Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
202-085
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Cut Tubing Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Resrvoir P&A 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,186' N/A Casing Collapse Conductor N/A Production 5,410psi Liner A N/A Liner B N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7,775' MILNE PT UNIT S-27 MILNE POINT SCHRADER BLUFF OIL N/A Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 4,084' 11,186' 4,084' 1,153 N/A Subsequent Form Required: Suspension Expiration Date: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 1/1/2026 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 202-085 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23084-00-00 Hilcorp Alaska LLC C.O. 477B Length Size Proposed Pools: 112' 112' 9.3# / L-80 / EUE 8rd TVD Burst 7,838' MD N/A N/A 7,240psi N/A 4,104' 4,068' 4,081' 8,302' 11,009' 112' 20" 7" 4-1/2" 8,302' 4-1/2"2,990' 3,073' Perforation Depth MD (ft): 11,155' See Schematic See Schematic 3-1/2" Paragon II & Premier 7" x 3.5" and N/A 7,658 MD/ 3,969 & 7,786 MD/ 4,008 MD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 2-3/8" 4.6# / J-55 / Supermax 7,650' 4-1/2" 12.6# / L-80 / IBT Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.12.17 13:55:19 - 09'00' Taylor Wellman (2143) 325-767 By Grace Christianson at 2:21 pm, Dec 17, 2025 MGR19DEC2025 10-404 TS 12/19/25 19-DEC-2030* BOPE pressure test to 1500 psi. 24-hour notice to AOGCC for opportunity to witness. * AOGCC to witness coil tag of TOC ~7400' MD and pressure test to 1500 psi. DSR-12/19/25 12/19/25 Well: MPS-27 PTD: 202-085 Well Name:MPS-27 API Number:50-029-23084-00-00 Current Status:Shut-in Producer Rig:ASR #1 Estimated Start Date:1/1/2026 Estimated Duration:4 days Regulatory Contact:Tom Fouts Permit to Drill Number:202-085 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 1549 psi @ 3,960 TVD 12/5/2025 | 7.6 EMW, 8.0 KWF Max Potential Surface Pressure: 1,153 psi Gas Column Gradient (0.1 psi/ft) Max Angle:74° Sail Angle from 4,331 MD Brief Well Summary: The Milne Point S-27 well is a jet pump producer. July 2015 this well was converted to a FCJP in 2-3/8 tubing. July 2019 the well was shut in. Objectives: Pull 2-3/8 and 4-1/2 JP completions. Res P&A OB and OA laterals Notes Regarding Wellbore Condition: Currently Not Operable Pre-Rig Procedure (Non Sundried Work) Slickline 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. Drift and tag with sample bailer. 3. Pull SV from 7,631 MD 4. RDMO. Pumping & Well Support 5. Clear and level pad area in front of well. Spot rig mats and containment. 6. RD well house and flowlines. Clear and level area around well. 7. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 8. Pressure test lines to 3,000 psi. 9. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. Bullhead down 2-3/8 tbg and 4-1/2 IA taking returns to formation as needed to establish and maintain a full column of produced water. 10. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 11. RD Little Red Services and reverse out skid. 12. Set BPV. ND tree. NU 11 BOPE. This will be 63 off ground level. Well: MPS-27 PTD: 202-085 Brief RWO Procedure (Begin Sundried Work) 13. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 14. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 15. Test BOPE to 250 psi low/ 1,500 psi high. Test annular to 250 psi low/ 1,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test ram on 2-3/8 test Joint e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 16. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 17. PU 2-3/8 tubing. 2016 ASR pick up wt 24K. 18. TOOH. 19. TIH with Quadco 4-1/2 shear down retrieving tool on 2-3/8 Supermax tubing we just pulled from the well. 20. Shear down packer and release. Allow rubbers 30 min to relax before TOOH. Slickline rig assist: 21. RU SL and pressure test 22. Drift run down to the SS. 23. RIH Open SS at 7738 MD. 24. RD SL 25. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. Bullhead down 4-1/2 tbg and 7 IA taking returns to formation as needed to establish and maintain a full column of produced water. 26. Confirm well is dead. 27. Set 4" BPV and CTS plugs in 11 x 4-1/2" Tubing hanger. 28. Nipple down BOPs and Seaboard tubing spool. 29. Nipple up 11 BOPs. Replace the 2-3/8 ram with 2-7/8 x 5 VBRs. 30. Test BOPE to 250 psi low/ 1,500 psi high. Test annular to 250 psi low/ 1,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. f. Perform test per ASR 1 BOP Test Procedure g. Notify AOGCC 24 hours in advance of BOP test. h. Confirm test pressures per the Sundry conditions of approval. i. Test VBR ram on 4-1/2 test Joint j. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 31. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. Well: MPS-27 PTD: 202-085 32. RU spoolers to handle Tec-line. 33. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an FMC 11 x 4-1/2 Gen 6, with 4-1/2 TC-II T&B. b. 2002 tubing PU weight on D-14 not recorded. c. 4-1/2 L-80 IBT yield is 208 kip. 34. RU Eline. 35. RIH to make a Welltec 2-3/8 mechanical cut on 7 x 3-1/2 Baker Premier packer 7,788.1 7,789.8 MD. a. From the Top of the Packer to the top of the cut zone is 43.64in (3.64ft), cut zone is 21.39in (1.78ft). Mandrel ID is 2.87 and Max Cut OD is 3.85. b. Confirm CCL with OE prior to making cut. 36. POOH. RD Eline. 37. Confirm hanger free, lay down tubing hanger. 38. Close the annular and circulate 1.5x bottoms up to clear out any gas from underneath the packer. 39. Monitor well for 30 min. 40. POOH and lay down the 4-1/2 tubing. a. Do not keep tubing. b. Note any sand or scale inside or on the outside of the tubing on the morning report. c. Recorded Clamp Totals: i. I wire control line clamps = 98 41. Lay down 4-1/2 completion. Eline - rig assist: 42. RU Eline. 43. RIH to set 7 RBP at +-3,000 MD. 44. POOH. RD Eline. 45. Pressure test plug to 1500 psi charted for 30 minutes. Bleed of pressure. 46. Set J-plug BPV in 11 x 7" Tubing hanger. 47. Nipple down BOPs. 48. NU Upper Tbg Spool , 11 x 7 DSA and Dry Hole Tree 49. PT tree 500/5000 psi 50. Dry Rod out J-plug BPV 51. Secure tree and cellar 52. RDMO ASR. Coil Procedure: 53. MIRU CTU. PT PCE accordingly with respect to the coil weekly BOP testing 54. RIH w/ 2.00 coil RIH with Baker 7 RBP retrieving head. 55. Latch plug, pick up to confirm the plug is moving, stop and let rubbers relax for 30 min. 56. POOH 57. RIH cleanout BHA: dual BPV, coil disconnect, GR/CCL, Tempress Hydro pull and down jet nozzle 58. RIH and dry tag. PU and break circulation. Make cut with eline then rig up for pulling tubing. - mgr 37. 34. RU Eline. Well: MPS-27 PTD: 202-085 59. Begin FCO/ Fluff-n-stuff to PBTD. a. Anticipating to be entering into the lower OB lateral b. Perform PU weights as seen fit by WSM c. Perform down log to ±8300-ft MD. d. Obtain continuous single pass from 7900 8300-ft MD if possible 60. POOH to surface and download memory GR/CCL a. Compare the logging runs w/ GR/CCL to verify which lateral being entered (OA or OB) and whether both runs were consistent. If see only one lobe of sand OA lateral, if see two lobes of a sand OBA lateral. Contact OE and Geo Patrick Boyle patrick.boyle@hilcorp.com or (267) 2407493 to confirm which lateral was entered. b. (If entry into the OA (upper lateral)) i. RIH w/ FCO BHA and perform FCO/ Fluff-n-stuff to PBTD of the OA lateral. ii. We do not want to cement the OA first. 61. Assuming we default into the OB lateral as planned. MU cementing BHA with circ sub, Tempress and RIH to enter into the OB lateral. Once at PBTD, mix 44 bbls of cement and pump down the coil taking returns to formation. Once cement is at the nozzle lay in cement 1:1 from PBTD to 8280-ft MD as per PE manual recommendations. NOTE: OB Lateral Volume: (11155 8280 = 2875-ft MD) x 0.0152 bpf = 44 bbls 62. At the lateral junction swap over to Gel and contaminate the cement to ensure we can set the Hook wall hanger and reenter the OA lateral. 63. POOH and circulate as needed to clear coil and replace pipe displacement. WOC to reach compressive strength. 64. RIH with 3.75 drift BHA and confirm cement top below the junction. 65. MU cementing BHA w/ Baker 9 degrees bent sub and indexing tool (Yankee screwdriver) BHA. RIH and orient as needed to enter the OA lateral. NOTE: TOC in the OB lateral should be at ±8280-ft MD a. If entry into the OA lateral is unachievable see Contingency: If upper OA lateral cannot be entered at the end of this procedure 66. Once at PBTD, mix 67 bbls of cement and pump down the coil taking returns to formation. Once cement is at the nozzle lay in cement 1:1 from PBTD to ±7400-ft MD as per PE manual recommendations. a. OA Lateral Volume: (10965 7936 = 3029-ft MD) x 0.0152 bpf = 46 bbls b. 7 Volume: (7936 7400 = 536-ft MD) x 0.0383 bpf = 21 bbls 67. POOH and circulate as needed to clear coil and replace pipe displacement 68. RDMO Coil Unit. Slickline: 69. RU and pressure test PCE. 70. RIH with a drift BHA and tag cement. State witnessed 71. Pressure test to 1500 psi charted for 30 minutes. State witnessed. 72. RD Contingency:If upper OA lateral cannot be entered Coil Tubing Abandonment Well: MPS-27 PTD: 202-085 73. RIH with 7 RBP and set at 3000 MD. 74. RDMO and wait for Diverter tool to be manufactured. 75. MIRU CTU. PT PCE accordingly with respect to the weekly coil BOP testing 76. RIH w/ 2.00 coil RIH with Baker 7 RBP retrieving head. 77. Latch plug, pick up to confirm the plug is moving, stop and let rubbers relax for 30 min. 78. POOH 79. MU Lateral Re-entry diverter BHA. 80. TIH to set Lateral Re-entry diverter in Model B-2 Hook Wall Hanger junction 81. TOOH with Lateral Re-entry diverter deployment BHA. If we are unable to get the Lateral Re-entry Diverter set in the Model B-2 Hook Hgr, Hilcorp will submit a Change of Procedure to the state requesting Approval to proceed with setting a 7 Cmt Retainer above the Model B-2 Hook Hgr Assy to bullhead cement into the upper OA lateral. 82. RIH to ensure we are defaulting into the upper OA lateral and not tagging TOC in the lwr OB lateral (TOC 8280-ft CTMD) 83. MU FCO/ Fluff-n-Stuff BHA NOTE: Baker Hughes Lateral Re-entry Diverter has a 3.76-in ID (3.625 drift) and 4-½, 12.6# L80 IBT Solid/Slotted Lnr is 3.958-in nominal ID (3.833 drift) 84. RIH to +/- 7900-ft MD and come online with pumps while taking returns to formation. Begin FCO/ Fluff-n-Stuff to bottom screen in upper OA lateral (10,965-ft MD). 85. Once at PBTD, mix 67 bbls of cement and pump down the coil taking returns to formation. Once cement is at the nozzle lay in cement 1:1 from PBTD to +/- 7400-ft MD as per PE manual recommendations. a. OA Lateral Volume: (10965 7936 = 3029-ft MD) x 0.0152 bpf = 46 bbls b. 7 Volume: (7936 7400 = 536-ft MD) x 0.0383 bpf = 21 bbls 86. POOH and circulate as needed to clear coil and replace pipe displacement 87. RDMO. Slickline 88. RU and Pressure test PCE 89. RIH with drift BHA and tag cement. State witnessed 90. Pressure test to 1500 psi charted for 30 minutes. State witnessed 91. RDMO Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Tree Diagram 4. 11 BOPE Schematic 5. Coil BOPE Schematic _____________________________________________________________________________________ Updated By: RJL 12/15/25 SCHEMATIC Milne Point Unit Well: MPU S-27 Last Completed: 7/20/2015 PTD: 202-085 TD =11,186(MD) / TD = 4,084(TVD) 20 Orig. DF Elev. = 67.30 / Orig. GL Elev.= 39.30 7 9 10 13 14 15 16 17 18 4 1920 21 OA Lateral PBTD =11,186(MD) / PBTD = 4,084(TVD) 12 11 OB Lateral 1 2 3 5 6 7 8 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 N/A Surface 112' 7" Intermediate 26 / L-80 / Btc-Mod 6.276 Surface 8,302 4-1/2 Slotted Liner A 12.6 / L-80 / IBT 3.958 7,936 11,009 4-1/2 Slotted Liner B 12.6 / L-80 / IBT 3.958 8,165 11,155 TUBING DETAIL 2-3/8 Tubing 4.6/ J-55/ SuperMax 1.995 Surface 7,650 4-1/2 Tubing 12.6 / L-80 / IBT 3.958 Surface 7,775 3-1/2" Tubing 9.3 / L-80 / EUE 8rd 2.992 7,775 7,838 JEWELRY DETAIL No Depth Item 1 7,628 Jet Pump Cavity and Retriever Assembly (Standing valve only 4-9-21) 30 bbls 2 7,631 Locator Seal Assembly 3 7,632 Seal Assembly Extension 4 7633 Seal Bore, 19 Long 5 7,646 Seal Units x 4 Bottom @ 7,650 6 7,650 WLEG Bottom @ 7,650.35 7 7,658 Packer, Paragon II (2.0 ID Bore) 8 7,692 WLEG 9 7,727 Phoenix Discharge Pressure Gauge 3.850 ID 10 7,738 HES 4.5 XD Dura Sliding Sleeve 11 7,758 Phoenix Sensor 4-1/2 Casing ID Change to 2.840 12 7,773 XO 4.512.6# NSCT Box x 3.5 NSCT Box 13 7,775 HSE 3.5 X-Nipple NSCT 14 7,786 Baker Premier Packer 7 x 3.5 15 7,833 HES 3.5 XN-Nipple 2.750 No Go 16 7,836 3.5 NSCT WLEG Bottom @ 7,837 17 7,936 Baker Hook Wall, Hanger above 7 Window 18 7,962 Baker Hook Wall, Hanger outside 7 Window 19 8,165 Baker Tie Back Sleeve 20 8,177 Baker ZXP Liner Top Packer 21 8,185 Baker 7 x 5 HMC Liner Hanger OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset (Approx) in 42 Hole 7 Cmt w/ 1,360 sx Class PF L, 650sx Glass G in 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 600 MD 70 to 73 Deg. 2,900 7,800 Max Hole Angle = 73 deg. @ 6,000 MD 72 Deg. @ Sliding Sleeve GENERAL WELL INFO API: 50-029-23084-00-00 Drilled and Completed by Doyon 141 - 15/28/2002 NOTE: Prior to setting or pulling 4.5 BPV or TWC, notify FMC. 4.5 TCII thread profile compatibility issue exists. LATERAL WINDOW DETAIL Window in 7 Casing @ 7,948 to 7,960 Well Angle @ Window =74 Deg. WELLHEAD Tree 4-1/165M FMC Wellhead 11 x 4.5 5M Gen. 6 w/ 4.5 TC-II T&B Tubing Hanger CIW H BPV Profile Hole New Tubing Head (Installed 2015) Tubing Hanger w/ 2-3/8 8RD Lift Threads Jet Pump: E8 pulled 4/8/21 Standing Valve: New valve set without screen on 4/9/21 _____________________________________________________________________________________ Updated By: TDF 12/9/2025 PROPOSED Milne Point Unit Well: MPU S-27 Last Completed: 7/20/2015 PTD: 202-085 TD =11,186(MD) / TD = 4,084(TVD) 20 Orig. DF Elev. = 67.30 / Orig. GL Elev.= 39.30 7 18 OA Lateral PBTD =11,186(MD) / PBTD = 4,084(TVD) OB Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 N/A Surface 112' 7" Intermediate 26 / L-80 / Btc-Mod 6.276 Surface 8,302 4-1/2 Slotted Liner A 12.6 / L-80 / IBT 3.958 7,936 11,009 4-1/2 Slotted Liner B 12.6 / L-80 / IBT 3.958 8,165 11,155 TUBING DETAIL 2-3/8 Tubing 4.6/ J-55/ SuperMax 1.995 Surface 7,650 4-1/2 Tubing 12.6 / L-80 / IBT 3.958 Surface 7,775 3-1/2" Tubing 9.3 / L-80 / EUE 8rd 2.992 7,775 7,838 JEWELRY DETAIL No Depth Item 1 7,628 Jet Pump Cavity and Retriever Assembly (Standing valve only 4-9-21) 30 bbls 2 7,631 Locator Seal Assembly 3 7,632 Seal Assembly Extension 4 7633 Seal Bore, 19 Long 5 7,646 Seal Units x 4 Bottom @ 7,650 6 7,650 WLEG Bottom @ 7,650.35 7 7,658 Packer, Paragon II (2.0 ID Bore) 8 7,692 WLEG 9 7,727 Phoenix Discharge Pressure Gauge 3.850 ID 10 7,738 HES 4.5 XD Dura Sliding Sleeve 11 7,758 Phoenix Sensor 4-1/2 Casing ID Change to 2.840 12 7,773 XO 4.512.6# NSCT Box x 3.5 NSCT Box 13 7,775 HSE 3.5 X-Nipple NSCT 14 7,786 Baker Premier Packer 7 x 3.5 15 7,833 HES 3.5 XN-Nipple 2.750 No Go 16 7,836 3.5 NSCT WLEG Bottom @ 7,837 17 7,936 Baker Hook Wall, Hanger above 7 Window 18 7,962 Baker Hook Wall, Hanger outside 7 Window 19 8,165 Baker Tie Back Sleeve 20 8,177 Baker ZXP Liner Top Packer 21 8,185 Baker 7 x 5 HMC Liner Hanger OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset (Approx) in 42 Hole 7 Cmt w/ 1,360 sx Class PF L, 650sx Glass G in 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 600 MD 70 to 73 Deg. 2,900 7,800 Max Hole Angle = 73 deg. @ 6,000 MD 72 Deg. @ Sliding Sleeve GENERAL WELL INFO API: 50-029-23084-00-00 Drilled and Completed by Doyon 141 - 15/28/2002 NOTE: Prior to setting or pulling 4.5 BPV or TWC, notify FMC. 4.5 TCII thread profile compatibility issue exists. LATERAL WINDOW DETAIL Window in 7 Casing @ 7,948 to 7,960 Well Angle @ Window =74 Deg. WELLHEAD Tree 4-1/165M FMC Wellhead 11 x 4.5 5M Gen. 6 w/ 4.5 TC-II T&B Tubing Hanger CIW H BPV Profile Hole New Tubing Head (Installed 2015) Tubing Hanger w/ 2-3/8 8RD Lift Threads TOC ~7400' MD Milne Point ASR Rig 1 BOPE 2025 Updated 7/31/2025 11 BOPE 4.48' 4.54' 2.00' INTEGRATED 4.30'INTEGRATED 11" - 5000 2-7/8" x 5" VBR Blind11'- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head STATE OF ALASKA ALL OIL AND GAS CONSERVATION COMIIION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations Li Fracture Stimulate u Pull Tubing Li Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ R&R Jet Pump s Plug for Redrill ❑ °rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ R&R Packer ❑., 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Developments Exploratory ❑ 202-085 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23084-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380109 MILNE PT UNIT SB S-27 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: JECEVFD orifIEC IVFD Total Depth measured 11,186 feet Plugs measured N/A true vertical 4,084 feet Junk measured N/A feet 'E j' 2 0 2f 1`, ^ Effective Depth measured 11,186 feet Packer measured 7,658&7,775' feet GCC true vertical 4,084 feet true vertical 3,968&4,004 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Production 8,302' 7" 8,302' 4,104' 7,240psi 5,410psi LinerA 3,073' 4-1/2" 11,009' 4,068' N/A N/A Liner 2,990' 4-1/2" 11,155' 4,081' N/A N/A Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2-3/8" 4.6#/J-55/Supermax 7,650' 3,966' 4-1/2" 12.6#/L-80/IBT 7,775' 4,004' Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80/EUE 8rd 7,838' 4,022' Paragon II& Packers and SSSV(type,measured and true vertical depth) Premier 7"x 3.5" N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A k;y N Q 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 0 0 Subsequent to operation: 190 13 556 740 238 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations s Exploratory El Developments Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL U Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-321 /� Contact Ted Kramer �, P4" Email tkramer(a�hilcorp.com Printed Name 'y� Bo York - , _,- Title Operations Engineer L Signature' i� G Phone 777-8345 Date Lio S C�1``` t. /04it" le Form 10-404 Revised 5/2015 RBDMS L ' SEP 2 2201iubmit Original Only 50 /oar/6 • Milne Point Unit Well: MPU S-27 ti • SCHEMATIC Last Completed: 7/20/2015 PTD: 202-085 Hamra Alaska,LLC NOTE: WELLHEAD Prior to setting or pulling 4.5"BPV or Tree 4-1/16"—5M FMC TWC,notify FMC.4.5"TCII thread 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Orig.DE Elev.=67.30'/Orig.GL Elev.=39.30' profile compatibility issue exists. Tubing Hanger CIW"H"BPV Profile Hole Wellhead New Tubing Head(Installed 2015) ?( k Tubing Hanger w/2-3/8"8RD Lift Threads 2(Tj , OPEN HOLE/CEMENT DETAIL 20" Cmt w/260 sx of Arcticset(Approx)in 42"Hole 7„ Cmt w/1,360 sx Class PF"L",650sx Glass"G"in 9-7/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 92/H-40 N/A Surface 112' 7" Intermediate 26/L-80/Btc-Mod 6.276 Surface 8,302' 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 7,936' 11,009' 4-1/2" Slotted Liner"B" 12.6/L-80/IBT 3.958 8,165' 11,155' TUBING DETAIL 2-3/8" Tubing 4.6/1-55/SuperMax 1.995 Surface 7,650' 4-1/2" Tubing 12.6/L-80/IBT 3.958 Surface 7,775' 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.992 7,775' 7,838' WELL INCLINATION DETAIL KOP@600'MD 70 to 73 Deg.2,900'—7,800' Max Hole Angle=73 deg. @ 6,000'MD 72 Deg.@ Sliding Sleeve 9 1 JEWELRY DETAIL 2 3 No Depth Item 4 1 7,628' Jet Pump Cavity and Retriever Assembly k 5 2 7,631' Locator Seal Assembly k 3 7,632' Seal Assembly Extension 4 7633' Seal Bore,19'Long 5 7,646' Seal Units x 4—Bottom @ 7,650' 6 6 7,650' WLEG—Bottom @ 7,650.35' 7 7,658' Packer,Paragon!!(2.0"ID Bore) 7 8 7,692' WLEG '1 i ' 9 7,727' Phoenix Discharge Pressure Gauge—3.850"ID 10 7,738' HES 4.5"'XD'Dura Sliding Sleeve 11 7,758' Phoenix Sensor 4-1/2"Casing—ID Change to 2.840" 8 12 7,773' XO 4.5"12.6#NSCT Box x 3.5"NSCT Box 13 7,775' HSE 3.5"X-Nipple NSCT •0• 9 14 7,786' Baker Premier Packer 7"x 3.5" t0 15 7,833' HES 3.5"XN-Nipple—2.750"No Go 11 16 7,836' 3.5"NSCT WLEG—Bottom @ 7,837' 12 17 7,936' Baker Hook Wall,Hanger above 7"Window — 18 7,962' Baker Hook Wall,Hanger outside 7"Window atxf sx 13 Fish:Aluminum Blowout 19 8,165' Baker Tie Back Sleeve 14 Plug—Lost 7/25/15.OD: 20 8,177' Baker ZXP Liner Top Packer 2.49"/Length:2.75"/Tag @ 15 7,732'SLM 21 8,185' Baker 7"x 5"HMC Liner Hanger LATERAL WINDOW DETAIL 16 Window in 7"Casing @ 7,948'to 7,960' NWell Angle @ Window=74 Deg. II GENERAL WELL INFO "ox Lateral API:50-029-23084-00-00 19 ' Drilled and Completed by Doyon 141 -15/28/2002 II "OB'Lateral 7 p TD=11,186'(MD)/TD=4,084'(TVD) PBTD=11,186'(MD)/PBTD=4,084'(TVD) Updated By:TDF 9/15/2016 • • . • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-27 ASR#1 50-029-23084-00-00 202-085 6/24/16 8/9/16 Daily Operations: r;i` tkkm I 6/22/2016-Wednesday No activity to report. 6/23/2016-Thursday No activity to report. 6/24/2016- Friday MIRU Set Matting Boards in Place, Install BPV, Haul Trailers Co man Shack&Change House, and ASR Rig, Pit Module, Catwalk, Pipe Racks, Well House, Rig Floor, Rig up Alaska Crane;Nipple down Tree, Check Lock down Screws for Travel & Hanger Threads ( Good) Nipple up Bop Stack and mud Cross Valves. Spot Pit Module, Rig Down Alaska Crane and Release, Hilcorp Electricians Disconnect electrical on well House S-26 Prep for Removal Unable to set ASR Rig well House over well do to S-26 Well House in the way. Continue to prep S-26 well house for removal. Take on Source water into pits (200 bbls). Pull well house off of S-26. Spot well cover over well. PU well cover and install VR plug in well head on lower annulus valve. Remove lower annulus valve and install flange and 2" bull plug(lower annulus valve sticking out too far to set well cover down).Spot& level well cover. Spot rig floor. Set mud boat in place. Back rig in and raise mast. Spot cat walk. Rig up hoses and lines. well support greasing BOP stack. Pull BPV. Install TWC. Well on slight vac. 6/25/2016-Saturday Service Rig, Check Fluid Levels. Rig up test equipment shell test Bop Equipment to 3,000psi. Check for Leaks (AOGCC Jeff Jones Waives Test @ 2110 hrs. on 6-24-16).Testing Bop,Test all valves & Rams to 250psi low/3,000psi high_Test Annular @ 250psi low/2,500psi high. (Johnny Hill with AOGCC witnessed Bop Test) Bump Test Gas alarms per AOGCC Rep. Well Head Rep Removed TWC Valve from Hanger. Made up Landing Joint RIH Make up into Hanger BOLDS, Pulled Hanger to the rig Floor @ 29k Break out Lay down Hanger and Landing Joint. Made up a Joint of 2-3/8" Super Max RIH to no/go on Seal Assembly at 24'ASR RKB 14.5 tubing Hanger& Pup Joint 4.5'. RIH W/Tubing&Seal Assembly into the PBR confirmed Space out had 5' stick up from original Space out to the top of the no/go to top of the PDR. TOOH Lay down 2-3/8" Super Max Tubing on Pipe Racks. Continue to POH Lay down 2-3/8" Super Max Tubing on Pipe Racks. Break off last joint of 2-3/8". LD XO's and seal assembly in one piece. LD total of 247 jts. Install BPV. Blow down all lines. Remove pipe racks. Electricians unhook alarms.4 bolt BOPE. Remove cat walk. Lower mast and move rig off of mats. Pull liner and save for reuse at A Pad. Transport rig to A Pad & lay containment while waiting on Roads & Pads to arrive at S Pad with crane. Remove rig floor w/ crane.Stairs& landing. Remove well cover. Remove BOPE. 6/26/2016-Sunday Nipple up 4-1/16" Double Valve Dry Tree (Northern Energy Service went through Hilcorp orientation with Thad Safety). Well Head Rep Removed BPV and installed TWC Valve. Fill Tree with Diesel test Tree and Void to 5,000 psi. Northern Energy Service Moved the ASR Equipment to A-Pad. Clean and Wash ASR Rig Floor, ASR Well House,ASR Rig, organize Tool Shed. 6/27/2016- Monday No activity to report. 6/28/2016-Tuesday No activity to report. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-27 ASR#1 50-029-23084-00-00 202-085 6/24/16 8/9/16 Daily,Operations: ya 7/13/2016-Wednesday No activity to report. 7/14/2016-Thursday RU SLB CTU 8. Start BOPE test. PT low 250, high 4,000 on all rams and valves. BOPE test complete. No failures. Stack down lubricator. Set down injector head. Change pack offs. Secure BOPE with night cap.All ground valves closed.SDFN. 7/15/2016- Friday Hold safety meeting. Discuss JSA and job procedure. Make up MHA. 2.12" OD Coil connector, 2.13" DFCV, 2.25" Hailey accelerator, 2.13" weight bar, 2.13" weight bar, 2.25" Hailey DAJ, 2.13" T1 hyd disco (9/16" ball). Pull test to 20k PT MHA to 250/3,500 psi. Bleed down install x-over ported sub to Sucker rod, SLJDC, 3.2" PIIP test tool. Stab on well. PT stack 250/3,500 psi. Open master swab and RIH. WT CHK 2500' 6,300 lbs, WT CHK 7500' 11.3K. Stack 2k down on packer at 7,667' CTMD. RIH wt was 2,000 lbs. Set down to-500 lbs. Stacked down to 5k. Online down CT at 1 bbl/min pressure up tubing to 2,500psi. Start 15 minute test 10:43 @ 2,555psi end at 10:58 @ 2,527psi. Good PT. Bleed down through choke. Attempt to pull off 11k normal OOH wt. PU to 21k wait for jars. No jars, PU to 25k. No jar fired. RIH and stack-5k attempt to reset jars. Wait 5 minutes. Pick up 25k. Wait 15 minutes no jar lick. RIH stack down 5k at 7,667'. Wait 8 minutes no down jar. Repeat. 13 attempts to set jars and hit up. 14th attempt started seeing small jar licks. Over pull to 28k Jars hit. Weight broke back to 11k. POOH to surface.Tagged up. Blow down. Pop off well. Missing two orings from PIIP test tool. Break down test tool and JDC. Install TTS PIIP retrieval tool. 3.67" OD.Stab on well. PT stack 250/3,500psi. Open master and swab. RIH. WT CHK @ 7,500'. 11k. Stack weigh at 7,682'. 3,200Ibs down. Plck up. Over pull to 18k, latched up. Pick up to 20k. Weight broke back to OOH wt at 11k. Looks like we pulled out of fishing neck. 3 more attempts. Keep pulling out of fishing neck. May not be getting all the way into fishing neck for the grapples to latch.Stack 10k down. Pick up. NO over pull. Pins sheared. POOH to surface.Tagged up. Pins confirmed sheared. Break down Packer retrieval tool.Tool hand head to shop to re pin. Stack down injector head. SDFN. Wellsite secure. • i Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-27 ASR#1 50-029-23084-00-00 202-085 6/24/16 8/9/16 Daily Operations., ,lfi 7/16/2016-Saturday Safety meeting. Make up BHA 2.12" cc, 2.13" DFCV, 2.25" Hailey Accel, 2.13" wt bar, 2.13" Wt bar, 2.25" Hailey DAJ, 2.13" hyd, disco (9/16" ball) Pressure test tools to 250/3,500psi. Make up 2" ported sub x over, 3.67" TTS PIIP retrieval tool. Stab on well. PT stack 250/3,500psi. Attempt to RIH.Tagging up at 13.1'.4 attempts. Decided to pop off and look at tool and see if sheer screws are worn. Master swab closed.Tool looks ok. Stab back on PT. stack 250/3,500psi. Open master swab. RIH. Saw bobble at 13.1". RIH. Wt chk at 7,500' 10k stack weight at 7,678' -8k down. Stack again to-10k down. Pick up before jars hit. 17k weight beak back to 10k. Looks like we pulled out of fishing neck. RIH at 80 ft/min stack down to-18k. Pull to 28k weight breaking back slower. Looks like we are moving packer. Shut down for 30 minutes. Let packer elements relax so we don't roll elements. RIH to see if we stack weight. Stacking at 6,933'. Looks like we have packer. POOH to surface. Tagged up. Fish on break down packer and pulling tool. Install new BHA. Same CC, DFCV, Hailey DAJ,TY DISCO, 2.13 Titon Motor, 2.63"VJB (venturi junk basket), 2.63"VBJ filter, 2.63"VJB finger cage, 2.72" burn shoe with cutter blades.Stab on well. PT stack 250/3,500psi. RIH wt check 7,500' 10k. Stack 3k at 7,758'. Pick up to 7,730'. Online down CT @ 1 bbl/min Circ pressure 3,500 psi. RIH, slow down to .3 ft/min at 7,755' lightly stack 1k down at 7,758'.Small increase in motor work. Stack 2k down. 350psi motor work. Pressure or weight not breaking back. Looks like we are spinning Plug.Slack off to-15k. No increase in motor work.Still have 250-300psi. Weight not breaking back.Shut down pump. Pick up to 7,720' Back online with pump at 1 bbl/min. RIH at 80 ft/min stack to -15k. Motor should have stalled. 3,800psi motor work. Spin on plug for 20 minutes. Nothing changing. Down on pump. Pick up to 7,720' RIH at 100 ft/min. Stack to-15k. Online with pump 1 bbl/min. Pressure breaking over. 400psi motor work. Let sit for 15 minutes. No change in weight or pressure. Feels like we are pulling plug into venturi face and then stacking down and spinning plug on tubing x over. Continute attempts to stall motor. Pick up and RIH stack max 15k. Attempt to RIH slow and mill. NO change. Plug is spinning. Decide to POOH while pumping max. POOH to surface while pumping at 1 bbl/min and 3,800psi. Hope aluminum plug is pulling against body of burn shoe. Tagged up at surface. Close swab valve.Shut down pump. Blow down stack. Pop off well. No plug inside venturi. one small piece of aluminium in screen sub. Look down BOPE and no indication of plug setting on swab vavle. burn aggressive marks on burn shoe. Dispatch N2 to blow down CT reel. Rig down BHA set down 2x10' lubricators. Stab on well. Blow down backside line pump iron. Rack back on CTU. Waiting on N2. N2 on location. Hold safety meeting with SLB N2 crew. Rig up N2. Cool down. PT N2 lines to 250/4,000psi. Open to CT blow 1,500 scf/min for 20 minutes. Isolate N2. RDMO N2 pump. CT bleeding off. Rig down CTU. Pull off and park unit on edge of pad. Crews will move to deadhorse in AM. Well site secure. 7/17/2016-Sunday No activity to report. 7/18/2016-Monday No activity to report. 7/19/2016-Tuesday No activity to report. 0 • II Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number _ Start Date End Date MP S-27 CTU 50-029-23084-00-00 202-085 6/24/16 8/9/16 Daily Operations: 7/27/2016-Wednesday No activity to report. 7/28/2016-Thursday No activity to report. 7/29/2016- Friday No activity to report. 7/30/2016 -Saturday No activity to report. 7/31/2016-Sunday No activity to report. 8/1/2016- Monday Safety Meeting. MIRU Halliburton CTU with 1.75" tapered .204" to .156" WT CT. Coil length = 18,450' CV= 35.47 bbls. MU CTC, stinger and nozzle for BOP test. Load coil with 1% KCL water. Stab on well. BOPE Test. Good Test. State waived witness of test. MU Statewide BHA: 2.38" OD CTC, PULL TEST to 5k, 15k, and 25K lbs. MU 2.12" DBPV, 2.25" DAJ, 2.12" TJ DISCONNECT(9/16" BALL), 2.12" WT BAR, 2.125" OD SLAMMER HAMMER, PT TO 250/3,500 PSI. MU 2.125" XO, 2.65"OD 5- BLADE CONCAVE JUNK MILL. OAL= 17.87' Stab on well. PT stack to 250/3,500 psi. CORRECT CT DEPTH TO KB = +5'. OPEN WELL TO 0 PSI WHP. RIH. WT CK'S AT 2,000' - 11.8k/5,100' - 15.3k/7,620' -21.8k. RU HALLIBURTON ACID EQUIP TAG AND SET DOWN 5K AT 7,780'. PU GET WT BACK AT 7,776'. OBSTRUCTION AT 7,776'. LAY IN 7.6 BBLS 15% HCL ACID ON TOP OF FISH. SOAK FOR 1 HR. RIH AND NOW TAG AT 7,825' UNABLE TO WORK FISH BELOW THIS DEPTH WITH SLAMMER HAMMER. CONTINUOUS STALLS. ATTEMPT TO JAR DOWN AND NO JAR ACTION SEEN. POOH WITH SLAMMER HAMMER. L/D HAMMER, MU 2.12" OD TITAN MOTOR AND 1.3" OD TO 2.3" OD TAPERED STEP MILL. NEW OAL= 27.46'. BACK ON WELL, PT TO 250/3,500 PSI. OPEN WELL AND RIH WITH MOTOR AND MILL. RIH. WT CK AT 7,600' - 17K. TAG AND SET DOWN 3K AT 7,833'. WT BACK AT 7,828'. START MILLING - FS= 1.3 BPM AT 2,900PSI. STALL OUT AT 7,831'. PU AND RBIH MILLING. ABLE TO WORK DOWN AND OUT THE TUBING TAIL TO 7,841'. BACKREAM TO 7,750'. DRY RUN DOWN TO 7,922'WITH NO RESTRICTIONS. POOH. POOH. PUMP 6 BBLS METHANOL DOWN TUBING FOR FREEZE PROTECT. TAG UP. SECURE WELL. STAND BACK INJECTOR AND BOPE. LAY DOWN TOOLS. INSTALL NIGHT CAP ON WELL. FINISHED FOR DAY. RETURN IN MORNING TO RD. 8/2/2016-Tuesday RDMO Halliburton CTU. • s • II Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number _ Start Date End Date MP S-27 ASR#1 50-029-23084-00-00 202-085 6/24/16 8/9/16 Daily Operations: 8/3/2016-Wednesday No activity to report. 8/4/2016-Thursday MEET WITH CO MAN (LINDER) FOR PAPERWORK AND JOB SCOPE. SPOT EQUIPMENT, LAY DOWN PCE,TOOLS,AND NON- MOBILE. RIG UP PCS, TOOLS, FUNCTION TEST TOOLS, STAB ONTO WELL. Pressure test Lubricator 500psi low/3,000 psi high." OPEN SWAB, RIH WITH CALIPER TOOL. VEL/ ROLLER/5WT/ ROLLER/7WT/7WT/ ROLLER/TTTCU/AUH/ PKJ/QPC/ PKJ/CENT/ MIT/CENT.TOOL LENGTH 48.5'TOOL OD 3.125" TOOL WEIGHT 465 LBS" AT TD. LOG REPEAT AND MAIN CALIPER PASS FROM 7,740'TO SURFACE.TOOLS AT SURFACE. CLOSE SWAB. BLEED DOWN, BREAK OFF LUBE AND BREAK DOWN CALIPER TOOLS. RIG UP PACKER RUN. PT QTS, PT PASS, OPEN SWAB. BEGIN RIH WITH PACKER ASSEMBLY. ON BOTTOM, CORRELATE PACKER ON DEPTH. UNABLE TO FALL DOWN PAST 7,727' NIPPLE. PKR SET AT 7,658', CCL TO MID ELEMENT 15.75', CCL STOP DEPTH 7,642.25' BUMP UP, BLEED PRESSURE, BLOW DOWN LINES, RIG DOWN PCE/TOOLSTRING, LAYDOWN LUBE, LOAD EQUIPMENT, INSPECT LOCATION. 8/5/2016- Friday CHECK IN W/CO REP, P/U LUB TRAILER FROM A-PAD,TRAVEL TO LOC.AOL, CONTACT PAD OP,JSSM, MISU,JSA, LIFT PLAN, MOVE SUPPORT EQUIP, WELL S/I ON ARRIVAL. BEGIN R/U, REPACK STUFFING BOX, C/O STEM, CHECK PINS, .125" CARBON (23 turns),TS=1.75" RS,QC,8'x2-1/8" R-STEM (2.62" whls),QC,OJ,QC,KN,LSS, QC= 300.5"/25.04' OF 60/40, TO TEST PACKER, UNABLE TO GET TEST,TBG PSI DROPS OFF TO Opsi, 4 OJ LICKS @ 1300#s, PULL TEST TOOT. POOH. OOH, SIBD, HAVE TEST TOOL, TEST TOOL MISSING BALL(cause for not pressuring up), STAB ON WELL&SECURE, STANDBY FOR STATEWIDE TO BRING BALL& REDRESS KIT. STATEWIDE ON LOC, REDRESS PIIP ISO VLV TEST TOOL, ADD BALL, ADD QC,KN,5' x 2-1/8" R-STEM (2.62" whls). OOH, SIBD, HAVE SHEARED TEST TOOL, ADD 20' RISER, C/O BHA. P/T TO 250/3,500 PSI, RIH W/4-1/2" GS SETTING TOOL(1/2 brass), 4-1/2" SEAL BORE EXTENSION (21.34'), S/D @ 7,462' SLM, LRS R/U & PUMP 41BBLs OF PRODUCED WATER TO ASSIST US DOWN HOLE, S/D @ 7,610' SLM /7,637' MD, GOOD 500#. OVERPULL, POOR ACTION, HAVE LRS ROLL PUMP TO ASSIST SHEARING,AFTER 30min OF JARRING, SHEAR OFF & LOSE 400#. POOH. OOH, SIBD, NO SEAL BORE EXTENSION, GS SHEARED, BEGIN R/D R/D COMPLETE,TREE CAP ON &TESTED, CLEAN TOOLS, PAD OP NOTIFIED, PARK UNIT @ Y,TRAVEL TO CAMP. 8/6/2016-Saturday No activity to report. 8/7/2016-Sunday Installed VBR Plug in Annulus Valve, (Notified AOGCC of right to witness BOP Test @ 07:12 AM on 8-7-2016). Well Head Rep Tee Bar TWC Valve in Tubing Hanger. Nipple Down Tree, Nipple up 7" Bop Stack,Torqued up Flanges. Barge Arrived at F-Pad at 20:00 hrs. Unloaded pits, 13-5/8" Bop Equipment onto Flat Bed Truck, Unloaded Tool pusher Shack, Cat Walk and Pipe Racks,Tool Conex and Parts House, Hauled to S-Pad, Hauled Change House and Co. man Shack, From A-Pad to S-Pad (Barge Headed back to North Star Island at 22:30 hrs.) Spotted Mud Boat, Pits, Cat Walk,Tool Pusher Trailer, Co. man and Change House Trailer, Hauled and Unloaded 13-5/8" Bop Equipment at A-Pad, Nipple up Bop Flanges on Wing Valves Kill and Choke. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-27 ASR#1 50-029-23084-00-00 202-085 6/24/16 8/9/16 Daily Operations. 8/8/2016- Monday Continue barging Rig Equipment from North Star Island to Milne Point F-Pad. Offload Barge at MPF-Pad,Transport Rig Equipment from F-Pad to MPS-27.;Set Well Cover on S-27, Set Rig Floor. Raise Derrick, Rig up Rig floor, Install connections for gas alarms&test same. Held Safety Meeting and Review S-27 Sundry with all Crew Members. Connect BOP Hydraulic Hoses from koomey House to Bop Stack, Realign Cat walk to Rig Floor, Connect Kill and Choke Lines to Rig and Cellar area. Rig up Test Equipment Body Tested all Connections to 2,500psi (Good Test)AOGCC was Notified @ 22:28 hrs.Jeff Jones Waived witness of Test @ 22:30 hrs.)Tested Bop 250 Low/3,000 High 5 Min each Tested Annular 250/2,500psi. 5Min each, Tested with 2-3/8"Test Joint,Tested Accumulator,All gas Detectors were tested good. Remove TWC Valve from Tubing Hanger. Pick up & Make up Seal Assembly on 2.375 Super Max Completion Tubing.TIH with 2.375 Super Max Completion Pipe. 8/9/2016-Tuesday Continue to TIH with Completion, picking up 2-3/8" Supermax Tubing. No Go with Seal Assembly to 7,650',Space out with Pups joints, make up hanger& landing Joint, land Tubing Hanger, RILDS. PJSM, Pressure up with Little Red Services to 1,500 psi. and hold for 15 minutes to verify seal assembly space out is correct. (Good Test) Bleed Pressure off& Rig down little Red Services. Set BPV. Blow lines down & Prep for Rigging down. Break over Lower Derrick, Electricians Disconnected Gas and Fire Alarms;Nipple Down 7-1/16" BOP to Four Bolts, Roads and Pads Hauled Mud Boat Pit Module, Pipe Racks Cat Walk,to K=Pad, Crane Operator Removed Rig Floor&Well House, Remove BOP, Loaded on Flat Bed Truck, Install Production Tree and Nipple up. vOF Ty • • g ��\ I%%y ,,, THE STATE Alaska Oil and Gas • ,-� �a OfA LAsKA Conservation Commission f etx-:_4. -- 333 West Seventh Avenue �" `' C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 * Main: 907.279.1433 0,A, 7s--.0,- Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC �E® JAN0 9 ZJ17 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, SB S-27 Permit to Drill Number: 202-085 Sundry Number: 316-321 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a1/4i'glE41(. Cathy . Foerster Chair DATED this day of June, 2016. RBDMS L,L.-JON 1 3 2016 • • : L. ,t....„ 4.. .0. T %we..1/240 STATE OF ALASKA JUN 0 7 /2Q 16 ALASKA OIL AND GAS CONSERVATION COMMISSION QTS 71/e. APPLICATION FOR SUNDRY APPROVALS " OG CC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other.Remove and Replace Packer0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Ter p,,c-tvt P Hilcorp Alaska,LLC Exploratory 0 Development 0 y 202-085 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23084-00-00 ,, 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05 Will planned perforations require a spacing exception? Yes 0 No ❑., MILNE PT UNIT SB S-27 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380109 • MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,186' - - 4,084' . 11,186' • 4,084' 1,180 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Production 8,302' 7" 8,302' 4,104' 7,240psi 5,410psi Liner A 3,073' 4-1/2" 11,009' 4,068' N/A N/A Liner B 2,990' 4-1/2" 11,155' 4,081' N/A N/A Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2-3/8" 4.6#/J-55/Supermax 3,980' 4-1/2" 12.6#/L-80/IBT 7,775' See Attached Schematic % See Attached Schematic 3-1/2" 9.2#/L-80/NSCT 7,838' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"x 3.5"Packer and N/A , 7,786'(MD)/4,008'(TVD)and N/A 12.Attachments: Proposal Summary 0 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0- Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 6/20/2016 Commencing Operations: OIL 0- WINJ 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved 1 yr,./ herein will not be deviated from without prior written approval. Contact Ted Kramer '" Email tkramere hilcorr.com Printed Name Bo York Title Operations Manager C SignaturePhone 777-8345 Date 6/6/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. -.- \(siz _ 2 /�t Plug Integrity ❑ BOP Test V Mechanical Integrity Test 0 Location Clearance 0 `] Other: 1 30005:. .6c5 .-7-- c_.. 14-- Post f , *-- Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS fit- JUN 1 3 2016 Spacing Exception Required? Yes 0 No U Subsequent Form Required: ! 0--y 0 APPROVED BY Approved by: COMMISSIONER TH�ECOMMISSION Date: 6_,_ /� f ^� A Form 10-403 Revised 11/2015 WI aCaitb is valid for 12 months from tfj d to of approval. �'� Attachments in Duplicate • Well Prognosis • Well: MPS-27 Mean)Alaska.LL' Date: 6/6/2016 Well Name: MPS-27 API Number: 50-029-23084-00 Current Status: SI Producer Pad: S Pad Estimated Start Date: June 20, 2016 Rig: ASR# 1 Reg.Approval Req'd? Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-085 First Call Engineer: Ted Kramer (907)-777-8420 (0) (985)-867-0665 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 1,180 psi @ 3,999' TVD (Gauge) / Maximum Expected BHP: 1,180 psi @ 3,999' TVD (No perforating or cleanout planned)/ Max. Allowable Surface Pressure: 1062 psi (Assuming a .1 psi/ft. gas gradient) Brief Well Summary: The Milne Point S-27 well is a jet pump producer that recently quit surfacing reservoir fluid. Slick line diagnostics indicated that the well would not pass a pressure test after replacing the standing valve. The diagnostics indicate that there is a problem with either the seal bore or the elements of the packer. This well was passed a 4-1/2"X 7" pressure test to 4,200 psi in May 2013. RWO Objective: /"t -r This workover will involve pulling the 2-3/8" tubing inner string to perform diagnostics on the packer without the seals in place. If these diagnostics determine the packer is faulty, Hilcorp plans to pull and run a new packer. 1 h.n.tti f This sundry is written to pull and replace the packer. As stated, we will be running diagnostics with slick line along the way. If the diagnostics indicate faulty components along the way, Hilcorp may elect to replace only those components and return the well to production short of replacing the packer. Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and contaipment,t‘1z` , 2. RU Slick Line and pull th- . : •: :. : • • es. RDMO Slick Line. 3. RD well house and flowlines. Clear and level area around well. 4. RU Little Red Services and 500bbl returns tank with choke manifold. 5. Pressure test lines to 3,000psi. 6. Circulate at least one wellbore volume with 8.5 ppg sea water down tuing,taking returns up casing to 500bbl returns tank. .14 % 7. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 8. RD Little Red Services. 2,. 9. Set BPV. RU crane. ND Tree. NU 7-1/8" BOPE. RD Crane. • • HWell Prognosis Well: MPS-27 IIilcorp Alaska.LL Date:6/6/2016 10. NU BOPE house. Spot mud boat. WO Rig Procedure: 11. MIRU ASR# 1 Rig, ancillary equipment and lines to 500 bbl returns tank. 12. Check for pressure and if Opsi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5ppg seawater prior to pulling BPV. Set TWC. a. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each 60e6 ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. b. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. c. Notify AOGCC 24 hrs in advance of BOP test. d. Test rams on 2-3/8"test joint. e. Send BOP test report in to AOGCC within 5 days. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz(AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure C-/ c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500bbI returns tank. Pull TWC. Kill well w/8.5 ppg seawater as needed. 15. If able to circulate well, mix and pump caustic soda pill (-5 Ib/bbl) ahead of Baraklean pill (^'4 gal/bbl)to clean oil of tubulars. Displace with 8.5 ppg seawater. 16. PU landing joint and BOLDS. 3/�„ y G �,,_� S~ ^7/)COO I Ss 47 17. Pull over string weight on tubing hanger to confirm free . LD tubing hanger. PU additional joint(s)1 of 2-3/8" tubing and lower tubing into PBR to confirm we are inside of PBR. Record distance to bottoming out on no go. Confirm that the original space out was correct. 18. POOH with 2-3/8"Tubing,jet pump cavity and seals. 19. RU Slick line. RIH with slick-line, wt. bars spang jars and 4" GS spear. Note and record T.D. and any tight spots in the tubing. Latch into seal bore extension fishing neck and jar up to release anchor latch. POOH noting any tight spots. (Note: The shear screws are set to release at+/-5,620#.) Contingency: If unable to shear the set screws with Slick line,the alternative is to pick up the 2- 3/8" work string and pull the PBR on Tubing. • H • •• Well Prognosis • Well: MPS-27 Hiborp Alaska.Lb Date:6/6/2016 20. RIH hole with the following Slick Line bottom hole assembly: OD ID LENGTH DEPTH (Feet) (Feet) Top of RBP A 4-1/2" 10.5#-15.1# PIIP Anchor Latch Test Plug 3.650 //////// 2.58 (Pinned up to 4,200#; canned be pinned up to 21,000#) B 3" JDC Running Tool 2.750 //////// 1.50 C Spang Jars N/A N/A 5.00 Total BHA Length 21. TIH to the top of the packer. 22. Tag top of packer, tap down lightly to engage and latch collet and seals into packer. P/U 500 lbs. over pull to verify latch. Jar down on JDC running tool to release from test plug. POOH 23. Pressure Test as per Hilcorp procedure. If leak-off is present, isolate surface equipment. 24. After test is complete, R/U Slick line and RIH w/3"JDS pulling tool to latch top of test plug. P/U 500 lbs. over pull to verify latch.Jar up to open equalizing ports(pinned to 1,600 lbs. to equalize). Allow 15-30 minutes to equalize then continue to jar up to release Test plug from Packer(pinned up to 4,200 lbs. -21,000lbs. to release). POOH. 25. If test fails, prepare to pull 4-1/2" Paragon packer. 26. RIH with slick-line,wt. bars, spang jars, and 3.660"TTS buttress pulling tool. 27. Locate pulling tool on fishing neck of lower packer,jar-up to unset packer. (Note: Packer is pinned to release @ ±7,200# .) Once packer has sheared and stroked into the release position, shut down for 1 hour to allow the packer elements to relax.After waiting, proceed in pulling assembly out the hole. Note: Watch carefully while POOH. Utilize jars if needed during fishing operations. POOH. Contingency: : If unable to shear the set screws with Slick line,the alternative is to pick up the 2-3/8" work string and pull the Packer on Tubing. 28. Pickup RIH with junk basket or Venturi and 1-1/2" BHA on 2-3/8" WS to 7845'to insure that the tubing is clear. POOH with Same. Contingency: If unable to grab with the junk basket or venture basket,then we will mill out with a motor and mill. 29. RU E-line. PU RIH with new 4-1/2" packer @ 7,684+/-. Pressure test same to 500 psi. 30. PU RIH with seals, and jet pump cavity on 2-3/8"tubing. Land seals in packer. 31. Space out seals, 32. Install tubing hanger. Set BPV. ND BOP, NU Wellhead and test same. 33. RDMO ASR# 1 rig. (Oa- /h 34. Turn well over to production. ,circa s"Ei Pit" Well Prognosis • Well: MPS-27 Hilcorp Alaska,LLi Date: 6/6/2016 Attachments: 1. As-built Schematic 2. BOP Schematic 3. Fluid Flow diagram—Forward 4. Fluid Flow Diagram—Reverse 5. Fluid Flow Diagram—Bleed to Pits 6. Blank Procedure Change Form • 410 Milne Point Unit II Well: MPU S-27 SCHEMATIC Last Copleted: 7/20/2015 IIlikarp Alaska,LLC PTD: 202m085 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.DF Elev.=67.30'/Orig.GL Elev.=39.30 20" Conductor 92/H-40 N/A Surface 112' 7" Intermediate 26/L-80/Btc-Mod 6.276 Surface 8,302' 1 L 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 7,936' 11,009' 20 R 4-1/2" Slotted Liner"B" 12.6/L-80/IBT 3.958 8,165' 11,155' TUBING DETAIL 2-3/8" Tubing 4.6/J-55/SuperMax 1.995 Surface 7,692' 4-1/2" Tubing 12.6/L-80/IBT 3.958 Surface 7,775' r 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.992 7,775' 7,838' 4, JEWELRY DETAIL 1 1 No Depth Item 1 2,185' Camco 4.5"x 1"KGB-2 GLM w/RP valve BK Latch 2 7,656' Jet Pump Cavity and Retriever Assembly(Ran 7/25/15) 3 7,657' XO 2-3/8"Supermax x 2-3/8"8RD 4 7,661' Locator Seal Assembly(Spaced out 3.46'above Sealbore) 5 7,665' Sealbore,20'Long 6 7,686' Anchor Latch 7 7,688' Packer,Paragon II(2.0"ID Bore) 8 7,692' WLEG 9 7,727' Phoenix Discharge Pressure Gauge—3.850"ID ii 10 7,738' HES 4.5"'XD'Dura Sliding Sleeve C/a' 0.10 11 7,758' Phoenix Sensor 4-1/2"Casing—ID Change to 2.840" !ti 9 2 12 7,773' XO 4.5"12.6#NSCT Box x 3.5"NSCT Box 11 3 13 7,775' HSE 3.5"X-Nipple NSCT 14 7,786' Baker Premier Packer 7"x 3.5" 15 7,833' HES 3.5"XN-Nipple—2.750"No Go 16 7,836' 3.5"NSCT WLEG—Bottom @ 7,837' --^) 4 17 7,936' Baker Hook Wall,Hanger above 7"Window 18 7,962' Baker Hook Wall,Hanger outside 7"Window z� 5 19 8,165' Baker Tie Back Sleeve 20 8,177' Baker ZXP Liner Top Packer 21 8,185' Baker 7"x 5"HMC Liner Hanger ' s LATERAL WINDOW DETAIL OPEN HOLE/CEMENT DETAIL Window in 7"Casing @ 7,948'to 7,960' 20" Cmt w/260 sx of Arcticset(Approx)in 42"Hole itl 7 Well Angle @ Window=74 Deg. 7, Cmt w/1,360 sx Class PF"L",650sx Glass"G"in I=.B WELL INCLINATION DETAIL 9-7/8"Hole 8 , KOP @ 600'MD WELLHEAD 70 to 73 Deg.2,900'—7,800' Tree 4-1/16"—5M FMC 9 Max Hole Angle=73 deg. @ 6,000'MD 11"x 4.5"5M Gen.6 w/4.5"TC-IIT&B §� 72 Deg.@Sliding Sleeve Wellhead Tubing Hanger CIW"H"BPV Profile Hole b 10New Tubing Head(Installed 2015) \ 11 Tubing Hanger w/2-3/8"8RD Lift Threads FII12 , 13 GENERAL WELL INFO _MI, 14 API:50-029-23084-00-00 _.a* ,' Drilled and Completed by Doyon 141 -15/28/2002 "r"15 Fish:Aluminum Blowout Plug—Lost 7/25/15 NOTE: 117 OD:2.49"/Length:2.75"/Tag @ 7,732'SLM Prior to setting or pulling 4.5"BPV or TWC,notify FMC. 4.5"TCII thread profile compatibility issue exists. :+18 'ON Lateral 19' ..p ' 20 1 1 "OB"Lateral 7" _ TD=11,186'(MD)/TD=4,084'(TVD) PBTD=11,186'(MD)/PBTD=4,084'(TVD) Downhole Revised:7/25/2015 Updated By:TDF 5/24/2016 0 • Milne Point • flMime ASR Rig 1 7-1/16" BOPE: S-27 Ifilenrp tla.ka...LTA 7-1/16" BOPE 41111111 Stripping Head !hail iii III lit iii In II 2.57' ., S . et 7 1/165000 ° Iii ill iii Iii I I I MUIMULLM.11- 11111) Ifl 111 III AMONW- 'IMMO' _ 2 3/8-3%variable 70 . drilla', e."- CAMERON Wm _ 3.68' 09* 4111111; r--- * MP" MIA WEE Blind comilel 7 1/16 5000 mint 04 I' 1 il•ii r., 0 \ 6 l , / Vil film ft-fl , 2 1 16 5M Kill Line Valves . 2 1/16 5M Choke Line Valves tll i Ai - IOC -i - - - 1.56' , 11 ,, ...: i t , . • : k* t Y )0 1,-3.•. .e4 -0. -Ai . 7 1/16 5000 c ,0 1.. ortk '41,E-Verlit't 11,74E i .l'il ' ' ILA: t;IF. 4 E 1q ( t i i i liiimaildiikiii — - Manual Manual 4141.P.. Manual HCR Updated 6/06/2016 MPS-27 7-20-15 • • 2 9/16" tree w/ 2 3/8" Tbg Hgr. Prepped for 2" ,,, ,,, "H" BPV.Sits on 11 x 4 5K � ; FMC adapter. "`pm ill 0Swab valve Cameron 0 0 ''' FL-2 9/16" 5K, manual gate o0 0-‘0 valve, EE PSL2,PR2 "`11111111"'� PI 441232-31-07-02 7y� 0. Tbg Spool o1s'' 0� 10 k-'" 2ea-Wing valve Cameron Seaboard, SM-E-CL.4 1/8" 5K r ; 6,.. _C) -4)11O - l� >. ,, / FL-2 9/16" 5K, manual gate x 4 1/8" 5K. With 2ea 2 1/16" ,`, � C"— valve, EE PSL2,PR2 5K Annulus. 7, —°` 7. PN 441232-31-07-02 2ea. WHD 0 0 0 , PN 564630-DPQ 0 C o'=0 0 0 Master Cameron FL-2 9 16" DD-NI PSL@, PR1 / "`ems" ��° 5K, manual gate valve, EE PN W11795-003 - SN — PSL2,PR2 PN 441222-31-07- IIIMMIP -, 02 of p, ® o' O Tbg Hgr o `o i g N Tbg Hd adapter Seaboard, 4 ® �'. di I q o.� 1, 1/8" x 2 9/16" 5K, Centered. Seaboard, SM-E-CL. 2 3/8" _ o b ,*, g ,i .ti EUE top x Bot w/ 2 3/8" EUE "' @® Bottom prepped for Tbg HGr ■ x NUE pup. Prepped for 2" ` °° neck PN A26476-003 "H" BPV PN A29348-005 S��� SN /' in I .--. IN ":1 PD ape"' .... lg 4 on 1 1': IE l 1 ® . IO O 0 111 L;+ 1!1 III un 21 IZ/ , o o i I Mill 1®04YD1111 iorn-J-, - — M \L ,O,- - - L • • ;tet ® 1E E 's° CC Sf R 7 h) o > .' Q V o; U a U > o 0 7 ° m o ° 7 c Cr. > 0.1 .- W W -4 IXgri'll® m R RR 2S 9 0 Doo D04o> > w O u T7 T7 z >> O . Lo ❑ a z 13 6) TO VD J- 3 YM u.. m2 A (7 Y V. O = V m d V m m O m N tom < 0) u'''.1. TTal C M cuC t ro .'g C aD 0 o 4 Q v A c o v L.. 1 V . N c ._ i- a = o > Co ,T.:Al m �— V c i I' r. VI! _I o uignl i II, Ili i I � El MIN= Y a za a 1111''y H z 0 0 N co - co O coL A -Dm Q--C H I H ce Y Q co O Y$ a ,n l7 E _ --Doi—Dom • ,sr 9N Y H Y 1S Y R M I ®E § l� w -I I— r m a t- Lo a H 2 x m a vl p Y a D T — H I--- a Y1 � o — M • • b > `i' S C.) fj u U L L A r= 74 �. R m a, 2S § 111414 D04 -o > o Oil 9U w 2 v > > V R Ca c 7 T ,,.-2 _� J Z a' 0 > ,-C �• .§ Y W a Y Z Z V i C7 > y a) O y Q Q Q r•. ...pQu W O `° - L ~ bU m _, w > C7 W d ... l7 Z m u• 6) IU t9 m Y V. = V ppp ""l 2 m d V CO m O O m C. m Q g3NY V N C UU N - J @ N a 0 r A 00 cu z = > W 1 V e L. L — v < Nuignl 9—I ., o. -- tn Y o .J 2 k D V 0 C m m O m i, C 7J WH H H K H CO y 0 CO O 4 Y Q N I Z —001 --D�--DOo-- Y 9N Y H I— Y W v, r m a r z m a H F— z a Qiikl- 2 T - —II- a C a• • _ o V z LLu U Y . • 0 • - E 4t m <I I E E Psi t -k 7• 2 .-- -1.• E.EL" •E ..,,, a., > ',5" ... ••11 .41 I X g 13-2110 co § § 0 01) 913 o o, ,. Tt C g, a, _, fri rj 0 z Ir .-,-,• 4 c7.: 0 Tu ,..,' 1.-- p, _ -,• , x up kJ•E a) tij °>' >o '-U g ..... z < < 2 -,.. 0... ..•.),• 1.•. 6) T 3 Da _, z ll) Z3 Lo• O VD v, 0 0 o .. •U ,• 2 U . c. c. .., .. 0 o co o Vio Lr, o o < 8D Ln IN• ,--1• U. il a) ...1 a) ).C2 CO O. C n a., _. o = L.) 0 m — ' a Z OA ra 0) 1.•• :u iti n i : i I Ir r II *a •• ,-, - a• Z , vi --F-' °. — & V < )-- v) L., z ,..2. 1 :-, r 7 u a.) -, = co 'L co o co ...ill 'C' a) I —I I > cc i— ce6_ H H 7 x co < L.r) F- 2 c'zill il a v, L.L. 0 E -Docl- g 1 9>I§.1 1..1.1 041.1 HI— HF cc c_ vn 0 < 7 fikE 2 I -N- --N— —N- -I I- ocsa.. C-- g a . C16 V . .2 =g 4 1." :••L .4. . 0 0 a - 0 / ƒ 2 ® 0 al f / Oo2 .E 7 2 k 2 § ° « — Ea G 0 . TS U) 00 stTo d f § f k- \ E � i ,_ .- \ e = o \ / \ f...X OS" 0. 5 I 2 Ca ±Cr C0 § » ■ a) / C k k CD m Co / E L » ka CD _ak C.) IN- > \ a) U) p2 o 2 kf / 14 = / \ a) -00 -a 13 OO S C 2 cp a)2 E § a_ = G o O 2 0 •.R O 0_ / = k § 2 § § .r \ 2 / a) 2 / 0 C I t $ ,0 u) 2 § � % g / Ct Q. m < $ § a) 0 . a k 0 � -o Cl E 0 cA C Q e x 2 I- CU 2 / \ § a) a) 0 \ 0 CL, CD / a 2 2 © � \ U g > - . 2 > 2 a) 1 f 0 3 / \CO < I - STATE OF ALASKA A OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations ❑ Fracture Stimulate U Pull Tubing U Operations shutdown H Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well Q Re-enter Susp Well❑ Other: Install Jet Pump ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development❑., Exploratory ❑ 202-085 ' 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23084-00-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380109 ' MILNE PT UNIT SB S-27 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: RECEIVED Total Depth measured 11,186 * feet Plugs measured N/A feet SEP 2 5 2015 true vertical 4,084 • feet Junk measured N/A feet Effective Depth measured 11,186 feet Packer measured 7,786 feet AOGCC true vertical 4,084 feet true vertical 4,008 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Production 8,302' 7" 8,302' 4,104' 7,240psi 5,410psi LinerA 3,073' 4-1/2" 11,009' 4,068' N/A N/A Liner 2,990' 4-1/2" 11,155' 4,081' N/A N/A Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet 2-3/8" 4.6#/J-55/Supermax 7,692' 3,980' 4-1/2" 12.6#/L-80/IBT 7,775' 4,004' Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80/EUE 8rd 7,838' 4,022' Packers and SSSV(type,measured and true vertical depth) Premier 7"x 3.5" N/A 7,786'/4,008 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 0 4 Subsequent to operation: 332 20 74 3,217 231 14.Attachments(required per 20 AAC 25.070.,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑., Exploratory❑ Development L.../.1 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-297 Contact Stan Porhola Email sporhola ac hilcorp.com Printed Name Stan Porhola Title Operations Engineer I Signature , i Phone 777-8412 Date 9/25/2015 j0./4tf,i� Form 10-404 Revised 5/2015 .�p 0/‘67(5. -RBDMS /SEP 2 9 2015 Submit Original Only .II • Milne Point Unit ,.. Well: MPU S-27 SCHEMATIC Last Completed: 7/20/2015 tiifcorp Alaska,LLC PTD: 202-085 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.DF Elev.=67.30'/Orig.GL Elev.=39.30 20" Conductor 92/H-40 • N/A Surface 112' 7" _ Intermediate 26/L-80/Btc-Mod 6.276 Surface 8,302' 44-1/2" Slotted Liner"A" 12.6/L-80/MT 3.958 7,936' 11,009' IFS' 4-1/2" Slotted Liner"B" 12.6/L-80/IBT 3.958 8,165' 11,155' TUBING DETAIL 2-3/8" Tubing 4.6/1-55/SuperMax 1.995 Surface 7,692' 4-1/2" Tubing _ 12.6/L-80/IBT 3.958 Surface 7,775' 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.992 7,775' 7,838' JEWELRY DETAIL 1 No Depth Item kvy 1 2,185' Camco 4.5"x 1"KGB-2 GLM w/RP valve BK Latch 3, ti _ d 2 7,656' Jet Pump and Retriever Assembly(Ron 7/15/15) 3 7,657' XO 2-3/8"Supermax x 2-3/8"8RD u 4 7,659' Jet Pump BHA `�iwl k n'l1 5432 7777::666655560,976:' ,660 Standing Valve(Set 7/25/15;7632'Stn�) ,/ k 6 7,661' Locator Seal Assembly(Spaced out 3.46'above Sealbore) J •,,-, „� 7 7,665' Sealbore,20'Long L 8 7,686' Anchor Latch / 9 7,688' Packer,Paragon II(2.0"ID Bore) ✓ 10 7,692' WLEG 11 7,727' Phoenix Discharge Pressure Gauge—3.850"ID (i! 2 12 7,738' HES 4.5"'XD'Dura Sliding Sleeve 3 13 7,758' Phoenix Sensor 4-1/2"Casing—ID Change to 2.840" 1 14 7,773' XO 4.5"12.6#NSCT Box x 3.5"NSCT Box i ;; 4 15 7,775' HSE 3.5"X-Nipple NSCT • 5 16 7,786' Baker Premier Packer 7"x 3.5" * ;,; 17 7,833' HES 3.5"XN-Nipple—2.750"No Go f 6 18 7,836' 3.5"NSCT WLEG—Bottom @ 7,837' 19 7,936' Baker Hook Wall,Hanger above 7"Window 7 20 7,962' Baker Hook Wall,Hanger outside 7"Window 21 8,165' Baker Tie Back Sleeve 22 8,177' Baker ZXP Liner Top Packer IL"i 8 23 8,185' Baker 7"x 5"HMC Liner Hanger 9 LATERAL WINDOW DETAIL OPEN HOLE/CEMENT DETAIL Q .' Window in 7"Casing @ 7,948'to 7,960' 20' Cmt w/260 sx of Arcticset(Approx)in 42"Hole ` r z. 10 a Well Angle @ Window=74 Deg. Cmt w/1,360 sx Class PF"L",650sx Glass"G"in 4 r, 7„ 9-7/8"Hole i 11 ma .74WELL INCLINATION DETAIL WELLHEAD '4 •I• x`12 i, KOP @ 600'MD Tree 4-1/16"-5M FMC I.k i 13 70 to 73 Deg.2,900'—7,800' 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B IA 'r ' 14 Max Hole Angle=73 deg. @ 6,000'MD Wellhead Tubing Hanger CIW"H"BPV Profile Hole 15 New Tubing Head(Installed 2015) 4%, -B 72 Deg.@Sliding Sleeve V> '* ' 16 Tubing Hanger w/2-3/8"8RD Lift Threads .i 0 17 Fish:Aluminum Blowout Plug—Lost 7/25/15 OD:2.49"/Length:2.75"/Tag @ 7,732'SLM GENERAL WELL INFO 18 ii 0 API:50-029-23084-00-00 Drilled and Completed by Doyon 141 -15/28/2002 19 t20 NOTE: Prior to setting or pulling 4.5"BPV or TWC,notify FMC. Ni "0 Lateral 4.5"TCII thread profile compatibility issue exists. 21 t 22; 7" \ No TD=11,186'(NID)/TD=4,084'(TVD) PBTD=11,186'(ND)/PBTD=4,084'(TVD) Downhole Revised:7/25/2015 Updated By:STP 7/28/2015 Hilcorp Alaska, LLC 1,i,,.,,,.,> 1,,A:,.1,u Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP S-27 50-029-23084-00-00 202-085 6/9/2015 7/20/2015 Daily Operations: 6/10/15-Wednesday No operations to report. 6/11/15-Thursday No operations to report. 6/12/15-Friday No operations to report. 6/13/15-Saturday No operations to report. 6/14/15-Sunday Rig Up E line and lubricator with grease injection and wireline valves. PT lubricator to 2,000psi. RIH and correlate to GLM and pups @ 2,192'. RIH and set packer @ 7,687'WLM. 6/15/15-Monday RU slickline. PU MU PBR 19' on slickline.TIH and latch into packer @ 7,687'.Snap in and test to 1,000#overpull,shear off POOH.Top depth of PBR is 7,668'. Pressure test 4-1/2"tubing and packer w/burst disks to 500psi, charted good. 6/16/15-Tuesday Install BPV. ND tree, NU new 4-1/16"5M x 7-1/16" 5M THA. NU BOP stack and stripping head. Blind rams and all wing valves are secured. Hole is full. • Hilcorp Alaska, LLC lIiItorp LLIC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP S-27 50-029-23084-00-00 202-085 7/18/2015 7/20/2015 Daily Operations: 7/15/15-Wednesday No operations to report. 7/16/15-Thursday No operations to report. 7/17/15-Friday No operations to report. 7/18/15-Saturday JSA prepare for rig acceptance inspection.Shell test BOP's and lines to 5,000psi.Arrival of Johnnie Hill and Bob Noble from AOGCC. Rig tour inspection.Test BOPE per start up request 250psi low and 5,000psi high.Test annular 250psi low, 2,500psi high.Test and chart. Charts given to AOGCC Rep Bob Noble.Strap pipe. LD test joint and RD pump truck. Pull TWC. PU 2-3/8"4.6#Supermax tbg,sgl, install starting mandrel,stab 2-3/8"stripper.Set torque to crimp/crush 1 joint. Problems with tongs over hole and automated system difficult to utilize stabbing guide. PU Pup and practice connections, set torque @ 1,000 ft/lbs as per manufacturer guideline. Depth 800' . 7/19/15-Sunday Continue RIH to 171 jts" 5,301'.Tubing is overflowing, dispacement annulus too small.Attempt to surge with closed TIW, minimal results cannot displace. Kill tank almost as tall as wellhead reconfigure flow path,drain stack,and begin bucket catch displacement. Resume RIH with 2-3/8"tag 7,668' @ up on PBR.Space out and tag up in PBR at 7,685', 11.8' in on jt 248'. Begin RD operations on peripheral equipment. Organize equipment and RU pump truck to freeze protect. RU for U tube PT all lines and pump 31 bbls freeze protect down annulus. RD hot oiler allow well to U tube.Space out with 246 jts 2-3/8"Super Max J-55 tbg, 2 ea 10' pup jts, 1 sgl jt 2-3/8 tbg,and 4' pup and hanger. EOT 7,681'. 7/20/15-Monday RDMO ancillary equipment, Move rig out of the way. ND BOPE NU tree and test 250psi low, 5,000psi high. Install BPV to be removed by production. 7/21/15-Tuesday No operations to report. IP ("FoF T��1//7�,cv THE STATE Alaska Oil and Gas s���, of Conservation Commission _ _- . ALASk:A u4117/-7:77,-14-_-:-.-1-_-:-= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "� Main: 907.279.1433 OF ALAS�P Fax: 907.276.7542 www.aogcc.alaska.gov August 14, 2015 Mr. Stan Porhola Operations Engineer Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 SCANNED AUG 1 3 2015 RE: No-Flow Verification Milne Point Unit S-27 PTD 2020850 Dear Mr. Porhola: On July 31, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Milne Point Unit (MPU) S-27. The well is operated by Hilcorp Alaska, LLC and was recently recompleted with a concentric jet pump installation (addition of 2-3/8-inch tubing inside existing 4-1/2-inch tubing). This no-flow test was required as a condition attached to Sundry Approval 315-297. The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 —was rigged up on MPU S-27 prior to the test. The well was shut in for more than 3 hours followed by a half-hour flow monitoring period. Resulting flow rates (oil and gas) were unmeasurable after opening the well to flow and well pressure was expelled in less than 2 minutes,passing the no-flow test. MPU S-27 is authorized to operate without a subsurface safety valve based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265 and Sundry Approval 315-297. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in MPU S-27 will necessitate a subsequent no flow test. Sincerely, k James B. Regg lj Petroleum Inspection Supervisor ecc: Wyatt Rivard(Hilcorp) P. Brooks AOGCC Inspectors • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ►?e zit S DATE: Saturday, August 01, 2015 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: No Flow Test Petroleum Inspector MPU S-27 Hilcorp LLC PTD #202-085 Friday, July 31, 2015: Witnessed the No Flow test on Hilcorp's well MPU S-27 in the Milne Point Unit. I met Matt Linder on location this afternoon. The subject well was lined up to a horizontal tank via a 2" high pressure line. This is a "Concentric Spaghetti Tubing" completion with 2 3/8" tubing landed inside the original 4 1/2" production tubing. Pressures shown below represent the 4 1/2" tubing as the inner annulus (IA) and the 7" production casing as the outer annulus (OA). This is an original "Monobore" completion and as a result there is not any traditional OA. The well schematic is attached. The Tubing and IA (micro-annulus) were tied together with permanent piping and open to each other during flow periods. An isolation gate valve was closed during shut in periods. After a 3 hour and 40 minute shut in period the Tubing/micro-annulus were lined up together and the 13 psi of pressure that had built up was blown down to tankage through the 2" high pressure hose. All pressure was expelled within 2 minutes and no fluids were observed in the tankage The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 12:25/00:00 0/0/120 0 0 Lined up to open top tank 00:15 0/0/120 0 0 Shut in Tubing/IA 03:55 0/13/120 Unknown 0 Shut in/Open to tankage 03:57 0/0/120 0 0 Flow expelled to zero 04:00/16:25 0/0/120 0 0 Test ended 1 Pressures are T/IA/OA Summary: I witnessed the No Flow test on Hilcorp's Milne Point Unit well #S-27. This well appears to meet set forth criteria for No Flow status. Attachments: MPU S-27 Wellbore Schematic SCANNED Jul_ 1 8 20 2015-0731_No-FlowMPU_S-27_1g.docx Page 1 of 1 ' il • * MilneWell: MPU Point 5 Uni7 2t SCHEMATIC Last Completed: 7/20/2015 , Mean)Alaska,LC PTD: 202-085 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.DF Elev.=67.30'/Orig.GL Elev.=39.30 20" Conductor 92/H-40 N/A Surface 112' 7" Intermediate 26/L-80/Btc-Mod 6.276 Surface 8,302' 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 7,936' 11,009' 20', 4-1/2" Slotted Liner"B" 12.6/L-80/IBT 3.958 8,165' 11,155' TUBING DETAIL 2-3/8" Tubing 4.6/1-55/SuperMax 1.995 Surface 7,692' 4-1/2" Tubing 12.6/L-80/IBT 3.958 Surface 7,775' /. ' 3-1/2" Tubing 9.3/L-80/EUE 8rd JEWELRY DETAIL 2.992 7,775' 7,838' 1 No Depth Item 1 2,185' Camco 4.5"x 1"KGB-2 GLM w/RP valve BK Latch 2 7,656' Jet Pump and Retriever Assembly(Ran 7/25/15) 3 7,657' XO 2-3/8"Supermax x 2-3/8"8RD 4 7,659' Jet Pump BHA 5 7,660' Standing Valve(Set 7/25/15;7,631'SLM) 6 7,661' Locator Seal Assembly(Spaced out 3.46'above Sealbore) (( 7 7,665' Sealbore,20'Long fi` 8 7,686' Anchor Latch 9 7,688' Packer,Paragon II(2.0"ID Bore) 10 7,692' WLEG 11 7,727' Phoenix Discharge Pressure Gauge-3.850"ID 2 12 7,738' HES 4.5"'XD'Dura Sliding Sleeve ( 3 13 7,758' Phoenix Sensor 4-1/2"Casing-ID Change to 2.840" i 14 7,773' X0 4.5"12.6#NSCT Box x 3.5"NSCT Box 4 15 7,775' HSE 3.5"X-Nipple NSCT 16 7,786' Baker Premier Packer 7"x 3.5" A 5 17 7,833' HES 3.5"XN-Nipple-2.750"No Go 11 6 18 7,836' 3.5"NSCT WLEG-Bottom @ 7,837' 19 7,936' Baker Hook Wall,Hanger above 7"Window 7 20 7,962' Baker Hook Wall,Hanger outside 7"Window 21 8,165' Baker Tie Back Sleeve 22 8,177' Baker ZXP Liner Top Packer 8 23 8,185' Baker 7"x 5"HMC Liner Hanger LATERAL WINDOW DETAIL OPEN HOLE/CEMENT DETAIL - : 9 A ,m Window in 7"Casing @ 7,948'to 7,960' 20" Cmt w/260 sx of Arcticset(Approx)in 42"Hole 10 Well Angle @ Window=74 Deg. 7, Cmt w/1,360 sx Class PF"L",650sx Glass"G"in 9-7/8"Hole s ,111 WELL INCLINATION DETAIL WELLHEAD •i• ' 12 L, KOP @ 600'MD Tree 4-1/16"-5M FMC ,, 13 70 to 73 Deg.2,900'-7,800' 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B ` 14 �! Max Hole Angle=73 deg. @ 6,000'MD Tubing g Han ger CIW"H"BPV Profile Hole 15 72 Deg.@ Sliding Sleeve New Tubing Head(Installed 2015) es LmuA 16 Tubing Hanger w/2-3/8"8RD Lift Threads i .17 Fish:Aluminum Blowout Plug-Lost 7/25/15 GENERAL WELL INFO � OD:2.49"/Length:2.75"/Tag @ 7,732'SLM 4, 18 i API:50-029-23084-00-00 Drilled and Completed by Doyon 141 -15/28/2002 X20 .elNOTE: Prior to setting or pulling 4.5"BPV or TWC,notify FMC. i "OA"Lateral 4.5"TCII thread profile compatibility issue exists. 21 `4, 22 3 A "06"Lateral 7 NI TD=11,186'(MD)/TD=4,084'(R/D) PBTD=11,186'(MD)/PBTD=4,084'(TVD) Downhole Revised:7/25/2015 Updated By:STP 7/28/2015 Alt_Pt4S-- Z-7 Pit ?C)Z.f6SO , Regg, James B (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> tettl 614116 Sent: Thursday, June 04, 2015 2:45 PM I To: Regg,James B (DOA) Subject: MPS-27 (PTD #202085) Power Fluid Shutdown Attachments: PI-MOS-00030-001_DC.PDF; PI-MOS-00030-001_Demo.pdf Jim, The Milne Point Field Foreman confirmed that the reconfigured MPS-27 wellhead system will retain an automated shut- off valve for the power fluid.There are currently two actuated valves on the tree, one is the SSV and the other shuts in the power fluid. Both are triggered by the low pressure pilot trip. The power fluid valve has additional trip logic to shut in for high flowrate (in the event of jet pump washout). For the new "normal flow" design,the SSV will be moved adjacent to the 2-3/8" by 4-1/2" annular wing valve. Power fluid will still run through the actuated power fluid valve but will then be routed into the new 2-3/8" completion instead of the 4-1/2" x 7" annulus. The attached drawings show the SSV in Red and the power fluid valve in Green. The demo drawing depicts the current configuration while the DC drawing shows the proposed design. Thanks, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED JUL 0 22015 Hamm AI a&*,LLC In u J In E§ c'j A I U 4 ,c,:, I Q `�./ 11 _ fi ihh -40 .m., 44g o'lad %(/11 VIc:i ! !8°7 — J '' o g 4 iT WK S 60 0 SC A MI - N . . . m m a a - =a= 0 a z i �w ,� a Y � 6707- N z gtwj: .. .4. N aco0 Vlw ; J E g• — g Q Wfw�w a _ cfrl WAN -,' 0 1 431;:rit. .<7....3 LEj ;.--.15: � � W .g & L %E7 i� Q 8 $$$$i 9 5y� s�oa g fp i j Iii ?£xxsa — I l 3[ w Z _ Ckt O' ,i H z : ‹ .)a , 8 r- O1C Oe I I a 9t,- J a gritiLL •11�_.x •1.-L3NJ-0Z9Z-fid _ W1 i 1 X133 1 n �r NI- V- 1.3N0 L]NJ i 4 - .li.l, P rC E.: Ili_ g.A i El, il x Ni81\Nr2 ✓ ;W I§ �a ` d ar o -1 I fi u ` .-7` � N rits lE ,_, II 1 -+–� U-59 7131136 11flAq 33SN g _ `A'i �, a! 00-01q ' < - I 7299 231136 123Nq 3061fq _ 1`\\ > `� r r---- i w -o8 Sah — I SZ-59 231136 12YJ0 3061113 ,!��j��;s, ----- SL-$92J1136 L231IU 301$21 -- -- bi— % or V. 2 -00=0_s �pp5 1 tl p 1Fj� - 1% r -.1 p}ZOEOa••<- _ a y m aaaa�a ; lo'r: :71 a fi I'-:'.'i 2 ►�F 1 I I Iii ._..c .:_, ,„§§ I I I $� n xa !ID 1 A AII ) $ Q'ItL__A WirA 1 i !q8..r 4it 5� F I o• N x " Q ,— LI =ZS IC II � x� 1 ��( I 1 I O�'y� < '' )� y as 1 ¢2n a z 8 w w �$Oi6 S 1 1 3nzz:gg y J� 44 nww� LIN�Sl -"-'�=3- I - - I - ---� I J e'd'woaaoa C W „, I I Ili I I 1�1 .. 1 �, w » s_KJ I © ` , -+ ' GCCKK L! -H L I t I 1 'as _11 iiA . . pm . ---1 I I IA 2 2 I ' r 1 ' ) 1 1 �_� I ' L — C_ y 1 $ 1 I. I I '-1 4'p'— � I 1 ----- -- -- ' 1 `.)I S CO as CO 30 r 11 la I u ? P p3 . I . y I _g „.._ I"- N � A • e V s f, ',ft\ !, !, 1 a 3� bihvv 8 8 V.o h4a O 7S <sG3 V (n- 1! za �i a � 6qo fL^3, vii Z 3 i(n ' .0_11Y 5 igt ggFgg6 0 gk.,,f aoF — 7 " i 7 "' . g g n 2E!3R <�pmix w v z . — z 4. T j� �W4 01 6d i i at a= owgZ o �. 1� - N Z s .o ri m o� ati1 a z ; 1 W60� 3 $ (lJ 1 ,iN Ai �m✓w1 v10 p pp 4___H___ caw Z•1eelEor-- --yl ' - ' -- _ ----- - -- -44 irN ` ti /% C 5 1444 I z g .� —. 7 �' le 4' < • I �� D6 -DQ1 m � I L s I Ste— I (f) g NNNNN 0 0 0 0 0 1 :7 0 p a����� $ L ` `iE7 s $���� J a we \ :-:,i1 \ O p VI O _ IPea I g. • eE a Io Gil \ 1 ►� r 0 s yt7 a s 1�y,, �In Os I .LI O Q l l g t Pi 3 C'e ' "4 .t-L7Ni-OZBL-fid _ I ff s F m 11 J-")1_ e�`3�I 1-----5L3 � I I i flS� b1�1 •µ t z z T X 3 m I ♦ 111 } �1 :��oLm S J Nj..k . : 5 µ � 1e N kl§)ate — - 1 m o SR N I j r�mn in I n r- \M 1 0 iV ' 1 1`4 1f� .. y�fid g g w.y �,�� Q to N3�� !WA 1 01 a1 r g p I ... ... I nF-8.1 -trO I g -- I LL-50 N3113V6 RCM 306M —--_ 11 tl' �. I p.c. a 8 I- --—--—-- I o a-v < -, LZiO tl31Z3161H'3�q 3061110 i k _ r r _ r---- - L 1 g oB-k8'N" - — r_- __ SL-50 1f31U61![15o 3061f10 -_ __ . 1 I ,- ... a�''.--E.,:',-;',,,,.: r SL-50 alias 1i a 306N $dr q _p I o 8_6_0 I 1 I Ro go.f f �� I 8 0 8 0 2 7 OOP \ ' n� 1 0� d Yi�m 1 000 I al 4.4 'T 5. a Ilg �I :4'� i 1§.'huai 1 2 I I I I 1 1 I g g �I= " , 1 3< 1 P1-7 Ag • ) Pd I I N tn GS � isol "„ h �� b : I ' NN2 - 0 6 . I I p MOM I— — �.� I WD8770x I • 6G C:H%;K Jii V- a iSi �' eg 0 I 5 8 b ; No 20,0 0.8 a �-1 ) I E € W —\ L___ I I i 4! i 1,1 i ” ill 1^ ------------------J CO 6 S 5 CO U V PI sk11 q I U ? . I Q G AOGCC Memorandum Date: 6/4/2015 To: Files From: Jim Regg, Petroleum Engineer 1/4"7 Subject: Request for Variance— SSV Location J°S-27 (PTD 2020850) Hilcorp Alaska LLC SCANNED JUN 0 9 2015 Docket# OTH 15-19 I spoke with Mr. Wyatt Rivard (Hilcorp North Slope Well Integrity Engineer; 907-777-8547) regarding Hilcorp's May 18, 2015 request for variance to operate Milne Point Unit S-27 with a surface safety valve positioned on the production tree's wing (horizontal run of the tree). AOGCC regulation 20 AAC 25.265 requires the actuated surface safety valve be installed in the vertical run of the tree but also provides for approving a variance if the operator presents justification that the alternative location provides for an equal or improved level of safety. The purpose of my discussion with Mr. Rivard was to clarify the need for this request in light of AOGCC's approval of Sundry 315-297. Mr. Rivard stated he intended to contact us about the variance request and agreed it was unnecessary. Sundry Approval 315-297 includes the following statement: "SSV placement in Hor. [horizontal] run approved per 20 AAC 25.265(o)(1)." Docket Other 15-19 can be closed without taking any further action. '1 c i btu, ,�G trS A A ' s �a.,t.,.t O''''l 1-1)14M- �'fSTATE OF ALASKA U O�t(k�` 4 I ; 01-ALASKA OIL AND GAS CONSERVATION COMMISSION �4z ,k�) APPLICATION FOR SUNDRY APPROVALShis/c 20 MC 25.280 -2 , 04 1•Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing Q • Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ ,! Plug for Redrill❑ Perforate New Pool ❑ Repair Well D Re-enter Susp Well ❑ Other: Install Jet Pump Q '1( 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC . Exploratory ❑ Development 0 202-085 . 3.Address: Stratigraphic ❑ Service El6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23084-00-00 , 7.It perforating: 110 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 477,05- Will planned perforations require a spacing exception? Yes ❑ No QQ MILNE PT UNIT SB S-27 • 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0380109 • MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft). Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,186 4,084 11,186 . 4,084 , N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Production 8,302' 7" 8,302' 4,104' 7,240psi 5,410psi LinerA 3,073' 4-1/2" 11,009' 4,068' N/A N/A Liner B 2,990' 4-1/2" 11,155' 4,081' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4-1/2" 12.6#/L-80/IBT 7,775' See Schematic , See Schematic 3-1/2" 9.2#/L-80/NSCT 7,838' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"x 3.5"Packer and N/A - 7,786'(M0)/4,008'(TVD)and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 5/29/2015 Commencing Operations: OIL ✓❑ , WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tede Kramer Email tkramer[a)hilcorp.com Printed Name Ted Kramer Title Operations Engineer Signature (�� z.--z____ Phone 777-8420 Date 5/8/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315- 2q`i Plug Integrity ❑ BOP Test [� Mechanical Integrity Test 0 Location Clearance ❑ Other: T -3(x)z) fr5;, (3U.0 t- (yAcP — Ors..: ) , Spacing Exception Required? Yes ❑ No © Subsequent Form Required: /0— I 0 41 APPROVED BY _ Approved by: f;30.4,74......,— (:::: COMMISSIONER THE COMMISSION Date: 5-� / S fly C �y t /J"- s(�/� Submit Form and i j/ Form 10-403 Revised 5/2015 A ve application Irt..valfd for 12 months from the date of approval Attachments in Duplicate • 1:11[ RECEIVED Post Office Box 244027 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC MAY 1 8 2015 3800 Centerpoint Drive Suite 100 AOGV Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 May 18, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: MPS-27 (PTD# 2020850) - Request for variance to 20 AAC 25.265(c)(1) Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a variance to 20 AAC 25.265(c)(1) to operate a surface safety valve (SSV) that is not located in the vertical run of the tree on Milne Point Unit (MPU) well S-27 (PTD# 2020850). MPS-27 is a long term shut-in jet pump producer with known production casing damage near surface. The well is a "Monobore" completion with a production casing only. Two successive MTT (Magnetic Thickness Tool) logs run in January 2008 and May 2009 identified circumferential production casing damage near surface. In November 2009, the well was shut in to mitigate risk since MPS-27 does not have surface casing and uses high pressure power fluid in the IA. A third MTT log was run in December 2011 and a fourth log was run in May 2013. All four logs indicate a ^'9%to "'12% circumferential metal loss in the production casing over the —7 ft to ^'41 ft interval. The well passed a MIT-IA to 3000 psi in 2010 and a CMIT-TxIA to 4200 psi in 2013. HAK plans to address the casing damage risk by running a 2-3/8"jet pump completion with packer inside the existing 4-1/2" tubing to recomplete the well as a "normal flow" jet pump. In this configuration high the pressure power fluid would be pumped down the 2-3/8" completion with production returning up the 2-3/8" by 4-1/2" annulus. Because production is around the innermost 2-3/8" completion, there is no way to utilize a SSV within the vertical run of the tree. Instead, HAK intends to horizontally mount the SSV adjacent to annular wing valve. This configuration provides an equivalent level of protection and places two barriers between high pressure power fluid and the damaged 7" production casing. Pictures and additional information on the completion design are provided to support this request for variance (see Attachment 1- 3). Page 12 If you have any additional questions concerning this request, please contact me at 777- 8547 or by email at wrivard@hilcorp.com. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Guy Schwartz James Regg Attachment 1 . MPS-27 BHTA,Otis,2 9/16 5M r 0 1 • 1 I' Tubing hanger,FMC-TC-B- IOW EC,11 X 2 7/8 EUE 8rd lift Valve,Swab,WKM M, and susp,w/4'pup&4" 2 9/16 5M FE,HWO,DD type H BPV profile,300-4 ilk trim , . pkt,1-CCL,3.266"centers, i' , L' Alloy material I I O III r It <_ / ISI �_ -1• Ma1 7LP 9 Valve,Master,WKM-M, = 0" 29/165MtFmHWO,DD , . �� ���;. (<, 4-7 'L— iii” 1111 I1 II I1 bg� 0 a o ubing hanger 7 1/16 X 2 3/8 ��.\'' '.1.\- _ • • 8 Seaboard/W 2" BPV profile �1c Qoo\&daP' eS I/1 I Q1 oa�a 6g0 O Ja 2 1/16 SSV Seal c) 6�� o IF 1 IED COAl [o t• 1 o 11- I_ eil 7 i U Adapter,FMC A-5-EC, 111 11"5M rot flg btm X 2 9/16 5M stdd top,w/ 300-4 pkt,w/2-CCL, Tubinghead, FMC OBS, prepped f/BIW -- • A I�1 penetrator,3.266 centers 13 5/8 5M Stdd bottom x � 11"5M FE,T /2-2 1/ _�� •- ==_ 16 5M SSstyle . lockIII r co itor:!..4-1,11111110 'LT 111411" ,., -sigrirt4v• llimr‘l nirli, ,400•1: 1/1,111111111_ ., .1/4.0 0 fir` - dilator _ Casing head,FMC-OBS, _ nes All casing valves2 1/16 5M 135/85MFEX133/8 Via'' Aim OCT 20 SOW,w/2 2 1/16 5M -• — 1' Pr ME B- SSO, IP style lockpins lel ` IUI (-•y i I,*..,_ . (76_1 11114:. %lion ) — II 4cf°17.04111111;601C.). d 1 _II it 1u Attachment 2 . U 1 Rl I Q - R- - j o s • Q (Y ii Y IT r I ae-- a• Mi 1 II li i I N o 0 ® �, Io o `� `i � a � ate$B Es tl ;III�� % o1 E r7-120:E R 6 101! ' fn 11 1� Y •1 q : PP ��s aF g — ! ; 10aoil; W"2 i iaRIfillip a 5� 3�- d-.� EM . R�d�,.1 hoe =a i 5 a i - Q ¢ + ws e i �ev9 i8' a 131 N g i !_g 4Q N Cu .i .g. 1— I_El 1 IF 4 (f) FF In i-i-:,:ilit . .,, _ .im IA-, : I L. (..) 8- of_ IA) ,. Z i *z 0 1`i 'i I iZ a i ° I : Q ,s 2°-� � I L7 s z r., IILLt 1 3 Q. p @ QI I @d� r,-.14 G6 4 I L J"'j ,f 5t5 (1) I if II r: l•Era e pl .s-eau-ma:� t .1 �' = 6! I ' I T°;' PI 1 11 12E'' 1 I Iil').1, I 24 Y 4 Sr Q' 4 :f Ii di w N� LI I�� i a��� k 11 Q � 0 i:).1 ! :). to i -414i tl , ci .- 1 it.. Will rtFl • 1Islff � � rI 13-10 101.9611:1111341:1 - I ktiC — ;51—\ 0 r— ' I rdl I I I O 1 ❑ fad i f r I 2y Iig;�_ ' d � 1 I ILS I ' ,.. - - K-y 14%9 � I � 1_ c 1 I � �11 El g ti €I'. 6 IIII gi �.21' Pa i ) NI ! k-Vir ri!../li I II , @a t IR-, aliliitIXl I I ' ' ( �j,lia-r E. ICI120 iiriitt Jr tcoe a 1 L I IU I I I -� : I 4. i- I ; I s I 6 J , I 11�p_I , 'Iq til I vs6I Bassa ga �, I I : / 11 g /k.1 I I glp 0� 11 tE L------------_.___1 i co co 1 11 s 1 li . I U t Rf I Q Attachment 3 Milne Point Unit PROPOSED Well: MPU 5-27 Last Completed: 5/23/2002 ua,„r„,u.i�.ka.>I.c PTD: 202-085 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.DF Elev.=67.30'/Orig.GL Elev.=39.30 20" Conductor 92/H-40 N/A Surface 112' 7" Intermediate 26/L-80/Btc-Mod 6.276 Surface 8,302' 20 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 7,936' 11,009' 4-1/2" Slottedliner"B" 12.6/L-80/IBT 3.958 8,165' 11,155' TUBING DETAIL 2-3/8" _ Tubing 6.4/J-55/IBT 1.995 Surface ±7,737' 4-1/2" Tubing 12.6/L-80/IBT 3.958 Surface 7,775' 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.992 7,775' 7,838' JEWELRY DETAIL 1 No Depth Item b;' 1 2,185' Camco 4.5"x 1"KGB-2 GLM w/RP valve BK Latch 2 7,727' Phoenix Discharge Pressure Gauge—3.850"ID 3 ±7,730' 4.5"x 2-3/8"Packer 4 ±7,734' Concentric Jet Pump 5 7,738' HES 4.5"'XD'Dura Sliding Sleeve 6 7,758' Phoenix Sensor 4-1/2"Casing—ID Change to 2.840" 7 7,773' XO 4.5"12.6#NSCT Box x 3.5"NSCT Box 8 7,775' HSE 3.5"X-Nipple NSCT 9 7,786' Baker Premier Packer 7"x 3.5" 10 7,833' HES 3.5"XN-Nipple—2.750"No Go 11 7,836' 3.5"NSCT W LEG—Bottom @ 7,837' 12 7,936' Baker Hook Wall,Hanger above 7"Window 13 7,962' Baker Hook Wall,Hanger outside 7"Window 14 8,165' Baker Tie Back Sleeve 15 8,177' Baker ZXP Liner Top Packer 16 8,185' Baker 7"x 5"HMC Liner Hanger LATERAL WINDOW DETAIL Window in 7"Casing @ 7,948'to 7,960' Well Angle @ Window=74 Deg. WELL INCLINATION DETAIL KOP@600'MD 70 to 73 Deg.2,900'—7,800' Max Hole Angle=73 deg. @ 6,000'MD 72 Deg.@ Sliding Sleeve OPEN HOLE/CEMENT DETAIL 2 20" Cmt w/260 sx of Arcticset(Approx)in 42"Hole , 3 7„ Cmt w/1,360 sx Class PF"L",650sx Glass"G"in II ' 4 9-7/8"Hole ILi .5 En ii 6 WELLHEAD iMi IMI 7 Tree 4-1/16"—5M FMC . 8 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Wellhead 9 Tubing Hanger CIW"H"BPV Profile Hole '10 GENERAL WELL INFO 11 ;; API:50-029-23084-00-00 1 Drilled and Completed by Doyon 141 -15/28/2002 12 3113 NOTE: ,,?' Prior to setting or pulling BPV or TWC,notify FMC. Profile TCII thread compatibility issue exists. i "OA'Lateral 14 15 J. '. 16 "OB"Lateral 7 TD=11,186'(MD)/TD=4,084'(TVD) PBTD=11,186'(MD)/PBTD=4,084'(TVD) Created By:TDF 5/8/2015 Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Monday, June 01, 2015 3:01 PM To: Schwartz, Guy L (DOA); Loepp, Victoria T (DOA) Cc: Tom Fouts; Chris Kanyer Subject: MPU S-27 Program Change - Rig Sundry# 315-297 PTD 202-085 Guy and Victoria, This E-mail is to let you know that above well has been changed from the Nordic#3 to the ASR#1 Rig Line. The reason for this change is that: a) The location of S-27 and the softness of the gravel roads(summer conditions)Would make the well difficult to get to for the Nordic#3 rig without laying a large number of rig mats. The ASR#1 rig is truck mounted and it can be driven to location minimizing the impact to the road system. b) The S-27 RWO is believed to be a straight forward work over and will be a good well to start with for a new rig and crew. Since this is planned to be the first well worked on for the ASR#1 rig, Hilcorp rig acceptance and AOGCC approval to work activities will be completed prior to starting the S-27 work over. The BOP stack and the well tree will remain the same. Please call me with any questions or concerns. Sincerely, SINNED Jul. 0 2 2015 Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 1 - of • (ts-,17j, sTHE STATEaska Oil and Gas of T A S KA Conservation Commission ` t itt==__ = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279 1433 oA ALAS" 2 Fax. 907.276 7542 C�NNEn MAY 0 201 www aogcc.alaska.gov Ted Kramer ^ Operations Engineer 'L d�— c7 Hilcorp Alaska, LLC O� 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB S-27 Sundry Number: 315-297 Dear Mr. Kramer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, !iv Cathy P. •erster � - Chair DATED this �v day of May, 2015 Encl. • RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION '7'; i 3 ?Di: APPLICATION FOR SUNDRY APPROVALS S 0s/� 20 MC 25.280 AOGCC S 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing Q ' Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool 0 Repair Well Q, Re-enter Susp Well ❑ Other: Install Jet Pump ❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC , Exploratory ❑ Development Q 202-085 3.Address: Stratigraphic ❑ Service El6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23084-00-00 , 7.If perforating: #13 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05-- Will 77.08Will planned perforations require a spacing exception? Yes ❑ No E MILNE PT UNIT SB S-27 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380109 • MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,186' 4,084 ' 11,186• 4,084 • N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Production 8,302' 7" 8,302' 4,104' 7,240psi 5,410psi LinerA 3,073' 4-1/2" 11,009' 4,068' N/A N/A Liner B 2,990' 4-1/2" 11,155' 4,081' N/A N/A Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size. Tubing Grade. Tubing MD(ft). 4-1/2" 12.6#/L-80/IBT 7,775' See Schematic , See Schematic 3-1/2" 9.2#/L-80/NSCT 7,838' Packers and SSSV Type. Packers and SSSV MD(ft)and ND(ft): 7"x 3.5"Packer and N/A • 7,786'(MD)/4,008'(TVD)and N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development E• Service El 14.Estimated Date for 15.Well Status after proposed work: 5/29/2015 Commencing Operations: OIL ❑✓ , WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tede Kramer Email tkramer@hilcorp.com Printed Name Ted Kramer Title Operations Engineer Signature ,....2- 4,,, ,,,-....___�� ' ' Phone 777-8420 Date 5/8/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3k5- 241-1 Plug Integrity ❑ BOP Test L Mechanical Integrity Test ❑ Location Clearance ❑ Other - 3a)1-' PSz 6C -7-7;; t- MAS-to pc,: ) `wJ /ow k F- /'� tS Vp14-e--0---,14- , - Mori. 2P /32.4_ 7-4-3 L Z o��o S�o)C 1 Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: /() ( V 4-1 APPROVED BY _ Approved by. fC6747 7 COMMISSIONER THE COMMISSION Date. 5 - �,S S (ii g S- GiReil R ' �(�/� Submit Form and Form 10-403 Revised 5/2015 p Iicati0 it.-aal!d for 12 months from the date of approval3 Attachments in Duplicate ,44041* RBDMS MAY 1 13 2015 Well Prognosis Well: MPS-27 Hilcory Alaska,LLi Date:4/16/2015 Well Name: MPS-27 API Number: 50-029-23084-00 Current Status: SI Producer Pad: S Pad Estimated Start Date: May 27, 2015 Rig: Nordic 3 Reg.Approval Req'd? May 20,2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-085 First Call Engineer: Ted Kramer (907)-777-8420(0) (985)-867-0665 (M) Second Call Engineer: Chris Kanyer (907) 777-8377 (0) (907) 727-9247 (M) AFE Number: Current Bottom Hole Pressure: 1,531 psi @ 3,999' TVD (Gauge) Maximum Expected BHP: 1,531 psi @ 3,999' TVD (No perforating or cleanout planned) Max.Allowable Surface Pressure: 0 psi (Based on actual reservoir conditions and water cut of 78% (0.4313psi/ft)with an added safety factor of 1000'TVD of oil cap) Brief Well Summary: The Milne Point S-27 well is a shut in jet pump producer that has been shut in since 2009 after running a MTT log in the tubing that indicated a possible 12% metal loss in the production casing. The operator at the time elected to shut the well in since they were putting high pressure jet pump fluid down the tubing by production casing annulus. This was a concern because there was no surface casing ran in this well bore. The most recent casing MIT was conducted on 5/13/2013 and .assed at 4 200 •si. Therefore, no casing test is planned as part of this work due to the work nature. This workover will involve running a 2-3/8" tubing string inside of the existing 4-1/2" production tubing creating a 4-1/2" X 2-3/8" concentric Jet pump installation. This will allow the well to be placed back on production without having high pressure fluid being pumped down the production casing by 4-1/2" tubing annulus. Instead, high pressure fluid will be pumped down the 2-3/8" tubing and returns will be brought up the 4-1/2"X 2-3/8" annulus. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issue suspected. RWO Objective: Install a 2"jet bump cavity on 2-3/8" tubing inside of the current 4-1/2" production tubing. 1424 Brief Procedure: 1. Add 2-3/8"tubing completion spool to current MPS 27 welhead. 54 2. MIRU Nordic#3 Rig. 300c' 3. ND tree, NU 11" BOPE and test to 250psi low/ si high, annular to 250psi low/2,96Cpsi high. a. Notify AOGCC 24hrs in advance to witness test. Well Prognosis Well: MPS-27 Ililcorp Alaska,LI) Date:4/16/2015 4. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 5. PU 2-3/8" tubing in singles and run in hole washing out any sand . POH with 2-3/8" tubing standing back. 6. PU 2"pump cavity, RIH on 2-3/8" production tubing and set. 7. ND BOP, NU tree and test. 8. RDMO workover rig and equipment. 9. Turn well over to production. Attachments: /V h 1. As-built Schematic 7:0_4.1` LJ 7 p' Lt/z- 2. Proposed Schematic 3. BOP Schematic Milne Point Unit Well: MPU S-27 . 11 SCHEMATIC Last Completed: 5/23/2002 Ililcorp Alaska,LLC PTD: 202-085 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.DF Elev.=67.30'/Orig.GL Elev.39.30' 20" Conductor 92/H-40 N/A Surface 112' 7" Intermediate 26/L-80/Btc-Mod 6.276 Surface 8,302' i1 l ; 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 7,936' 11,009' ► . 4-1/2" Slottedliner"B" 12.6/L-80/IBT 3.958 8,165' 11,155' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT 3.958 Surface 7,775' 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.992 7,775' 7,838' JEWELRY DETAIL No Depth Item 1 1 2,185' Camco 4.5"x 1"KGB-2 GLM w/RP valve BK Latch 2 7,727' Phoenix Discharge Pressure Gauge 3 7,738' HES 4.5"'XD'Dura Sliding Sleeve 4 7,758' Phoenix Sensor 4-1/2"Casing—ID Change to 2.840" 5 7,773' X0 4.5"12.6#NSCT Box x 3.5"NSCT Box 6 7,775' HSE 3.5"X-Nipple NSCT 7 7,786' Baker Premier Packer 7"x 3.5" 8 7,833' HES 3.5"XN-Nipple—2.750"No Go 9 7,836' 3.5"NSCT W LEG—Bottom @ 7,837' 10 7,936' Baker Hook Wall,Hanger above 7"Window 11 7,962' Baker Hook Wall,Hanger outside 7"Window 12 8,165' Baker Tie Back Sleeve 13 8,177' Baker ZXP Liner Top Packer 14 8,185' Baker 7"x 5"HMC Liner Hanger LATERAL WINDOW DETAIL Window in 7"Casing @ 7,948'to 7,960' Well Angle @ Window=74 Deg. WELL INCLINATION DETAIL KOP@600'MD 70 to 73 Deg.2,900'—7,800' Max Hole Angle=73 deg. @ 6,000'MD 72 Deg.@ Sliding Sleeve OPEN HOLE/CEMENT DETAIL 20" Cmt w/260 sx of Arcticset(Approx)in 42"Hole ". 7„ Cmt w/1,360 sx Class PF"L",650sx Glass"G" } in 9-7/8"Hole .',47, I ;1 WELLHEAD fj iir 512 Tree 4-1/16"—5M FMC ,, a ' •r• `3 Wellhead 11"x 4.5"SM Gen.6 w/4.5"TC-II T&B t' Tubing Hanger CIW"H"BPV Profile Hole 1 aer _4 4 Mt :J s GENERAL WELL INFO `t. J 6 API:50-029-23084-00-00 7 Drilled and Completed by Doyon 141 -15/28/2002 NOTE: 9 . Prior to setting or pulling zBPV or TWC,notify FMC. 4 r Profile TCII thread compatibility issue exists. v 10 j, 11 +f� Lateral12 �wM gm13 1.4 ...."0,4“ 14 A "OB"LBeral 7" N TD=11,186'(IVD)/TD=4,084(TVD) PBTD=11,186'(MD)/PBTD=4,084'(TVD) Created By:TDF 5/8/2015 Milne Point Unit • Well: MPU S-27 PROPOSED Last Completed: 5/23/2002 Hilcorp Alaska,LIA, H PTD: 202-085 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 92/H-40 N/A Surface 112' Orig.DF Elev.=67.30/Orig.GL Elev.=39.30' 7" Intermediate 26/L-80/Btc-Mod 6.276 Surface 8,302' L.: 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 7,936' 11,009' 20' 4-1/2" SlottedLiner"B" 12.6/L-80/IBT 3.958 8,165' 11,155' TUBING DETAIL 2-3/8" Tubing 6.4/J-55/IBT 1.995 Surface ±7,737' 4-1/2" Tubing 12.6/L-80/IBT 3.958 Surface 7,775' 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.992 7,775' 7,838' JEWELRY DETAIL No Depth Item 1 2,185' Camco 4.5"x 1"KGB-2 GLM w/RP valve BK Latch 2 7,727' Phoenix Discharge Pressure Gauge—3.850"ID 3 ±7,730' 4.5"x 2-3/8"Packer 4 ±7,734' Concentric Jet Pump 5 7,738' HES 4.5"'XD'Dura Sliding Sleeve 6 7,758' Phoenix Sensor 4-1/2"Casing—ID Change to 2.840 7 7,773' X0 4.5"12.6#NSCT Box x 3.5"NSCT Box 8 7,775' HSE 3.5"X-Nipple NSCT 9 7,786' Baker Premier Packer 7"x 3.5" 10 7,833' HES 3.5"XN-Nipple-2.750"No Go 11 7,836' 3.5"NSCT WLEG—Bottom @ 7,837' 12 7,936' Baker Hook Wall,Hanger above 7"Window 13 7,962' Baker Hook Wall,Hanger outside 7"Window 14 8,165' Baker Tie Back Sleeve 15 8,177' Baker ZXP Liner Top Packer 16 8,185' Baker 7"x 5"HMC Liner Hanger LATERAL WINDOW DETAIL Window in 7"Casing @ 7,948'to 7,960' Well Angle @ Window=74 Deg. WELL INCLINATION DETAIL KOP@600'MD 70 to 73 Deg.2,900'—7,800' Max Hole Angle=73 deg. @ 6,000'MD 72 Deg.@ Sliding Sleeve OPEN HOLE/CEMENT DETAIL 2 20" Cmt w/260 sx of Arcticset(Approx)in 42"Hole 3 Cmt w/1,360 sx Class PF"L",65osx Glass"G"in 7, 9-7/8"Hole — 5 6 WELLHEAD PI 7 Tree 4-1/16"—5M FMC $ 11"x4.5"5M Gen.6 w/4.5"TC-II T&B 9 Wellhead, 49441 Tubing Hanger CIW"H"BPV Profile Hole .'10 GENERAL WELL INFO 1d 11 API:50-029-23084-00-00 Drilled and Completed by Doyon 141 -15/28/2002 12 j `z33 ng i i_ Prior to setting or pulling BPV or TWC,notify FMC. 1, •' Profile TCII thread compatibility issue exists. `v "G4 Waal 14 An 15 / '""'k . 6 k.... "CB"Lateral 7" 1D=11,186'(MD)/TD=4,084'0) PBTD=11,186'(MD)/PBTD=4,084'(TVD) Created By:TDF 5/8/2015 . 11. MPS -27 2015 Nordic #3 Hilmrp Alaska_HA, May 2015 I 1 0 0 I iii Iii iii iii iii ill It 2.57' Shaffer 7 1/16 5000 it rai Tun] fin 7 1H WTI tUrnz 2 3/8-3%variable / I r_ CAMERON I — 3.68' H H \ e 8 -!'1 1P / i1 Blind H I 7 1/16 5000 ... \ H ill Iii 16111 lit 2 1/16 10M Kill ValvesOW 2 1/16 lOM Choke Valves Manual and HCR Manual and HCR ETi ill.lei`1:!I !f r li . 1.56' ! ' - = 7 1/16 5000 : ! ' 4�,4 1s1■Ii■1i1JIWt/ -- - o MPS-27 BHTA,.,.is,2 9/16 5M I' Tubing hanger,FMC-TC-B- EC,11 X 2 7/8 EUE 8rd lift Valve,Swab,WKM-M, , and susp,w/4'pup&4" 2 9/16 5M FE,HWO,DD 1 r,j type H BPV profile,300-4 trim • pkt,1-CCL,3.266"centers, ri Alloy material NMI 19 ' IIill 10.,1 II\ / ® f ivy-pi' .(0„III a , N -11, 490 I i. 0, N., l'o ® 9/6� Valve,Master,WKM-M, --1® �' "J ) 2 9/16 5M FE,HWO,DD ®� FF. „,.. �¢� trim ® el -4k/1 O r f\ III Ill I I - I/ 16g �� 0:0--k, _ Tubing hanger 7 1/16 X 2 3/8 I 16` -,— ,ova—sem—�_ aboard/W 2"BPV profile ti6`'-ooh ' ze s ,i 1�1 1 a`o00 „b",,�O JaN�e ! 2 1/16 SSV Immo Sea 9� 6`j` o ®II[®(0)®,Ian ® I[®l /) 11,i,I:IIII! I:i o r( a r I. Adapter,FMC A-S-EC, I (a 11"5M rot flg btm X 2 9/16 5M stdd top,w/ 300-4 pkt,w/2-CCL, Tubing head,FMC-OBS, 1 '■ 1e1 prepped f/BIW milkpenetrator,3.266 centers 13 5/8 5M Stdd bottom xiii 11"5M FE,Top,w/2-2 1/ EN _ INII in_ 16 5M SSO,IP style n! • 1_ lockpins 14-11111 ' 114.74:11 mliliti imim'k111 I . 1S ...,.. 0 . !„,_,. 1_,rra' Casing head,FMC OBS, .- All casing valves2 1/16 5M 13 5/8 5M FE X 13 3/8 SOW,w/2-2 1/16 5M =• M — -_ — ■= OCT-20 SSO,IP style lockpins 1N1 `I I� i ® ml i 11 I1 li �,i • ®1i Hi-11111 l111 (l II M I (% II US- -iE. , ipoi i • Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Friday, May 15, 2015 9:54 AM To: Schwartz, Guy L (DOA); Wyatt Rivard Subject: RE: MPS-27 Jet Pump Completion Guy, Wyatt is out today but we wanted to get you answers to your questions below. Answers are below in red. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, May 14, 2015 3:58 PM To: Wyatt Rivard Cc: Ted Kramer Subject: RE: MPS-27 Jet Pump Completion Wyatt, 1)Will need details on how powerfluid shutdown is tied into SVS system. SVS is tied to an automatic control valve on the power fluid side. When the SVS closes,the powerfluid control valve closes as well. 2) Well will need to pass a no flow test. No flow test can certainly be conducted after the well work. All calculations based on the pressure of the downhole gauge (which is still working in this well) indicate that it should pass. 3) the variance request for annular flow is not needed 4) do need a variance request for moving the SSV to wing. Wyatt is working on this request. Are you looking for formal document or is an email requesting the waiver sufficient? 5)How was well configured as a jet pump before. (power fluid down 7" casing and Production up 4 %2"tubing?) High pressure power fluid was injected down the IA(4-1/2" X 7" Annulus) and up the 4-1/2" tubing. 1 , 6)the procedure is very light on details ... be more specific. How are you providing mechanical barrier to add tubing spool, remove SSV etc. A test packer(or storm packer will be set at 300' (+/-) prior to adding the tubing spool to isolate the well. Guy Schwartz Senior 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 Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From: Wyatt Rivard [nailto:wrivardCalhilcorp.com] Sent: Wednesday, May 13, 2015 7:30 AM To: Schwartz, Guy L (DOA) Subject: RE: MPS-27 Jet Pump Completion Guy, Here is a better drawing of the wellhead configuration for MPS-27. Thanks, Wyatt From: Wyatt Rivard Sent: Tuesday, May 12, 2015 5:37 PM To: Schwartz, Guy L (DOA) Subject: MPS-27 Jet Pump Completion Hello Guy, As discussed,we have a jet pump well at Milne Point, MPS-27(PTD#2020850), that has been a long term shut-in due to near-surface metal loss in the 7" production casing. We are planning a workover(proposed schematic attached)that will involve setting a 2-3/8"jet pump completion inside the existing 4.5"tubing.The 4.5"tubing will effectively isolate the damaged production casing from both production and high pressure power fluid once the sliding sleeve is closed. The jet pump completion would utilize a "normal flow" in which high pressure power fluid was pumped down the 2-3/8" tubing with production returning up the 2-3/8" by 4-1/2" annulus. I am currently preparing a letter requesting variance to 20 AAC 25.265(c)(1)for a horizontally mounted SSV to placed adjacent to the wing. I had thought we may also need to get approval to produce up the new annulus under 20 AAC 25.200 (d) .You had mentioned possibly needing a no- flow test as well.Would the no-flow be required to satisfy the conditions of 20 AAC 25.200 (d)? Thank You, Wyatt Rivard` Well Integrity Engineer 0: (907) 777-b347 I C: (509)670-8001 I wrivard@thilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 2 4 . Schwartz, Guy L (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, May 12, 2015 5:37 PM To: Schwartz, Guy L(DOA) Subject: MPS-27 Jet Pump Completion Attachments: S-27 PROPOSED 5-8-2015.doc Hello Guy, As discussed,we have a jet pump well at Milne Point, MPS-27(PTD#2020850),that has been a long term shut-in due to near-surface metal loss in the 7" production casing.We are planning a workover(proposed schematic attached)that will involve setting a 2-3/8"jet pump completion inside the existing 4.5"tubing.The 4.5"tubing will effectively isolate the damaged production casing from both production and high pressure power fluid once the sliding sleeve is closed. The jet pump completion would utilize a "normal flow" in which high pressure power fluid was pumped down the 2-3/8" tubing with production returning up the 2-3/8" by 4-1/2" annulus. I am currently preparing a letter requesting variance to 20 AAC 25.265(c)(1)for a horizontally mounted SSV to placed adjacent to the wing. I had thought we may also need to get approval to produce up the new annulus under 20 AAC 25.200 (d) .You had mentioned possibly needing a no- flow test as well.Would the no-flow be required to satisfy the conditions of 20 AAC 25.200 (d)? Thank You, Wyatt Rivard Well Integrity Engineer 0: (907) 777-8547 1 C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,State 1400 I Anchorage,AK 99503 1l.IrIIrp 11.i.1►0. 1.1.(, 1 4 . 11 Milne Point Unit Well: MPU S-27 PROPOSED Last Completed: 5/23/2002 Hilcora.Alaska,LLC PTD: 202-085 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.DF Elev.=67.30'/Orig.GL Elev.3930' 20" Conductor 92/H-40 N/A Surface 112' 7" Intermediate 26/L-80/Btc-Mod 6.276 Surface 8,302' 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 7,936' 11,009' 2e: 4-1/2" SlottedLiner"B" 12.6/L-80/IBT 3.958 8,165' 11,155' ( TUBING DETAIL e 2-3/8" Tubing 6.4/J-55/IBT 1.995 Surface ±7,737' I C_S'' 4-1/2" Tubing 12.6/L-80/IBT 3.958 Surface 7,775' 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.992 7,775' 7,838' JEWELRY DETAIL 1 No Depth Item 1 2,185' Camco 4.5"x 1"KGB-2 GLM w/RP valve BK Latch 2 7,727' Phoenix Discharge Pressure Gauge—3.850"ID 3 ±7,730' 4.5"x 2-3/8"Packer 4 ±7,734' Concentric Jet Pump 5 7,738' HES 4.5"`XD'Dura Sliding Sleeve 6 7,758' Phoenix Sensor 4-1/2"Casing—ID Change to 2.840" 7 7,773' XO 4.5"12.6#NSCT Box x 3.5"NSCT Box 8 7,775' HSE 3.5"X-Nipple NSCT 9 7,786' Baker Premier Packer 7"x 3.5" 10 7,833' HES 3.5"XN-Nipple—2.750"No Go 11 7,836' 3.5"NSCT WLEG—Bottom @ 7,837' 12 7,936' Baker Hook Wall,Hanger above 7"Window 13 7,962' Baker Hook Wall,Hanger outside 7"Window 14 8,165' Baker Tie Back Sleeve 15 8,177' Baker ZXP Liner Top Packer 16 8,185' Baker 7"x 5"HMC Liner Hanger LATERAL WINDOW DETAIL Window in 7"Casing @ 7,948'to 7,960' Well Angle @ Window=74 Deg. WELL INCLINATION DETAIL KOP @ 600'MD 70 to 73 Deg.2,900'—7,800' Max Hole Angle=73 deg. @ 6,000'MD 72 Deg.@ Sliding Sleeve t` OPEN HOLE/CEMENT DETAIL y 2 20" Cmt w/260 sx of Arcticset(Approx)in 42"Hole II 37" Cmt w/1,360 sx Class PF"L",650sx Glass"G"in 9-7/8" 1 4 las 'S WELLHEAD 6 pZv • Tree 4-1/16"—5M FMC 4g Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-IIT&B Tubing Hanger CIW"H"BPV Profile ;. —�>-410 GENERAL WELL INFO API:50-029-23084-00-00 11 a Drilled and Completed by Doyon 141 -15/28/2002 . .12 NOTE: ;: { .-13 Prior to setting or pulling zBPV or TWC,notify FMC. Profile TCII thread compatibility issue exists. 'i "OA"Lateal gni15: .:- 5: .: k16 'OB'Lateral 7' ` _ TD=11,186'(MD)/TD=4,084'(1VD) PBTD=11,186'(IVB)/PBTD=4,084'(TVD) Created By:TDF 5/8/2015 ) ImagL )roject 'Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ýJ4!J ... = TOTAL PAGES ?5C¡ vWJ P:~:;;i:n S:::::~TFROM SCANNED FILE: a 0 C~.JLv P ~ C{C .k~ PAGE COUNT MATCHES NUMBER IN SCANNINt PREPARATION: ¿ES NO BEVERLY ROBIN VINCENT SHERY~INDY DATE:<6:'~.þI0qt- - VVî f Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO ~o~ - 0 qgWell History File Identifier Organizing (dOlj(~) RESCAN 0 Two-Sided DI~AL DATA tJf Diskettes, No. Lf- 0 Other, NolType 0 Color items: 0 Grayscale items: 0 Poor Quality Originals: 0 Other: NOTES: BY: BEVERLY ROBIN VINCENT SHERY~WINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHER,£" MARIA )rINDY Scanning Preparation ~ x 30 = 00 BY: BEVERLY ROBIN VINCENT SHERYL~INDY BY: BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECiAl ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS Due TO QUALITY , GRAYSCALE OR COLOR IMAGES) ReScanned findi\;ido;;1 PHF' {,';f'0r:i,11 ;.r¡(:i!tíolJ.l,<,(",1ì ninq 1:[)f/lpl ~l(';dJ RESCANNED B": BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this fìle: 0 Rescan Needed OVERSIZED (Scannable) 0 Maps: 0 Other items scannable by large scanner O,RSIZED (Non-Scannable) , h. f , - , \4' Logs of various kinds '- I ~ , Q Other .~ DATE:r-I~~/SI rr f .1 .~~ '1ci J ;i¿~ pi DATEl ~ i{)Cf,S' +&c¡ , DATE: r' if ð1þs' I DATE: /s/ DATE: /s/ Quality Checked (rlnl!!:) 12/1 OlO2Rev3NOTScannBd, wpd • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 , Post Office Box 196612 tf Anchorage, Alaska 99519 - 6612,. December 30, 2011 1A ,14 0 FEB2: 4 '012 Mr. Tom Maunder . 0 $S Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 5 ' Anchorage, Alaska 99501 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, Mehreen Vazir BPXA, Well Integrity Coordinator • S 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 0.25 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 7/29/2011 MPS-12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7/29/2011 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 7/29/2011 MPS-15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS-16 2030650 50029231510000 1.2 NA 1.2 NA 10.2 7/29/2011 MPS-17 2021730 50029231150000 Open Flutes - Treated MPS -18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7/29/2011 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 MPS -22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 7/28/2011 MPS -23 2021320 50029230980000 Open Flutes - Treated MPS-24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 7/28/2011 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 7/28/2011 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 1.2 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 10/11/2011 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 . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 25,2006 RE: MWD Fonnation Evaluation Logs: MPS-27, L1 & PB1 AK-MW-22071 MPS-27, Ll & PBl: Digital Log Images 50-029-23084-00, 60, 70 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITT AL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ~ËEË\\IÊtJ518 t-.\JG 3 0 'l006 Dat~ C mmlssion ~ 01\ & Gas Cons. 0 . Anc\'lOl'age BP Exploration (Alaska) Inc. Petro technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 QcL¡ Signed: _ J /' I SCANNED AUG 312005 ÐO'd - 01f~- 11 14 III 1:1 LIIl d dO'd - O~0 - - MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc 'Ì .. \ cf-. ;.. 'I-.Ì '-N~ DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020850 Well Name/No. MILNE PT UNIT 5B 5-27 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23084-00-00 MO 11186 -- ----- ----" --- -- ------ ----- TVO 4084 Completion Date 5/22/2002 Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No ---~~ -- --- -~---------~-- DATA INFORMATION Types Electric or Other Logs Run: MWO, LWO, GR, RES, DEN, NEU Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~-------- , Rpt LIS Verification F1=D 0 OirectionalSurvey , '=ô 0 Directional Survey ~ ~pt fED 0 ~Pt .JÆt) 0 ç,éo 0 ~ 0 i ~pt ¡ ißpt l,_~ - -- -------- Log Log Run Scale Media No 1 Directional Survey Oirectional$urvé}l , Directional Survey LIS Verification b.o965 ') \erification t..Kf966 US Verifitation Directional Survey Directional SlIrvey Directional Survey Well Cores/Samples Information: Name Interval Start Stop Sent Received Well Cored? ADDITIONAL INFORMATION v€) Daily History Received? Chips Received? .-¥++I Analysis Received? ._----~----- Formation Tops ---¥'1'N Sp~ IMt7 lûÒ)- Current Status 1-0lL UIC N Directional Survey No (data taken from Logs Portion of Master Well Data Maint) Interval OHI Start Stop CH Received Comments 57 7532 Open 7/10/2002 PB1 6385 11186 Open 7/2/2002 0 7569 Open 7/2/2002 PB1 6385 11186 Open 7/2/2002 0 7569 Open 7/2/2002 PB1 MWO 6385 11186 Open 7/2/2002 MWO 57 11122 Open 7/10/2002 57 11122 Open 7/10/2002 57 7532 Open 7/1 0/2002 PB1 0 7569 Open 7/2/2002 PB l' MWD 0 7569 Open 7/2/2002 PB1 6385 11186 Open 7/2/2002 MWD ~" .~ Sample Set Number Comments (hN ß)N DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020850 Well Name/No. MILNE PT UNIT S8 S-27 Operator 8P EXPLORATION (ALASKA) INC MD 11186 TVD 4084 C omme nts : L! Ü-, '---y... rt '^- ..... N -LtcL --O-~"~t.- Ù P"'-- ~ ---------- -~------------- Compliance Reviewed By: Completion Date 5/22/2002 r-- v~ ~ (;.f t~---1t- \.D I ) (l,l ~~W~ ~ Completion Status 1-01L Current Status 1-01L 'fM.,¡ M W D.; A 8 1/£1::: rzj C fl f I1IJ ð f1.. n- till f)l<¡(1.s ~ kat ï tfJ .. Date: API No. 50-029-23084-00-00 UIC N 3ô ~~AA~ '1 ~ -- ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised 09/06/02, Start Production ~ " . 1. Status of Well I8J Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Ala'ska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. L~~~~~~~[,~~1I1?~~~~~~C 12, T12N, R10E, UM .",l,:~,COi'Jf~.,".I~~,)~~.~".~~,~" ~t,'Oè?Ãm,"".' :,~,".1" At top of productive interval ~l~~~~ ~" Ìì 3553' NSL, 2099' WEL, SEC,' 11, T12N, R10E, UM ,'~ ~IFŒ/) I,' , $, ' ~ '''~'''',., ;. At total depth ~ ~ ,: 3466' NSL 2159' WEL SEC 11 T12N R1 OE UM ~~;~~==.:':::j ~ m. t'~"., ,\...~,~. , ,.", .r''''''''''~IÍI\'J~ ",,', ,~&~.';..",r;'. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 67.3' ADL 380109 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 5-1-2002 5-14-2002 5-22-2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 11186 4084 FT 11186 4084 FT 0 Yes I8J No 22. Type Electric or Other Logs Run GR, RES, PWD, PM, MWD, ABI 1 IFR 1 CASANDRA 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE 20" 92# H-40 Surface 112' 42" 7" 26# L-80 28' 8302' 9-7/8" Classification of Service Well 7. Permit Number 202-085 8. API Number 50- 029-23084-00 9. Unit or Lease Name Milne Point Unit 10. Well Number M PS-27 11. Field and Pool Milne Point Unit 1 Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1800' (Approx.) CEMENTING RECORD 260 sx Arctic Set (Approx.) 1360 sx Class PF 'L', 650 sx Class'G' (Top Job) 427 sx PF 'L' 6-1/8" Uncemented Slotted Liner 4-1/2" 12.6# L-80 8165' 11155' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Liner 25. SIZE 4-1/2", 12.6#, L-80 MD TVD TVD MD 8280' - 11111' 4101' - 4076' 26. AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 7838' PACKER SET (MD) 7786' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 27 Bbls Diesel in tubing 27. Date First Production September 2, 2002 Date of Test Hours Tested 9/3/2002 6 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD 2317 OIL -BBL GAs-McF 843 GAs-McF WATER-BBL 2692 WATER-BBL CHOKE SIZE 176 OIL GRAVITY-API (CORR) GAS-OIL RATIO 364 28. CORE DATA .1 c: r ""~, .' ~ , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SIJ~ Vé~i~. L. tJ No core samples were taken. Form 10-407 Rev. 07-01-80 nip 1 ""', è1'O'''i,i') r- :," 'f¡' 0... L c.'''',,, , 1" ì,,":';( & Ga,~~ GonG. t;û¡¡¡,¡¡¡¡:;¡';¡ÜI AtiehGm(';(,; ,~ Submit In Duplicate ) 29. Geologic Markers Marker Name Measured True Vertical Depth Depth SBF2-NA 7506' 3918' SBF1-NB 7563' 3937' SBE4-NC 7645' 3965' SBE2-NE 7688' 3978' SBE1-NF 78431 4023' TSBD-OA 7946' 4050' TSBC 8059' 4073' TSBB-OB 8236' 4095' SBAS 11 080' 4073' 31. List of Attachments: ) 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GaR, and time of each phase. '£:(""''''''' 0 ~'<L t ìV L!~ S""'p 1 '"¡ ("¡Of*? " t Lt." i...., & G;J¡¿ì GiJm; tìo¡,¡¡¡¡¡'~~ltll jRI!'ìCbiì(~~r'.;:! 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed son~~ Title Technical Assistant MPS-27 202-085 Well Number Permit No. / Approval No. INSTRUCTIONS Date oC>¡ - C-~ CJ - C) ~ Prepared By Name/Number: Sondra Stewman, 564-4750 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 Legal Name: MPS-27 Common Name: MPS-27 Test Date 5/13/2002 Test Type FIT Test Depth (TMD) 8,342.0 (ft) BPEXPLORA TION Leak-Off Test Summary Test Depth (TVD) 4,100.0 (ft) AMW 9.00 (ppg) Surface Pressure 435 (psi) LeélkOff Pressure (BHP) 2,352 (psi) Page.1 of 1 EMW 11.04 (ppg) ---' ("=~ Printed: 5/2812002 11: 18:57 AM ) ) BP EXPLORATION 0 peratio nsSu m rnary . Repo r1: Page 1 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-27 MPS-27 DRILL +COMPLETE DOYON DOYON 141 Start: 5/1/2002 Rig Release: 5/22/2002 Rig Number: 141 Spud Date: 5/1/2002 End: 5/22/2002 Date From - To Hours Task Code NPT Phase Description of Operations 4/28/2002 00:00 - 00:00 24.00 MOB P PRE PREP LOCATION FOR RIG AND CAMP. DRILL CONDUCTOR FOR MPS-23. STAGE RIG FROM PHILLIPS TO MPU-S PAD. MOVE ON RIG CAMP AND TRUCK SHOP. SPOT PIPE SHED AND CUTTING WASHER AT TEXACO PAD. 4/29/2002 00:00 - 00:00 24.00 MOB P PRE PREPARING LOCATION FOR RIG. FINISHED DRILLING CONDUCTOR FOR MPU S-23 AND PUMPED INITIAL CEMENT. SPREAD GRAVEL AND LEVEL LOCATION FOR DRILL RIG WHILE WAITING ON CEMENT. MOVED RIG MODULES ON LOCATION AND STAGED ON S-PAD.LAID RIG MATS AND SPOTTED SUB BASE ON MPU S-27. 4/30/2002 00:00 - 05:00 5.00 MOB P PRE MOVE AND SPOT RIG MODULES 05:00 - 09:00 4.00 RIGU P PRE RIG UP , RIG ACCEPT @ 0900 4-30-02 09:00 - 18:00 9.00 DIVRTR P INT1 NIPPLE UP 20" DIVERTER AND LINES 18:00 - 21 :00 3.00 DRILL P INT1 LOAD PIPE SHED WITH BHA AND 4" DRILL PIPE AND STRAP SAME 21 :00 - 21 :30 0.50 DRILL P INT1 FUNCTION TEST DIVERTER AND ACC. TEST WITNESS OF DIVERTER TEST WAS WAVIER BY JOHN SPAULDING OF AOGCC 21 :30 - 22:00 0.50 DRILL P INT1 PICK UP 4" HANDLING TOOLS 22:00 - 22:30 0.50 DRILL P INT1 PJSM ON PICKING UP PIPE, AND TRAINING WITH WEATHERFORD ON MAKING UP AND HANDLING 4" XT39 PIPE 22:30 - 00:00 1.50 DRILL P INT1 PICKING UP 4" DRILL PIPE AND STANDING IN DERRICK 5/1/2002 00:00 - 11 :00 11.00 DRILL P SURF PICKING UP 4" PIPE AND INSTALL SAVER SUB ON TOP DRIVE 11 :00 - 13:30 2.50 DRILL P SURF PICKING UP BHA 9 7/8 BIT WITH 3/151/10 JETS, 1.5 BEND MOTOR, STAB,GRlRES/PWD/PM MWD, STAB.3- FLEX COLLARS, STAB, XOVER,15-HWDP, XOVER,JARS,XOVER,5-HWDP,XOVER 13:30 - 16:30 3.00 DRILL N WAIT SURF PHASE 3 WEATHER AND WAITING ON PARTS FOR MWD 16:30 - 19:00 2.50 DRILL P SURF FINISH PICKING UP BHA, UP LOAD MWD TOOLS 19:00 - 20:00 1.00 DRILL P SURF CIRC FILL HOLE WITH MUD AND CHECK FOR LEAKS, WASH FROM 105 TO 112 FT. 20:00 - 00:00 4.00 DRILL P SURF SPUD WELL AND DRILLING FROM 112 TO 350 FT. WITH 400 GALS MIN. 1300 PSI, 50 RPMS, 5/10 BITWT. ART 1.8 HRS 5/2/2002 00:00 - 22:30 22.50 DRILL P SURF DIRECTIONAL DRILLING FROM 700 TO 2803 WITH 450 GALS MIN. 2200 PSI, 80 RPMS, 15/20 BIT WT. AST 6.58 ART 9.83 TQ 4,000 ECD 10.3 22:30 - 00:00 1.50 DRILL P SURF CIRC 3 BOTTOMS UP, WITH 2200 PSI, 450 GALS MIN, 80 RPMS, STAND BACK ONE STAND EVERY BOTTOMS UP, ECD DROP TO 10.0, TOP DRIVE SEALS LEAKING OIL. TRIPPING OUT FOR REPAIRS 5/3/2002 00:00 - 04:30 4.50 DRILL P SURF PUMPING OUT TO BHA WITH 400 GALS MIN. 1800 PSI (NO PROBLEMS) 04:30 - 06:30 2.00 DRILL P SURF TRIP OUT WITH BHA, AND DOWN LOAD MWD TOOL 06:30 - 10:00 3.50 DRILL N RREP SURF REPAIR TOP DRIVE, REPLACE BAD OIL SEAL 10:00 - 12:30 2.50 DRILL P SURF TRIP IN HOLE, RESET MOTOR TO 1.22, BIT #2 MXC-1 WITH 3-14,1-10 JETS, WASH AND REAM TIGHT SPOT@ 1716 TO 1775 12:30 - 13:00 0.50 DRILL P SURF WASH AND REAM 2713-2803,90 FT. TO BOTTOM, NO FILL 13:00 - 00:00 11.00 DRILL P SURF DRILL DIRECTIONAL 2803'-4205' WITH 3100 PSI, 490 GPM, Printed: 5/2812002 11:19:07AM ') ) BP EXPLORATION Operations Summary Report Page 2 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-27 MPS-27 DRILL +COMPLETE DOYON DOYON 141 Start: 5/1/2002 Rig Release: 5/22/2002 Rig Number: 141 Spud Date: 5/1/2002 End: 5/22/2002 Date From - To Hours Task Code NPT Phase Description of Operations 5/3/2002 13:00 - 00:00 11.00 DRIll P SURF 120 RPMS, 15/25 BIT WT, TO 6,000, ECD 10.2, AST 2.1 ART 3.3 5/4/2002 00:00 - 15:00 15.00 DRILL P SURF DRill DIRECTIONAL 4205'.6354' WITH 3300 PSI, 475 GPM, 120 RPMS, 20/30 BIT WT, TO 6,000, ECD 10.2, AST 1 ART 7.5 15:00 - 18:00 3.00 DRILL P SURF CIRC. 3 BOTTOMS UP, STANDING BACK ONE STAND PER. BOTTOMS UP, CIRC WITH 475 GALS MIN., 3000 PSI, 125 RPMS, ECD DROPPED TO 9.9 18:00 - 00:00 6.00 DRill P SURF SHORT TRIPPING FROM 6354 TO 850, PULLED TWO STANDS WELL STARTED TO SWAB, PUMP OUT WITH 390 GALS MIN 1700 PSI, @ 1300 FT@ 24:00 HRS. (NO PROBLEMS) CHANGE PUMP LINERS TO 5.5 ON TRIP OUT. 5/5/2002 00:00 - 00:30 0.50 DRILL P SURF FINISH TRIP OUT TO HWP 00:30 - 01 :00 0.50 DRILL P SURF SERVICE TOP DRIVE 01 :00 - 04:00 3.00 DRilL P SURF TRIP TO BOTTOM, BRIDGE @ 5500, WASH AND REAM 90 FT. TO BOTTOM 04:00 - 16:30 12.50 DRilL P SURF DRILL DIRECTIONAL 6354' to 7382 WITH 3500 PSI, 500 GPM, 120 RPMS, 20/30 BITWT, TO 8,000, ECD 10.1, AST 6.25 ART 2.5, (NOT GETTING THE TURN WE NEEDED) 16:30 - 19:30 3.00 DRILL N DPRB SURF CIRC, 3 BOTTOMS, WITH 500 GALS MIN. 3500 PSI 125 RPMS, STANDING BACK ONE STAND PER BOTTOMS UP, ECD DROP TO 9.8 19:30 - 00:00 4.50 DRILL N DPRB SURF PUMP OUT TO 6300 WITH 390 GALS MIN 1700 PSI, PULLING OUT OF HOLE TO 1700' 10/20,000 OVERPULL @ 1700' DIDN'T SWAB. 5/6/2002 00:00 - 01 :00 1.00 DRILL N DPRB SURF TRIP OUT TO BHA 01 :00 - 02:00 1.00 DRILL N DPRB SURF TRIPPING OUT WITH BHA 02:00 - 04:00 2.00 DRILL N DPRB SURF PICK UP NEW BITMXC-1 WITH 3/15,1/10 JETS AND SET MOTOR TO 1.5 04:00 - 08:30 4.50 DRILL N DPRB SURF TRIP IN TO BOTTOM, WASH 90, NO FILL 08:30 - 11 :30 3.00 DRILL P SURF DRilL DIRECTIONAL 7382 TO 7569 WITH 3100 PSI, 500 GPM, 80 RPMS, 20/30 BIT WT, TO 8,000, ECD 10.1, AST 2.5 ART .25, (NOT GETTING THE TURN WE NEEDED) 11 :30 - 13:30 2.00 DRILL N DPRB SURF CIRC, WITH 500 GALS MIN. 3100 PSI, 80 RPMS 13:30 - 14:30 1.00 DRILL N DPRB SURF SHORT TRIP UP TO 6357 14:30 - 16:00 1.50 DRILL N DPRB SURF CIRC @ 6357 WITH 500 GALS MIN, 3100 PSI, 80 rpms 16:00 - 17:00 1.00 DRIll N DPRB SURF TRIP IN TO 7569 AND SPOT 108 BBLS OF HIGH VIS WT. PILL FROM 7569 TO 6400 17:00 - 18:30 1.50 DRILL N DPRB SURF TRIP OUT TO 6357 18:30 - 19:30 1.00 DRILL N DPRB SURF ORIENT AND TIME DRILL TO OPEN HOLE, SIDE TRACK WELL @ 6400 19:30 - 00:00 4.50 DRILL N DPRB SURF DRILL DIRECTIONAL 6400 TO 6654 WITH 3100 PSI, 480 GPM, 50 RPMS, 20/30 BIT WT, TO 8,000, ECD 9.9, AST 3.5 ART 1, 517/2002 00:00 - 23:30 23.50 DRILL P SURF DRIll DIRECTIONAL 6654 TO TO AT 8317 WITH 3650 PSI, 500 GPM, 80 RPMS, 20/30 BIT WT, TO 8,000, ECD 10.0, AST 13.6 ART 3.7, 23:30 - 00:00 0.50 DRIll P SURF CIRC, 3 BOTTOMS UP WITH 3650 PSI 500 GALS MIN 80 RPM ECD 9.8 5/8/2002 00:00 - 02:30 2.50 DRILL P SURF CIRC AT TO, THREE BOTTOMS UP, WITH 500 GALS MIN. 3650 PSI 80 RPMS Printed: 5/2812002 11: 19:07 AM ) ') BP EXPLORATION Operations Sum.maryReport Page 3 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-27 MPS-27 DRILL +COMPLETE DOYON DOYON 141 Start: 5/1/2002 Rig Release: 5/22/2002 Rig Number: 141 Spud Date: 5/1/2002 End: 5/22/2002 Date From - To Hours Task Code NPT Phase Description of Operations 5/8/2002 02:30 - 04:30 2.00 DRILL P SURF SHORT TRIP UP TO 6,200, NO PROBLEMS 04:30 - 05:30 1.00 DRILL P SURF TRIP BACK TO BOTTOM, WASH 90 FT. NO FILL 05:30 - 08:30 3.00 DRILL P SURF CIRC THREE BOTTOMS UP 24,000 PUMP STKS. 500 GALS MIN, 3650 PSI, 80 RPMS 08:30 - 10:30 2.00 DRILL P SURF TRIPPING OUT TO 6,200, PULLING STANDS AND RACK IN DERRICK (NO PROBLEMS) 10:30 - 21 :00 10.50 DRILL P SURF LAYING DOWN 4" DRILL PIPE OUT OF HOLE AND DERRICK WIPE TIGHT SPOTS @ 2900,2400,1950,1685 (10-15,000 OVERPULLS) 21 :00 - 00:00 3.00 DRILL P SURF LAYING DOWN BHA, AND DOWN LOAD MWD 5/9/2002 00:00 - 01 :00 1.00 DRILL P SURF LAYING DOWN BHA 01 :00 - 02:00 1.00 CASE P SURF RIG UP TO RUN 7" CSG, PJSM, 200 TON AND USE HAND SLIPS 02:00 - 05:30 3.50 CASE P SURF RUNNING 7' 26# 1-80 CSG TO 2844 05:30 - 07:30 2.00 CASE N DPRB SURF CIRC AND WORK CSG TRYING TO GET PASS BRIDGE @ 2844, MADE NO HEAD WAY 07:30 - 14:30 7.00 CASE N DPRB SURF LAYING DOWN CSG 14:30 - 15:00 0.50 CASE N DPRB SURF RIG UP TO PICKUP HOLE OPENER AND BHA 15:00 - 16:00 1.00 CASE P SURF CUT DRILL LINE 16:00 - 19:30 3.50 CASE N DPRB SURF PICKING UP 9 7/8 HOLEOPENER AND, BITSUB, XaVER, FLEX DC, STAB, 2 FLEX DC, STAB, JARS, XOVER AND 4" DRILL PIPE TO 2,840 (SET DOWN ON BRIDGE WITH HOLE OPENER) 19:30 - 20:00 0.50 CASE N DPRB SURF REAM AND WASH BRIDGE @ 2844 WITH 500 GALS MIN. 1200 PSI 120 RPMS 20:00 - 21 :00 1.00 CASE N DPRB SURF PICKED UP PIPE TO 3,513 ( NO PROBLEMS) CIRC AND SLUG PIPE AND PICKED UP 3 MORE JOINTS AND TRIP IN TO 3,607 21 :00 - 23:00 2.00 CASE N DPRB SURF TRIPPING OUT STANDING PIPE IN DERRICK, ONE OVER PULL @ 1170 FT 15,000# (WIPED ONE TIME, OK) 23:00 - 00:00 1.00 CASE N DPRB SURF LAY DOWN BHA 5/10/2002 00:00 - 00:30 0.50 CASE N DPRB SURF CLEAR FLOOR TO RUN CSG 00:30 - 01 :30 1.00 CASE P SURF RIG UP TO RUN CSG AND PJSM 01 :30 - 10:00 8.50 CASE P SURF PICKING UP 203 JTS 7" 26# L-80 CSG, LANDED WITH 35,000 STRING WT., SHOE @ 8301 FLOAT COLLAR 8217 10:00 - 11 :00 1.00 CASE P SURF CIRC, TRU FRANKS FILL UP TOOL WITH 600 PSI 336 GALS PER MIN, FOR 416 BBLS 11 :00 - 12:00 1.00 CASE P SURF RIG DOWN FRANKS TOOL, RIG UP CEMENT HEAD 12:00 - 13:00 1.00 CASE P SURF CIRC TRU CEMENT HEAD WITH 600 PSI 336 GALS PER MIN, 633 BBLS, THIN MUD 13:00 - 18:45 5.75 CASE P SURF CEMENT WITH HALLIBURTON, PUMPED 10 WATER, TEST LINES TO 3500PSI, 65 WATER, 50 BBLS 10.2 SPACER WITH DYE, 935 BBLS, 10.7 CLASS L, YIELD 4.16 LEAD CEMENT WITH FULL RETURNS, PUMPING @ 6 BBLS MIN., LOST RETURNS PUMP 70 MORE BBLS LEAD W/ NO RETURNS TOTAL OF 1360 SXS. 1005 BBLS LEAD, SWITCH TO TAIL CEMENT PUMP 650 SXS, CLASS G 15.8,YIELD 1.15, TOTAL 133 BBLS, PUMPED @ 4 BBLS MIN, NO RETURNS, DROP TOP PLUG, PUMP 30 WATER,SWITCH TO RIG PUMPS DISPLACE WITH 5 BBLS MIN. WITH 285 BBLS MUD, NO RETURNS, NO DYE OR SPACER TO SURFACE, TOTAL LOSSES TO WELL 518 BBLS, Printed: 5/2812002 11: 19:07 AM ) ') BP EXPLORATION Operations Summary Report Page 4 ata Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-27 M PS-27 DRILL +COMPLETE DOYON DOYON 141 Start: 5/1/2002 Rig Release: 5/22/2002 Rig Number: 141 Spud Date: 5/1/2002 End: 5/22/2002 Date From -To Hours Task Code NPT Phase Descriptionot Operations 5/10/2002 13:00 - 18:45 5.75 CASE P SURF CAL.CEMENT TOP WITH 617 BBLS OF LEAD OUTSIDE PIPE WHEN WE LOST RETURNS IS 788 FT. BUMP PLUG W/2000# FLOATS OK 18:45 - 22:00 3.25 CASE P SURF LAY DOWN LANDING JT, NIPPLE DOWN DIVERTER 22:00 - 23:30 1.50 CASE P SURF PICKING UP 1" PIPE FOR TOP JOB, RUN TO 870' TAG UP AT 870' 23:30 - 00:00 0.50 CASE P SURF RIG UP TO CIRC TRU 1" WITH WATER 5/11/2002 00:00 - 02:30 2.50 CASE P SURF CIRC. AND DISPLACE CSG ANNULUS WITH WATER, SAW TRACES OF CEMENT AND DYE, PUMPED 175 BBLS WATER @ 1 1/4 BBLS MIN. 1200 PSI 02:30 - 03:00 0.50 CASE P SURF OFF LOAD WATER TRUCKS 03:00 - 08:30 5.50 CASE P SURF CEMENT 7" ANNULUS TRU 1" @ 870' WITH 316 BBLS CLASS L 10.7427 SXS, 20 BBLS OF 10.7 CEMENT TO SURFACE 08:30 - 18:00 9.50 DRILL P INT1 N/U HEAD FMC GEN-6 11" BY5000# AND TEST TO 1,000#, NIPPLE UP BOPS, BOPS WERE BROKEN IN 5 PIECES HAD TO RESTACK. 18:00 - 19:30 1.50 DRILL P INT1 TRIP IN HOLE WITH 4" DRILL PIPE 19:30 - 20:30 1.00 DRILL P INT1 REPAIR FLOW LINE 20:30 - 23:00 2.50 DRILL P INT1 LAYING DOWN 4" DRILL PIPE 23:00 - 00:00 1.00 DRILL P INT1 CHANGE OUT SAVER SUB. ON TOP DRIVE TO 3.5 5/12/2002 00:00 - 01 :00 1.00 BOPSURP INT1 CHANGE OUT SAVER SUB. AND PULL WEAR RING 01 :00 - 05:30 4.50 BOPSUR P INT1 TEST BOPS 250-4,000# HYDRIL 250-2,500# OK NO LEAKS, WITNESS OF BOP TEST WAS WAVIER BY LOU GRIMALDI 05:30 - 06:00 0.50 BOPSUR P INT1 INSTALL WEAR RING 06:00 - 11 :00 5.00 DRILL P INT1 PICKING UP 3.5 PIPE 15.50# (54 STANDS) 11 :00 -12:00 1.00 DRILL P INT1 CIRC, VOL. OF 3.5 PIPE 12:00 - 13:30 1.50 DRILL P INT1 TRIPPING OUT WITH 3.5 AND STAND IN DERRICK 13:30 - 16:30 3.00 DRILL P INT1 PICK UP BHA. BIT SEC. 2643 WITH 3/12 JETS, 4 3/4 SERRYDRILL MOTOR WITH 1.5 BEND, FLOAT SUB,4 3/4 GR & EWD, 4 3/4 PWD & PM, HANG OFF SUB, 3 NON MAG FLEX DC., JARS, 16:30 - 23:30 7.00 DRILL P INT1 PICKING UP 3.5 13.30# DRILL PIPE (200 JTS 66 STANDS) 23:30 - 00:00 0.50 DRILL P INT1 CIRC BOTTOMS WITH 250 GALS MIN. 2400 PSI 50 RPMS 5/13/2002 00:00 - 00:30 0.50 DRILL P INT1 CIRC 00:30 - 01 :30 1.00 DRILL P INT1 TEST 7" 26# CSG TO 4,000 PSI FOR 30 MIN. 01 :30 - 03:30 2.00 DRILL P INT1 DRILL CEMENT, FLOAT@ 8,217 AND SHOE @ 8,301, WASH TO 8317 AND DRILL NEW HOLE TO 8347 03:30 - 04:30 1.00 DRILL P INT1 CIRC, BOTTOMS UP WITH 250 GALS MIN 2300 PSI 04:30 - 05:00 0.50 DRILL P INT1 FIT TEST, WITH 9.0 MUD IN HOLE TVD 4,100 430 PSI = 11.0 MUD WT. 05:00 - 06:00 1.00 DRILL P INT1 CIRC AND DISPLACE HOLE WITH 9.1 FLOW-PRO MUD 06:00 - 00:00 18.00 DRILL P INT1 DIRECTIONAL DRILL 8347 TO 10,028 WITH 250 GALS MIN, 2600 PSI, 317,000 BIT WT., 80 RPM, ECD 11.3 TO. 5,000 ART 6.7 AST 4 (CONTROL DRILL @ 200 FT PER HR.) 5/14/2002 00:00 - 10:30 10.50 DRILL P INT1 DIRECTIONAL DRILL FROM 10,028' TO 11186' - WOB 0/5K - GPM 250 - PP 2650 - RPM 80 - TO 5K ON BTM - TO 4K OFF BTM - ECD 11.6 - PU 105K - SO 65K - ROT 85K 10:30 - 14:00 3.50 DRILL P INT1 CIRCULATE 3 X BOTTOMS UP - GPM 280 - PP 3100 - RPM 100 - TQ 5K 14:00 - 16:30 2.50 DRILL Þ INT1 PUMP OUT TO SHOE FROM 11186' TO 8267' - HOLE IN EXCELLENT SHAPE Printed: 512812002 11: 19:07 AM ) \ BP EXPLORATION Operations Summary Report Page 5 ofB Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-27 MPS-27 DRILL +COMPLETE DOYON DOYON 141 Start: 5/1/2002 Rig Release: 5/22/2002 Rig Number: 141 Spud Date: 5/1/2002 End: 5/22/2002 Date From-To HoLirs Task Code NPT Phase Description of Operations 5/14/2002 16:30 - 17:00 0.50 DRILL P INn SERVICE TOP DRIVE AND BLOCKS 17:00 - 18:30 1.50 DRILL P INT1 RIH FROM 8267' TO 11141' - PRECAUCTIONARY WASH FROM 11141' TO 11186' - HOLE IN EXCELLENT SHAPE 18:30 - 21 :30 3.00 DRILL P INT1 CIRCULATE 3 X BOTTOMS UP - GPM 280 - PP 3100 - RPM 100 - TO 5K 21 :30 - 00:00 2.50 DRILL P INT1 PUMP OUT TO SHOE FROM 11186' TO 8267' 5/15/2002 00:00 - 03:00 3.00 DRILL P INT1 MONITOR WELL - WELL STABLE - PUMP DRY JOB - POOH TO BHA 03:00 - 04:00 1.00 DRILL P INn DOWNLOAD MWD 04:00 - 04:30 0.50 DRILL P INT1 LAY DOWN BHA & CLEAR RIG FLOOR 04:30 - 05:00 0.50 CASE P INT1 RIG UP CASING RUNNING TOOLS - PJSM WITH CREW ON RUNNING LINER 05:00 - 07:00 2.00 CASE P INT1 RUN 75 JOINTS OF 4.5" SLOTTED LINER - PICK UP PACKER / HANGER AND MAKE UP TO LINER 07:00 - 11 :00 4.00 CASE P INT1 RUN LINER IN HOLE ON 3.5" DRILL PIPE TO 11155' 11 :00 - 12:00 1.00 CASE P INT1 DROP BALL - SET PACKER - TOP OF LINER 8165'- BOTTOM OF LINER 11155' 12:00 - 15:00 3.00 CASE P INT1 POOH WITH LINER RUNNING TOOL - LAY DOWN RUNNING TOOL 15:00 - 15:30 0.50 BOPSUR P INT2 PULL WEAR RING - SET TEST PLUG 15:30 - 20:00 4.50 BOPSUR P INT2 TEST BOPS - ANNULAR 250 LOW 5 MINS 2500 HIGH 5 MINS - TOP RAMS - BOTTOM RAMS - BLIND RAMS - CHOKE MANIFOLD - HCR CHOKE VALVES - MANUAL CHOKE VALVES - TIW - DART - UPPER - LOWER IBOP VALVES - 250 LOW 5 MINS - 4000 HIGH 5 MINS- ACCUMULATOR TEST - ALL TEST GOOD 20:00 - 20:30 0.50 BOPSUR P INT2 PULL TEST PLUG - SET WEAR RING 20:30 - 00:00 3.50 STWHIP P INT2 PICK UP WHIPSTOCK MILLING ASSEMBLY - MAKE UP - PU MWD - MILLS - DC'S - 3.5" HEAVY WEIGHT DRILL PIPE 5/16/2002 00:00 - 04:00 4.00 STWHIP P INT2 RIH WITH WHIPSTOCK ASSY 04:00 - 04:30 0.50 STWHIP P INT2 SET WHIPSTOCK 8 DEGREE LEFT OF HIGH SIDE - TOP OF WINDOW 7948' 04:30 - 08:00 3.50 STWHIP P INT2 MILL WINDOW FROM 7948' TO 7960' - DRILL TO 7973' 08:00 - 09:30 1.50 STWHIP P INT2 CIRCULATE HOLE CLEAN - GPM 300 - 2 X BOTTOMS UP - MONITOR WELL - WELL STATIC - PUMP DRY JOB 09:30 - 12:30 3.00 STWHIP P INT2 PULL OUT HOLE WITH WHIPSTOCK RUNNING ASSY -LAY DOWN ASSY - PU MOTOR MAKE UP TO MWD STAND BACK - STAND BACK DC'S - 3.5" HWDP 12:30 - 13:00 0.50 BOPSUR P INT2 FLUSH BOP'S OF METAL CUTTINGS 13:00 - 15:00 2.00 DRILL P INT2 PU DILLING ASSY - ORIENT AND PROGRAM MWD 15:00 - 18:00 3.00 DRILL P INT2 RIH TO 7888' - FILLING PIPE EVERY 25 STANDS 18:00 - 19:00 1.00 DRILL P INT2 CUT DRLG LINE - RIG SERVICE 19:00 - 00:00 5.00 DRILL P INT2 ORIENT ASSY TO HIGH SIDE - CON'T RIH TO 7963' - SLIGHT BOBBLE GOING INTO WINDOW - BRING PUMPS ON WORK STING FROM 7963' TO 7973' CLEANING UP PILOT HOLE - DIRECTIONAL DRILL FROM 7973' TO 8351'- WOB 5K TO 10K - RPM 80 - TO 4K - GPM 250 - PP 2250- ECD 11 - PU 87K - SO 64K - ROT 76K 5/17/2002 00:00 - 08:00 8.00 DRILL P INT2 DIRECTIONAL DRILL FROM 8351' TO 9028' - 5K TO 1 OK - RPM 80 - TQ 5K ON BTM - 3K OFF BTM - GPM 250 - PP 2260 - ECD 11.2 - PU 90K - SO 60K - ROT 75K 08:00 - 09:30 1.50 DRILL N DFAL INT2 SPERRY SUN LWD FAILURE (RESISTIVITY FLAT LlNED)- CIRCULATE 2 X BOTTOMS UP - RPM 80 - 250 GPM - PP Printed: 5/2812002 11: 19:07 AM ') ) BPEXPLORA TION Operations$ummary Report Page 60f 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M PS-27 MPS-27 DRILL +COMPLETE DOYON DOYON 141 Start: 5/1/2002 Rig Release: 5/22/2002 Rig Number: 141 Spud Date: 5/1/2002 End: 5/22/2002 Date From-To Hours Task Code NPT Phase Description, of Operations 5/17/2002 08:00 - 09:30 1.50 DRILL N DFAL INT2 2150 09:30 - 10:30 1.00 DRILL N DFAL INT2 PUMP OUT FROM 9028' TO 7973' . PULL THROUGH WHIPSTOCK WITHOUT PUMP OR ROTATION TO 7850'- NO PROBLEMS - HOLE IN GOOD SHAPE 10:30 . 13:00 2.50 DRILL N DFAL INT2 MONITOR WELL - WELL STATIC - PUMP DRY JOB. POOH FROM 7850' TO BHA 13:00 -16:30 3.50 DRILL N DFAL INT2 STAND BACK JARS - FLEX DC'C - DOWN LOAD MWD - LD HANG OFF SUB. CHANGE OUT SPERRY SUN MWD - ORIENT AND PROGRAM MWD - RIH WITH FLEX DC'S - JARS - PULSE TEST MWD 16:30 - 20:00 3.50 DRILL N DFAL INT2 RIH WITH 3.5" DP TO 7888' - FILLING PIPE EVERY 25 STANDS - ORIENT MOTOR TO HIGH SIDE - RIH TO 8980' NO PUMP OR ROTATION - NO PROBLEMS GOING THROUGH WHIPSTOCK 20:00 - 20:30 0.50 DRILL N DFAL INT2 MAD PASS LOGGING FROM 8980' TO 9028' 20:30 - 00:00 3.50 DRILL P INT2 DIRECTIONAL DRILL FROM 9028' TO 9429 - WOB 3K TO 10K - RPM 80 - TO 6K ON BTM - 4K OFF BTM - GPM 250- PP 2400 - ECD 10.9 TO 11.4 - MUD CUT FROM 9.2# TO 7.7# ON BTMS UP AFTER TRIP - ON CONNECTIONS MUD CUT FROM 9.2# TO 8.5# 5/18/2002 00:00 - 21 :30 21.50 DRILL P INT2 DIRECTIONAL DRILL FROM 9429' TO 11255' MD (3959' TVD) - T.D. OA LATERAL - WOB 3K TO 10K . RPM 80 . TO 6K ON BTM - 4K OFF BTM - GPM 250 - PP 2600 - ECD 11.3 TO 11.7 - PU 95K - SO 50K - ROT 76K - DRILLING RATE HELD TO MAXIUM 200 FEET PER HOUR PER GEOLOGIST 21 :30 - 00:00 2.50 DRILL P INT2 CBU 3 X - GPM 280 - PP 3000 - RPM 100 - TO 4K 5/19/2002 00:00 - 02:30 2.50 DRILL P INT2 PUMP OUT TO 7992' - GPM 250 - PP 2100 - SHUT DOWN PUMP PULL THROUGH WHIPSTOCK WITHOUT PUMPING OR ROTATION TO 7900'. NP PROBLEMS WITH HOLE OR WHIPSTOCK 02:30 - 03:00 0.50 DRILL P INT2 MONITOR WELL. WELL STABLE. RIG SERVICE - TOP DRIVE SERVICE 03:00 - 04:00 1.00 DRILL P INT2 RIH FROM 7900' TO 11255' - FILL EVERY 25 STANDS - NO PROBLEMS GOING THROUGH WHIPSTOCK - HOLE IN GOOD SHAPE 04:00 - 06:30 2.50 DRILL P INT2 CBU 3 X TIMES - SPOT NEW MUD IN DRILL STRING - GPM 280 - PP 2800 - RPM 100. TO 3K - WHILE CIRCULATING 06:30 - 08:30 2.00 DRILL P INT2 PUMP OUT TO 7992' . GPM 250 - PULL TO 7900' WITHOUT PUMP OR ROTATION THROUGH WHIPSTOCK. NO PROBLEMS 08:30 - 09:00 0.50 DRILL P INT2 MONITOR WELL - WELL STATIC - PUMP DRY JOB 09:00 . 11 :00 2.00 DRILL P INT2 POOH TO BHA 11 :00 - 12:00 1.00 DRILL P INT2 LD BHA 12:00 - 14:30 2.50 DRILL P INT2 PU JT 3.5" HWDP - MU WHIPSTOCK RETRIEVING TOOL - MU MWD - ORIENT - DOWN LOAD MWD . REPROGRAM TOOL - MU BUMPER SUB - OIL JARS. RIH WITH 4 STANDS DC'S - 5 STANDS 3.5" HWDP - PULSE TEST MWD 14:30.17:00 2.50 DRILL P INT2 RIH TO 7901' . FILLING EVERY 25 STANDS 17:00.17:30 0.50 DRILL P INT2 BREAK CIRC. ORIENT RETRIEVING TOOL. LATCH ONTO WHIPSTOCK @ 7952 '. PULL WHIPSTOCK LOOSE 150K - 60K OVER STRING WEIGHT - RELEASE ANCHOR. MONITOR WELL - WELL STATIC - PUMP DRY JOB 17:30 . 21 :00 3.50 DRILL P INT2 POH WITH WHIPSTOCK TO BHA Printed: 5/2812002 11: 19: 07 AM .') ') BP EXPLORATION Operations Summary Report Page? of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-27 M PS-27 DRILL +COMPLETE DOYON DOYON 141 Start: 5/1/2002 Rig Release: 5/22/2002 Rig Number: 141 Spud Date: 5/1/2002 End: 5/22/2002 Date From -To Hours Task Code NPT Phase Description of Operations 5/19/2002 21 :00 - 00:00 3.00 DRILL P INT2 LAY DOWN 3.5" HWDP - 4.75" DC'S - BUMPER SUB - OIL JARS - HANG OFF SUB - DOWN LOAD MWD - LD MWD - BAKER WHIPSTOCK TRAY / ANCHOR - 6 JTS 3.5" DP - 1 PUP / SEAL ASSEMBLY 5/20/2002 00:00 - 00:30 0.50 DRILL P INT2 RIG UP CASING TOOLS TO RUN 4.5" LINER - PJSM ON RUNNING LINER 00:30 - 02:30 2.00 DRILL P INT2 PU 77 JTS 4.5" SLOTTED LINER 02:30 - 04:30 2.00 DRILL P INT2 MAKE UP HANGER ASSEMBLY - RIH TO 7948' 04:30 - 05:30 1.00 DRILL P INT2 ORIENT - ACCESS LINER OUT WINDOW 05:30 - 07:00 1.50 DRILL P INT2 CON'T RIH WITH LINER TO 11008' 07:00 - 08:00 1.00 DRILL P INT2 HOOK LINER AT 7960' - DROP BALL SET HANGER AT 7936' 08:00 - 11 :00 3.00 DRILL P INT2 MONITOR WELL - WELL STATIC - POH LAYING DOWN 35 STANDS OF 3.5" DP 11 :00 - 13:30 2.50 DRILL P INT2 MAKE UP MULE SHOE - RIH TO 7920' 13:30 - 15:00 1.50 DRILL P INT2 DISPLACE WELL WITH 8.8 NACL - PUMP SWEEP - 6550 STKS AT 9.4 BPM 15:00 - 16:00 1.00 DRILL P INT2 DISPLACE WELL WITH 9.2 NACL - 3840 STKS - 9.8 BPM 16:00 - 16:30 0.50 DRILL P INT2 MONITOR WELL - WELL STATIC 16:30 - 17:30 1.00 DRILL P INT2 CUT DRLG LINE - RIG SERVICE 17:30 - 22:30 5.00 DRILL P INT2 POH LAYING DOWN 3.5" DP 22:30 - 00:00 1.50 DRILL P INT2 CHANGE OUT 3.5" SAVOR SUB TO 4" XT39 - CHANGE OUT GRABBER DIES 5/21/2002 00:00 - 01 :00 1.00 DRILL P INT2 CHANGE 3.5" TO 4" SAVER SUB - GRABBER DIES 01 :00 - 01 :30 0.50 BOPSUR P COMP PULL WEAR RING 01 :30 - 03:00 1.50 RUNCOI\.tP COMP RIG UP CASING TOOLS - I LINE SPOOL - TO RUN 4.5" COMPLETION 03:00 - 06:30 3.50 RUNCOI\.tP COMP PJSM WITH CREW AND ALL PERSONNEL INVOLVED IN COMPLETION OPERATION - PU COMPLETION ASSEMBLY'S - TIE PHOENIX GAUGES TOGETHER - AND TO I LINE 06:30 - 14:00 7.50 RUNCOI\.tP COMP RIH WITH COMPLETION STRING 14:00 - 16:30 2.50 RUNCOI\.tP COMP INSTALL TWC - TIE IN I WIRE - LAND TUBING - RUN IN LOCK DOWN SCREWS - TUBING LANDED AT 16:30 HRS 16:30 - 17:00 0.50 RUNCOI\.tP COMP LAY DOWN LANDING JOINT - RIG DOWN CASING TOOLS - TEST TWC / SEALS TO 1000 PSI 17:00 - 18:00 1.00 RUNCOI\.tP COMP NIPPLE DOWN 13 5/8" BOP'S 18:00 - 19:30 1.50 RUNCOI\.tP COMP ORIENT - NIPPLE UP CIW 41/16" 5000 TREE- 19:30 - 20:30 1.00 RUNCOI\.tP COMP TEST TUBING HANGER VOID 5K 10 MINS - TEST TREE AND RECORD 5K 15 MIN 20:30 - 22:00 1.50 RUNCOI\.tP COMP PULL TWC 22:00 - 00:00 2.00 RUNCOI\.tP COMP CIRC - HEAT COMPLETION FLUID BEFORE SETTING PACKER - WARMING UP FLUID TO 100 DEGREE - 5/22/2002 00:00 - 02:30 2.50 RUNCOI\.tP COMP CIRCULATE - HEATING COMPLETION FLUID TO 100 DEGREE 02:30 - 03:30 1.00 RUNCOI\.tP COMP DROP BALL - SET PACKER - TEST @ 4000 PSI FOR 30 MINS ON CHART - BLEED TUBING DOWN TO 2500 PSI 03:30 - 04:00 0.50 RUNCOI\.tP COMP TEST ANNULUS TO 4500 PSI FOR 30 MINS ON CHART - 04:00 - 05:00 1.00 RUNCOI\.tP COMP BLEED TUBING DOWN TO 1500 PSI- RP VALVE SHEARED OUT - BLEED TO 0 PSI - PUMP 27 BBLS DIESEL IN TUBING FOR FREEZE PROTECTION 05:00 - 06:30 1.50 RUNCO~ COMP U-TUBE WELL - CLEANING PITS - CHANGE OUT 3.5" RAMS FROM BOTTOM SET RAMS TO 4" 06:30 - 07:00 0.50 RUNCO~ COMP SET BPV - CONTINUE CLEANING PITS Printed: 5/2812002 11:19:07AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) '\ BP EXPLORATION Operations Summary"Report MPS-27 MPS-27 DRILL +COMPLETE DOYON DOYON 141 Start: 5/1/2002 Rig Release: 5/22/2002 Rig Number: 141 5/22/2002 07:00 - 09:00 From - To Hours Task Code NPT Phase COMP SECURE WELL - CLEAN CELLAR AREA - RELEASE RIG Description of Operations Date 2.00 RUNCOMJ Page aof a Spud Date: 5/1/2002 End: 5/22/2002 Printed: 5/28/2002 11: 19:07 AM aOdt -685 27-Jun-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPS-27 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 6,385.70' MD Window / Kickoff Survey 6,400.00 MD (if applicable) Projected Survey: 11 ,186.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards William T. Allen Survey Manager RECEIVED Attachment(s) JUL :2 2002 Alaska Oil & Gas Cons. Commision Anchorage D pc¡:a F"~ r..1 r\.. ~ 11.- :~ ~ v.. ""- ~ f' ¡"~ F' w ~. I¡¡¡ , - ¡-=t '.,' .¡ f.A-'~¡': Hi' - ~ ti~ ~ ~ 't - BP EXPLORATIØ"~ir1JJt..A.SKA) INC. -- Milne Point Unit BPXA Milne Point MPS, .S/ot MPS-27 MPS.27 ' Job No. AKZZ22071, Surveyed: 14 May, 2002 _/ SURVEY REPORT 26 June,. 2002 Your Ref: API 5OO823084OD Surface Coordinates: 5999943.96 H, 565700.12 E (10° 24' 37.0499" N, 149027' 54.0825" W) Kelly Bushing: 67.3Oft above Mean Sea Level - =at ,.-.¡ II .y.....,., DRILLING S-=..RVIc:es A Halliburton Company Survey Ref: svy10129 ~~F . . . Sperry-Sun DrlllillgServices Survey Report tor-MPS..27 Your Ref: API 5l1lJ2f23D8400 Job No. AKZZ22071, Surveyød: 14 May, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6385.70 72.740 302.100 3474.37 3541.67 2542.14 N 3723.01 W 6002453.25 N 561954.89 E 3797.21 Tie On Point 6400.00 72.800 301.900 3478.60 3545.90 2549.38 N 3734.59 W 6002460.39 N 561943.24 E 1 .400 3809.01 Window Point "'- 6479.31 69.430 299.630 3504.27 3571.57 2587.77 N 3799.05 W 6002498.21 N 561878.45 E 5.038 3874.58 6572.55 69.270 297.310 3537.16 3604.46 2629.35 N 3875.74 W 6002539.12 N 561801.40 E 2.335 3952.48 6665.95 70.710 293.690 3569.13 3636.43 2667.12 N 3954.94 W 6002576.18 N 561721.87 E 3.955 4032.77 6759.55 70.430 289.540 3600.27 3667.57 2699.63 N 4036.98 W 6002607.97 N 561639.55 E 4.192 4115.74 6852.99 71.900 285.970 3630.45 3697.75 2726.58 N 4121.19W 6002634.18 N 561555.10 E 3.943 4200.72 6946.59 71.320 284.670 3659.98 3727.28 2750.05 N 4206.85 W 6002656.89 N 561469.24 E 1.456 4287.04 7040.24 71.270 282.020 3690.02 3757.32 2770.52 N 4293.15 W 6002676.61 N 561382.76 E 2.681 4373.91 7133.20 71.830 280.100 3719.44 3786.74 2787.43 N 4379.69 W 6002692.76 N 561296.08 E 2.050 4460.92 7226.53 70.390 277.410 3749.66 3816.96 2800.88 N 4466.95 W 6002705.44 N 561208.70 E 3.133 4548.54 7320.28 68.310 273.820 3782.73 3850.03 2809.48 N 4554.23 W 6002713.27 N 561121.35 E 4.214 4636.04 7413.36 68.400 269.910 3817.07 3884.37 2812.29 N 4640.68 W 6002715.32 N 561034.88 E 3.906 4722.54 7507.14 69.280 264.630 3850.95 3918.25 2808.12 N 4728.00 W 6002710.38 N 560947.60 E 5.333 4809.69 7600.00 70.590 259.130 3882.82 3950.12 2795.79 N 4814.30 W 6002697.29 N 560861.41 E 5.739 4895.59 7693.58 72.090 255.4 70 3912.77 3980.07 2776.29 N 4900.77 W 6002677.03 N 560775.11 E 4.037 4981.44 7785.82 73.250 250.190 3940.27 4007.57 2750.29 N 4984.86 W 6002650.30 N 560691.26 E 5.607 5064.71 7880.32 74.490 244.720 3966.54 4033.84 2715.49 N 5068.66 W 6002614.76 N 560607.77 E 5.713 5147.44 7973.94 76.810 239.910 3989.75 4057.05 2673.35 N 5148.93 W 6002571.91 N 560527.87 E 5.560 5226.42 8066.85 82.220 236.810 4006.66 4073.96 2625.43 N 5226.66 W 6002523.31 N 560450.56 E 6.683 5302.68 8159.74 83.150 234.780 4018.49 4085.79 2573.64 N 5302.86 W 6002470.85 N 560374.83 E 2.388 5377.29 8254.45 82.370 234.000 4030.42 4097.72 2518.93 N 5379.24 W 6002415.48 N 560298.93 E 1.160 5452.01 8325.84 83.440 233.980 4039.24 4106.54 2477.28 N 5436.55 W 6002373.32 N 560241.99 E 1.499 5508.05 8373.19 89.800 237.210 4042.03 4109.33 2450.59 N 5475.52 W 6002346.29 N 560203.25 E 15.058 5546.21 8422.42 93.690 237.310 4040.53 4107.83 2423.99 N 5516.90 W 6002319.32 N 560162.11 E 7.904 5586.78 8465.37 93.230 234.300 4037.94 4105.24 2399.90 N 5552.36 W 6002294.92 N 560126.86 E 7.077 5621.50 8514.65 94.290 228.560 4034.71 4102.01 2369.25 N 5590.79 W 6002263.94 N 560088.71 E 11.820 5659.00 8556.22 93.320 222.330 4031.94 4099.24 2340.16 N 5620.33 W 6002234.59 N 560059.42 E 15.134 5687.66 8608.22 89.240 218.560 4030.78 4098.08 2300.62 N 5654.04 W 6002194.75 N 560026.06 E 10.681 5720.18 8653.04 89.430 218.120 4031.30 4098.60 2265.46 N 5681.84 W 6002159.36 N 559998.57 E 1.069 5746.91 26 June, 2002 - 16:03 Page 20'5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report forcMPS.27 Your Ref: API5002f2308400 Job No. AKZZ22071, SulV8yed: 14 May, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8701.42 90.210 214.320 4031.46 4098.76 2226.44 N 5710.42 W 6002120.08 N 559970.33 E 8.018 5774.32 8744.38 90.590 211.690 4031 .16 4098.46 2190.42 N 5733.82 W 6002083.85 N 559947.25 E 6.185 5796.63 8793.68 89.010 210.500 4031.33 4098.63 2148.20 N 5759.28 W 6002041.42 N 559922.16 E 4.012 5820.82 -- 8836.09 87.860 210.460 4032.49 4099.79 2111.67 N 5780.79 W 6002004.70 N 559900.98 E 2.713 5841.22 8885.32 87.660 209.360 4034.41 4101.71 2069.03 N 5805.31 W 6001961.84 N 559876.83 E 2.269 5864.4 7 8929.85 89.970 211.090 4035.33 4102.63 2030.57 N 5827.72 W 6001923.18 N 559854.76 E 6.480 5885.72 8977.34 90.820 212.040 4035.00 4102.30 1990.10 N 5852.58 W 6001882.50 N 559830.26 E 2.684 5909.36 9021.05 90. 190 210.920 4034.62 4101.92 1952.83 N 5875.41 W 6001845.03 N 559807.76 E 2.940 5931.06 9071.46 89.980 210.150 4034.54 4101.84 1909.41 N 5901.02 W 6001801.39 N 559782.53 E 1.583 5955.37 9113.42 89.570 209.170 4034.71 4102.01 1872.95 N 5921.78 W 6001764.74 N 559762.09 E 2.532 5975.03 9163.18 89.580 209.130 4035.08 4102.38 1829.49 N 5946.02 W 6001721.08 N 559738.24 E 0.083 5997.96 9206.88 88.940 212.690 4035.64 4102.94 1792.01 N 5968.46 W 6001683.40 N 559716.13 E 8.276 6019.28 9257.39 89.300 214.210 4036.42 4103.72 1749.87 N 5996.30 W 6001641.02 N 559688.66 E 3.092 6045.85 9300.48 87.780 214.580 4037.52 4104.82 1714.33 N 6020.63 W 6001605.26 N 559664.64 E 3.630 6069.11 9346.12 87.300 214.290 4039.47 4106.77 1676.72 N 6046.42 W 6001567.43 N 559639.19 E 1.228 6093.76 9392.89 88.530 215.670 4041.18 4108.48 1638.42 N 6073.21 W 6001528.90 N 559612.73 E 3.951 6119.40 9437.49 92.450 216.200 4040.79 4108.09 1602.32 N 6099.38 W 6001492.57 N 559586.88 E 8.869 6144.48 9486.36 92.030 216.730 4038.88 4106.18 1563.05 N 6128.40 W 6001453.04 N 559558.21 E 1.383 6172.31 9531.98 93.970 215.990 4036.50 4103.80 1526.36 N 6155.41 W 6001416.12 N 559531.52 E 4.551 6198.21 9580.52 94.020 216.980 4033.12 4100.42 1487.43 N 6184.20 W 6001376.94 N 559503.08 E 2.037 6225.83 9624.11 92.120 216.710 4030.78 4098.08 1452.60 N 6210.30 W 6001341.88 N 559477.28 E 4.402 6250.88 9670.66 91.760 216.880 4029.20 4096.50 1415.35 N 6238.16 W 6001304.38 N 559449.75 E 0.855 6277.62 9715.51 91.830 217.580 4027.80 4095.10 1379.65 N 6265.29 W 6001268.45 N 559422.94 E 1.568 6303.67 9764.19 91.750 217.440 4026.28 4093.58 1341.06 N 6294.91 W 6001229.59 N 559393.65 E 0.331 6332.13 9811.30 92.020 216.450 4024.73 4092.03 1303.43 N 6323.21 W 6001191.71 N 559365.69 E 2.177 6359.29 9857.41 90.670 215.880 4023.65 4090.95 1266.21 N 6350.41 W 6001154.26 N 559338.81 E 3.178 6385.37 9902.28 90.550 215.360 4023.17 4090.47 1229.74 N 6376.55 W 6001117.56 N 559313.00 E 1.189 6410.40 9950.82 90.650 215.320 4022.66 4089.96 1190.15 N 6404.62 W 6001077.72 N 559285.28 E 0.222 6437.28 9993.52 90.400 214.520 4022.27 4089.57 1155.14 N 6429.06 W 6001042.50 N 559261.14 E 1.963 6460.67 10043.90 90.520 213.470 4021.87 4089.17 1113.37 N 6457.23 W 6001000.48 N 559233.35 E 2.098 6487.58 26 June, 2002 - 16:03 Page 30'5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey ReportforcMPS-27 Your Ref: AP15OlJ29æOBilOO Job No. AKZZ22071, SU11leyèd: 14 May, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS 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) (°/1 OOff) 10086.56 90.190 213.630 4021.60 4088.90 1077.82 N 6480.81 W 6000964.73 N 559210.08 E 0.860 6510.08 10136.58 90.100 213.530 4021.47 4088.77 1036.14 N 6508.47 W 6000922.81 N 559182.79 E 0.269 6536.49 _. 10181.27 90.120 216.110 4021.39 4088.69 999.46 N 6533.99 W 6000885.90 N 559157.59 E 5.773 6560.90 - 10229.25 91.290 218.870 4020.80 4088.10 961.40 N 6563.18 W 6000847.59 N 559128.73 E 6.247 6588.95 10274.45 90.600 218.480 4020.05 4087.35 926.11 N 6591.43 W 6000812.06 N 559100.80 E 1.753 6616.13 10322.64 90.740 218.900 4019.49 4086.79 888.50 N 6621.55 W 6000774.18 N 559071.01 E 0.919 6645.11 10368.31 92.990 219.160 4018.00 4085.30 853.05 N 6650.29 W 6000738.47 N 559042.58 E 4.959 6672.78 10413.71 92.900 219.270 4015.67 4082.97 817.92 N 6678.95 W 6000703.09 N 559014.23 E 0.313 6700.39 10458.72 92.820 218.480 4013.42 4080.72 782.92 N 6707.17 W 6000667.85 N 558986.32 E 1.762 6727.54 10507.57 92.760 218.130 4011.05 4078.35 744.63 N 6737.41 W 6000629.30 N 558956.42 E 0.726 6756.63 10551.20 92.140 216.470 4009.18 4076.48 709.96 N 6763.83 W 6000594.39 N 558930.31 E 4.058 6782.00 10600.19 91.740 216.550 4007.52 4074.82 670.61 N 6792.96 W 6000554.78 N 558901.53 E 0.833 6809.94 10645.73 91.880 216.530 4006.09 4073.39 634.03 N 6820.06 W 6000517.98 N 558874.75 E 0.311 6835.94 10693.36 91.600 215.350 4004.64 4071.94 595.49 N 6848.00 W 6000479.19 N 558847.15 E 2.545 6862.72 10738.66 91.740 215.190 4003.32 4070.62 558.52 N 6874.15 W 6000441.99 N 558821.33 E 0.469 6887.75 10786.97 92.640 215.020 4001.47 4068.77 519.03 N 6901.91 W 6000402.26 N 558793.91 E 1.896 6914.32 10831.54 91.900 213.950 3999.71 4067.01 482.32 N 6927.12 W 6000365.33 N 558769.02 E 2.917 6938.43 10878.96 91.940 214.420 3998.12 4065.42 443.12 N 6953.75 W 6000325.89 N 558742.74 E 0.994 6963.88 10922.48 89.860 214.340 3997.43 4064.73 407.20 N 6978.32 W 6000289.76 N 558718.49 E 4.783 6987.36 10970.83 86.700 215.310 3998.89 4066.19 367.54 N 7005.92 W 6000249.85 N 558691.24 E 6.836 7013.76 11020.71 86.690 214.420 4001.76 4069.06 326.68 N 7034.38 W 6000208.75 N 558663.14 E 1.781 7041.00 11063.70 85.600 214.620 4004.65 4071.95 291.34 N 7058.69 W 6000173.19 N 558639.14 E 2.578 7064.24 11107.63 84.010 214.620 4008.63 4075.93 255.34 N 7083.54 W 6000136.98 N 558614.60 E 3.619 7088.01 11186.00 84.010 214.620 4016.81 4084.11 191.19 N 7127.82 W 6000072.45 N 558570.89 E 0.000 7130.36 Projected Survey 26 June, 2002 - 16:03 Page 4 of 5 DrillQuest 2.00.08.005 .~ . . . "" ~ . Sperry-Sun Ori/llÎlfg/Services SUfV8y Reportf!l!:',!~17 Your Ref: API ~'301IOO Job No. AKZZ22071,Sum,1Id:1"4 May, 2002 BP EXPLORATION (ALASKA) INC. Milne Point Unit BPXA Milne Point MPS All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Welf. The Dogleg Severity is in Degrees per 100 feet (US). ~ Vertical Section is from Well and calculated along an Azimuth of 271.710° (True). -~/ Based upon Minimum Curvature type calculations, at a Measured Depth of 11186.000., The Bottom Hole Displacement is 7130.39ft., in the Direction of 271.537° (True). Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastings (ft) (ft) (ft) Comment 6385.70 6400.00 11186.00 3541.67 3545.90 4084.11 2542.14 N 2549,38 N 191.19 N 3723.01 W 3734.59 W 7127.82 W Tie On Point Window Point Projected Survey Survey tool program for MPS-27 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Toof Description (ft) (ft) (ft) (ft) 0.00 0.00 11186.00 4084.11 AK-6 BP _IFR-AK (MPS-27PB1) -----~------ 26 June, 2002 - 16:03 Page 50f5 DrillQuest 2.00.08.005 ) ) dOJ-o<6S 27 -J u n-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-27 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 6,385.70' MD Window / Kickoff Survey 6,400.00' MD (if applicable) Projected Survey: 11,186.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Su rvey Manager Attachment(s) RECEIVED q J tj 0002 '-'u~ L L AIæka Oil & Gas Cons. Commission Anchorage BP EXPLORA TION-(ALASKA) INC. Milne Po;lft~Unit 8"X(f- Milne Point MPS,-S/ot MPS-27 MPS-27MWD Job No. AKMW22071, Surveyed: 14 May, 2002 SURVEY REPORT 26 June, 2002 Your Ref: APl50Ø292-308400 Surface Coordinates: 5999943.96 N, 565700,,12 E(to024' 37.0499" N, 149° 27' 54.0825" W) Kelly Bushing: 67.3Oft above Mean Sea Level Sf-r-. .. .Y-!5LJr1 DFtILLjNIa =-bRVIc:es A Halliburton Company Survey Ref: svy10115 ," 7~>' >~ . '. ~@{~~- . .. Sperry-Sun Drillilfg Serviees Survey Report for MPS-27 MWD Your Ref: AP/500292308400 Job No. AKMW22071, SUtVeyec#: 14 May, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6385.70 72.740 303.790 3474.39 3541.69 2611.28 N 3674.56 W 6002522.82 N 562002.74 E 3750.84 Tie On Point 6400.00 72.800 301.900 3478.63 3545.93 2618.69 N 3686.03 W 6002530.13 N 561991.20 E 12.631 3762.53 Window Point 6479.31 69.430 299.740 3504.30 3571.60 2657.14 N 3750.45 W 6002568.01 N 561926.44 E 4.969 3828.07 6572.55 69.270 297.440 3537.19 3604.49 2698.89 N 3827.06 W 6002609.08 N 561849.47 E 2.315 3905.89 6665.95 70.710 294.890 3569.15 3636.45 2737.58 N 3905.82 W 6002647.07 N 561770.37 E 2.993 3985.77 6759.55 70.430 290.650 3600.30 3667.60 2771.73 N 3987.19W 6002680.51 N 561688.71 E 4.282 4068.12 6852.99 71.900 287.790 3630.4 7 3697.77 2800.83 N 4070.68 W 6002708.88 N 561604.96 E 3.296 4152.45 6946.59 71.320 286.450 3660.00 3727.30 2826.98 N 4155.56 W 6002734.28 N 561519.85 E 1.493 4238.07 7040.24 71.270 283.620 3690.04 3757.34 2849.99 N 4241.22 W 6002756.53 N 561433.99 E 2.863 4324.38 7133.20 71.830 280.980 3719.46 3786.76 2868.77 N 4327.37 W 6002774.55 N 561347.68 E 2.760 4411.05 7226.53 70.390 276.900 3749.69 3816.99 2882.50 N 4414.57 W 6002787.52 N 561260.36 E 4.414 4498.62 7320.28 68.310 271.570 3782.77 3850.07 2889.00 N 4502.02 W 6002793.25 N 561172.87 E 5.764 4586.22 7413.36 68.400 268.910 3817.11 3884.41 2889.36 N 4588.52 W 6002792.85 N 561086.36 E 2.658 4672.70 7507.14 69.280 262.950 3850.99 3918.29 2883.15 N 4675.71 W 6002785.87 N 560999.23 E 6.000 4759.66 7600.00 70.590 259.280 3882.85 3950.15 2869.67 N 4761.86 W 6002771.63 N 560913.20 E 3.971 4845.37 7693.58 72.090 256.400 3912.80 3980.10 2850.98 N 4848.52 W 6002752.18 N 560826.71 E 3.327 4931.43 7785.82 73.250 251.330 3940.29 4007.59 2826.51 N 4933.06 W 6002726.97 N 560742.38 E 5.395 5015.21 7880.32 74.490 246.080 3966.56 4033.86 2793.55 N 5017.61 W 6002693.26 N 560658.13 E 5.496 5098.73 7973.94 76.810 241.500 3989.78 4057.08 2753.49 N 5098.94 W 6002652.49 N 560577.16 E 5.348 5178.84 8066.85 82.220 238.490 4006.68 4073.98 2707.80 N 5178.01 W 6002606.11 N 560498.49 E 6.637 5256.50 -- 8159.74 83.150 236.070 4018.51 4085.81 2658.00 N 5255.51 W 6002555.63 N 560421.43 E 2.771 5332.49 8254.45 82.370 235.080 4030.45 4097.75 2604.89 N 5333.01 W 6002501.84 N 560344.40 E 1.324 5408.37 8325.84 83.440 237.350 4039.26 4106.56 2565.50 N 5391.89 W 6002461.93 N 560285.87 E 3.493 5466.04 8373.19 89.800 234.080 4042.06 4109.36 2538.89 N 5430.91 W 6002434.98 N 560247.08 E 15.096 5504.26 8422.42 93.690 240.170 4040.55 4107.85 2512.19 N 5472.21 W 6002407.92 N 560206.02 E 14.672 5544.74 8465.37 93.230 233.090 4037.96 4105.26 2488.63 N 5507.99 W 6002384.04 N 560170.45 E 16.489 5579.80 8514.65 94.290 228.4 70 4034.73 4102.03 2457.54 N 5546.08 W 6002352.62 N 560132.64 E 9.599 5616.94 8556.22 93.320 223.470 4031.97 4099.27 2428.72 N 5575.89 W 6002323.54 N 560103.08 E 12.226 5645.88 8608.22 89.240 220.550 4030.80 4098.10 2390.11 N 5610.67 W 6002284.62 N 560068.64 E 9.647 5679.50 8653.04 89.430 215.590 4031.32 4098.62 2354.84 N 5638.30 W 6002249.11 N 560041.33 E 11.074 5706.06 ------------~ 26 June, 2002 - 16:22 Page 20f5 DrillQuest 2.00.08.005 Sperry-Sun Dr¡ ~:: gServices . Survey Report 1or1l!!.8-27-MWlJ Your Ref: API5tJl1823084lJO Job No. AKMW22071, SllMJjød: 14 May, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8701.42 90.210 216.840 4031.48 4098.78 2315.80 N 5666.88 W 6002209.83 N 560013.09 E 3.045 5733.46 8744.38 90.590 209.490 4031.18 4098.48 2279.87 N 5690.37 W 6002173.68 N 559989.92 E 17.131 5755.86 --- 8793.68 89.010 211.420 4031.35 4098.65 2237.37 N 5715.35 W 6002130.97 N 559965.31 E 5.059 5779.57 8836.09 87.860 211.760 4032.51 4099.81 2201.26 N 5737.56 W 6002094.67 N 559943.42 E 2.828 5800.69 8885.32 87.660 210.110 4034.43 4101.73 2159.07 N 5762.85 W 6002052.25 N 559918.50 E 3.374 5824.71 8929.85 89.970 209.600 4035.35 4102.65 2120.46 N 5785.01 W 6002013.45 N 559896.68 E 5.312 5845.71 8977.34 90.820 214.930 4035.02 4102.32 2080.32 N 5810.35 W 6001973.09 N 559871.70 E 11.365 5869.84 9021.05 90.190 212.310 4034.64 4101.94 2043.93 N 5834.55 W 6001936.48 N 559847.82 E 6.165 5892.94 9071.46 89.980 208.160 4034.56 4101.86 2000.38 N 5859.93 W 6001892.72 N 559822.82 E 8.243 5917.01 9113.42 89.570 208.420 4034.73 4102.03 1963.43 N 5879.81 W 6001855.60 N 559803.26 E 1.157 5935.78 9163.18 89.580 211.200 4035.10 4102.40 1920.26 N 5904.55 W 6001812.21 N 559778.91 E 5.587 5959.22 9206.88 88.940 211.520 4035.66 4102.96 1882.95 N 5927.29 W 6001774.70 N 559756.50 E 1.637 5980.83 9257.39 89.300 214.980 4036.44 4103.74 1840.72 N 5954.97 W 6001732.23 N 559729.19 E 6.886 6007.25 9300.48 87.780 214.110 4037.54 4104.84 1805.24 N 5979.40 W 6001696.53 N 559705.07 E 4.064 6030.60 9346.12 87.300 212.540 4039.50 4106.80 1767.14 N 6004.45 W 6001658.22 N 559680.36 E 3.594 6054.51 9392.89 88.530 214.510 4041.20 4108.50 1728.18 N 6030.26 W 6001619.03 N 559654.89 E 4.963 6079.14 9437.49 92.450 217.620 4040.82 4108.12 1692.14 N 6056.51 W 6001582.76 N 559628.96 E 11.218 6104.30 9486.36 92.030 215.080 4038.91 4106.21 1652.82 N 6085.45 W 6001543.18 N 559600.37 E 5.264 6132.06 9531.98 93.970 214.270 4036.52 4103.82 1615.35 N 6111.37W 6001505.49 N 559574.78 E 4.607 6156.85 9580.52 94.020 218.420 4033.13 4100.43 1576.36 N 6140.06 W 6001466.25 N 559546.43 E 8.529 6184.36 9624.11 92. 120 215.680 4030.80 4098.10 1541.62 N 6166.28 W 6001431.28 N 559520.52 E 7.642 6209.53 9670.66 91.760 220.250 4029.22 4096.52 1504.95 N 6194.89 W 6001394.36 N 559492.23 E 9.842 6237.04 9715.51 91.830 218.980 4027.82 4095.12 1470.42 N 6223.47 W 6001359.58 N 559463.95 E 2.835 6264.58 9764.19 91.750 216.730 4026.30 4093.60 1432.01 N 6253.33 W 6001320.90 N 559434.44 E 4.623 6293.28 9811.30 92.020 218.190 4024.75 4092.05 1394.63 N 6281.97 W 6001283.28 N 559406.13 E 3.150 6320.79 9857.41 90.670 218.430 4023.67 4090.97 1358.46 N 6310.54 W 6001246.86 N 559377.87 E 2.974 6348.27 9902.28 90.550 213.720 4023.19 4090.49 1322.21 N 6336.95 W 6001210.38 N 559351.78 E 10.500 6373.59 9950.82 90.650 216.930 4022.68 4089.98 1282.61 N 6365.02 W 6001170.53 N 559324.07 E 6.616 6400.46 9993.52 90.400 218.210 4022.29 4089.59 1248.77 N 6391.05 W 6001136.46 N 559298.33 E 3.054 6425.47 10043.90 90.520 218.390 4021.88 4089.18 1209.24 N 6422.27 W 6001096.66 N 559267.46 E 0.429 6455.50 26 June, 2002 - 16:22 Page 30f5 DrillQuesf 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for WlP8-27 MWD Your Ref: AP 500292308400 Job No. AKMW22071, Sun/eyed: 14 May, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) eft) (ft) (ft) (°/1 OOft) 10086.56 90.190 216.500 4021.62 4088.92 1175.37 N 6448.21 W 6001062.56 N 559241.82 E 4.497 6480.41 10136.58 90.100 215.030 4021.49 4088.79 1134.78 N 6477.44 W 6001021.72 N 559212.95 E 2.944 6508.42 - 10181.27 90.120 216.590 4021.41 4088.71 1098.54 N 6503.59 W 6000985.25 N 559187.12 E 3.491 6533.47 10229.25 91.290 220.630 4020.82 4088.12 1061.06 N 6533.52 W 6000947.51 N 559157.52 E 8.765 6562.27 10274.45 90.600 220.580 4020.07 4087.37 1026.75 N 6562.93 W 6000912.94 N 559128.41 E 1.531 6590.65 10322.64 90.740 220.940 4019.51 4086.81 990.25 N 6594.40 W 6000876.16 N 559097.27 E 0.801 6621.01 10368.31 92.990 219.650 4018.02 4085.32 955.44 N 6623.91 W 6000841.09 N 559068.06 E 5.678 6649.47 10413.71 92.900 219.810 4015.69 4082.99 920.57 N 6652.89 W 6000805.97 N 559039.39 E 0.404 6677.40 10458.72 92.820 222.060 4013.44 4080.74 886.61 N 6682.35 W 6000771.75 N 559010.23 E 4.996 6705.83 10507.57 92.760 217.240 4011.06 4078.36 849.05 N 6713.47 W 6000733.93 N 558979.44 E 9.856 6735.82 10551.20 92.140 219.430 4009.20 4076.50 814.86 N 6740.51 W 6000699.50 N 558952.71 E 5.212 6761.82 10600.19 91.740 215.330 4007.54 4074.84 775.97 N 6770.22 W 6000660.34 N 558923.33 E 8.404 6790.36 10645.73 91.880 215.010 4006.10 4073.40 738.76 N 6796.44 W 6000622.90 N 558897.44 E 0.767 6815.46 10693.36 91.600 213.950 4004.65 4071.95 699.51 N 6823.39 W 6000583.42 N 558870.84 E 2.301 6841.23 10738.66 91.740 214.860 4003.33 4070.63 662.16 N 6848.98 W 6000545.84 N 558845.58 E 2.032 6865.69 10786.97 92.640 214.080 4001.49 4068.79 622.36 N 6876.30 W 6000505.81 N 558818.61 E 2.464 6891.81 10831.54 91.900 211.470 3999.72 4067.02 584.92 N 6900.41 W 6000468.15 N 558794.84 E 6.082 6914.79 10878.96 91.940 217 .480 3998.13 4065.43 545.86 N 6927.22 W 6000428.87 N 558768.37 E 12.667 6940.42 10922.48 89.860 211.150 3997.45 4064.75 509.94 N 6951.74 W 6000392.73 N 558744.17 E 15.308 6963.86 10970.83 86.700 212.320 3998.90 4066.20 468.85 N 6977.15 W 6000351.41 N 558719.11 E 6.969 6988.04 11020.71 86.690 212.570 4001.77 4069.07 426.82 N 7003.87 W 6000309.15 N 558692.77 E 0.501 7013.49 11063.70 85.600 210.980 4004.66 4071.96 390.36 N 7026.46 W 6000272.50 N 558670.50 E 4.477 7034.97 11107.63 84.010 210.090 4008.64 4075.94 352.68 N 7048.68 W 6000234.62 N 558648.61 E 4.144 7056.07 11186.00 84.01 0 210.090 4016.82 4084.12 285.24 N 7087.76 W 6000166.84 N 558610.13 E 0.000 7093.11 Projected Survey ------- --------~. "-- - -- 26 June, 2002 - 16:22 Page 4 of5 DrillQuest 2.00.08.005 j .' Sperry-Sun Drilling Services Survey Report for MPS-27 MWD Your Ref: API5OtIi92308400 Job No. AKMW22071, Sut1lêyed:14 May, 2002 . BP EXPLORATION (ALASKA) INC. Milne Point Unit BPXA Milne Point MPS All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. '-- The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of271.710° (True). "-~' Based upon Minimum Curvature type calculations, at a Measured Depth of 11186.000., The Bottom Hole Displacement is 7093.50ft., in the Direction of 272.305° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 6385.70 6400.00 11186.00 3541.69 3545.93 4084.12 2611.28 N 2618.69 N 285.24 N 3674.56 W 3686.03 W 7087.76 W Tie On Point Window Point Projected Survey Survey tool program for MPS-27 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 11186.00 4084.12 MWD Magnetic (MPS-27PB1 MWD) 26 June, 2002 - 16:22 Page 50f5 DrillQuest 2.00.08.005 ) ) ~()d-()ÕS 27 -J u n-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPS-27PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Su rvey: Window / Kickoff Survey Projected Survey: 0.00' MD 0.00' M D (if applicable) 0.00' MD Please call me at 273-3545 if -you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment(s) ~ ~ P '1 2002 ~.-.... '-- Alaska Oil & Gas Cons, Commission Anchorage : t....: ::: ~~~. ~~- :. i - (, JEF1'" r"'!~..'.::¡,:<: If.~ - .' I~~ ! - ..r; ¡j :~,! ~¡ '!,.. ,- -j p ,¡ \1 " ,.,, '; J ~ u 'i ÍIIiii BP EXPLORA TlONfAl..ASKA) INC. ."-., Milne Point. Unit SPXA Milne Point MPS, Slot MPS-27 MPS.27PB1 Job No. AKZZ22071, SurveYed: 5 May, 2002 SURVEY"PORT 26 June, 2002 Your Ref: API StIfI&tl301t47D Surface Coordinates: 5999943.96 N, 56570ö.12:E'~(10° 24' 37.0499" N, 1490 27' 54.0825" W) Kelly Bushing: 67.3Oft above Mean Sea Level ,,-. !!Ip8Ii 4 ~V~~~:u'" DRILLING êéAVh..ES A Halliburton Company Survey Ref: svy10113 . " . - , Sperry-Sun Drilling Services Survey Report for'MPS.27PB1 Your Ref: API 500292308470 Job No. AKZZ22071, Surveyèd:.SMaY,2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/1 OOtt) 0.00 0.000 0.000 -67.30 0.00 0.00 N O.ooE 5999943.96 N 565700.12 E 0.00 AK-6 BP _IFR-AK 121.84 0.240 46.520 54.54 121.84 0.18 N 0.19 E 5999944.14 N 565700.30 E 0.197 -0.18 .~ "- 196.09 0.360 66.090 128.79 196.09 0.38N 0.51 E 5999944.34 N 565700.63 E 0.210 -0.50 309.17 0.460 77.460 241.87 309.17 0.62N 1.28 E 5999944.59 N 565701.39 E 0.114 -1.26 400.74 0.490 81.090 333.43 400.73 0.76N 2.02E 5999944.74 N 565702.14 E 0.046 -2.00 492.18 0.470 35.940 424.87 492.17 1.12 N 2.63E 5999945.11 N 565702.74 E 0.404 -2.60 584.60 1.780 330.240 517.27 584.57 2.68N 2.14E 5999946.66 N 565702.24 E 1.778 -2.06 679.66 3.730 317.110 612.22 679.52 6.22N 0.70W 5999950.18 N 565699.37 E 2.143 0.88 773.06 5.810 305.140 705.29 772.59 11.17 N 6.63W 5999955.07 N 565693.39 E 2.457 6.96 871.91 9.300 303.310 803.27 870.57 18.44 N 17.40 W 5999962.25 N 565682.56 E 3.539 17.94 965.10 14.540 304.150 894.42 961.72 29.15 N 33.39 W 5999972.82 N 565666.48 E 5.626 34.24 1061.02 20.190 303.980 985.93 1053.23 45.17 N 57.10 W 5999988.63 N 565642.63 E 5.891 58.42 1152.83 20.830 304.850 1071.92 1139.22 63.36 N 83.63 W 6000006.58 N 565615.94 E 0.772 85.48 1245.73 22.490 304.560 1158.26 1225.56 82.88 N 111.82 W 6000025.85 N 565587.58 E 1.791 114.24 1340.62 24.890 301.440 1245.15 1312.45 103.59 N 143.81 W 6000046.28 N 565555.41 E 2.853 146.84 1434.49 26.370 301.120 1329.78 1397.08 124.67 N 178.51 W 6000067.05 N 565520.52 E 1.584 182.15 1528.45 26.310 302.320 1413.98 1481.28 146.59 N 213.97 W 6000088.66 N 565484.87 E 0.570 218.25 1621.06 30.070 302.900 1495.59 1562.89 170.17 N 250.81 W 6000111.92 N 565447.82 E 4.071 255.78 1714.92 30.430 303.530 1576.67 1643.97 196.07 N 290.37 W 6000137.47 N 565408.04 E 0.511 296.09 1800.60 34.550 303.860 1648.93 1716.23 221.61 N 328.65 W 6000162.67 N 565369.54 E 4.813 335.11 1900.92 35.210 305.420 1731.23 1798.53 254.22 N 375.84 W 6000194.86 N 565322.06 E 1.106 383.26 1994.53 33.780 304.820 1808.38 1875.68 284.72 N 419.20 W 6000224.98 N 565278.43 E 1.570 427.51 2091.36 37.050 304.420 1887.28 1954.58 316.59 N 465.37 W 6000256.44 N 565231.98 E 3.386 474.61 2181.93 40.780 304.290 1957.74 2025.04 348.69 N 512.33 W 6000288.13 N 565184.74 E 4.119 522.51 2273.63 45.170 303.870 2024.81 2092.11 383.70 N 564.10 W 6000322.68 N 565132.67 E 4.797 575.30 2368.22 50.530 303.900 2088.27 2155.57 422.78 N 622.30 W 6000361.25 N 565074.13 E 5.667 634.63 2462.15 54.180 303.330 2145.63 2212.93 463.94 N 684.23 W 6000401.87 N 565011.84 E 3.915 697.77 2556.10 56.560 303.750 2199.01 2266.31 506.66 N 748.65 W 6000444.01 N 564947.04 E 2.560 763.44 2649.18 58.130 302.490 2249.24 2316.54 549.47 N 814.29 W 6000486.24 N 564881.03 E 2.036 830.32 2742.76 62.690 301.550 2295.44 2362.74 592.59 N 883.27 W 6000528.76 N 564811.67 E 4.950 900.56 --- -- ----- 26 June, 2002 - 16:00 Page 20'5 DrillQuest 2.00.08.005 Sperry-Sun Dril,.. Services . SurveyReport.~~S.~7PB1 Your/ljJf: APl5lWI)3Q8470 Job No. AKZØ2D7! ~ ,. sûiiifjyédrSMay, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Ea.tlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 2835.28 67.180 302.290 2334.62 2401.92 636.90 N 954.38 W 6000572.44 N 564740.17 E 4.907 972.96 2928.89 70.170 303.520 2368.66 2435.96 684.27 N 1027.58 W 6000619.16 N 564666.56 E 3.421 1047.54 .- -~ 3022.10 68.860 303.590 2401.28 2468.58 732.53 N 1100.34 W 6000666.78 N 564593.38 E 1.407 1121.71 3115.22 71. 150 303.280 2433.12 2500.42 780.74 N 1173.37 W 6000714.35 N 564519.93 E 2.479 1196.14 3208.63 71.170 304.520 2463.29 2530.59 830.05 N 1246.74 W 6000763.01 N 564446.13 E 1.257 1270.95 3302.04 70.040 304.550 2494.30 2561.60 880.00 N 1319.32 W 6000812.32 N 564373.11 E 1.210 1344.99 3396.45 70.220 305.270 2526.39 2593.69 930.81 N 1392.13 W 6000862.49 N 564299.85 E 0.742 1419.29 3488.53 69.720 305.790 2557.93 2625.23 981.08 N 1462.54 W 6000912.14 N 564229.01 E 0.759 1491.16 3582.16 70.310 307.070 2589.93 2657.23 1033.34 N 1533.33 W 6000963.77 N 564157.76 E 1 .431 1563.48 3676.26 70.800 307.890 2621.26 2688.56 1087.33 N 1603.74 W 6001017.14 N 564086.87 E 0.973 1635.48 3768.04 69.500 307.980 2652.42 2719.72 1140.40 N 1671.83 W 6001069.61 N 564018.32 E 1.419 1705.11 3861.19 68.180 305.730 2686.05 2753.35 1192.50 N 1741.33 W 6001121.10 N 563948.37 E 2.661 1776.14 3955.34 68.900 305.040 2720.50 2787.80 1243.24 N 1812.76 W 6001171.21 N 563876.49 E 1.025 1849.06 4049.38 70.610 303.650 2753.04 2820.34 1293.01 N 1885.61 W 6001220.33 N 563803.21 E 2.287 1923.35 4143.46 69. 170 303.070 2785.38 2852.68 1341.59 N 1959.39 W 6001268.26 N 563729.00 E 1.636 1998.56 4237.01 71.470 302.700 2816.89 2884.19 1389.41 N 2033.36 W 6001315.43 N 563654.62 E 2.487 2073.92 4331.48 73.830 303.310 2845.06 2912.36 1438.53 N 2108.97 W 6001363.88 N 563578.57 E 2.573 2150.96 4423.39 73.030 303.600 2871.27 2938.57 1487.09 N 2182.47 W 6001411.80 N 563504.65 E 0.921 2225.87 4516.64 71.910 304.460 2899.36 2966.66 1536.85 N 2256.16 W 6001460.90 N 563430.53 E 1.489 2301.02 4610.35 72.020 304.800 2928.37 2995.67 1587.49 N 2329.48 W 6001510.89 N 563356.76 E 0.364 2375.82 ~,~ -- 4703.65 72.590 305.270 2956.73 3024.03 1638.51 N 2402.26 W 6001561.28 N 563283.54 E 0.777 2450.08 4796.04 71.190 304.370 2985.45 3052.75 1688.66 N 2474.35 W 6001610.78 N 563211.02 E 1.776 2523.63 4890.50 70.950 304.700 3016.09 3083.39 1739.31 N 2547.95 W 6001660.79 N 563136.97 E 0.417 2598.72 4983.53 71.930 304.460 3045.70 3113.00 1789.36 N 2620.56 W 6001710.20 N 563063.92 E 1.081 2672.79 5077.19 72.080 304.250 3074.63 3141.93 1839.63 N 2694.10 W 6001759.82 N 562989.94 E 0.267 2747.80 5170.38 72.000 304.010 3103.37 3170.67 1889.37 N 2767.48 W 6001808.91 N 562916.12 E 0.260 2822.63 5263.82 72.170 304.300 3132.11 3199.41 1939.29 N 2841.06 W 6001858.18 N 562842.11 E 0.347 2897.66 5357.62 71.670 304.410 3161.22 3228.52 1989.60 N 2914.67 W 6001907.85 N 562768.06 E 0.545 2972.74 5450.99 72.360 303.960 3190.05 3257.35 2039.50 N 2988.13 W 6001957.10 N 562694.16 E 0.870 3047.66 5544.31 72.820 303.730 3217.97 3285.27 2089.09 N 3062.09 W 6002006.04 N 562619.77 E 0.546 3123.07 26 June, 2002 - 16:00 Page 3 of 5 DrillQuest 2.00.08.005 Sperry-Sun DrillifJg Services . Survey Repon for1N!8-21P81 Your Ref: API,!itltfIlÞOSïJ70 Job No. AKZZ22071, SUNêYéd: SMay, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5637.97 72.560 303.940 3245.84 3313.14 2138.88 N 3136.36 W 6002055.17 N 562545.06 E 0.351 3198.79 5731.72 71.920 304.100 3274.44 3341.74 2188.83 N 3210.36 W 6002104.47 N 562470.63 E 0.702 3274.25 '- '---- 5825.24 72.150 304.740 3303.28 3370.58 2239.12 N 3283.75 W 6002154.11 N 562396.80 E 0.696 3349.10 5918.76 72.500 304.670 3331.68 3398.98 2289.85 N 3357.00 W 6002204.19 N 562323.11 E 0.381 3423.84 6012.02 73.140 305.070 3359.23 3426.53 2340.79 N 3430.10 W 6002254.49 N 562249.56 E 0.799 3498.43 6105.39 72.040 305.920 3387.16 3454.46 2392.52 N 3502.64 W 6002305.57 N 562176.57 E 1.464 3572.4 7 6199.62 71.890 303.970 3416.34 3483.64 2443.84 N 3576.08 W 6002356.25 N 562102.68 E 1.974 3647.41 6293.4 7 71.350 304.530 3445.93 3513.23 2493.96 N 3649.70 W 6002405.72 N 562028.63 E 0.807 3722.49 6385.70 72.740 302.100 3474.37 3541.67 2542.14 N 3723.01 W 6002453.25 N 561954.89 E 2.925 3797.21 6479.46 73.120 300.800 3501.89 3569.19 2588.90 N 3799.47 W 6002499.34 N 561878.02 E 1.386 3875.04 6573.50 74.200 301.330 3528.35 3595.65 2635.47 N 3876.77 W 6002545.22 N 561800.32 E 1.269 3953.69 6665.48 73.070 299.740 3554.26 3621.56 2680.31 N 3952.78 W 6002589.39 N 561723.92 E 2.064 4031.00 6758.79 70.820 297.010 3583.19 3650.49 2722.47 N 4030.82 W 6002630.87 N 561645.51 E 3.681 4110.26 6852.15 70.570 294.370 3614.05 3681.35 2760.67 N 4110.21 W 6002668.36 N 561565.79 E 2.682 4190.76 6946.52 72.750 291.570 3643.75 3711.05 2795.60 N 4192.67 W 6002702.57 N 561483.02 E 3.642 4274.23 7039.82 71.170 288.440 3672.65 3739.95 2825.96 N 4276.01 W 6002732.19 N 561399.41 E 3.611 4358.44 7133.47 70.340 284.600 3703.53 3770.83 2851.10 N 4360.76 W 6002756.59 N 561314.45 E 3.971 4443.90 7227.13 71. 140 279.650 3734.44 3801.74 2869.66 N 4447.17W 6002774.38 N 561227.88 E 5.062 4530.82 7320.00 71.310 279.650 3764.33 3831.63 2884.39 N 4533.86 W 6002788.36 N 561141.07 E 0.183 4617.91 ~~ 7414.26 71 . 170 276.950 3794.65 3861.95 2897.28 N 4622.16 W 6002800.47 N 561052.65 E 2.716 4706.56 7507.22 69.860 273.480 3825.67 3892.97 2905.25 N 4709.42 W 6002807.67 N 560965.33 E 3.791 4794.02 7569.00 69.860 273.480 3846.94 3914.24 2908.77 N 4767.31 W 6002810.69 N 560907.40 E 0.000 4851.99 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 271.710° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7569.00ft., The Bottom Hole Displacement is 5584.64ft., in the Direction of 301.389° (True). ~ --- --------- 26 June, 2002 - 16:00 Page 4 0'5 DrillQuest 2.00.08.005 . .-,' . ' -::J;':¿~;> ,~ ; Sperry-SfItJ ....~.~.. ~.:fJ-:Serv¡(ies Survey Report fofp"fpS.27ÞS1 Your Ref: API 500292308470 Job No. AKZZ22011, SUn/eyed: 5 May, 2002 . BP EXPLORATION (ALASKA) INC. Milne Point Unit BPXA Milne Point MPS Comments ',,-- Measured Depth (ft) Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) Comment 7569.00 3914.24 2908.77 N 4767.31 W Projected Survey Survey tool program for MPS-27PB1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 7569.00 3914.24 AK-6 BP _IFR-AK ~" .--- -- -- 26 June, 2002 . 16:00 Page 50f5 DrillQuest 2.00.08.005 27-Jun-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-27PB1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk 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) RECEIVED !! " i) 00Q2 '-'-- L.. L Alaska Oil & Gas Cons. Commmsion Anchorage aOd-O~S BP EXPLORA TIOff-(ALASKA) INC. ---- MilnePoi~fUnit ""x,: Milne Point MPS¡X$lot MPS-27 MPS-27PB1MWD Job No. AKMW22071, Surveyed: 5 May, 2002 -,' SURVEY IEPORT 26 June, 2002 Your Ref: API 5t1IJ2f2308470 Surface Coordinates: 5999943.96 N, 565700.12 E (70° 24' 37.0499" N, 1490 27' 54.0825" W) Kelly Bushing: 67.3Oft above Mean Sea Level ~.- =a! ..-.¡ '.¡-.' 1..E5Un . :w . OAIL-LING S_FlVlces A Halliburton Company Survey Ref: svy10120 Sperry-Sun Dri/ltlgServices . Survey Report fOr "'2'1PS1MWÐ Your Ref: AP15I'Jljjf23ØN70 Job No. AKMW22D711 SUfVèyed: 5 MaYI 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs. Northing. Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -67.30 0.00 O.OON O.OOE 5999943.96 N 565700.12 E 0.00 MWD Magnetic 121.84 0.240 47.820 54.54 121.84 0.17 N 0.19E 5999944.13 N 565700.31 E 0.197 -0.18 '- 196.09 0.360 67.170 128.79 196.09 0.37N 0.52E 5999944.33 N 565700.64 E 0.209 -0.51 309.17 0.460 77.760 241.87 309.17 0.60 N 1.29 E 5999944.57 N 565701.41 E 0.111 -1.27 400.74 0.490 82.110 333.43 400.73 0.73 N 2.04E 5999944.71 N 565702.15 E 0.051 -2.01 492.18 0.470 36.480 424.87 492.17 1.09 N 2.65E 5999945.07 N 565702.76 E 0.408 -2.61 584.60 1.780 330.790 517.27 584.57 2.64 N 2.17E 5999946.62 N 565702.27 E 1.778 -2.09 679.66 3.730 317.700 612.22 679.52 6.22 N 0.63W 5999950.18 N 565699.44 E 2.142 0.81 773.06 5.810 305.650 705.29 772.59 11.22 N 6.52W 5999955.13 N 565693.51 E 2.460 6.85 871.91 9.300 303.390 803.27 870.57 18.54 N 17.25 W 5999962.35 N 565682.70 E 3.543 17.80 965.10 14.540 304.150 894.42 961.72 29.26 N 33.23 W 5999972.92 N 565666.63 E 5.625 34.09 1061.02 20.190 304.240 985.93 1053.23 45.34 N 56.90 W 5999988.80 N 565642.82 E 5.890 58.23 1152.83 20.830 305.060 1071.92 1139.22 63.63 N 83.36 W 6000006.86 N 565616.20 E 0.764 85.22 1245.73 22.490 304.830 1158.26 1225.56 83.27 N 111.47W 6000026.25 N 565587.92 E 1.789 113.90 1340.62 24.890 301.700 1245.15 1312.45 104.13 N 143.36 W 6000046.83 N 565555.85 E 2.855 146.40 1434.49 26.370 301.570 1329.78 1397.08 125.43 N 177.93 W 6000067.82 N 565521.09 E 1.578 181.59 1528.45 26.310 302.770 1413.98 1481.28 147.62 N 213.22 W 6000089.70 N 565485.61 E 0.570 217.53 1621.06 30.070 303.420 1495.60 1562.90 171.52 N 249.85 W 6000113.28 N 565448.77 E. 4.073 254.86 1714.92 30.430 304.180 1576.67 1643.97 197.83 N 289.15 W 6000139.23 N 565409.25 E 0.560 294.92 - 1800.60 34.550 304.4 90 1648.93 1716.23 223.78 N 327.14 W 6000164.86 N 565371.03 E 4.813 333.67 1900.92 35.210 305.950 1731.23 1798.53 256.87 N 374.OOW 6000197.53 N 565323.88 E 1.061 381.50 1994.53 33.780 305.320 1808.38 1875.68 287.76 N 417.08W 6000228.04 N 565280.53 E 1.574 425.48 2091.36 37.050 304.950 1887.28 1954.58 320.05 N 462.97 W 6000259.92 N 565234.36 E 3.384 472.31 2181.93 40.780 305.210 1957.74 2025.04 352.74 N 509.51 W 6000292.21 N 565187.52 E 4.122 519.81 2273.63 45.170 304.390 2024.82 2092.12 388.39 N 560.84 W 6000327.40 N 565135.88 E 4.826 572.18 2368.22 50.530 305.360 2088.27 2155.57 428.50 N 618.34 W 6000367.00 N 565078.04 E 5.717 630.85 2462.15 54.180 305.190 2145.63 2212.93 471.44 N 679.05 W 6000409.41 N 565016.95 E 3.889 692.81 2556.10 56.560 305.190 2199.02 2266.32 515.99 N 742.22 W 6000453.40 N 564953.39 E 2.533 757.29 2649.18 58.130 303.040 2249.24 2316.54 559.92 N 807.10 W 6000496.76 N 564888.13 E 2.574 823.45 2742.76 62.690 301.060 2295.44 2362.74 603.06 N 876.07 W 6000539.29 N 564818.78 E 5.208 893.67 ----- ----.- 26 June, 2002 - 16:18 Page 20t5 DrmQuest 2.00.08.005 Sperry-Sun DrHlillgServices . Survey Report for MPS<i27PB1 MWD Your Ref: API 500292308470 Job No. AKMW22071, Surveyed: 5 May, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Ea'tlngs Northing. Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 2835.28 67.180 303.430 2334.63 2401.93 647.79 N 946.91 W 6000583.39 N 564747.55 E 5.379 965.82 2928.89 70.170 304.820 2368.67 2435.97 696.71 N 1019.08 W 6000631.68 N 564674.95 E 3.481 1039.41 -~ 3022.10 68.860 304.860 2401.29 2468.59 746.59 N 1090.74 W 6000680.93 N 564602.86 E 1.406 1112.53 3115.22 71 . 1 50 304.630 2433.13 2500.43 796.46 N 1162.64 W 6000730.16 N 564530.52 E 2.470 1185.89 3208.63 71.170 305.850 2463.30 2530.60 847.47 N 1234.84 W 6000780.53 N 564457.87 E 1.236 1259.58 3302.04 70.040 305.690 2494.31 2561.61 898.97 N 1306.33 W 6000831.40 N 564385.93 E 1.220 1332.57 3396.45 70.220 306.390 2526.40 2593.70 951.21 N 1378.13 W 6000883.01 N 564313.68 E 0.723 1405.90 3488.53 69.720 306.490 2557.94 2625.24 1002.59 N 1447.72 W 6000933.78 N 564243.64 E 0.553 1476.99 3582.16 70.310 307.510 2589.94 2657.24 1055.55 N 1517.99 W 6000986.12 N 564172.90 E 1.202 1548.81 3676.26 70.800 308.560 2621.27 2688.57 1110.22 N 1587.88 W 6001040.17 N 564102.54 E 1.174 1620.30 3768.04 69.500 308.940 2652.43 2719.73 1164.25 N 1655.20 W 6001093.61 N 564034.74 E 1.469 1689.21 3861.19 68.180 306.980 2686.06 2753.36 1217.69 N 1723.68 W 6001146.44 N 563965.79 E 2.420 1759.25 3954.82 68.900 306.800 2720.32 2787.62 1270.00 N 1793.38 W 6001198.13 N 563895.64 E 0.790 1830.48 4049.38 70.610 305.200 2753.04 2820.34 1322.13 N 1865.15 W 6001249.64 N 563823.41 E 2.406 1903.77 4143.46 69.170 305.390 2785.38 2852.68 1373.18 N 1937.25 W 6001300.04 N 563750.86 E 1.542 1977.37 4237.01 71.470 303.530 2816.89 2884.19 1423.00 N 2009.88 W 6001349.23 N 563677.80 E 3.090 2051.45 4331.48 73.830 304.500 2845.06 2912.36 1473.45 N 2084.61 W 6001399.01 N 563602.63 E 2.683 2127.65 4423.39 73.030 305.990 2871.27 2938.57 1524.28 N 2156.56 W 6001449.21 N 563530.24 E 1.781 2201.08 4516.64 71.910 305.290 2899.36 2966.66 1576.09 N 2228.82 W 6001500.38 N 563457.52 E 1.398 2274.86 "-'" 4610.35 72.020 306.640 2928.37 2995.67 1628.42 N 2300.94 W 6001552.08 N 563384.95 E 1.375 2348.50 4703.65 72.590 306.240 2956.73 3024.03 1681.22 N 2372.44 W 6001604.24 N 563312.98 E 0.735 2421.55 4796.04 71.190 305.180 2985.45 3052.75 1732.47 N 2443.74 W 6001654.87 N 563241.23 E 1.867 2494.35 4890.50 70.950 304.530 3016.09 3083.39 1783.54 N 2517.06 W 6001705.29 N 563167.47 E 0.699 2569.16 4983.53 71.930 305.430 3045.70 3113.00 1834.10 N 2589.32 W 6001755.21 N 563094.77 E 1.397 2642.90 5077.19 72.080 304,110 3074.64 3141.94 1884.89 N 2662.49 W 6001805.36 N 563021.15 E 1.350 2717.55 5170.38 72.000 304.900 3103.38 3170.68 1935.11 N 2735.54 W 6001854.93 N 562947.66 E 0.811 2792.07 5263.82 72.170 307.100 3132.12 3199.42 1987.37 N 2807.47 W 6001906.55 N 562875.28 E 2.248 2865.52 5357.62 71.670 304.950 3161.24 3228.54 2039.81 N 2879.58 W 6001958.36 N 562802.71 E 2.243 2939.16 5450.99 72.360 304.410 3190.07 3257.37 2090.34 N 2952.61 W 6002008.24 N 562729.24 E 0.921 3013.67 5544.31 72.820 305.070 3217.99 3285.29 2141.08 N 3025.78 W 6002058.34 N 562655.63 E 0.836 3088.32 -- --.- --- 26 June, 2002 - 16:18 Page 30f5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for M~~..27PB1 MWD Your Ref: API 500292308470 Job No. AKMW22011, Surveyed: 5 May, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Ea.tlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5637.97 72.560 305.820 3245.86 3313.16 2192.94 N 3098.62 W 6002109.55 N 562582.33 E 0.813 3162.68 5731.72 71.920 305.860 3274.45 3341.75 2245.21 N 3171.00W 6002161.19 N 562509.49 E 0.684 3236.59 ~~/ 5825.24 72.150 306.660 3303.30 3370.60 2297.83 N 3242.73 W 6002213.17 N 562437.30 E 0.850 3309.86 5918.76 72.500 306.670 3331.69 3398.99 2351.04 N 3314.21 W 6002265.75 N 562365.36 E 0.374 3382.89 6012.02 73.140 305.910 3359.24 3426.54 2403.77 N 3386.02 W 6002317.85 N 562293.08 E 1.038 3456.24 6105.39 72.040 308.070 3387.18 3454.48 2457.37 N 3457.18 W 6002370.82 N 562221.46 E 2.502 3528.97 6199.62 71.890 303.870 3416.36 3483.66 2509.98 N 3529.68 W 6002422.79 N 562148.50 E 4.241 3603.00 6293.47 71.350 306.100 3445.96 3513.26 2561.04 N 3602.64 W 6002473.21 N 562075.09 E 2.327 3677.46 6385.70 72.740 303.790 3474.39 3541.69 2611.28 N 3674.56 W 6002522.82 N 562002.74 E 2.819 3750.84 6479.46 73.120 300.550 3501.92 3569.22 2659.00 N 3750.41 W 6002569.86 N 561926.46 E 3.328 3828.09 6573.50 74.200 302.340 3528.38 3595.68 2706.07 N 3827.40 W 6002616.26 N 561849.07 E 2.158 3906.44 6665.48 73.070 299.4 70 3554.30 3621.60 2751.40 N 3903.11 W 6002660.92 N 561772.96 E 3.236 3983.4 7 6758.79 70.820 296.190 3583.23 3650.53 2792.82 N 3981.54 W 6002701.65 N 561694.17 E 4.121 4063.10 6852.15 70.570 295.040 3614.09 3681.39 2830.91 N 4060.98 W 6002739.04 N 561614.39 E 1.193 4143.65 6946.52 72.750 290.670 3643.80 3711.10 2865.67 N 4143.51 W 6002773.07 N 561531.56 E 4.965 4227.18 7039.82 71.170 288.910 3672.69 3739.99 2895.71 N 4226.97 W 6002802.38 N 561447.84 E 2.467 4311.50 7133.47 70.340 285.340 3703.57 3770.87 2921.75 N 4311.45 W 6002827.67 N 561363.13 E 3.706 4396.72 7227.13 71 . 140 283.490 3734.46 3801.76 2943.76 N 4397.08 W 6002848.92 N 561277.31 E 2.051 4482.97 7320.00 71.310 279.650 3764.36 3831.66 2961.39 N 4483.20 W 6002865.79 N 561191.04 E 3.919 4569.58 7414.26 71. 170 270.940 3794.73 3862.03 2969.62 N 4571.97 W 6002873.24 N 561102.20 E 8.750 4658.55 7507.22 69.860 273.670 3825.74 3893.04 2973.13 N 4659.52 W 6002875.99 N 561014.62 E 3.106 4746.17 7569.00 69.860 273.670 3847.02 3914.32 2976.84 N 4717.41 W 6002879.19 N 560956.71 E 0.000 4804.14 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 271.710° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7569.00ft., The Bottom Hole Displacement is 5578.13ft., in the Direction of 302.253° (True). 26 June, 2002 - 16:18 Page 4 0'5 DrillQuest 2.00.08.005 . Sperry-Sun Drll.g$êWic:;~ Survey Report for M~21PB1 MWD Your Ref: API 5Oð292308470 Job No. AKMW22071, SUtVèyed: 5 May, 2002 . BP EXPLORATION (ALASKA) INC. Milne Point Unit BPXA Milne Point MPS Comments '-, Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment ~/~ 7569.00 3914.32 2976.84 N 4717.41 W Projected Survey Survey tool program for MPS-27PB1 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 7569.00 3914.32 MWD Magnetic .~ - -~--~-_.- 26 June, 2002 - 16:18 Page 50'5 DrillQuest 2.00.08.005 ') aDa~{)?5 IOo,tos WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 July 03, 2002 RE: MWD Fonnation Evaluation Logs MPS-27, AK-MW-22071 1 LIS fonnatted Disc with verification listing. API#: 50-029-23084-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: signe~{AF-- ) RECE'VED JUL 1 C 2002 Alaska Oil & Gas Cons. Commission Anctlorage ') aOd"O~S I O~loto WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 ~chorage,Alaska 99501 July 03, 2002 RE: MWD Fonnation Evaluation Logs MPS-27 PB 1, AK-MW-22071 1 LIS fonnatted Disc with verification listing. API#: 50-029-23084-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. ~chorage, Alaska 99649-6612 Date: Sign~(J ~ RECEIVED JUL ~ c 2002 Alaska Oil & Gas Cons. Commission Anchorage Re: MPS-27 open hole sidetrack! ) ) Subject: Re: MPS-27 open hole sidetrack! Date: Mon, 06 May 2002 16:35:57 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Dixon, Charles T (Fairweather)" <DixonCT@BP.com> cc: "Campbell, Steve K" <CampbeIS@BP.com>, "Archey, Pat" <ArcheyPJ@BP.com>, "Green, Matt D" <GreenMD@BP.com>, John D Hartz <jack_hartz@admin.state.ak.us>, Winton GAubert <winton_aubert@admin.state.ak.us> ~Dd - O<gS- Steve, I confirm our discussion. The acceptability of the plan is that you intend to sidetrack within the Ugnu and the cementing of ultimate wellbore will result with the Ugnu being isolated. Potential communication along the old wellpath will be within the Ugnu. Had you planned to sidetrack above the Ugnu, then it would have been quite possible that cement would have been necessary. Spotting the high vis pill should help in preventing cement from going down the old hole. Weighted mud might be a better choice due to recent experience with intermediate OH plugs falling downhole despite being set on high vis pills. The angle you have in the hole will likely help mitigate any fall in contrast to the vertical holes I was referring to. With regard to the tail cement, I share your concern with the weight of the column. Regardless of the type of cement, it is most important that the surface casing be cemented successfully. Good luck. Tom Maunder, PE AOGCC "Dixon, Charles T (Fairweather)" wrote: > As per our conversation 5/6/02 1600 hrs. Below is the proposed open hole > sidetrack information as requested. > > This sidetrack is required to stay on original well path. This plan does not > deviate from the original plan that was permitted with the State. > > Current total depth: 7569' MO, 3901' TVO/RKB > Avg angle: 71 deg > Hole size: 9-7/8" > Top of Ugnu: 6230' MO > > Proposed open hole sidetrack procedure: > > 1. Circulate and condition the mud at 7569'. Spot heavy/viscous pill from > 7569' to 6403' MO (Proposed Sidetrack depth). > 2. Sidetrack the well at 6403' MO, 3546' TVO/RKB. > 3. Orill the well to originally planned total depth of 8384' MO, 4142' > TVO/RKB > 3. Run and cement a full string of 7" casing. (Bring 15.8 ppg tail cement > to 100' above sidetrack @ 6403' MO) > 4. Finish drilling well as multi-Iat as originally proposed. > > Thanks for your help! 1of2 5/6/024:48 PM T<d ~tS ~HB 1'bn: MPS-n.~ (P'.....\wS-1j,Il<J:¡~1Tt 0emI1>y: Ken AIm E'k4'3mt12 CD 00 c:- I ~ õ !.::rn!ou:r<cE I!;Jœ1AAW.ti C~(IW;;~ '/MCt$<I\oaIm'-lI,Tn;- VtrfaJ (I'D} I!diIeI<r 8h1IJir nœ s.øm(VS)~ ~. ,(I.({tI,O..'/Ð. N~~~ ~Dn "!'2..~1 =-N'-.t: pe.......,funð, iŒ..EY:1î(JQ'.A)f E1op6.n IJerbY.. ~lW ?I!CI ICCIl-)) I"8md: wm¡ ~Ví 1W1.ÐJ 111L9.<'o& ~!oI= W"",,VE ~ RcT-~: &è: I!m:- " . DR A T;>-r'1 rflnp"\.T ON¡L'í --f--:dFh~- : [--:-1--;--, " -}, ...CH I \..--v- I J: j : -}¡~;if~1t -'i -H,\d~: -~H'i~9:ii1;; . ~ ~,~ ~-~-:, 'i 1i (. $,¡rt-- Jwl.L- T"" _'10"" WI,_T" --DÞ~-r, -p--1t~-iJl?: ~-~~-7./:A1.~---('r=:- --~---~-4 .~. sæD~~'~:=~=::~= mo l~ '.. .. . V"" r. f, ~ ~ ~ ?".C1 ~ ~..¡. q: T":,II V ¡OO) , 7-"1 . - l'~ J¡..;/L. ~J.~ lJ: '":¡¡;:)vA ; L)L. i4.AI . :.. :.:. ~ l ~~" 5tatDirfJI00':é6Y2..f4'MÐ.:161UTTVD .ErtilÐìr:L~11/¡,MD..4IWj'tVD . . .TT,f...foooo!'l jif tX-f!I.. ", r.'F :' ': ~ ~ \CO~ 0& II~Dír:7~gS.on.ID.J\I61'J\'D SWtDltfJI00';l06S3..1S"Mn,4IlS.Ð'TYD N~ a....-.rv_#I'I<r_"tfllr...,on~n"'" Un _~f"ttlrfü'TI ~ .ID.4l41'IVD ¡,¡, 'MD-.41.59,i'iVD . ~=r\:~f47':;::~'" . , U 0 '". 1000 2400 -, 8rlTli ~~ J~~~j ~ ~ ~ ~ ~ ~ V-rtital S«ti1J1l al211.1ro [8OOtVÏJJ~ OR.9I.'IYIJErAID; 117'- CcWoIb> ~ Púiozg, 1:'- ==I~~.~ 9<..r:= ~~c.z., fORMAJID1{ Tor DETArtS ~ c:- ~ " All TVD depths are YS'f'ViJplllS 72tfor-P.:FEB£-: ~ 4 S ~ 7 8 9 Nn. TVDl'afll MD!'aIt "'CCfI1II1tioll LS22..00 3%"7.00 3m.OO 41}12.00 41)27.00 IIC67.00 4!m.OO 4H7.00 4[42.00 924.47 J.PRF . 1(jO)S.C>.~f2.NA 1758.61' :::Bfl.N~ nag,1J :::8FA-KC 1Ggg.69 ::SEZ.,'Œ wn.81 :::Bël.IY'F 31 H.1n -:SB(}.OA &!4g,40 -:sue &S8U [ "':'SBB-OS ~ = ~ ----~-- --; I c:- CD ~ I ~ ï ~ ~ : ¡+! ; _.; 1, :.; .¡ . . -- i~~~~~'2~~r°ir2rJ'=ír: 9:~MD..wfT'fD .,:, ,-, ~ ~.; &Ja Dir .Y1/}{f: 10(1 ~fD.61I9.84'T\I1) ... L;::~lt ~~~:L~¡L~ ~. ~ --1: ~~t~ m ~ ~ ~ ~ ~ ~ ~ ~ m -. ~- .;-. .:.' :-:~~Ðir "IOU: 1611..f6'M[}, 1I71'T'i1J I60Q E ..::; - ~ .;. . ~ -.'.. ;-.. . f -- ,- E'1Îd Vir: 19Z4.f1' .\il>. 1822' 1VD ~ -: i ! : J : : . :SurtIr.'¡"[0'I:20l6.trMD.I91:TTW i ~j)f'[~'[ ;~:J~-¡ J 2400 = . :.._¡._~ -~), ~-- L-!. --:--~-~- ~-~'-~-JÐ;d Dr : !%91niD,¥#S2~~1) ~ . . , , . r:: il- I Liï'- ~ ~ In n::: 0 m -< = I E ~ u... = ~ ~ ~ = ~ ~ I ~ ~ I ~ ~ ~. ~ , ~ ~ ~ war. VEfAI.' IoCr WE o£I.1[' ~ Eod8t ~ ~:lk< f\l:lMIS"-%t ~ ~ S1/IIWm' :IQ.'(QI! ~..fn'«::œ! [~~~ .q,'1. z ~ TAWi1=rf"f:YAn~ Noø- TWì- .lI\Z 1£i~9;' Ibtia,¡ ~.fio>I" Pn'$-lTKA -,"'II} mJlV ~ .ou:m1'» So!I:JN11JJ IbU ras-¡-¡ r> 4OnOO 11~ .f1'N.&'9 _UI _OJ- ~, H 4ntm ~¡ eUJT ~ 1."37<;S II} ..... ~-D n -Inul) tf.U1 <fiUJ a:cœa~ _00- pœ;.!7 n .tilflro ZH~ -!m~ «GøPJ !O'iIJII:OO? ~ NPS.'21G.. "'Iam 1i111M .~" IDi!WYI =~~ rm;-D n -IIUt<) 1m 17 as!V> ællliJl"1 SECTION DETAILS !íec MD lDc Azì 1VD +WooS tf'J. W DLe~ 1Fl.I:~ VS"eç Tatþ:!t 1 72.00 O.~D 0.00 12.ça t.oo 0.00 U~ ~.OO 0.00 2 500.00 IUJD 0.00 500.00 il.l)() IÌ.GO Ojl\) iI.OO 0.<10 5 100.00 4.(J() J03.ß\J 6-99.34 j.89 -5.19 H ~ J03.S9 59! ... 1625.46 )!.76 J03.89 1 5nCO 160.8f) .2.!9".]g J.O~ 0.00 14.f.06 5 1924.41 34.75 Jf)).ß'} 1822.00 15Z.22 .m.49 L.Of} ~.OO J82.8J <i 204<í.lg 14..75 JOJ.B9 1I}21.C.Q 2.90.91 -4!).1J9 0.80 ~.OO '+floSS 1 2969.2& 7L~8 303.9 1465.24 6%.GS .1(1)6.12 4.8() om 10%.47 II 66J2.44 7(.~& J03.89 3616.17 26JS.29 .:N22.16 1).81} 0.00 3?9\1.4S <) 769S.1J4 n.'8 2.S9l1tJ 1961.00 2S2.9.29 488U8 4.{1~ -~.~ 4%2,91 l-œs.:J7 NA Ii} 18fXLíH 7 Lfi8: 259.00 40C(I.OO :Jt.HI.21 -4978.71 0.{11) ~.OO ~.[4 Il 8384. U BO.50 2.M.JS 4142.GO 2.m.69 .s(98.{)1 4.0r . 7l.18 5512.80 MPS.21 Tr 12 B62{j56 'H.27 :l09:n 41oW.1O 2418,35 .S66U~ IHI () -69.1l 5?Z9.1f6 13 9L'w.n 91..27 209.2L 4l47.91 [95J.41 .S92(Uß 0.01) 1).00 S~S.88 14 '343.1* '1.11 2.16..56 4t44.oo 119U1 .{jQ20.M 4.80 9&.'7 ~~.% MPS-27 TZ IS 93S'2.J9 90.82 2.16.55 4r4:t3.5 Im.ll ~2;.2;t 4.0~ -171.90 6015.90 l6 101S:S3.15 90..82 2.16.55 4[25.1.3 146.37 '{ 80U(I OJ} ) {tOO fiSI U2 l1 10~61.[4 1)1. 1 Z 216-'S .125.00 141).9) -6804.S(I 4.QO I).S2 6&23.54 MPS-'t7U IS 10663.76 !H.12 216.45 4124.95 138.8J -6806>06 4.Ç1) -S!U!5 ðS25".OJ l'1 10886.26 91.12 2J6.45 4120.60 SSM8 ~"JU [ D.C ) )J}O 695 1.8CJ 2Q 1M08.lS J2.iJO 2J6...fS 412G.OO $42.20 -61}S I.n 4.C<) BJ{) 6964.JJ MPS.17T4 :J( 1094HI 91.26 211.11 4n8.]6 SIJ.61 -6972.6<1 4.00 2S.17 6984-.110 ,21 1 Jj¡~. Ç>.t 9 }.26 217.12 4097.00 2L4":'J .7[9').19 O.CI) 1).00 nÐ2.~ Ml'S.17 TS CASING D£L-\ftS h.'o.. TVD MD }o'an:.J" Siœ 4[42.00 8JS.f.1L 1- 1.000 401}1.flO rH19.J3 oJ fr.' 450{ CD CO (:) I u... ~ C> C> ........ ~ C> = n.. --I J C> co ~ I t- CD CO C'-I ~ CO to- CO to- C> CD UJ- ~ en 0:: 0 CO < = I E 0 .... u... C'-I ....r- C'-I C> = C'-I I CO = I >- (U ::¡;: ~ bp 0 400()- CCNr»CY W).,'U nr/u:oJ¡z¡ ~~ ~0:rÞtn ~= ~.y*,.~ [mr~ó;; ~Ic-. 9;.'rrf"1~Ðh:::sH~ ... IIl.IitJIE1>Œ I)¡JW.M~ l1DZ; ('-oNE)~ 111'" Cr:t=L"aI Nf'S.U. f'~1i.á Viñ;U(tVIJJ~ r,f'a¡1Jr'J'71IJ:' -('I~~ ~. \o.<r«-lmQ 7~~~~~~(' Sl.r;I;VEY fRCO>.....v. ~Fö D.ørb ~ ~~ ~~ :=:;~:m~ ?tat: tm.J? 'N¡61I tPm WS-U''t't.3t \ß':W'i) r..1 0Wd.ßy: 11m Mb, n...ŒI:- DJ!'<:" '8IæO:i DfH: [}u(:- CII'~ M'N1>1JRoU> Iœíe<ted: \\'Ul. 0CfAL! (¡c, tWoS ~ IÞtdI ~ !~ tf3.'I.1J-t ~ I'Ia m>s.!:1 .aD #031.1 ~12 5üõOOJo >r.nìJ]!~ ¡~Vlt~W MIA TAIlŒT m:¡,\[U; ¡...,. !\oTo .w.:; tE.<W ~ ~ S/oIr< ~ K"- 1J67.',J: ~ ~ur 'lG'i1lgf »ms OJ I\v W;.V n «97..XI nw .71"' IJ -~ 5œoJ ro - MT.>-rr r4 .m.;J.J UU1 <mIl! ~ UJi~D1 ~ MlU7 n ~IU..~ ¡an -...~ ~t 5..-00- M1.t-Z7 n ~Ia.~ JjtH/ ~"'!lœ JD:Wt!L!) - Mlto:ItlJ"- K'S-I:J(¡"" ..tz.~ lß1.~ ~ ~jm sœr1ILoJ Nf- ),9,;.Z7 r.:! ilUaJ Inn, 81lðUo 6:C~ ~ bl p,,¡i" SECTION DIITArLS Se..: MD rr:c .m TVD tN{~ I-W-W 1){.cg: TFa(t" V~e(: Tz,rgei I 1'2.01) CUll) O.iJO n.OD (tOO 0'.00 O.( () o.œ O.M 2 Soo.OO ().(J() D.OG 500.00 0.00 0.00 0.00 0.00 (J.OO J 700.00 4.01) 31lU9 ~W.B4 3$9 -5.79 2,(10 31».89 5.91 4 1/t15.46 .!t.11S J()}.89 1572.00 t61).8& -2J'US 3.00 0.00 144.06 .s lon".41 J.05" 3t)U9 nl1.oo 252.22. .J15.49 1.00 0.00 !R2.3} . 6 2f14.6.rß J4.15 j()}.89 1C¡2l:.C1) l~()."Jl -4H.09 0.00 0.00 "1.55 ! 1 2~69.2g 1E.'~ JI)}.89 .M6S.14 69(i(l! . LI}J6.22 .f.00 ML LOSU7 i g õ6J'l,44 71.6~ J )}.89 ]616.17 2635'.2' -31)22.76 0.00 0.00 399?4S ! Q 7695.1)4 1U~ U9.00 }< 67.Cf) 28:29.29 -4881).S8 4.00 .91.40 4\162.91 tdl'S.lTNA :] } 1800.oJ 1I.6~ 259.00 4(lOO.CO 281027 -4~71 0.00 0.00 SOóO.I. ; 11 8JS4.l1 80.50 2]6.3.5 4l.r!.W 2594.6.' .S"4o/.t.02 4.05 -11.18 5512.$(1 M!'S.2TT[ 12. 8626-.56 '1.2.1 lOO.2.t 4l S<J.1O 2..ILS.s.. -1éõO.. W 1,.00 -69.7E 5729.66 .IJ 'JIS'J.91 91.2.1 2.09,2.1 4: [47.9J (9S.Ut -59'1.0.38 (/.00 0.00 S91S.tS : 14 9J!3.74 9U1 116.I6 U44.00 t799.11 ~fOlO.{ 9 "'.00 9Ct.67 6070..9& MPS-211'l i 15 9JS1.)~ 9<1.81 2lfiH t 14J.&5 11!t2.ZJ -rotS.2.4 ..00 -]77.<;0 ~437HG 16 L06H.1S 9U'Z :WUS 4IlS.B 146.11 -&00. LI} ~.ço (H<J 6U9.n 11 l06fJl.14 91.12 ZI&.SS 412;.00 WJ.!H -æ4U.SO 4.CO I).~ 6&1J.S4 MPS-11U StoUt Dir 121100': 8..'84. L[' MDAl42'TVD L8 L06f)1.16 9Ut 21(;..45 41'14.95 7JB.!H ao6.06 4.00 -89.&05 6JZ5.(U &./IIt Ði~ 4.C~ltr,(/': 180(UU' MD. .wçurVD 19 L0E86.1¡) 9Ut tlM5 4t21UiO SYJ.88 -6938.21 ...r¡( )J'.(I 6'151.81) 20 LQ<)( g, 25 92.00 llUS 4121).00 542.2.0 -6951.27 4.00 1)-10 6964.3J MPS-2.1T4 Et.dDír : i'695.I:4.lt.ID.J961'TYD 21 l094J.'9l 93.2.6 !t1.12 41UU6 SB.~7 -691Z.60 4.00 23..17 mM.S() c.v,.,...,"Í hole 22 tBI9-,4 Q3.2.6 l17.12 4091.00 2r~..n -?14i19.r9 6'.00 1l.«J T.02.3P. MPS.2.7TS FORMATION TOr> DETAILS No. '1VIJhth ',.1DPath fÐJG1ronn J(lOH -- ~--.._... ---.:-.-1 I L32:2.f.( 192".47 8.PRF . ~ ~ L J'167.00 769s.o~ SHF2..}fA :§ - ¡ :' ""'-~-"J": : : ''''''d- J~OO ~: ' 'I ~' .,() 3 J9087.00 77S8.61 SBfl~ g :; ~Ðir ~!6l6..~6'lIo~,41~9_J"'TVD~".: ¡ . rðp v~.......... ~ 6Z!ð /"f~ 39" ¡r. 4 4012.00 n~8.7J SBFA-NC Ë ' ;~ , . : ; ~ - . :H; :~ . ~ - --~;;¿-- ~ :- ~ ~~::: ~~;:~~ ~~~:: f:' ~ --- --_: :'. . r': . I:'Q( : .. 1 4œ2..00 snus -rnHD-OA :ë £000--- ; . ~Wt 1)!I'¡¡lW ;~m~32: M¡}.4~41~n 'Io'J) . : ... . : 3 4H7.OO 1118-410 TSBC ~ " .M.ts-.111l. t : ; : : ~( ¡.; ~ 41~(Þ SJS~.1l TSBB-OB . ~,!... f:: . l ' : i . . ~~ ! Stu; Dir WOO': L62S.4QMD,IS12TYD - .--_.---~- ~rrS:21Tr.----- ~---~--,----- - . ~ i MI'S-17 WpfN I:, ! ' ! '. . ~ ~ ~ J Iì RA.. kT (-~ (-~i P -\T O~ N' r . y : ¡-T--~-~ IS"! S""DW JiI'" , _!dD, """'"T1IIJ f1 : ~Olal!v.:~: 11~l9.g~' M .4I:o/TVD:. I j' - ~~ t. Á ,'-" '-J ,.,. 1 "- L "'- : ~ :: ¡ IpOO StutDü2J100'. 500 MD. 500'rVD ~ --- ~: : -,' - u:. _n ._-;--.,-- --¡--- .', . _.~ -- --+---:---:---;--_.. --or --, -_,__¡_n- ~ -r---.- --":'--~---:-¡----~--f-'-~" --1---~ ,-; - -~~--~ -- 'I' ;¡; "1' I r If";1" ,; i 'I ¡~i'I';¡: ,;;; ""1'" -7000 -6600 -5000 -4001) -JOOO .zac.) .]OCO (t (Ci:O Wt$(.~Ean(~) [l00lJftJïot SiD: 1.00(} 4.ro~ -WØ() Re: MPS-27 Annular test ( t ¡)' Od--O~ç: Subject: Re: MPS-27 Annular test Date: Thu, 02 May 2002 10:11:58 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Campbell, Steve K" <CampbeIS@BP.com> CC: Pat Archey <archeypj@bp.com> Steve, As we discussed when looking at the regulations, this request is appropriate. In the permit application, you requested a 3500 psi BOP test. You chose 3500 psi due to your planned casing test pressure. When only considering your calculated MASP, a lower pressure might have been appropriate. With regard to the annular, 20 MC 25.035 (e) (10) states, 1I...an annular type preventer need not be tested to more than 50% of its rated working pressure. II Good luck with the operations. 141 was one of the first rigs I worked with nearly 18 years ago. I believe it still is one of the most consistent rigs operating. Tom Maunder, PE AOGCC IICampbell, Steve KII wrote: > Tom, now that we have moved to Doyon 141 drilling rig they have requested > us to only test the Annular on the BOP stack to 2500 psi vs 3500 psi. Are > you ok with making that change or does it require a sundry notice? If this > emial will work, I will use it as an verbal and send out to the rig.. Thanks. > > Steve Campbell > 907-564-4401 (0) > 907-564-4441 (f) > campbels@bp.com Tom Maunder <tom maunder(â2admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 5/3/02 8:48 A~ ~, ~~!Æ~E : f !Æ~!Æ~~~1. AIjASKA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. ""PH 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-27 BP Exploration (Alaska), Inc. Permit No: 202-085 Sur Loc: 2001' SNL, 311' WEL, Sec. 12, TI2N, RI0E, UM Btmhole Loc. 1791' SNL, 2229' WEL, Sec. 11, TI2N, RI0E, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. The pennit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. BP Exploration (Alaska), Inc. will assume the liability of any protest to the spacing exception tbat may occur. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and, does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill applicati ()n for Milne Point Unit MPS-27. The request for a waiver to drill this well without a diverter system is denied. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a rep resentative of the Commission to witness a test ofBOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope paEer at 659-3607. Sw~erely, Ut ~"1dr/ Cam~echsli Taylqr' Chair BY ORDER OF THE COMMISSION DATED thi~*ttay of April, 2002 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Hole 42" 9-7/8" 6-1/8" ALASKi..¡L AND ~:~~g~S~~:~ON COMJ,~5JON PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory Q¡Stratigraphic Test 1m Development Oil 0 Service 0 Development Gas 121 Single Zone /Ø 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Fielcfánd Pool Planned KBE = 68' Milne Point Unit / Schrader 6. Property Designation Bluff ADL 380109 7. Unit or Property Name Milne Point Unit 8. Well Number MPS-27 9. Approximate spud date April 20, 2002 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 113191 MD / 4097' TVD 0 17. Anticipated pressure {see 2C(AAC 25.035 (e) (2)} 94 Maximum surface 1448 psig, At total depth (TVD) 4142' / 1863 psig Setting Depth TQD Botom MD TVD MD TVD Surface Surface 113' 113' Surface Surface 8384' 4142' 8384' 4142' 11319' 4097' \lJ (;Å- '-f( IS 1'0 1- ~}"'\ l--t( ~y -G :2. 1 a. Type of work 1m Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2001' SNL, 311' WEL, SEC 12, T12N, R10E, UM At top of productive interval 1791' SNL, 2229' WEL, SEC. 11, T12N, R10E, UM At total depth 1791' SNL, 22291 WEL, SEC. 11, T12N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well /' ADL025627, 3049' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 320' MD Maximum Hole Angle 18. Casin~ Program Specifications Size CasinQ WeiQht Grade CouDlinQ 20" 92# H-40 Welded 7" 26# L-80 BTC 4-1/2" 12.6# L-80 IBT-M 11. Type Bond (See 20 MC 25.025) Number 2S100302630-277 Lenç th 80' 8384' 2935' Quantitv of Cement (include staQe data) 260 sx Arctic Set (Approx,) 1018 sx Class 'L', 382 sx Class'GI Uncemented Slotted Liner / 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED Perforation depth: measured APR 0 9 2002 AlllkaOlI & Gas ConI. CommiSSion Ai¡d\oragt true vertical II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Campbell, 564-4401 Prepared By Name/Number: Sondra Stewman, 564-4750 2' ':"".'~~;~;:i:C,~~;;~:,:£~:~,;~;r,r,:;!:!a,6~:,::,r'~:::::::~~.~~i:~E;~;~;%g,.e,,;I~~I~,:~,.",~,,~,,~;'.;I:i'>'III'.'I;,,::,i'}''.:I"~;':IIII,::,,/,II,":"":"~""':~";~'~'/":"':i"";,,,V'.:"',i:'?;,',;",1'1' :f,;,:,:~:;":,,-;,,,,,,, ':"i¡:!,;",':, . I,','~:I", I ' I,: ,,':. I', 'j I I.., . .'". '. ", " I",: :',',', I.:,:'. i, ,,:.' '. '1."1" ' .."', '-I.,' .'.! '.:1'", ;., ':,,',"" !:I: ,,1: :1. '.[ ':.' :. ':::1 .,';'il": ~:; ;:].:\'11', ; d,.,I::,':. ':; 'I' :'" -;-:'-1,,' I.~:: "I: I :,! ':i'II.; 11,1:" ":'d ,,', :::"'.II:,I .!',I.: ::::, "':1,1, :1": ::";',.,','1 ',',,' ':,:,'; I ",Qm,~ :~:~~I'I~I :.f:I:"I:,~'~,~ I ,~:",~¥:,:¡,!~,,':i ,:1,1, :::. :1:1 ';"':'. ~','II:!' 1,-" :'1 I.; ;'1 "l,:/(, :1';' 1,':':'1 ,:,I ';.!,:' ;1::1 ;'>i, I I:,~,',: ";;,1'1:: ,,;,;' ".;'; : I'; I :.'1; "1,'1','.: ,I:: 'I" i..:' '. ':: : ,I.,.' '{I ;:"",":1"1 , :;" '1'.11 ','1',111:, ",' ' ',1,1"" ,I ,1:,'0' :' 'I"'r\,:;' 'I,~'.,. ,',,: 'I... 1,""';-';' I" I: .I,ll ~. I Permit Number t:?c-. API Numbßr -? L b¿ / 61'----' P,pp~val Date~ See cover letter 262-r-C~o~ 50-0Z.q- 2-_=jL~ í "',-.J L\' ~(() .() d--. for other requirements Conditions of Approval: Samples Required DYes EI No Mud Log Required DYes ¡sa'No Hydrogen Sulfide Measures DYes 181 No Directional Survey Required IB) Yes D No Requ~red ~orking p:essure for B9PE~D 2K D 3K D 4K D5K D 10K D 15K p(3.5K psi ft;~;¿W-IJ Othe~n~,~~~~- \ù.::.,~~ \\'(:C) Cammy Oachsh T aylCM' Approved By ~ qó'm~i~s~od\r ~ Form 10-401 Rev. 12-01-85 II tJ ij ~ \] ii L- 20. Attachments . by order of the commission Date W...Jlt>- O?- Submit In Triplicate f aoCj -a~ Date: April 17, 2002 To: Tom Maunder (AOGCC) From: Steve Campbell (BP) RE: Information for a diverter waiver (MPS-27 ML) Tom, As per our conversation this week about a diverter waiver for MPS-27, I have attached the following information for your review: MPS-15: Mud logs, E-line logs, MWD logs (this was the first well on the pad) MPS-21: MWD LOGS MPS-31: MWD LOGS MPS-09: MWD LOGS MPS-07: MWD LOGS MUD DENSITY VS DEPTH (TVD) for all above wells All of these wells have been drilled to total depth without any problems with gas or abnormal pressures. I hope that is sufficient information for your consideration. Please call me if you have any questions or concerns. 907-564-4401 siðc/en, r"e, Iy, .jjt¡;Æ,v t:: - j /J ¡/ /l Steve Camp~~'. BP Drilling Engineer RECEIVED AP,~ l~:"1 :J-Dd¥ "'Oil & G.sGons. Commission Anchorage 0 500 1000 1500 2000 c > I- .c 2500 .... c. Q) c 3000 3500 x 4000 4500 5000 8 ,-I )r.' ..1. .n _nt' L. I 9 liS-PAD II Mud Wt VS Depth . - I I l I. ¡ I J 10 Mud WI. (ppg) 11 ( --+- MPS-15 --- MPS-21 - - MPS-31 --*- MPS-9 ::t( MPS-7 I, . L ,1. l. 12 :( BP Exploration (Alaska) Inc PO Box 196612 Anchorage, AK 99519-6612 (" April 9, 2002 Tom Maunder Petroleum Engineer AOGCC 333 W. 7" Avenue Suite 100 Anchorage, AK 99501-3539 Re: Milne Point Unit MPS-27 (Diverter) BP Exploration (Alaska) Inc. Surface Location: 3277' FSL, 311' FEL, SEC. 12, T12N, R10E, UM Btmhole Location: 3488' FSL, 2229' FEL, SEC. 11 ,T12N, R10E, UM Dear Mr. Maunder: In reference to the above mention well, BP would like a wavier to drill this well ./ without a diverter system. The proposed surface hole would be drilled into the top of the Schrader bluff "OB" sand without a diverter. A full stfng 7" casing would be set and BOP's nipples up prior to drilling out of the surface casing. The Schrader Bluff sands are normally pressured sands in the direct offset wells. Gas hydrates and abnormal pressures have not been seen on the pad with the first 5 well'>drilled and are not anticipated. The Doyon 141 drilling rig should be on location on or about April 20, 2002 and will be ready to spud the S-27 well. Your prompt attention to the request is appreciated. Please call Steve Campbell (564-4401) or Pat Archey (564-5803) if you have any questions. RECEIVED Sincerely, l~{~ APR 0 9 Z007 AI..OiI & Gas ConI. Commission AncbOfage Steve Campbell Operations Drilling Engineer ~ L. { IWell Name: I MPS-27 Drill and Complete Plan Summary Milne ~'" t MPS-27 Well Permit I Type of Well (service / producer / injector): I Multi Lateral Producer "OA" & "OB" 20011 FNL, (3277 FSL), 3111 FEL, (4968 FWL), SEC. 12, T12N, R1 DE X=565,700.12 Y=5,999,943.96 17911 FNL, (34881 FSL), 22291 FEL, (30491 FWL), SEC. 11, T12N,R1 OE X=558,500.00 Y=6,000,095.00 2=4045' TVD/RKB 17911 FNL, (34881 FSL), 22291 FEL, (30491 FWL), SEC. 11, T12N,R1 OE ./ X=558,500.00 Y=6,000,095.00 2=4097' TVD/RKB 17911 FNL, (34881 FSL), 22291 FEL, (30491 FWL), SEC. 11, T12N,R1 OE X=558,500.00 Y=6,000,095.00 2=4097' TVD/RKB I AFE Number: I TBD I RiQ: I Doyon 141 / I I Estimated Start Date: I April 20, 2002 I I OperatinQ days to complete: 123 1 I MD: 1113191 I TVD: 14097 I I 1 Max Inc: 194 I I KOP: 1320 I I KBE: 168 I I I Surface Location: Target Location: Bottom "OA" Target Location: Bottom "OB Total Depth I Well DesiQn (conventional, slim hole, etc.): I Conventional Grass Roots Producer I Objective: I Schrader "OA" & "OB" Mud Program: 9-7/8" Surface Hole Mud Properties: Density (ppg) Funnel visc YP 8.6 - 9.20// 75 -150 25 - 60 HTHP Spud - LSND Freshwater Mud pH API Filtrate LG Solids < 6.5 9.0-9.5 <8 N/A 6-1/8" Production Hole Mud Properties: KCL-CaC03 Flow Pro Density (ppg) Funnel visc YP HTH P pH API Filtrate LG Sol ids 8.6 - 9.20 j' 40 55 22 - 27 <10 8.0 - 8.5 4 - 6 < 12 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 IR. 1 't Milne P(' 'MPS-27 Well Permit Cement Program: Casing Size 17" 26lb/ft L-80 BTC Surface casing Basis 250% excess over gauge hole in permafrost interval, 40% excess over gauge hole below permafrost Total Cement Volume: Wash 50 bbl of Newtonian Wash weighted to 8.32 ppg Spacer 50 bbl of Viscosified Spacer (Alpha,Design) weighted to 10.50 ppg .; Lead 1018 sxs 10.7Ib/gal Class L - 4.1~cuft/sx (cement to surface) Tail 382 sxs 15.8 lb/gal Prem G - 1.15 cuft/sx (top of tail at 7195' MD) Temp 1 BHST ~ 800 F from SOR, BHCT 850 F estimated by Halliburton Evaluation Program: 9 7/8" Hole Section: Open Hole: Cased Hole: 6-1/8" Hole section: Open Hole: MWD/GR/RES IFR/CASANDRA N/a MWD/GR/RES ABI/IFR/CASANDRA Formation Markers: Formation Tops MD kb (ft) TVDrkb Pore Pressure Estimated EMW r (ft) *(Psi) (ppg) Base Permafrost 1924 1822 819 8.65 SVl N/A Top Ugnu 6432 3457 1554 8.65 Top Ugnu M N/A NA 7695 3967 1784 8.65 NB 7758 3987 1793 8.65 NC 7838 4012 1804 8.65 NE 7888 4027 1811 8.65 NF 8032 4067 1829 8.65 Top OA 8134 4092 1840 8.65 Base OA 8248 4117 1851 8.65 Top OB 8384 4142 1863 8.65 TD 11319 4097 1842 8.65 . Based on TVD depths 2 ¡ , Milne PI 1 MPS-27 Well Permit , CasinglTubing Program: Hole Size Csg/ WtlFt Grade Conn Length Top Bottom Tbg MD/ MD / TVDrkb O.D. TVDrkb 42" 20" * 92# H-40 Welded 80' 0' 113'/113' 9 7/8" 7" 26# L-80 BTC 8384' 0' 8384/4142 6-1/8" 4-1/2" /' 0 A lateral Slotted 12.6# L-80 IBT-M 3185' 8,134/4,091 11,319'/4,045' Liner 6-1/8" 4-1/2" OB lateral Slotted 12.6# L-80 IBT-M 2935' 8384' /4142' 11,319' /4,097' Liner *The 20" casing is insulated Recommended Bit Pro~ram: BHA Hole Depth (MD) Bit Type Nozzle/Flow Size rate 1 9 7/8" 0' - 5067' Smith "Twist" 3-13 & 1-10 2 6 1/8" 5067' - TD' PDC TBD Well Control: . Production hole will be drilled without a diverter. "See Attached Letter" Surface Interval: . Maximum anticipated BHP: . Maximum surface pressure: . Planned BOP test pressure: . Kick tolerance: . Planned completion fluid: 1863 psi @ 4142TVDJkb - Top of "DB" 1448 psi @ surface ( (Based on BHP and a full column of gas from TD @ 0.1 psi/ft) Test Rams and Annular to 3500 psi N/A 9.1 ppg KCL / 6.8 ppg Diesel 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 (+/- 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 3 f Milne P{ 1 MPS-27 Well Permit 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,øverpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be (8.65 Ib/gal EMW). In this well, the Schrader Bluff formation will be drilled with 9.1 ppg mud. Offset injectors that have above normal shut-in pressures will be shut-in prior to drilling this well. Some of the wells on H-pad have experienced sever gas cut mud well below the permafrost. Pad Data Sheet . Please Read the S-Pad Data Sheet thoroughly. Breathing . N/A Hydrocarbons . Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Fa u Its . NA Hydrogen Sulfide . MPS Pad is not designated as an H2S Pad. Anti-collision Issues . MPS-27 has no anti-collision issues. 4 { Milne P( ~ MPS-27 Well Permit DRILL & COMPLETION PROCEDURE Pre- Rig Operations 1. The 20" conductor has been pre installed Procedure 1. MIRU, NU riser on 20" conductor, PU 5" drill pipe 2. Drill 9-7/8" surface hole as per directional plan. Maximum angle 840 3. Condition mud with lubes and spot casing running lube pill prior to 7" casing run. POOH laying down DP 4. Run and cement 7" casing from TD to surface. 5. Install FMC II" 5m horizontal wellhead 6. N/U and test 13 0/8" 5m BOP to 3500 psi I / 7. Rill with 6-1/8" bit and BHA. Test casing to 3500 psi. / 8. Drill out float equipment and 25' of new hole and perform FIT to 11.0 ppg 9. Drill 6-1/8" OB horizontal production hole as per directional plan. 10. Run 4-1/2" slotted liner and hang off 100' inside 7" casing. ( 11. M,ake up Baker Window Master milling assembly with bottom trip anchor and MWD. a. RIH. Orient and set whipstock to place window at top of the OA interval. b. Shear off and mill window thru 7" casing. 12. Drill 6-1/8" OA lateral geosteering and short tripping as required. Maintain FloPro mud properties and POOH. MU whipstock retrieving tool and pull whipstock / Run 4 Y2" slotted liner with Baker Hook Hanger and hang off in 7" casing ;' Displace out drilling mud with 9.1 ppg KCL POOH Run in hole with 4-1/2" jet pump completion as per schematic Land tubing hanger and test Set BPV ND BOP Install and test tree Pull BPV Freeze protect Drop ball and set production packer / Test 7" x 4-1/2" annulus and packer to 3500 psi Install BPV and secure the well RD/MO ~"Y 9'" 13. I 14. " 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. \27. 5 bp REFERENCE INFORMATION Co-ordinate (NIE) Reference: Wen Centre: Plan MPS.27, T roe No<1b Ve0ûc31 (lVD) Referenœ: S.Pad De," 72.00 Section (VS) Reference: Slol - (O.OON,O.OOE) Measured Depth Reference: S.Pad~' 72.00 Cakulation Method: Minimmn Cur'\'ature SURVEY PROGRAM Depth Fro Depth To Sur..eyiPlan CB-GYRO.SS M\\'D-IFR+MS 72.00 1000.00 P!anneò; MPS-27 Wp04 VI 1000.00 11319.94 PIanœd:MPS-27Wp04VI COMPANY DETAILS BP Anxx:o Calculation Melbod: Minimmn Curvature Error System: ISCWSA Sam Method: T ray Cylinder Nor1h Error Surface: EUipûca1 -:- Casing "'amÎl1¡;! Method: Rules Based FORMATIONTOPDET~S All TVD depths are ssTVD plus 72'fo1" RKBE. No. TVDPath MDPath Fonnation 1924.47 7695.04 7758.67 7838.73 7888.69 8032.87 8134.08 8248.40 8384.11 B.PRF SBF2-NA SBFI-NB SBE4-NC SBE2-NE SBEI-NF TSBD-OA TSBC TSBB-OB I 2 3 4 5 6 7 8 9 1822.00 3967.00 3987.00 4012.00 4027.00 4067.00 4092.00 4117.00 4142.00 0 : 500' MD, 500'TVD 800 1625.46' MD, 1572'TVD 1600 ~ ~ ~ ..c Õ. Ö ~ t: ~ 2400 ¡:: 3200 4000 Tool Name PLm MPS-27 +N'-S -f:l-W -28.25 -64523 5999944,02 Plan: MI'S.27 Wp04 (1'1all MI'S-27il'lall MPS.H) C"....IOO By: Ken AliL" Chech-.J: Date: 4/X/21XI2 Date: Rc...icwcd: Dale: WELL DETAII_~ N<'¡lIung (;..sting I..alitud: Ltlo~itud: Slut 5r.5700.l1 7rr24'37.050N 149"2T54,OK'W N'A TARGET DETAILS Nan>: WD -N'-S +E/.W Northin¡; I"",injl Slwpc MPS.27 NA 3967.00 21i2929 -4S1<O.8X {,(J027.10,OO 5(,0195.00 I'uinl MPS.27 T5 4097.00 214.3.1 -7199.19 6000095,00 551(500.00 11()inl MPS.27 T4 4120.00 54220 -6951.27 (.000425,00 55&745.00 I'uint MPS.27 n 4125.00 740.9.1 -68~.50 (.000625,00 55&890.00 'I~)in\ MPS-27 TI 4142.00 2594.69 .5498,02 {,(J02490,OO 5(,oI~O.OO Puint MPS.27 Goo 4142.00 2697,6.1 .5262,09 6002595,00 5(,Q.¡15.00 1'~llyg('n Mps.27 T2 4144,00 1799,17 -6020,09 6()()1690,OO 559(~S.OO rllill( MD Ine Azi TVD 72.00 0.00 0.00 72.00 500.00 0.00 0.00 500.00 700.00 4.00 303.89 699.84 1625.46 31.76 303.89 1572.00 1924.47 34.75 303.89 1822.00 2046.18 34.75 303.89 1922.00 2969.28 71.68 303.89 2465.24 6632.44 71.68 303.89 3616.77 7695.04 71.68 259.00 3967.00 7800.03 71.68 259.00 4000.00 8384.11 80.50 236.35 4142.00 8626.56 91.27 209.21 4159.70 9159.92 91.27 209.21 4147.91 9343.74 91.17 216.56 4144.00 9352.39 90.82 216.55 4143.85 10653.75 90.82 216.55 4125.13 10661.14 91.12 216.55 4125.00 10663.76 91.12 216.45 4124.95 10886.26 91.12 216.45 4120.60 10908.25 92.00 216.45 4120.00 10943.91 93.26 217.12 4118.36 11319.94 93.26 217.12 4097.00 SECTION DETAILS +N/-S DLeg TFaee +EI-W 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.89 -5.79 2.00 303,89 5.91 160.80 -239.38 3.00 0,00 244.06 252.22 -375.49 1.00 0.00 382.83 290.91 -433.09 0.00 0,00 441.55 696.08 -1036.22 4.00 0,01 1056.47 2635.29 -3922.76 0.00 0,00 3999.45 2829.29 -4880.88 4.00 -97.40 4962.91 2810.27 -4978.71 0.00 0.00 5060.14 2594.69-- -5498.02 - 4.05 -71.18 5572.80 2418.85 -5660.19 ~O -69.71 5729.66 1953.41 -5920.38 0.00 0.00 5975.88 1799.17 -6020.09 4.00 90.67 6070.96 1792.23 -6025.24 4.00 -177.90 6075.90 746.87 -6800.10 0.00 0.00 6819.32 740.93 -6804.50 4.00 0.52 6823.54 738.83 -6806.06 4.00 -89.85 6825.03 559.88 -6938.21 0.00 0.00 6951.80 542.20 -6951.27 4.00 0.30 6964.33 513.67 -6972.60 4.00 28.17 6984.80 214.33 -7199.19 0.00 0.00 7202.38 CASING DETAILS No. TVD MD Name 4142,00 8384.11 7" 4097.00 11319.9341/2" VSee Target -. MPS-27 NA MPS-27T1 - -r7~8 MPS-27 T2 MPS-27 T3 MPS-27 T4 MPS-27 T5 Size 7.000 4.500 Tolal Depth: 11319.94' MD. 4097' T-=..... 5600 6400 7200 4000-- 3000-- ~ 4:: 0 0 ~ £ 2000 ..c: 1:: ~ :E :; 0 (/) 1000 bp COMPANY DETAILS REFERENCE INFORMA nON SURVEY PROGRAM Depth Fm Depth To Sury<y,vlan Crc;¡led By: Ken AJkl1 Checked : Plan: MPS-27 Wp04 (l'lan MPS-271j'lan MPS-27) Dale: Tool Co-onlinao, (N;E) Referenc<: Well Centre: Plan MPS-27, T"", North Veruc..1 (lVD) Ref=nœ: S-Pad De\' n.oo S<clion (VS) Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: S-Pad Dev n,oo CakuJalÏOJ1 MetOOd: Minimum CUr..a~ BP Amoco n.oo ]000.00 Pianœd: MPS-27 Wp04 VI 1000.00 ]13 19.94 Pianœd: MPS-27 Wp04 VI CB-GYRO-SS MWD"IFR~MS Calcu1a1ion Method: Mininllnn Curvature Error System: ISCWSA Scan Method: TJav Cylinder North Erro£ Surface: EllipIi<3I + Casing WamilJ ! MeûJocê Rules Based Rcviewed: WEll. DETAII$ All TVD depths are plus 72'for RKBE. N3rœ 'EI-W Lalitud: Northing Eastinll +N'..s Plan MI'S-27 -28.25 -64523 5999944,02 5r.5700, I I 70"24'.17.050N WY'27'54,OKtW N'A TARGET DETAILS Nan>: 1'01) 'N'~~ -+E/-W N<orthin~ I:a...tin~ Shape MPS.27 NA 3967.00 282929 48110,S¡¡ £.002730,00 5MH95.00 I'oinl MPS-27 T5 4097.00 214.33 .7199,19 WOOO95.00 558500.00 ¡'uin( MPS.27 T4 4120.00 54220 -6951.27 £.000425,00 558745.00 I.oim MI'S-27 D 4125.00 740,93 -681).1.50 £.000625.00 SS~90.(X) I'oinl MPS-27 TI 4142.00 2594.69 -5498.02 £.002490,00 560180.00 Ilninl MI'S.27 Goo 4142.00 2697.63 -5262,09 £.002595,00 560415.00 Inl}'[wn MPS-27 T2 4144,00 1799.17 -6020,09 6001690.00 559665.00 I'ninl SECfION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg Tfaee 1 72.00 0.00 0.00 72.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 3 700.00 4.00 303.89 699.84 3.89 -5.79 2.00 303.89 4 1625.46 31.76 303.89 1572.00 160.80 -239.38 3.00 0.00 5 1924.47 34.75 303.89 1822.00 252.22 -375.49 1.00 0.00 6 2046.18 34.75 303.89 1922.00 290.91 -433.09 0.00 0.00 7 2969.28 71.68 303.89 2465.24 696.08 -1036.22 4.00 0.01 8 6632.44 71.68 303.89 3616.77 2635.29 -3922.76 0.00 0.00 9 7695.04 71.68 259.00 3967.00 2829.29 .4880.88 4.00 -97.40 10 7800.03 71.68 259.00 4000.00 28] 0.27 -4978.71 0.00 0.00 11 8384.11 80.50 236.35 4142.00 2594.69 -5498.02 4.05 -71.18 12 8626.56 9\.27 209.21 4159.70 2418.85 -5660.19 12.00 -69.71 13 9159.92 91.27 209.21 4147.91 ] 953.41 -5920.38 0.00 0.00 14 9343.74 91.17 216.56 4144.00 ]799.17 -6020.09 4.00 90.67 15 9352.39 90.82 216.55 4143.85 ] 792.23 -6025.24 4.00 -177.90 16 10653.75 90.82 216.55 4125.13 746.87 -6800.] 0 0.00 0.00 17 10661.14 91.12 216.55 4125.00 740.93 -6804.50 4.00 0.52 18 10663.76 91.12 216.45 4124.95 738.83 -6806.06 4.00 -89.85 19 10886.26 91.12 216.45 4120.60 559.88 -6938.21 0.00 0.00 20 10908.25 92.00 216.45 4120.00 542.20 -6951.27 4.00 0.30 21 10943.91 93.26 2]7.12 4118.36 513.67 -6972.60 4.00 28.17 22 11319.94 93.26 217.12 4097.00 214.33 -7199.19 0.00 0.00 c::. ,. '/~ ! ¡ I r I I Start Dir 12/1 00' : 8384.11' MD, 4142'TVD Start Dir 4.05/1 00' : 7800.03' MD, 4000'TVD . j Eod 0;, ,7695.04' MD, 3967' TVD 4000 /.( Dale: 418/2IJ02 Dale: tunp.îtud.: Shl( VSee Target 0.00 0.00 5.91 244.06 382.83 441.55 1056.4 7 3999.45 4962.9] 5060.14 5572.80 5729.66 5975.88 6070.96 6075.90 6819.32 6823.54 6825.03 6951.80 6964.33 6984.80 7202.38 .- MPS-27 NA MPS-27 T] MPS-27 T2 MPS-27 T3 MPS-27 T4 MPS-27 T5 : 6632.44' MD, 3616.77TVD fORMATION TOP DETA]LS No. TVDPath MDPath fonnalÏon Start Dir 4/100' : 2046.18' MD, 1922'TVD Dir : 1924.47' MD, 1822' TVD Dir 1/100': 1625.46' MD, 1572'TVD 1ft Dir 3/100' : 700' MD, 699.84'TVD Start Dir 2/100': 500' MD, 500TVD 0 jut' I ! I 1, ! t 1 i f ~ 4] 42.00 8384.1 I 7" 4097.00 ] 1319.93 41/2" 1 2 3 4 5 6 7 8 9 1822.00 3967.00 3987.00 4012.00 4027.00 4067.00 4092.00 4117.00 4142.00 CASING DETAILS No. TVD MD -8000 I -7000 -1000 I -6000 I -50uu W est( - )/East( +) [IOOOftlin] 1924.47 B.PRf 7695.04 SBf2-NA 7758.67 SBfl-NB 7838.73 SBE4-NC 7888.69 SBE2-NE 8032.87 SBEI-Nf 8134.08 TSBD-OA 8248.40 TSBC 8384.11-- TSBB-OB- ..-... Name Size 7.000 4.500 I 1000 ( BP My Planning Report Company: BP Amoco Field: Milne Point Site: M Pt S Pad Well: Plan MPS-27 Wellpath: Plan MPS-27 ( Date: 4/5/2002 Time: 13: 17:01 Page: Co-ordinate(NE) Reference: Well: Plan MPS-27. True North Vertical (fVD) Reference: S-Pad Dev 72.0 Section (VS) Reference: Well (0.00N.0.00E,271.71Azi) Survey Calculation Method: Minimum Curvature Db: Oracle MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO ft deg deg ft ft ft deg/100ft deg/100ft deg/10Ott deg 72.00 0.00 0.00 72.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 4.00 303.89 699.84 3.89 -5.79 2.00 2.00 0.00 303.89 1625.46 31.76 303.89 1572.00 160.80 -239.38 3.00 3.00 0.00 0.00 1924.47 34.75 303.89 1822.00 252.22 -375.49 1.00 1.00 0.00 0.00 2046.18 34.75 303.89 1922.00 290.91 -433.09 0.00 0.00 0.00 0.00 2969.28 71.68 303.89 2465.24 696.08 -1036.22 4.00 4.00 0.00 0.01 6632.44 71.68 303.89 3616.77 2635.29 -3922.76 0.00 0.00 0.00 0.00 7695.04 71.68 259.00 3967.00 2829.29 -4880.88 4.00 0.00 -4.22 -97.40 7800.03 71.68 259.00 4000.00 2810.27 -4978.71 0.00 0.00 0.00 0.00 8384.11 80.50 236.35 4142.00 2594.69 -5498.02 4.05 1.51 -3.88 -71.18 8626.56 91.27 209.21 4159.70 2418.85 -5660.19 12.00 4.44 -11.19 -69.71 9159.92 91.27 209.21 4147.91 1953.41 -5920.38 0.00 0.00 0.00 0.00 9343.74 91.17 216.56 4144.00 1799.17 -6020.09 4.00 -0.05 4.00 90.67 9352.39 90.82 216.55 4143.85 1792.23 -6025.24 4.00 -4.00 -0.15 -177.90 10653.75 90.82 216.55 4125.13 746.87 -6800.10 0.00 0.00 0.00 0.00 10661.14 91.12 216.55 4125.00 740.93 -6804.50 4.00 4.00 0.04 0.52 10663.76 91.12 216.45 4124.95 738.83 -6806.06 4.00 0.01 -4.00 -89.85 10886.26 91.12 216.45 4120.60 559.88 -6938.21 0.00 0.00 0.00 0.00 10908.25 92.00 216.45 4120.00 542.20 -6951.27 4.00 4.00 0.02 0.30 10943.91 93.26 217.12 4118.36 513.67 -6972.60 4.00 3.53 1.89 28.17 11319.94 93.26 217.12 4097.00 214.33 -7199.19 0.00 0.00 0.00 0.00 Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Map Zone: Coordinate System: Geomagnetic Model: Site: M Pt S Pad Site Position: From: Map Position Uncertainty: Ground Level: Northing: 5999978.00 ft Easting: 566345.00 ft Latitude: Longitude: North Reference: Grid Convergence: 0.00 ft 0.00 ft Well: Plan MPS-27 Slot Name: +N/-S -28.25 ft Northing: 5999944.02 ft +E/-W -645.23 ft Easting: 565700.11 ft Position Uncertainty: 0.00 ft Well Position: Latitude: Longitude: Wellpath: Plan MPS-27 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: S-Pad Dev 6/29/2001 57460 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 72.00 ft Plan: MPS-27 Wp04 Date Composed: Version: Tied-to: Principal: Yes Casing Points MD TVD ft ft 8384.11 4142.00 11319.94 4097.00 Hole Size in Diameter in Name 7.000 4.500 9.875 6.125 7" 4 1/2" Plan Section Information Alaska, Zone 4 Well Centre BGGM2001 70 24 37.329 N 149 27 35.171 W True 0.51 deg 70 24 37.050 N 149 27 54.083 W Well Ref. Point 0.00 ft Mean Sea Level 26.28 deg 80.78 deg Direction deg 271.71 4/5/2002 1 From: Definitive Path Target MPS-27 NA MPS-27 T1 MPS-27 T2 MPS-27 T3 MPS-27 T4 MPS-27 T5 I~ BP My Planning Report (' ~. Company: BP Amoco Field: Milne Point Site: M Pt S Pad Well: Plan MPS-27 Wellpath: Plan MPS-27 Targets Date: 4/5/2002 Time: 13: 17:01 Page: Co-ordinate(NE) Reference: Well: Plan MPS-27, True North Vertical (TVD) Reference: S-Pad Dev 72.0 Section (VS) Reference: Well (0.00N,0.00E,271.71Azi) Survey Calculation Method: Minimum Curvature Db: Oracle 2 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 MPS-27 NA 3967.00 2829.29 -4880.88 6002730.00 560795.00 70 25 4.860 N 149 30 17.198 W MPS-27 T5 4097.00 214.33 -7199.19 6000095.00 558500.00 70 24 39.124 N 149 31 25.101 W MPS-27 T 4 4120.00 542.20 -6951.27 6000425.00 558745.00 70 24 42.351 N 149 31 17.843 W MPS-27 T3 4125.00 740.93 -6804.50 6000625.00 558890.00 70 24 44.307 N 149 31 13.546 W MPS-27 T1 4142.00 2594.69 -5498.02 6002490.00 560180.00 70 25 2.549 N 149 30 35.289 W MPS-27 Geo 4142.00 2697.63 -5262.09 6002595.00 560415.00 70 25 3.563 N 149 30 28.373 W -Polygon 1 4142.00 2730.56 -5591.84 6002625.00 560085.00 70 25 3.884 N 149 30 38.042 W -Polygon 2 4142.00 2794.97 -4961.19 6002695.00 560715.00 70 25 4.522 N 149 30 19.552 W -Polygon 3 4142.00 2086.28 -5682.58 6001980.00 560000.00 70 24 57.547 N 149 30 40.688 W -Polygon 4 4142.00 -1.40 -7101.31 5999880.00 558600.00 70 24 37.003 N 149 31 22.226 W -Polygon 5 4142.00 430.45 -7302.50 6000310.00 558395.00 70 24 41.249 N 149 31 28.135 W MPS-27 T2 4144.00 1799.17 -6020.09 6001690.00 559665.00 70 24 54.721 N 149 30 50.577 W Survey Tool/Cömll1ent deg/1 OOft 72.00 0.00 0.00 72.00 0.00 5999944.02 565700.11 0.00 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 28.00 5999944.02 565700.11 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 128.00 5999944.02 565700.11 0.00 0.00 CB-GYRO-SS 300.00 0.00 0.00 300.00 228.00 5999944.02 565700.11 0.00 0.00 CB-GYRO-SS 400.00 0.00 0.00 400.00 328.00 5999944.02 565700.11 0.00 0.00 CB-GYRO-SS 500.00 0.00 0.00 500.00 428.00 5999944.02 565700.11 0.00 0.00 CB-GYRO-SS 600.00 2.00 303.89 599.98 527.98 5999944.98 565698.65 1.48 2.00 CB-GYRO-SS 700.00 4.00 303.89 699.84 627.84 5999947.86 565694.28 5.91 2.00 CB-GYRO-SS 800.00 7.00 303.89 799.37 727.37 5999953.13 565686.28 14.02 3.00 CB-GYRO-SS 900.00 10.00 303.89 898.26 826.26 5999961.26 565673.94 26.53 3.00 CB-GYRO-SS 1000.00 13.00 303.89 996.24 924.24 5999972.23 565657.30 43.40 3.00 MWD+IFR+MS 1100.00 16.00 303.89 1093.04 1021.04 5999986.01 565636.40 64.58 3.00 MWD+IFR+MS 1200.00 19.00 303.89 1188.40 1116.40 6000002.55 565611.29 90.03 3.00 MWD+IFR+MS 1300.00 22.00 303.89 1282.06 1210.06 6000021.82 565582.06 119.67 3.00 MWD+IFR+MS 1400.00 25.00 303.89 1373.75 1301.75 6000043.76 565548.77 153.41 3.00 MWD+IFR+MS 1500.00 28.00 303.89 1463.24 1391.24 6000068.30 565511.52 191.17 3.00 MWD+IFR+MS 1600.00 31.00 303.89 1550.26 1478.26 6000095.40 565470.41 232.84 3.00 MWD+IFR+MS 1625.46 31.76 303.89 1572.00 1500.00 6000102.69 565459.34 244.06 3.00 MWD+IFR+MS 1700.00 32.51 303.89 1635.12 1563.12 6000124.51 565426.24 277.62 1.00 MWD+IFR+MS 1800.00 33.51 303.89 1718.97 1646.97 6000154.48 565380.76 323.72 1.00 MWD+IFR+MS 1900.00 34.51 303.89 1801.87 1729.87 6000185.26 565334.06 371.06 1.00 MWD+IFR+MS 1924.47 34.75 303.89 1822.00 1750.00 6000192.91 565322.45 382.83 1.00 B.PRF 2000.00 34.75 303.89 1884.06 1812.06 6000216.60 565286.50 419.27 0.00 MWD+IFR+MS 2046.18 34.75 303.89 1922.00 1850.00 6000231.08 565264.52 441.55 0.00 MWD+IFR+MS 2100.00 36.91 303.89 1965.63 1893.63 6000248.42 565238.22 468.21 4.00 MWD+IFR+MS 2200.00 40.91 303.89 2043.43 1971.43 6000282.97 565185.80 521.36 4.00 MWD+IFR+MS 2300.00 44.91 303.89 2116.67 2044.67 6000320.42 565128.97 578.96 4.00 MWD+IFR+MS 2400.00 48.91 303.89 2184.97 2112.97 6000360.59 565068.01 640.75 4.00 MWD+IFR+MS 2500.00 52.91 303.89 2248.02 2176.02 6000403.29 565003.23 706.42 4.00 MWD+IFR+MS 2600.00 56.91 303.89 2305.49 2233.49 6000448.31 564934.93 775.66 4.00 MWD+IFR+MS 2700.00 60.91 303.89 2357.13 2285.13 6000495.42 564863.45 848.11 4.00 MWD+IFR+MS 2800.00 64.91 303.89 2402.66 2330.66 6000544.40 564789.14 923.44 4.00 MWD+IFR+MS 2900.00 68.91 303.89 2441.88 2369.88 6000595.00 564712.36 1001.28 4.00 MWD+IFR+MS i{ BP ( My Planning Report Company: BP Amoco Date: 4/5/2002 Time: 13:17:01 Page: 3 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-27, True North Site: M Pt S Pad Vertical (TVD) Reference: S-Pad Dev 72.0 Well: Plan MPS-27 Section (VS) Reference: Well (0.00N,0.00E,271.71Azi) Wellpath: Plan MPS-27 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS Tool/Comment ft deg deg ft ft ft ft ft deg/1 000 2969.28 71.68 303.89 2465.24 2393.24 6000630.89 564657.91 1056.47 4.00 MWD+IFR+MS 3000.00 71.68 303.89 2474.89 2402.89 6000646.94 564633.57 1 081 . 15 0.00 MWD+IFR+MS 3100.00 71.68 303.89 2506.33 2434.33 6000699.18 564554.31 1161.49 0.00 MWD+IFR+MS 3200.00 71.68 303.89 2537.77 2465.77 6000751.41 564475.06 1241.83 0.00 MWD+IFR+MS 3300.00 71.68 303.89 2569.20 2497.20 6000803.65 564395.80 1322.17 0.00 MWD+IFR+MS 3400.00 71.68 303.89 2600.64 2528.64 6000855.89 564316.55 1402.51 0.00 MWD+IFR+MS 3500.00 71.68 303.89 2632.07 2560.07 6000908.13 564237.29 1482.85 0.00 MWD+IFR+MS 3600.00 71.68 303.89 2663.51 2591.51 6000960.37 564158.04 1563.19 0.00 MWD+IFR+MS 3700.00 71.68 303.89 2694.94 2622.94 6001012.60 564078.78 1643.53 0.00 MWD+IFR+MS 3800.00 71.68 303.89 2726.38 2654.38 6001064.84 563999.53 1723.87 0.00 MWD+IFR+MS 3900.00 71.68 303.89 2757.81 2685.81 6001117.08 563920.28 1804.21 0.00 MWD+IFR+MS 4000.00 71.68 303.89 2789.25 2717.25 6001169.32 563841.02 1884.55 0.00 MWD+IFR+MS 4100.00 71.68 303.89 2820.69 2748.69 6001221.56 563761.77 1964.89 0.00 MWD+IFR+MS 4200.00 71.68 303.89 2852.12 2780.12 6001273.79 563682.51 2045.23 0.00 MWD+IFR+MS 4300.00 71.68 303.89 2883.56 2811.56 6001326.03 563603.26 2125.57 0.00 MWD+IFR+MS 4400.00 71.68 303.89 2914.99 2842.99 6001378.27 563524.00 2205.91 0.00 MWD+IFR+MS 4500.00 71.68 303.89 2946.43 2874.43 6001430.51 563444.75 2286.25 0.00 MWD+IFR+MS 4600.00 71.68 303.89 2977.86 2905.86 6001482.75 563365.49 2366.59 0.00 MWD+IFR+MS 4700.00 71.68 303.89 3009.30 2937.30 6001534.98 563286.24 2446.93 0.00 MWD+IFR+MS 4800.00 71.68 303.89 3040.73 2968.73 6001587.22 563206.98 2527.27 0.00 MWD+IFR+MS 4900.00 71.68 303.89 3072.17 3000.17 6001639.46 563127.73 2607.61 0.00 MWD+IFR+MS 5000.00 71.68 303.89 3103.61 3031.61 6001691.70 563048.48 2687.95 0.00 MWD+IFR+MS 5100.00 71.68 303.89 3135.04 3063.04 6001743.94 562969.22 2768.29 0.00 MWD+IFR+MS 5200.00 71.68 303.89 3166.48 3094.48 6001796.17 562889.97 2848.63 0.00 MWD+IFR+MS 5300.00 71.68 303.89 3197.91 3125.91 6001848.41 562810.71 2928.97 0.00 MWD+IFR+MS 5400.00 71.68 303.89 3229.35 3157.35 6001900.65 562731.46 3009.31 0.00 MWD+IFR+MS 5500.00 71.68 303.89 3260.78 3188.78 6001952.89 562652.20 3089.65 0.00 MWD+IFR+MS 5600.00 71.68 303.89 3292.22 3220.22 6002005.13 562572.95 3169.99 0.00 MWD+IFR+MS 5700.00 71.68 303.89 3323.65 3251.65 6002057.36 562493.69 3250.33 0.00 MWD+IFR+MS 5800.00 71.68 303.89 3355.09 3283.09 6002109.60 562414.44 3330.67 0.00 MWD+IFR+MS 5900.00 71.68 303.89 3386.53 3314.53 6002161.84 562335.18 3411.01 0.00 MWD+IFR+MS 6000.00 71.68 303.89 3417.96 3345.96 6002214.08 562255.93 3491.35 0.00 MWD+IFR+MS 6100.00 71.68 303.89 3449.40 3377.40 6002266.32 562176.68 3571.69 0.00 MWD+IFR+MS 6200.00 7.1.68 303.89 3480.83 3408.83 6002318.55 562097.42 3652.03 0.00 MWD+IFR+MS 6300.00 71.68 303.89 3512.27 3440.27 6002370.79 562018.17 3732.37 0.00 MWD+IFR+MS 6400.00 71.68 303.89 3543.70 3471.70 6002423.03 561938.91 3812.71 0.00 MWD+IFR+MS 6500.00 71.68 303.89 3575.14 3503.14 6002475.27 561859.66 3893.05 0.00 MWD+IFR+MS 6600.00 71.68 303.89 3606.57 3534.57 6002527.51 561780.40 3973.38 0.00 MWD+IFR+MS 6632.44 71.68 303.89 3616.77 3544.77 6002544.45 561754.69 3999.45 0.00 MWD+IFR+MS 6700.00 71.35 301.07 3638.20 3566.20 6002578.38 561700.35 4054.49 4.00 MWD+IFR+MS 6800.00 70.95 296.86 3670.52 3598.52 6002623.46 561617.19 4138.59 4.00 MWD+IFR+MS 6900.00 70.64 292.64 3703.44 3631.44 6002662.22 561531.12 4225.47 4.00 MWD+IFR+MS 7000.00 70.42 288.40 3736.78 3664.78 6002694.48 561442.56 4314.68 4.00 MWD+IFR+MS 7100.00 70.31 284.15 3770.40 3698.40 6002720.08 561351.96 4405.81 4.00 MWD+IFR+MS 7200.00 70.30 279.91 3804.12 3732.12 6002738.88 561259.74 4498.41 4.00 MWD+IFR+MS 7300.00 70.38 275.66 3837.78 3765.78 6002750.81 561166.37 4592.03 4.00 MWD+IFR+MS 7400.00 70.57 271.42 3871.21 3799.21 6002755.80 561072.28 4686.20 4.00 MWD+IFR+MS 7500.00 70.85 267.19 3904.26 3832.26 6002753.82 560977.95 4780.48 4.00 MWD+IFR+MS 7600.00 71.23 262.98 3936.76 3864.76 6002744.89 560883.84 4874.40 4.00 MWD+IFR+MS 7695.04 71.68 259.00 3967.00 3895.00 6002730.00 560795.00 4962.91 4.00 MPS-27 NA 7700.00 71.68 259.00 3968.56 3896.56 6002729.06 560790.39 4967.50 0.00 MWD+IFR+MS 7758.67 71.68 259.00 3987.00 3915.00 6002717.95 560735.82 5021.84 0.00 SBF1-NB ( BP (' My Planning Report Company: BP Amoco Date: 4/5/2002 Time: 13:17:01 Page: 4 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-27, True North Site: M Pt S Pad Vertical (TVD) Reference: S-Pad Dev 72.0 Well: Plan MPS-27 Section (VS) Reference: Well (0.00N,0.00E,271.71Azi) Wellpath: Plan MPS-27 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS Tool/Comment ft deg deg ft ft ft ft ft deg/1 000 7800.03 71.68 259.00 4000.00 3928.00 6002710.12 560697.35 5060.14 0.00 MWD+IFR+MS 7838.73 72.19 257.44 4012.00 3940.00 6002702.30 560661 .40 5095.91 4.05 SBE4-NC 7888.69 72.87 255.44 4027.00 3955.00 6002690.72 560615.18 5141.89 4.05 SBE2-NE 7900.00 73.03 254.99 4030.32 3958.32 6002687.87 560604.75 5152.25 4.05 MWD+IFR+MS 7905.78 73.11 254.76 4032.00 3960.00 6002686.38 560599.42 5157.55 4.05 B.Ugnu 8000.00 74.45 251.04 4058.32 3986.32 6002659.02 560513.22 5243.17 4.05 MWD+IFR+MS 8032.87 74.94 249.76 4067.00 3995.00 6002648.12 560483.45 5272.70 4.05 SBE1-NF 8100.00 75.95 247.15 4083.88 4011.88 6002623.73 560423.24 5332.39 4.05 MWD+IFR+MS 8134.08 76.47 245.83 4092.00 4020.00 6002610.26 560393.02 5362.33 4.05 TSBD-OA 8200.00 77.50 243.30 4106.85 4034.85 6002582.17 560335.27 5419.48 4.05 MWD+IFR+MS 8248.40 78.28 241.46 4117.00 4045.00 6002559.87 560293.54 5460.74 4.05 TSBC 8300.00 79.11 239.51 4127.12 4055.12 6002534.56 560249.74 5504.01 4.05 MWD+IFR+MS 8384.11 80.50 236.35 4142.00 4070.00 6002490.00 560180.00 5572.80 4.05 MPS-27 Geo -- '~ÞD 8400.00 81.17 234.54 4144.53 4072.53 6002480.99 560167.16 5585.45 12.00 MWD+IFR+MS 8425.00 82.23 231.70 4148.14 4076.14 6002465.97 560147.51 5604.79 12.00 MWD+IFR+MS 8450.00 83.32 228.88 4151.28 4079.28 6002449.96 560128.57 5623.39 12.00 MWD+IFR+MS 8475.00 84.42 226.08 4153.96 4081.96 6002433.00 560110.40 5641.20 12.00 MWD+IFR+MS 8500.00 85.53 223.28 4156.15 4084.15 6002415.14 560093.05 5658.17 12.00 MWD+IFR+MS 8525.00 86.65 220.49 4157.85 4085.85 6002396.43 560076.57 5674.26 12.00 MWD+IFR+MS 8550.00 87.78 217.71 4159.07 4087.07 6002376.92 560061.00 5689.42 12.00 MWD+IFR+MS 8575.00 88.92 214.93 4159.79 4087.79 6002356.66 560046.38 5703.61 12.00 MWD+IFR+MS 8600.00 90.06 212.15 4160.01 4088.01 6002335.71 560032.75 5716.80 12.00 MWD+IFR+MS 8626.56 91.27 209.21 4159.70 4087.70 6002312.76 560019.40 5729.66 12.00 MWD+IFR+MS 8700.00 91.27 209.21 4158.08 4086.08 6002248.36 559984.14 5763.57 0.00 MWD+IFR+MS 8800.00 91.27 209.21 4155.87 4083.87 6002160.68 559936.14 5809.73 0.00 MWD+IFR+MS 8900.00 91.27 209.21 4153.66 4081.66 6002072.99 559888.13 5855.90 0.00 MWD+IFR+MS 9000.00 91.27 209.21 4151.45 4079.45 6001985.31 559840.12 5902.06 0.00 MWD+IFR+MS 9100.00 91.27 209.21 4149.24 4077 .24 6001897.63 559792.11 5948.23 0.00 MWD+IFR+MS 9159.92 91.27 209.21 4147.91 4075.91 6001845.09 559763.34 5975.88 0.00 MWD+IFR+MS 9200.00 91.25 210.81 4147.03 4075.03 6001810.22 559743.61 5994.88 4.00 MWD+IFR+MS 9300.00 91.19 214.81 4144.90 4072.90 6001725.74 559690.19 6046.52 4.00 MWD+IFR+MS 9343.74 91.17 216.56 4144.00 4072.00 6001690.00 559665.00 6070.96 4.00 MPS-27 T2 9352.39 90.82 216.55 4143.85 4071.85 6001683.01 559659.91 6075.90 4.00 MWD+IFR+MS 9400.00 90.82 216.55 4143.16 4071.16 6001644.52 559631.91 6103.10 0.00 MWD+IFR+MS 9500.00 90.82 216.55 4141.73 4069.73 6001563.68 559573.08 6160.23 0.00 MWD+IFR+MS 9600.00 90.82 216.55 4140.29 4068.29 6001482.84 559514.25 6217.35 0.00 MWD+IFR+MS 9700.00 90.82 216.55 4138.85 4066.85 6001402.00 559455.42 6274.48 0.00 MWD+IFR+MS 9800.00 90.82 216.55 4137.41 4065.41 6001321.16 559396.59 6331.60 0.00 MWD+IFR+MS 9900.00 90.82 216.55 4135.97 4063.97 6001240.32 559337.77 6388.73 0.00 MWD+IFR+MS 10000.00 90.82 216.55 4134.53 4062.53 6001159.48 559278.94 6445.86 0.00 MWD+IFR+MS 10100.00 90.82 216.55 4133.09 4061.09 6001078.63 559220.11 6502.98 0.00 MWD+IFR+MS 10200.00 90.82 216.55 4131.65 4059.65 6000997.79 559161.28 6560.11 0.00 MWD+IFR+MS 10300.00 90.82 216.55 4130.22 4058.22 6000916.95 559102.45 6617.23 0.00 MWD+IFR+MS 10400.00 90.82 216.55 4128.78 4056.78 6000836.11 559043.63 6674.36 0.00 MWD+IFR+MS 10500.00 90.82 216.55 4127.34 4055.34 6000755.27 558984.80 6731.48 0.00 MWD+IFR+MS 10600.00 90.82 216.55 4125.90 4053.90 6000674.43 558925.97 6788.61 0.00 MWD+IFR+MS 10653.75 90.82 216.55 4125.13 4053.13 6000630.97 558894.35 6819.32 0.00 MWD+IFR+MS 1 0661.14 91.12 216.55 4125.00 4053.00 6000625.00 558890.00 6823.54 4.00 MPS-27 T3 10663.76 91.12 216.45 4124.95 4052.95 6000622.88 558888.46 6825.03 4.00 MWD+IFR+MS 10700.00 91.12 216.45 4124.24 4052.24 6000593.55 558867.20 6845.68 0.00 MWD+IFR+MS 10800.00 91.12 216.45 4122.29 4050.29 6000512.61 558808.52 6902.65 0.00 MWD+IFR+MS 10886.26 91.12 216.45 4120.60 4048.60 6000442.80 558757.90 6951.80 0.00 MWD+IFR+MS 10908.25 92.00 216.45 4120.00 4048.00 6000425.00 558745.00 6964.33 4.00 MPS-27 T 4 .' Company: BP Amoco Field: Milne Point Site: M Pt S Pad Well: Plan MPS-27 Wellpath: Plan MPS-27 Survey MD Incl Azim ft deg deg 10943.91 93.26 217.12 11000.00 93.26 217.12 11100.00 93.26 217.12 11200.00 93.26 217.12 11300.00 93.26 217.12 11319.94 93.26 217.12 t f BP My Planning Report Date: 4/5/2002 Time: 13:17:01 Page: Co-ordinate(NE) Reference: Well: Plan MPS-27, True North Vertical (TVD) Reference: S-Pad Dev 72.0 Section (VS) Reference: Well (0.00N.0.00E,271.71Azi) Survey Calculation Method: Minimum Curvature Db: 5 Oracle TVD Sys TVD MapN MapE VS DLS Tool/Comment ft ft ft ft ft deg/10OO 4118.36 4046.36 6000396.29 558723.93 6984.80 4.00 MWD+IFR+MS 4115.18 4043.18 6000351.35 558690.52 7017.25 0.00 MWD+IFR+MS 4109.50 4037.50 6000271.22 558630.97 7075.12 0.00 MWD+IFR+MS 4103.81 4031.81 6000191.10 558571.42 7132.98 0.00 MWD+IFR+MS 4098.13 4026.13 6000110.98 558511.87 7190.84 0.00 MWD+IFR+MS 4097.00 4025.00 6000095.00 558500.00 7202.38 0.00 MPS-27 T5 Field: Milne Point Well: S-27 ML DIRECTIONAL LWD OPEN HOLE LOGGING NONE NONE Dir/GR/RES NONE FORMATION TDp of Lead Cement Base of Permafrost Top of Tail Cement Top of N sand (' " ( BP EXPLORATION Milne Point Unit 5-27 & 527 L 1 Actual Surface Location: 3277' FSL 311' FEL DEPTH MD I TVD TOC 113' 113' Surf Surf 1,924' 1,822' 7,195' 7,695' 3,967' --õ~/~;. -.. - ..-..- .. -..-- --.. - ..-. .-... ABI/GR NONE OA sand 8,134' 4,091' - ----..-.. -..- ..- ..- ..- .._..1::.32~ ~~O~I.. 7" Surface casing , " ""....- 8,384' 4,142' - - õfr/Rëš . - . . - . . - . . - . . - . . - . . - . . - . . - . . - ... - ABI/GR NONE OB sand 8,384' 4,142' 11,319' 4,097' , - -.--.. -.. - ..- ..- ..- ..-. --.-1--.-. -- .-.- .--.. 4/9/2002 ENG: Steve Campbell RIG: Doyon 141 MSL 35' RKB: 72' HOLE CASING MUD INFO TOC SIZE SPECS PIT INFO INFORMATION Wellhead &..\,, o ....1.""", H-40 FMC Gen 6 20" x 11" 5M InsulatedWelde N/A 42" d KOP @ 300' MD EOB @ 2969' MD 6-1/8" Hole - 4-1/2",12.6#, L-80 Slotted Liner 9-7/8" Surface Casing 7" 26# L-80 BTC MW = 9.2 6-1/8" Hole - 4-1/2",12.6#, L-80 Slotted Liner 1 MPS-27ML WBD.xls j ( - S-Pad PRODUCER CoJ'r'letion Diagram (PROPOSED) .'1;' 8 .. 8 Of- -- "II, ~I. I" ~I i: ~ ~I II ~I n ì,',¡r.1 ~ 51 I j ~ ..- ~ Tubing hanger connection NSCTpin x-overpup NSCT box X IBT pin 4-1/2" X 1" KBMG 4-1/2" 12.6# L80 IBT-M tubing Phoenix Pressure Sensor - BTC box X Pin 4-1/2" Halliburton Sliding Sleeve with 3.813 bore 7" x 5-1/2" packer S-3 5-1/2" X 4-1/2" x-over 10'Pup 4-1/2" 'XN' nipple 3.813 BORE with 3.725" no-go 10'Pup Re-entry guide 7",26#, L-80, BTC-M R3 Apr-08-Z00Z 16:01 r -. T"" - -:- "ï" - ì From-MCC WING 6 ( +901-659-5065 1( ~ I r I L I I ~ ! I r I I.. I I ~ ---1 . 9í 1--MPS-7¡ + r ~- I I.. I I ~ I ~.@ ~fÇl. . --1 - / ~ ",.. .. I 1 I J I I ~ I I 1 I .I I I ~I I I .:J~SE:c.r --. - r- ..... -- 7". \ SEIcr - .. ...!.12/V ð II ' / n?"" 1"I:7D£ ",-N. R11t ~- I 1 I I - i - -:""'T_. - - 1...'::"- - ..L - .31 MPS-29i + M~S-27 ..- MPS-2~i + .21i .15i I PI.AN T - Z--('8 ) 15'00'00" I GRID .. MPU S-P AD LEGEN_D -+ AS-BUILT CONDUCTOR EXISTING CONDUCTOR . ----. ,NOTES: 1, DATE OF" SURVEY; MARCH 26, 28, &. 31, 2002. 2. REFERENCE FIELD BOOK: MP02-03 PQS. 61-69, MP02-04 PGS. 9-11. 3. CQORDINA rES ARE: ALASKA STATe: PLANE. ZONE-4 NAD-27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCAI..E: FACTOR IS: 0.999904923, 6. HORIZONTAL CONTROL IS BASED ON MPU CF'P MONUMENT CFP-3 AND MPU H-PA[) MONUMENT H-'. 7. EI...~VA TIONS ARI;; SPX MEAN SEA \..EVEL BASED ON MILNE POINT PIPELINE V~RTICAL CONTROl-. 2\ 28 ß 3't H-PAD noS/,; T12N 2 :5:) ~ 32 -~ ~~ 5 ~Cf3 IÆI\ 11 e !'\ 10 , <1 ,~ 6= ,~ 17 16 15 &1k VICINITY__. MAP N.T.S. _$,URVEYOR'S CERTIFICATE I H~REBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STAr~ OF A~ASKA AND THAT THIS P~A T REPRESENTS A SURVEY MAOe: BY ME OR UNDER MY DIRECT SUPERVISION ANI:) TI"IAT ALL DIMENSIONS AND OTHER DET An,S AR¡:: CORRECT AS OF MARCH 31, 2002. LOCATED WITHIN PROTRACT~D SEC, 12, T. 12.N., R. 10 E.. UM1AT MERIDIAN, ALASKA. WELL. --.. A,S,P, PLANT ".., GEODETIC GEODETIC CE"CLAR SECTION NO. <?OORDINATES COORDINATES POSITION(DMS) ~O~I!ION(D.DD) BOX ELE,V. OFFSETS PS-7' y= 6,000,021.49 N= 2,2J6.84 70'24'37,787" 70.4104965" 3,353' FSL ~ ."- I x= 565.~,~9.85 E- 6.a68;q::¡ 149'27' 4~~570" 149.4S26583~ 38,9 20' F,EL MPS-24' Y=5,999,955.70 N~ 2,2.37.07 70"24'37.162" 70.4103228" ,3,289' FSl. - I x= 595.J43.45 E= §J,~1 3. 90 149.271,~2,809" 1 49.4646692" 39.1 267' FEL MPS-27 Y~5,999,943.96 N== 2,236.95 70"24':n:Òso" 70,410291'" 39.3' 3,278' FSL n., x~ 565.17.°0,12 E= ..6,5,f?9.00 149'27'54.083" 149.4650231' ..31" FEL MPS-29' Y=5.999,936.18 N= 2,236.98 70"24'3Ii976" 70.410~á"ï1. 39," 3,27Õ" FSL I .X= 565,670.94 Eo:: 6,538.80 1 ~9'27'54,940" 149,:,4652611' 340' rEI- n 4/0"//02 ,SSuE:() FOR INfQf.1W''I1CIII .t:I.Q,. ,., ~An¡ --, ti~VI~'O.. . t~'" ROJlelt -. ('¡i<"",N: - ~~coes , ~- ' . C~£Ct<E~' ALUSON ,-- ~] ~ ¡¡ '~M£: I ._"~= ! -- °F~g~Ž' ~~:81:~ao , ~ ffi~ærnœc "OD ~~. J.JC t.OH £h~Æ'''' _n ",,,,,D ..."..-.:"ta",. ~(''''IIA: .., -.T ""CIIIC'D ~A". MY ~"n( ""'ÞOICflJI\I1C. '¡',,':I~#I Q~~OI ,"- 200' ObP MILNE POINT UNIT S-P AD AS-BUILT CONDUCTORS WELL.S MP S-71. 24i. 27 & 29i ~"e:e:T: 1 Qr 1 04/08/02 MON 15:08 [TX/RX NO 6406] IãI 001 H 206298 DATE 03/14/02 CHECK NO. 00206298 DATE INVOICE I CREDIT MEMO DESCRIPTION .1 - GROSS VENDOR DISCOUNT Ai ASKAOlt A NET i 00. otJ 00 031202 CK03i202H PYMT COMMENTS: HANDL:NG INST: ioa. 00 H Permit to Drill çee S/H - Terrie Hubhle X4628 RECEIVED APR 0 0 ¿'r,¡ii) t) I,¡: tVì psc. ;( 7 ~ AlaskaOU it Gas Cons. CommiS3ion Anchorage THE ATIACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. 111!11 100. 00 iOO on BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 206298 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00206298 ._~........ . PAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 03/14/02 AMOUNT $100.00 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333.WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 \2- ~ ,-1 t\ " f n /1\./ ,/; ,< . ~..."J/ ¡,,;. :'. . ",'.: .k.. .,-,~.,-:; III 2 0 b 2 g a III I: 0 a.. . 2 0 j 8 g 5 I: 0 0 8 I. L. . g III CHECK 1 ST ANDARD LEITER DEVELOPMENT vi DEVELOPMENT REDRILL EXPLORA TION INJECTION WELL INJECTION WELL REDRILL ;~ ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITIAL LETTER WELL NAME ¡f) p¿t 5 - Z 7 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) P~OT HOLE (PH) ANNUL,~SPOSAL NO ANNULAR DISPOSAL <--> YES ANNULAR DISPOSAL THIS WELL "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 originaJ API number stated above. ' In accordance with 2.0 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly dìfferentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (na,me on permit). Annular disposal has ~ot been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. ~ . ANNULUS <--> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .sùbJect to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuan'ce of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may ~cur. WELL PERMIT CHECKLIST COMPANY 8;/;( WELL NAME IJ1Pt.,( ;;.- 7./ FIELD & POOL N /I ~ INIT CLASS --:¡;;'C V l' GI L ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . ~ N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Œ N ~: ~~~~~~~~~~~:ed:~~en~~ob:~.....::::::..::..:::: 14'~J)[IAj.s,~bdu~~'J(.b-~Cq4( 5óvA of ilv- ~;Us~j . 5. Well located proper d~stance from drilling unit boundary. . . . ~, N sd~~ br !3/ufi f/'IJ(' ",ß~,~7 4 /.Ii~LCj- / < 1 ru/¿ ~, r rf:ly I' 6. Well located proper distance from otherwjill~.. . . . . . . . . d)Ji. pr¡/Iu'tj t.'¿Jl,""¡ ¡"O ~ dt>t~"¿"ÞUI1.4..d«'" tf{yð-r-~ S12-c-1?~. // 7. Suffic~ent a~reage availabl~ in drilling uni(V. . . . . . . . . . ~ ~5(A ¿. . (~, (;tr1 -h, ~8if' cf¡( IJ rr?~' J ~ -h ¿."-# / r7 ~' ,~ 8. If deviated, IS wellbore plat Included.. . . . . . . . . . . . . . ~ N IlLS ~ ~Á-L SC¿ALL,' '¿rh ntitvJf.1..., I Cjf ~ ~LhQ~ ,~ 9. Operator only affected party.. . . . . . . . . . . . . . . . . . ~ N <'t;:So /??P/i .s -¡<Í-~ . _~/1'1 ~ -4(/~"'fP~1 '5 ~~UiH:d 10. Operator has appropriate bond in force. . . . . . . . . . . . . \ N ~ /~. D;; : í ~;~ ~ ~t ~ ~~. '-" r I~~ '¿;¿Lrf7h"r7i1 . 11. Permit can be issued withqut conservation order. . . . . . . . y~"¡' ~ Iu-,/ 1<11./ ¡;¡r ,LÇ; ." . ¿5^ 12. Permit can be issued without administrative approval.. . . . . ~""l\r' 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y Qb 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ~ N to'/ @ li ~ ¡ , 15. Surface casing protects all known USDWs. . . . . . . . . . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . "N 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . .-v---N- f\.Í/k 18. CMT will cover all known productive horizons. . . . . . . . . . ~~--N- s/~iI¿J~. 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N 0 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . ,N r,1l.\a-"'- Illl . 21. If a re-drill, has a 10-403 for abandonment been approved. . . ~ ¡\J/I'Q 22. Adequate wellbore separation proposed.. . . . . . . . . . . . W N 23. If diverter 'required, does it meet regulations. . . . . . . . .. i:. 'j-... N P t "ev ~ wct,.i "'fly 24. Drilling fluid program .schematic & equip list adequate. . . . . ~~, N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N r 26. BOPE press rating appropriate; test to '3500 psig. N }/LSP 7. 1 44-f f(A. . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . @ ~ 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y .æ, 30. Permit can be issued w/o hydrogen sulfide measures. . . . . ~ 31. Data presented on potential overpressure zones. . . . . .. Q. Y N 32. Seismic analysis of shallow gas zones. . . . . . . . . . Z.. <f' Y N A~~, P .,R OATE 33. Seabed condition survey (if off-shore). . . . . . . . . '" Y N Þ 1) V.lf. ó z.- 34. Contact name/phone for weekly progress reports [explo tory only] Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ',' . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and '(E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: it (), (),~'1 , TEM "TZ- ( '-t¡~ ~ WGA 1jJf4!r APPR DATE ENGINEERING APPR DA T~ \iJ6Æ- ef( ,S(Ot. &nvl '-1t;f-\1"0 J GEOLOGY APPR DATE PROGRAM: Exp - Dev V. Redrll - Serv - Wellbore seg - Ann. disposal para req - GEOL AREA Bc;n UNIT# ()/ /3 z.B ON/OFF SHORE C)~ v" Õ uP~ td. Lee:..., ""L "T, ~V:J ,,~\. = Q ~ \ ,,~~ , - \N~",([, \ ":> ~.\- <" \'~~ Ç" '):r\<-- C ) . G<V'7 :þ c, t- ::. 3"'5 00 {J c~ , J52 ~f/.. '-Y :>t( ( Y N Y N Nou. 'f"'ZUßsþj. ,,~S\V ~ ~ r Comments/Instructions: RPC- SFD- COT DTS 0 t( <.'6jc <-- JMH. G:\geology\templates \checklist. doc ) ') Well H ¡story File APPENDIX Infonnation of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. , To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologicaHy . . organize this category of infonnation. ) dOê)-D ~ lOÇJto5 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jul 03 09:01:00 2002 Reel Header Service name. . . . . . . . . . . . .LISTPE Date.................... .02/07/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Tape Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/07/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments............... ..STS LIS Physical EOF Comment Record TAPE HEADER MPU MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22071 A. WEAVER E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 5 AK-MW-22071 J. STRAHAN C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services MPS-27 500292308400 BP Alaska, Inc. Sperry-Sun Drilling 03-JUL-02 Services MWDRUN 2 AK-MW-22071 A. WEAVER E. VAUGHN MWDRUN 4 AK-MW-22071 A. WEAVER E. VAUGHN 12 12N 10E 3278 311 67.30 39.30 ') ) # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 20.000 113.0 6.125 7.000 8301.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1,2,4,AND 5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE WHILE DRILLING (PWD). THE PLANNED TURN COULD NOT BE MADE, SO THIS WELL SECTION WAS KICKED-OFF AT 6400'+/- MD IN THE MPS-27 PBl WELL BORE. 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 5/23/02. MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1, 2, 4, AND 5 REPRESENT WELL MPS-27 WITH API#: 50-029- 23084-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11186'MD/4084'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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.OOl Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/07/03 Maximum Physical Record. .65535 File Type.... . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and 1 clipped curves; all bit runs merged. DEPTH INCREMENT: # FILE SUMMARY PEU TOOL CODE GR FET RPD RPM RPS RPX ROP $ ) ) .5000 START DEPTH 57.5 100.5 100.5 100.5 100.5 100.5 105.0 STOP DEPTH 11122.5 11129.5 11129.5 11129.5 11129.5 11129.5 11186.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PEU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 57.5 2803.0 MWD 2 2803.0 6400.0 MWD 4 6400.0 8317.0 MWD 5 8317.0 11186.0 $ # 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 Uni t s. . . . . . . . . . . . . . . . . . . . . . . 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 57.5 11186 5621.75 22258 57.5 11186 ROP MWD FT/H 0.35 1453.15 267.06 22163 105 11186 GR MWD API 7.39 123.23 68.6601 22131 57.5 11122.5 RPX MWD OHMM 0.17 1857.87 21.5805 22059 100.5 11129.5 RPS MWD OHMM 0.23 1451.36 27.4687 22059 100.5 11129.5 RPM MWD OHMM 0.37 2000 37.5131 22059 100.5 11129.5 RPD MWD OHMM 0.22 2000 36.3476 22059 100.5 11129.5 FET MWD HOUR 0.05 127.64 1.12226 22059 100.5 11129.5 ) First Reading For Entire File......... .57.5 Last Reading For Entire File.......... .11186 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/07/03 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...... .02/07/03 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 57.5 100.5 100.5 100.5 100.5 100.5 105.0 STOP DEPTH 2767.0 2759.0 2759.0 2759.0 2759.0 2759.0 2803.0 # 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: 03-MAY-02 Insite 66.37 Memory 2803.0 57.0 2803.0 .0 62.7 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PBOO166HRG6 PBOO166HRG6 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O J 9.875 LSND 9.50 132.0 8.0 500 7.6 2.100 1.920 1.800 2.500 68.0 75.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 57.5 2803 1430.25 5492 57.5 2803 ROP MWD010 FT/H 7.14 1453.15 240.048 5397 105 2803 GR MWD010 API 16.58 120.74 61.9916 5420 57.5 2767 RPX MWD010 OHMM 0.17 126.88 32.5067 5318 100.5 2759 RPS MWD010 OHMM 0.23 539.31 45.9751 5318 100.5 2759 RPM MWD010 OHMM 0.37 2000 69.7012 5318 100.5 2759 RPD MWD010 OHMM 0.22 2000 70.075 5318 100.5 2759 FET MWD010 HOUR 0.07 2.28 0.444255 5318 100.5 2759 ) First Reading For Entire File......... .57.5 Last Reading For Entire File.... . . . . . . .2803 File Trailer Service name............ .STSLIB.002 Service Sub Level Name.. . Version Number....... ... .1.0.0 Date of Generation...... .02/07/03 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...... .02/07/03 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 RPS FET RPD RPX RPM GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2759.5 2759.5 2759.5 2759.5 2759.5 2767.5 2803.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 6400.0 6400.0 6400.0 6400.0 6400.0 6400.0 6400.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # 05-MAY-02 Insite 66.37 Memory 6400.0 2803.0 6400.0 67.2 73.8 TOOL NUMBER PBOO166HRG6 PBOO166HRG6 ) BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 9.875 LSND 9.30 148.0 8.0 200 9.4 2.000 1.550 1.200 2.300 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 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR Min 2759.5 0.35 7.39 4.56 4.64 2.23 1.58 0.05 Max 6400 1216.04 123.23 35.64 35.02 32.39 33.08 15.37 First Reading For Entire File......... .2759.5 Mean 4579.75 378.305 68.1409 10.7928 11.0434 11.2666 11.5237 0.67494 Nsam 7282 7194 7266 7282 7282 7282 7282 7282 ,) 70.0 92.4 70.0 68.0 First Reading 2759.5 2803.5 2767.5 2759.5 2759.5 2759.5 2759.5 2759.5 Last Reading 6400 6400 6400 6400 6400 6400 6400 6400 ) Last Reading For Entire File.......... .6400 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/07/03 Maximum Physical Record. .65535 File Type.... ......,.... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/07/03 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 FET ROP GR RPX RPS RPD RPM $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 6400.5 6400.5 6400.5 6400.5 6400.5 6400.5 6400.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 8272.0 8317.0 8279.5 8272.0 8272.0 8272.0 8272.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA 07-MAY-02 Insite 66.37 Memory 8317.0 6400.0 8317.0 68.3 83.2 TOOL NUMBER PBOO166HRG6 PBOO166HRG6 } OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 9.875 LSND 9.20 91.0 8.5 200 8.0 1.700 1.210 1.200 2.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HOUR Min 6400.5 0.57 22.99 4.59 4.55 4.07 3.24 0.07 Max 8317 1231.1 116.71 301.11 762.75 760.88 444.64 40.46 First Reading For Entire File......... .6400.5 Last Reading For Entire File.......... .8317 Mean 7358.75 187.458 68.515 32.2509 41.767 44.8362 42.4352 0.64754 Nsam 3834 3834 3759 3744 3744 3744 3744 3744 70.0 101.2 70.0 70.0 First Reading 6400.5 6400.5 6400.5 6400.5 6400.5 6400.5 6400.5 6400.5 Last Reading 8317 8317 8279.5 8272 8272 8272 8272 8272 ) File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/07/03 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/07/03 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 5 ) header data for each bit run in separate files. 5 .5000 START DEPTH 8272.5 8272.5 8272.5 8272.5 8272.5 8280.0 8317.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 11129.5 11129.5 11129.5 11129.5 11129.5 11122.5 11186.0 14-MAY-02 Insite 66.37 Memory 11186.0 8317.0 11186.0 83.4 94.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB00180GR4/181H PB00180GR4/181H # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 ) 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: FLO-PRO 9.20 58.0 9.0 34000 3.4 .080 .050 .040 .060 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD050 FT/H GR MWD050 API RPX MWD050 OHMM RPS MWD050 OHMM RPM MWD 050 OHMM RPD MWD050 OHMM FET MWD050 HOUR Min 8272.5 5.41 34.58 0.25 0.29 0.79 0.63 0.29 Max 11186 556.72 119.21 1857.87 1451.36 2000 2000 127.64 Mean 9729.25 206.181 75.7762 18.1686 21.8099 36.2064 32.6056 2.63415 Nsam 5828 5738 5686 5715 5715 5715 5715 5715 First Reading For Entire File......... .8272.5 Last Reading For Entire File.......... .11186 62.0 95.0 62.0 62.0 First Reading 8272.5 8317.5 8280 8272.5 8272.5 8272.5 8272.5 8272.5 Last Reading 11186 11186 11122.5 11129.5 11129.5 11129.5 11129.5 11129.5 ) ') File Trailer Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/07/03 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/07 /03 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. . . . . . . . . . . . . . . . . . . . .02/07/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ) ) dQ:)-D<6S I oO¡ ltJl..o Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jul 03 09:36:29 2002 Reel Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/07/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/07/03 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 MPU MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-27 PB1 500292308470 BP Alaska, Inc. Sperry-Sun Drilling 03-JUL-02 Services JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22071 A. WEAVER E. VAUGHN MWDRUN 2 AK-MW-22071 A. WEAVER E. VAUGHN MWD RUN 3 AK-MW-22071 A. WEAVER E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3278 311 MSL 0) 67.30 39.30 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 20.000 113.0 ) ) 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1-3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) ; AND PRESSURE WHILE DRILLING (PWD). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 5/23/02. MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1-3 REPRESENT WELL MPS-27 PB1 WITH API#: 50-029-23084-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7569'MD/3914'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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/07/03 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX 1 clipped curves; all bit runs merged. .5000 START DEPTH 57.5 94.5 100.5 100.5 100.5 100.5 100.5 STOP DEPTH 7532.5 7569.5 7524.5 7524.5 7524.5 7524.5 7524.5 ) ) $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 57.5 2 2803.0 3 7382.5 MERGE BASE 2803.0 7382.5 7569.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per ~ecord............ . 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 57.5 7569.5 3813.5 15025 57.5 7569.5 ROP MWD FT/H 0.35 1985.51 305.67 14951 94.5 7569.5 GR MWD API 7.39 123.23 64.8454 14951 57.5 7532.5 RPX MWD OHMM 0.17 431.97 24.3108 14849 100.5 7524.5 RPS MWD OHMM 0.23 752.7 31.5381 14849 100.5 7524.5 RPM MWD OHMM 0.37 2000 40.9605 14849 100.5 7524.5 RPD MWD OHMM 0.22 2000 40.4206 14849 100.5 7524.5 FET MWD HOUR 0.05 17.24 0.676113 14849 100.5 7524.5 First Reading For Entire File......... .57.5 Last Reading For Entire File.......... .7569.5 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/07/03 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...... .02/07/03 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP RPD RPM RPS RPX FET $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 57.5 94.5 100.5 100.5 100.5 100.5 100.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 2767.0 2803.0 2759.0 2759.0 2759.0 2759.0 2759.0 03-MAY-02 Insite 66.37 Memory 2803.0 57.0 2803.0 .0 62.7 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PBOO166HRG6 PBOO166HRG6 # 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): 9.875 LSND 9.50 132.0 8.0 500 7.6 ) ) / RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 2.100 1.920 1.800 2.500 68.0 75.0 68.0 68.0 # 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 MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 57.5 2803 1430.25 5492 57.5 2803 ROP MWD010 FT/H 0.95 1985.51 243.496 5418 94.5 2803 GR MWD010 API 16.58 120.74 61.9916 5420 57.5 2767 RPX MWD010 OHMM 0.17 126.88 32.5067 5318 100.5 2759 RPS MWD010 OHMM 0.23 539.31 45.9751 5318 100.5 2759 RPM MWD010 OHMM 0.37 2000 69.7012 5318 100.5 2759 RPD MWD010 OHMM 0.22 2000 70.075 5318 100.5 2759 FET MWD010 HOUR 0.07 2.28 0.444255 5318 100.5 2759 First Reading For Entire File......... .57.5 Last Reading For Entire File.......... .2803 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/07/03 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...... .02/07/03 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 FET RPD RPM RPS RPX GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2759.5 2759.5 2759.5 2759.5 2759.5 2767.5 2803.5 STOP DEPTH 7337.5 7337.5 7337.5 7337.5 7337.5 7345.5 7382.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 05-MAY-02 Insite 66.37 Memory 7382.0 2803.0 7382.0 67.2 74.3 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PBOO166HRG6 PBOO166HRG6 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT LSND 9.30 148.0 8.0 200 9.4 TEMPERATURE (DEGF) ., ) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 2.000 1.550 1.200 2.300 70.0 92.4 70.0 68.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 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 2759.5 7382.5 5071 9247 2759.5 7382.5 ROP MWD020 FT/H 0.35 1216.04 349.272 9159 2803.5 7382.5 GR MWD020 API 7.39 123.23 66.2201 9157 2767.5 7345.5 RPX MWD020 OHMM 4.56 431.97 19.4958 9157 2759.5 7337.5 RPS MWD020 OHMM 4.64 752.7 23.2408 9157 2759.5 7337.5 RPM MWD020 OHMM 2.23 622.42 24.5848 9157 2759.5 7337.5 RPD MWD020 OHMM 1.58 419.74 23.4133 9157 2759.5 7337.5 FET MWD020 HOUR 0.05 15.37 0.645607 9157 2759.5 7337.5 First Reading For Entire File......... .2759.5 Last Reading For Entire File.......... .7382.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/07/03 Maximum Physical Record. .65535 File Type........ ....... .LO Next File Name. ......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/07/03 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 RPD RPM RPS RPX FET GR ROP $ 4 ) header data for each bit run in separate files. 3 .5000 START DEPTH 7338.0 7338.0 7338.0 7338.0 7338.0 7346.0 7383.0 STOP DEPTH 7524.5 7524.5 7524.5 7524.5 7524.5 7532.5 7569.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 06-MAY-02 Insite 66.37 Memory 7569.0 7382.0 7569.0 69.9 71.2 TOOL NUMBER PBOO166HRG6 PBOO166HRG6 9.875 LSND 9.20 91.0 8.0 200 8.4 1.600 65.0 ) MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 1.060 1.200 1.600 101.2 65.0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7338 7569.5 7453.75 464 7338 7569.5 ROP MWD030 FT/H 7.1 490.03 138.544 374 7383 7569.5 GR MWD030 API 46.08 109.53 72.543 374 7346 7532.5 RPX MWD030 OHMM 6.73 74.4 25.6602 374 7338 7524.5 RPS MWD030 OHMM 7.28 109.72 29.4067 374 7338 7524.5 RPM MWD030 OHMM 8.55 165.97 33.2305 374 7338 7524.5 RPD MWD030 OHMM 9.96 178.51 35.1636 374 7338 7524.5 FET MWD030 HOUR 0.26 17.24 4.71987 374 7338 7524.5 First Reading For Entire File......... .7338 Last Reading For Entire File.......... .7569.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/07/03 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.005 ') Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/07/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Reel Trailer Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/07/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Physical EOF Physical EOF End Of LIS File ') Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services
