.09 67.336 19689 67.5 9911.5 RPX MWD OHMM 0.06 2000 14.7469 11508 4165 9918.5 RPS MWD OHMM 2.45 2000 14.9636 11508 4165 9918.5 · .4165 RPM MWD OHMM 1.14 2000 24.046 11508 9918.5 RPD MWD OHMM 0.32 2000 25.8609 11508 4165 9918.5 FET MWD HOUR 0.15 45.7 1. 30272 11508 4165 9918.5 First Reading For Entire File........ ..67.5 Last Reading For Entire File... ....... .9966.5 File Trailer Service name...... ...... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...04/11/24 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..... ..04/11/24 Maximum Physical Record. .65535 File Type... ........ ... ..LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 67.5 112.5 STOP DEPTH 3076.0 3121.0 # 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: 16-0CT-04 Insite 66.37 Memory 3121. 0 112.0 3121.0 .8 62.2 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 061497 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13.500 112.0 # . 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 MWD010 GR MWD010 Size 4 4 4 Units FT FT/H API Nsam Rep 1 68 1 68 1 68 Code . Water 9.50 155.0 9.0 300 8.8 Based .000 .000 .000 .000 .0 75.2 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67.5 3121 1594.25 6108 67.5 3121 ROP MWD010 FT/H 2.22 1880.94 152.698 6018 112.5 3121 GR MWD010 API 21.3 117.07 66.5853 6018 67.5 3076 First Reading For Entire File......... .67.5 Last Reading For Entire File......... ..3121 File Trailer Service name... ......... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/24 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...... .04/11/24 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 . header data for each bit run in separate files. 2 .5000 START DEPTH 3076.5 3121. 5 STOP DEPTH 4145.0 4190.0 # 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 (TOP 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: $ 17-0CT-04 Insite 66.37 Memory 4190.0 3121. 0 4190.0 57.7 62.5 TOOL NUMBER 061497 13.500 112.0 Spud Mud 9.70 80.0 8.0 300 8.4 .000 .000 .000 .000 .0 86.0 .0 .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 Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD020 MWD020 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3076.5 4190 3633.25 2228 3076.5 4190 ROP MWD020 FT/H 11. 36 417.43 210.663 2138 3121. 5 4190 GR MWD020 API 18.06 132.09 70.5159 2138 3076.5 4145 First Reading For Entire File...... ....3076.5 Last Reading For Entire File... ....... .4190 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation...... .04/11/24 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...... .04/11/24 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 GR RPS RPX RPM RPD 4 header data for each bit run in separate files. 3 .5000 START DEPTH 4145.5 4165.0 4165.0 4165.0 4165.0 STOP DEPTH 6488.0 6480.5 6480.5 6480.5 6480.5 . FET ROP $ 4165.0 4190.5 6480.5 6525.0 # 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 (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # 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 MWD030 GR MWD030 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code . 20-0CT-04 Insite 66.37 Memory 6525.0 4190.0 6525.0 58.3 82.3 TOOL NUMBER 124724 127479 9.875 4182.0 LSND 10.50 53.0 9.0 400 7.4 3.000 1. 660 4.500 4.700 65.0 123.2 65.0 65.0 Offset o 4 8 Channel 1 2 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4145.5 6525 5335.25 4760 4145.5 6525 ROP MWD030 FT/H 0.81 492.65 180.301 4670 4190.5 6525 GR MWD030 API 20.44 116.95 67.0718 4686 4145.5 6488 RPX MWD030 OHMM 0.06 68.1 9.37903 4632 4165 6480.5 RPS MWD030 OHMM 2.45 2000 10.8722 4632 4165 6480.5 RPM MWD030 OHMM 2.53 2000 14.0548 4632 4165 6480.5 RPD MWD030 OHMM 0.32 2000 18.2095 4632 4165 6480.5 FET MWD030 HOUR 0.15 45.63 1.03226 4632 4165 6480.5 First Reading For Entire File.......... 41415.5 Last Reading For Entire File.......... .652~ File Trailer Service name...... .......STSLIB.004 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation...... .04/11/24 Maximum Physical Record..65535 File Type..... ......... ..LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name....... ..... .STSLIB.005 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/11/24 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 6481. 0 6481.0 6481. 0 6481.0 6481. 0 6488.5 6525.5 STOP DEPTH 6937.0 6937.0 6937.0 6937.0 6937.0 6937.0 6937.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE 22-OCT-04 . 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 EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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): 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 Insite 66.37 Memory 6937.0 6525.0 6937.0 . 87.1 95.3 TOOL NUMBER 62456 130910 6.750 6515.0 Versa Pro 10.50 67.0 .0 40000 .0 .000 .000 .000 .000 .0 116.6 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6481 6937 6709 913 6481 6937 ROP MWD040 FT/H 5.86 331.7 208.35 824 6525.5 6937 GR MWD040 API 33.84 84.08 58.661 898 6488.5 6937 RPX MWD040 OHMM 7.12 2000 24.4729 913 6481 6937 RPS MWD040 OHMM 8.12 1891.67 25.0107 913 6481 6937 RPM MWD040 OHMM 1.14 2000 122.123 913 6481 6937 RPD MWD040 OHMM 7.82 2000 126.834 913 6481 6937 FET MWD040 HOUR 0.21 45.7 5.09331 913 6481 6937 First Reading For Entire File......... .6481 Last Reading For Entire File... ....... .6937 File Trailer Service name........... ..STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/11/24 Maximum Physical Record..65535 File Type................ LO Next File Name... ....... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name. . . Version Number......... ..1.0.0 Date of Generation..... ..04/11/24 Maximum Physical Record..65535 File Type.. .... ..... ... ..LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS ROP RPX $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 6937.5 6937.5 6937.5 6937.5 6937.5 6937.5 6937.5 STOP DEPTH 8094.0 8094.0 8094.0 8094.0 8094.0 8094.0 8094.0 # 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): 23-0CT-04 Insite 66.37 Memory 8094.0 6937.0 8094.0 . HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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): 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... ..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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 87.5 102.1 TOOL NUMBER 62456 130910 6.750 6515.0 Versa Pro 10.50 61. 0 .0 36000 .0 .000 .000 .000 .000 .0 116.6 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6937.5 8094 7515.75 2314 6937.5 8094 ROP MWD050 FT/H 2.67 348.77 183.225 2314 6937.5 8094 GR MWD050 API 42.71 88.46 62.3252 2314 6937.5 8094 RPX MWD050 OHMM 8.03 1645 19.4638 2314 6937.5 8094 · .37.5 RPS MWD050 OHMM 8.32 2000 19.3162 2314 8094 RPM MWD050 OHMM 9.09 1544.85 18.4286 2314 6937.5 8094 RPD MWD050 OHMM 10.26 11 7.04 17.1896 2314 6937.5 8094 FET MWD050 HOUR 0.24 8.56 0.50497 2314 6937.5 8094 First Reading For Entire File... ...... .6937.5 Last Reading For Entire File.......... .8094 File Trailer Service name... ....... ...STSLIB.006 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .04/11/24 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . .LO Next File Name. ....... ...STSLIB.007 Physical EOF File Header Service name. .......... ..STSLIB.007 Service Sub Level Name... Version Number.... ..... ..1.0.0 Date of Generation...... .04/11/24 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name.. .....STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPS ROP FET RPX RPM RPD GR $ 7 header data for each bit run in separate files. 6 .5000 START DEPTH 8094.5 8094.5 8094.5 8094.5 8094.5 8094.5 8094.5 STOP DEPTH 9245.0 9245.0 9245.0 9245.0 9245.0 9245.0 9245.0 # 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: 24-0CT-04 Insite 66.37 Memory 9245.0 8094.0 9245.0 86.6 94.7 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY TOOL NUMBER 62456 . EWR4 $ 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): 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 130910 . 6.750 6515.0 Versapro 10.50 58.0 .0 45000 .0 .000 .000 .000 .000 .0 116.6 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8094.5 9245 8669.75 2302 8094.5 9245 ROP MWD060 FT/H 1.46 345.98 187.782 2302 8094.5 9245 GR MWD060 API 37.39 113.27 72.7793 2302 8094.5 9245 RPX MWD060 OHMM 3.81 1791.37 14.8722 2302 8094.5 9245 RPS MWD060 OHMM 3.97 214.64 13.2914 2302 8094.5 9245 RPM MWD060 OHMM 4.19 1381.33 14.6258 2302 8094.5 9245 RPD MWD060 OHMM 4.44 1379.41 14.7452 2302 8094.5 9245 FET MWD060 HOUR 0.21 15.67 0.6002 2302 8094.5 9245 First Reading For Entire File........ ..8094.5 . Last Reading For Entire File.. ........ .9245 . File Trailer Service name...... ..... ..STSLIB.007 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation... ....04/11/24 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.008 Physical EOF File Header Service name............ .STSLIB.008 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation... ... .04/11/24 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPD RPM GR ROP FET $ 8 header data for each bit run in separate files. 7 .5000 START DEPTH 9196 . 5 9196 . 5 9196.5 9196.5 9245.5 9245.5 9245.5 # 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 EWR4 $ STOP DEPTH 9347.5 9347.5 9347.5 9347.5 9340.5 9396.0 9347.5 24-0CT-04 Insite 66.37 Memory 9396.0 9245.0 9396.0 81.5 85.9 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 62456 130910 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # 6.750 6515.0 . 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-t)~e...O . Versa Pro 10.50 58.0 .0 45000 .0 .000 .000 .000 .000 .0 116.6 .0 .0 Name Service Order Units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9196.5 9396 9296.25 400 9196 . 5 9396 ROP MWD070 FT/H 3.41 578.82 168.253 302 9245.5 9396 GR MWD070 API 52.21 96.6 71.8443 191 9245.5 9340.5 RPX MWD070 OHMM 4.3 28.67 13 .1239 303 9196.5 9347.5 RPS MWD070 OHMM 4.66 32.61 13.4716 303 9196.5 9347.5 RPM MWD070 OHMM 4.85 32.83 13.9309 303 9196.5 9347.5 RPD MWD070 OHMM 5.79 29.55 14.5824 303 9196.5 9347.5 FET MWD070 HOUR 0.32 5.86 1.13795 205 9245.5 9347.5 First Reading For Entire File......... .9196.5 Last Reading For Entire File.......... .9396 File Trailer Service name............ .STSLIB.008 Service Sub Level Name... Version Number. ....... ...1.0.0 . Date of Generation...... .04/11/24 Maximum Physical Record. .65535 File Type................ LO Next File Name......... ..STSLIB.009 Physical EOF File Header Service name........... ..STSLIB.009 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation.... ...04/11/24 Maximum Physical Record. .65535 File Type........ ... .... .LO Previous File Name.... ...STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 9 . header data for each bit run in separate files. 8 .5000 START DEPTH 9341.0 9348.0 9348.0 9348.0 9348.0 9348.0 9396.5 # 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: # STOP DEPTH 9911.5 9918.5 9918.5 9918.5 9918.5 9918.5 9966.5 25-0CT-04 Insite 66.37 Memory 9967.0 9396.0 9967.0 87.5 94.5 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 87224 156401 # 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): 6.750 6515.0 Versa Pro 10.50 56.0 .0 48000 .0 . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: . .000 .000 .000 .000 .0 116.6 .0 .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 MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9341 9966.5 9653.75 1252 9341 9966.5 ROP MWD080 FT/H 1. 36 2682.94 179.74 1141 9396 . 5 9966.5 GR MWD080 API 45.07 102.26 71. 6705 1142 9341 9911. 5 RPX MWD080 OHMM 4.8 52.25 19.1188 1142 9348 9918.5 RPS MWD080 OHMM 4.77 41.06 18.266 1142 9348 9918.5 RPM MWD080 OHMM 4.92 38.17 18.3082 1142 9348 9918.5 RPD MWD080 OHMM 5.68 32.68 18.1816 1142 9348 9918.5 FET MWD080 HOUR 0.33 20.48 2.4314 1142 9348 9918.5 First Reading For Entire File...... ....9341 Last Reading For Entire File....... ....9966.5 File Trailer Service name.. ......... ..STSLIB.009 Service Sub Level Name... Version Number.. ....... ..1.0.0 Date of Generation..... ..04/11/24 Maximum Physical Record..65535 File Type................ LO Next File Name.. '" ......STSLIB.010 . . Physical EOF Tape Trailer Service name. ........ ....LISTPE Date.................... .04/11/24 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. . . . . . . . . . . . . . . . . . . . .04/11/24 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 . Sperry-Sun Drilling Services LIS Scan Utility . óZtfJ c¡ - II éJ $Revision: 3 $ LisLib $Revision: 4 $ Tue Nov 23 11:09:14 2004 Reel Header Service name...... ...... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/23 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. . . . . . . . . . . . . . . . . . . . .04/11/23 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 Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPH-16 PB3 500292322772 B.P Exploration (Alaska) Inc. Sperry-Sun Drilling Services 23 -NOV-04 -:If )d- c¡ )'6 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003330703 T. MCGUIRE E. VAUGHN MWD RUN 2 MW0003330703 T. MCGUIRE EDDIE VAUGHN MWD RUN 3 MW0003330703 C.A. DEMOSKI E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003330703 C.A. DEMOSKI D. GREEN MWD RUN 5 MW0003330703 C.A. DEMOSKI D. GREEN MWD RUN 6 MW0003330703 C.A. DEMOSKI D. GREEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 34 13N 10E 2969 4003 70.25 36.20 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 13.500 9.875 6.750 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 112.0 4182.0 6515.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK, EXITING FROM MPH-16 PB2 AT 8094'MD/ 4024'TVD. MPH-16 EXITS FROM THIS WELLBORE AT 9245'MD/4002'TVD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 3 - 6 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 4 - 6 ALSO INCLUDED AT-BIT INCLINATION (ABI) AND PRESSURE WHILE DRILLING (PWD). 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 11/2/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 6 REPRESENT WELL MPH-16 PB3 WITH API#: 50-029-23227-72. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9482'MD/3998'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 (SEDP). SLIDE = NON-ROTATED INTERVALS. $ File Header Service name........ .... .STSLIB.001 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation..... ..04/11/23 Maximum Physical Record. .65535 File Type............... .LO Previous File Name... ....STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 . . # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ START DEPTH 67.5 112.5 4165.0 4165.0 4165.0 4165.0 4165.0 STOP DEPTH 9425.5 9480.0 9246.5 9432.5 9432.5 9432.5 9432.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 67.5 3121.0 MWD 2 3121. 0 4190.0 MWD 3 4190.0 6525.0 MWD 4 6525.0 6937.0 MWD 5 6937.5 8094.0 MWD 6 8094.5 9480.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67.5 9480 4773.75 18826 67.5 9480 ROP MWD FT/H 0.81 1880.94 177.034 18736 112.5 9480 GR MWD API 18.06 132.09 67.0526 18717 67.5 9425.5 RPX MWD OHMM 0.06 2000 14.355 10536 4165 9432.5 RPS MWD OHMM 2.45 2000 14.6859 10536 4165 9432.5 RPM MWD OHMM 1.14 2000 24.6201 10536 4165 9432.5 RPD MWD OHMM 0.32 2000 26.62 10536 4165 9432.5 FET MWD HOUR 0.15 45.7 1.17902 10164 4165 9246.5 First Reading For Entire File. ........ .67.5 . ... Last Readlng For Entlre Flle..... ......9480 . File Trailer Service name.......... ...STSLIB.001 Service Sub Level Name... Version Number.. .........1.0.0 Date of Generation...... .04/11/23 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..... ..04/11/23 Maximum Physical Record. .65535 File Type... .......... ...LO Previous File Name.... ...STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 67.5 112.5 STOP DEPTH 3076.0 3121. 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: 16-0CT-04 Insite 66.37 Memory 3121. 0 112.0 3121. 0 .8 62.2 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 061497 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13.500 112.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): Water Based 9.50 155.0 9.0 300 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: . 8.8 . .000 .0 .000 75.2 .000 .0 .000 .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.. ...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 DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67.5 3121 1594.25 6108 67.5 3121 ROP MWD010 FT/H 2.22 1880.94 152.698 6018 112.5 3121 GR MWD010 API 21.3 117.07 66.5853 6018 67.5 3076 First Reading For Entire File..........67.5 Last Reading For Entire File..... ......3121 File Trailer Service name..... ...... ..STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/23 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..... ..04/11/23 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 . header data for each bit run in separate files. 2 .5000 START DEPTH 3076.5 3121. 5 STOP DEPTH 4145.0 4190.0 # 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 (TOP 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........... .......0 Data Specification Block Type.....O Logging Direction......... ........Down Optical log depth units.......... .Feet 17-0CT-04 Insite 66.37 Memory 4190.0 3121. 0 4190.0 57.7 62.5 TOOL NUMBER 061497 13.500 112.0 Spud Mud 9.70 80.0 8.0 300 8.4 .000 .000 .000 .000 .0 86.0 .0 .0 . Data Reference Point.. ........... . Undefined Frame Spacing......... ........ ....60 .1IN Max frames per record.. ..... ......Undefined Absent value................... ...-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Service Order Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD020 MWD020 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3076.5 4190 3633.25 2228 3076.5 4190 ROP MWD020 FT/H 11.36 417.43 210.663 2138 3121. 5 4190 GR MWD020 API 18.06 132.09 70.5159 2138 3076.5 4145 First Reading For Entire File.. ....... .3076.5 Last Reading For Entire File.......... .4190 File Trailer Service name......... ... .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.... ...04/11/23 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..... ..04/11/23 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 GR FET RPD RPM RPS RPX ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 4145.5 4165.0 4165.0 4165.0 4165.0 4165.0 4190.5 STOP DEPTH 6488.0 6480.5 6480.5 6480.5 6480.5 6480.5 6525.0 # LOG HEADER DATA DATE LOGGED: 20-0CT-04 . 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 EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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): 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 . Insite 66.37 Memory 6525.0 4190.0 6525.0 58.3 82.3 TOOL NUMBER 124724 127479 9.875 4182.0 LSND 10.50 53.0 9.0 400 7.4 3.000 1.660 4.500 4.700 65.0 123.2 65.0 65.0 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 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4145.5 6525 5335.25 4760 4145.5 6525 ROP MWD030 FT/H 0.81 492.65 180.301 4670 4190.5 6525 GR MWD030 API 20.44 116.95 67.0718 4686 4145.5 6488 RPX MWD030 OHMM 0.06 68.1 9.37903 4632 4165 6480.5 RPS MWD030 OHMM 2.45 2000 10.8722 4632 4165 6480.5 RPM MWD030 OHMM 2.53 2000 14.0548 4632 4165 6480.5 RPD MWD030 OHMM 0.32 2000 18.2095 4632 4165 6480.5 FET MWD030 HOUR 0.15 45.63 1.03226 4632 4165 6480.5 First Reading For Entire File. ........ .4145.5 Last Reading For Entire File.......... .6525 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation. ..... .04/11/23 Maximum Physical Record. .65535 File Type................ LO Next File Name....... ....STSLIB.005 Physical EOF File Header Service name....... ..... .STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation... ....04/11/23 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 6481. 0 6481.0 6481.0 6481.0 6481.0 6488.5 6525.5 STOP DEPTH 6937.0 6937.0 6937.0 6937.0 6937.0 6937.0 6937.0 # 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): 22-0CT-04 Insite 66.37 Memory 6937.0 6525.0 6937.0 . BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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): 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.. ...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 . 87.1 95.3 TOOL NUMBER 62456 130910 6.750 6515.0 Versa Pro 10.50 67.0 .0 40000 .0 .000 .000 .000 .000 .0 116.6 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6481 6937 6709 913 6481 6937 ROP MWD040 FT/H 5.86 331. 7 208.35 824 6525.5 6937 GR MWD040 API 33.84 84.08 58.661 898 6488.5 6937 . . RPX MWD040 OHMM 7.12 2000 24.4729 913 6481 6937 RPS MWD040 OHMM 8.12 1891. 67 25.0107 913 6481 6937 RPM MWD040 OHMM 1.14 2000 122.123 913 6481 6937 RPD MWD040 OHMM 7.82 2000 126.834 913 6481 6937 FET MWD040 HOUR 0.21 45.7 5.09331 913 6481 6937 First Reading For Entire File..... .....6481 Last Reading For Entire File....... ....6937 File Trailer Service name..... ....... .STSLIB.005 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation.......04/11/23 Maximum Physical Record..65535 File Type... ......... ....LO Next File Name......... ..STSLIB.006 Physical EOF File Header Service name......... ....STSLIB.006 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.... ...04/11/23 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD ROP GR RPX RPM FET RPS $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 6937.5 6937.5 6937.5 6937.5 6937.5 6937.5 6937.5 STOP DEPTH 8094.0 8094.0 8094.0 8094.0 8094.0 8094.0 8094.0 # 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: 23-0CT-04 Insite 66.37 Memory 8094.0 6937.0 8094.0 87.5 102.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR EWR4 $ . DUAL GAMMA RAY 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): 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 62456 130910 . 6.750 6515.0 Versa Pro 10.50 61. 0 .0 36000 .0 .000 .000 .000 .000 .0 116.6 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6937.5 8094 7515.75 2314 6937.5 8094 ROP MWD050 FT/H 2.67 348.77 183.225 2314 6937.5 8094 GR MWD050 API 42.71 88.46 62.3252 2314 6937.5 8094 RPX MWD050 OHMM 8.03 1645 19.4638 2314 6937.5 8094 RPS MWD050 OHMM 8.32 2000 19.3162 2314 6937.5 8094 RPM MWD050 OHMM 9.09 1544.85 18.4286 2314 6937.5 8094 RPD MWD050 OHMM 10.26 117.04 17.1896 2314 6937.5 8094 FET MWD050 HOUR 0.24 8.56 0.50497 2314 6937.5 8094 . First Reading For Entire File.. ....... .6937.5 Last Reading For Entire File.......... .8094 . File Trailer Service name.. .......... .STSLIB.006 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation... ....04/11/23 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name.... ........ .STSLIB.007 Service Sub Level Name... Version Number... ...... ..1.0.0 Date of Generation..... ..04/11/23 Maximum Physical Record..65535 File Type............... .LO Previous File Name... ....STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR ROP FET $ 7 header data for each bit run in separate files. 6 .5000 START DEPTH 8094.5 8094.5 8094.5 8094.5 8094.5 8094.5 8094.5 STOP DEPTH 9432.5 9432.5 9432.5 9432.5 9425.5 9480.0 9246.5 # 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: 24-0CT-04 Insite 66.37 Memory 9482.0 8094.0 9482.0 86.6 94.7 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 62456 130910 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 6515.0 # . 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 . Versapro 10.50 58.0 .0 45000 .0 .000 .000 .000 .000 .0 116.6 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8094.5 9480 8787.25 2772 8094.5 9480 ROP MWD060 FT/H 1.46 345.98 183.952 2772 8094.5 9480 GR MWD060 API 37.39 114.57 72.2317 2663 8094.5 9425.5 RPX MWD060 OHMM 3.81 1791.37 15.098 2677 8094.5 9432.5 RPS MWD060 OHMM 3.97 214 . 64 13.7612 2677 8094.5 9432.5 RPM MWD060 OHMM 4.19 1381.33 14.9994 2677 8094.5 9432.5 RPD MWD060 OHMM 4.44 1379.41 15.1461 2677 8094.5 9432.5 FET MWD060 HOUR 0.21 15.67 0.600174 2305 8094.5 9246.5 First Reading For Entire File..... .....8094.5 Last Reading For Entire File...... .....9480 File Trailer Service name..... ....... .STSLIB.007 Service Sub Level Name... ,. . Version Number.......... .1.0.0 Date of Generation... ....04/11/23 Maximum Physical Record..65535 File Type....... ........ .LO Next File Name.......... .STSLIB.OOB . Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/23 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. . . . . . . . . . . . . . . . . . . . .04/11/23 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 . Sperry-Sun Drilling Services LIS Scan Utility . õ(olf-/9o $Revision: 3 $ LisLib $Revision: 4 $ Tue Nov 23 10:39:48 2004 Reel Header Service name........ .....LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/23 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. . . . . . . . . . . . . . . . . . . . .04/11/23 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 Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA \~q)7 MPH-16 PB2 500292322771 B.P Exploration (Alaska) Inc. Sperry-Sun Drilling Services 23 -NOV - 04 1i JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003330703 T. MCGUIRE E. VAUGHN MWD RUN 2 MW0003330703 T. MCGUIRE EDDIE VAUGHN MWD RUN 3 MW0003330703 C.A. DEMOSKI E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003330703 C.A. DEMOSKI D. GREEN MWD RUN 5 MW0003330703 C.A. DEMOSKI D. GREEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 34 13N 10E 2969 4003 MSL 0) 70.25 36.20 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 13.500 9.875 6.750 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 112.0 4182.0 6515.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK, EXITING FROM MPH-16 PBl AT 6937'MD/ 4055'TVD. MPH-16 PB3 EXITS FROM THIS WELLBORE AT 8094'MD/4024'TVD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 3 - 5 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 4 & 5 ALSO INCLUDED AT-BIT INCLINATION (ABI) AND PRESSURE WHILE DRILLING (PWD). 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 11/2/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 5 REPRESENT WELL MPH-16 PB2 WITH API#: 50-029-23227-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8882'MD/3966'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 (SEDP). SLIDE = NON-ROTATED INTERVALS. $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/23 Maximum Physical Record. .65535 File Type.......... ..... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ . START DEPTH 67.5 112.5 4165.0 4165.0 4165.0 4165.0 4165.0 STOP DEPTH 8826.5 8882.5 8833.5 8833.5 8833.5 8833.5 8833.5 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 5 MERGED MAIN PASS. $ MERGE TOP 67.5 3121.0 4190.0 6525.0 6937.5 MERGE BASE 3121. 0 4190.0 6525.0 6937.0 8882.5 # 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 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 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR MWD MWD MWD MWD MWD MWD MWD Min 67.5 0.81 18.06 0.06 2.45 1.14 0.32 0.15 Max 8882.5 1880.94 132.09 2000 2000 2000 2000 45.7 Mean 4475 176.675 67.0889 13 . 1589 13.9379 24.8257 27.0888 1. 24572 Nsam 17631 17541 17519 9338 9338 9338 9338 9338 First Reading For Entire File. ........ .67.5 Last Reading For Entire File........ ...8882.5 First Reading 67.5 112.5 67.5 4165 4165 4165 4165 4165 Last Reading 8882.5 8882.5 8826.5 8833.5 8833.5 8833.5 8833.5 8833.5 . . File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/11/23 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...... .04/11/23 Maximum Physical Record. .65535 File Type......... ...... .LO Previous File Name... ....STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 67.5 112.5 STOP DEPTH 3076.0 3121. 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: 16 -OCT- 04 Insite 66.37 Memory 3121. 0 112.0 3121.0 .8 62.2 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 061497 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13.500 112.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): Water Based 9.50 155.0 9.0 300 8.8 . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: . .000 .000 .000 .000 .0 75.2 .0 .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 DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67.5 3121 1594.25 6108 67.5 3121 ROP MWD010 FT/H 2.22 1880.94 152.698 6018 112.5 3121 GR MWD010 API 21.3 117.07 66.5853 6018 67.5 3076 First Reading For Entire File...... ....67.5 Last Reading For Entire File.......... .3121 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/23 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...... .04/11/23 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 . header data for each bit run in separate files. 2 .5000 START DEPTH 3076.5 3121.5 STOP DEPTH 4145.0 4190.0 # 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 (TOP 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................ ..0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point... ...... ... ..Undefined 17-0CT-04 Insite 66.37 Memory 4190.0 3121.0 4190.0 57.7 62.5 TOOL NUMBER 061497 13.500 112.0 Spud Mud 9.70 80.0 8.0 300 8.4 .000 .000 .000 .000 .0 86.0 .0 .0 . Frame Spacing.............. ...... .60 .1IN Max frames per record...... ...... . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . 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 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3076.5 4190 3633.25 2228 3076.5 4190 ROP MWD020 FT/H 11. 36 417.43 210.663 2138 3121. 5 4190 GR MWD020 API 18.06 132.09 70.5159 2138 3076.5 4145 First Reading For Entire File. ........ .3076.5 Last Reading For Entire File...... .....4190 File Trailer Service name...... ...... .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .04/11/23 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...... .04/11/23 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 GR RPS FET RPD RPX RPM ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 4145.5 4165.0 4165.0 4165.0 4165.0 4165.0 4190.5 STOP DEPTH 6488.0 6480.5 6480.5 6480.5 6480.5 6480.5 6525.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE 20-0CT-04 . 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 EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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): 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 Insite 66.37 Memory 6525.0 4190.0 6525.0 . 58.3 82.3 TOOL NUMBER 124724 127479 9.875 4182.0 LSND 10.50 53.0 9.0 400 7.4 3.000 1.660 4.500 4.700 65.0 123.2 65.0 65.0 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 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4145.5 6525 5335.25 4760 4145.5 6525 ROP MWD030 FT/H 0.81 492.65 180.301 4670 4190.5 6525 GR MWD030 API 20.44 116.95 67.0718 4686 4145.5 6488 RPX MWD030 OHMM 0.06 68.1 9.37903 4632 4165 6480.5 RPS MWD030 OHMM 2.45 2000 10.8722 4632 4165 6480.5 RPM MWD030 OHMM 2.53 2000 14.0548 4632 4165 6480.5 RPD MWD030 OHMM 0.32 2000 18.2095 4632 4165 6480.5 FET MWD030 HOUR 0.15 45.63 1.03226 4632 4165 6480.5 First Reading For Entire File..........4145.5 Last Reading For Entire File.......... .6525 File Trailer Service name........ .... .STSLIB.004 Service Sub Level Name. . . Version Number... ...... ..1.0.0 Date of Generation...... .04/11/23 Maximum Physical Record..65535 File Type........... .... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name....... ..... .STSLIB.005 Service Sub Level Name. . . Version Number... ........1.0.0 Date of Generation...... .04/11/23 Maximum Physical Record..65535 File Type........... .... .LO Previous File Name..... ..STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM FET RPD GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 6481. 0 6481.0 6481. 0 6481. 0 6481.0 6488.5 6525.5 STOP DEPTH 6937.0 6937.0 6937.0 6937.0 6937.0 6937.0 6937.0 # 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): 22-0CT-04 Insite 66.37 Memory 6937.0 6525.0 6937.0 . HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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): 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 . 87.1 95.3 TOOL NUMBER 62456 130910 6.750 6515.0 Versa Pro 10.50 67.0 .0 40000 .0 .000 .000 .000 .000 .0 116.6 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6481 6937 6709 913 6481 6937 ROP MWD040 FT/H 5.86 331.7 208.35 824 6525.5 6937 GR MWD040 API 33.84 84.08 58.661 898 6488.5 6937 RPX MWD040 OHMM 7.12 2000 24.4729 913 6481 6937 . . 6481 RPS MWD040 OHMM 8.12 1891. 67 25.0107 913 6937 RPM MWD040 OHMM 1.14 2000 122.123 913 6481 6937 RPD MWD040 OHMM 7.82 2000 126.834 913 6481 6937 FET MWD040 HOUR 0.21 45.7 5.09331 913 6481 6937 First Reading For Entire File..... .....6481 Last Reading For Entire File......... ..6937 File Trailer Service name......... ... .STSLIB.005 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation.......04/11/23 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number... ... .....1.0.0 Date of Generation.... ...04/11/23 Maximum Physical Record..65535 File Type............... .LO Previous File Name. ..... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP RPD RPM RPS RPX GR FET $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 6937.5 6937.5 6937.5 6937.5 6937.5 6937.5 6937.5 STOP DEPTH 8882.5 8833.5 8833.5 8833.5 8833.5 8826.5 8833.5 # 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: 23-0CT-04 Insite 66.37 Memory 8882.0 6937.0 8882.0 87.5 102.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY TOOL NUMBER 62456 EWR4 $ . 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): 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 130910 . 6.750 6515.0 Versa Pro 10.50 61. 0 .0 36000 .0 .000 .000 .000 .000 .0 116.6 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6937.5 8882.5 7910 3891 6937.5 8882.5 ROP MWD050 FT/H 1.8 473.49 184.024 3891 6937.5 8882.5 GR MWD050 API 42.71 105.63 67.976 3779 6937.5 8826.5 RPX MWD050 OHMM 3.92 1645 15.0515 3793 6937.5 8833.5 RPS MWD050 OHMM 4.02 2000 15.0166 3793 6937.5 8833.5 RPM MWD050 OHMM 4.04 1544.85 14.559 3793 6937.5 8833.5 RPD MWD050 OHMM 4.76 117.04 13.923 3793 6937.5 8833.5 FET MWD050 HOUR 0.24 8.56 0.580266 3793 6937.5 8833.5 First Reading For Entire File..... .....6937.5 . Last Reading For Entire File.......... .8882.5 . File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation.......04/11/23 Maximum Physical Record..65535 File Type.............. ..LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name......... ... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/23 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. . . . . . . . . . . . . . . . . . . . .04/11/23 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 . Sperry-Sun Drilling Services LIS Scan Utility . }01-11û $Revision: 3 $ LisLib $Revision: 4 $ Tue Nov 23 10:01:49 2004 Reel Header Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/23 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. . . . . . . . . . . . . . . . . . . . .04/11/23 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 Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPH-16 PB1 500292322770 B.P Exploration (Alaska) Inc. Sperry-Sun Drilling Services 23-NOV-04 if p. q)~ JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003330703 T. MCGUIRE E. VAUGHN MWD RUN 2 MW0003330703 T. MCGUIRE EDDIE VAUGHN MWD RUN 3 MW0003330703 C.A. DEMOSKI E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003330703 C.A. DEMOSKI D. GREEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 34 13N 10E 2969 4003 70.25 36.20 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 13.500 9.875 6.750 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 112.0 4182.0 6515.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MPH-16 PB2 EXITS FROM THIS WELLBORE AT 6937'MD/4055'TVD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 3 & 4 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 4 ALSO INCLUDED AT-BIT INCLINATION (ABI) AND PRESSURE WHILE DRILLING (PWD). 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 11/2/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 4 REPRESENT WELL MPH-16 PB1 WITH API#: 50-029-23227-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7376'MD/4019'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 (SEDP). SLIDE = NON-ROTATED INTERVALS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/11/23 Maximum Physical Record. .65535 File Type..... ...... .....LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ . START DEPTH 67.5 112.5 4165.0 4165.0 4165.0 4165.0 4165.0 STOP DEPTH 7320.5 7376.5 7327.5 7327.5 7327.5 7327.5 7327.5 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 MERGED MAIN PASS. $ MERGE TOP 67.5 3121.0 4190.0 6525.0 MERGE BASE 3121. 0 4190.0 6525.0 7376.5 # 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67.5 7376.5 3722 14619 67.5 7376.5 ROP MWD FT/H 0.81 1880.94 175.546 14529 112.5 7376.5 GR MWD API 18.06 132.09 67.5152 14507 67.5 7320.5 RPX MWD OHMM 0.06 2000 11.4885 6326 4165 7327.5 RPS MWD OHMM 2.45 2000 12.6523 6326 4165 7327.5 RPM MWD OHMM 1.14 2000 29.0191 6326 4165 7327.5 RPD MWD OHMM 0.32 2000 32.7921 6326 4165 7327.5 FET MWD HOUR 0.15 45.7 1. 55625 6326 4165 7327.5 First Reading For Entire File..........67.5 Last Reading For Entire File........ ...7376.5 File Trailer . Service name...... .......STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.... ...04/11/23 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..... ..04/11/23 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 67.5 112.5 STOP DEPTH 3076.0 3121.0 # 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 (TOP 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: 16-0CT-04 Insite 66.37 Memory 3121. 0 112.0 3121.0 .8 62.2 TOOL NUMBER 061497 13.500 112.0 Water Based 9.50 155.0 9.0 300 8.8 .000 .0 .000 75.2 . MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 . .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Da ta 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 MWD010 GR MWDOIO Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67.5 3121 1594.25 6108 67.5 3121 ROP MWD010 FT/H 2.22 1880.94 152.698 6018 112.5 3121 GR MWD010 API 21.3 117.07 66.5853 6018 67.5 3076 First Reading For Entire File......... .67.5 Last Reading For Entire File.......... .3121 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation... ....04/11/23 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..... ..04/11/23 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 . header data for each bit run in separate files. 2 .5000 START DEPTH 3076.5 3121. 5 STOP DEPTH 4145.0 4190.0 # 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 (TOP 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. ....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 17-0CT-04 Insite 66.37 Memory 4190.0 3121. 0 4190.0 57.7 62.5 TOOL NUMBER 061497 13.500 112.0 Spud Mud 9.70 80.0 8.0 300 8.4 .000 .000 .000 .000 .0 86.0 .0 .0 . Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR Service Order Nsam 1 1 1 Units FT FT/H API Size 4 4 4 MWD020 MWD020 . Rep 68 68 68 Code Channel 1 2 3 Offset o 4 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3076.5 4190 3633.25 2228 3076.5 4190 ROP MWD020 FT/H 11.36 417.43 210.663 2138 3121.5 4190 GR MWD020 API 18.06 132.09 70.5159 2138 3076.5 4145 First Reading For Entire File......... .3076.5 Last Reading For Entire File.......... .4190 File Trailer Service name..... ........STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/23 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...... .04/11/23 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 GR FET RPD RPM RPS RPX ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 4145.5 4165.0 4165.0 4165.0 4165.0 4165.0 4190.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : STOP DEPTH 6488.0 6480.5 6480.5 6480.5 6480.5 6480.5 6525.0 20-0CT-04 Insite 66.37 Memory . 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 EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # 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.. ...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 6525.0 4190.0 6525.0 58.3 82.3 TOOL NUMBER 124724 127479 9.875 4182.0 LSND 10.50 53.0 9.0 400 7.4 3.000 1. 660 4.500 4.700 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 Name Service unit Min Max Mean Nsam . 65.0 123.2 65.0 65.0 First Reading Last Reading · .45.5 DEPT FT 4145.5 6525 5335.25 4760 6525 ROP MWD030 FT/H 0.81 492.65 180.301 4670 4190.5 6525 GR MWD030 API 20.44 116.95 67.0718 4686 4145.5 6488 RPX MWD030 OHMM 0.06 68.1 9.37903 4632 4165 6480.5 RPS MWD030 OHMM 2.45 2000 10.8722 4632 4165 6480.5 RPM MWD030 OHMM 2.53 2000 14.0548 4632 4165 6480.5 RPD MWD030 OHMM 0.32 2000 18.2095 4632 4165 6480.5 FET MWD030 HOUR 0.15 45.63 1.03226 4632 4165 6480.5 First Reading For Entire File......... .4145.5 Last Reading For Entire File.... ...... .6525 File Trailer Service name.. .......... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/23 Maximum Physical Record. .65535 File Type......... ..... ..LO Next File Name. ...... ....STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.. ..... ....1.0.0 Date of Generation... ....04/11/23 Maximum Physical Record. .65535 File Type............... .LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 6481.0 6481.0 6481.0 6481. 0 6481. 0 6488.5 6525.5 STOP DEPTH 7327.5 7327.5 7327.5 7327.5 7327.5 7320.5 7376.5 # 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: 22-0CT-04 Insite 66.37 Memory 7376.0 6525.0 7376.0 87.1 95.3 . # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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): 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 . TOOL NUMBER 62456 130910 6.750 6515.0 Versa Pro 10.50 67.0 .0 40000 .0 .000 .000 .000 .000 .0 116.6 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6481 7376.5 6928.75 1792 6481 7376.5 ROP MWD040 FT/H 3.28 331.7 199.159 1703 6525.5 7376.5 GR MWD040 API 33.84 117.67 68.2713 1665 6488.5 7320.5 RPX MWD040 OHMM 3.77 2000 17.2565 1694 6481 7327.5 RPS MWD040 OHMM 3.87 1891.67 17.5199 1694 6481 7327.5 RPM MWD040 OHMM 1.14 2000 69.9368 1694 6481 7327.5 RPD MWD040 OHMM 4.17 2000 72.6661 1694 6481 7327.5 FET MWD040 HOUR . 0.21 45.7 2.98902 1694 . 6481 7327.5 First Reading For Entire File......... .6481 Last Reading For Entire File.......... .7376.5 File Trailer Service name............ .STSLIB.005 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ..... .04/11/23 Maximum Physical Record..65535 File Type..... ........ ...LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/23 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. . . . . . . . . . . . . . . . . . . . .04/11/23 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