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Home My WebLink About203-147STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS v QED i !l Lei ii 1. Operations Abandon L1 Plug Perforations Ll Fracture Stimulate LJ Pull Tubing Li Operations shutdown Li Perfomred: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Place Cement Plug ❑� Plug for Redrill ❑ �rforale New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CT FCO ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 203-147 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-23176-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0380109 MILNE PT UNIT S-22 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT/ UGNU UNDEFINED OIL 11. Present Well Condition Summary: Total Depth measured 9,242 feet Plugs measured 5,212 feet true vertical 3,648 feet Junk measured N/A feet Effective Depth measured 5,212 feet Packer measured 5,083 feet true vertical 3,723 feet true vertical 3,698 feet Casing Length Size MD TVD Burst Collapse Conductor 75' 20" 110' 110' N/A N/A Surface 2,527' 10-3/4" 2,561' 2,406' 5,210psi 2,470psi Intermediate 5,183' 7-5/8" 5,216' 3,723' 6,890psi 4,790psi Production 4,166' 4" 9,242' 3,648' 7,910psi 6,590psi 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 / IBT 5,118' 3,705' Packers and SSSV (type, measured and true vertical depth) ZXP LTP 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 0 237 239 Subsequent to operation: 0 0 1 0 246 233 14. Attachments (required per 20 Aac 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations E Exploratory❑ Development ❑✓ 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: 319-343 Authorized Name: Chad Helgeson Contact Name: Ian Toomey 5� Authorized Title: Operations Manager Contact Email: itoorney%7hilcorp.com /i Authorizetl Signature: Date: 9/16/2019 Contact Phone: 777-8434 �L ( RBDMSLJSEP 19 2019 Form 10-404 Revised 4/2017 (/ Submit Original Only K Ililcora Alaska. LLC OigK& 72.00/OdgGL: 3o04(DaM 14) SCHEMATIC Milne Point Unit Well: MPU S-22 Last Completed: 10/6/2003 PTD: 203-147 TREE / WELLHEAD Tree 1 4-1/16" SM FMC Wellhead FMC 11"x4.5"5M Gen 6 w/4.5"TC-II Btm T&B. Tubing Hanger, CIW'H' BPV Profile OPEN HOLE/ CEMENT DETAIL 20" 260 sx of Arctic set In 24" Hole 10-3/4" 485 sx Class'L', 312 sx Class "G" In 13-1/2" Hole 7-5/8" 292 sx Class "G" In 9-7/8" Hole CASING DETAIL Type I Wt/ Grade/ Conn ID Top Btm BPF Conductor 1 92/H-40/N/A 1 19.124 1 Surface 110' 1 N/A Surface 45.5 / L-80 / BTC 9.950 1Surface 2,561' 0.0962 Itermediate 29.7/2.-80/IBT-M 6.875 Surface 5,989' 0.0459 LINER DETAIL Btm (MD) Top (TVD) 4" Liner 9.5/L-80/IBT-M 1 3.548 1 5,076' 9,242' N/A 4" Screened Liner 9.5 / L-80 / IBT-M 1 3.548 5,208' 9,195' N/A TUBING DETAIL 25 7/25/2004 -1/2" Tubing 12.6/L-80/IBT 1 3.958 Surface 5,118' 0.0152 TD= 9,247 (MD) /TD= 3,648' (TVD) WELL INCLINATION DETAIL KOP @ 425' MD Hole Angie Passes 50 Deg. @ 2,770' Max Angle in Tubing = 78 Deg. 73 Deg. @ Sliding Sleeve JEWELRY DETAIL th Item 4' FMC TC -SA -EMS 11" x4.5" Tubing Hanger 7' GLM: 4-1/2" x 1" KBG-2 w/ DCK-2 Shear Valve BEK Latch 5' Phoenix Discharge Pressure Gauge 3' HES 4-1/2- XD DURA Sliding Sleeve w/Centralizers - Reverse Orculatin let Pump 0' 4-1/2" Phoenix Pressure Sensor 5' HES 4-1/2" XN Nipple - MIN ID= 3.725" No-go w/ PXN Plug set 8/8/2019 6' 7-5/8" x 5.5" Uner Tieback Sleeve 3' -5/8'x 5.5" ZXP BoLTP 3' Baker 80-47 Seal re Assembly -BTM @ 5,118' 0' Crossover 5-1/2" x 4-1/2" - L-80 IBT 7' Crossover 4-1/2"x4"IBT PERFORATION DETAIL p (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status ;,460' 5,485' 3,742' 3,742' 25 7/26/2004 Open ;,690' 5,715' 3,748' 3,689' 25 7/25/2004 Open 1,920' 5,945' 3,745' 3,743' 25 7/25/2004 Open 1,150' 6,175' 3,730' 3,728' 25 7/25/2004 Open 1,380' 6,405' 3,716' 3,714' 25 7/25/2004 Open 1,610' 6,635' 3,699' 3,697' 25 7/25/2004 Open 1,890' 6,915' 3,675' 3,673' 25 7/25/2004 Open 1,300' 7,325' 3,643' 3,640' 25 7/24/2004 Open 1,825' 7,850' 3,621' 3,622' 25 12/9/2004 Open 1,000' 1 8,025' 3,624' 3,625' 25 1 12/9/2004 Open ;,380' 1 8,405' 3,629' 3,629' 25 1 12/9/2004 Open !tail: 2.5" HMX 6SPF Random Orientation. PDS tie In log 7/24/2004 GENERAL WELL INFO API: 50-029-23176-00-00 Drilled and Complete by Doyon 14 -30/6/2003 CTU Perf Add -8/13/2004 Revised By: TDF 9/16/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPS-22 Coil 50-029-23176-00-00 203-147 7/30/2019 1 9/1/2019 Daily Operations. 7/24/2019- Wednesday No operations to report. 7/25/2019 -Thursday No operations to report. 7/26/2019 - Friday No operations to report. 7/27/2019-Saturday No operations to report. 7/28/2019-Sunday No operations to report. 7/29/2019 - Monday No operations to report. 7/30/2019-Tuesday SLB Travel to MPU S-22. PTW, JSA with Field Foreman. MIRU SLB CTU # 6 with 2.0" coil. Perform BOPE test. Test all rams and valves 250/3,000 psi for 10 minutes. Make up Coil connector, DFCV, 2x stinger, Tempress Extended reach vibratory tool, x over and 1SN. Stack down on deck. Night cap installed on BOPE stack. Location walk around complete. SDFN. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig I API Number Well Permit Number Start Date End Date MP 5-22 Coil 1 50-029-23176-00-00 203-147 7/30/2019 9/1/2019 Daily Operations. 7/31/2019- Wednesday BHA: CC 2.25" OD x 1.5", Stinger 2.0" OD x 96", Stinger 2.0" OD x 96", Ball drop jet swirl nozzle 2.5" OD x 7". Initial WHP 0 psi, IA 0, OA 75 psi. Stab on well. PT stack 250/3,000 psi for 5 minutes. RIH. WT check 5,074' CTMD 13.6K. RIH Wt 8800 lbs. Stack weight at 9,130' CTMD. PU WT 17K. Tagged 104' higher than previous tempress run for FCO. Pump down Coil and circulate to surface confirm well is fluid packed. Shut in Choke. Perform pre cement job injection test at 1 bbl/min. Pressure climbed and slowed down and injected at 230 psi. PJSM with cement crews and coil. 0923 hrs cement wet. Online down coil parked at 9,130' CTMD with 15.8 ppg class G cement. Cement at nozzle drop rate to .5 bbls/min POOH at 60 ft/min. Laying in cement 1:1.5207' park coil and close choke. Start squeezing 5 His of cement 356 psi. PU to 5100' squeeze 5 bbls of cement. 60 bbls of cement pumped. final squeeze pressure 542 psi WHP. Pressure never broke over. PU to 4,600' Load .7" ball and lauch down coil. Clean out with 80 bbls of N-Vis gel down to 5,113' CTMD. Dress top of cement Wash up and down from 5,113' up to 4,800' Holding 250 psi WHP. Strapping return tank and not getting 1:1's. Drop back pressure to 0 psi open choke. (cement in place at 11:53) Wash all the way to surface at 2.2 bbls/min. Close master swab. 0 psi T/0 IA/ 75 OA. Pop off well. Install night cap. Rig back injector head. LICA for cement requires 24 hours prior to gaining 1,000 psi compressive strength. Location secure. SDFN. Plan forward. RIH and tag cement top. Pressure test with state Rep to 1,500 psi. 24 hr abandonment notification sent 7/30/19 @ 15:12 hrs. Brian Bixby requested witness. 8/1/2019-Thursday RIH with 2.0" CT and 2.5" nozzle to 5,000' . No cement across sliding sleeve. Wait for 1,000 psi compressive strength prior to tagging cement top. State Rep Adam Earl and Brian Bixby on location. 13:00 hours 1000 psi strength on cement. RIH from 4,900'. Tag TOC with 5k donw at 5,212'. Cement is low. Required cement top was 5,121'. Fluid pack to surface. Close choke and Attempt 1,500psi pressure test for 30 minutes. Pressure climbed to 1,320 psi and broke over. Failed PT. POOH . Lay in 60/40 freeze protect from 2,500' to surface. RDMO SLB CTU 6. Tubing 0 psi, IA 0 psi, OA 32 psi. 8/2/2019 - Friday No operations to report. 8/3/2019-Saturday No operations to report. 8/4/2019-Sunday No operations to report. 8/5/2019 - Monday No operations to report. 8/6/2019-Tuesday Pressure test Tbg cement plug (PT surface Equip. 250/2500 psi) Pump 0.46 bbls Dsl to reach 1st test pressure. In 4 Min Tbg lost 175 psi. Bump up Tbg pressure to 1000 psi. In 5 Min Tbg lost 289 psi. Let chart run for 10 more Min. Tbg lost 479 psi for 15 Min. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-22 Coil 50-029-23176-00-00 203-147 1 7/30/2019 9/1/2019 Daily Operations. 8/7/2019- Wednesday No operations to report. 8/8/2019 - Thursday WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H. RUN DUAL X -WING MAGNETS W/3.80"" GAUGE RING, TAG XN NIP @ 5,048' SLM. SHIFT XD -SS @ 4973' MD OPEN. SET PXN PLUG BODY IN XN-NIP @ 5,065' MD. SET PRONG IN PXN PLUG @ 5,041' SLM. WELL S/I UPON DEPARTURE. 8/9/2019 - Friday No operations to report. 8/10/2019 -Saturday No operations to report. 8/11/2019 -Sunday No operations to report. 8/12/2019 - Monday No operations to report. 8/13/2019 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-22 Coil 50-029-23176-00-00 203-147 7/30/2019 9/1/2019 Daily Operations. 8/28/2019- Wednesday No operations to report. 8/29/2019 - Thursday No operations to report. 8/30/2019 - Friday No operations to report. 8/31/2019 -Saturday No operations to report. 9/1/2019 -Sunday Pressure Test Plug (PASSED) (PT surface Equip. 250/3,000 psi) Pump 3.5 bbls 60/40 to reach test pressure. 1st 15 Min IA lost 169 psi. 2nd 15 Min IA lost 70 psi. 3rd 15 Min IA lost 58 psi. Bleed IA down w/ 2.9 bbls 60/40 returned. 9/2/2019 - Monday No operations to report. 9/3/2019 -Tuesday No operations to report. MEMORANDUM TO: Jim Regg P.I. Supervisor l FROM: Adam Earl Petroleum Inspector Section: 12 Township: Drilling Rig: n/a Rig Elevation: Operator Rep: Cole Bartlewski Casing/Tubing Data (depths are MD): Conductor: 20" O.D. Shoe@ Surface: 10 3/4" O.D. Shoe@ Intermediate: ADL0380109 O.D. Shoe@ Production: 7 5/8" O.D. Shoe@ Liner: 4" O.D. Shoe@ Tubing: 41/2 O.D. Seal ass. Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: August 1, 2019 SUBJECT: Well Bore Plug & Suspension MPU S-22 Hilcorp Alaska LLC PTD 2031470; Sundry 319-343 12N " Range: 10E Meridian: Umiat n/a Total Depth: 9,242 ft MD Lease No.: ADL0380109 Suspend: X P&A: Casing Removal: 110 Feet Csg Cut@ n/a Feet 2561 Feet Csg Cut@ n/a Feet Feet Csg Cut@ Feet 5216 Feet Csg Cut@ n/a Feet 9242 Feet Csg Cut@ Feet 5118 Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore Bottom 5,212 ft MD C.T. Tag Initial 15 min 30 min 45 min Result Tubing IA F ✓ OA Initial 15 min 30 min 45 min Result Tubing IA OA _ Remarks: I traveled out to MPU S-22 for a plug tag and pressure test. The top of the 4 1/2" screened liner is @ 5,208 ft MD. The calculated top of cement (TOC) in the liner was 5,121 ft MD - tagged low @ 5,212 ft MD. Pressure test of 1500 psi followed the tag; the pressure never made it past 1,320 psi before it broke over and the well started taking fluid. Plan forward is to do another cement job. I left location. Attachments: none rev. 11-28-18 2019-0801 _Plug_Verification_MPU_S-22_AE 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, Ugnu Undefined Oil Pool, MPU S-22 Permit to Drill Number: 203-147 Sundry Number: 319-343 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 vvvdw, a ogc c. a las ka. 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, y 2,:ieelowski Commissioner DATED this 2g day of July, 2019. BBDMS. ( uj1UL 3 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS F st--CE � tu r L, Gb.26U 1. Type of Request: Abandon ❑ Plug Perforations rjt F „L racure Stimulate D _ ❑ Repair Well ❑ Operations shutdown ❑ Suspend Q • Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program] Plug for Redrill ❑ Perforate New Pool EJRe-enterSusp Well ❑ Alter Casing ❑ Other: Res-Atgr ! 2. Operator Name: :Cuuent Well Class: 5. Permit to Drill Numbeg, — �o Hilcorp Alaska LLC ory ❑ DevelopmenP8WelI 203-147 3. Address: 3800 Centerpoint Dr, Suite 1400phic ❑ Service6. API Number: Anchorage Alaska 99503 _ 7. If perforating: 50-029-23176-00-00 ame andNumber: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 Will planned perforations require a spacing exception? Yes ❑ No Q MILNE PT UNIT S-22 9. Property Designation (Lease Number): ield/Pool(s): 11. ADL0380109 10. FMILNE POINT / UGNU UNDEFINED OIL PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth M (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs 9,242' . 3,648' 9,242' 3,648' 1 1,275 Casing Length Size Mp N/A N/A TVD Burst Collapse Conductor 75' 20" 110' 110' N/A N/A Surface 2,527' 10-3/4" 2,561' 2,406' 5,210 si Intermediate 5,183' 7-5/8" 5,216' P 2,470psi 3,723' 6,890 si ProductionP 4,790psi 4,166' 4" 9,242' 3,648' 7,910 si Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubin Grade: P 6,590psi 9 Tubing MD (ft): See Schematic See Schematic 4-1/2" 12.6 / L-80 / IBT Packers and SSSV Type: 5,118' Packers and SSSV MD (ft) and TVD (ft): ZXP LTP and N/A 5,083 MD/ 3,698 TVD and N/A 12. Attachments: Proposal Summary r Wellbore schematic U� 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch❑ Exploratory ❑ E]Stratigraphic ❑ Development ❑✓ •Service PVerbal ted Date for 15. Well Status after proposed work: ing Operations: 7/25/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑� ' Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ n Representative:GINJ ❑ Op Shutdown ❑ Abandonedby certify that the foregoing is true and the procedure approvedherein will not ed from without prior written approval. Name: Chad Helgeson Authorized Title: Operations Manager Contact Name: Ian Toomey ._J'r� Contact Email: jtOOme hllCof .Corn Authorized Signatur � . C ft� Date: 7/19/2019 Contact Phone: 777-8434 COMMISSION USE ONLY Conditions of appro * Notify Commission so that a representative may witness Sundry Number: �Iq 3W3 Plug Integrity BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: k, tUr (.� � r ^ 0 U l•, J,,7\Jt 4''j Jr �.rS s•F-r� ZvLS ar V c/A tT RBDMS4�11ti 3 1 "1 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ❑- Subsequent Form Required: 16 „ yo 7 \'r Approved by: � 1/k_ COMMISSIONER THEAPPCOMMISSION Date' W)A M ale 7%" �� Form 10-403 Revised /2017 Approved a i s r f r from the date of approv Submit Form and Attachments in Duplicate U Ilil.m Alaska, LU Reservoir Abandonment Well: MPU 5-22 Date: 07/18/2019 Well Name: MPU 5-22 API Number: 50-029-23176-00-00 Current Status: Reservoir isolated Pad: MP S -Pad Estimated Start Date: July 25th, 2019 Rig: CTU Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203-147 First Call Engineer: Ian Toomey (907) 777-8434 (0) (907) 903-3987 (M) Second Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228 (M) AFE Number: TBD IWeIIEZ Entry Required: Yes Current Bottom Hole Pressure: 1495 psi @ 3750' TVD (SBHP 04/27/09/ EMW = 7.7 ppg) Maximum Expected BHP: 1650 psi @ 3750' TVD (EMW = 8.5 ppg) MPSP: 1275 psi (0.1 psi/ft gas gradient) Brief Well Summary: MP 5-22 was drilled and completed in October 2003 as a JP producer in the Ugnu sand. The well was BOL and sanded off quickly. After several unsuccessful attempts to get the well to flow without sanding off the well was shut-in January 2005. The well was secured in August 2010 with a PXN plug set in the nipple at 5065'. The well _ is currently being used to circulate power fluid to stabilize the booster pumps Notes Regarding Wellbore Condition a The 7-5/8" casing has not been tested since original installation in October 2003. Prior to opening the sliding sleeve, the PXN plug and 4-1/2" tubing passed a MIT to 2000 psi on 8/18/2010. Objective: To abandon the entire horizontal lateral with cement. The Ugnu lateral needs to be abandoned prior to drilling 5-203 and 5-202 due to close approach risks and to help prevent potential MBE's. Little Red Services: 1. RU LRS. 2. Ensure the well is fluid packed. Perform CMIT—T x IA to 2500 psi for 30 minute 3. RD LRS. 3O M Slicklline: 4. RU HES slickline. 5. Shift sliding sleeve at 4976' closed. / 6. Pull PXN prong and pull PXN plug body from nipple at 5065'. 7. RD HES slickline. H Mile.. Alaska, LU Reservoir Abandonment Well: MPU 5-22 Date:07/18/2019 Coil Tubing: 8. MIRU CTU and spot support equipment. Fill uprights with seawater. 9. Pressure test BOPE to 250/3000 psi for 10 minutes each. a. Each subsequent test of the lubricator will be to 250/3000 psi to confirm no leaks. 30. RIH with 2" nozzle to the top of the 4" screens at 5208'. Cleanout the 4", 9.5# liner to the top of the float collar at 9240' with seawater and gel sweeps. Note: In April 2009 an FCO was done down to 6405' were the engineer had them stop. A FCO in December 2004 made it to 8865' and could not make it any deeper. �i 11. POOH. 12. MU ball drop cementing nozzle and RIH to 9240' or deepest depth reached during FCO. 13. RU cementers. 14. Mix and pump 60 bbls of 15.8 ppg Class G cement down the coil tubing taking returns up the 4-1/2" tubing. Use freshwater spacers as needed around the cement. 15. Allow —1 bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1. Pause at 5207' and and attempt to squeeze ±5bbls cement until a bump in pressure is observed. 16. PU to 5100' and attempt to squeeze away ±5bbls of cement. 17. Swap to contaminate and RIH to cleanout to 5121' MD. 18. POOH and circulate coil tubing clean as needed. a. Freeze protect well on way out of hole. 19. Wait on cement to gain 1000 psi compressive strength. 20. RIH and tag the top of cement. Pressure test the cement to 1500 psi for 30 minutes (charted). a. If the pressure test of the cement plug ai s contact the Operations ngineer to iscuss pumping additional cement. hB / 21. RD CT unit. /T ISYGC�� itti�neS Yu—q�r�SS�� Z Attachments: 1. As -built Schematic 2. Proposed Schematic 3. Blank Sundry Change Form C A)L, T€ Cal (T �� S R 'corn Aloaka. LLC. Ong la 72oD/OrI9GL* 3004(1)uron 14) 103/4" SCHEMATIC TREE / WELLHEAD Milne Point Unit Well: MPU S-22 Last Completed: 10/6/2003 PTD: 203-147 Tree 4-1/16" SM FMC Wellhead FMC 11"x4.5"SM Gen6w/4.5"TC-II T&B. Tubing Hanger, CIW'H' BPV Profile OPEN HOLE / CEMENT DETAIL 20" 260 sX of Arctic set in 24" Hole 10-3/4" 485 sx Class'U, 312 sx Class "G" In 13-1/2" Hole 7-5/8" 292 sx Class "G" In 9-7/8" Hole CASING DETAIL Size Type Wt/Grade/Conn ID 30.04' Btm BPF 20" Conductor 92 / H-40 / N/A 19.124fs�-rf;' Phoenix Dischar a Pressure Gau e 110' N/A 10-3/4" Surface 45.5/L-80/BTC 9.9507-5/8" 6 5,065' HES 4-1/2"XN Nipple -MIN ID= 3.7 w/RHC Plu 7 Intermediate 29.7/L-80/IBT-M 6.8755,989' 5,083' 5,945' 0.0459 LINER DETAIL TUBING DETAIL 41/2"I Tubing 1 12.6 / L-80 / IBT 3.958 Surface 5,118' 0.0152 WELL INCLINATION DETAIL KOP @ 425' MD Hole Angle Passes 50 Deg. LD 2,770' Max Angle In Tubing = 78 Deg. 73 Deg. @ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 30.04' FMC TC -IA -EMS 11" x4.5" Tubing Hanger 2 2,107 GLM:4-1/2" x 1" KBG-2 w/ DCK-2 Shear Valve BEK Latch 3 4,965' Phoenix Dischar a Pressure Gau e 4 4,973' HES 41/2"XD DURA Sliding Sleeve w/Centralizers - Reverse Clrculatin Jet Pum 5 5,000' 4-1/2" Phoenix Pressure Sensor 6 5,065' HES 4-1/2"XN Nipple -MIN ID= 3.7 w/RHC Plu 7 51076' 7-5/8" x 5.5" Liner Tieback Sleeve 8 5,083' 5,945' 9 5,083' Baker 80-47 Seal Bore Assembly -BTM@5,118' 30 5,120' Crossover 5-1/2" x -41/2- - L-80 IST 31 5,207' Crossover 4-1/2"x4"IBT j5 y t 'Vnr,,.T MNID@5,065' ID=3.725" N -= TD=9,242' (MD)/TD= 3,648' (TVD) PERFORATION DETAII Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status 5,460' 5,485' 3,742' 3,742' 25 7/26/2004P 5,690' S,690' 5,715' 3,748' 3,689' 25 7/25/2004 Open It "1 5,920' 5,945' 3,745' 3,743' 2S 7/25/2004 Open 6,150' 6,175' 3,730' 3,728' 25 7/25/2004 Open Ugnu 6,380' 6,405' 3,716' 3,714' 25 7/25/2004 Open Undefined 6,610' 6,635' 3,699' 3,697' 25 7/25/2004 Open 6,890' 6,915' 3,675' 3,673' 25 7/25/2004 Open 7,300' 7,325' 3,643 3,640' 25 7/24/2004 Open 7,825' 7,850' 3,621' 3,622' 25 12/9/2004 Open 8,000' 8,025' 3,62'V 3,625' 25 12/9/2004 Open 8,380'1 8,405' 1 3,629' 1 3,629' 1 25 Perforation Charge Detail: 2.5" HX 6SPF Random Orientation. PDS tie In log 7/24/2004 12/9/2004 Open GENERAL WELL INFO API: 50-029.23176-00-00 Drilled and Complete by Doyon 14 -10/6/2003 CTU Perf Add -8/13/2004 Revised By: TDF 7/17/2019 R corp Almke, LLC Orig KB: 72.00/Ddg GL: 3004(D yw 14) 10-3/4" MN ID@SOBS' I11� 3.725" No - TD= 9,242' (MD) /TD= 3,648' (TVD) Proposed SCHEMATIC TREE / WELLHFAD Milne Point Unit Well: MPU S-22 Last Completed: 10/6/2003 PTD: 203-147 Tree 4-1/16" 5M FMC Wellhead FMC 11"x4.5"5M Gen 6w/4.5"TC-11 T&B. Tubing Hanger, CIW'H' BPV Profile OPEN HOLE/ CEMENT DETAIL 20" 260 sx of Arctic set in 24" Hole 10-3/4" 485 sx Class'L', 312 sx Class "G" in 13-1/2" Hole 7-5/8" 292 sx Class "G" in 9-7/8" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 92/H-40/N/A 19.124 Surtace 110' N/A 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,561' 0.0962 7-5/8" Intermediate 29.7/L-80/IB7-M 6.875 Surface 5,989' 0.0459 DETAIL TUBING DETAIL Tubing 1 12.6 / L-80 / IBT 1 3.958 1 Surface 5,118' 0.0152 WELL INCLINATION DETAIL KOP @ 425' MD Hole Angle Passes 50 Deg. @ 2,770' Max Angle in Tubing = 78 Deg. 73 Deg. @ Sliding Sleeve JEWELRY DETAII PERFORATION DETAII Sands h Item Top (TVD) ' ,5'Tubin Han er FMC TC-1A-EWLTP' Date 7' GLM: 4-1/2" z2 w/ DCK-25hear Valve BEK Latch 5,460' ' Phoenix Dischsure Gau e' 3,742' 55,083'7-5/8"x HE54-1/2" XDiding Sleeve w/Centralizersse Circulating Jet Pump' 4-1/2" Phoenie Sensor' Open HES 4-1/2" XN MIN ID= 3.725" No- a w/R' 5,715' 3,748' 7-5/8" x 5.5" ack Sleeve' 25 7/25/2004 7-5/8" x 5.5" 2 9 5,083' 1 Baker 80-47 Seal Bore Assembly- ATM @5,118' 105,120 3,743' Crossover5-1/2"x4-1/2"-L-801BT 11 5,2071 Crossover 4-1/2" x 4" IBT PERFORATION DETAII Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status 5,460' 5,485' 3,742' 3,742' 25 7/26/2004 Open 5,690' 5,715' 3,748' 3,689' 25 7/25/2004 Open 5,920' 5,945' 3,745' 3,743' 25 7/25/2004 Open 6,150' 6,175' 3,730' 3,728' 15 7/25/2004 Open Ugnu 6,380' 6,405' 3,716' 3,714' 25 7/25/2004 peen Undefined 6,610' 6,635' 3,699' 3,697' 25 7/25/2004 Open 6,890' 6,915' 3,675' 3,673' 25 7/25/2004 Open 7,300' 7,325' 3,15AT 3,640' 25 7/24/2004 Open 7,825' 7,850' 3,621' 3,622' 25 12/9/2004 Open 8,000' 8,025' 3,624' 3,625' 25 12/9/2004 Open 8,380' 8,405' 3,629' 3,629' 25 12/9/2004 Open Perforation Charge Detail: 2.5" HMX 6SPF Random Orientation. PDS tie in log 7/24/2004 Ct,111�41t_ GENERAL WELL INFO API: 50-029.23176,00-00 Drilled and Com lete by Doyon 14 -10/6/2003 CTU PerfAdd-8/13/2004 Revised By: IAT 7/18/2019 Hileorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: July 1911, 2019 Subject: Changes to Approved Sundry Procedure for Well S-22 Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK HAK Prepared Approved B initials B initials AOGCC Written Approval Received Person and Date Approval: Chad Helgeson Operations Manager Date Prepared: Ian Toomey Operations Engineer Date 10 000 1,000,000 r C c0 C L CL 100,000 LL V ,O 10,000 O O O N a+ f0 v (7 LL 1,000 V 3 V C m 100 3 L h 10 1 Jan. Hilcorp Alaska LLC, MILNE PT UNIT S-22 (203-147) MILNE POINT, UGNU UNDEFINE OIL Monthly Production Rates 10,000,000 1,000,000 100,000 10,000 1,000 100 to I -- ---- Jan-[ulu Jan -2015 Jan -2020 e Produced Gas (MCPM) a GOR Produced WaterBOPM --0-- ( 1 Produced Oil (BOPM( SPREADSHEET-2031470_MPU_S-22_Prod_Cu rves_Well_Oil_V120_20190723.xlsx 7/23/2019 L From: Stan Porhola <sporhola@hilcorp.com> Sent: Monday, July 29, 2019 3:46 PM To: Schwartz, Guy L (CED); Rixse, Melvin G (CED) Cc: Wyatt Rivard Subject: RE: [EXTERNAL] RE: MPU S-22 (PTD 203-147) - Liner Plugback (Coiled Tubing) Guy, Per our discussion, MPU S-22 (along with MPU S-29 [PTD 202-195]) is a former development well that is currently used to regulate power fluid water to our Booster Pumps to allow those pumps to operate within the required pump curve parameters. Low pressure (250 psi) power fluid is circulated down the IA and produced up the tubing, the same configuration as its original jet pump completion, but without a downhole jet pump installed. MPU 5-22 has operated in this configuration with a downhole mechanical plug set in the tubing above the liner top. After the coiled tubing plugback of the liner top, the plan would be to reset the plug and return the well to use as a power fluid circulating well. Stan From: Schwartz, Guy L (CED) [mailto:guy.schwartz@alaska.gov] Sent: Monday, July 29, 2019 2:46 PM To: Stan Porhola <sporhola@hilcorp.com>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: MPU S-22 (PTD 203-147) - Liner Plugback (Coiled Tubing) Stan, Have it in the que ... can you elaborate on the circulation path used for the booster pumps. We were debating whether to call this a service well instead of suspended. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conseryation fidential and/or privileged Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain con information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv.schwartz@alaska aov(. From: Stan Porhola <sporhola@hilcoro com> Sent: Monday, July 29, 2019 12:43 PM To: Schwartz, Guy L (CED) <Ruy.schwartzCa)alaska eov>; Rixse, Melvin G (CED) <melvin.rixseCdalaska.¢ov> Subject: MPU S-22 (PTD 203-147) - Liner Plugback (Coiled Tubing) Guy/Mel, We submitted a sundry for MPU 5-22 (PTD 203-147) for a plugback of a 4" liner using coiled tubing. Do you know where this sundry is located in the process? We have the opportunity to pick up a coiled tubing unit this week outside of our normal schedule and would like to start as soon as possible. Regards, Stan Porhola j Operations Engineer North Slope Asset Team Hilcorp Alaska, LLC S12orholaPhilcor com Office: (907) 777-8412 Mobile: (907) 331-8228 The information contained in this e-mail message is confidential information intended only for the use of the recipient($) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. 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 tarty out such virus and other checks as it considers appropriate. • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 — Post Office Box 196612? Anchorage, Alaska 99519 - 6612.,'} December 30, 2011 SD FEB 4 2012 Mr. Tom Maunder �� /14 Alaska Oil and Gas Conservation Commission 7 333 West 7 Avenue Anchorage, Alaska 99501 1�1/I Ps- I,t Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -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, 1. ) Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPS -Pad 10/11/2011 Corrosion • Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # , API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPS-01A 2070340 50029231410100 025 NA 0.25 NA 5.1 9/6/2011 MPS -02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/30/2011 MPS-03 2021460 50029231050000 Open Flutes - Treated MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/3/2009 MPS-08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/30/2011 MPS-09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS -10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -11 2021130 50029230920000 1 NA 1 NA 10.2 7292011 MPS -12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7292011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS -14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 7292011 MPS -15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/312011 MPS-16 2030650 50029231510000 1.2 NA 1.2 NA 102 7292011 MPS-17 2021730 50029231150000 Open Flutes - Treated MPS -18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7292011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7/29/2011 MPS-20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 '- -�j MPS -22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 728/2011 MPS-23 2021320 50029230980000 Open Flutes - Treated MPS-24 2030380 50029231420000 1.3 NA 1.3 NA 102 7282011 MPS -25 2021030 50029230890000 Open Flutes - Treated MPS -26 2030610 50029231500000 1 NA 1 NA 8.5 7/28/2011 MPS -27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7282011 MPS -28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7/28/2011 MPS -29 2021950 50029231190000 Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 12 NA 11.9 7/28/2011 MPS-31 2020140 50029230660000 Open Flutes - Treated MPS-32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7/28/2011 MPS -33A 2061720 50029231230100 1 NA 1 NA 6.8 7/28/2011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7/28/2011 MPS-35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-37 2070520 50029233550000 13.9 Need top job NA MPS-39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS -41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS-43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/112011 MPS-90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB -04 500299990799 0.6 NA 0.6 NA 3.4 7/30/2011 • ~... ~~:. _~ '• ~ 03/01/2008 DO N4T PLACE ~~; ~~, ~,f: _ ~. ANY NEW MATERIAL UNDER THIS PAGE F : ~LaserFiche\CvrPgs_InsertslMicrofilm_Marker. doc · WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: MPS-20, MPS-22, MPS-30, MPS-90. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 MPS-20: U'Ie..- Q6d - d(./ { it /L.!3'6L( Digital Log Images: 50-029-23132-00 1 CD Rom .. - MPS-22: dO'3 -/4./9 143~'5 Digital Log Images: 50-029-23176-00 1 CD Rom MPS-30: u:¡:C- 86d -d-3C,o "* IL..!3?51- Digital Log Images: 50-029-23131-00 1 CD Rom MPS-90: dÖS- -135" +/l./3150 Digital Log Images: 50-029-23276-00 1 CD Rom SCANNED FEB 0 1 2007 r -:> \) ') WELL LOG TRANSMITTAL J¿}:)-/41 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16,2006 13·7 ð1 RE: MWD Formation Evaluation Logs MPS-22, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPS-22: LAS Data & Digital Log Images: 50-029-23176-00 &CANNEK) M/\H n ~; 200H 1 CD Rom ~I t:",'ì I~l o/ð' c ) C:::> I'ù\V )...0\';)& DATA SUBMITTAL COMPLIANCE REPORT 11/8/2005 Permit to Drill 2031470 Well Name/No. MILNE PT UNIT UGNU $-22 Operator BP EXPLORATION (ALASKA) INC ),~ "- 7 S~ ~Ò"J API No. 50-029-23176-00-00 MD 9242- TVD 3662 - Completion Date 10/6/2003""" Completion Status 1-01L Current Status 1-01L UIC N -~._---_._-~-_._~-~-~-- REQUIRED INFORMATION ----_._-~-'"~-_._. o;'ect;O",I~ x.. 2 . Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GYRO, MWD, GR, RES, IFR/CASANDRA, ASI PWD Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH/ . Scale Media No Start Stop CH Received Comments O· 9242 10/27/2003 ..... . . 0 9242 10/27/2003 MWD 0 725 10/27/2003 Gyro 69 9188 Open 12/16/2003 GR, EWR4, ROP I I 69 9188 Open 12/16/2003 GR, EWR4, ROP I I 69 9188 Open 12/16/2003 GR, EWR', ROP. I wQ a"'o~ gl'J~" 12/Ið/.Wö~ Ón., I!vv~4, R(,)~__ Sample Set Sent Received Number Comments . Daily History Received? ~N Formation Tops ~ Log/ Electr Data Digital Dataset Type Med/Frmt Number Name I:~- Directional Survey I Rpt Directional Survey ! Rpt Directional Survey I ~D D Las 12305 Induction/Resistivity ED D Las 12305 Rate of Penetration Rpt Inellolstiel'l/Re!li3tlltity L.. S 11&1.1' ~ fo.I.,.I: 1# - I~ Rete ef rel'lelratiel'l' L-___~"__ Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? "'i'7N' Analysis ~ Received? Comments: .-. DATA SUBMITTAL COMPLIANCE REPORT 11/8/2005 Permit to Drill 2031470 Well Name/No. MILNE PT UNIT UGNU S-22 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23176-00-00 MD 9242 TVD3662 \Co~Pletion_ Date 10/6/2003 Compliance Reviewed By: m___~_____ Completion Status 1-01L Current ~~:~~ :-j 3 ~~c;- . . . STATE OF ALASKA . ALA· OIL AND GAS CONSERVATION C~ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D RepairWellD Pull TubingD Operation Shutdown D PluQ PerforationsD Perforate New PoolD Perforate [K] Stimulate 0 waiverD OtherD Time ExtensionD Re-enter Suspended WellD 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development Œ] ExploratoryD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Stratigraphic D 9. Well Name and Number: MPS-22 10. Field/Pool(s): Milne Point Field I Ugnu Undefined Oil Pool ServiceD 5. Permit to Drill Number: 20 -1470 6. API Number 50-029-23176-00-00 72.18 8. Property Designation: ADL-380109 11. Present Well Condition Summary: Total Depth measured 9242 feet true vertical 3662.2 feet Effective Depth measured 9242 feet true vertical 3662.2 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 20" 94# H-40 35 110 35.0 - 110.0 1530 520 LINER 49 4-1/2" 12.6# L-80 5076 - 5125 3708.2 - 3718.3 8430 7500 LINER 4071 4" 9.5# L-80 5125 - 9196 3718.3 - 3662.7 7910 6590 LINER 46 4-1/2" 12.6# L-80 9196 - 9242 3662.7 - 3662.2 8430 7500 PRODUCTION 5184 7-5/8" 29.7# L-80 32 - 5216 32.0 - 3735.9 6890 4790 SURFACE 2526 10-3/4" 45.5# L-80 35 - 2561 35.0 - 2407.0 5210 2480 Perforation Depth: Measured depth: See Attachment True vertical depth: See Attachment Tubing ( size, grade, and measured depth): 4-1/2 Inch 12.6 Lb L-80 @ 30 5118 Packers & SSSV (type & measured depth): 5-1/2" Baker ZXP Hydro Set Packer @ 5083 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: Oil-Bbl o o Representative Dailv Averaae Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 0.01 0 275 0.01 0 600 Tubing Pressure 170 296 14. Attachments: ! 15. Well Class after proposed work: Exploratory 0 16. Well Status after proposed work: OilŒ] GasD Development ŒI ServiceD Copies of Logs and Surveys run _ Daily Report of Well Operations_ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron kje; Signature Title Production Technical Assistant Phone 564-4657 Date 1/27105 RBDMS 8Ft FEB 0 4 Z005 Form 10-404 Revised 4/2004 . . Attachment Perforation Depth Measured Depth (ft) TVD Depth (ft) 5208 - 5246 3734.4 - 3741.16 5253 - 5320 3742.24 - 3750.34 5363 - 5399 3753.56 - 3754.34 5440 - 5485 3755.17 - 3756.37 5518 - 5556 3757.39 - 3758.54 5598 - 5636 3759.73 - 3760.84 5678 - 5715 3762.13 - 3763.15 5758 - 5796 3764.23 - 3764.95 5834 - 5872 3764.7 - 3762.58 5915 . 5952 3759.7 - 3757.2 5995 - 6032 3754.26 - 3751.73 6073 - 6111 3748.95 - 3746.44 6150 - 6191 3744.05 - 3741.68 6234 - 6271 3739.1 - 3736.67 6311 - 6349 3733.99 - 3731.79 6380 - 6429 3730.03 - 3727.21 6472 - 6509 3724.66 - 3722.45 6550 - 6587 3719.76 - 3716.08 6610 - 6667 3713.64 - 3707.56 6709 - 6746 3704 - 3701.4 6788 - 6826 3698.05 - 3694.66 6868 - 6915 3690.7 - 3687.18 6946 - 6984 3685.29 - 3683.02 7026 - 7064 3680.55 - 3678.01 7106 - 7143 3674.71 - 3671.39 7184 - 7222 3667.37 - 3663.64 7264 - 7325 3660.11 - 3654.77 7345 - 7382 3652.99 - 3649.73 7425 - 7462 3645.95 - 3642.68 7504 - 7542 3639.16 - 3636.56 7582 - 7620 3634.91 - 3634.12 7663 - 7670 3633.73 - 3633.71 7741 - 7778 3633.96 - 3634.37 7819 - 7856 3635.23 - 3636.11 7897 - 7934 3636.76 - 3637.38 7975 - 8025 3637.92 - 3638.94 8056 - 8093 3639.9 - 3641 .18 8136 - 8174 3642.5 - 3643.63 8216 - 8253 3644.56 - 3645.29 8294 - 8331 3645.38 - 3644.59 8372 - 8409 3643.57 - 3643.08 8452 - 8490 3642.57 - 3641.93 8532 - 8569 3641 .41 - 3641 .53 8610 - 8647 3641.91 - 3642.83 8688 - 8726 3643.99 - 3645.15 8767 - 8805 3646.56 - 3647.86 8846 - 8884 3649.58 - 3651.59 8925 - 8962 3653.55 - 3655.13 9003 - 9040 3657.16 - 3659.21 TVD De th ft 3660.76 - 3662.21 3663.09 - 3662.72 . . MPS-22 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 12/07/04 CTU #4, FCO/FISH/ADD PERF; MIRU DS CTU #4. RIH WITH 2.5" JSN. HAD DISCHARGE FROM INJECTOR SUMP. POOH. FOUND PARTIALLY PLUGGED DRAIN HOSE. INSPECTED AND CHANGED OUT PACK-OFFS. RBIH WITH 2.5" JSN. SAW INDICATIONS OF FILL AT 4510' CTMD. BEGIN JETTING FILL, CONTINUE RIH TAKING RETURNS TO TANKS. CO NT' ON WSR 12/08/04 ... 12/08/04 CTU #4, FCO/PULL JET PUMP/FCO/ADD PERF; CONT' FROM WSR 12/07/04... RIH WITH 2.5" JSN JETTING FILL. CLEAN DOWN TO TOP OF PUMP AT 4953' CTMD PUMPING FLOPRO SWEEPS. POOH. MU AND RIH WITH BAKER FISHING ASSY (4" GS). LATCH AND PULL JET PUMP AT 4970' CTM. MU AND RIH WITH 3.6" SS SHIFTING TOOL. CLOSE SS AT 4974' CTM. VERIFY CLOSED WITH LRS PUMPING DOWN THE IA. PRESSURE IA TO 2000 PSI- HELD. TUBING PRESSURE WAS 48 PSI AND DID NOT CHANGE. POOH. MU AND RIH WITH 2.5" JSN. SAW SOME RESISTANCE AT 5050' CTMD. BEGIN JETTING WITH FLOPRO SWEEPS. CLEAN TO 6300' CTMD. SHORT TRIP TO 3500' CTMD. RBIH JETTING. CLEAN TO 8300' CTMD. HAVING TROUBLE GETTING DEEPER. SHORT TRIP PIPE TO 2500' CTMD. CONT' ON WSR 12/09/04 ... 12/08/04 [ASSIST CTU] PUMPED 15 BBLS MEOH TO FILL AND TEST IA TO 2000 PSI. GOOD TEST. BLEED BACK TO 200 PSI.. INITIAL WHP=CTU, 200.. FINAL WHP=CTU, 200. 12/09/04 CTU #4, FCO/ FISH/ADD PERF; CONT' FROM WSR 12/08/04... SHORT TRIP TO 2500' CTMD. RBIH JETTING. CLEAN OUT TO 8865' CTMD. CANNOT GET DEEPER, POSSIBLY LOCKED UP. POOH. MU AND RIH WITH GUN #1 - 25' OF 2.5" 6 SPF, 2506PJ GUNS. SHOOT INTERVAL 8380' - 8405'. CORRECT DEPTH TO RKB. POOH. MU AND RIH WITH GUN #2 - 25' OF 2.5" 6 SPF, 2506PJ. SHOOT INTERVAL 8000' TO 8025'. POOH. MU AND RIH WITH GUN #3 - 25' OF 2.5" 6 SPF, 2506PJ. CONT' ON WSR 12/10/04 ... 12/10/04 CTU #4, FCO/ADD PERF; CONT' FROM WSR 12/09/04... RIH WITH GUN #3. SHOOT INTERVAL 7825' TO 7850'. POOH. FP WELL WITH 40 BBLS DIESEL. WELL LEFT SHUT IN. PAD OPERATOR NOTIFIED OF WELL STATUS. FLUIDS PUMPED BBLS 1380 XS 1% KCL 92 Flo Pro 363 60/40 Methonal 127 Diesel 1962 TOTAL Page 1 ~ 4-1/16" - SM FMC Wellhead' 11" x 4.S" SM . w/4.S" TCII T&B Tubing er CIW "H" BPV profile MPS-22 20" x 34" insulated, 215 lIft À-53 ~ 103/4" 45.5 lIft L-80 BTC I 2s611 75/8" 29.7# L-80 IBT-M casing (drift ID = 6.75", cap = .0262 BPF w/ tbg. ) 4.5" 12.6# L-80 IBT-M tubing ( ID = 3.958", cap = .0152 BPF ) Peñoration Summary Ref loa: PDS Tie in log 7/24/04 Size spf Interval 2.5 6 5,460' - 5,485' 2.5 6 5,690' - 5,715' 2.5 6 5,920' - 5,945' 2.5 6 6,150' - 6,175' 2.5 6 6,380' - 6,405' 2.5 6 6,610' - 6,635' 2.5 6 6,890' - 6,915' 2.5 6 7,300' - 7,325' 2.5 6 7,825' - 7850' 2.5 6 8,000' - 8,025' 2.5 6 8,380' - 8,405' 2.5" HMX 6SPF Random orieniation 7 S/8" HES Float Collar S128' 7 S/8" HES Float Shoe S216' COMMENTS 10/6/03 08/13/04 Lee Hulme Drilled and Completed by Doyon 14 MDO CTU Add perfs / 2nd Add perfs 12/09/04 Orig. KB elev. = 72.00' (Doyon 14) .. GL. elev.= 30.04' (Doyon 14) KOP @ 425' Hole angle passes 50 degrees @ 2770' Max angle in tubing = 78 degree 73 degrees at sliding sleeve Camco 4.5" x 1" w/ BK latch sidepocket KG B-2 GLM I 2107' I ,.,40Y Min. ID through tubj.pg 3.8'., ".@4976' Min. ID through XN~.72S"~· . '~96S' . ., ,.... .,. ": ..,.."".,.. Phoenix Discharge gauge (3.956 ID) 4.5" HES "XD" Dura sliding sleeve 3.813" ID (Opens down) Phoenix Jet Pump gauge sensor (3.833" ID) (3690' tvd) 4.5" HES 'XN' Nipple (3.813 Pkg ID, 3.725 No-go ID) 7 5/8" x 5.5" Lnr Tie Back Sleeve 75/8" x 5.5" Baker ZXP Lnr Top Pkr (4.89" Min ID) 7 5/8" x 5.5" Baker Flex Lock Lnr Hgr Baker Csg Seal Bore Receptacle (4.75 Bore ID) w/ 80-47 Seal Assembly stung in (3.87 ID) 1496S'I 14976'1 I sooo'l 1 s06s'I I s076'I 1 s083'I 1 s090'I 1 s100'I 5.5" X 4.5" X-over Pup 4" Screened Lnr 5208' - 9195' 6 1/8" Hole \,c@ 9242.' (3660' tvd) 8tm. HES 41/2" Guide Shoe 9242' MILNE POINT UNIT WELL 8-22 API NO: 50-029-23176-00 BP EXPLORATION (AK) e STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMIS~ : REPORT OF SUNDRY WELL OPER _~.jl ~~f\'ìY 1. Operations Performed: RepairWellD Pluç¡ PerforationsD ;) [:.1 Abandon D &'m,'ate DO· . îa$~~~éO. Alter Casing D Pull Tubing 0 Perforate New Pool 0 wÞ..\a&~~~ xt~jOI)D Change Approved Program D Operation Shutdown 0 Perforate ŒJ nC \""'J Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Œ] ExploratoryD 203-1470 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-23176-00-00 7. KB Elevation (ft): 9. Well Name and Number: 72.18 MPS-22 8. Property Designation: 10. Field/Pool(s): ADL-380109 Milne Point Field I Ugnu Oil Pool 11. Present Well Condition Summary: Total Depth measured 9242 feet true vertical 3662.2 feet Plugs (measured) None Effective Depth measured 9242 feet Junk (measured) None true vertical 3662.2 feet Casing Length Size MD TVD Burst Collapse Conductor 75 20" 94# H-40 35 - 110 35.0 - 110.0 1530 520 Liner 49 4-1/2" 12.6# L-80 5076 - 5125 3708.2 - 3718.3 8430 7500 Liner 4071 4" 9.5# L-80 5125 - 9196 3718.3 - 3662.7 7910 6590 Liner 46 4-112" 12.6# L-80 9196 - 9242 3662.7 - 3662.2 8430 7500 Production 5184 7-5/8" 29.7# L-80 32 - 5216 32.0 - 3735.9 6890 4790 Surface 2526 10-3/4" 45.5# L-80 35 - 2561 35.0 - 2407.0 5210 2480 Perforation depth: Measured depth: See Attachment True vertical depth: See Attachment Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 30 - 5118 Packers & SSSV (type & measured depth): 5-1/2" Baker ZXP Hydro Set Packer @ 5083 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubinç¡ Pressure Prior to well operation: 154 0.01 0 600 294 Subsequent to operation: 151 0.01 0 0 244 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development ŒI ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations_ ! OilŒ] GasD WAGD GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact Garry Catron N/A Printed Name Garry Catron Title Production Technical. Assistant Signature i:1 /1 ~ -..-. (ph-- Phone 564-4657 Date 9/23/04 <.I Form 10-404 Revised 4/2004 u ¡¡\J/--\L R8r~S8fL SfP 2 \) 10~~ . . Attachment Perforations (MD): Perforations (TVD): Perforations (MD): Perforations (TVD): Top I Base Top I Base Top I Base Top I Base 5208 5246 3734.4 3741 .16 7897 7934 3636.76 3637.38 5253 5320 3742.24 3750.34 7975 8013 3637.92 3638.64 5363 5399 3753.56 3754.34 8056 8093 3639.9 3641.18 5440 5460 3755.17 3755.66 8136 8174 3642.5 3643.63 5460 5477 3755.66 3756.14 8216 8253 3644.56 3645.29 5477 5485 3756.14 3756.37 8294 8331 3645.38 3644.59 5518 5556 3757.39 3758.54 8372 8409 3643.57 3643.08 5598 5636 3759.73 3760.84 8452 8490 3642.57 3641.93 5678 5690 3762.13 3762.47 8532 8569 3641 .41 3641.53 5690 5715 3762.4 7 3763.15 8610 8647 3641.91 3642.83 5758 5796 3764.23 3764.95 8688 8726 3643.99 3645.15 5834 5872 3764.7 3762.58 8767 8805 3646.56 3647.86 5915 5920 3759.7 3759.37 8846 8884 3649.58 3651.59 5920 5945 3759.37 3757.67 8925 8962 3653.55 3655.13 5945 5952 3757.67 3757.2 9003 9040 3657.16 3659.21 5995 6032 3754.26 3751.73 9081 9118 3660.76 3662.21 6073 6111 3748.95 3746.44 9158 9196 3663.09 3662.72 6150 6154 3744.05 3743.81 6154 6175 3743.81 3742.59 6175 6191 3742.59 3741.68 6234 6271 3739.1 3736.67 6311 6349 3733.99 3731.79 6380 6391 3730.03 3729.4 6391 6405 3729.4 3728.6 6405 6429 3728.6 3727.21 6472 6509 3724.66 3722.45 6550 6587 3719.76 3716.08 6610 6630 3713.64 3711.47 6630 6635 3711.47 3710.92 6635 6667 3710.92 3707.56 6709 6746 3704 3701.4 6788 6826 3698.05 3694.66 6868 6890 3690.7 3688.91 6890 6906 3688.91 3687.78 6906 6915 3687.78 3687.18 6946 6984 3685.29 3683.02 7026 7064 3680.55 3678.01 7106 7143 3674.71 3671.39 7184 7222 3667.37 3663.64 7264 7300 3660.11 3656.99 7300 7302 3656.99 3656.81 7302 7325 3656.81 3654.77 7345 7382 3652.99 3649.73 7425 7462 3645.95 3642.68 7504 7542 3639.16 3636.56 7582 7620 3634.91 3634.12 7663 7670 3633.73 3633.71 7741 7778 3633.96 3634.37 7819 7856 3635.23 3636.11 · e MPS-22 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/24/04 Perforate 7300'-7325' 6 SPF 07/25/04 Perforate 5690'-5715' 6 SPF, 5920'-5945' 6 SPF, 6150'-6175' 6 SPF, 6380'-6405' 6 SPF, 6610'-6635' 6 SPF, 6890'-6915' 6 SPF 07/26/04 Perforate 5460'-5485' 6 SPF FLUIDS PUMPED BBLS 233 1 % KCL 921 1 % XSLK KCL 30 Flo Pro 1184 TOTAL Page 1 Tree' 4-1/16" - 5M FMC _ Wellhead' 11" x 4.5" 5M Ge"" wI 4.5" TCII T&B Tubing Hanger CIW "H" BPV profile MPS-22 20" x 34" insulated, 215 #/ft A-53 c::!1Ð 103/4" 45.5 #/ft L-80 BTC I 2561 i 75/8" 29.7# L-80 IBT-M casing ( drift ID = 6.75", cap = .0262 BPF w/ tbg. ) 4.5" 12.6# L-80 IBT-M tubing ( ID = 3.958", cap = .0152 BPF ) Perforation Summary Ref loa: PDS Tie in log 7/24/04 Size spf Interval 2.5 6 2.5 6 2.5 6 2.5 6 2.5 6 2.5 6 2.5 6 2.5 6 5,460' - 5,485' 5,690' - 5,715' 5,920' - 5,945' 6,150' - 6,175' 6,380' - 6,405' 6,610' - 6,635' 6,890' - 6,915' 7,300' - 7,325' 2.5" HMX 6SPF Random orieniation 75/8" HES Float Collar 5128' 7 5/8" HES Float Shoe 5216' .~ DATE REV. BY COMMENTS 10/6/03 08/13/04 Lee Hulme Drilled and Completed by Doyon 14 MDO CTU Add perfs ~B elev. = 72.00' (Doyon 14) ~L. elev.= 30.04' (Doyon 14) KOP @ 425' Hole angle passes 50 degrees @ 2770' Max angle in tubing = 78 degree 73 degrees at sliding sleeve Camco 4.5" x 1" w/ BK latch sidepocket KG B-2 GLM I 2107' I t· ." :/~\. Min. IDtt:!róugh tubing 3.813"@ 4976' Min. IDtti~ough>XN 3.725" @ 5065' .. Phoenix Discharge gauge (3.956 ID) 14965' I 4.5" HES "XD" Dura sliding sleeve 3.813" ID (Opens down) 14976' I Phoenix Jet Pump gauge sensor (3.833" ID) (3690' tvd) 4.5" HES 'XN' Nipple (3.813 Pkg ID, 3.725 No-go ID) 7 5/8" x 5.5" Lnr Tie Back Sleeve 15000' I I 5065' I 15076' I I 5083' I 7 5/8" x 5.5" Baker ZXP Lnr Top Pkr (4.89" Min ID) 7 5/8" x 5.5" Baker Flex Lock Lnr Hgr I 5090' 1 Baker Csg Seal Bore Receptacle I 5100' 1 (4.75 Bore ID) . w/ 80-47 Seal Assembly stung in (3.87 ID) 5.5" X 4.5" X-over Pup 1 5120' I 61/8" Hole td @ 9242' (3660' tvd) 4" Screened Lnr 5208' - 9195' Btm. HES 4 1/2" Guide Shoe 9242' MILNE POINT UNIT WELL 5-22 API NO: 50-029-23176-00 BP EXPLORATION (AKì . . 803~/'I t WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 09, 2003 RE: MWD Formation Evaluation Logs MPS-22, AK-MW-2678821 1 LIS formatted Disc with verification listing. J/l305 ilPI#: 50-029-23176-00 cY' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Signed~"'~(";;\~~-.I. ;'V\. "'~ ,0 l~~ f~- ~~~\'<"\~ a STATE OF ALASKA .. ALASKA" AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised 12/03/03, Start Production 1a. Well Status: IHI Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 IHI Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit Number BP Exploration (Alaska) Inc. 10/6/2003 203-147 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/27/2003 50- 029-23176-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Number Surface: 10/4/2003 MPS-22 3297' NSL, 238' WEL, SEC. 12, T12N, R10E, UM 8. Elevation in feet (indicate KB, DF, etc.) 15. Field and Pool Top of Productive Horizon: 2431' NSL, 2935' WEL, SEC. 12, T12N, R10E, UM KBE = 72.18' Milne Point Unit / Ugnu Total Depth: 9. Plug Back Depth (MD+ TVD) 803' NSL, 1033' WEL, SEC. 11, T12N, R10E, UM 9242 + 3662 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Lease Designation and Serial No. Surface: x- 565773 y- 5999964 Zone- ASP4 9242 + 3662 Ft ADL 380109 TPI: x- 563083 y- 5999075 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 559720 y- 5997419 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey IHI Yes DNa N/A MSL 1800' (Approx.) 21. Logs Run: GYRO, MWD , GR , RES, IFRlCASANDRA , ABI , PWD 2. CASING, LINER AND CEMENTING RECORD CASING . ~ETTING LJEÞ'tH HOLE ............ " SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 92# H-40 35' 110' 42" 60 sx Arctic Set (Approx.) 10-3/4" 45.5# L-80 35' 2561' 13-1/2" 85 sx Class 'L', 312 sx Class 'G' 7-5/8" 29.7# L-80 32' 5216' 9-7/8" 92 sx Class 'G' 5" x4" 15.5# x 9.5# L-80 5076' 9242' 6-1/8" Sand Screen Liner 23. Perforations open to Production (MD + TVD of Top and ?4:I..ii ...." ..I,IT"åING·.... ¡i II¡ii 'i Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4" Sand Screen Liner 4-1/2", 12.6#, L-80 5118' 5083' MD TVD MD TVD 1?5. ".."."I¡'··ftC!~IF"·' .'~"¡ \i:î'¡;¡';', ~ 5208' - 9195' 3734' - 3663' 'i" .,.·{·;'0'- ",.,.". DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 82 Bbls of Diesel. 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): November 24, 2003 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF WATER-BSL CHOKE SIZE GAS-OIL RATIO 11/19/2003 6 TEST PERIOD .. 69 4 0 64 Flow Tubing Casing Pressure CALCULATED .. OIL-BSL GAs-McF WATER-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 (a a . ssary). Submit core chips; if none, state "none". J .- -~¡"..:-- None DEC - 3 2003 ORIGINAL Aiaska Oil & Gas Cons. Commission Anchorage Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE ,.-- G l'" RBDMS Bfl DEC ,~¡003 28. GEOLOGIC MARKERS NAME MD rvD 5187' 3730' 5437' 3755' 6818' 3695' 7437' 3645' 7794' 3635' 8860' 3650' MA MSI MSI MA MA MSI 29. .RMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests 'were conducted. state "None". None RECEIVED DEC - 3 2003 Alaska Oil & Gas Cons. CommissiQn Anchorage 30. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Work Summary and a Leak-Off Test summary. Signed Title 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. I . Date IfJ -(5)-0 Technical Assistant Sondra MPS-22 Well Number 203-147 Permit No. / A roval No. Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Matt Green, 564-5581 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". O Q I G I ~\LA L . r..,cr~"'~Yf~·ij¡ii. Form 1 0-407 Revised 2/2003 I STATE OF ALASKA _ .. ALASKA AND GAS CONSERVATION COM~ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 18. Well Status: DD Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 DD Development o Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit Number BP Exploration (Alaska) Inc. 10/6/2003 .. 203-147 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/27/2003 . 50- 029-23176-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Number Surface: 10/4/2003 - MPS-22 3297' NSL, 238' WEL, SEC. 12, T12N, R10E, UM 8. Elevation in feet (indicate KB, DF, etc.) 15. Field and Pool Top of Productive Horizon: 2431' NSL, 2935' WEL, SEC. 12, T12N, R10E, UM KBE = 72.18' Milne Point Unit I Ugnu Total Depth: 9. Plug Back Depth (MD+ TVD) 803' NSL, 1(33' WEL, SEC. 11, T12N, R10E, UM 9242 + 3662 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Lease Designation and Serial No. Surface: x- 565773' y- 5999964 \ Zone- ASP4 9242 + 3662 Ft ADL 380109 --~ 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 563083 y- 5999075 Zone- ASP4 Total Depth: x- 559720 y- 5997419' Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DD Yes DNo N/A MSL 1800' (Approx.) 21. Logs Run: GYRO, MWD , GR , RES, IFRlCASANDRA , ABI , PWD 22. CASING, LINER AND CEMENTING RECORD '''~AC::INr::'' .......... SETTING UEPTR ..... ~?~f. . '1sTiË' ... wT .þf;RFT.( .·..GRAPIE Top BOTTOM ..... 6n 20" 92# H-40 35' 110' 42" 260 sx Arctic Set (ADDrox.) 10-3/4" 45.5# L-80 35' 2561' 13-1/2" ~85 sx Class 'L', 312 sx Class 'G' 7-518" 29.7# L-80 32' 5216' 9-7/8" )92 sx Class 'G' 5" x4" 15.5# x 9.5# L-80 5076' 9242' 6-1/8" Sand Screen Liner 23. Perforations open to Production (MD + TVD of Top and 24.·.····· IBING. Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4" Sand Screen Liner 4-1/2", 12.6#, L-80 5118' 5083' MD TVD MD TVD 5208' - 9195' 3734' - 3663' 25. " .,t.,cID" pt:Mt:NI ETP,......". DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 82 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 -BBl GAs-McF W A TER-BBl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... Oll-BBl GAs-McF W A TER-BBl 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".r·'··..·....., " ~ CDrr?i..r:;"iON ! , "', ~'·,,..n , None V&,~~ ! VEfiiFim JO DIG , ~\, A L I ~ ! . ,,~ ì. ~ ,. ¡ ( ..:._ ",' , . ", "J ...f't Form 10-407 Revised 2/2003 - )..... CONTINUED ON REVERSE SIDE tlØl8BfL (:l 28. GEOLOGIC MARKERS 29. MATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". MA 5187' 3730' None MBI 5437' 3755' MBI 6818' 3695' MA 7437' 3645' MA 7794' 3635' MBI 8860' 3650' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Work Summary and a Leak-Off Test summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Technical Assistant Date MPS-22 Well Number 203-147 Permit No. I A roval No. Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Matt Green, 564-5581 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". ORIG'~~AL Form 10-407 Revised 2/2003 ·.. .. . ..... . . BP ExÞLoRATION (,)perations Summary Report .,.:.:.:...:. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-22 MPS-22 DRILL +COMPLETE DOYON DRilLING INC. DOYON 14 Däte From - To Hours Task" Code NPT Phase -------- 9/26/2003 21 :00 - 23:30 2.50 MOB P PRE 23:30 - 00:00 0.50 RIGU P PRE 9/27/2003 00:00 - 03:00 3.00 RIGU P PRE 03:00 - 09:30 6.50 RIGU P PRE 09:30 - 11 :00 1,50 RIGU P PRE 11 :00 - 11 :30 0.50 DRILL P SURF 11 :30 - 12:00 0.50 BOPSU P SURF 12:00 - 13:00 1.00 DRILL P SURF 13:00 - 13:30 0.50 DRILL P SURF 13:30 - 14:30 1.00 DRILL P SURF 14:30 - 15:30 1.00 DRILL P SURF 15:30 - 00:00 8.50 DRILL P SURF 9/28/2003 00:00 - 16:00 16.00 DRILL P SURF 16:00 - 18:00 2.00 CASE P SURF 18:00 - 19:30 1.50 CASE P SURF 19:30 - 20:00 0.50 CASE P SURF 20:00 - 21 :30 1.50 CASE P SURF 21 :30 - 22:30 1.00 CASE P SURF 22:30 - 00:00 1.50 CASE P SURF 9/29/2003 00:00 - 01 :30 1.50 CASE P SURF 01 :30 - 02:30 1.00 CASE P SURF 02:30 - 05:30 3.00 CASE P SURF 05:30 - 06:00 0.50 CASE P SURF 06:00 - 07:30 1.50 CASE P SURF 07:30 - 09:30 2.00 CEMT P SURF 09:30 - 11 :00 1.50 CASE P SURF 11 :00 - 12:00 1.00 CASE P SURF 12:00 - 15:00 3.00 CASE P SURF 15:00 - 19:00 4.00 BOPSU P SURF 19:00 - 19:30 0.50 CASE P SURF 19:30 - 21 :00 1.50 CASE P SURF 21 :00 - 21 :30 0.50 CASE P SURF 21 :30 - 23:00 1.50 CASE P SURF 23:00 - 23:30 0.50 CASE P SURF . ' Pag~Jof ~, Start: 9/17/2003 Rig Release: 10/7/2003 Rig Number: 14 Spud Date: 9/27/2003 End: 10/6/2003 Description of Operations Move rig from MPS-25 Load pipe shed, Nippling up 21 1/4 Diverter Nipple up Diverter, load pipe shed, Derrick inspection Picking up drill pipe from shed standing in derrick, Mixing spud mud Pick up BHA #1 Rig up Gyro, Prime pumps Function test Diverter, Lou Grimaldi of AOGCC witnessed test Program MWD, M/U BHA Pre Spud meeting Spud well, Drill 112 to 257 Pick up BHA Directional drill 257' to 665' with 400 gals min. 1200 psi, 70 rpms, running Gyros every 30' ART 1.5 AST 2.08 Directional drill 665 to 2570' with 400 gals min. 1300 psi, 80 rpms Running Gyros to 800 ft. total of 13 Gyros run AST 7 ART 4.75 Circ, Three bottoms up with 500 gals, 2000 psi, 100 rpms Pumping out to HWP with full drilling rate Trip back to bottom Circ, Three bottoms up with 500 gals, 2000 psi, 100 rpms Pumping out to HWP with full drilling rate Trip out with, BHA Laying down BHA, clear floor Rig up to run CSG, PJSM Picking up 10.7545.5# L-80 BTC CSG, 61 jts total 2521 ft., shoe 2561, float 2478, P/U 175000 S/O 120,000 Rig down franks tool, rig up cement head Circ, two CSG volumes reduce mud vis for cement job. 378 gals min , 350 psi, PJSM on cementing Cement with Dowell with 10 bbls water, test lines to 3500 psi,10 bbls water, 50 bbls 10.3 mud push, one gal of dye in first 5 bbls of mud push,drop bottom plug, mixed and pump 485 sx, type ASL, 370 bbls mixed @ 10.7, Tail with 312 sxs Class G, 64.5 Bbls mixed @ 15.8, drop top plug, 30 bbls water, displace with rig pump 208 bbls mud, cement was mix and pumped 6.5 bbls min., Displace @ 10 bbls min.,full returns, 238 bbls cement to surface, bumped plug with 1580 psi, floats held Flush Diverter ,RID cement head, Lay down landing Jt. Nipple down diverter Nipple up FMC 11" 5,000# casing head and 11" X 11" Tubing head Nipple up BOPS Test Bops and manifold with 250-3500 psi for 5 min. per test, Annular 250-2500 psi for 5 min. per test, The right to witness test was wavier by John Crisp AOGCC, install wear ring Mobilize BHA, change out bails and elevators Picking up BHA #29.875 FGXIVC w/3-15 1-10 jets, 7" sperry drill with 1.22 bend,stab,float sub,6 3/4 GRlRES, 63/4 DM, hang off sub,stab, 3 flex dc, stab, 12 hwdp,jars,5 hwdp Trip in hole to 2448 Slip and cut drillline,Circ bottoms up while cutting drlg line Test csg to 2500 psi for 30 min. Printed: 10/13/2003 9:08:49 AM BP:EXPLORA TION Operåtiogs '$ummary Report Page 2 of 5 Legal Well Name: MPS-22 Common Well Name: MPS-22 Spud Date: 9/27/2003 Event Name: DRILL +COMPLETE Start: 9/17/2003 End: 10/6/2003 Contractor Name: DOYON DRILLING INC. Rig Release: 10/7/2003 Rig Name: DOYON 14 Rig Number: 14 , I ' I " Hours I Task .. . ... ... , Description of Operations ,>,'," ';,Date From:- To" Cödê NPT ,Phase , I 9/29/2003 23:30 - 00:00 0.50 DRILL P INT1 Drill float collar and cement 9/30/2003 00:00 - 00:30 0.50 DRILL P INT1 Drill cement and float shoe @ 2561 and 20' new hole to 2,590' 00:30 - 01 :00 0.50 DRILL P INT1 Circ bottoms up, displace with new 9.0 mud 01 :00 - 01 :30 0.50 DRILL P INT1 Fit test with TVD 2400, MW 9.0, 315 psi= EMW 11.5 01 :30 - 19:00 17.50 DRILL P INT1 Directional Drill 2590' to 5225' with 450 GPM, PP on 2400 - off 2030 - RPM 120 - TQ on 9K - off 7K - PU 145K - SO 85K- ROT 108K 19:00 - 21:30 2.50 DRILL P INT1 CBU 3 X - 12,500 strokes - 450 gpm - PP 2200 - RPM 120 - TQ 8K - PU 148K - SO 85K - ROT 108K 21 :30 - 23:30 2.00 DRILL P INT1 Pump out to shoe from 5225' to 2524' - Full drlg rate 450 gpm - Hole in good shape 23:30 - 00:00 0.50 DRILL P INT1 CBU at shoe - Lots of clay balls circulated out of hole 10/1/2003 00:00 - 01 :00 1.00 CASE P INT1 RIH from 2524' to 5135' - Precauctionary wash from 5135' to 5225' - Hole in good shape - No problems 01 :00 - 03:00 2.00 CASE P INT1 CBU 3 X - 12,500 strokes - GPM 480 - PP 2540 - RPM 100- TQ 7K - PU 148K - SO 86K - ROT 110K - Monitorwell- well static 03:00 - 05:00 2.00 CASE P INT1 Pump out from 5225' to 2524' - Pump out at drlg rate 450 gpm - Hole in good shape 05:00 - 05:30 0.50 CASE P INT1 CBU - GPM 480 - PP 1800 05:30 - 06:30 1.00 CASE P INT1 Con't POH from 2524' to 710' @ BHA 06:30 - 08:00 1.50 CASE P INT1 Lay down 5" HWT - 8" BHA 08:00 - 10:00 2.00 CASE P INT1 Change out top rams to 7 5/8" - Rig up to run casing - Pull wear ring - Install tst plug - Body test BOP's to 1500 psi 10:00 - 10:30 0.50 CASE P INT1 PJSM ôn running 7 5/8" casing 10:30 - 13:00 2.50 CASE P INT1 Pick up and run 60 joints of 75/8" 29.7# L-80 BTC-M casing to 2450' 13:00 - 13:30 0.50 CASE P INT1 Circulate casing volume 116 bbls - 1200 strokes @ 6 bpm - PP 350 13:30 - 16:00 2.50 CASE P INT1 Con't run in hole with 7 5/8" casing from 2450' to 5135' - break circulation last joint - wash from 5135' to 5175' - Make up landing joint I hanger to casing - Land casing on hanger @ 5215' - 123 total Joints of 75/8" 29.7# L-80 BTC-M casing ran- Shoe 5215' - Float collar 5128' 16:00 - 16:30 0.50 CASE P INT1 Rig down Frank's fill up tool - Make up Schlumberger cementing head - Cementing lines 16:30 - 18:30 2.00 CASE P INT1 Circulate two casing volume's - 5000 strokes - 6 bpm @ 360 psi - No losses 18:30 - 19:30 1.00 CEMT P INT1 Schlumberger pump 5 bbl water - Test lines to 3500 psi - Pump 15 bbls water 4 bpm @ 380 psi - 30 bbls Mud Push mixed at 10.2 - 5 bpm @ 500 psi - (Dropped btm plug last 5 bbls spacer pumped on the fly) - Mix and pump 63 bbls 292 sxs of Class "G" cement - mixed at 15.8 - with .3% D065 - 2% S001 - .3% D167 - .2% D046 - 3% D174 - Yield 1.21 culsx - Drop top plug - Displace with 20 bbls water with Schlumberger - Give to rig - displaced with 216 bbls of mud at 6 bpm @ 200 psi - bumped plug with 1500 psi - 1000 over circulating pressure - Held pressure for 3 mins - bleed off pressure - floats holding - CIP 19:30 hrs 19:30 - 20:30 1.00 CASE P INT1 Rig down Schlumberger cementing head - cmt lines - Rig down elevators - clear floor of casing tools I cementing tools - lay down landing joint 20:30 - 21 :00 0.50 CASE P INT1 Install FMC 7 5/8" pack-off - Test to 5K for 10 mins - Test good Printed: 10/13/2003 9:08:49 AM .:.... '~~: :. . . ... . ... .......... - -- .. . ... . .. .. .. .. ...... .. ... -- --e·þ EXPLORATION - -- :(>perations SUmmary Report - - ... .." . : Legal Well Name: MPS-22 Common Well Name: MPS-22 Event Name: DRILL +COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date I From -~ To ,Hours Task 10/1/2003 10/2/2003 10/3/2003 10/4/2003 1 0/5/2003 21 :00 - 22:00 22:00 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 03:00 03:00 - 04:00 04:00 - 04:30 04:30 - 05:30 05:30 - 07:00 07:00 - 07:30 07:30 - 00:00 00:00 - 01 :00 01 :00 - 09:00 09:00 - 10:30 10:30 - 12:00 00:00 - 03:00 03:00 - 05:00 05:00 - 07:30 07:30 - 09:30 09:30 - 10:30 10:30 - 11 :30 11 :30 - 15:30 15:30 - 17:30 17:30 - 19:30 19:30 - 22:30 22:30 - 23:00 23:00 - 00:00 00:00 - 01 :00 -'Page 3 of 5 . 9/17/2003 10/7/2003 14 Spud Date: 9/27/2003 End: 10/6/2003 Start: Rig Release: Rig Number: Phase L______._. 1.00 CASE I Code I_~PT ¡ P INT1 1.00 CASE P INT1 0.50 CASE P 0.50 CASE P 1.50 CASE P INT1 INT1 INT1 1.50 CASE P 1.00 CASE P 0.50 CASE P 1.00 DRILL P 1.50 CASE P 0.50 DRILL P INT1 INT1 INT1 INT1 INT1 INT1 16.50 DRILL P INT1 1.00 DRILL P INT1 8.00 DRILL P INT1 1.50 DRILL P INT1 1.50 DRILL P INT1 3.00 DRILL P INT1 2.00 CLEAN P 2.50 CLEAN P 2.00 CLEAN P 1.00 CLEAN P 1.00 CLEAN P 4.00 CLEAN P COMP COMP COMP COMP COMP COMP 2.00 CLEAN P COMP 2.00 CLEAN P COMP 3.00 CLEAN P COMP 0.50 CLEAN P COMP 1.00 CLEAN P 1.00 CLEAN P COMP COMP Description of Operations Change out top rams from 7 5/8" casing rams to 2 7/8" X 5" variable Install upper test plug - Open annulus valves - Test top rams to 250 low 3500 high for 5 mins each test - pull test plug - Install wear ring - Close annulus valves Install bails - elevators - pick up BHA to rig floor Make up bit - motor - mwd - orient same Con't pick up BHA - From bit to GR 54.03 - RES 46.97 - DM 68.13 - PWD 75.76 - Surface test MWD @ 217' RIH from 217' to 5100' - Fill pipe @ 2600' Cut drlg line - Service top drive Test casing to 3500 psi for 30 mins - record on chart Drill float equipment - 20' new hole from 5225' to 5245' Displace with 9.5 ppg Flo Pro Perform FIT - TVD 3737' - MD 5216' - Mud weight 9.5- surface pressure 390 = 11.5 EMW - Recorded on chart Directional Drill from 5245' to 7171' - WOB 4K to 8K - RPM 80- TQ on 7K - off6K - PP on 2120 - off 1820 - PU 125K - SO 65K - ROT 95K CBU - ECD 11.6 - PP on btm 2120 psi - GPM 250 - RPM 80- TQ 6K - PP 2020 off btm - ECD after CBU up 11.1 Directional Drill from 7171' to 7987' - WOB 4K to 8K - RPM 80 - TQ on 8K - off 5K - GPM 250 - PP 2250 - off 1800 - PU 125K- SO - 65K - ROT 1 OOK ECD 11.87 - CBU 3 X - PP on btm 2250 psi - GPM 251 - RPM 80 - TQ 6K - PP off btm 1800 - ECD after CBU 11.6 Directional Drill from 7987' to 9190' - WOB 4K to 10K - RPM 80 - TQ 6K on - off 5K - GPM 250 - PP 1900 - off 1700 - PU 117K - SO 60K - ROT 98K Directional Drill from 9190' to 9242' - T.D. 6.125" hole - WOB 10K - RPM 80 - TQ on 8K - off 5K - GPM 250 - PP on 1850- off 1700 - PU 117K - SO 60K - ROT 98K CBU 3 X - 7500 strokes - GPM 260 - RPM 100 - TQ 5K Pump out from 9242' to 5800' at full drlg rate 250 gpm Mad Pass log from 5800' to 5216' - @ 450' per hour Monitor well - well static - Pump dry job - POH to BHA Lay down 6.125" BHA - Make up hole opener RIH with hole opener to 9242' - No problems hole in good condition CBU 3 X - 7500 strokes - RPM 120 - TQ 5K - GPM 293 - PP 2380 Displace well to solids free 9.5 ppg Flo Pro - Pump 20 bbls spacer - Pump 160 bbls 9.5 brine @ 3.9 bpm @ 1000 psi- Pump 440 bbls of 9.5 ppg Flo Pro - Pump 4 bpm and RPM 45 for 209 bbls of spacers and Flo Pro pumped - Increase to 7 bpm @ 2300 psi and RPM 120 TQ 5K for remaining displacement of Flo Pro - Monitor well - well static Pump out from 9242' to 5216' - Pump at drlg rate 250 gpm- Hole in good shape - No problems CBU @ 5150' - 230 GPM - PP 1300 - RPM 120 - TQ 3K - Drop 2" drift down D.P. Con't POH to BHA from 5150' to 1100' Con't POH - Lay down Jars - 6.125" hole opener Printed, 10/13/2003 9,08A9 AM ,)!SP EXPLORATION <J~age4 of 5 Oper$tions Summary Report .:~~,; i ~.'. Legal Well Name: MPS-22 Common Well Name: MPS-22 Spud Date: 9/27/2003 Event Name: DRILL +COMPLETE Start: 9/17/2003 End: 10/6/2003 Contractor Name: DOYON DRILLING INC. Rig Release: 10/7/2003 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours ¡ Task' ¡code ,NPT Phase Description of Operations ! 10/5/2003 01 :00 - 02:00 1.00 CASE P COMP Rig up to run 4" C27 Saker Med Excluder IST-M Screen liner- PJSM running screen liner 02:00 - 06:30 4.50 CASE P COMP PIU and run Screen liner - 51 total 4" screens - 50 total 4" blanks ran - PU Saker hanger I Packer make up to liner - One centralizer per screen and two centralizers per joint on blanks - Total ran 151 centralizers - 50 stop rings 06:30 - 08:30 2.00 CASE P COMP Con't RIH with liner on 4" DP to 9242' - PU 128K - SO 85K 08:30 - 09:30 1.00 CASE P COMP Set liner hanger @ 4000 psi - Test annulus to 2000 psi - Release from hanger - shear ball and seat 09:30 - 10:00 0.50 CASE P COMP Flow check well - pump dry job 10:00 - 13:00 3.00 CASE P COMP Stand back 9 stands - Lay down 4" drill pipe 13:00 - 13:30 0.50 CASE P COMP Lay down liner running tool 13:30 - 15:30 2.00 RUNCO COMP RIH with circulating tool to 5064' 15:30 - 18:00 2.50 RUNCO COMP Displace Flo Pro with 8.7 brine 435 bbls - followed by 9.2 brine 290 bbls w/1 drum of corrision inhibitor added - 10 bpm @ 1300 psi - 120 rpm TQ 2K - Flow check - well static 18:00 - 21:30 COMP Lay down 4" drill pipe 21 :30 - 22:30 COMP Pull wear ring - Rig up casing tools - Rig up I-wire spool - PJSM on running tubing 22:30 - 00:00 COMP Run 4.512.6# L-80 1ST Tubing completion - Make up seal assembly - XN nipple - 4.5" Phoenix pressure sensor - HES dual sliding sleeve - Phoenix Discharge pressure gauge - Tie the gauge - sensor with I-wire and test - 10/6/2003 00:00 - 06:00 COMP Con't run 4.5" completion - Total joints ran 1204.5" L-80 12.6# 1ST tubing - Pick up and make up space out pup, landing jt and hanger(TWC installed) - make up I-wire to hanger and test. PU weight 95K SO weight 85K. 06:00 - 06:30 COMP Test 7-5/8" X 4-1/2" annulus to 1500 psi. Tested TWC to 1000 psi from the top. Laid down landing joint. 06:30 - 07:00 COMP Laid down tubing running tools and cleared floor. 07:00 - 08:00 COMP Nipple down SOPE. 08:00 - 10:00 COMP Nippled up adapter flange and CIW 4-1/16" 5M tree. Tested tree and adapter flange to 5000 psi. 10:00 - 10:30 COMP Rigged up lubricator and pulled TWC. 10:30 -13:30 DFAL COMP Dropped 1-7/8" ball and rod assembly and rigged up First Energy on tubing. Attempted to pressure test tubing, ball not on seat. Dropped 1.81" OD blind box with rollers. Pressured up on tubing to 4000 psi. Pressure bled off 1000 psi per minute. Pressured back up on tubing and pressure bled off at same rate. No flow on annulus. Appears to be leaking past ball on RHC plug. . 13:30 - 14:30 COMP Tested 4-1/2" X 7-5/8" annulus to 1500 psi for 30 minutes. Good test. Recorded on chart. 14:30 - 15:00 0.50 COMP Install TWC in tubing hanger and test from the top to 1000 psi. 15:00 - 16:00 1.00 COMP Secure tree and rinse out pits. RELEASED RIG AT 1600 HRS 10-6-2003. 00:00 - 0.00 CONS P PRE RIG MAINTENANCE 16:00 - 17:00 1.00 CONS P PRE Add wraps to drawworks for laying down top drive 17:00 - 18:00 1.00 CONS P PRE Take torque tube off top drive 18:00 - 19:00 1.00 CONS P PRE Prepare top drive to lay down 19:00 - 21:00 2.00 CONS P PRE Lay down top drive 21 :00 - 00:00 3.00 CONS P PRE Clear floor - Install traveling block carriage - Rig up derrick to Printed: 10/13/2003 9:08:49 AM .. ", . . . .. . .. . . . . . . . . . ... . .·¡i~:'BPExPLöRA TION , Operþti()ns Summary Report Pêige 9 of'S Legal Well Name: MPS-22 Common Well Name: MPS-22 Event Name: DRILL +COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date:; .·1 From - To Hours Task CQde NPT I 10/6/2003 21 :00 - 00:00 3.00 CONS P 1017/2003 00:00 - 02:00 2.00 CONS P 02:00 - 03:30 1.50 CONS P 03:30 - 04:00 0.50 CONS P 04:00 - 05:00 1.00 CONS P 05:00 - 08:00 3.00 CONS P 08:00 - 10:00 2.00 CONS P 10:00 - 16:00 6.00 CONS P 16:00 - 18:00 2.00 CONS P 18:00 - 19:30 1.50 CONS P 19:30 - 00:00 4.50 CONS P 10/8/2003 00:00 - 12:00 12.00 CONS P .. ., .~ Start: Rig Release: Rig Number: Phase 9/17/2003 10/7/2003 14 Spud Date: 9/27/2003 End: 10/6/2003 Description. of Operations ... .... ..--.---.--- PRE lay down - modify possum belly PRE RIG MAINTENANCE Bridle up tie back lines in derrick PRE Raise and pin C-section PRE Blow down rig floor - prepare to slide rig floor from drlg position to move position PRE Slide rig floor from drlg position to move position PRE Move rig off well S-22 - spot rig for maintenance PRE Prep derrick for laying down - lay down derrick PRE Rig up to unstring blocks - Unstring blocks PRE prepare crown to remove crown sheaves PRE Remove crown sheaves - take to shop to rebuild PRE Rebuild and inspect crown sheaves - change out bolt on A-leg base - change shakle on top of block hanging line - change out choke hoses - PRE RIG MAINTENANCE Change out bolts in derrick base - Work on possum belly shaker box - Work on crown sheaves - prepare crown cluster to reinstall on derrick - Install heater in cellar Take slack out of block restring line - Install guards back on crown sheaves - Install hand rails around crown - Restring blocks and crown sheaves Raise derrick Skid rig floor from move position to drlg position Lower C-section - unbridle blocks - hang bridle lines in derrick RIG MAINTENANCE Remove trolly from blocks Pick up top drive Rig up lines on rig floor Cut drlg line Rig up top drive Replace chains in draworks - Change out leaking hyd line on top drive - service top drive - preform derrick inspection - repair fold out step on derrick board skid rig floor from drlg position to move position Weld covers under pits across abandon discharge line holes - 12:00 - 15:00 3.00 CONS P PRE 15:00 - 19:30 4.50 CONS P PRE 19:30 - 21 :00 1.50 CONS P PRE 21 :00 - 22:00 1.00 CONS P PRE 22:00 - 00:00 2.00 CONS P PRE 10/9/2003 00:00 - 02:00 2.00 CONS P PRE 02:00 - 03:00 1.00 CONS P PRE 03:00 - 05:00 2.00 CONS P PRE 05:00 - 06:00 1.00 CONS P PRE 06:00 - 10:00 4.00 CONS P PRE 10:00 - 19:30 9.50 CONS P PRE 19:30 - 20:30 1.00 CONS P PRE 20:30 - 22:00 1.50 CONS P PRE Printed, 10/13/2003 9,08A9 AM . . Well: Field: API: Permit: MPS-22 Milne Point Unit / Ugnu 50-029-23176-00-00 203-147 Accept: Spud: Release: Rig: 09/26/03 09/27/03 1 0/06/03 Doyon 14 .,=.=,.~~..., ~.... ,^' ·VYM"V" ·v..w, POST-RIG WORK 10/07/03 PULLED BPV, RIGGED UP 1" HOSE FROM WING VALVE TO BLEED TANK TO CIRCULATE FREEZE PROTECT DOWN lA, AND OUT TUBING. FREEZE PROTECT TUBING AND ANNULUS WITH DIESEL. 1 0/09/03 PULLED 5' OF ROLLER STEM & BLIND BOX @ 5028'WLM. PULLED BALL & ROD @ 5034'WLM. 10/10/03 TEST TBG AND IA. POST COMPLETION WORK. SET 13C JET PUMP, SER# BP-1070. TEST TBG AND IA. POST COMPLETION WORK. SET 13B JET PUMP, SER# BP-1070. 10/19/03 ALL SURFACE PIPING WAS LEAK TESTED AND TEST WAS GOOD. 1 0/20/03 TUBING, lA, AND SURFACE HARDLlNE FREEZE PROTECTED WITH 82 BBLS OF DIESEL. 10/24/03 PULLED JET PUMP, CLOSED SSD, PT CASING TO 2000#. HELD SOLID. 11/01/03 CTU #5, LNRfTBG WASH. RIH W/ 2.5" JET SWIRL NOZZLE. TAGGED TD @ 9185' CTM. LAY IN 80 DEG F 60/40 DIESEUXYLENE W/ 1% W54 AND 1% W60 DE-EMULSIFIERS. PUMPED A TOTAL OF 229 BBLS OF DIESEL XYLENE W/ AVERAGE OF 75% RETURNS TO TEST SEPARATOR. Printed: 10/13/2003 9:08:41 AM ~~~__,~jL. 11.53 (ppg) 11.51 (ppg) 11.51 (ppg) 11.51 (ppg) Page 1 of 1 _~~~~ Off ~~~..:ö.~r~,(~HP) I 1,437 (psi) 2,234 (psi) (psi) (psi) 315 (psi) 390 (psi) (psi) (psi) AMW Surface Pressure - ..-.....--..... ..-....... ....... 9.00 (ppg) 9.50 (ppg) (ppg) (ppg) Test Depth (TVD) 2,400.0 (ft) 3,737.0 (ft) (ft) (ft) BP EXPLORATION Leak-Off Test Summary ,Test Depth (TMD) ..-.--..,....- 25,661.0 (ft) 5,215.0 (ft) (ft) (ft) Test Type MPS-22 MPS-22 FIT FIT FIT FITO _...____._.~.__....__m.._... T~$t p;lte 9/30/2003 10/2/2003 1017/2003 10/9/2003 Legal Name: Common Name: e AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 e , 13-0ct-03 Re: Distribution of Survey Data for Well MPS-22 Gyro Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) "v~'Gr,\ ~b ðC6 --)1..11- ..... Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-22 Gyro Job No. SCIENTIFIC GYRO, Surveyed: 4 October, 2003 Survey Report 8 October, 2003 Your Ref: API 500292317600 . Surface Coordinates: 5999963.59 N, 565772.53 E (70024' 37.2367" N, 149027'51.9549" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 999963.59 N, 65772.53 E (Grid) Surface Coordinates relative to Structure: 6.37 S, 572.55 W (True) Kelly Bushing: 72. 18ft above Mean Sea Level Elevation relative to Project V Reference: 72. 18ft Elevation relative to Structure: 72.18ft sper"'r"ry-su., DAIL.L.ING SeAVICeS A Halliburton Company D EFI N ITIVE . . Survey Ref: svy1267 ...... Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-22 Gyro Your Ref: API 500292317600 Job No. SCIENTIFIC GYRO, Surveyed: 4 October, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured 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) 0.00 0.000 0.000 -72.18 0.00 0.00 N 0.00 E 5999963.59 N 565772.53 E 0.00 AK-1 BP _HG 99.00 0.340 312.590 26.82 99.00 0.20 N 0.22 W 5999963.79 N 565772.31 E 0.343 0.13 186.00 0.590 308.350 113.82 186.00 0.65 N 0.76W 5999964.23 N 565771.77 E 0.290 0.46 275.00 0.680 291.780 202.81 274.99 1.13 N 1.61 W 5999964.71 N 565770.91 E 0.229 1.07 307.00 0.810 273.520 234.81 306.99 1.22 N 2.01 W 5999964.79 N 565770.51 E 0.841 1.41 . 364.00 0.820 246.910 291.80 363.98 1.08 N 2.79W 5999964.65 N 565769.73 E 0.658 2.18 394.00 0.840 225.760 321.80 393.98 0.84 N 3.14W 5999964.41 N 565769.38 E 1.018 2.60 425.00 1.020 210.640 352.80 424.98 0.45 N 3.45 W 5999964.01 N 565769.08 E 0.977 3.03 455.00 1.310 192.120 382.79 454.97 0.12 S 3.65W 5999963.44 N 565768.88 E 1.572 3.43 484.00 1.560 184.700 411.78 483.96 0.84 S 3.76W 5999962.72 N 565768.78 E 1.072 3.80 512.00 2.120 175.570 439.77 511.95 1.73 S 3.75W 5999961.83 N 565768.80 E 2.251 4.12 544.00 2.740 170.760 471.74 543.92 3.08 S 3.58W 5999960.48 N 565768.98 E 2.038 4.47 634.00 5.270 175.680 561.51 633.69 9.32 S 2.92W 5999954.24 N 565769.69 E 2.834 6.19 725.00 7.140 194.960 651.98 724.16 18.96 S 4.07W 5999944.60 N 565768.63 E 3.050 10.85 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 248.080° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 725.00f1., The Bottom Hole Displacement is 19.39f1., in the Direction of 192.108° (True). . 8 October, 2003 - 8:53 Page 2 of 3 DrillQuest 3.03.02.005 .... Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-22 Gyro Your Ref: API 500292317600 Job No. SCIENTIFIC GYRO, Surveyed: 4 October, 2003 BP EXPLORA TlON (ALASKA) INC. Milne Point Unit BPXA Survey tool program for MPS-22 Gyro From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 725.00 724.16 AK-1 BP _HG . . 8 October, 2003 - 8:53 Page 3 of 3 DrillQuest 3.03.02.005 e AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-22 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 9,242.00' MD (if applicable) , Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~b"\)\\.,~ ÐO,.3"/L/7- 13-0ct-03 Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-22 Job No. AKZZ0002678821, Surveyed: 4 October, 2003 Survey Report 10 October, 2003 ~ Your Ref: API 500292317600 Surface Coordinates: 5999963.59 N, 565772.53 E (70024' 37.2367H N, 149027' 51.9549H W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 999963.59 N, 65772.53 E (Grid) Surface Coordinates relative to Structure: 6.37 S, 572.55 W (True) Kelly Bushing: 72. 18ft above Mean Sea Level Elevation relative to Project V Reference: 72.18ft Elevation relative to Structure: 72. 18ft spar"r"Y-SUf1 CAlLLlNG . SEAVn:::eS A Halliburton Company DEFINITIVE . . Survey Ref: svy1268 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-22 Your Ref: API 500292317600 Job No. AKZZ0002678821, Surveyed: 4 October, 2003 BP EXPLORA nON (ALASKA) INC. BPXA Milne Point Unit Measured 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) 725.00 7.140 194.960 651.98 724.16 18.96 S 4.07W 5999944.60 N 565768.63 E 10.85 AK-6 BP _IFR-AK 756.64 7.140 206.060 683.38 755.56 22.62 S 5.44 W 5999940.92 N 565767.29 E 4.354 13.49 853.25 8.850 227.450 779.07 851.25 33.04 S 13.55 W 5999930.43 N 565759.27 E 3.522 24.91 949.75 11 .230 244.540 874.10 946.28 42.11 S 27.51 W 5999921.24 N 565745.39 E 3.926 41.24 1044.63 13.580 263.650 966.80 1038.98 47.31 S 46.93 W 5999915.87 N 565726.01 E 4.952 61.20 1140.49 14.640 268.510 1059.77 1131.95 48.87 S 70.23 W 5999914.10 N 565702.73 E 1.658 83.40 . 1236.18 15.680 271.430 1152.13 1224.31 48.86 S 95.25 W 5999913.89 N 565677.72 E 1.348 106.60 1331.36 18.860 268.410 1243.01 1315.19 48.97 S 123.49 W 5999913.53 N 565649.48 E 3.470 132.84 1428.39 21.120 270.270 1334.19 1406.37 49.32 S 156.65 W 5999912.89 N 565616.32 E 2.419 163.74 1525.16 20.320 266.830 1424.70 1496.88 50.17 S 190.86 W 5999911.74 N 565582.11 E 1.505 195.80 1619.05 19.920 267.660 1512.86 1585.04 51.72 S 223.12 W 5999909.90 N 565549.87 E 0.523 226.30 1716.63 19.250 267.780 1604.80 1676.98 53.03 S 255.81 W 5999908.31 N 565517.20 E 0.688 257.11 1812.64 18.220 270.230 1695.72 1767.90 53.58 S 286.63 W 5999907.49 N 565486.38 E 1.350 285.91 1907.94 17.620 270.570 1786.40 1858.58 53.38 S 315.95 W 5999907.43 N 565457.06 E 0.639 313.04 2004.61 19.810 267.150 1877.95 1950.13 54.05 S 346.95 W 5999906.49 N 565426.07 E 2.533 342.04 2101.40 24.220 265.930 1967.66 2039.84 56.27 S 383.15 W 5999903.95 N 565389.89 E 4.580 376.46 2197.04 28.780 263.010 2053.24 2125.42 60.47 S 425.60 W 5999899.38 N 565347.48 E 4.957 417.40 2291.79 34.260 262.710 2133.98 2206.16 66.63 S 474.73 W 5999892.78 N 565298.41 E 5.786 465.28 2388.02 39.690 259.100 2210.83 2283.01 75.89 S 531.82 W 5999883.02 N 565241.40 E 6.075 521.70 2483.66 45.140 257.710 2281.42 2353.60 88.89 S 594.97 W 5999869.47 N 565178.36 E 5.782 585.14 2574.57 48.020 257.800 2343.90 2416.08 102.89 S 659.50 W 5999854.90 N 565113.96 E 3.169 650.23 2668.52 49.650 258.020 2405.74 2477.92 117.70 S 728.65 W 5999839.48 N 565044.94 E 1.744 719.92 . 2764.81 53.250 258.160 2465.73 2537.91 133.24 S 802.33 W 5999823.29 N 564971.41 E 3.740 794.06 2861.23 54.390 258.540 2522.65 2594.83 148.95 S 878.55 W 5999806.91 N 564895.33 E 1.224 870.64 2955.59 55.350 258.060 2576.95 2649.13 164.60 S 954.12 W 5999790.59 N 564819.90 E 1.099 946.59 3050.72 55.620 257.820 2630.85 2703.03 180.98 S 1030.77 W 5999773.54 N 564743.39 E 0.352 1023.81 3146.52 55.630 258.000 2684.94 2757.12 197.54 S 1108.09W 5999756.30 N 564666.23 E 0.155 1101.72 3243.67 56.320 258.480 2739.30 2811.48 213.95 S 1186.91 W 5999739.20 N 564587.55 E 0.820 1180.98 3340.52 56.620 258.750 2792.80 2864.98 229.89 S 1266.06 W 5999722.56 N 564508.55 E 0.387 1260.35 3432.99 57.390 259.190 2843.16 2915.34 244.72 S 1342.18 W 5999707.06 N 564432.56 E 0.923 1336.51 3528.68 57.450 259.320 2894.68 2966.86 259.76 S 1421.40W 5999691.33 N 564353.47 E 0.131 1415.61 3625.48 55.630 257.710 2948.05 3020.23 275.82 S 1500.53 W 5999674.56 N 564274.48 E 2.337 1495.02 3721.72 55.540 257.740 3002.45 3074.63 292.70 S 1578.11 W 5999657.00 N 564197.06 E 0.097 1573.29 3817.90 55.920 257.810 3056.61 3128.79 309.53 S 1655.79 W 5999639.49 N 564119.53E 0.400 1651.64 3913.98 56.140 258.160 3110.29 3182.47 326.12 S 1733.73 W 5999622.22 N 564041.74 E 0.379 1730.14 10 October, 2003 - 9:58 Page 2 of 6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-22 Your Ref: API 500292317600 Job No. AKZZ0002678821, Surveyed: 4 October, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured 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) 4007.19 56.570 258.420 3161.93 3234.11 341.87 S 1809.71 W 5999605.80 N 563965.90 E 0.516 1806.50 4103.26 57.660 258.140 3214.09 3286.27 358.26 S 1888.70 W 5999588.72 N 563887.05 E 1.161 1885.90 4199.05 58.210 255.640 3264.95 3337.13 376.67 S 1967.75 W 5999569.60 N 563808.17 E 2.285 1966.11 4294.94 58.450 254.700 3315.30 3387.48 397.56 S 2046.64 W 5999548.02 N 563729.47 E 0.871 2047.10 4390.83 59.110 251.390 3365.01 3437.19 421.48 S 2125.06 W 5999523.42 N 563651.26 E 3.031 2128.78 4486.73 60.220 247.380 3413.46 3485.64 450.63 S 2202.50 W 5999493.59 N 563574.08 E 3.790 2211.50 . 4582.99 62.390 242.470 3459.70 3531.88 486.43 S 2278.93 W 5999457.11 N 563497.97 E 5.009 2295.76 4680.02 63.890 235.660 3503.58 3575.76 530.92 S 2353.10 W 5999411.97 N 563424.20 E 6.448 2381.18 4774.98 66.580 229.370 3543.38 3615.56 583.39 S 2421.43 W 5999358.90 N 563356.33 E 6.647 2464.16 4871.32 70.370 225.480 3578.74 3650.92 644.03 S 2487.37 W 5999297.68 N 563290.92 E 5.438 2547.97 4967.98 72.920 223.980 3609.18 3681.36 709.20 S 2551.93 W 5999231.94 N 563226.95 E 3.021 2632.19 5063.04 77.700 223.380 3633.27 3705.45 775.69 S 2615.41 W 5999164.90 N 563164.05 E 5.065 2715.90 5121.20 78.320 222.290 3645.36 3717.54 817.41 S 2654.09 W 5999122.84 N 563125.74 E 2.121 2767.36 5160.39 78.760 222.050 3653.14 3725.32 845.87 S 2679.87 W 5999094.15 N 563100.21 E 1.273 2801.91 5227.47 79.450 221.060 3665.82 3738.00 895.16 S 2723.57 W 5999044.48 N 563056.95 E 1.777 2860.84 5275.57 83.200 220.360 3673.08 3745.26 931.20 S 2754.57 W 5999008.17 N 563026.27 E 7.928 2903.06 5323.05 83.700 219.360 3678.49 3750.67 967.41 S 2784.80 W 5998971.69 N 562996.35 E 2.342 2944.62 5370.54 88.830 216.580 3681.59 3753.77 1004.75 S 2813.94 W 5998934.09 N 562967.54 E 12.280 2985.60 5420.20 88.890 217.070 3682.57 3754.75 1044.50 S 2843.70 W 5998894.09 N 562938.14 E 0.994 3028.04 5468.93 88.400 216.610 3683.73 3755.91 1083.49 S 2872.91 W 5998854.85 N 562909.27 E 1.379 3069.70 5515.52 88.150 215.940 3685.13 3757.31 1121.03S 2900.47 W 5998817.06 N 562882.05 E 1.534 3109.27 5563.40 88.400 215.550 3686.57 3758.75 1159.87 S 2928.42 W 5998777.97 N 562854.43 E 0.967 3149.71 . 5611.01 88.340 215.220 3687.92 3760.10 1198.67 S 2955.98 W 5998738.93 N 562827.22 E 0.704 3189.76 5660.07 88.210 214.930 3689.40 3761.58 1238.80 S 2984.16 W 5998698.55 N 562799.39 E 0.648 3230.88 5706.97 88.460 214.310 3690.76 3762.94 1277.38 S 3010.79 W 5998659.74 N 562773.10 E 1.425 3269.99 5758.95 88.640 217.220 3692.08 3764.26 1319.54S 3041 .16 W 5998617.32 N 562743.11 E 5.607 3313.90 5802.72 89.320 217.130 3692.86 3765.04 1354.41 S 3067.61 W 5998582.22 N 562716.97 E 1.567 3351.45 5854.77 93.640 217.870 3691.51 3763.69 1395.68 S 3099.27 W 5998540.67 N 562685.67 E 8.420 3396.24 5900.32 93.890 217.710 3688.52 3760.70 1431.60S 3127.12 W 5998504.51 N 562658.13 E 0.651 3435.49 5950.69 93.890 217.520 3685.11 3757.29 1471.41 S 3157.80 W 5998464.43 N 562627.81 E 0.376 3478.80 5995.89 93.950 217.320 3682.02 3754.20 1507.22 S 3185.20 W 5998428.38 N 562600.73 E 0.461 3517.59 6047.99 93.880 215.820 3678.46 3750.64 1548.97 S 3216.17 W 5998386.36 N 562570.13 E 2.876 3561.90 6092.80 93.830 215.460 3675.45 3747.63 1585.30 S 3242.22 W 5998349.80 N 562544.40 E 0.809 3599.64 6142.87 93.390 214.120 3672.29 3744.47 1626.34 S 3270.73 W 5998308.51 N 562516.25 E 2.812 3641 .41 6188.07 93.270 213.860 3669.67 3741.85 1663.75 S 3295.96 W 5998270.88 N 562491.35 E 0.633 3678.78 10 October, 2003 - 9:58 Page 3 of 6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-22 Your Ref: AP/500292317600 Job No. AKZZ0002678821, Surveyed: 4 October, 2003 BP EXPLORA T/ON (ALASKA) INC. BPXA Milne Point Unit Measured 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) 6238.98 93.640 213.830 3666.60 3738.78 1705.96 S 3324.26 W 5998228.42 N 562463.42 E 0.729 3720.79 6283.62 94.010 213.290 3663.62 3735.80 1743.07 S 3348.88 W 5998191.09 N 562439.13 E 1.464 3757.49 6334.67 93.210 214.750 3660.41 3732.59 1785.30 S 3377.38 W 5998148.62 N 562411.00 E 3.256 3799.69 6380.83 93.270 214.390 3657.80 3729.98 1823.25 S 3403.53 W 5998110.44 N 562385.18 E 0.789 3838.12 6430.59 93.330 213.980 3654.93 3727.11 1864.35 S 3431.45 W 5998069.10 N 562357.63 E 0.831 3879.35 6476.04 93.460 215.450 3652.24 3724.42 1901.64 S 3457.28 W 5998031.58 N 562332.13 E 3.241 3917.25 . 6509.96 93.390 216.870 3650.22 3722.40 1928.97 S 3477.26 W 5998004.07 N 562312.39 E 4.184 3945.99 6540.63 93.890 217.660 3648.27 3720.45 1953.33 S 3495.79 W 5997979.55 N 562294.07 E 3.044 3972.27 6569.85 96.120 219.440 3645.72 3717.90 1976.10 S 3513.93 W 5997956.63 N 562276.14 E 9.750 3997.60 6604.37 96.050 221.350 3642.06 3714.24 2002.24 S 3536.18 W 5997930.29 N 562254.12 E 5.506 4027.99 6637.00 96.430 222.920 3638.51 3710.69 2026.29 S 3557.94 W 5997906.05 N 562232.58 E 4.923 4057.16 6666.89 95.560 224.680 3635.39 3707.57 2047.74 S 3578.51 W 5997884.41 N 562212.19 E 6.539 4084.25 6700.01 94.450 226.450 3632.50 3704.68 2070.84 S 3602.07 W 5997861.11 N 562188.84 E 6.291 4114.73 6733.31 93.830 228.120 3630.10 3702.28 2093.37 S 3626.47 W 5997838.36 N 562164.63 E 5.337 4145.78 6762.17 94.570 231.040 3627.98 3700.16 2112.03 S 3648.38 W 5997819.51 N 562142.89 E 10.411 4173.07 6795.95 94.880 233.740 3625.20 3697.38 2132.57 S 3675.05 W 5997798.73 N 562116.41 E 8.018 4205.48 6829.72 95.560 237.540 3622.13 3694.31 2151.55 S 3702.80 W 5997779.51 N 562088.82 E 11.385 4238.31 6858.85 95.370 239.890 3619.35 3691.53 2166.61 S 3727.58 W 5997764.24 N 562064.17 E 8.057 4266.92 6892.11 94.200 242.090 3616.58 3688.76 2182.68 S 3756.57 W 5997747.91 N 562035.33 E 7.471 4299.81 6925.89 93.460 244.150 3614.32 3686.50 2197.92 S 3786.63 W 5997732.41 N 562005.41 E 6.467 4333.39 6955.54 93.460 247.470 3612.53 3684.71 2210.04 S 3813.62 W 5997720.05 N 561978.52 E 11.177 4362.95 6988.80 93.330 249.130 3610.56 3682.74 2222.32 S 3844.47 W 5997707.50 N 561947.78 E 4.998 4396.15 . 7021.22 93.390 250.510 3608.66 3680.84 2233.48 S 3874.85 W 5997696.07 N 561917.50 E 4.253 4428.50 7051.32 93.950 252.010 3606.73 3678.91 2243.13 S 3903.29 W 5997686.17 N 561889.15 E 5.310 4458.49 7102.93 94.820 253.670 3602.79 3674.97 2258.32 S 3952.46 W 5997670.55 N 561840.11 E 3.623 4509.77 7147.13 95.500 256.050 3598.81 3670.99 2269.81 S 3994.95 W 5997658.68 N 561797.73 E 5.579 4553.48 7196.40 95.870 257.970 3593.93 3666.11 2280.83 S 4042.72 W 5997647.24 N 561750.06 E 3.950 4601.91 7243.58 94.630 260.380 3589.61 3661.79 2289.66 S 4088.86 W 5997638.02 N 561703.99 E 5.725 4648.01 7289.78 95.060 261.240 3585.71 3657.89 2297.01 S 4134.30 W 5997630.26 N 561658.62 E 2.075 4692.92 7339.65 95.120 261.120 3581.29 3653.47 2304.62 S 4183.39 W 5997622.21 N 561609.60 E 0.268 4741.30 7389.38 95.000 261.230 3576.90 3649.08 2312.22 S 4232.34 W 5997614.18 N 561560.72 E 0.327 4789.54 7435.57 95.120 261.190 3572.83 3645.01 2319.26 S 4277.81 W 5997606.75 N 561515.31 E 0.274 4834.35 7484.74 94.880 260.970 3568.54 3640.72 2326.85 S 4326.20 W 5997598.73 N 561466.99 E 0.661 4882.08 7530.93 93.760 261.380 3565.06 3637.24 2333.92 S 4371.71 W 5997591.27 N 561421.54 E 2.581 4926.94 7580.48 91.540 262.100 3562.77 3634.95 2341.03 S 4420.69 W 5997583.72 N 561372.63 E 4.710 4975.03 10 October, 2003 - 9:58 Page 4 of 6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-22 Your Ref: API 500292317600 Job No. AKZZ0002678821, Surveyed: 4 October, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured 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) 7626.89 90.740 266.110 3561.85 3634.03 2345.79 S 4466.84 W 5997578.55 N 561326.53 E 8.809 5019.62 7678.59 90.000 265.760 3561.51 3633.69 2349.46 S 4518.40 W 5997574.43 N 561274.99 E 1.583 5068.83 7724.54 89.630 265.990 3561.66 3633.84 2352.76 S 4564.23 W 5997570.73 N 561229.19 E 0.948 5112.58 7773.38 89.260 265.670 3562.13 3634.31 2356.31 S 4612.94 W 5997566.75 N 561180.52 E 1.002 5159.09 7820.53 88.400 265.300 3563.10 3635.28 2360.02 S 4659.94 W 5997562.62 N 561133.56 E 1.986 5204.07 7869.61 89.140 267.310 3564.15 3636.33 2363.19 S 4708.90 W 5997559.03 N 561084.62 E 4.363 5250.68 . 7917.06 89.010 267.640 3564.92 3637.10 2365.28 S 4756.30 W 5997556.52 N 561037.25 E 0.747 5295.43 7967.00 89.320 268.550 3565.64 3637.82 2366.94 S 4806.20 W 5997554.42 N 560987.36 E 1.925 5342.35 8013.36 88.640 265.510 3566.47 3638.65 2369.34 S 4852.49 W 5997551.61 N 560941.09 E 6.718 5386.18 8062.18 87.900 264.710 3567.94 3640.12 2373.50 S 4901.11 W 5997547.03 N 560892.51 E 2.232 5432.84 8109.40 88.270 265.110 3569.52 3641.70 2377.68 S 4948.12 W 5997542.42 N 560845.54 E 1.154 5478.01 8161.46 88.270 264.870 3571.09 3643.27 2382.23 S 4999.95 W 5997537.42 N 560793.75 E 0.461 5527.80 8205.49 88.890 264.830 3572.18 3644.36 2386.18 S 5043.79 W 5997533.09 N 560749.95 E 1.411 5569.94 8252.51 88.890 264.540 3573.10 3645.28 2390.53 S 5090.60 W 5997528.32 N 560703.18 E 0.617 5614.99 8299.74 91.110 263.650 3573.10 3645.28 2395.39 S 5137.58 W 5997523.05 N 560656.25 E 5.064 5660.39 8350.77 91.600 264.090 3571.89 3644.07 2400.84 S 5188.30 W 5997517.15 N 560605.57 E 1.290 5709.48 8397.78 90.550 264.780 3571.01 3643.19 2405.40 S 5235.08 W 5997512.18 N 560558.84 E 2.673 5754.58 8445.76 90.740 264.370 3570.47 3642.65 2409.93 S 5282.84 W 5997507.23 N 560511.12 E 0.942 5800.58 8493.92 91.170 265.000 3569.66 3641.84 2414.39 S 5330.79 W 5997502.35 N 560463.21 E 1.584 5846.72 8543.73 89.810 264.900 3569.24 3641.42 2418.78 S 5380.40 W 5997497.52 N 560413.64 E 2.738 5894.39 8590.07 89.570 264.890 3569.49 3641.67 2422.90 S 5426.56 W 5997493.00 N 560367.52 E 0.518 5938.75 8638.88 88.270 264.740 3570.41 3642.59 2427.31 S 5475.16 W 5997488.16 N 560318.96 E 2.681 5985.48 . 8686.59 88.460 264.570 3571.77 3643.95 2431.75 S 5522.64 W 5997483.30 N 560271.52 E 0.534 6031.19 8735.32 87.960 264.090 3573.29 3645.47 2436.57 S 5571.11 W 5997478.06 N 560223.10 E 1.422 6077.95 8782.33 88.150 264.210 3574.89 3647.07 2441.35 S 5617.85 W 5997472.86 N 560176.40 E 0.478 6123.10 8830.49 87.530 264.470 3576.70 3648.88 2446.10 S 5665.74 W 5997467.69 N 560128.55 E 1.396 6169.30 8878.44 86.730 264.490 3579.10 3651.28 2450.71 S 5713.40 W 5997462.66 N 560080.93 E 1.669 6215.24 8927.08 87.720 263.930 3581.46 3653.64 2455.61 S 5761.74 W 5997457.34 N 560032.64 E 2.338 6261.91 8974.74 87.280 263.700 3583.54 3655.72 2460.74 S 5809.08 W 5997451.79 N 559985.35 E 1.042 6307.74 9023.54 86.610 264.110 3586.14 3658.32 2465.91 S 5857.53 W 5997446.19 N 559936.94 E 1.609 6354.62 9071.34 88.270 263.670 3588.27 3660.45 2471.00 S 5905.01 W 5997440.69 N 559889.51 E 3.592 6400.56 9117.80 87.410 263.560 3590.02 3662.20 2476.16 S 5951.15W 5997435.12 N 559843.42 E 1.866 6445.30 9166.63 90.620 263.360 3590.86 3663.04 2481.72 S 5999.65 W 5997429.13 N 559794.97 E 6.587 6492.36 9242.00 90.620 263.360 3590.05 3662.23 2490.43 S 6074.51 W 5997419.76 N 559720.19 E . 0.000 6565.06 Projected Survey 10 October, 2003 - 9:58 Page 50f6 DrillQuest 3.03.02.005 , Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-22 Your Ref: API 500292317600 Job No. AKZZ0002678821, Surveyed: 4 October, 2003 BP EXPLORA nON (ALASKA) INC. Milne Point Unit BPXA 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 248.080° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9242.00fl., The Bottom Hole Displacement is 6565.20fl., in the Direction of 247.707° (True). . Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9242.00 3662.23 2490.43 S 6074.51 W Projected Survey Survey toolproQram for MPS-22 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 725.00 0.00 724.16 725.00 9242.00 724.16 3662.23 AK-1 BP _HG (MPS-22 Gyro) AK-6 BP _IFR-AK (MPS-22) . 10 October, 2003 - 9:58 Page 6 of 6 DrillQuest 3.03.02.005 It AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well MPS-22 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 9,242.00' MD (if applicable) &0 3- LI -r- 13-0ct-03 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) -~-:çs\\f\\ .:.~ Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-22 MWD . Job No. AKMW0002678821, Surveyed: 4 October, 2003 Survey Report 10 October, 2003 Your Ref: API 500292317600 Surface Coordinates: 5999963.59 N, 565772.53 E (70024' 37.2367H N, 149027' 51.9549H W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 999963.59 N, 65772.53 E (Grid) Surface Coordinates relative to Structure: 6.37 S, 572.55 W (True) Kelly Bushing: 72. 18ft above Mean Sea Level Elevation relative to Project V Reference: 72. 18ft Elevation relative to Structure: 72.18ft st=J,e..........'.J-sul'1 OAILLIN·G SERVlc:es A Halliburton Company Survey Ref: svy1290 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-22 MWD Your Ref: API 500292317600 Job No. AKMW0002678821, Surveyed: 4 October, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured 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) 725.00 7.140 194.960 651.98 724.16 18.96 S 4.07W 5999944.60 N 565768.63 E 10.85 MWD Magnetic 756.64 7.140 206.830 683.38 755.56 22.61 S 5.46 W 5999940.93 N 565767.27 E 4.655 13.51 853.25 8.850 227.940 779.07 851.25 32.95 S 13.69 W 5999930.52 N 565759.13 E 3.488 25.00 949.75 11.230 244.930 874.10 946.28 41.91 S 27.72 W 5999921.44 N 565745.18 E 3.912 41.36 1044.63 13.580 263.780 966.80 1038.98 47.03 S 47.17 W 5999916.15 N 565725.77 E 4.902 61.32 . 1140.49 14.640 268.740 1059.77 1131.95 48.52 S 70.47 W 5999914.45 N 565702.49 E 1.677 83.49 1236.18 15.680 271.580 1152.13 1224.31 48.43 S 95.49 W 5999914.32 N 565677.47 E 1.335 106.66 1331.36 18.860 268.440 1243.01 1315.19 48.49 S 123.73 W 5999914.01 N 565649.23 E 3.480 132.89 1428.39 21.120 270.260 1334.19 1406.37 48.84 S 156.89 W 5999913.37 N 565616.07 E 2.416 163.78 1525.16 20.320 267.050 1424.70 1496.88 49.62 S 191.11 W 5999912.29 N 565581.86 E 1 .435 195.82 1619.05 19.920 268.010 1512.86 1585.04 51.02 S 223.38 W 5999910.61 N 565549.61 E 0.552 226.27 1716.63 19.250 268.160 1604.80 1676.98 52.11 S 256.07 W 5999909.23 N 565516.93 E 0.689 257.01 1812.64 18.220 270.640 1695.72 1767.90 52.45 S 286.90 W 5999908.61 N 565486.11 E 1.356 285.74 1907.94 17.620 269.850 1786.39 1858.57 52.32 S 316.22 W 5999908.48 N 565456.79 E 0.679 312.89 2004.61 19.810 267.680 1877.95 1950.13 53.03 S 347.22 W 5999907.51 N 565425.79 E 2.377 341.91 2101.40 24.220 266.460 1967.66 2039.84 54.92 S 383.44 W 5999905.30 N 565389.59 E 4.580 376.22 2197.04 28.780 263.590 2053.23 2125.41 58.70 S 425.92 W 5999901.14 N 565347.14 E 4.951 417.05 2291.79 34.260 263.330 2133.97 2206.15 64.35 S 475.12 W 5999895.06 N 565298.00 E 5.785 464.79 2388.02 39.690 259.660 2210.83 2283.01 73.02 S 532.30 W 5999885.89 N 565240.89 E 6.089 521.07 2483.66 45.140 258.260 2281.41 2353.59 85.41 S 595.58 W 5999872.94 N 565177.73 E 5.783 584.40 2574.57 48.020 258.030 2343.89 2416.07 98.97 S 660.19 W 5999858.81 N 565113.23 E 3.173 649.41 2668.52 49.650 258.290 2405.73 2477.91 113.48 S 729.41 W 5999843.69 N 565044.14 E 1.747 719.05 . 2764.81 53.250 257.940 2465.73 2537.91 128.99 S 803.09 W 5999827.53 N 564970.61 E 3.749 793.19 2861.23 54.390 258.590 2522.65 2594.83 144.82 S 879.29 W 5999811.03 N 564894.55 E 1.302 869.79 2955.59 55.350 257.690 2576.95 2649.13 160.68 S 954.81 W 5999794.51 N 564819.17 E 1.282 945.77 3050.72 55.620 257.700 2630.85 2703.03 177.39 S 1 031 .40 W 5999777.13 N 564742.74 E 0.284 1023.05 3146.52 55.630 258.250 2684.94 2757.12 193.86 S 1108.73 W 5999759.97 N 564665.55 E 0.474 1100.95 3243.67 56.320 258.990 2739.30 2811.48 209.75 S 1187.66W 5999743.39 N 564586.76 E 0.950 1180.10 3340.52 56.620 258.970 2792.80 2864.98 225.18 S 1266.91 W 5999727.26 N 564507.65 E 0.310 1259.38 3432.99 57.390 258.660 2843.15 2915.33 240.22 S 1342.99 W 5999711.55 N 564431.71 E 0.879 1335.58 3528.68 57.450 258.520 2894.68 2966.86 256.17 S 1422.03 W 5999694.90 N 564352.81 E 0.138 1414.86 3625.48 55.630 257.11 0 2948.05 3020.23 273.21 S 1500.96 W 5999677.18 N 564274.03 E 2.239 1494.44 3721.72 55.540 256.920 3002.44 3074.62 291.05 S 1578.33 W 5999658.65 N 564196.83 E 0.188 1572.88 3817.90 55.920 256.790 3056.60 3128.78 309.12 S 1655.73 W 5999639.90 N 564119.59 E 0.411 1651.43 3913.98 56.140 256.500 3110.29 3182.47 327.53 S 1733.25 W 5999620.81 N 564042.23 E 0.339 1730.22 10 October, 2003 . 9:59 Page 20f6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-22 MWD Your Ref: API 500292317600 Job No. AKMW0002678821, Surveyed: 4 October, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured 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) 4007.19 56.570 257.120 3161.93 3234.11 345.23 S 1808.80 W 5999602.44 N 563966.84 E 0.721 1806.92 4103.26 57.660 257.080 3214.09 3286.27 363.24 S 1887.44 W 5999583.74 N 563888.36 E 1.135 1886.59 4199.05 58.210 254.710 3264.95 3337.13 383.03 S 1966.16 W 5999563.26 N 563809.82 E 2.174 1967.01 4294.94 58.450 254.850 3315.30 3387.48 404.45 S 2044.91 W 5999541.14 N 563731.26 E 0.279 2048.06 4390.83 59.110 251.870 3365.01 3437.19 427.94 S 2123.46 W 5999516.97 N 563652.92 E 2.745 2129.70 4486.73 60.220 248.050 3413.45 3485.63 456.31 S 2201.19 W 5999487.91 N 563575.44 E 3.627 2212.40 . 4582.99 62.390 243.120 3459.69 3531.87 491.23 S 2278.02 W 5999452.32 N 563498.92 E 5.026 2296.72 4680.02 63.890 236.110 3503.57 3575.75 535.00 S 2352.61 W 5999407.89 N 563424.72 E 6.627 2382.25 4774.98 66.580 229.900 3543.38 3615.56 586.89 S 2421.40 W 5999355.40 N 563356.39 E 6.578 2465.44 4871.32 70.370 226.050 3578.73 3650.91 646.89 S 2487.92 W 5999294.82 N 563290.40 E 5.412 2549.55 4967.98 72.920 224.450 3609.17 3681.35 711.48 S 2553.06 W 5999229.66 N 563225.84 E 3.070 2634.09 5063.04 77.700 223.930 3633.27 3705.45 777.39 S 2617.13 W 5999163.18 N 563162.35 E 5.056 2718.14 5121.20 78.320 222.720 3645.35 3717.53 818.78 S 2656.16 W 5999121.45 N 563123.68 E 2.297 2769.80 5160.39 78.760 222.570 3653.14 3725.32 847.03 S 2682.18 W 5999092.97 N 563097.91 E 1.184 2804.49 5227.47 79.450 221.170 3665.82 3738.00 896.08 S 2726.15 W 5999043.53 N 563054.38 E 2.293 2863.58 5275.57 83.200 220.370 3673.07 3745.25 932.09 S 2757.19 W 5999007.26 N 563023.65 E 7.968 2905.82 5323.05 83.700 219.490 3678.49 3750.67 968.26 S 2787.47 W 5998970.82 N 562993.70 E 2.121 2947.41 5370.54 88.830 216.710 3681.58 3753.76 1005.54 S 2816.69 W 5998933.29 N 562964.80 E 12.280 2988.44 5420.20 88.890 217.160 3682.57 3754.75 1045.22 S 2846.53 W 5998893.34 N 562935.32 E 0.914 3030.93 5468.93 88.400 216.600 3683.72 3755.90 1084.19 S 2875.76 W 5998854.12 N 562906.43 E 1.527 3072.60 5515.52 88.150 215.830 3685.12 3757.30 1121.76 S 2903.28 W 5998816.30 N 562879.24 E 1.737 3112.16 5563.40 88.400 215.530 3686.56 3758.74 1160.64 S 2931.19W 5998777.18 N 562851.67 E 0.815 3152.56 . 5611.01 88.340 215.400 3687.92 3760.10 1199.40 S 2958.80 W 5998738.18 N 562824.40 E 0.301 3192.65 5660.07 88.210 215.110 3689.40 3761.58 1239.44 S 2987.11 W 5998697.89 N 562796.45 E 0.648 3233.86 5706.97 88.460 214.370 3690.76 3762.94 1277.97 S 3013.82 W 5998659.13 N 562770.08 E 1.665 3273.02 5758.95 88.640 217.200 3692.07 3764.25 1320.12 S 3044.21 W 5998616.72 N 562740.07 E 5.454 3316.94 5802.72 89.320 217.180 3692.85 3765.03 1354.98 S 3070.66 W 5998581.62 N 562713.92 E 1.554 3354.50 5854.77 93.640 217.750 3691.51 3763.69 1396.27 S 3102.30 W 5998540.06 N 562682.65 E 8.372 3399.27 5900.32 93.890 217.920 3688.52 3760.70 1432.17 S 3130.18 W 5998503.92 N 562655.08 E 0.663 3438.53 5950.69 93.890 217.740 3685.10 3757.28 1471.86S 3161.00 W 5998463.95 N 562624.61 E 0.357 3481.94 5995.89 93.950 217.520 3682.01 3754.19 1507.57 S 3188.54 W 5998428.00 N 562597.39 E 0.503 3520.82 6047.99 93.880 216.200 3678.45 3750.63 1549.16 S 3219.71 W 5998386.14 N 562566.58 E 2.531 3565.27 6092.80 93.830 215.740 3675.44 3747.62 1585.34 S 3245.97 W 5998349.72 N 562540.64 E 1.030 3603.14 6142.87 93.390 214.100 3672.29 3744.47 1626.31 S 3274.58 W 5998308.50 N 562512.40 E 3.385 3644.97 6188.07 93.270 214.180 3669.66 3741.84 1663.66 S 3299.90 W 5998270.93 N 562487.41 E 0.319 3682.40 10 October, 2003 - 9:59 Page 3 of6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-22 MWD Your Ref: API 500292317600 Job No. AKMW0002678821, Surveyed: 4 October, 2003 BP EXPLORA nON (ALASKA) INC. BPXA Milne Point Unit Measured 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) 6238.98 93.640 214.080 3666.59 3738.77 1705.73 S 3328.41 W 5998228.62 N 562459.27 E 0.753 3724.56 6283.62 94.010 213.480 3663.62 3735.80 1742.75 S 3353.18 W 5998191.38 N 562434.83 E 1.577 3761.35 6334.67 93.210 214.920 3660.40 3732.58 1784.88 S 3381.82 W 5998148.99 N 562406.56 E 3.222 3803.65 6380.83 93.270 214.720 3657.79 3729..97 1822.72 S 3408.13 W 5998110.93 N 562380.58 E 0.452 3842.19 6430.59 93.330 214.290 3654.93 3727.11 1863.66 S 3436.27 W 5998069.74 N 562352.80 E 0.871 3883.57 . 6476.04 93.460 215.860 3652.24 3724.42 1900.79 S 3462.34 W 5998032.39 N 562327.06 E 3.460 3921.62 6509.96 93.390 217.370 3650.21 3722.39 1927.96 S 3482.54 W 5998005.03 N 562307.11 E 4.448 3950.50 6540.63 93.890 218.170 3648.26 3720.44 1952.16 S 3501.28 W 5997980.67 N 562288.57 E 3.071 3976.93 6569.85 96.120 219.860 3645.71 3717.89 1974.77 S 3519.61 W 5997957.90 N 562270.45 E 9.562 4002.37 6604.37 96.050 221.570 3642.05 3714.23 2000.79 S 3542.00 W 5997931.69 N 562248.29 E 4.930 4032.85 6637.00 96.430 223.120 3638.51 3710.69 2024.768 3563.84 W 5997907.52 N 562226.65 E 4.864 4062.07 6666.89 95.560 224.820 3635.39 3707.57 2046.16 S 3584.48 W 5997885.95 N 562206.21 E 6.361 4089.20 6700.01 94.450 226.700 3632.50 3704.68 2069.17 S 3608.12 W 5997862.72 N 562182.77 E 6.573 4119.72 6733.31 93.830 228.660 3630.09 3702.27 2091.53 S 3632.68 W 5997840.15 N 562158.41 E 6.159 4150.85 6762.17 94.570 231.600 3627.98 3700.16 2109.98 S 3654.76 W 5997821.51 N 562136.49 E 10.478 4178.23 6795.95 94.880 234.420 3625.19 3697.37 2130.24 S 3681.65 W 5997801.02 N 562109.78 E 8.370 4210.73 6829.72 95.560 238.600 3622.12 3694.30 2148.79 S 3709.69 W 5997782.22 N 562081.91 E 12.490 4243.67 6858.85 95.370 240.190 3619.35 3691.53 2163.55 S 3734.65 W 5997767.23 N 562057.08 E 5.472 4272.33 6892.11 94.200 242.610 3616.57 3688.75 2179.41 S 3763.74 W 5997751.12 N 562028.12 E 8.059 4305.25 6925.89 93.460 244.320 3614.32 3686.50 2194.47 S 3793.90 W 5997735.79 N 561998.10 E 5.505 4338.84 6955.54 93.460 247.410 3612.53 3684.71 2206.57 S 3820.90 W 5997723.46 N 561971.21 E 1 0.403 4368.41 6988.80 93.330 249.090 3610.56 3682.74 2218.87 S 3851.74 W 5997710.88 N 561940.48 E 5.057 4401.61 . 7021.22 93.390 250.460 3608.66 3680.84 2230.06 S 3882.11 W 5997699.43 N 561910.21 E 4.223 4433.96 7051.32 93.950 251.930 3606.73 3678.91 2239.74 S 3910.54 W 5997689.49 N 561881.86 E 5.217 4463.96 7102.93 94.820 253.610 3602.78 3674.96 2254.99 S 3959.69 W 5997673.82 N 561832.85 E 3.657 4515.24 7147.13 95.500 255.960 3598.81 3670.99 2266.54 S 4002.16 W 5997661.89 N 561790.48 E 5.514 4558.96 7196.40 95.870 257.680 3593.93 3666.11 2277.72 S 4049.90 W 5997650.30 N 561742.85 E 3.554 4607.41 7243.58 94.630 260.180 3589.61 3661.79 2286.74 S 4096.00 W 5997640.87 N 561696.83 E 5.895 4653.55 7289.78 95.060 260.760 3585.71 3657.89 2294.36 S 4141 .40 W 5997632.85 N 561651.49 E 1.559 4698.51 7339.65 95.120 260.800 3581.28 3653.46 2302.32 S 4190.43 W 5997624.46 N 561602.54 E 0.144 4746.97 7389.38 95.000 260.820 3576.90 3649.08 2310.238 4239.33 W 5997616.12 N 561553.71 E 0.245 4795.29 7435.57 95.120 260.670 3572.82 3645.00 2317.63 S 4284.74 W 5997608.32 N 561508.36 E 0.415 4840.18 7484.74 94.880 260.460 3568.54 3640.72 2325.66 S 4333.06 W 5997599.86 N 561460.11 E 0.648 4888.00 7530.93 93.760 260.770 3565.06 3637.24 2333.17 S 4378.51 W 5997591.95 N 561414.74 E 2.515 4932.96 7580.48 91.540 261.410 3562.77 3634.95 2340.83 S 4427.40 W 5997583.86 N 561365.91 E 4.662 4981.19 10 October, 2003 - 9:59 Page 4 of6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-22 MWD Your Ref: API 500292317600 Job No. AKMW0002678821, Surveyed: 4 October, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured 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) 7626.89 90.740 265.380 3561.84 3634.02 2346.17 S 4473.48 W 5997578.12 N 561319.88 E 8.724 5025.93 7678.59 90.000 265.140 3561.51 3633.69 2350.44 S 4525.01 W 5997573.39 N 561268.40 E 1.505 5075.32 7724.54 89.630 265.370 3561.66 3633.84 2354.24 S 4570.80 W 5997569.19 N 561222.64 E 0.948 5119.22 7773.38 89.260 264.860 3562.13 3634.31 2358.40 S 4619.46 W 5997564.60 N 561174.02E 1.290 5165.92 7820.53 88.400 264.390 3563.09 3635.27 2362.82 S 4666.39 W 5997559.77 N 561127.13 E 2.078 5211.11 . 7869.61 89.140 266.690 3564.15 3636.33 2366.63 S 4715.31 W 5997555.52 N 561078.25 E 4.922 5257.91 7917.06 89.010 266.790 3564.91 3637.09 2369.33 S 4762.67 W 5997552.41 N 561030.91 E 0.346 5302.86 7967.00 89.320 267.720 3565.64 3637.82 2371.72 S 4812.55 W 5997549.58 N 560981.05 E 1.963 5350.02 8013.36 88.640 265.050 3566.47 3638.65 2374.64 S 4858.81 W 5997546.25 N 560934.82 E 5.942 5394.03 8062.18 87.900 264.190 3567.94 3640.12 2379.22 S 4907.39 W 5997541.25 N 560886.28 E 2.323 5440.81 8109.40 88.270 264.560 3569.52 3641.70 2383.85 S 4954.36 W 5997536.21 N 560839.36 E 1.108 5486.10 8161.46 88.270 264.340 3571.09 3643.27 2388.88 S 5006.15 W 5997530.72 N 560787.61 E 0.422 5536.03 8205.49 88.890 264.340 3572.18 3644.36 2393.22 S 5049.95 W 5997525.99 N 560743.85 E 1 .408 5578.29 8252.51 88.890 264.420 3573.09 3645.27 2397.82 S 5096.73 W 5997520.98 N 560697.11 E 0.170 5623.41 8299.74 91.110 263.340 3573.09 3645.27 2402.86 S 5143.69 W 5997515.53 N 560650.20 E 5.227 5668.85 8350.77 91.600 263.800 3571.88 3644.06 2408.57 S 5194.39 W 5997509.37 N 560599.56 E 1.317 5718.01 8397.78 90.550 264.420 3571.00 3643.18 2413.39 S 5241.14 W 5997504.13 N 560552.85 E 2.594 5763.18 8445.76 90.740 263.990 3570.46 3642.64 2418.24 S 5288.87 W 5997498.87 N 560505.16 E 0.980 5809.27 8493.92 91.170 264.650 3569.66 3641.84 2423.00 S 5336.79 W 5997493.68 N 560457.29 E 1.635 5855.51 8543.73 89.810 264.430 3569.23 3641 .41 2427.74 S 5386.37 W 5997488.51 N 560407.75 E 2.766 5903.27 8590.07 89.570 264.460 3569.48 3641.66 2432.23 S 5432.49 W 5997483.61 N 560361.67 E 0.522 5947.73 8638.88 88.270 264.210 3570.40 3642.58 2437.05 S 5481.05 W 5997478.37 N 560313.15 E 2.712 5994.58 . 8686.59 88.460 264.080 3571.77 3643.95 2441.91 S 5528.49 W 5997473.09 N 560265.75 E 0.482 6040.41 8735.32 87.960 263.510 3573.29 3645.47 2447.18 S 5576.91 W 5997467.40 N 560217.38 E 1.556 6087.30 8782.33 88.150 263.670 3574.88 3647.06 2452.42 S 5623.60 W 5997461.74 N 560170.74 E 0.528 6132.57 8830.49 87.530 263.930 3576.70 3648.88 2457.62 S 5671.45 W 5997456.12 N 560122.95 E 1.396 6178.89 8878.44 86.730 263.990 3579.10 3651.28 2462.66 S 5719.07 W 5997450.66 N 560075.37 E 1.673 6224.96 8927.08 87.720 263.560 3581 .45 3653.63 2467.93 S 5767.37 W 5997444.97 N 560027.12 E 2.219 6271.73 8974.74 87.280 263.320 3583.53 3655.71 2473.37 S 5814.67 W 5997439.11 N 559979.87 E 1.051 6317.64 9023.54 86.610 263.960 3586.13 3658.31 2478.76 S 5863.10 W 5997433.29 N 559931.49 E 1.897 6364.58 9071.34 88.270 263.170 3588.27 3660.45 2484.12 S 5910.55 W 5997427.52 N 559884.09 E 3.845 6410.60 9117.80 87.410 263.160 3590.02 3662.20 2489.64 S 5956.65 W 5997421.59 N 559838.04 E 1.851 6455.43 9166.63 90.620 263.130 3590.86 3663.04 2495.47 S 6005.11 W 5997415.34 N 559789.63 E 6.574 6502.57 9242.00 90.620 263.130 3590.04 3662.22 2504.48 S 6079.94 W 5997405.66 N 559714.88 E 0.000 6575.35 Projected Survey 10 October, 2003 - 9:59 Page 5 of 6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-22 MWD Your Ref: API 500292317600 Job No. AKMW0002678821, Surveyed: 4 October, 2003 BP EXPLORA nON (ALASKA) INC. Milne Point Unit BPXA 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 248.080° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9242. OOft. , The Bottom Hole Displacement is 6575.57ft., in the Direction of 247.612° (True). . Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9242.00 3662.22 2504.48 S 6079.94 W Projected Survey Survey tool program for MPS-22 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 725.00 0.00 724.16 725.00 9242.00 724.16 3662.22 AK-1 BP _HG (MPS-22 Gyro) MWD Magnetic (MPS-22 MWD) . 10 October, 2003 - 9:59 Page 6 of 6 DrillQuest 3.03.02.005 RE: Mf'S-22 Monobore Completion \" ".. . . Subject: RE: MPS-22 Monobore Completion Date: Tue, 23 Sep 200315:42:13 -0500 From: "Green, Matt Dn <GreenMD@BP.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> . Cheers, ~o~- \ L--\\ Try this file Tom. Matt. -----Original Message----- From: Tom Maunder fmailto:tom maunder@admin.state.ak.usl Sent: Tuesday, 23 September 2003 11 :22 AM To: Green, Matt D Subject: Re: MPS-22 Monobore Completion Hi Matt, I was getting through the em ails that came in while I was out and I saw this one. We cannot open canvas over hear, if you would paste the drawing into a word document that should allow me to open it. Then I can make sure things get to the file. Thanks, Tom Maunder "Green, Matt D" wrote: > Tom, > > Please find attached the revised completion for MPS-22. The new completion > is a monobore 4.5-in completion, using the liner top packer as the > production packer and a seal assembly below the packer into which the tubing > can be stung in. As per recommendation from Winton, the tubing will be > tested to 4,OOO-psi using a ball and rod placed in the RHC-M at the XN > nipple, then annulus will be tested to 4,500-psi. > > Please let me know if you have any problem with the proposed layout. > > Cheers, > > Matt. > > «MPS-22 JetPump Comp v2.0.ZIP» > >------------------------------------------------------------------------ > Name: MPS-22 JetPump Comp v2.0.ZIP > MPS-22 JetPump Comp v2.0.ZIP Type: Zip Compressed Data (application/x -zip-com pressed) > Encodmg:base64 r--.----.........:-.M"..-----...-..----¡.-..'.'".--.-----",..-.-__._._......__....'-".....",......""'....>.:;"...:......______ .. Name: MPS-22 JetPump Comp v2.0.pdf ~MPS-22 JetPump Comp v2.0.pdf Type: Acrobat (application/pdf) Encoding: quoted-printable 1 of 1 9/23/2003 1 :06 PM TREE: Cameron 4-1/16" 5M WELLHEAD: FMC Gen 6 11",5M Tubing Head: 11" x 4-1/2", FMC Tubing Hanger 112' 20" 92 Ib/tt, H-40 Welded Insulated 10-3/4" 45.5#, L-80, BTC-M Casing Drift: 9.875 Casing 10: 9.950 Coupling 00: 11.75" Burst: 5,210 psi Collapse: 2,480 psi 7-5/8" 29.7#, L-80, BTC-M Casing Drift: 6.75 Casing 10: 6.875 Coupling 00: 11.75" Burst: 6,890 psi Collapse: 4,790 psi PROPOSED COMPLETION. . - Diesel Freeze protect to 500' MD 9.7-lb/gal KCI with corrosion inhibitor as packer fluid Jet Pump Installed in Sliding Sleeve Post rig! 9-7/8" Hole 7.625" Casing Shoe @ 5,148' MD; 3,737' TVD Well Inclination @ Shoe = 77 Degrees DATE 18 Sep 2003 REV. BY MDG COMMENTS Monobore Completion KB. ELEV =72.0' Cellar Box ELEV = 38.1' 42" Hole -1/2" x 1" Gas Lift Mandrel @ 2,200' MD; 1,965' TVD, 13-1/2" hole 4-112", 12.6Iblft, L-80, IBT-M Coupling 00: 5.2" DriftllD: 3.833" Burst: 8,430, 80% 6,744 psi Colla se: 7 500 80% 6 000 si 10-3/4"@ 2563' MD, 2,412' TVDrkb ;)O~- \q ~ Phoenix Pressure Gauge (3.850" ID, W/BIW I-wire down to lower sensor) Phoenix Pressure Gaug 4.5-in HES 'XN' nipple 2.750" ID No Go W/RHC ball & rod 7-5/8" x 5-1/2" C-2 ZXP I Set @ 5,000' MD Liner Top Packer Casing Seal Receptacle and Locator Seal Assembly 5" Sand Screen Liner W/Baker Flexlock liner hanger - - -- - - - - -- Ugnu Horizontal 6-1/8" hole 19,423' MD/3,597' TVD Milne Point Unit WELL - MPS-22 API NO' BP Exploration (Alaska) . . FRANK H. MURKOWSKI, GOVERNOR AI¡ASKA. OIL AND 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. PO Box 196612 Anchorage AK 99519 Re: Milne Point Unit MPS-22 BP Exploration (Alaska), Inc. Permit No: 203-147 Surface Location: 3297' NSL, 238' WEL, SEC. 12, TI2N, RI0E, UM Bottomhole Location: 774' NSL, 1218' WEL, SEe. 11, TI2N, RI0E, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, H~~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this '" day of September, 2003 cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encI. Exploration, Production and Refineries Section _ STATE OF ALASKA .. ALASKA ðll!'AND GAS CONSERVATION COMWsSION PERMIT TO DRILL 20 MC 25.005 1a. Type of work III Drill o Redrill rb. Current Well Class o Exploratory III Development Oil o Multiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas III Single Zone 2. Operator Name: 5. Bond: IHI Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S 1 00302630-277 MPS-22 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 9423' TVD 3597' Milne Point Unit / Ugnu 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 380109 3297' NSL, 238' WEL, SEC. 12, T12N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 2299' NSL, 3041' WEL, SEC. 12, T12N, R10E, UM September 16, 2003 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 774' NSL, 1218' WEL, SEC. 11, T12N, R10E, UM 2560 770' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool Surface: x-565773 ' y- 5999964 . Zone-ASP4 (Height above GL): KBE = 72' feet None 16. Deviated Wells: 17. Anticipated pressure (see 20 AA,C 25.035) 0 Kickoff Depth . 400 ft Maximum Hole Angle 96 Max. Downhole Pressure: 1631 psig. Max. Surface Pressure: 1255 psig ~ß.ÇªsingProgram Specifications Setting Depth Quantity of Cement Size Top Bottom (c.f. or sacks) Hole Casina Weiaht Grade CouDlina Lenath MD TVD MD TVD (includinQ staQe data) 42" 20" 92# H-40 Weld 112' Surface Surface 112' 112' 60 sx Arctic Set (Approx.) 13-1/2" 10-3/4" 45.5# L-80 BTC 2563' Surface Surface 2563' 2412' 93 sx Class 'L', 261 sx Class 'G' 9-7/8" 7-5/8" 29.7# L-80 BTC 5148' Surface Surface 5148' 3737' 71 sx Class 'G' 6-1/8" 5"x4" 15.5# x 9.5# L-80 BTC 4375' 5048' 3747' 9423' 3597' and Screen Liner 19: » iJ'PI ELI..\..iUNUI .IUN SUMtv1A~'Y'.(To beCQn"IpleteqforReqriU.ANQ.ß~øl1trYOþ!;}ratiqÓ$) , ...../ Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): I Effective Depth TVD (ft): I Junk (measured): i~ .).'i ""' i'" 'ii" OIL."."'" )) .» '''''' i·i,...· »'MQ'·i C:::tro ,do or",1 Conductor ~, 1. Production Liner Perforation Depth MD (ft): IPerfOration Depth TVD (ft): 20. Attachments IHI Filing Fee o BOP Sketch IHI Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report o Drilling Fluid Program 1H120 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Campbell, 564-4401 Printed Name Pat Archey Title Senior Drilling Engineer -fJ 'S ac4., Phone X .>ØO) Date,.;11/03 Prepared By Name/Number: Signature Sondra Stewman, 564-4750 , Commission Use Only Permit To Dril~L3' c./ I API Number: 2-3 JÎtp -- oð I Permit A~/}~ /. I See cover letter for Number: 2- - / 7 50- ('12- q- Date: ~ ot . ~ ;/ f" ,~' ", Conditions of Approval: Samples Required DYes JNO Mud Log Réquireè! ./ tJ'Yes \~; \{ J Hydrogen Sulfide Measures D Yes No Directional Survey Required ~X~r ¡.or\? Other: ",."-..--" ,,"," ,-".' ~,L~ ORIGINAL :7/I¿/ð'3 ß-.~ BY ORDER OF ADDroved Bv: COMMISSIONER THE COMMISSION Date Form 10-401 Revised 3/200t Submit In Duplicate e _e Point MPS-22 Well Permit IWell Name: I MPS-22 Drill and Complete Plan Summary I Type of Well (service / producer / injector): I Single Lateral Producer UPPER TUZB I ./ ./ Surface Location: 1983' FNL, (3296' FSL): 238' FEL, (5041' FWL), SEC. 12, T12N, R10E E=565772.53 N=5999963.59 ,/ Target Location: 2980' FNL, (2299' FSL), 3041' FEL, (2237' FWL), SEC.12, T12N, R10E TOP "TUZB" E=562977.65 N=5998942.59 Z=3757' TVD Target Location: 4504' FNL, (774' FSL), 1218' FEL, (4060' FWL), SEC. 11 T12N, R10E BHL Well TD E=559535 N=5997390.0.0 Z=3597' TVD Distance to Property line 770' Distance to nearest pool NA No other producing/injection wells within the Ugnu .,;' " I AFE Number: I I Rig: I Doyon 14 I Estimated Start Date: I Sep. 16 2003 I Operating days to complete: 113.3 [M[] 9423 II I TVD: 13597 ( I Max Inc: ~ I KOP: ~ I KBE: 172 Well Design (conventional, slim hole, etc.): Conventional Grass Roots Lateral Producer ./ I Objective: I Ugnu TUZB Sand Mud Program: 13-1/2" Surface Hole Mud Properties: Spud - LSND Freshwater Mud Density Funnel visc YP HTHP pH API Filtrate LG Solids 8.6-9.0 75 - 150 25 - 60 N/A 8.5 -9.5 <8 <12 9-7/8" Intermediate Hole Mud Properties: LSND Freshwater Mud Densitv , Funnel visc YP HTHP pH API Filtrate LG Solids 9.0-9.3 75 - 150 25 - 60 N/A 9.0-9.5 <8 <12 6.125-in Production Hole Mud Properties: KCL-CaC03 Flo-Pro Density , Funnel visc YP HTHP pH API Filtrate LG Solids 8.6 -10.0 40 - 55 22 - 27 <10 8.0- 8.5 4-6 <8 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation ,/ Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-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 1 R. 1 Cement Program: e . Point MPS-22 Well Permit Wash S acer Lead Tail Temp 20-bbl water 50-bbl 10.2-lb/ al AI ha S acer 364-bbl, 493-sx 10.7 Ib/gal Class L - 4.15 ft /sx cement to surface 54-bbl, 261-sx 15.8 Ib/gal Prem G - 1.15 ft /sx to of tail at 2, 135-ft MD BHST == 55°F from SOR, BHCT 60°F estimated by Halliburton Casin Size 7-5/8 29.7-lb/ft L-80 BTC Intermediate Casin Basis 40% excess over au e hole. Lead 500-ft MD above to of U nu. Total Cement Volume: 88-bbl Wash 5-bbl water S acer Lead Temp Evaluation Program: 13-1/2" Section Open Hole: MWD/GR IFRlCASANDRA Gvro as reQuired Cased Hole: N/A 9-7/8" Section Open Hole: MWD/GRlRES IFRlCASANDRA Cased Hole: N/A 6-1/8"Section Open Hole: MWD/GRlRES ABIIPWD IFRlCASANDRA ". ". 2 e ,. Point MPS-22 Well Permit Formation Markers: Formation Tops Base Permafrost TUZC TUZC-1 TUZB MDrkb ft 1867 4574 5148 5349 TVDrkb ft 1822 3542 3737 3757 Pore Pressure si 1537 1622 1631 8.35 8.35 8.35 CasingITubing Program: Hole Csg/ WtlFt Grade Conn Length Top Bottom Size Tba O.D. MD / TVDrkb MD / TVDrkb 42-in 20-in* 92# H-40 Weld 112' 0 112-ft/ 112-ft 1 3-1 12" 1 0-3/4" 45.5# L-80 BTC 2563 0 2563' I 2412' 9-7/8" 7-5/8" 29.7# L-80 BTC 5148' 0 5148' I 3737' 6-1/8" 4-1/2" 12.7# L-80 BTC 4375' 5048' I 3747' 9423'/3597' NB *The 20" casing is insulated Recommended Bit Program: BHA Hole Size Depth (MD) Bit Type Nozzle/Flow rate 1 13-1/2" 0-2,536' Mill tooth 3-15 & 1-1 0 2 9-7/8" 2,536' -5148' Mill tooth 3-15 & 1-1 0 3 6-1/8" 5148' - TD Secu rity 3-12 FM2643 3 e . Point MPS-22 Well Permit Well Control: Surface Interval · The surface hole will be drilled with a diverter. Intermediate and Production Intervals · Maximum anticipated BHP: · Maximum surface pressure: 1 ,631-psi @ 3,757-ft TVD - Top of TUZB-sand . 1,255-psi @ surface. (Based on BHP and a full column of gas from TD @ 0.1-psi/ft) Diverter will be function tested. BOPs: Test annular 250-psi low and 2,500-psi high, and rams to 250-psi low and 3,500-psi high. An FIT to 11.5-lb/gal will be made on the 7-5/8" casing shoe. 59-bbl with 9.2-lb/gal mud and FIT of 11.5-lb/gal @ 10-3/4" casing shoe. 9.2-lb/gal NaCI I 6.8-lb/gal Diesel · Planned BOP test pressure: · Integrity test: · Kick tolerance: · Planned completion fluid: Drilling Hazards & Contingencies: Hydrates · Hydrates have not been seen on S pad, but has been encountered in the surface holes on other pads, especially nearby H-Pad. Hydrates generally occur just below the Permafrost (+1- 1800 ss) but may be present in shallower SV sands and also as deep as 3000 ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates. Pretreat mud with DrilTreat; Increase mud wt; Maintain cool mud « 60 deg F); Limit ROP and Reduce pump rate while drilling hydrates; Circulate connections thoroughly. See Well Program and Recommended Practices for specific information. · Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation · We do not expect losses while drilling this well. / · Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Below is a list of the wells and the lost circulating problems associated with them. H-06 (1995): Lost 100 bbls running 9-5/8" casing, good returns during cementing except no returns for last 20 bbls, contaminated cement to surface, cement 12 ft down, no top job. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures ~ ~ /.» · It is unlikely there will be unexpected overpressure when drilling to the Sc~f formation. Reservoir pressure is expected to be (8.35 Ib/gal EMW). . 4 e . Point MPS-22 Well Permit Pad Data Sheet · Please read the S-Pad Data Sheet thoroughly. Breathing · N/A Hydrocarbons 0-r¡,c- .. ~b · Hydrocarbons will be encountered in th~t~~ Faults Hydrogen Sulfide · MPS Pad is not designated as an H2S Pad. Anti-collision Issues 5 e DRILL & COMPLETION PROCEDURE . Point MPS-22 Well Permit Pre-Rig Operations 1. Install 20-in insulated conductor. Procedure 1. MIRU. NU diverter on 20-in conductor and function test. 2. Drill 13-1/2" surface hole as per directional plan. 3. Case and cement 1 0-3/4" surface casing. 4. NO diverter, NU BOPE and test. 5. Perform FIT. it tn~ ~ /;. 6. Drill 9-7/8" hole to land in top of thepdtf-sand as per directional plan. 7. Case and cement 7-5/8" intermediate casing. Freeze protect 7-5/8" x 10-3/4" annulus. 8. Drill out shoe~d 20-ft new formation and perform FIT. 9. Drill 6-1/8")dB-sand lateral as per directional plan. 1 O. Run 5" uncemented sand screens and hang off 100-ft inside 7-5/8" casing. 11. Displace drilling mud to brine. 12. Run 4-1/2" jet pump completion as per schematic. 13. Land tubing hanger and test. 14. Set BPV. 15. NO BOP. 16. Install and test tree. 17. Pull BPV. 18. Test 7-5/8" x 4-1/2" annulus. 19. Freeze protect thru GLM. 20. Install BPV and secure well. 21. RD/MO. 6 Jet Pump Installed in Sliding Sleeve Post rig! . KB. ELEV =72.0' Cellar Box ELEV = 38.1' TREE: Cameron 4-1/16" 5M WELLHEAD: FMC Gen 6 11 ", 5M Tubing Head: 11" x 4-1/2", FMC Tubing Hanger 112' Diesel Freeze protect to 500' MD 42" Hole -1/2" x 1" Gas Lift Mandrel @ 2,200' MD; 1,965' TVD, 20" 92 Ib/tt, H-40 Welded Insulated 13-1/2" hole 10-3/4" 45.5#, L-80, BTC-M Casing Drift: 9.875 Casing 10: 9.950 Coupling 00: 11.75" Burst: 5,210 psi Collapse: 2,480 psi 4-1/2",12.6 Iblll, L-80, IBT-M Coupling 00: 5.2" OriIVIO: 3.833" Burst: 8,430, 80% 6,744 psi II e: 7 500 80% 6 0 10-3/4"@ 2563' MD, 2,412' TVDrkb 9.7-lb/gal KCI with corrosion inhibitor as packer fluid Phoenix Pressure Gauge (3.850" ID, W/BIW 1- wire down to lower sensor) Phoenix Pressure Gauge (2.840" ID) 7-5/8" 29.7#, L-80, BTC-M Casing Drift: 6.75 Casing 10: 6.875 Coupling 00: 11.75" Burst: 6,890 psi Collapse: 4,790 psi 7-5/8" x 4-1/2" Premier Packer Iset @ 5,000' MD 3-1/2" HES 'XN' nipple 2.750" IDNo Go W/RHC ball & rod Wireline Entry Guide 9-7/8" Hole 7.625" Casing Shoe @ 5,148' MD; 3,737' TVD Well Inclination @ Shoe = 77 Degrees 5" Sand Screen Liner W/Baker HR-ZXP liner hanger -- - - -- - - - - - - -- "NSHorizontal 6-1/8" hole () ð I'lIA- .;!b 19,423' MD/3,597' TVD I·· DATE REV. BY COMMENTS Milne Point Unit WELL: MPS-22 API NO: COMPANY DErAILS BPAmœo REFERENCE INFORMATION 72.70 Calculation Method; Minimum Guvature Error System: ISCWSA Scan Method; Trav Cylinder North Error Surface: Elliptical + OIsing Wamin Method; RuJes Based SURVEY PROGRAM j)¢pth Fm Depth To Srnvey/P1a.n Tool Date: 8/29/2003 Date Reoviewed: Date:~ Name +N/...s +E!~W Northing Plan MPS·22 -932 ~572.63 599996359~. 56577253"> Longitude Slot 149"17'5L955W N/A TARGET DETAILS N,,,,,, TVD +N1-g +P1·W Easting. Shape Narthíng SECTION DETAILS See MD lfie Azi IVD +N/-S +E/-W DLeg TFace VSec Target Start Dir 2/100' : 400' MD, 400'TVD I 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 /' 2 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 / . Start Dír 2.5/100' : 500' MD, 499.98'TVD 3 500.00 2.00 ]80.00 499.98 -1.75 0.00 2.00 ]80.00 0.65 4 685.01 6.00 219.19 684.53 -12.47 -6.11 2.50 55.00 10.33 5 1113.07 14.00 265.00 11 06.29 -34.39 -72.02 2.50 69.08 79.66 6 1472.04 ]9.38 265.00 1450.00 -43.37 ·174.70 1.50 0.00 178.26 7 1919.40 19.38 265.00 ]872.00 -56.31 ·322.62 0.00 0.00 320.32 8 2831.16 55.67 258.28 2583.30 ·149.12 ·860.26 4.00 ·9.36 853.75 9 4150.85 55.67 258.28 3327.48 ·370.48 ·1927.39 0.00 0.00 1926.38 10 5]48.48 77.00 221.00 3737.70 ·840.]0 ·2680.29 4.00 ·66.93 2800.]5 MPS-22 T1.1 Start Dir 1.5/100' : 11 13.07' MD, !l06.29'TVD 11 5168.48 77.00 221.00 3742.20 ·854.81 .2693.07 0.00 0.00 28] 7.50 ]2 5266.42 88.07 2]7.02 3754.9] ·930.]7 .2754.06 12.00 ·19.92 2902.21 13 5818.37 88.07 217.02 3773.47 -1370.62 -3086.18 0.00 0.00 3374.73 14 5900.49 93.00 217.00 3772.70 ·1436.17 ·3135.60 6.00 -0.21 3445.04 MPS-22 T2.1 15 5965.20 96.66 215.70 3767.25 ·1488.09 .3173.81 6.00 ·19.49 3499.87 End Dir : 1472.04' MD, 1450' TVD 16 6502.99 96.66 215.70 3704.89 ·1921.89 ·3485.49 0.00 0.00 3950.94 17 6993.32 93.00 245.00 3662.70 -2229.92 ·3857.68 6.00 95.73 4411.21 MPS·22 13.1 18 7333.78 87.64 264.72 3660.77 ·2318.36 ·4184.59 6.00 105.00 4747.50 19 8101.59 87.64 264.72 3692 .36 -2388.95 ·4948.49 0.00 0.00 5482.54 20 8210.96 92.00 264.33 3692.70 ·2399.38 ·5057.33 4.00 -5.09 5587.41 MPS-22 T4.1 21 8274.96 94.56 264.33 3689.04 -2405.69 -5120.91 4.00 0.00 5648.75 Start Dir 4/100' : 1919.4' MD, 1872'TVD 22 9423.83 94.56 264.33 3597.70 -2518.80 ·626055 0.00 0.00 6748.24 MPS-22 T5.1 FORMA nON TOP DET AlLS CASING DETAlLS No. TYDPath MDPath Formation No. TVD MD Name Size 1 1822.70 1867.14 BPRF 1 2412.70 2563.52 2 3542.70 4574.30 TUZC 2 3737.70 5]48.48 3 3737.70 5]48.48 TUZC·] 3 3597.70 9423.82 5 screens!! 4 3757.70 5349.47 TUZB End Dír : 283l.J6' MD, 2583.3' TVD : 4150.85' MD, 3327.48'TVD End Dir : 5148.48' MD, 3737.7' TVD Start Dir 12/100': 5168.48' MD, 3742.2'TVD End Dir : 5266.42' MD, 3754.91' TVD 800 1600 if COMPANY DETAILS REFERENCE INFOR,\iA TION SURVEY PROGRAM Plan: MPS-22 wp06 (PJan MPS-22iPJan MPS-22) BPAmoco J::kpth Fm J::kpth To &'tttveyiP.Ian Too! Created By: Ken Allen Cheçked: Date: 8/2912ù03 Calculation Method: Minimum Curv:J.ÌUn~ Euor System: ¡SeWSA ScauMethod: TravCylinderNorth w~or=:: ~~~~Qwing 72.70 CB-GYRO-SS MWD+IFR+MS Date Reviewed: Date SECTION DETAILS FORMA nON TOP DETAILS See MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target No. TVDPath MDPat1, Formation I 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 1 1822.70 1867.14 BPRF 2 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 2 3542.70 4574.30 TUZC 3 500.00 2.00 180.00 499.98 -1.75 0.00 2.00 180.00 0.65 3 3737.70 5148.48 TUZC-1 4 685.01 6.00 219.19 684.53 -12.47 -6.1I 2.50 55.00 10.33 4 3757.70 5349.47 TUZB 5 1113.07 14.00 265.00 1106.29 -34.39 -72.02 2.50 69.08 79.66 6 1472.04 19.38 265.00 1450.00 -43.37 ·174.70 1.50 0.00 178.26 7 1919.40 19.38 265.00 1872.00 -56.31 -322.62 0.00 0.00 320.32 8 2831.16 55.67 258.28 2583.30 -149.12 -860.26 4.00 -9.36 853.75 9 4150.85 55.67 258.28 3327.48 -370.48 -1927.39 0.00 0.00 1926.38 10 5148.48 77.00 221.00 3737.70 -840.10 -2680.29 4.00 -66.93 2800. I 5 MPS-22 n.l 11 5168.48 77.00 221.00 3742.20 -854.81 -2693.07 0.00 0.00 2817.50 12 5266.42 88.07 217.02 3754.91 -930.17 -2754.06 12.00 -19.92 2902.21 13 5818.37 88.07 217.02 3773.47 -1370.62 -3086.18 0.00 0.00 3374.73 14 5900.49 93.00 217.00 3772.70 -1436.17 -3135.60 6.00 -0.21 3445.04 MPS-22 T2.1 15 5965.20 96.66 215.70 3767.25 -1488.09 -3173.81 6.00 -19.49 3499.87 16 6502.99 96.66 215.70 3704.89 -1921.89 -3485.49 0.00 0.00 3950.94 17 6993.32 93.00 245.00 3662.70 -2229.92 -3857.68 6.00 95.73 4411.21 MPS-22 B.! 18 7333.78 87.64 264.72 3660.77 -2318.36 -4184.59 6.00 105.00 4747.50 19 8101.59 87.64 264.72 3692.36 -2388.95 -4948.49 0.00 0.00 5482.54 20 8210.96 92.00 264.33 3692.70 -2399.38 -5057.33 4.00 -5.09 5587.41 MPS-22 T4.1 21 8274.96 94.56 264.33 3689.04 -2405.69 -5120.91 4.00 0.00 5648.75 22 9423.83 94.56 264.33 3597.70 -2518.80 -6260.55 0.00 0.00 6748.24 MPS-22 T5. 1 WELL DETAILS N"",, +N/-S +E!-W Northing .llisting Latitude Longitude Slot PlanMPS-22 -9.31 -512.63 599996359 56577253 70"14'31.237N j49"27'5L955W N/A TARGET DETAILS N"",, TVD +N¡...g +E!-W Nillihing Easting Shape MPS-22T5.l MPS-12 T3J MPS-22 T4.l MPS--22 TLl MPS-22 FolyLl MPS-22 T2.l CASING DETAILS No. TVD MD Name 2412.70 2563.52 10314" 3737.70 5148.48 7 5/8" 3597.70 9423.82 5 scroons" Size 10.750 7.625 5.000 -2400 Start Djr 2/100' : 400' MD, 400'TVD Start Djr 2.5/100' : 500' MD, 499.98'TVD Start Dir 1.5/100' : 1 113J)7' MD, 1l06.29'TVD \ End Djr : 1472.04' MD, 1450' TVD \' '2 -800 :fi '" '" eo:. +' :E ~ ~ ~ ;:J 0 -160 00 -3200 West(-)/East(+) [800f!lin] Company: Field: Site: Well: Wellpath: e BP KW A Planning Report BP Amoco Milne Point M PtSPad Plan MPS-22 Plan MPS-22 e Date: 8/29/2003 Time: 12:02:25 Page: Co-ordinate(NE) Reference: Well: Plan MPS-22. True North Vertical (TVD) Reference: 72.70 MPS-22 WI D-14 @ 72.7 Section (VS) Reference: Well (0.00N,0.00E.248.08Azi) Survey Calculation Method: Minimum Curvature Db: Oracle 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: Site: M pt S Pad Northing: Easting: 5999978.00 ft 566345.00 ft Latitude: 70 24 Longitude: 149 27 North Reference: Grid Convergence: Site Position: From: Map Position Uncertainty: Ground Level: Well: 0.00 ft 0.00 ft Plan MPS-22 Slot Name: Well Position: +N/-S -9.32 ft Northing: 5999963.59 ft Latitude: +E/-W -572.63 ft Easting: 565772.53 ft Longitude: Position Uncertainty: 0.00 ft _n_n__..' .......___._.... Alaska, Zone 4 Well Centre bggm2003 37.329 N 35.171 W True 0.51 deg 70 24 37.237 N 149 27 51.955 W Wellpath: Plan MPS-22 Current Datum: Magnetic Data: Field Strength: Vertical Section: 72.70 MPS-22 WI D-14 @ 11/1/2002 57504 nT Depth From (TVD) ft 34.30 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Well Ref. Point 34.30 ft Mean Sea Level 25.70 deg 80.80 deg Direction deg 248.08 Height 72.70 ft +N/-S ft 0.00 Principal: Yes Plan: MPS-22 wp06 Date Composed: Version: Tied-to: Casing Points MD ft 2563.52 5148.48 9423.82 Formations MD ft 1867.14 4574.30 5148.48 5349.47 Targets TVD ft 2412.70 3737.70 3597.70 Hole Size in Diameter in n.___uh_......____ ...... .....n................_. ....n. .... ..... .._O"__._._U_. 10.750 7.625 5.000 12.250 9.875 6.125 103/4" 7 5/8" 5 screens" 8/28/2003 31 From Well Ref. Point ._--~~_~=J ..---- TV]) ft . ,..--- ....-. .... 1822.70 BPRF 3542.70 TUZC 3737.70 TUZC-1 3757.70 TUZB Map Map Name Description TVD +N/-S +E/-W Northing Easting Dip. Dir. ft ft ft ft ft -----..-.--.-. ........ "0'." . ._~___.___..____._..__._.___. ".n_ .._u__..____..____.. __. _.__.. MPS-22 T5.1 3597.70 -2518.80 -6260.55 5997390.00 559535.00 MPS-22 T3.1 3662.70 -2229.92 -3857.68 5997700.00 561935.00 MPS-22 T4.1 3692.70 -2399.38 -5057.33 5997520.00 560737.00 MPS-22 T1.1 3737.70 -840.10 -2680.29 5999100.00 563100.00 MPS-22 Poly1.1 3737.70 -758.07 -2909.59 5999180.00 562870.00 -Polygon 1 3737.70 -758.07 -2909.59 5999180.00 562870.00 -Polygon 2 3737.70 -761.66 -2502.57 5999180.00 563277.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 <- Latitude ---> <- Longitude -> : Deg Min Sec Deg Min Sec ....- ..-..-..-.-.-......-.- 70 24 12.439 N 149 30 55.393 W 70 24 15.296 N 149 29 44.992 W 70 24 13.622 N 149 3020.141 W 70 24 28.970 N 149 29 10.507 W 70 24 29.776 N 149 29 17.228 W 70 24 29.776 N 149 29 17.228 W 70 24 29.742 N 149 29 5.299 W Company: Field: Site: Well: Wellpatb: Targets --.--.......--. Name -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 MPS-22 T2.1 BP Amoco Milne Point M PI S Pad Plan MPS-22 Plan MPS-22 e Description TVD Dip. Dir. ft 3737.70 3737.70 3737.70 3737.70 3737.70 Plan Section Information MD ft 34.30 400.00 500.00 685.01 1113.07 1472.04 1919.40 2831.16 4150.85 5148.48 5168.48 5266.42 5818.37 5900.49 5965.20 6502.99 6993.32 7333.78 8101.59 8210.96 8274.96 9423.83 Survey ft 34.30 100.00 200.00 300.00 400.00 500.00 600.00 685.01 700.00 800.00 900.00 1000.00 1100.00 1113.07 1200.00 1300.00 1400.00 1472.04 1500.00 1600.00 Incl deg 0.00 0.00 2.00 6.00 14.00 19.38 19.38 55.67 55.67 77.00 77.00 88.07 88.07 93.00 96.66 96.66 93.00 87.64 87.64 92.00 94.56 94.56 deg 0.00 0.00 0.00 0.00 0.00 Azim .. deg 0.00 0.00 180.00 219.19 265.00 265.00 265.00 258.28 258.28 221.00 221.00 217.02 217.02 217.00 215.70 215.70 245.00 264.72 264.72 264.33 264.33 264.33 Azim deg 0.00 0.00 0.00 0.00 0.00 2.00 4.00 6.00 6.14 7.52 9.37 11.47 13.70 14.00 15.30 180.00 210.83 219.19 222.47 240.17 251.70 259.26 264.44 265.00 265.00 265.00 265.00 265.00 265.00 265.00 16.80 18.30 19.38 19.38 19.38 BP KW A Planning Report +N/-S ft -961.67 -2421.21 -2678.77 -2358.75 -2138.11 e Date: Time: 12:02:25 Co-ordinate(NE) Reference: Well: Plan MPS-22. True Vertical (TVD) Reference: 72.70 MPS-22 WI D-14 @ 72.7 Section (VS) Reference: Well (0.00N,0.00E.248.Ö8Azi) Survey Calculation Method: Minimum Curvature Db: Oracle ...._______.__ .. ....._..__..__..._.h.......___.... ....._____n_.·.. +E/-W ft -2504.33 -3714.35 -6266.96 -6264.14 -4061.90 Map Map <- Latitude --> <-- Longitude -> Northing Easting Deg Min Sec Deg Min Sec ft ft .-.--.----... .....--.--...-.-.--..... .--......-.-.----. 5998980.00 563277.00 70 24 27.775 N 149 29 5.349 W 5997510.00 562080.00 70 24 13.415 N 149 29 40.789 W 5997230.00 559530.00 70 24 10.866 N 149 30 55.577 W 5997550.00 559530.00 70 24 14.013 N 149 30 55.502 W 5997790.00 561730.00 70 24 16.198 N 149 2950.977 W 3772.70 -1436.17 -3135.60 5998500.00 562650.00 70 2423.106 N 149 2923.843 W TVD ft 34.30 400.00 499.98 684.53 1106.29 1450.00 1872.00 2583.30 3327.48 3737.70 3742.20 3754.91 3773.47 3772.70 3767.25 3704.89 3662.70 3660.77 3692.36 3692.70 3689.04 3597.70 ft 34.30 100.00 200.00 300.00 400.00 499.98 599.84 684.53 699.43 798.73 897.65 996.00 1093.59 1106.29 1190.38 1286.48 1381.82 1450.00 1476.38 1570.71 +N/-S ft 0.00 0.00 -1.75 -12.47 -34.39 -43.37 -56.31 -149.12 -370.48 -840.10 -854.81 -930.17 -1370.62 -1436.17 -1488.09 -1921.89 -2229.92 -2318.36 -2388.95 -2399.38 -2405.69 -2518.80 +EI-W DLS Build Turn ft deg/100ft deg/100ft deg/100ft _...._.._.....-----~--......._._._. 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 2.00 -6.11 2.50 2.16 -72.02 2.50 1.87 -174.70 1.50 1.50 -322.62 0.00 0.00 -860.26 4.00 3.98 -1927.39 0.00 0.00 -2680.29 4.00 2.14 -2693.07 0.00 0.00 -2754.06 12.00 11.31 -3086.18 0.00 0.00 -3135.60 6.00 6.00 -3173.81 6.00 5.65 -3485.49 0.00 0.00 -3857.68 6.00 -0.75 -4184.59 6.00 -1.57 -4948.49 0.00 0.00 -5057.33 4.00 3.98 -5120.91 4.00 4.00 -6260.55 0.00 0.00 0.00 0.00 0.00 21.18 10.70 0.00 0.00 -0.74 0.00 -3.74 0.00 -4.07 0.00 -0.02 -2.01 0.00 5.98 5.79 0.00 -0.36 0.00 0.00 ft -38.40 27.30 127.30 227.30 327.30 427.28 527.14 611.83 626.73 726.03 824.95 923.30 1020.89 1033.59 1117.68 1213.78 1309.12 1377.30 1403.68 1498.01 .... ."-. ...._---.. . 5999963.59 5999963.59 5999963.59 5999963.59 5999963.59 565772.53 565772.53 565772.53 565772.53 565772.53 5999961.85 5999957.09 5999951.07 5999949.86 5999942.57 565772.55 565770.80 565766.53 565765.50 565756.27 5999936.64 5999932.08 5999928.89 5999928.57 5999926.46 5999923.81 5999920.92 5999918.69 5999917.80 5999914.61 565742.92 565725.46 565703.93 565700.82 565678.93 565651.41 565621.39 565598.23 565589.00 565555.96 ft 0.00 0.00 0.00 0.00 0.00 0.65 4.08 10.33 11.74 23.05 37.65 55.54 76.66 79.66 100.69 127.15 156.00 178.26 187.14 218.90 TFO deg 0.00 0.00 180.00 55.00 69.08 0.00 0.00 -9.36 0.00 -66.93 0.00 -19.92 0.00 -0.21 -19.49 0.00 95.73 105.00 0.00 -5.09 0.00 0.00 deg/100ft 0.00 0.00 0.00 0.00 0.00 2.00 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 1.50 1.50 1.50 1.50 0.00 0.00 Target nn...._____.._n MPS-22T1.1 MPS-22 T2.1 MPS-22 T3.1 MPS-22 T4.1 MPS-22 T5.1 ".. .--...----.--. 0.00 CB-GYRO-SS 0.00 CB-GYRO-SS 0.00 CB-GYRO-SS 0.00 CB-GYRO-SS 0.00 CB-GYRO-SS 0,00 CB-GYRO-SS 55.00 CB-GYRO-SS 24.21 CB-GYRO-SS 69.08 CB-GYRO-SS 65.83 CB-GYRO-SS 48.25 CB-GYRO-SS 36.84 CB-GYRO-SS 29.41 CB-GYRO-SS 24.34 CB-GYRO-SS 0.00 CB-GYRO-SS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS e BP KW A Planning Report e , Company: BP Amoco " Date: 8/29/2003 Time: 12:02:25 Page: 3 I Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-22, True North Site: M Pt S Pad Vertical (TVD) Reference: 72.70 MPS-22 WI 0-14 @ 72.7 Well: Plan MPS-22 Section (VS) Reference: Well (0.00N,0.00E,248.08Azi) Wellpath: Plan MP5-22 Survey Cakulation Method: Minimum Curvature I)b: Oracle ..h_~._..__._.__ ...---...-....- ---.- ----......-... ,- ......... ..........- --.. --..- "I Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Too ft deg deg ft ft ft ft ft deg/100ft deg .... ,"-- ... .. _n. .........-----.---. ........... ........n._ ..-....... ......... _._n_____..._._m_ ....----.... ..n. 1700.00 19.38 265.00 1665.04 1592.34 5999911.43 565522.93 250.65 0.00 0,00 MWD+IFR+MS 1800.00 19.38 265.00 1759.37 1686.67 5999908.25 565489.89 282.41 0.00 0.00 MWD+IFR+MS 1867.14 19.38 265.00 1822.70 1750.00 5999906.11 565467.72 303.73 0.00 0.00 BPRF 1900.00 19.38 265.00 1853.70 1781.00 5999905.06 565456.86 314.16 0.00 0.00 MWD+IFR+MS 1919.40 19.38 265.00 1872.00 1799.30 5999904.44 565450.45 320.32 0.00 0.00 MWD+IFR+MS 2000.00 22.57 263.64 1947.25 1874.55 5999901.31 565421.77 348.03 4.00 350.64 MWD+IFR+MS 2100.00 26.54 262.38 2038.19 1965.49 5999895.86 565380.59 388.18 4.00 351.92 MWD+IFR+MS 2200.00 30.51 261.43 2126.03 2053.33 5999888.69 565333.40 434.55 4.00 353.06 MWD+IFR+MS 2300.00 34.49 260.68 2210.35 2137.65 5999879.85 565280.41 486.90 4.00 353.90 MWD+IFR+MS 2400.00 38.47 260.07 2290.74 2218.04 5999869.38 565221.90 544.99 4.00 354.53 MWD+IFR+MS 2500.00 42.46 259.55 2366.80 2294.10 5999857.32 565158.15 608.53 4.00 355.03 MWD+IFR+MS 2600.00 46.45 259.11 2438.17 2365.47 5999843.75 565089.46 677.20 4.00 355.42 MWD+IFR+MS 2700.00 50.44 258.72 2504.49 2431.79 5999828.71 565016.18 750.69 4.00 355.73 MWD+IFR+MS 2800.00 54.43 258.38 2565.45 2492.75 5999812.30 564938.66 828.62 4.00 355.99 MWD+IFR+MS 2831.16 55.67 258.28 2583.30 2510.60 5999806.91 564913.69 853.75 4.00 356.20 MWD+IFR+MS 2900.00 55.67 258.28 2622.12 2549.42 5999794.88 564858.14 909.70 0.00 0.00 MWD+IFR+MS 3000.00 55.67 258.28 2678.51 2605.81 5999777.39 564777.44 990.98 0.00 0.00 MWD+IFR+MS 3100.00 55.67 258.28 2734.90 2662.20 5999759.91 564696.73 1072.26 0.00 0.00 MWD+IFR+MS 3200.00 55.67 258.28 2791.29 2718.59 5999742.43 564616.03 1153.54 0.00 0.00 MWD+IFR+MS 3300.00 55.67 258.28 2847.68 2774.98 5999724.94 564535.33 1234.82 0.00 0.00 MWD+IFR+MS 3400.00 55.67 258.28 2904.07 2831.37 5999707.46 564454.62 1316.10 0.00 0.00 MWD+IFR+MS 3500.00 55.67 258.28 296Q.46 2887.76 5999689.98 564373.92 1397.38 0.00 0.00 MWD+IFR+MS 3600.00 55.67 258.28 3016.85 2944.15 5999672.49 564293.22 1478.66 0.00 0.00 MWD+IFR+MS 3700.00 55.67 258.28 3073.25 3000.55 5999655.01 564212.51 1559.93 0.00 0.00 MWD+IFR+MS 3800.00 55.67 258.28 3129.64 3056.94 5999637.53 564131.81 1641.21 0.00 0.00 MWD+IFR+MS 3900.00 55.67 258.28 3186.03 3113.33 5999620.04 564051.11 1722.49 0.00 0.00 MWD+IFR+MS 4000.00 55.67 258.28 3242.42 3169.72 5999602.56 563970.40 1803.77 0.00 0.00 MWD+IFR+MS 4100.00 55.67 258.28 3298.81 3226.11 5999585.08 563889.70 1885.05 0.00 0.00 MWD+IFR+MS 4150.85 55.67 258.28 3327.48 3254.78 5999576.19 563848.66 1926.38 0.00 0.00 MWD+IFR+MS 4200.00 56.46 256.11 3354.92 3282.22 5999566.80 563808.99 1966.64 4.00 293.07 MWD+IFR+MS 4300.00 58.18 251.82 3408.93 3336.23 5999542.82 563728.34 2050.34 4.00 294.29 MWD+IFR+MS 4400.00 60.04 247.69 3460.28 3387.58 5999512.40 563648.14 2136.09 4.00 296.60 MWD+IFR+MS 4500.00 62.02 243.72 3508.73 3436.03 5999475.69 563568.77 2223.47 4.00 298.72 MWD+IFR+MS 4574.30 63.57 240.86 3542.70 3470.00 5999444.45 563510.56 2289.20 4.00 300.65 TUZC 4600.00 64.11 239.89 3554.03 3481.33 5999432.88 563490.61 2312.06 4.00 301.95 MWD+IFR+MS 4700.00 66.30 236.21 3595.97 3523.27 5999384.16 563414.05 2401.42 4.00 302.38 MWD+IFR+MS 4800.00 68.58 232.64 3634.35 3561.65 5999329.77 563339.46 2491.13 4.00 303.93 MWD+IFR+MS 4900.00 70.92 229.19 3668.97 3596.27 5999269.99 563267.20 2580.74 4.00 305.30 MWD+IFR+MS 5000.00 73.33 225.83 3699.67 3626.97 5999205.09 563197.63 2669.81 4.00 306.49 MWD+IFR+MS 5100.00 75.79 222.56 3726.30 3653.60 5999135.41 563131.08 2757.92 4.00 307.52 MWD+IFR+MS 5148.48 77.00 221.00 3737.70 3665.00 5999100.00 563100.00 2800.15 4.00 308.40 MPS-22 T1.1 5168.48 77.00 221.00 3742.20 3669.50 5999085.18 563087.35 2817.50 0.00 0.00 MWD+IFR+MS 5175.00 77.74 220.73 3743.63 3670.93 5999080.33 563083.22 2823.16 12.00 340.08 MWD+I FR+MS 5200.00 80.56 219.69 3748.33 3675.63 5999061.44 563067.54 2844.86 12.00 340.14 MWD+IFR+MS 5225.00 83.39 218.68 3751.82 3679.12 5999042.12 563052.08 2866.53 12.00 340.33 MWD+IFR+MS 5250.00 86.21 217.67 3754.09 3681.39 5999022.42 563036.86 2888.11 12.00 340.48 MWD+IFR+MS 5266.42 88.07 217.02 3754.91 3682.21 5999009.30 563027.03 2902.21 12.00 340.57 MWD+IFR+MS 5300.00 88.07 217.02 3756.04 3683.34 5998982.33 563007.06 2930.96 0.00 0.00 MWD+IFR+MS 5349.47 88.07 217.02 3757.70 3685.00 5998942.59 562977.65 2973.31 0.00 0.00 TUZB 5400.00 88.07 217.02 3759.40 3686.70 5998902.01 562947.60 3016.57 0.00 0.00 MWD+IFR+MS 5500.00 88.07 217.02 3762.76 3690.06 5998821.69 562888.14 3102.17 0.00 0.00 MWD+IFR+MS 5600.00 88.07 217.02 3766.12 3693.42 5998741.37 562828.68 3187.78 0.00 0.00 MWD+IFR+MS h_.~... Company: Field: Site: Well: Wellpath: Survey BP Amoco Milne Point MPt S Pad Plan MPS~22 Plan MPS-22 .--.-.-...-------.--..-,..- MD ft 5700.00 5800.00 5818.37 5850.00 5900.49 5950.00 5965.20 6000.00 6100.00 6200.00 6300.00 6400.00 6502.99 6550.00 6600.00 6650.00 6700.00 6750.00 6800.00 6850.00 6900.00 6950.00 6993.32 7000.00 7050.00 7100.00 7150.00 7200.00 7250.00 7300.00 7333.78 7400.00 7500.00 7600.00 7700.00 7800.00 7900.00 8000.00 8101.59 8200.00 8210.96 8274.96 8300.00 8400.00 8500.00 8600.00 8700.00 8800.00 8900.00 9000.00 9100.00 9200.00 9300.00 lncl deg 88.07 88.07 88.07 89.97 93.00 95.80 96.66 96.66 96.66 96.66 96.66 96.66 96.66 96.37 96.05 95.70 95.35 94.98 94.59 94.20 93.79 93.37 93.00 92.90 92.12 91.33 90.54 89.75 88.96 88.17 87.64 87.64 87.64 87.64 87.64 87.64 87.64 87.64 87.64 91.56 92.00 94.56 94.56 94.56 94.56 94.56 94.56 94.56 94.56 94.56 94.56 94.56 94.56 ....". ...........- e BP KW A Planning Report ___ ____._...__. __ ._.h_ . _.n...n._on_.. ___..___ Azim deg 217.02 217.02 217.02 217.01 217.00 216.00 215.70 215.70 215.70 215.70 215.70 215.70 215.70 218.52 221.52 224.52 227.51 230.50 233.48 236.47 239.45 242.42 245.00 245.39 248.29 251.18 254.08 256.97 259.87 262.76 264.72 264.72 264.72 264.72 264.72 264.72 264.72 264.72 264.72 264.37 264.33 264.33 264.33 264.33 264.33 264.33 264.33 264.33 264.33 264.33 264.33 264.33 264.33 TVD ft 3769.49 3772.85 3773.47 3774.01 3772.70 3768.90 3767.25 3763.22 3751.62 3740.03 3728.43 3716.83 3704.89 3699.56 3694.15 3689.03 3684.21 3679.71 3675.54 3671.71 3668.23 3665.11 3662.70 3662.36 3660.17 3658.67 3657.85 3657.72 3658.29 3659.54 3660.77 3663.50 3667.61 3671.72 3675.84 3679.95 3684.07 3688.18 3692.36 3693.04 3692.70 3689.04 3687.05 3679.10 3671.15 3663.20 3655.25 3647.30 3639.35 3631.40 3623.45 3615.50 3607.54 e r:l~æ;;~;"TIm'~~K~~~~~~~@:~"¡W~0!f¡W1 Section (VS) Reference: Well (0.00N,0.00E.248.08Azi), ._~_u._r~ey'~~lc~l~ti~n.~eth~d_:____~~~~um Curvatu~___ Db: Oracle _0"' "'. ..... n.' _.. _...___ _________."_..__.____._.___ ........ ........n .. .....N ._. .."_'" .._.._........._"..._..,._.,.______ Sys TVD ft 3696.79 3700.15 3700.77 3701.31 3700.00 3696.20 3694.55 3690.52 3678.92 3667.33 3655.73 3644.13 3632.19 3626.86 3621.45 3616.33 3611.51 3607.01 3602.84 3599.01 3595.53 3592.41 3590.00 3589.66 3587.47 3585.97 3585.15 3585.02 3585.59 3586.84 3588.07 3590.80 3594.91 3599.02 3603.14 3607.25 3611.37 3615.48 3619.66 3620.34 3620.00 3616.34 3614.35 3606.40 3598.45 3590.50 3582.55 3574.60 3566.65 3558.70 3550.75 3542.80 3534.84 MapN ft 5998661.05 5998580.73 5998565.98 5998540.56 5998500.00 5998460.07 5998447.75 5998419.50 5998338.34 5998257.18 5998176.01 5998094.85 5998011.26 5997973.77 5997935.44 5997898.78 5997863.91 5997830.92 5997799.90 5997770.94 5997744.11 5997719.49 5997700.00 5997697.15 5997677.10 5997659.38 5997644.04 5997631.12 5997620.65 5997612.67 5997608.70 5997602.03 5997591.96 5997581.89 5997571.82 5997561.75 5997551.68 5997541.62 5997531.39 5997521.17 5997520.00 5997513.13 5997510.45 5997499.73 5997489.01 5997478.29 5997467.58 5997456.86 5997446.14 5997435.42 5997424.70 5997413.99 5997403.27 MapE ft _______._____n 562769.22 562709.75 562698.83 562680.02 562650.00 562620.99 562612.25 562592.33 562535.10 562477.86 562420.62 562363.38 562304.43 562276.59 562244.96 562211.36 562175.86 562138.58 562099.60 562059.03 562017.00 561973.60 561935.00 561928.97 561883.23 561836.51 561788.94 561740.65 561691.77 561642.44 561608.92 561543.10 561443.70 561344.30 561244.91 561145.51 561046.11 560946.72 560845.74 560747.89 560737.00 560673.49 560648.67 560549.58 560450.48 560351.39 560252.29 560153.19 560054.10 559955.00 559855.91 559756.81 559657.71 VS ft 3273.39 3359.00 3374.73 3401.82 3445.04 3487.09 3499.87 3529.06 3612.93 3696.81 3780.68 3864.56 3950.94 3990.99 4034.84 4079.89 4126.01 4173.06 4220.93 4269.48 4318.58 4368.09 4411.21 4417.87 4467.81 4517.76 4567.59 4617.16 4666.34 4714.99 4747.50 4810.89 4906.62 5002.36 5098.09 5193.82 5289.56 5385.29 5482.54 5576.90 5587.41 5648.75 5672.72 5768.42 5864.12 5959.82 6055.52 6151.23 6246.93 6342.63 6438.33 6534.03 6629.74 DLS deg/100ft 0.00 0.00 0.00 6.00 6.00 6.00 6.00 0.00 0.00 0.00 0.00 0.00 0.00 TFQ deg ......_.__......_...~_._.._. 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 359.79 MWD+IFR+MS 359.79 MPS-22 T2.1 340.51 MWD+IFR+MS 340.44 MWD+IFR+MS 180.00 MWD+IFR+MS 180.00 MWD+IFR+MS 180.00 MWD+IFR+MS 180.00 MWD+IFR+MS 180.00 MWD+IFR+MS 180.00 MWD+IFR+MS 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 95.73 MWD+IFR+MS 96.05 MWD+IFR+MS 96.37 MWD+IFR+MS 96.68 MWD+IFR+MS 96.96 MWD+IFR+MS 97.23 MWD+IFR+MS 97.48 MWD+IFR+MS 97.71 MWD+IFR+MS 97.92 MWD+IFR+MS 98.10 MPS-22 T3.1 105.00 MWD+IFR+MS 105.02 MWD+IFR+MS 105.14 MWD+IFR+MS 105.23 MWD+IFR+MS 105.28 MWD+IFR+MS 105.28 MWD+IFR+MS 105.25 MWD+IFR+MS 105.18 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 4.00 4.00 4.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 MWD+IFR+MS 354.91 MWD+IFR+MS 354.91 MPS-22 T4.1 360.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0'.00 MWD+I FR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS I···························',· Company: Field: Site: Well: Wellpath: Survey MD Incl ft deg ..._.___.___._... _nO.'.. B¡;A~~~ Milne Point M Pt S Pad Plan MPS-22 Plan MPS-22 9400.00 9423.83 94.56 94.56 Azim deg 264.33 264.33 e BP KW A Planning Report e Date: 8/29/2003 Time: 12;02:25 Page: 5 Co-ordinate(NE) Reference: Well: Plan MPS-22, True North Vertical (TVD) Reference: 72.70 MPS-22 WI D-14 @ 72.7 Section (VS) Reference: Well (O.00N,0.00E,248.08Azi) Survey Calculatio~ M~th~~: .... .~.~n~~~m Curvature___.Db: --.9..ra~~~ ,. 3599.59 3526.89 5997392.55 3597.70· 3525.00 5997390.00 559558.62 6725.44 559535.00 6748.24 DLS TFO Tool deg/100ft deg ; .___._n._ ".n__"'_ .. ...... 0.00 0.00 MWD+IFR+MS 0.00 0.00 MPS-22 T5.1 '" TVD Sys TVD MapN MapE VS ft ft ft ft ft __......__... ...___....._. ....... ...h_"._.n___.____.__ .... .."_._ ......_ _..._.__.__ WHL DETAILS Næoo +N!~S +E!-W NorIhing ~g Latitude Longitude Slot Plan MPS-22 -9.32 -572.63 5999963.59 565772.53 70624'37.237N 149627'51.955W NiA COMPANY DETAILS ANTI-COLLISION SEITINGS Interpolation MetllodMD Depth Range From: 34.30 Maximum Range: 1138.95 Interval: 25.00 To: 9423.83 Reference: Plan: MPS-n wp06 BP Amoco 128 120 100 40 20 o 27 SURVEY PROGRAM Depth Fm Depth To SurveyfPlau Tool WELLPATHDETAILS From Colour ToMD PJanMPS-22 34 300 72.70MPS-22WfD-I4@ 12.70ft 300 600 600 900 ~=~D 900 1200 248.08" 0.00 0.00 34.30 1200 1500 1500 2000 2000 2500 2500 3000 3000 3500 3500 4000 4000 4500 4500 5000 5000 6000 6000 8000 8000 9000 9000 10000 0000 12000 0 15000 Se~ MD I", Azi I 1 100 3 4 5 6 1 8 9 ¡o 120 II 12 13 128 J4 15 J6 J1 J8 J9 20 l' 21 SEC110N DETAILS TVD +NJ-S +E!·W Dug TFáctI vSec Targt"! MPS~22 T!.! MPß....Z2ru MPS~22 1'3_ ¡ MPS~21 1'4. ¡ .' ~ w c f I ~ 2 ~ ." ~ !II i ~ ¡ A " f ~ t I DA1E .~ NO. .34 =~~ !~!, .25 .~~i MPS-22t21i .20 .19¡ .18 ¡~g¡ .14 .13i ='i .10 .9¡ .8 .7i --- ·.6 ¡¡ .2 . 1 I -Z-C I PLANT ~ 15'00'00· GRID MPU S-PAD Ww 13 S';:: 18 17 erer LEGEND 14 16 15 ..- . AS-BUILT CONDUCTOR EXISTING CONDUCTOR --- I I I .l SE:c - - - ¡- ----... ::--!.. 12 TI2 II SE:CT 7· . N. RIDE: TI2N. R7i"f- . . I. I I VICINITY MAP N.T.S. NOTES: 1. DATE OF SURVEY: FEBRUARY 18, 2003. 2. REFERENCE FIELD BOOK: MP03-01 PAGES 30-32. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD-27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.999904923. 6. HORIZONTAL CONTROL IS BASED ON MPU CFP MONUMENT CFP-3 AND MPU H-PAD MONUMENT H-1. 7. ELEVATIONS ARE BPX MEAN SEA LEVEL BASED ON MILNE POINT PIPELINE VERTICAL CONTROL. 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 FEBRUARY 18, 2003. LOCATED WITHIN PROTRACTED SEC. 12, T. 12 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 ELEY. OFFSETS MPS-22 Y=5,999,963.59 N= 2,237.16 70'24'37.237" 70.4103436' 38.4' 3,297' FSL X= 565,772.53 E= 6 644.03 149'27'51.955" 149.4644319' 238' FEL ~, DRAWN: Obp COTTON CHECKEQ, O'HANLEY 0"11:, 22003 ORA'MNG: MILNE POINT UNIT S-PAD FRB03 MPS 07-00 SHEn ~~o JOe N(), seA : AS-BUILT CONDUCTOR FOR _.'IION JJC ICW DlGlClRSNClLMO~ WELL MPS-22 1 Of 1 _IIIES'I' I'IIÞGD UN: 1'. 160' _ON BY QI( -.-- -. .. a STATE OF ALASKA . ALASKA ~AND GAS CONSERVATION COM . SION PERMIT TO DRILL 20 MC 25.005 / 1a. Type of work 1/ Drill o Redrill 1b. Current Well Class o Exploratory 1/ Development Oil o MUltiPI~e ORe-Entry o Stratigraphic Test o Service o Development Gas 1/ Single ne 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well Name and N.~r: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 MPS- 3. Address: 6. Proposed Depth: 12.''''d/7 P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 9820' TVD 3597' Milne Point it / Ugnu 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 380109 3297' NSL, 238' WEL, SEC. 12, T12N, R10E, UM . 8. Land Use Permit: 13'7oximate Spud Date: Top of Productive Horizon: 2892' NSL, 2606' WEL, SEC. 12, T12N, R10E, UM . Milne Point Unit September 9, 2003 Total Depth: 9. Acres in Property: )4. Distance to Nearest Property: 774' NSL, 1218'WEL, SEC. 11, T12N, R10E, UM· 2560 / 770' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Plann~ 15. Distance to Nearest Well Within Pool Surface: X-565773 . y- 5999964 . Zone-ASP4 (Height above GL): KBE = 'feet None 16. Deviated Wells: 17. Anticipated pressure ~~O MC 25.035) Kickoff Depth 400 it Maximum Hole Angle "94 0 Max. Downhole Pressu : 1637' psig. Max. Surface Pressure: 1259' psig 18. Casing Program , >. .- » $èfting~pttí QÚâhtity Of cemeht Size Top Bottom (c.f. or sacks) Hole Casina Weiaht Grade CouDlina Lenath MD TVQ./ MD TVD (includina staae data) 42" 20" 92# H-40 Weld 11 V Surface Sur;;fáce 112' 112' 260 sx Arctic Set (Approx.) 13-1/2" 10-3/4" 45.5# L-80 BTC 26~ ' S\Jrface S(¡rface 2635' 2412' 493 sx Class 'L', 261 sx Class 'G' 9-7/8" 7-5/8" 29.7# L-80 BTC 480 Surface 4801' 3752' 1271 sx Class 'G' 6-1/8" 5" x4" 15.5# x 9.5# L-80 BTC 5119' ,70Y 3549' 9820' 3597' Sand Screen Liner \ ( 1 )' / \, / 19. PRESENTWELL CON[)ITI()NSI.JM~(J'b be compléted for RédriIIÂN[)Ré~el1try Operation!3) ..""'.' Total Depth MD (ft): Total Depth TVD (ft): I Plugs ((r;rrr~: I Effective Depth MD (ft): IEffective Depth TVD (ft):1 Junk (measured): Casing Length Size r / Cement Volume MD rvD Structural {'-' Cnnrlur.tor N / Surface ll/ / IntArmArli;::¡tA íì' / Production {L{' / I inAr ^ \\\/ { IV '7 I ___ / / Perforation Depth MD (ft): }// IPerfOration Depth TVD (ft): 20. Attachments 181 Filing F~~t o BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property lat o Diverter Sketch o Seabed Report o Drilling Fluid Program 18120 MC 25.050 Requirements 21. Verbal Approval: Cofmission Representative: Date: 22. I h~reby certify that th/foregoing is true and correct to the best of my.know.l~dge5~¡u,.. Dr-¡ u~ontact Steve Campbell, 564-4401 Pnnted Name . mtk-e. -vYJ.;'II~y' Title SeBlElr @,IIII, ~¡::lIlP"""'e~.I"í A~ u;;;¡~· '1.- /I,..,..;Z// . ! Prepared By Name/Number: Sianature ;?¡ , V~ Phone 5bf--9>tl:.(þ Date ~ 2.ð(t.>1 Sondra Stewman, 564-4750 / Commission Use Only PermitToDrill .:£.. <l7IAPI Num~.: I Permit Approval I See cover letter for Number:.2D ~ / 50- D 2 - 2~/70-DO Date: other requirements Conditions of Approval: Samples Required DYes ,8J No Mud Log Required DYes [gNo Hydrogen Sulfide Measures DYes ~No Directional Survey Required ~Yes DNo Other: o R J G llilA!eNER BY ORDER OF Approved Bv: THE COMMISSION Date Form 10-401 Revised 3/2003 Submit In Duplicate e A Point MPS-22 Well Permit IWell Name: IMPS-22 Drill and Complete Plan Summary 7 1 Type of Well (service / producer / injector): I Single Lat~r~1 Producer UPPER TUZB , Surface Location: 1983' FNL, (3296' FSL), 238' FEL, (5041' FWL), SEC. 12, T12N, R10E E=565772.53" N=5999963.59 . Target Location: 2386' FNL, (2892' FSL), 2606' FEL: (2673' FWL), SEC.12, T12N, R10E TOP "TUZB" E=563407. 74 N=5999539.90 Z=3772' TVD Target Location: 4504' FNL, (774' FSL(1218' FEL,"(4060' FWL), SEC. 11 T12N, R10E BHL Well TD E=559535 N=5997390.0 Z=3597' TVD Distance to Property line 770' Distance to nearest pool NA No other producinQ/iniection wells within the UQnu ./ ./ ,..; 1 AFE Number: I 1 Rig: 1 Doyon 14 I Estimated Start Date: I Sep. 9, 2003 1 Operating days to complete: 113.3 ~ 9820 1/ I TVD: 13597 1 / 1 Max Inc: ~ I KOP: @QQJ'" I KBE: 172 U nu TUZB Sand Well Design (conventional, slimhole, etc.): Mud Program: 13-1/2" Surface Hole Mud Pro erties: Densit Funnel visc YP HTHP 8.6 - 9.0 75 - 150 25 - 60 N/A Spud - LSND Freshwater Mud H API Filtrate LG Solids 8.5 - 9.5 < 8 < 12 9-7/8" Intermediate Hole Mud Pro erties: Densit Funnel visc YP HTHP 9.0 - 9.3 75 - 150 25 - 60 N/A LSND Freshwater Mud H API Filtrate LG Solids 9.0 - 9.5 < 8 < 12 6.125-in Production Hole Mud Pro erties: KCL-CaCOs Flo-Pro Densit Funnel visc YP HTHP H API Filtrate LG Solids 8.6 - 10.0' 40 - 55 22 - 27 <10 8.0 - 8.5 4 - 6 < 8 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation 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 1 R. 1 Cement Program: e . Point MPS-22 Well Permit Wash S acer Lead Tail Temp 20-bbl water 50-bbl 10.2-lbl al AI ha S acer 364-bbl, 493-sx 10.7 Ib/gal Class L - 4.15 ft Isx cement to surface 54-bbl, 261-sx 15.8 Ib/gal Prem G - 1.15 ft Isx to of tail at 2, 135-ft MD BHST:= 55°F from SOR, BHCT 60°F estimated by Halliburton Casin Size 7-5/8 29.7-lb/ft L-80 BTC Intermediate Casin Basis 40% excess over au e hole. Lead 500-ft MD above to of U nu. Total Cement Volume: 88-bbl Wash 5-bbl water S acer Lead Temp Evaluation Program: 30-bbl 10.2-lbl al AI ha S acer AI ha I I II 59-bbl, 271-sx 15.6 Ib/gal Prem G - 1.22 ft Isx to of lead at 3771-ft MD BHST := 80°F from SOR, BHCT 70°F estimated by Halliburton 13-1/2" Section Open Hole: MWD/GR IFR/CASANDRA Gyro as required Cased Hole: N/A 9-7/8" Section Open Hole: MWD/GR/RES IFR/CASANDRA Cased Hole: N/A 6-1/8"Section Open Hole: MWD/GR/RES ABI/PWD IFR/CASANDRA / 2 · . Point MPS-22 Well Permit Formation Markers: Formation Tops MDrkb TVDrkb Pore Pressure ft ft si Base Permafrost 1896 1822 To U nu 4271 3562 1546 Middle U nu 4801 3752 1629 TUZB 4997 3772 1637 , 8.35 8.35 8.35 ./ CasinglTubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Bottom Size Tbg O.D. MD / TVDrkb M D / TVDrkb 42-in 20-in* 92# H-40 Weld 112' 0 112-ft / 112-ft 13-1/2" 1 0-3/4" 45.5# L-80 BTC 2635 0 2635' / 2412' 9-7/8" 7-5/8" 29.7# L-80 BTC 4801' 0 4801' / 3752' 6-1/8" 4-1/2" 12.7# L-80 BTC 5119' 4701' / 3549' 9820'/ 3597' NB *The 20" casing is insulated Recommended Bit Program: BHA Hole Size Depth (MD) Bit Type Nozzle/Flow rate 1 13-1/2" o - 2,635' Mill tooth 3-15 & 1-1 0 2 9-7/8" 2,635' -4801 ' Mill tooth 3-15 & 1-1 0 3 6-1/8" 4,801' - TO Security 3-12 FM2643 3 e . Point MPS-22 Well Permit Well Control: Surface Interval · The surface hole will be drilled with a diverter. Intermediate and Production Intervals · Maximum anticipated BHP: 1,637-psi @ 3,772-ft TVD - Top of TUZB-sand · Maximum surface pressure: 1,259-psi @ surface (Based on BHP and a full column of gas from TD @ 0.1-psi/ft) · Planned BOP test pressure: Diverter will be function tested. BOPs: Test annular 250-psi low and 2,500-psi high, and rams to 250-psi low and 3,500-psi high. An FIT to 11.5-lb/gal will be made on the 7-5/8" casing shoe. 59-bbl with 9.2-lb/gal mud and FIT of 11.5-lb/gal @ 10-3/4" casing shoe. 9.2-lb/gal NaCI I 6.8-lb/gal Diesel Integrity test: Kick tolerance: · · · Planned completion fluid: Drilling Hazards & Contingencies: Hydrates · Hydrates have not been seen on S pad, but has been encountered in the surface holes on other pads, especially nearby H-Pad. Hydrates generally occur just below the Permafrost (+1- 1800 ss) but may be present in shallower SV sands and also as deep as 3000 ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates. Pretreat mud with DrilTreat; Increase mud wt; Maintain cool mud « 60 deg F); Limit ROP and Reduce pump rate while drilling hydrates; Circulate connections thoroughly. See Well Program and Recommended Practices for specific information. · Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation · We do not expect losses while drilling this well. · Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Below is a list of the wells and the lost circulating problems associated with them. H-06 (1995): Lost 100 bbls running 9-5/8" casing, good returns during cementing except no returns for last 20 bbls, contaminated cement to surface, cement 12 ft down, no top job. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up'to recommended circulating rate slowly prior to cementing. Expected Pressures · It is unlikely there will be unexpected overpressure when d~ng to the Schrader Bluff formation. Reservoir pressure is expected to be (8.35 Ib/gal EMW). 4 e . Point MPS-22 Well Permit Pad Data Sheet · Please read the S-Pad Data Sheet thoroughly. Breathing · N/A Hydrocarbons · Hydrocarbons will be encountered in the NA through the Schrader Bluff. Faults Hydrogen Sulfide · MPS Pad is not designated as an H2S Pad. Anti-collision Issues 5 e a Point MPS-22 Well Permit DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. Install 20-in insulated conductor. Procedure 1. MIRU. NU diverter on 20-in conductor and function test. 2. Drill 13-1/2" surface hole as per directional plan. 3. Case and cement 1 0-3/4" surface casing. 4. ND diverter, NU BOPE and test. 5. Perform FIT. 6. Drill 9-7/8" hole to land in top of the NB-sand as per directional plan. 7. Case and cement 7-5/8" intermediate casing. Freeze protect 7-5/8" x 10-3/4" annulus. 8. Drill out shoe and 20-ft new formation and perform FIT. 9. Drill 6-1/8" NB-sand lateral as per directional plan. 10. Run 5" uncemented sand screens and hang off 100-ft inside 7-5/8" casing. 11. Displace drilling mud to brine. 12. Run 4-1/2" jet pump completion as per schematic. 13. Land tubing hanger and test. 14. Set BPV. 15. ND BOP. 16. Install and test tree. 17. Pull BPV. 18. Test 7-5/8" x 4-1/2" annulus. 19. Freeze protect thru GLM. 20. Install BPV and secure well. 21. RD/MO. 6 KB ELEV =72.0' Cellar Box ELEV = 38.1 e 1,965' TVD 42" Hole Gas Lift Mandrel @ 2,200' MD; -80, IBT-M Coupling OD: 5.2' 13-1/2" hole TREE: Cameron 4-1116" 5M WELLHEAD: FMC Gen 6 11".5M Tubing Head: 11" x 4-1/2" FMC Tubing Hanger / ~ - Diesel Fr .. / 500' MD eeze protect to/ I 112' I 1 -1/2" X 20" 92 Ibltt, H-40 Welded Insulated si 10-3/4"@ 2,635' MD, 2,412' TVDrkb wire down 1- D, W/BIW ~ BIW 1- Wire Phoenix Pressure Gauge (3.850" to lower sensor) D) Set @ 4,600' MD D No Go W/RHC ball & rod Phoenix Pressure Gauge (2.840' 7-5/8" x 4-1/2" Premier Packer HES 'XN' nipple 2.750" Wire line Entry Guide 3-1/2' / 10-3/4" 45.5#, L-80, BTC-M Casing Drift: 9.875 Casing 10: 9.950 Coupling 00: 11.75 Burst: 5,210 psi Collapse: 2,480 psi 9.7-lb/gal KCI with corrosion inhibitor as packer fluid Jet Pump Installed in Sliding Sleeve Post rig. BTC-M 7-5/8" 29.7#, L-80, Casing Drift: 6.75 Casing 10: 6.875 Coupling 00: 11.75 Burst: 6,890 psi Collapse: 4,790 p si hanger 5" Sand Screen Liner W/Baker HR-ZXP liner 9-7/8" Hole --- - - - - - - ~ 7.625" Casing Shoe @ 4,801' MD; 3,772' TVD Well Inclination @ Shoe = 77 Degrees -------- ~rizontal A-""" J. 9,820' MD/3,597' TVD API NO: 6-1/8" hole SP COMMENTS REV. BY DATE .34 .33 .32 .31i .30 .29i I~~ .25 .24i 123 MPS-22 21i .20 .19i .18 I~~ .15i .14 .13i IVi .10 .9i .8 .7i ----- -. 6 Ii .2 . 1 I -Z-c I PLANT ---l15'OO'oon GRID MPU S-PAD Ww 13 ~:: 18 17 "'''' LEGEND 16 15 14 ... . AS-BUILT CONDUCTOR EXISTING CONDUCTOR VICINITY MAP N.T.S. ----- I I I _l StCT - - - ¡- ____ ~ 12 TI2N I I tCl?-' _,RIOt 112N, R/'ìf- _ _ I. I I NOTES: 1. DATE OF SURVEY: FEBRUARY 18, 2003. 2. REFERENCE FIELD BOOK: MP03-01 PAGES 30-32. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD-27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.999904923. 6. HORIZONTAL CONTROL IS BASED ON MPU CFP MONUMENT CFP-3 AND MPU H-PAD MONUMENT H-1. 7. ELEVATIONS ARE BPX MEAN SEA LEVEL BASED ON MILNE POINT PIPELINE VERTICAL CONTROL. 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 FEBRUARY 18, 2003. LOCATED WITHIN PROTRACTED SEC. 12, T. 12 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 MPS-22 Y=5,999,963.59 . N= 2,237.16 70'24'37.237" 70.4103436' 38.4' 3,297' FSL X= 565,772.53' E= 6,644.03 149'27'51.955" 149.4644319' 238' FEL ,/ ~~, DRAWN: Obp COTTON CHECKED, O'HANLEY DATE: 2 20 03 DRAWING: MILNE POINT UNIT S-PAD SHEET: FRB03 MPS 07-00 ~ ffi~~[I][~o JOB NO: SCALE: AS-BUILT CONDUCTOR D 2 20 0 ISSUED FDR INFDRMATlDN JJC KW ENGlNEERSA.NDlANOstJR'o£I'CRS WELL MPS-22 1 OF 1 SOII'I£ST FlRE'fÆED LANE ,"= '60' NO. DATE RElllSlDN BY CHK ANQ-IORAŒ, AlASKA 99503 õ 0- o 16 0 " ~ :5 ~ ..c: ! 'õi ... 'f .. > 24 vv 2 f- 320 40vv V J!.~,,- ^~'-., ~~ ~ ~~~--~--- ~'--t:: "StartDirI.5/loo':4oo'MD,400'TVD #' #' =-- ~ ...- StartDir3/100':533.33'MD,533.31'TVD #' , 0 '~ '##c:. ~~~~ .# #" COMPANY UETAIlS HPAID.:Io.'o Cllcu\atiooM~thod; Minim\lmC~ =:le: ~~w¿~~.œ Nonh Error Surfaœ: EJlipûcal + Casing Wlmm Metbod: Rules BaSc!d A ° 00\\ \6° RF.FERENC'E [NfORMA TION Co..{!rdilV'~ ..." "r" ,~~" . '.".'; . .... Veftic¡ \, "'.."..... .......... Seel \ .1,.". ... ~". . .... . M.:asun. II' I' .-~.' . '.~ ~I.' IV ".' 11"I Start Dir 2/100': 1475.86' MD, 1450'TVD 4° EndDir : 1837.2'MD, 1772'TVD Start Dir41IOO': 1953.29' MD, 1872'TVD :t EndDir :2159.15'MD,2041.23'TVD I I 00 ! I , , I I ! o ff Start Dir4/IOO': 3190.58' MD, 2845.55'TVD EndDir : 4801.75'MD, 3752.7'TVD I, Start Dir 10/100': 4821.75' MD, 3757.2'TVD 'I End Dir : 4946.83' MD, 3772.09' TVD ..j; .i .g '" T Z - 7 /8 '. . I.. SURVEY PROGRAM fÀ.'J!Ch Fm Depth To SUf\'I..')'lPlan )430 12~O.OO Planood: MpS·22 .....ros V28 125U.00 9820,75 Planned: MPS·22.....tm V28 Plan: MPS~22 wpOS {Plan Mps·22/Plan MPS-22J Tool Date: 8171200:\ £. 'CI..'ated By: Ken Allen Ch~ked . CB..QYRO-SS MWD+IFR"'MS Date Reviewed; Date: WELl. DEI AilS ...... I-N¡-S ~F.J-W Northing: F.uling utitude Longitude Slot Plan MPS·22 ..932 ·572.6] 5999963.59 56517253 70"24'37137N 149"27'51.955W ""A TARGET DETAILS N.... ND ~N..'.S +E¡-W ~'f1hìnø: Easting Share MPS-22 15 3~97.70 -2~18.80 -62605~ ~997J9O.00 ~~9~3~.OO Point MPS-22 T3 3667.70 -2229.92 -3857.68 5997700.00 ~6193~.OO PoiDt MPS-22 T4 3682.70 -239938 -505733 5997520.00 ~60737.00 Point MPS-22T1 3752.70 -253.86 ·2245.07 599%90.00 ~63~30.00 Point MPS·22 Poly 3752.70 -102.48 -2398.75 5999840.00 563375.00 Polygon MPS-22 T2 3782.70 -1043.3~ -2882.10 5998895.00 562900.00 Point SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 2 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 3 533.33 2.00 180.00 533.31 -2.33 0.00 1.50 180.00 0.87 4 710.50 7.00 207.90 709.89 -14.97 -5.06 3.00 38.00 10.28 5 1151.28 15.00 270.00 1143.43 -38.81 -74.98 3.00 89.37 84.04 6 1475.86 23.30 285.96 1450.00 -21.12 -178.94 3.00 40.00 173.89 7 1837.20 30.52 285.96 1772.00 23.80 -336.07 2.00 0.00 302.90 8 1953.29 30.52 285.96 1872.00 40.01 -392.76 0.00 0.00 349.44 9 2159.15 38.76 286.19 2041.23 72.41 -505.09 4.00 1.03 441.5 6 10 3190.58 38.76 286.19 2845.55 252.46 -1125.16 0.00 0.00 949.61 II 4801.75 77.00 221.00 3752.70 -253.86 -2245.07 4.00 -78.62 2177.57 MPS-22 TI 12 4821.75 77.00 221.00 3757.20 -268.56 -2257.85 0.00 0.00 2194.92 13 4946.83 89.30 218.72 3772.09 -363.72 -2337.26 10.00 ·10.59 2304.11 14 5817.95 89.30 218.72 3782.70 -1043.35 -2882.10 0.00 0.00 3063.25 MPS-22 T2 15 5987.93 95.09 210.31 3776.18 -1183.11 -2978.24 6.00 -55.33 3204.60 16 6716.85 95.09 210.31 3711.51 -1809.90 -3344.67 0.00 0.00 3778.50 17 7395.51 92.00 251.00 3667.70 -2229.92 -3857.68 6.00 92.85 4411.21 MPS-22 T3 18 7600.77 89.03 262.95 3665.86 -2276.08 -4057.27 6.00 103.87 4613.60 19 8572.78 89.03 262.95 3682.40 -2395.32 -5021.80 0.00 0.00 5552.93 20 8608.55 90.00 264.00 3682.70 -2399.38 -5057.33 4.00 47.05 5587.41 MPS-22 14 21 8714.01 94.20 264.35 3678.83 -2410.08 -5162.15 4.00 4.71 5688.65 22 9820.75 94.20 264.35 3597.70 -2518.80 -6260.55 0.00 0.00 6748.24 MPS-22 T5 FORMATION TOP DETAILS No. TVDPath MDPath Fonnation I 1822.70 1896.06 BPRF 2 3562.70 4271.51 TUZC 3 3752.70 4801.75 TUlC-1 4 3772.70 4997.02 TUZB CASING DETAILS All TVD depths are No. TVD MD Name Size 1 2412.70 2635.51 103/4" 10.750 ssTVD plus 72. 70'for RKBE. 2 3752.70 4801.75 75/8" 7.625 3 3597.70 9820.74 5 screens" 5.000 End Dir : 7600.77' MD, 3665.86' TVD i Total Depth: 9820.75' MD, 3597.7' TVD v MPS-22 wp05 ! I lanD, 41 '. 2 "" I 0 ;~re ns' 4rvb I i , ! , I - , , ,1- 5600 6400 7200 800 1600 2400 3200 4000 Vertical Section at 248.08° [800ft/in] 4800 BPArtIl'll.;('I REfERENCE INFORMA llON ("Oo1.Jl'dinalt: (NÆ Reference; Wen CØItre; Plan Mf'S..22. TI"* North Vertical ((WI Refenn:e; 72.10 Mps-22 WI D-14@: 72.70 So;lìon (VS) Relèrence; Slot· (O.OON,O.OOE) M~D:pthRerereoce: 72.70Mps·nW!D-14l'íJ 72.10 Ca1culalion MeIhod: Minimum CUI'V8tun: SURVEY PROGRAM Depth ¡':m Del1h To Surwy/PIan 34.30 1250.uO Planned: MPS.22 wpœ; V28 1250.£10 9820.7~ rlanned: MPS-22 \\~ V28 Plan: MPS·22 wpOS (plan MPS-12/Plan MPS-22) bp o COMPANY OfTAII.s Calculation Method: Minim.un eur...1U/'e :':r: ~~ ~~1{~~~nœrNl1rth Error Sudàce: Elliptical" Casing Waminu: Method: Rules ~ Tool CB-GYRO·SS MWD~IFR+MS ('realed lJy: KL'Il Alh.'I1 Dale: K/1!100~ Chcded' Datc' Reviewed: Date' . WELL DETAILS /0.- //~~ / /V~ 0.-,~ ~~ ~/ / /~~~ ~~ 0.-Ì'---- ø / /y/~~~ ~~ ~~ ~ l /~~í:::/"~~;;;~);Y:::::: -I ~~ / ~~ ~)( ~~ ~ ¡PlY ~~ ~~Ì'---- I ~-<- ~ ~ I " ~ ~ # '-- ------ -: - -- -- -- - ~ eVoo #' #' /000 #.&> 0 ;V # '/000 ,'" ^'- 'V ~Oo ~ Vo #~ If """ ~Ni....':; '-f/.W N\'fthing Fastin¡l. lalirude Longin>œ Sk't PlanMPS-22 .932 -~72.63 :"99996359 ~M772."'3 70"24'37131N 149°27·~1.9"''''W N'A TARGET [)flAILS ""'" ND 'Ni-S -boW Northing [:asting Shar<: MPS-22T5 3:"97.70 -2"'18.80 ~260."'5 5997390.00 ......9...3:".00 Point MPS-22 T3 3667.70 -2229.92 -3857.68 "'997700.00 561935.00 Point MPS-221'4 3682.70 -2399.38 ·...057.33 "'997"'20.00 560737.00 Point MPS-22 TI 3752.70 ·253.86 ·2245.07 "'999690.00 %3"'30.00 Point MPS-22 Polv 3752.70 -102_48 ·2398.7:' 5999840.00 563375_00 Púl)'@.on Mps·22 T2' 3182.70 -104J.J5 ·2882.10 59988'.15.00 562900.00 Point SECTION DETAILS Sec MD Inc AzI TVD +N/-S +E/-W DLeg TFace VSec I 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 2 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 3 533.33 2.00 180.00 533.31 -2.33 0.00 1.50 180.00 0.87 4 710.50 7.00 207.90 709.89 -14.97 -5.06 3.00 38.00 10.28 5 1151.28 15.00 270.00 1143.43 -38.81 -74.98 3.00 89.37 84.04 6 1475.86 23.30 285.96 1450.00 -21.12 -178.94 3.00 40.00 173.89 7 1837.20 30.52 285.96 1772.00 23.80 -336.07 2.00 0.00 302.90 8 1953.29 30.52 285.96 1872.00 40.01 -392.76 0.00 0.00 349.44 9 2159.15 38.76 286.19 2041.23 72.41 -505.09 4.00 1.03 441.56 10 3190.58 38.76 286.19 2845.55 252.46 -1125.16 0.00 0.00 949.61 II 480 I. 75 77.00 221.00 3752.70 -253.86 -2245.07 4.00 -78.62 2177.57 12 4821.75 77.00 221.00 3757.20 -268.56 -2257.85 0.00 0.00 2194.92 13 4946.83 89.30 218.72 3772.09 -363.72 -2337.26 10.00 -10.59 2304.11 14 5817.95 89.30 218.72 3782.70 -1043.35 -2882.10 0.00 0.00 3063.25 15 5987.93 95.09 210.31 3776.18 -1183.11 -2978.24 6.00 -55.33 3204.60 16 6716.85 95.09 210.31 3711.51 -1809.90 -3344.67 0.00 0.00 3778.50 17 7395.51 92.00 251.00 3667.70 -2229.92 -3857.68 6.00 92.85 4411.21 18 7600.77 89.03 262.95 3665.86 -2276.08 -4057.27 6.00 103.87 4613.60 19 8572.78 89.03 262.95 3682.40 -2395.32 -5021.80 0.00 0.00 5552.93 20 8608.55 90.00 264.00 3682.70 -2399.38 -5057.33 4.00 47.05 5587.41 21 8714.01 94.20 264.35 3678.83 -2410.08 -5162.15 4.00 4.71 5688.65 22 9820.75 94.20 264.35 3597.70 -2518.80 -6260.55 0.00 0.00 6748.24 Target MPS-22 Tl MPS-22 T2 MPS-22 T3 MPS-22 T4 MPS-22 T5 End Dir : 1837.2' MD, 1772' TVD Start Dir4/100': 1953.29' MD. 1872'TVD ~ End Dir : 2159.15' MD, 2041.23' TVD Start Dir 4/1 00' : 3190.58' MD, 2845.55'TVD r--' '\ Start Dir 2/100' : 1475.86' MD, 1450'TVD Start Dir 3/100' : 533.33' MD, 533.31'TVD // Start Dir 1.5/100' : 400' MD, 400'TVD I v 5 0 " <no All TVD depths are ssTVD plus 72. 70'for RKBE. =- ~ 8 ~ / n If: S r 01 0 ' : 4 I 7' D 3 5 .2 T D +' ;;;: 1:: ~ -120v ;;;: ;; o f/) -6000 -4800 -3600 -2400 West(-)lEast(+) [I 200ft/in] ·1200 o FORMATION TOP DETAILS No. TVDPath MDPath Fonnation 1 1822.70 1896.06 BPRF 2 3562.70 4271.51 TUZC 3 3752.70 480 I. 75 TUZC-I 4 3772. 70 4997.02 TUZB CASING DETAILS ND. TVD MD Name Size 12100 1 2412.70 2635.51 103/4" 10.750 2 3752.70 4801.75 7 5/8" 7.625 3 3597.70 9820.74 5 screens" 5.000 r : " -24 S r II 52.8'M 62'V It BP KW A Planning Report e Company: BP Amoco Date: 8/7/2003 Time: 10:45:26 Page: 1 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-22. True North Site: M PI S Pad Vertical (fVD) Reference: 72.70 MPS-22 WI D-14 @ 72.7 Well: Plan MPS-22 Section (VS) Reference: Well (0.ooN,O.00E.248.08Azi) Wellpath: Plan MPS-22 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2003 Site: M Pt S Pad Site Position: Northing: 5999978.00 ft Latitude: 70 24 37.329 N From: Map Easting: 566345.00 ft Longitude: 149 27 35.171 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.51 deg Well: Plan MPS-22 Slot Name: Well Position: +N/-S -9.32 ft Northing: 5999963.59 ft Latitude: 70 24 37.237 N +E/-W -572.63 ft Easting : 565772.53 ft Longitude: 149 27 51.955 W Position Uncertainty: 0.00 ft Wellpath: Plan MPS-22 Drilled From: Well Ref. Point Tie-on Depth: 34.30 ft Current Datum: 72.70 MPS-22 WI D-14 @ Height 72.70 ft Above System Datum: Mean Sea Level Magnetic Data: 11/1/2002 Declination: 25.70 deg Field Strength: 57504 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.30 0.00 0.00 248.08 Plan: MPS-22 wp05 Date Composed: 8/6/2003 Version: 28 Principal: Yes Tied-to: From Well Ref. Point Casing Points MD TVD Diameter Hole Size Name ft ft in in 2635.51 2412.70 10.750 12.250 103/4" 4801.75 3752.70 7.625 9.875 7 5/8" 9820.74 3597.70 5.000 6.125 5 screens" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 1896.06 1822.70 BPRF 0.00 0.00 4271.51 3562.70 TUZC 0.00 0.00 4801.75 3752.70 TUZC-1 0.00 0.00 4997.02 3772.70 TUZB 0.00 0.00 Targets Map Map <-- Latitude --> <- Longitude -> Name Deseription TVD +N/-S +EI-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft MPS-22 T5 3597.70 -2518.80 -6260.55 5997390.00 559535.00 70 24 12.439 N 149 30 55.393 W MPS-22 T3 3667.70 -2229.92 -3857.68 5997700.00 561935.00 70 24 15.296 N 149 29 44.992 W MPS-22 T 4 3682.70 -2399.38 -5057.33 5997520.00 560737.00 70 24 13.622 N 149 3020.141 W MPS-22 T1 3752.70 -253.86 -2245.07 5999690.00 563530.00 70 24 34.737 N 149 28 57.757 W MPS-22 Poly 3752.70 -102.48 -2398.75 5999840.00 563375.00 70 24 36.225 N 149 29 2.263 W ·Polygon 1 3752.70 -102.48 -2398.75 5999840.00 563375.00 70 24 36.225 N 149 29 2.263 W -Polygon 2 3752.70 -385.63 -2046.20 5999560.00 563730.00 70 24 33.441 N 149 2851.927 W e BP KW A Planning Report e Company: BP Amoco Date: 8/7/2003 Time: 10:45:26 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-22, True North Site: M Pt S Pad Vertical (fVD) Reference: 72.70 MPS-22 WI D-14 @ 72.7 Well: Plan MPS-22 Section (VS) Reference: Well (0.OON,0.OOE.248.08Azi) Wellpath: Plan MPS-22 Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <- Latitude --> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min See Dip. Dir. ft ft ft ft ft -Polygon 3 3752.70 -2421.21 -3714.35 5997510.00 562080.00 70 24 13.415 N 149 29 40.789 W -Polygon 4 3752.70 -2678.77 -6266.96 5997230.00 559530.00 70 24 10.866 N 149 30 55.577 W -Polygon 5 3752.70 -2358.75 -6264.14 5997550.00 559530.00 70 24 14.013 N 149 3055.502 W -Polygon 6 3752.70 -2138.11 -4061.90 5997790.00 561730.00 70 24 16.198 N 149 29 50.977 W MPS-22 T2 3782.70 -1043.35 -2882.10 5998895.00 562900.00 70 24 26.970 N 149 29 16.419 W Plan Section Information MD Inel Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/1000 deg/100ft deg/1000 deg 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 533.33 2.00 180.00 533.31 -2.33 0.00 1.50 1.50 0.00 180.00 710.50 7.00 207.90 709.89 -14.97 -5.06 3.00 2.82 15.75 38.00 1151.28 15.00 270.00 1143.43 -38.81 -74.98 3.00 1.82 14.09 89.37 1475.86 23.30 285.96 1450.00 -21.12 -178.94 3.00 2.56 4.92 40.00 1837.20 30.52 285.96 1772.00 23.80 -336.07 2.00 2.00 0.00 0.00 1953.29 30.52 285.96 1872.00 40.01 -392.76 0.00 0.00 0.00 0.00 2159.15 38.76 286.19 2041.23 72.41 -505.09 4.00 4.00 0.11 1.03 3190.58 38.76 286.19 2845.55 252.46 -1125.16 0.00 0.00 0.00 0.00 4801.75 77.00 221.00 3752.70 -253.86 -2245.07 4.00 2.37 -4.05 -78.62 MPS-22 T1 4821.75 77.00 221.00 3757.20 -268.56 -2257.85 0.00 0.00 0.00 0.00 4946.83 89.30 218.72 3772.09 -363.72 -2337.26 10.00 9.84 -1.82 -10.59 5817.95 89.30 218.72 3782.70 -1043.35 -2882.10 0.00 0.00 0.00 0.00 MPS-22 T2 5987.93 95.09 210.31 3776.18 -1183.11 -2978.24 6.00 3.41 -4.95 -55.33 6716.85 95.09 210.31 3711.51 -1809.90 -3344.67 0.00 0.00 0.00 0.00 7395.51 92.00 251.00 3667.70 -2229.92 -3857.68 6.00 -0.46 6.00 92.85 MPS-22 T3 7600.77 89.03 262.95 3665.86 -2276.08 -4057.27 6.00 -1.45 5.82 103.87 8572.78 89.03 262.95 3682.40 -2395.32 -5021.80 0.00 0.00 0.00 0.00 8608.55 90.00 264.00 3682.70 -2399.38 -5057.33 4.00 2.73 2.93 47.05 MPS-22 T4 8714.01 94.20 264.35 3678.83 -2410.08 -5162.15 4.00 3.99 0.33 4.71 9820.75 94.20 264.35 3597.70 -2518.80 -6260.55 0.00 0.00 0.00 0.00 MPS-22 T5 Survey MD Inel .uim TVD Sys TVD MapN MapE VS DLS TFO Too ft deg deg ft ft ft ft ft deg/100ft deg 34.30 0.00 0.00 34.30 -38.40 5999963.59 565772.53 0.00 0.00 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 27.30 5999963.59 565772.53 0.00 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 127.30 5999963.59 565772.53 0.00 0.00 0.00 CB-GYRO-SS 300.00 0.00 0.00 300.00 227.30 5999963.59 565772.53 0.00 0.00 0.00 CB-GYRO-SS 400.00 0.00 / 0.00 400.00 327.30 5999963.59 565772.53 0.00 0.00 0.00 CB-GYRO-SS 500.00 1.50 180.00 499.99 427.29 5999962.28 565772.54 0.49 1.50 0.00 CB-GYRO-SS 533.33 2.00 180.00 533.31 460.61 5999961.26 565772.55 0.87 1.50 0.00 CB-GYRO-SS 600.00 3.78 199.01 599.89 527.19 5999958.02 565771.86 2.74 3.00 38.00 CB-GYRO-SS 700.00 6.69 207.43 699.46 626.76 5999949.69 565768.18 9.32 3.00 19.01 CB-GYRO-SS 710.50 7.00 207.90 709.89 637.19 5999948.58 565767.61 10.28 3.00 10.63 CB-GYRO-SS 800.00 7.52 228.87 798.68 725.98 5999939.85 565760.72 19.98 3.00 89.37 CB-GYRO-SS 900.00 9.06 246.90 897.65 824.95 5999932.34 565748.61 34.03 3.00 68.57 CB-GYRO-SS 1000.00 11.20 258.94 996.10 923.40 5999927.24 565731.89 51.44 3.00 50.73 CB-GYRO-SS 1100.00 13.66 266.93 1093.76 1021.06 5999924.56 565710.59 72.16 3.00 38.87 CB-GYRO-SS 1151.28 15.00 270.00 1143.43 1070.73 5999924.13 565697.91 84.04 3.00 31.06 CB-GYRO-SS 1200.00 16.15 273.38 1190.37 1117.67 5999924.41 565684.84 96.02 3.00 40.00 CB-GYRO-SS 1300.00 18.63 279.00 1285.80 1213.10 5999927.47 565655.14 122.30 3.00 36.74 MWD+IFR+MS 1400.00 21.25 283.31 1379.80 1307.10 5999933.85 565621.67 150.82 3.00 31.38 MWD+IFR+MS 1475.86 23.30 285.96 1450.00 1377.30 5999940.90 565593.80 173.89 3.00 27.32 MWD+IFR+MS 1500.00 23.78 285.96 1472.13 1399.43 5999943.46 565584.51 181.50 2.00 0.00 MWD+IFR+MS e BP KW A Planning Report e Company: BP Amoco Date: 8f712003 Time: 10:45:26 Page: 3 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-22, True North Site: M Pt S Pad Vertical (fVD) Reference: 72.70 MPS-22 WI D-14 @ 72.7 Well: Plan MPS-22 Section (VS) Reference: Well (O.OON,0.00E,248.08Azi) Well path: Plan MPS-22 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Too ft deg deg ft ft ft ft ft deg/1000 deg 1600.00 25.78 285.96 1562.92 1490.22 5999954.63 565544.12 214.58 2.00 0.00 MWD+IFR+MS 1700.00 27.78 285.96 1652.19 1579.49 5999966.63 565500.70 250.15 2.00 0.00 MWD+IFR+MS 1800.00 29.78 285.96 1739.83 1667.13 5999979.45 565454.30 288.15 2.00 0.00 MWD+IFR+MS 1837.20 30.52 285.96 1772.00 1699.30 5999984.43 565436.30 302.90 2.00 0.00 MWD+IFR+MS 1896.06 30.52 285.96 1822.70 1750.00 5999992.40 565407.49 326.49 0.00 0.00 BPRF 1900.00 30.52 285.96 1826.10 1753.40 5999992.93 565405.56 328.07 0.00 0.00 MWD+IFR+MS 1953.29 30.52 285.96 1872.00 1799.30 6000000.14 565379.47 349.44 0.00 0.00 MWD+IFR+MS 2000.00 32.39 286.02 1911.85 1839.15 6000006.65 565355.99 368.67 4.00 1.03 MWD+IFR+MS 2100.00 36.39 286.13 1994.35 1921.65 6000021.81 565301.59 413.17 4.00 0.98 MWD+IFR+MS 2159.15 38.76 286.19 2041.23 1968.53 6000031.54 565266.87 441.56 4.00 0.88 MWD+IFR+MS 2200.00 38.76 286.19 2073.08 2000.38 6000038.45 565242.25 461.68 0.00 0.00 MWD+IFR+MS 2300.00 38.76 286.19 2151.06 2078.36 6000055.38 565181.99 510.94 0.00 0.00 MWD+IFR+MS 2400.00 38.76 286.19 2229.05 2156.35 6000072.30 565121.72 560.20 0.00 0.00 MWD+IFR+MS 2500.00 38.76 286.19 2307.03 2234.33 6000089.23 565061.46 609.46 0.00 0.00 MWD+IFR+MS 2600.00 38.76 286.19 2385.01 2312.31 6000106.15 565001.20 658.71 0.00 0.00 MWD+IFR+MS 2700.00 38.76 286.19 2462.99 2390.29 6000123.08 564940.94 707.97 0.00 0.00 MWD+IFR+MS 2800.00 38.76 286.19 2540.97 2468.27 6000140.00 564880.67 757.23 0.00 0.00 MWD+IFR+MS 2900.00 38.76 286.19 2618.95 2546.25 6000156.93 564820.41 806.48 0.00 0.00 MWD+IFR+MS 3000.00 38.76 286.19 2696.94 2624.24 6000173.85 564760.15 855.74 0.00 0.00 MWD+IFR+MS 3100.00 38.76 286.19 2774.92 2702.22 6000190.78 564699.88 905.00 0.00 0.00 MWD+IFR+MS 3190.58 38.76 286.19 2845.55 2772.85 6000206.11 564645.30 949.61 0.00 0.00 MWD+IFR+MS 3200.00 38.83 285.60 2852.90 2780.20 6000207.68 564639.61 954.28 4.00 281.38 MWD+IFR+MS 3300.00 39.81 279.48 2930.28 2857.58 6000220.84 564577.69 1006.49 4.00 281.84 MWD+IFR+MS 3400.00 41.11 273.65 3006.39 2933.69 6000227.64 564513.23 1063.50 4.00 286.57 MWD+IFR+MS 3500.00 42.67 268.13 3080.86 3008.16 6000228.04 564446.52 1125.02 4.00 291.02 MWD+IFR+MS 3600.00 44.49 262.96 3153.32 3080.62 6000222.03 564377.90 1190.74 4.00 295.12 MWD+IFR+MS 3700.00 46.53 258.13 3223.42 3150.72 6000209.66 564307.70 1260.37 4.00 298.87 MWD+IFR+MS 3800.00 48.75 253.63 3290.81 3218.11 6000190.97 564236.26 1333.54 4.00 302.26 MWD+IFR+MS 3900.00 51.14 249.44 3355.17 3282.47 6000166.05 564163.93 1409.91 4.00 305.29 MWD+IFR+MS 4000.00 53.67 245.53 3416.19 3343.49 6000135.04 564091.06 1489.11 4.00 307.99 MWD+IFR+MS 4100.00 56.32 241.87 3473.57 3400.87 6000098.08 564018.01 1570.74 4.00 310.38 MWD+IFR+MS 4200.00 59.07 238.43 3527.02 3454.32 6000055.35 563945.13 1654.42 4.00 312.48 MWD+IFR+MS 4271.51 61.09 236.09 3562.70 3490.00 6000021.37 563893.32 1715.28 4.00 314.32 TUZC' 4300.00 61.90 235.18 3576.30 3503.60 6000007.06 563872. 78 1739.72 4.00 315.48 MWD+IFR+MS 4400.00 64.81 232.11 3621.15 3548.45 5999953.44 563801.32 1826.25 4.00 315.92 MWD+IFR+MS 4500.00 67.78 229.18 3661.36 3588.66 5999894.76 563731.07 1913.57 4.00 317.30 MWD+IFR+MS 4600.00 70.79 226.37 3696.73 3624.03 5999831.29 563662.40 2001.26 4.00 318.47 MWD+IFR+MS 4700.00 73.85 223.67 3727.10 3654.40 5999763.36 563595.64 2088.90 4.00 319.47 MWD+IFR+MS 4801.75 77.00 221.00 3752.70 3680.00 5999690.00 563530.00 2177.57 4.00 320.29 MPS-22 T1 4821.75 77.00 221.00 3757.20 3684.50 5999675.18 563517.35 2194.92 0.00 0.00 MWD+IFR+MS 4850.00 79.78 220.47 3762.89 3690.19 5999654.06 563499.48 2219.50 10.00 349.41 MWD+IFR+MS 4900.00 84.70 219.56 3769.64 3696.94 5999615.85 563467.97 2263.20 10.00 349.51 MWD+IFR+MS 4946.83 89.30 218.72 3772.09 3699.39 5999579.33 563438.79 2304.11 10.00 349.64 MWD+IFR+MS 4997.02 89.30 218.72 3772.70 3700.00 5999539.90 563407.74 2347.85 0.00 0.00 TUZB ./ 5000.00 89.30 218.72 3772.74 3700.04 5999537.56 563405.90 2350.44 0.00 0.00 MWD+IFR+MS 5100.00 89.30 218.72 3773.95 3701.25 5999459.01 563344.05 2437.59 0.00 0.00 MWD+IFR+MS 5200.00 89.30 218.72 3775.17 3702.47 5999380.45 563282.20 2524.73 0.00 0.00 MWD+IFR+MS 5300.00 89.30 218.72 3776.39 3703.69 5999301.89 563220.35 2611.88 0.00 0.00 MWD+IFR+MS 5400.00 89.30 218.72 3777.61 3704.91 5999223.33 563158.50 2699.02 0.00 0.00 MWD+IFR+MS 5500.00 89.30 218.72 3778.83 3706.13 5999144.78 563096.65 2786.17 0.00 0.00 MWD+IFR+MS 5600.00 89.30 218.72 3780.05 3707.35 5999066.22 563034.80 2873.31 0.00 0.00 MWD+IFR+MS 5700.00 89.30 218.72 3781.26 3708.56 5998987.66 562972.95 2960.46 0.00 0.00 MWD+IFR+MS 5800.00 89.30 218.72 3782.48 3709.78 5998909.10 562911.10 3047.60 0.00 0.00 MWD+IFR+MS e BP KW A Planning Report e Company: BP Amoco Date: 81712003 Time: 10:45:26 Page: 4 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-22. True North Site: M PIS Pad Vertical (fVD) Reference: 72.70 MPS-22 WI D-14 @ 72.7 Well: Plan MPS-22 Section (VS) Reference: Well (0.ooN,0.00E,248.08Azi) WeUpath: Plan MPS-22 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Too ft deg deg ft ft ft ft ft deg/100ft deg 5817.95 89.30 218.72 3782.70 3710.00 5998895.00 562900.00 3063.25 0.00 0.00 MPS-22 T2 5850.00 90.40 217.14 3782.78 3710.08 5998869.55 562880.53 3090.95 6.00 304.67 MWD+IFR+MS 5900.00 92.10 214.67 3781.69 3708.99 5998828.81 562851.58 3133.26 6.00 304.67 MWD+IFR+MS 5950.00 93.80 212.19 3779.12 3706.42 5998786.91 562824.44 3174.33 6.00 304.62 MWD+IFR+MS 5987.93 95.09 210.31 3776.18 3703.48 5998754.42 562805.11 3204.60 6.00 304.49 MWD+IFR+MS 6000.00 95.09 210.31 3775.11 3702.41 5998743.98 562799.13 3214.10 0.00 0.00 MWD+IFR+MS 6100.00 95.09 210.31 3766.23 3693.53 5998657.56 562749.63 3292.83 0.00 0.00 MWD+IFR+MS 6200.00 95.09 210.31 3757.36 3684.66 5998571.14 562700.12 3371.57 0.00 0.00 MWD+IFR+MS 6300.00 95.09 210.31 3748.49 3675.79 5998484.72 562650.61 3450.30 0.00 0.00 MWD+IFR+MS 6400.00 95.09 210.31 3739.62 3666.92 5998398.30 562601.11 3529.03 0.00 0.00 MWD+IFR+MS 6500.00 95.09 210.31 3730.75 3658.05 5998311.88 562551.60 3607.77 0.00 0.00 MWD+IFR+MS 6600.00 95.09 210.31 3721.87 3649.17 5998225.46 562502.09 3686.50 0.00 0.00 MWD+IFR+MS 6700.00 95.09 210.31 3713.00 3640.30 5998139.04 562452.58 3765.24 0.00 0.00 MWD+IFR+MS 6716.85 95.09 210.31 3711.51 3638.81 5998124.48 562444.24 3778.50 0.00 0.00 MWD+IFR+MS 6750.00 94.99 212.31 3708.60 3635.90 5998096.12 562427.33 3804.95 6.00 92.85 MWD+IFR+MS 6800.00 94.82 215.31 3704.32 3631.62 5998054.50 562399.99 3846.11 6.00 93.03 MWD+IFR+MS 6850.00 94.64 218.32 3700.19 3627.49 5998014.35 562370.49 3888.70 6.00 93.29 MWD+IFR+MS 6900.00 94.45 221.32 3696.23 3623.53 5997975.80 562338.91 3932.59 6.00 93.53 MWD+IFR+MS 6950.00 94.25 224.32 3692.43 3619.73 5997938.94 562305.36 3977.68 6.00 93.77 MWD+IFR+MS 7000.00 94.03 227.32 3688.82 3616.12 5997903.88 562269.90 4023.82 6.00 94.00 MWD+IFR+MS 7050.00 93.81 230.32 3685.40 3612.70 5997870.72 562232.66 4070.91 6.00 94.22 MWD+IFR+MS 7100.00 93.57 233.32 3682.18 3609.48 5997839.53 562193.72 4118.80 6.00 94.42 MWD+IFR+MS 7150.00 93.33 236.31 3679.17 3606.47 5997810.42 562153.19 4167.37 6.00 94.61 MWD+IFR+MS 7200.00 93.07 239.31 3676.38 3603.68 5997783.46 562111.19 4216.49 6.00 94.79 MWD+IFR+MS 7250.00 92.81 242.30 3673.81 3601.11 5997758.73 562067.82 4266.02 6.00 94.96 MWD+IFR+MS 7300.00 92.54 245.29 3671.48 3598.78 5997736.28 562023.21 4315.82 6.00 95.12 MWD+IFR+MS 7350.00 92.26 248.28 3669.39 3596.69 5997716.19 561977.49 4365.75 6.00 95.25 MWD+IFR+MS 7395.51 92.00 251.00 3667.70 3595.00 5997700.00 561935.00 4411.21 6.00 95.38 MPS-22 T3 7400.00 91.94 251.26 3667.55 3594.85 5997698.51 561930.77 4415.69 6.00 103.87 MWD+IFR+MS 7450.00 91.21 254.17 3666.17 3593.47 5997683.25 561883.18 4465.50 6.00 103.88 MWD+IFR+MS 7500.00 90.49 257.09 3665.43 3592.73 5997670.42 561834.88 4515.06 6.00 103.96 MWD+IFR+MS 7550.00 89.76 260.00 3665.32 3592.62 5997660.05 561785.97 4564.22 6.00 104.01 MWD+IFR+MS 7600.77 89.03 262.95 3665.86 3593.16 5997652.09 561735.84 4613.60 6.00 104.01 MWD+IFR+MS 7700.00 89.03 262.95 3667.55 3594.85 5997639.05 561637.50 4709.50 0.00 0.00 MWD+IFR+MS 7800.00 89.03 262.95 3669.25 3596.55 5997625.91 561538.39 4806.14 0.00 0.00 MWD+IFR+MS 7900.00 89.03 262.95 3670.95 3598.25 5997612.77 561439.28 4902.77 0.00 0.00 MWD+IFR+MS 8000.00 89.03 262.95 3672.65 3599.95 5997599.63 561340.17 4999.41 0.00 0.00 MWD+IFR+MS 8100.00 89.03 262.95 3674.35 3601.65 5997586.49 561241.06 5096.05 0.00 0.00 MWD+IFR+MS 8200.00 89.03 262.95 3676.05 3603.35 5997573.35 561141.95 5192.69 0.00 0.00 MWD+IFR+MS 8300.00 89.03 262.95 3677.75 3605.05 5997560.21 561042.85 5289.32 0.00 0.00 MWD+IFR+MS 8400.00 89.03 262.95 3679.46 3606.76 5997547.08 560943.74 5385.96 0.00 0.00 MWD+IFR+MS 8500.00 89.03 262.95 3681.16 3608.46 5997533.94 560844.63 5482.60 0.00 0.00 MWD+IFR+MS 8572. 78 89.03 262.95 3682.40 3609.70 5997524.37 560772.49 5552.93 0.00 0.00 MWD+IFR+MS 8608.55 90.00 264.00 3682.70 3610.00 5997520.00 560737.00 5587.41 4.00 47.05 MPS-22 T4 8700.00 93.65 264.30 3679.79 3607.09 5997509.88 560646.18 5675.23 4.00 4.71 MWD+IFR+MS 8714.01 94.20 264.35 3678.83 3606.13 5997508.38 560632.29 5688.65 4.00 4.72 MWD+IFR+MS 8800.00 94.20 264.35 3672.53 3599.83 5997499.18 560547.03 5770.98 0.00 0.00 MWD+IFR+MS 8900.00 94.20 264.35 3665.20 3592.50 5997488.49 560447.89 5866.72 0.00 0.00 MWD+IFR+MS 9000.00 94.20 264.35 3657.87 3585.17 5997477.79 560348.74 5962.46 0.00 0.00 MWD+IFR+MS 9100.00 94.20 264.35 3650.54 3577.84 5997467.09 560249.59 6058.20 0.00 0.00 MWD+IFR+MS 9200.00 94.20 264.35 3643.21 3570.51 5997456.40 560150.45 6153.94 0.00 0.00 MWD+IFR+MS 9300.00 94.20 264.35 3635.87 3563.17 5997445.70 560051.30 6249.68 0.00 0.00 MWD+IFR+MS e BP KW A Planning Report e' Company: BP Amoco Date: 8f712003 Time: 10:45:26 Page: S Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-22. True North Site: M PI S Pad Vertical (fVO) Reference: 72.70 MPS-22 WI D-14 @ 72.7 Well: Plan MPS-22 Section (VS) Reference: Well (0.OON.0.00E.248.08Azi) Well path: Plan MPS-22 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVO Sys TVD MapN MapE VS DLS TFO Too ft deg deg ft ft ft ft ft deg/100ft deg 9400.00 94.20 264.35 3628.54 3555.84 5997435.00 559952.16 6345.42 0.00 0.00 MWD+IFR+MS 9500.00 94.20 264.35 3621.21 3548.51 5997424.31 559853.01 6441.16 0.00 0.00 MWD+IFR+MS 9600.00 94.20 264.35 3613.88 3541.18 5997413.61 559753.86 6536.90 0.00 0.00 MWD+IFR+MS 9700.00 94.20 264.35 3606.55 3533.85 5997402.91 559654.72 6632.64 0.00 0.00 MWD+IFR+MS 9800.00 94.20 264.35 3599.22 3526.52 5997392.22 559555.57 6728.38 0.00 0.00 MWD+IFR+MS /9820.75 94.20 264.35 3597.70 3525.00 5997390.00 559535.00 6748.24 0.00 0.00 MPS-22 T5 MPS-22 Subject: MPS-22 Date: Mon, 25 Aug 2003 16:21 :31 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Pat Archey <archeypj@bp.com>, "Steve Campbell," <CampbeIS@BP.com>, Mike Miller <millerme@bp.com> Hello All, Steve Davies (one of our Geologists) just brought the permit for MPS-22 to me. He said he has a call in to Steve regarding the need for a spacing exception for this well. I don't have all the particulars on the issue, but your Steve should try to get hold of him as soon as possible. Tom Maunder c·····w····"m~mmmm~nNA' W', ""~'" """"""" 'W^"~,,~~,,~" C" ,"v '."W_·.w~'_"~'m~~.'m e ~m' Tom Maunder <tom maunder(á)admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission e 1 of 1 8/25/20034:40 PM MP 8-22 Subject: MP 5-22 Date: Mon, 25 Aug 2003 16:35:25 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Mike Miller <millerme@bp.com>, Pat Archey <archeypj@bp.com> Mike and Pat, I got the auto reply from Steve's mailbox that he is out until the end of the week. In order to avoid any hold up on the processing of this permit, one of you or someone should get with Steve Davies. I have one need and that is with regard to any close approaches for the well. That point in the permit application is blank. Thanks. e Tom Maunder 1;..", ",····,w"'''''''''''~·;·;,,,·^'',<,,'''~·········,······· ,·······"··n'···'·<···m'·m';·;m"w;·;"'^"·;,..·,,,·;0«~~~_""",,,,,,,,,,-,,,,,., _~,~="M"'"'__''''''''' ""~"~~~______~_~__;·_____"'_~_~."__'__~___W__________'_=_"'.",''''''''''''''''''0"'< .."...,_...".."....,............,.........."........".........""... ...... ......-,.-........... .,..,."'........,-_. , .",,,,,,,,,,,..,,.,,..,,,,,..,,, . , T Qr.:n...M~l~!1º.Q.r <!QlIUna u n der@ ªr.~ In ¡ n . S tat§!:..~~!s.:.v.~ > Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission e 1 of 1 8/25/20034:40 PM S-22 Spacing Exception .. e Subject: 5-22 Spacing Exception Date: Tue, 26 Aug 200314:14:34 -0800 From: Steve Davies <steve_davies@admin.state.ak.us> To: archeypj@bp.com CC: Tom Maunder <tom_maunder@admin.state.ak.us> Pat, Within the Milne Point Unit, the Ugnu undefined oil pool is not governed by any Conservation Order, so any wells drilled to or completed in the Ugnu are governed by statewide spacing regulations. Per 20 MC 25.055 (a)(3), since oil has been discovered in the Ugnu at Milne Point, the drilling unit for the Ugnu undefined oil pool is a governmental quarter section; not more than one well may be drilled to and completed in that pool on any governmental quarter section; a well may not be drilled or completed closer than 1,000 feet to any well drilling to or capable of producing from the same pool. Based on Commission records, it appears as though a spacing exception will be needed for S-22. S-14i has perforations in the Ugnu Formation from 5265' - 5285' MD. According to the well plan and directional data for the proposed S-22 producer, it appears as though S-22 will be open to production in the Ugnu about 910 feet from these perforations. It also appears that a portion of the Ugnu interval open to production in S-22 will also lie in the same governmental quarter section as the perfs in S-14i. Both of these conditions require a spacing exception according to 20 MC 25.055 (a)(3). Guidance for spacing exception applications is contained in regulation 20 MC 25.055 (d). This regulation can be found on the Commission's web site at h~~~. Jf..,..-;:.,_~."; fo)~éJ~~_Q._~:"· . .~. 11r:~~"?:.~.!1_~"'; :1C:r~ ~~ 1¡.\~I"':'IN '~)£~~Rt'·;: .' t'::~L:t~ '( ': ..~ I'~:; , ~. ""·:~0!:. !-or your (;ol1vonier'ce, Ilwvo attached tilE! :OXI of It'is rog~..ation 10 lt10 end of this em ail. The complete set of Commission regulations can be found on the web at: http://www.state.ak.us/local/akpaQes/ADMIN/oQc/ReQulations/art199.htm . To help you further as you prepare your application for spacing exception, I have also attached a copy of the checklist that the Commission staff uses during our evaluation of these applications. For planning purposes, the entire spacing exception process should take about 6 weeks. Once your application is received and deemed complete, a tentative date for a public hearing will be set and a Notice of Public Hearing will be published. There will then be a 30 day public comment period. If no request is made for a public hearing (and I wouldn't expect any for this particular well), the Commissioner's will typically vacate the hearing, and an exception will likely be granted. In the meantime, the well can be drilled, it just cannot be tested or produced until a spacing exception has been granted. If BP drills the well without a spacing exception, BP bears all risk in the event that an exception is not granted. Please don't hesitate to call if you have any questions. Sincerely, Steve Davies Petroleum Geologist Alaska Oil and Gas Conservation Commission Telephone: (907) 793-1224 Fax: (907) 276-7542 steve _ davies@admin.state.ak.us 1 of 3 e 8/26/2003 2:30 PM S-22 Spacing Exception ~ -- ---...-------------------...---------...--------...-------------------------- 20 MC 25.055 DRILLING UNITS AND WELL SPACING. (a) The commission will, in its discretion, establish drilling units to govern well spacing and prescribe a spacing pattern by pool rules adopted in accordance with 20 MC 25.520. In the absence of an order by the commission establishing drilling units or prescribing a spacing pattern for a pool, the following statewide spacing requirements apply: (1) for a well drilling for oil, a wellbore may be open to test or regular production within 500 feet of a property line only if the owner is the same and the landowner is the same on both sides of the line; (2) for a well drilling for gas, a well bore may be open to test or regular production within 1,500 feet of a property line only if the owner is the same and the landowner is the same on both sides of the line; (3) if oil has been discovered, the drilling unit for the pool is a governmental quarter section; not more than one well may be drilled to and completed in that pool on any governmental quarter section; a well may not be drilled or completed closer than 1,000 feet to any well drilling to or capable of producing from the same pool; (4) if gas has been discovered, the drilling unit for the pool is a governmental section; not more than one well may be drilled to and completed in that pool on any governmental section; a well may not be drilled or completed closer than 3,000 feet to any well drilling to or capable of producing from the same pool. (b) A well may not begin regular production of oil from a property that is smaller than the governmental quarter section upon which the well is located or begin regular production of gas from a property that is smaller than the governmental section upon which the well is located, unless the interests of the persons owning the drilling rights in and the right to share in the production from the quarter section or section, respectively, have been pooled under AS 31.05.100. (c) A pooling agreement under AS 31.05.100 must be filed with the commission before regular production from the affected property 2of3 e 8/26/2003 2:30 PM S-22 Spacing Exception .. begins. (d) The commission will review an application for an exception to the provisions of this section in accordance with 20 MC 25.540. The e e applicant for an exception shall send notice of the application by certified mail to the owners, landowners, and operators described in (1) of this subsection and shall furnish the commission with a copy of the notice, the date of mailing, and the addresses to which the notice was sent. The application must include (1) the names of all owners, landowners, and operators of all properties within 1,000 feet of a well drilling for oil or within 3,000 feet of a well drilling for gas for which an exception is sought; (2) a plat drawn to a scale of one inch equaling 2,640 feet or larger, showing the location of the well for which the exception is sought, all other completed and drilling wells on the property, and all adjoining properties and wells; and (3) an affidavit by a person acquainted with the facts, verifying that all facts are true and that the plat correctly portrays pertinent and required data. (e) Upon application by the operator, the commission will establish notice requirements different from those of (d) of this section if the operator demonstrates to the commission's satisfaction that compliance with the notice requirements in (d) of this section is not feasible because of the complexity of ownership within the notice area. History - Eff. 4/13/80, Register 74; am 4/2186, Register 97; am 1117/99, Register 152 ~ Step3 SpacinQ Exception Name: Step3 _ Spacing_ Exception_ CHECKLlST.doc ¡ CHECKLlST.docl.. TY...P. e: WINWORD File (application/msword) Ii Encoding: base64 . 30f3 8/26/2003 2:30 PM o o o Ó o o 'f5 N 149 28 00 W MD Ticks 1.'IS-13 560,000 I '-J 2 ,000 ~ .f:>- a a _I pQ55117 DATE 7/14/2003 CHECK NO. 055117 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 7/14/2003 INV# PR071003G PERMIT TO DRILL FEE H e Rs- LL THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ - NATIONAL CITY BANK Ashland, Ohio 56-389 412 No.P 055117 CONSOLIDATED COMMERCIAL ACCOUNT 333 W 7TH AVENUE SUITE 100 ..... ANCHORAßE, AK 99501-3539 NÖTV"'O~\",:,:'~á~;é:~::'.~:}~;:;<::~ ...... ..... ß.á~ .... .............. .....-...... " . :·:·:·:./>~AJf'J!., '. .:\... '.'" ~""~" "I . :. I Y'ri . .., ... . .. '" ... .,. "" .:~: .::\.~. .:::;:. .':"::~:: :¡'.::::;~".:\"i·:::·~.;·::~;j·::\;·:·,\:..:·"·;:..l "~...,:,:"::",:",,...'......".'......."'':'''':'':I..:'._'.J II- 0 5 5 ~. L ? II- ø: 0... ~ 20 j 8 ~ 5 I: 0 ~ 2 ? 8 ~ b liD e e TRANSMIT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME IJJ¡?¿{ 5-J.~ PTD# 2-03 -- IL('] CHECK WHAT APPLIES ADD-ONS (OPTIONS MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function ·of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) 04; '(Þ I (I r 0..' DRY DITCH SAMPLE Rev: 07110/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issu~nce of a conser;ation or~ro~ spacmg exception. ï( (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Field & Pool MILNE POINT, UGNU OIL UN DEFINE - 525160 Well Name: MILNE PT UNIT UGNU S-22 _Program DEV Well bore seg 0 BP EXPLORATION (ALASKA) INC Initial ClassfType DEV I PEND GeoArea 890 Unit j1328 On/Off Shore On Annular Disposal 0 Administration P§!rmit fee attached. - - - - - - - - - - - - - - - - - - - - - - - - - - - - .......Y.e$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 .Leas§! .number .approwiate. . - - - - - - - - - - - - - - - - - - - . . . . . . . . V§!$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 3 .U.nique weltn.a[T1J:J.atld Ol!mb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . V§!$ - - - - - - - - - - - - - - - - - - - - - - - - - -- . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 WeJIIQcatJ:Jd in.a. d.efinedpool. . . . . . . . . . - - - - - - - - . No. · . . MiJn.e Point Unit UQ.nu,. UndefinJ:Jd oil pop; first Ugnu. d.eveIQP[T1etlt weJ!. . . . . . . . . . - - - - - - - 5 WelUQcatJ:Jd prpperdistance. from driJling unitbound.al)'. - - - - - - - - .. YJ:Js - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 6 WeUIQcatJ:Jd proper .distance. from otber welJs. - - - - - - - - - - ........Y.e$ . 9/12/2003:.Reyi$ed. appljc.atiQn. with revised directjonal.p!an receiyed. .SpacioQ. exception not re~:¡uired.. . 7 .S.ufficienlacreaQ.e.aYailab1e in.drilJiog l!njl. . . - - - - - - - - - - - . . .Y.e$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 If.deviated, js weJlbQre platincJu.ded . - - - - - - - - - ..... YJ:J$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - , 9 .Qper.ator only affected party. . . . . . . . . . . - - - - - - - - - -- . . . .Y.e$ - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - 10 .Ope(ator bas.appropriate.b.ond inforce . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y§!$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - 11 PJ:Jrmit ~an Þe lS$l!ed witbQut cOMervation order. . . . . . . . . . . . . . . ... YJ:J$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 12 PJ:Jrmit~atl Þe lS$l!ed witbQut administratille.apprpval . . . . . . . . . . . ...... Ye$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - SFD 9/16/2003 13 Can permit be approved before 15-day wait Yes 14 WelUQcated within area al1d.strataauthorized by Injection Order # (PutlO# incpm[T1J:Jtlts) (For Y§!S - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - ~ - - - - - - - - e 15 .AJI weIJs. within .1 l4.llJile.area.of reyiew id§!otified (Fpr servjc.ewell only). . . . . . . . . . . . . . . YJ:J$ - - . - - - - - - - - - - - - - - - - - - - - - - - - - -. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 16 Pre-produ.cecl injector; Jluratio.nof pre-pro.duGlion I§!ss. than 3 months. (For.service well QnJy) . . YJ:J$ - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 ACMP.F'indjngof CQn$istencyh.a$ Þeenissued. for.tbi$ p(oiect . . . . . . . . . .... NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 C.ondu.ctor string.prQvided . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .... YJ:J$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 19 .S.uúaœ .casing. prQte~ts alLknown. USDWs . - - - - - - - - - - - - - - - -- NA · . . ,L\11 aq.uifers eXJ:Jmpted 40 CfR "147.. 102(b)(3) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 20 CMT vol adequ.ate.to circulate.o.nconductor. & $uJf.C$g . . . . . . . . . . . . . . ... YJ:J$ - - - - - - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - 21 CMT v.ol adequate.to tie-inJQngstring tosuú csg. . . . . . . . . . . . . . . . . . · . . . No. - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - 22 .CMTwill coyer.aJl !<nown.pro.ductiye bQri;zons. . . . . . . . . . . . . . . . . . No · . . screeJlcOllJpletioo plaoned. . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 23 .C.a$ing designs adeQua.te for C,T, B.&. permafrpst . . . . . . . . . . . . · . . . Y§!S - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequatetan.kage.or re.serve pit. . . . . . . . . . . . . . . - - - - - - - -- ... YJ:J$ · . Rig ise.quippe.dwith $teelpjts. .NQr reserve pit plan.ned. AII.wa$tetQ Class. It well(s) . . . . . . . . . . . . . . . . 25 If.a re-drilt bas a 10,.403 fQr abandonment beJ:Jn apprQved . - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - -- - ~ - - - - - - - - - - - - - - - - - 26 Adequatewellbore separatjo.n.proposed. . . . . . . . . . . . . . . . . . . . . . . .....Y.e$ - - - - - - - - - - - - -. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 27 Ifdiverter req.uired, dQes iLmeet regulations. . . . . . . . . . . . . . . . . · Ye$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 28 .Drilling fluid. program s~hematlc& equipli$tadequate. . . . . . . . . . . · . . . YJ:Js · . . Expected BHF' 8.35 EMW, PJanned llJud. wejQ.hts8.Q -. 10.0. . . . . . . . . . . . . . . . . . . . . TEM 9/16/2003 29 BOPE$,dpthey meet regulation - - - - - - - - - - - - - - - - - - -- .... YJ:J$ - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - 30 .BOPE.pres$ rating appropriate; test to.(put psig in.comment$) Ye$ · . . CalcuJated.MASF> 1259 psi.. Planned ßOP.test Press.ure.3500 psj. . . . . . . e 31 ChokellJanifold cQmplies w/API RF'-53(May 84). . . . . . . . . . . . _... Ye$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 WQrk will occur withoul.operatjonsbl!tdown. Ye$ - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is presence Qf H2S gas. prob.able . - - - - - - - - - - - - - - - ~ - - - - - - - _... .NA - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 34 Mecbanical.coodjllon pf well$ within ,L\OR yerified CFor.s.ervjce wel] only). NA - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - Geology 35 Permit catl Þe iS$l!ed w!o. hydrogen s.ulfide meas.ures. . - - - - - - -- . . . Y§!S - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - 36 .D.ata.preseoted on. pote.ntial pverpres.sure .zone$. . . . . . . . . . . . . . . . . . ... Ye$ . . Expected re$ervojr pre.S$uJe i$8.35 ppg EMW; wiJI be drilled with 6.6 ~ 1. O,Q ppg .mud.. . . . . . . . . . . . . . . . . . Appr Date 37 .Seismicanalysjs. Qf shallow gas zones NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - SFD 8/22/2003 138 Seabed .condjtioo $l!rvey(if off-sh.ore) . . . . . . . . · NA - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - -- - - - - -- 39 CQnta.ct namelphoneJor.weelsly progressreport$ [explQratpl)' .only]. . · .NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Date: Engineering Date Public Date Ugnu horizontal producer. Revised permit to drill application including revised directional plan received 9-12-2003. SFD Commissioner: Commissioner: Commissioner tJ~ c¡ ) J ) Jc 3 · 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 infomlation, 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 Drillllg Services LIS Scan Utility . dC;:3-¡LI+ $Revision: 3 $ LisLib $Revision: 4 $ Mon Dec 08 14:01:14 2003 /' I;). )O~ Reel Header Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/12/08 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 Da te. . . . . . . . . . . . . . . . . . . . . 03/12/08 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 Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-22 500292317600 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 08-DEC-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002678821 T. MCGUIRE E. VAUGHN MWD RUN 2 MW0002678821 J. STRAHAN E. VAUGHN MWD RUN 3 MW0002678821 J. STRAHAN E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3297 238 .00 72.18 38.40 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 13.500 9.875 6.125 CASING SIZE (IN) 20.000 10.750 7.625 DRILLERS DEPTH (FT) 112.0 2561.0 5215.0 # 'K~~(l\.~ REMARKS: . - 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS O~WISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 3 ALSO INCLUDED AT-BIT INCLINATION (ABI) AND PRESSURE WHILE DRILLING (PWD). MAD PASS DATA OVER THE INTERVAL 5805'MD - 5223'MD (BIT DEPTHS) WERE ACQUIRED WHILE POOH AT THE COMPLETION OF RUN 3. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY, BP EXPLORATION (ALASKA), INC., DATED 10/14/03. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 - 3 REPRESENT WELL MPS-22 WITH API#: 50-029-23176-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9242IMD/3660'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 (DEEP RESISTIVITY) . SLIDE = NON-ROTATED INTERVALS, REFLECTING BIT DEPTHS. CURVE MNEMONICS WITH AN 1M' SUFFIX DENOTE MAD PASS DATA. $ File Header Service name........... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/08 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 1 and clipped curves; all bit runs merged. .5000 START DEPTH STOP DEPTH GR ROP RPS RPX FET RPM RPD $ 69.5. 114.0 2550.0 2550.0 2550.0 2550.0 2550.0 9188.5 9242.0 9195.5 9195.5 9195.5 9195.5 9195.5 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 69.5 2570.0 5225.0 MERGE BASE 2570.0 5225.0 9242.0 # 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 69.5 9242 4655.75 18346 69.5 9242 ROP MWD FT/H 8.62 3244.6 275.084 18257 114 9242 GR MWD API 11.12 134.72 60.9534 18239 69.5 9188.5 RPX MWD OHMM 0.1 2000 25.1118 13292 2550 9195.5 RPS MWD OHMM 0.11 2000 62.6785 13292 2550 9195.5 RPM MWD OHMM 0.08 2000 69.0008 13292 2550 9195.5 RPD MWD OHMM 1.49 2000 77.541 13292 2550 9195.5 FET MWD HOUR 0.05 36.5 0.783212 13292 2550 9195.5 First Reading For Entire File......... .69.5 Last Reading For Entire File.......... .9242 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... version Number.......... .tIÞ.O Date of Generation...... .03/12/08 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...... .03/12/08 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE SGRC SESP SFXE SEMP SEXP SEDP SRAT $ # MERGED DATA SOURCE PBU TOOL CODE $ # REMARKS: 2 and clipped curves¡ all MAD runs merged using earliest passes. .5000 START DEPTH 5173.0 5180.0 5180.0 5180.0 5180.0 5180.0 5227.5 STOP DEPTH 5752.5 5759.0 5759.0 5759.0 5759.0 5759.0 5807.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MERGED MAD 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 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 · .~ng Last Name Service Unit Min Max Mean Nsam Reading DEPT FT 5173 5807 5490 1269 5173 5807 RAT MAD FT/H 10.88 922.19 389.302 1160 5227.5 5807 GR MAD API 23.6 90.81 56.8181 1160 5173 5752.5 RPX MAD OHMM 0.28 26.14 11.5735 1159 5180 5759 RPS MAD OHMM 0.29 2000 28.4182 1159 5180 5759 RPM MAD OHMM 0.19 2000 60.2688 1159 5180 5759 RPD MAD OHMM 0.38 2000 119.55 1159 5180 5759 FET MAD HOUR 44.06 86.51 50.3646 1159 5180 5759 First Reading For Entire File......... .5173 Last Reading For Entire File.......... .5807 File Trailer Service name............ .STSLIB.002 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/12/08 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...... .03/12/08 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. 1 .5000 START DEPTH 69.5 114.0 STOP DEPTH 2525.0 2570.0 # 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: 28-SEP-03 Insite 66.37 Memory 2570.0 112.0 2570.0 .3 47.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR $ DUALaMA 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 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 Rep 68 68 68 Code Nsam 1 1 1 155790 13.500 112.0 Spud Mud 9.30 134.0 8.0 800 9.4 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 . .0 71. 6 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 2570 1319.75 5002 69.5 2570 ROP MWD010 FT/H 52.19 1424.8 208.06 4913 114 2570 GR MWD010 API 18.74 118.19 58.7451 4912 69.5 2525 First Reading For Entire File......... .69.5 Last Reading For Entire File.......... .2570 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/08 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .~IB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/08 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 RPX RPS RPM RPD FET ROP $ 4 . header data for each bit run in separate files. 2 .5000 START DEPTH 2525.5 2550.0 2550.0 2550.0 2550.0 2550.0 2570.5 STOP DEPTH 5188.0 5180.0 5180.0 5180.0 5180.0 5180.0 5225.0 # 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. 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: 30-SEP-03 Insite 66.37 Memory 5225.0 2570.0 5225.0 48.0 78.8 TOOL NUMBER 149206 134758 9.875 2561.0 LSND 9.20 70.0 8.0 800 5.8 6.000 5.370 79.0 89.1 MUD FILTRATE AT MUD CAKE AT MT: MT:. 8.500 4.600 ~. # 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2525.5 5225 3875.25 5400 2525.5 5225 ROP MWD020 FT/H 30.32 3244.6 435.732 5310 2570.5 5225 GR MWD020 API 11.12 134.72 67.4159 5326 2525.5 5188 RPX MWD020 OHMM 0.14 75.43 11.6581 5261 2550 5180 RPS MWD020 OHMM 0.36 78.16 11.6748 5261 2550 5180 RPM MWD020 OHMM 0.08 588.57 12.4879 5261 2550 5180 RPD MWD020 OHMM 2.36 2000 19.4486 5261 2550 5180 FET MWD020 HOUR 0.05 33.67 0.60363 5261 2550 5180 First Reading For Entire File......... .2525.5 Last Reading For Entire File.......... .5225 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/08 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header service name............ .4ItLIB.005 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/08 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 RPX RPS GR ROP $ 5 . header data for each bit run in separate files. 3 .5000 START DEPTH 5180.5 5180.5 5180.5 5180.5 5180.5 5188.5 5225.5 STOP DEPTH 9195.5 9195.5 9195.5 9195.5 9195.5 9188.5 9242.0 # 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 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): 04-0CT-03 Insite 66.37 Memory 9242.0 5225.0 9242.0 79.5 96 .4 TOOL NUMBER 184054 159436 6.125 5215.0 Flo-pro 9.50 48.0 8.5 65000 5.4 .060 .050 .050 .120 72.0 88.9 72.0 72.0 # . . 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5180.5 9242 7211.25 8124 5180.5 9242 ROP MWD030 FT/H 8.62 1873.72 209.892 8034 5225.5 9242 GR MWD030 API 21. 26 99.04 58.0071 8001 5188.5 9188.5 RPX MWD030 OHMM 0.1 2000 33.9252 8031 5180.5 9195.5 RPS MWD030 OHMM 0.11 2000 96.0904 8031 5180.5 9195.5 RPM MWD030 OHMM 0.23 2000 106.022 8031 5180.5 9195.5 RPD MWD030 OHMM 1.49 2000 115.597 8031 5180.5 9195.5 FET MWD030 HOUR 0.17 36.5 0.900854 8031 5180.5 9195.5 First Reading For Entire File......... .5180.5 Last Reading For Entire File......... ..9242 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/08 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/12/08 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.................... .03/12/08 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File . Scientific Technical Services