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Home My WebLink About204-174Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/4/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221104 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU H-18 50029232240000 204174 10/2/2022 READ COILFLAG MPU F-01 50029225520000 195045 10/9/2022 READ CaliperSurvey MPU F-62A 50029226090100 220066 10/12/2022 READ CaliperSurvey MPU B-35 50029237240000 222085 10/17/2022 READ CaliperSurvey Please include current contact information if different from above. T37230 T37231 T27239 T37232 MPU H-18 50029232240000 204174 10/2/2022 READ COILFLAG Kayla Junke Digitally signed by Kayla Junke Date: 2022.11.07 16:21:15 -09'00' 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Pull Isolation Sleeve Performed: Suspend Perforate Other Stimulate Alter Casing Set CIBP Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Install Isolation Sleeve Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,639 feet N/A feet true vertical 4,226 feet N/A feet Effective Depth measured 8,642 feet feet true vertical 4,224 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / TDS 6,038' 3,883' Packers and SSSV (type, measured and true vertical depth)N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Contact Phone: 5,946, 6,042, 6,113, 6,199 & 6,692 3,838, 3,885, 3,920, 3,962, & 4,137 Premier, ZXP LTP, Swell, ZXP LTP & ZXP LTP 6,590psi 7,500psi 5,210psi 6,890psi 7,910psi 8,430psi Burst N/A Collapse N/A 2,480psi 4,790psi 3,199' 4,180' 4,220' 4,215' 4-1/2" 8,597' 8,565' 8,639' 4,226' 4-1/2" measuredPlugs Junk measured N/A Length 112' 4,562' 6,910' Size Surface Production Liner 'NB' 20" 10-3/4" 7-5/8" 4" Liner 'OA' Liner 'OB' 2,507' 1,993' 1,911' Casing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-174 50-029-23224-00-00 N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025906 MILNE POINT / SCHRADER BLUFF OIL Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: MILNE PT UNIT H-18 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 2,229 2,52237 0 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 35 Gas-Mcf MD 112' 4,562' 6,910' 180 Conductor TVD 112' 322-536 Sr Pet Eng: 7,500psi Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 236 8,430psi Brian Glasheen Brian.Glasheen@hilcorp.com 564-5277Authorized Title: Operations Manager Form 10-404 Revised 10/2021 Submit Within 30 days of Operations Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2022.10.20 13:27:52 -08'00' David Haakinson (3533) RBDMS JSB 102822 DSR-10/20/22MGR21OCT2022 _____________________________________________________________________________________ Revised By: TDF 10/20/2022 SCHEMATIC Milne Point Unit Well: MPU H-18 Last Completed: 11/24/2005 PTD: 204-174 27 28 29 30 25 26 Cleanout OB lateral to 8,624’ CTM 1/4/2018TD =8,639’(MD) / TD = 4,226’(TVD) 20” 7-5/8” 17 18 10-3/4” 1 2 13 21 22 “OA” Lateral PBTD =8,639’(MD)/ PBTD =4,226’(TVD) “OBA” Lateral 10 11 6 5 4 3 Orig. KB Elev.: 69.6’/ Orig. GL Elev.: 35.6’ RKB – Hanger: 20.07’ (Nabors 4ES) 13 “NB” Lateral 7 8 12 13 9 15 16 19 23 Min ID = 3.813” Min ID = 3.813” Min ID =2.620” 14 20 24 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / L-80 / BTC 9.794 Surface 4,562’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.750 Surface 10,228' 4” Liner NB 9.5 / L-80 / IBT 3.423 6,090’ 8,597’ 4-1/2” Liner OA 12.6 / L-80 / IBT 3.833 6,572’ 8,565’ 4-1/2” Liner OBA 12.6 / L-80 / IBT 3.833 6,728’ 8,639’ TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TDS 3.958 Surface 6,038’ JEWELRY DETAIL No Depth Item 1 2,062’ 4-1/2” X Profile (3.813” Packing Bore ID) 2 2,479’ KBG2 GLM 4.500” x 1” (Dummy Valve Set 12/02/05) 3 5,922’ 4-1/2” XD Sliding Sleeve Jet Pump Set 02/13/22 (8b) 4 5,946’ 7-5/8” x 4-1/2” Baker Premier Packer 5 6,014’ 4-1/2” X Profile (3.813” Packing Bore ID) 6 6,038’ Wireline Entry Guide 7 6,031’ NB Lateral Tie Back Sleeve 8 6,042’ NB Lateral ZXP Liner Top Packer 9 6,058’ NB Lateral Isolation Sleeve 10 6,058’ NB Lateral LEM #2 (Lateral Entry Module) 11 6,067’ NB Lateral Hook Wall, Hanger above 7-5/8” Window 12 6,073’ 4-1/2” XO Sliding Sleeve 13 6,084’ NB Lateral Hook Wall, Hanger below 7-5/8” Window 14 6,094’ 2-7/8”’ XN Nipple with PX Plug 15 6,113’ NB Lateral Swell Packer 16 6,188’ OA Lateral Tie Back Sleeve 17 6,199’ OA Lateral ZXP Liner Top Packer 18 6,539’ OA Lateral LEM #1 (Lateral Entry Module) 19 6,549’ OA Lateral Hook Wall, Hanger above 7-5/8” Window 20 6,566’ OA Lateral Hook Wall, Hanger below 7-5/8” Window 21 6,681’ OB Lateral Tie Back Sleeve 22 6,692’ OB Lateral ZXP Liner Top Packer 23 6,702’ OB Lateral 7-5/8” x 5-1/2” HMC Liner Hanger 24 6,800’ CIBP 25 8,552’ NB Lateral 4-1/2” Pack-off Bushing 26 8,597’ NB Lateral 4-1/2” Btm of Guide Shoe 27 8,520’ OA Lateral 4-1/2” Pack-off Bushing 28 8,565’ OA Lateral 4-1/2” Btm of Guide Shoe 29 8,595’ OB Lateral 4-1/2” Pack-off Bushing 30 8,639’ OB Lateral 4-1/2” Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 653 sx AS Lite, 257 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 604 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD Max Wellbore Angle = 93.0 deg @ 7,053’ MD 60 deg @ 6,038’ MD WELLHEAD Wellhead FMC Tubing Hanger, 11” x 4-1/2” TC-II Top & Bottom GENERAL WELL INFO API: 50-029-23224-00-00 Drilled and Completed by Doyon 14 – 10/13/2004 ESP Replacement by Nabors 4ES – 12/09/2004 ESP Replacement by Nabors 4ES – 2/20/2005 Convert to Jet Pump by Nabors 4ES – 11/24/2005 LATERAL WINDOW DETAIL Top of “NB” Window @ 6,072’ MD; Bottom @ 6,084’ MD; Angle @ top of window is 61 deg Top of “OA” Window @ 6,554’ MD; Bottom @ 6,566’ MD; Angle @ top of window is 75 deg Well Name Rig API Number Well Permit Number Start Date End Date MP H-18 Slickline 50-029-23224-00-00 204-174 9/25/2022 10/4/2022 No operations to report. No operations to report. 9/24/2022 - Saturday Pressure Test equipment to 250/2500 psi) Pumped 40 bbls criesel down TBG. Tags hung. 9/27/2022 - Tuesday 9/25/2022 - Sunday WELL SHUT-IN ON ARRIVAL, PT PCE 300L 3500H. PULL 3" JETPUMP (serial# - HC-00015, ratio: 10C) FROM XD-SS AT 5,922' MD. PULL 4-1/2" SLIP STOP FROM ISO SLV AT 6,055' SLM. PULL ISOLATION SLEEVE FROM 6,060' SLM (minor flow cutting). SHIFT XD- SS (appears closed) AT 5,922' MD. WELL SHUT-IN ON DEPARTURE, NOTIFIED PAD OP. 9/26/2022 - Monday 9/23/2022 - Friday No operations to report. 9/21/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/22/2022 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP H-18 Coil #9 50-029-23224-00-00 204-174 9/25/2022 Future WELL SHUT-IN ON ARRIVAL, PT PCE 300L /3500H. SHIFT 2-7/8"" XO-SS AT 6,073' SLM (appears open). SHIFT 4-1/2"""" XD-SS AT 5,922' MD (appears open). SET 3"" JETPUMP, SHOCK ABSORBER, DUAL SPARTEK GAUGES (serial# - HC-00025, ratio: 12A) IN XD-SS AT 5,922' MD. WELL SHUT-IN ON DEPARTURE, NOTIFIED PAD OP. MIRU CTU #9, Prep for BOP test. 10/1/2022 - Saturday CTU #9 wait on KWF 9.4 ppg. Pump 9.4 brine down Csg @ 4.4 bpm 161 bbls - NO FLOW Good - PJSM - pump across WH @ 0.5 bpm w/ no flow to trip tank. Pop off WH - BD Setting Tool - 1/2" ball recovered - Deploy sect 1 of Isolation sleeve - MU 2nd sec (setting tool) to sec 1. MU BHA to isolation sleeve assembly. MU QTS & test 4250 psi. RIH perform Inj Test. Sting isolation sleeve assembly into LEM 2. perform Inj Test. Pump 1/2" ball and set Pkr. POOH. FP Well. Blow 2" reel dry w/ N2. RDMO CTU #9. 10/4/2022 - Tuesday 10/2/2022 - Sunday BOP Test, MU ctc, DHCV, Stingers, & 2.25" JSN. Pt lubricator & stack to 280 low/ 3500 high. RIH clean to 7322' POOH stop at 7250.1' paint red flag. Continue POOH. At surface pop off MU Baker MHA test MU logging tools. RIH for logging pass stop at flag 7250' Log up at 50 fpm paint white flag at 6800' log up to 5800' stop wait POOH. At surface BD tools check for data.Good data -14' correction. MU CICR (use as CIBP). RIH correct depth at flag. Set CIBP @ 6800'. POOH pumping slick 1% kcl at 4.4 bpm. At Surf stop pumping and WHP 152 psi. Order KWF 9.4 ppg. 10/3/2022 - Monday 9/30/2022 - Friday No operations to report. 9/28/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/29/2022 - Thursday No operations to report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ƚŚĞďƌĂƐƐƵƉŽŶWKK,ǁŝƚŚ,͘ ϯ͘ ƚƐƵƌĨĂĐĞ͕ƉƌĞƉĂƌĞĨŽƌĚĞƉůŽǇŵĞŶƚŽĨ/ƐŽůĂƚŝŽŶƐůĞĞǀĞƉĞƌĂŬĞƌƌĞƉƌŝŬEĞůƐŽŶ͘ ϰ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘tĞůůƐŚŽƵůĚďĞĚĞĂĚĂƐƐƵŵŝŶŐŝƚƉĂƐƐĞĚƉƌĞƐƐƵƌĞƚĞƐƚĂďŽǀĞ͘,ŽǁĞǀĞƌ͕ŝĨ ƉƌĞƐƐƵƌĞŝƐŽďƐĞƌǀĞĚ͕ďůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨƚŽƌĞƚƵƌŶƚĂŶŬ͘<ŝůůǁĞůůǁͬ<t&͕ϴ͘ϱϱƉƉŐϭй<ůŽƌϴ͘ϱ /ƐŽůĂƚĞK tĞůů͗DWh,Ͳϭϴ ĂƚĞ͗ϵͬϴͬϮϮ ƉƉŐĂƐŶĞĞĚĞĚ͘DĂŝŶƚĂŝŶŚŽůĞĨŝůůƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽƚĂŶŬƵŶƚŝůůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶŝƐƌĞͲĞƐƚĂďůŝƐŚĞĚ͘ &ůƵŝĚƐŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚǁŚŝůĞĚĞƉůŽǇŝŶŐ,ƚŽĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚ ƚŚĞƌĞŝƐŶŽĞǆĐĞƐƐĨůŽǁ͘ ϱ͘ΎWĞƌĨŽƌŵĚƌŝůůďǇƉŝĐŬŝŶŐƵƉƐĂĨĞƚǇũŽŝŶƚǁŝƚŚd/tǀĂůǀĞĂŶĚƐƉĂĐĞŽƵƚďĞĨŽƌĞDh,͘ZĞǀŝĞǁǁĞůů ĐŽŶƚƌŽůƐƚĞƉƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚĐŽŵŵĞŶĐŝŶŐŵĂŬĞƵƉŽĨ,͘KŶĐĞ ƚŚĞƐĂĨĞƚǇũŽŝŶƚĂŶĚd/tǀĂůǀĞŚĂǀĞďĞĞŶƐƉĂĐĞĚŽƵƚ͕ŬĞĞƉƚŚĞƐĂĨĞƚǇũŽŝŶƚͬd/tǀĂůǀĞƌĞĂĚŝůǇĂĐĐĞƐƐŝďůĞ ŶĞĂƌƚŚĞǁŽƌŬŝŶŐƉůĂƚĨŽƌŵĨŽƌƋƵŝĐŬĚĞƉůŽǇŵĞŶƚŝĨŶĞĐĞƐƐĂƌǇ͘ Ă͘ƚƚŚĞďĞŐŝŶŶŝŶŐŽĨĞĂĐŚũŽď͕ƚŚĞĐƌŽƐƐŽǀĞƌͬƐĂĨĞƚǇũŽŝŶƚŵƵƐƚďĞƉŚǇƐŝĐĂůůǇDhƚŽƚŚĞ,ŽŶĞ ƚŝŵĞƚŽĐŽŶĨŝƌŵƚŚĞƚŚƌĞĂĚƐĂƌĞĐŽŵƉĂƚŝďůĞ͘ ϲ͘ƌĞĂŬůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂƚYd^ĂŶĚďĞŐŝŶŵĂŬĞƵƉ,ƉĞƌƐĐŚĞĚƵůĞďĞůŽǁ͘ŽŶƐƚĂŶƚůǇŵŽŶŝƚŽƌ ĨůƵŝĚƌĂƚĞƐƉƵŵƉĞĚŝŶĂŶĚĨůƵŝĚƌĞƚƵƌŶƐŽƵƚŽĨƚŚĞǁĞůů͘&ůƵŝĚƐ ŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚǁŚŝůĞ ĚĞƉůŽǇŝŶŐ,ƚŽĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞǆĐĞƐƐĨůŽǁ͘ ,^ĐŚĞĚƵůĞ;ƐƚŝŵĂƚĞ͗ĂĐƚƵĂůĚĞƉƚŚƐƐƵďũĞĐƚƚŽĐŚĂŶŐĞƉĞƌĂŬĞƌ,ƵŐŚĞƐƌĞƉƌŝŬEĞůƐŽŶͿ ΎϮϳͬϴ͛͛ϲ͘ϱηǁĞƌĞƵƐĞĚƚŽĞƐƚŝŵĂƚĞĨŽƌƚŚŝƐũŽďĂŶĚĐĂůĐƵůĂƚĞǁĞŝŐŚƚƐ͘ /dD >ĞŶŐƚŚ tĞŝŐŚƚůďƐ ZƵŶϭ DƵůĞ^ŚŽĞ ϭ͛ ϲ͘ϱ ϮͲϳͬϴ͛͛yEŶŝƉ Εϭ ϲ͘ϱ ddWŝŶƐƚĂůůĞĚƚŽ ŝƐŽůĂƚĞƚŚĞK ƐĂŶĚƐŝŶŝƚŝĂůůǇ͘ >ŽǁĞƌ^ĞĂůƐďĞůŽǁ>D ϱ͛ ϯϯ ϮͲϳͬϴ͛͛^ůŝĚŝŶŐƐůĞĞǀĞ ϱ͛ ϯϯ KƉĞŶƉŽƐŝƚŝŽŶƚŽ ĨůŽǁEƐĂŶĚƐ ŝŶŝƚŝĂůůǇĂŶĚƉƵŵƉ ĚŽǁŶĐŽŝů hƉƉĞƌ^ĞĂůƐďŽǀĞ>D ϱ͛ ϯϯ ϱͲϲ͛^ƉĂĐĞŽƵƚWhW ϱ͛ ϯϯ ϰϱ<ƉĂĐŬĞƌ ϱ͛ ϯϯ ŶĐŚŽƌ/^K ƐůĞĞǀĞŝŶƉůĂĐĞ ƐĞƚŝŶWhWũŽŝŶƚ ďĞůŽǁϲϬϱϱD ƉĞƌƚĂůůǇ /ƐŽůĂƚĞK tĞůů͗DWh,Ͳϭϴ ĂƚĞ͗ϵͬϴͬϮϮ /ƐŽůĂƚĞK tĞůů͗DWh,Ͳϭϴ ĂƚĞ͗ϵͬϴͬϮϮ ϳ͘ Z/,ǁŝƚŚ,ũƵƐƚĂďŽǀĞ>DϮĂƚϲϬϱϳ͛DƉĞƌdƵďŝŶŐƚĂůůǇ͘ ϴ͘ ƐƚĂďůŝƐŚŝŶũĞĐƚŝǀŝƚǇĚŽǁŶdďĂĐŬƐŝĚĞĚĂŶĚĚŽǁŶĐŽŝůƉƌŝŽƌƚŽƐƚŝŶŐŝŶŐŝŶƚŚĞƐĞĂůďŽƌĞ͘EŽƚĞŽŶt^Z͘ ϵ͘ Z/,ĂŶĚƐƚŝŶŐŝŶƚŽϯ͘ϲϴϴƐĞĂůďŽƌĞĂŶĚŶŽƚĞŝŶũĞĐƚŝǀŝƚǇĐŚĂŶ ŐĞĚŽǁŶďŽƚŚĐŽŝůďĂĐŬƐŝĚĞĂŶĚĐŽŝů͘EŽƚĞŽŶ t^Z͘ Ă͘ ƚƚŚŝƐƉŽŝŶƚŝĨƚŚĞƵƉƉĞƌƐĞĂůĂƌĞƉůĂĐĞĚĂďŽǀĞƚŚĞ>D͕ŝŶũĞĐƚŝǀŝƚǇĚŽǁŶƚŚĞďĂĐŬƐŝĚĞƐŚŽƵůĚ ƉƌĞƐƐƵƌĞƵƉǁŝƚŚŵŝŶŝŵĂůŝŶũĞĐƚŝǀŝƚǇŝĨĂŶǇ͘ ď͘ /ŶũĞĐƚŝǀŝƚǇǁŝƚŚƚŚĞƐůĞĞǀĞŽƉĞŶƐŚŽƵůĚĚĞĐƌĞĂƐĞǁŝƚŚƚŚĞůŽǁĞƌůĂƚĞƌĂůƐŝƐŽůĂƚĞĚǁŝƚŚƚŚĞƐĞĂůƐŝŶ ƉůĂĐĞĂŶĚƚŚĞddW͘ ϭϬ͘ ŶƐƵƌĞƐĞĂůƐĂƌĞƐƚƵŶŐŝŶƚŽƐĞĂůĂƐƐĞŵďůǇĂŶĚĚƌŽƉďĂůůƚŽƐĞƚƵƉƉĞƌϰϱ<WƉĂĐŬĞƌŵŝĚĞůĞŵĞŶƚŝŶƚŚĞ ŵŝĚĚůĞŽĨƚŚĞƉƵƉũŽŝŶƚďĞůŽǁϲϬϱϱD͘ ϭϭ͘ EŽƚĞWhǁĞŝŐŚƚĂŶĚĞŶƐƵƌĞƉĂĐŬĞƌŝƐƐĞƚ͘ ϭϮ͘ WƵŵƉƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚǁŚŝůĞWKK,͘^ƚŽƉĂƚƐƵƌĨĂĐĞƚŽƌĞĐŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘<ŝůůǁĞůůŝĨŶĞĐĞƐƐĂƌǇ͘ ϭϯ͘ ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐĂŶĚ^ƚĂŶĚŝŶŐKƌĚĞƌƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚ ĐŽŵŵĞŶĐŝŶŐďƌĞĂŬĚŽǁŶŽĨ,͘ ϭϰ͘ ŶƐƵƌĞƐĂĨĞƚǇũŽŝŶƚĂŶĚd/tǀĂůǀĞĂƐƐĞŵďůǇĂƌĞŽŶͲŚĂŶĚďĞĨŽƌ ĞďƌĞĂŬŝŶŐŽĨĨůƵďƌŝĐĂƚŽƌƚŽ>,͘ ϭϱ͘ ZDKdh͘ ϭϲ͘ ZdWŽƌ&WǁĞůů͘ ^ůŝĐŬůŝŶĞ͗ ϭ͘ D/Zh^ůŝĐŬůŝŶĞ͘WdůƵďƌŝĐĂƚŽƌƚŽϭ͕ϱϬϬƉƐŝ,ŝϮϱϬ>Žǁ͘ Ϯ͘ KƉĞŶy^ůŝĚŝŶŐ^ůĞĞǀĞΛϱ͕ϵϮϮ͛D͘ ϯ͘ ^ĞƚϭϮ:ĞƚƉƵŵƉǁŝƚŚŚĂŶŐŝŶŐŐĂƵŐĞŝŶ^ůŝĚŝŶŐ^ůĞĞǀĞΛϱ͕ϵϮϮ͛D͘ Ă͘ WƌŽŐƌĂŵŐĂƵŐĞĨŽƌϭŵŝŶƵƚĞĚĂƚĂŝŶƚĞƌǀĂůƐ͘ ϰ͘ Z^ůŝĐŬͲůŝŶĞ͘ 083&( /ƐŽůĂƚĞK tĞůů͗DWh,Ͳϭϴ ĂƚĞ͗ϵͬϴͬϮϮ ϱ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶƚŽƚĞƐƚE^ĂŶĚƉƌŽĚƵĐƚŝŽŶ KƉĞƌĂƚŝŽŶƐ͗ ϭ͘ Zh&ůŽǁďĂĐŬƚĂŶŬĂŶĚƐŚĂŬĞƐŚĂĐŬĨŽƌƐŚĂŬĞŽƵƚĂŶĂůǇƐŝƐ͘ Ϯ͘ dƵƌŶǁĞůůŽŶĂƚϭϱϬϬWƉŽǁĞƌĨůƵŝĚƌĂƚĞ͘ ϯ͘ ůůŽǁǁĞůůƚŽĨůŽǁĂƚϭϱϬϬWĨŽƌƵƉƚŽϲŚŽƵƌƐ͕ŽƌƵŶƚŝůƚŚĞ/ŝƐĨůƵŝĚƉĂĐŬĞĚ Ă͘ &ůƵŝĚƉĂĐŬŝŶŐŝƐŝŶĚŝĐĂƚĞĚďǇďƵŝůĚŝŶŐŽĨ/ƉƌĞƐƐƵƌĞ͘ ϰ͘ ZĂŵƉƵƉƉŽǁĞƌͲĨůƵŝĚƉƌĞƐƐƵƌĞďǇϮϬϬƉƐŝŐĞǀĞƌǇϲŚŽƵƌƐ͘ Ă͘ ĞŐŝŶƚĂŬŝŶŐƐŚĂŬĞŽƵƚƐŽŶϭͲŚŽƵƌŝŶƚĞƌǀĂůƐƚŽĚĞƚĞƌŵŝŶĞŝĨǁĞůůŝƐŵĂŬŝŶŐƐŽůŝĚƐŽƌŽŝů͘ ď͘ /ĨǁĞůůďĞŐŝŶƐƚŽŵĂŬĞхϭйƐŽůŝĚƐ͕ĚŝǀĞƌƚƚŽĨůŽǁͲďĂĐŬƚĂŶŬ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ŽŝůdƵďŝŶŐKW^ĐŚĞŵĂƚŝĐ ϰ͘ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽǇŵĞŶƚ ϱ͘ ƋƵŝƉŵĞŶƚ>ĂǇŽƵƚŝĂŐƌĂŵ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗E>tϬϮͬϭϯͬϮϮ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh,Ͳϭϴ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϭͬϮϰͬϮϬϬϱ Wd͗ϮϬϰͲϭϳϰ Ϯϰ Ϯϱ Ϯϲ Ϯϳ ϮϮ Ϯϯ ůĞĂŶŽƵƚKůĂƚĞƌĂůƚŽ ϴ͕ϲϮϰ͛dDϭͬϰͬϮϬϭϴdс ϴ͕ϲϯϵ͛;DͿͬdсϰ͕ϮϮϲ͛;dsͿ ϮϬ´ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ ³2$´/DWHUDO Wdс ϴ͕ϲϯϵ͛;DͿ ͬWdсϰ͕ϮϮϲ͛;dsͿ ³2%$´/DWHUDO KƌŝŐ͘<ůĞǀ͗͘ϲϵ͘ϲ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϯϱ͘ϲ͛ Z<ʹ,ĂŶŐĞƌ͗ϮϬ͘Ϭϳ͛;EĂďŽƌƐϰ^Ϳ ³1%´/DWHUDO 0LQ,' ´ 0LQ,' ´ 0LQ,' ´ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϮͬ,ͲϰϬͬtĞůĚĞĚ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϭϬͲϯͬϰ͟ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ>ͲϴϬͬd ϵ͘ϳϵϰ ^ƵƌĨĂĐĞ ϰ͕ϱϲϮ͛ ϳͲϱͬϴΗ WƌŽĚƵĐƚŝŽŶ Ϯϵ͘ϳͬ>ͲϴϬͬdͲDK ϲ͘ϳϱϬ ^ƵƌĨĂĐĞ ϭϬ͕ϮϮϴΖ ϰ͟ >ŝŶĞƌE ϵ͘ϱͬ>ͲϴϬͬ/d ϯ͘ϰϮϯ ϲ͕ϬϵϬ͛ ϴ͕ϱϵϳ͛ ϰͲϭͬϮ͟ >ŝŶĞƌK ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϴϯϯ ϲ͕ϱϳϮ͛ ϴ͕ϱϲϱ͛ ϰͲϭͬϮ͟ >ŝŶĞƌK ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϴϯϯ ϲ͕ϳϮϴ͛ ϴ͕ϲϯϵ͛ dh/E'd/> ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬd^ ϯ͘ϵϱϴ ^ƵƌĨĂĐĞ ϲ͕Ϭϯϴ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ Ϯ͕ϬϲϮ͛ ϰͲϭͬϮ͟yWƌŽĨŝůĞ;ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞ/Ϳ Ϯ Ϯ͕ϰϳϵ͛ <'Ϯ'>Dϰ͘ϱϬϬ͟ǆϭ͟;ƵŵŵǇsĂůǀĞ^ĞƚϭϮͬϬϮͬϬϱͿ ϯ ϱ͕ϵϮϮ͛ ϰͲϭͬϮ͟y^ůŝĚŝŶŐ^ůĞĞǀĞ :ĞƚWƵŵƉ^ĞƚϬϮͬϭϯͬϮϮ;ϴďͿ ϰ ϱ͕ϵϰϲ͛ ϳͲϱͬϴ͟ǆϰͲϭͬϮ͟ĂŬĞƌWƌĞŵŝĞƌWĂĐŬĞƌ ϱ ϲ͕Ϭϭϰ͛ ϰͲϭͬϮ͟yWƌŽĨŝůĞ;ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞ/Ϳ ϲ ϲ͕Ϭϯϴ͛ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ ϳ ϲ͕Ϭϯϭ͛ E>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϴ ϲ͕ϬϰϮ͛ E>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϵ ϲ͕Ϭϱϴ͛ E>ĂƚĞƌĂů>DηϮ;>ĂƚĞƌĂůŶƚƌǇDŽĚƵůĞͿ ϭϬ ϲ͕Ϭϲϳ͛ E>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌĂďŽǀĞϳͲϱͬϴ͟tŝŶĚŽǁ ϭϭ ϲ͕Ϭϴϰ͛ E>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌďĞůŽǁϳͲϱͬϴ͟tŝŶĚŽǁ ϭϮ ϲ͕ϭϭϯ͛ E>ĂƚĞƌĂů^ǁĞůůWĂĐŬĞƌ ϭϯ ϲ͕Ϭϲϳ͛ E>ĂƚĞƌĂů/ƐŽůĂƚŝŽŶ^ůĞĞǀĞ;ϲ͕Ϭϲϳ͛Ͳϲ͕Ϭϴϲ͛Ϳ ϭϰ ϲ͕ϭϴϴ͛ K>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϭϱ ϲ͕ϭϵϵ͛ K>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϲ ϲ͕ϱϯϵ͛ K>ĂƚĞƌĂů>Dηϭ;>ĂƚĞƌĂůŶƚƌǇDŽĚƵůĞͿ ϭϳ ϲ͕ϱϰϵ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌĂďŽǀĞϳͲϱͬϴ͟tŝŶĚŽǁ ϭϴ ϲ͕ϱϲϲ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌďĞůŽǁϳͲϱͬϴ͟tŝŶĚŽǁ ϭϵ ϲ͕ϲϴϭ͛ K>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϮϬ ϲ͕ϲϵϮ͛ K>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ Ϯϭ ϲ͕ϳϬϮ͛ K>ĂƚĞƌĂůϳͲϱͬϴ͟ǆϱͲϭͬϮ͟,D>ŝŶĞƌ,ĂŶŐĞƌ ϮϮ ϴ͕ϱϱϮ͛ E>ĂƚĞƌĂůϰͲϭͬϮ͟WĂĐŬͲŽĨĨƵƐŚŝŶŐ Ϯϯ ϴ͕ϱϵϳ͛ E>ĂƚĞƌĂůϰͲϭͬϮ͟ƚŵŽĨ'ƵŝĚĞ^ŚŽĞ Ϯϰ ϴ͕ϱϮϬ͛ K>ĂƚĞƌĂůϰͲϭͬϮ͟WĂĐŬͲŽĨĨƵƐŚŝŶŐ Ϯϱ ϴ͕ϱϲϱ͛ K>ĂƚĞƌĂůϰͲϭͬϮ͟ƚŵŽĨ'ƵŝĚĞ^ŚŽĞ Ϯϲ ϴ͕ϱϵϱ͛ K>ĂƚĞƌĂůϰͲϭͬϮ͟WĂĐŬͲŽĨĨƵƐŚŝŶŐ Ϯϳ ϴ͕ϲϯϵ͛ K>ĂƚĞƌĂůϰͲϭͬϮ͟ƚŵŽĨ'ƵŝĚĞ^ŚŽĞ KWE,K>ͬDEdd/> ϮϬΗ ŵƚǁͬϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϰϮ͟,ŽůĞ ϭϬͲϯͬϰΗ ŵƚǁͬϲϱϯƐǆ^>ŝƚĞ͕ϮϱϳƐǆůĂƐƐ͞'͟ŝŶϭϯͲϭͬϮ͟,ŽůĞ ϳͲϱͬϴ͟ ŵƚǁͬϲϬϰƐǆůĂƐƐ͞'͟ŝŶϵͲϳͬϴ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϱϬϬ͛D DĂǆtĞůůďŽƌĞŶŐůĞсϵϯ͘ϬĚĞŐΛϳ͕Ϭϱϯ͛D ϲϬĚĞŐΛϲ͕Ϭϯϴ͛D t>>, tĞůůŚĞĂĚ &DdƵďŝŶŐ,ĂŶŐĞƌ͕ϭϭ͟ǆϰͲϭͬϮ͟dͲ//dŽƉΘŽƚƚŽŵ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϮϮϰͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚŽŵƉůĞƚĞĚďǇŽǇŽŶϭϰʹϭϬͬϭϯͬϮϬϬϰ ^WZĞƉůĂĐĞŵĞŶƚďǇEĂďŽƌƐϰ^ʹϭϮͬϬϵͬϮϬϬϰ ^WZĞƉůĂĐĞŵĞŶƚďǇEĂďŽƌƐϰ^ʹϮͬϮϬͬϮϬϬϱ ŽŶǀĞƌƚƚŽ:ĞƚWƵŵƉďǇEĂďŽƌƐϰ^ʹϭϭͬϮϰͬϮϬϬϱ >dZ>t/EKtd/> dŽƉŽĨ͞E͟tŝŶĚŽǁΛϲ͕ϬϳϮ͛D͖ŽƚƚŽŵΛϲ͕Ϭϴϰ͛D͖ŶŐůĞΛƚŽƉŽĨǁŝŶĚŽǁŝƐϲϭĚĞŐ dŽƉŽĨ͞K͟tŝŶĚŽǁΛϲ͕ϱϱϰ͛D͖ŽƚƚŽŵΛϲ͕ϱϲϲ͛D͖ŶŐůĞΛƚŽƉŽĨǁŝŶĚŽǁŝƐϳϱĚĞŐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϵͬϴͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh,Ͳϭϴ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϭͬϮϰͬϮϬϬϱ Wd͗ϮϬϰͲϭϳϰ Ϯϳ Ϯϴ Ϯϵ ϯϬ Ϯϱ Ϯϲ ůĞĂŶŽƵƚKůĂƚĞƌĂůƚŽ ϴ͕ϲϮϰ͛dDϭͬϰͬϮϬϭϴdс ϴ͕ϲϯϵ͛;DͿͬdсϰ͕ϮϮϲ͛;dsͿ ϮϬ´ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ ³2$´/DWHUDO Wdс ϴ͕ϲϯϵ͛;DͿ ͬWdсϰ͕ϮϮϲ͛;dsͿ ³2%$´/DWHUDO KƌŝŐ͘<ůĞǀ͗͘ϲϵ͘ϲ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϯϱ͘ϲ͛ Z<ʹ,ĂŶŐĞƌ͗ϮϬ͘Ϭϳ͛;EĂďŽƌƐϰ^Ϳ ³1%´/DWHUDO 0LQ,' ´ 0LQ,' ´ 0LQ,' ´ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϮͬ,ͲϰϬͬtĞůĚĞĚ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϭϬͲϯͬϰ͟ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ>ͲϴϬͬd ϵ͘ϳϵϰ ^ƵƌĨĂĐĞ ϰ͕ϱϲϮ͛ ϳͲϱͬϴΗ WƌŽĚƵĐƚŝŽŶ Ϯϵ͘ϳͬ>ͲϴϬͬdͲDK ϲ͘ϳϱϬ ^ƵƌĨĂĐĞ ϭϬ͕ϮϮϴΖ ϰ͟ >ŝŶĞƌE ϵ͘ϱͬ>ͲϴϬͬ/d ϯ͘ϰϮϯ ϲ͕ϬϵϬ͛ ϴ͕ϱϵϳ͛ ϰͲϭͬϮ͟ >ŝŶĞƌK ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϴϯϯ ϲ͕ϱϳϮ͛ ϴ͕ϱϲϱ͛ ϰͲϭͬϮ͟ >ŝŶĞƌK ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϴϯϯ ϲ͕ϳϮϴ͛ ϴ͕ϲϯϵ͛ dh/E'd/> ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬd^ ϯ͘ϵϱϴ ^ƵƌĨĂĐĞ ϲ͕Ϭϯϴ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ Ϯ͕ϬϲϮ͛ ϰͲϭͬϮ͟yWƌŽĨŝůĞ;ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞ/Ϳ Ϯ Ϯ͕ϰϳϵ͛ <'Ϯ'>Dϰ͘ϱϬϬ͟ǆϭ͟;ƵŵŵǇsĂůǀĞ^ĞƚϭϮͬϬϮͬϬϱͿ ϯ ϱ͕ϵϮϮ͛ ϰͲϭͬϮ͟y^ůŝĚŝŶŐ^ůĞĞǀĞ :ĞƚWƵŵƉ^ĞƚϬϮͬϭϯͬϮϮ;ϴďͿ ϰ ϱ͕ϵϰϲ͛ ϳͲϱͬϴ͟ǆϰͲϭͬϮ͟ĂŬĞƌWƌĞŵŝĞƌWĂĐŬĞƌ ϱ ϲ͕Ϭϭϰ͛ ϰͲϭͬϮ͟yWƌŽĨŝůĞ;ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞ/Ϳ ϲ ϲ͕Ϭϯϴ͛ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ ϳ ϲ͕Ϭϯϭ͛ E>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϴ ϲ͕ϬϰϮ͛ E>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϵ цϲ͕Ϭϱϱ͛ E>ĂƚĞƌĂů/ƐŽůĂƚŝŽŶ^ůĞĞǀĞʹŽƚƚŽŵΛцϲ͕ϬϴϮ͛ ϭϬ ϲ͕Ϭϱϴ͛ E>ĂƚĞƌĂů>DηϮ;>ĂƚĞƌĂůŶƚƌǇDŽĚƵůĞͿ ϭϭ ϲ͕Ϭϲϳ͛ E>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌĂďŽǀĞϳͲϱͬϴ͟tŝŶĚŽǁ ϭϮ цϲ͕Ϭϳϱ͛ ^ůŝĚŝŶŐ^ůĞĞǀĞ ϭϯ цϲ͕Ϭϴϭ͛ ϮͲϳͬϴ͛͟yEEŝƉƉůĞǁŝƚŚWyWůƵŐ ϭϰ ϲ͕Ϭϴϰ͛ E>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌďĞůŽǁϳͲϱͬϴ͟tŝŶĚŽǁ ϭϱ ϲ͕ϭϭϯ͛ E>ĂƚĞƌĂů^ǁĞůůWĂĐŬĞƌ ϭϲ ϲ͕ϭϴϴ͛ K>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϭϳ ϲ͕ϭϵϵ͛ K>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϴ ϲ͕ϱϯϵ͛ K>ĂƚĞƌĂů>Dηϭ;>ĂƚĞƌĂůŶƚƌǇDŽĚƵůĞͿ ϭϵ ϲ͕ϱϰϵ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌĂďŽǀĞϳͲϱͬϴ͟tŝŶĚŽǁ ϮϬ ϲ͕ϱϲϲ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌďĞůŽǁϳͲϱͬϴ͟tŝŶĚŽǁ Ϯϭ ϲ͕ϲϴϭ͛ K>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϮϮ ϲ͕ϲϵϮ͛ K>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ Ϯϯ ϲ͕ϳϬϮ͛ K>ĂƚĞƌĂůϳͲϱͬϴ͟ǆϱͲϭͬϮ͟,D>ŝŶĞƌ,ĂŶŐĞƌ Ϯϰ цϲ͕ϴϬϬ͛ /W Ϯϱ ϴ͕ϱϱϮ͛ E>ĂƚĞƌĂůϰͲϭͬϮ͟WĂĐŬͲŽĨĨƵƐŚŝŶŐ Ϯϲ ϴ͕ϱϵϳ͛ E>ĂƚĞƌĂůϰͲϭͬϮ͟ƚŵŽĨ'ƵŝĚĞ^ŚŽĞ Ϯϳ ϴ͕ϱϮϬ͛ K>ĂƚĞƌĂůϰͲϭͬϮ͟WĂĐŬͲŽĨĨƵƐŚŝŶŐ Ϯϴ ϴ͕ϱϲϱ͛ K>ĂƚĞƌĂůϰͲϭͬϮ͟ƚŵŽĨ'ƵŝĚĞ^ŚŽĞ Ϯϵ ϴ͕ϱϵϱ͛ K>ĂƚĞƌĂůϰͲϭͬϮ͟WĂĐŬͲŽĨĨƵƐŚŝŶŐ ϯϬ ϴ͕ϲϯϵ͛ K>ĂƚĞƌĂůϰͲϭͬϮ͟ƚŵŽĨ'ƵŝĚĞ^ŚŽĞ KWE,K>ͬDEdd/> ϮϬΗ ŵƚǁͬϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϰϮ͟,ŽůĞ ϭϬͲϯͬϰΗ ŵƚǁͬϲϱϯƐǆ^>ŝƚĞ͕ϮϱϳƐǆůĂƐƐ͞'͟ŝŶϭϯͲϭͬϮ͟,ŽůĞ ϳͲϱͬϴ͟ ŵƚǁͬϲϬϰƐǆůĂƐƐ͞'͟ŝŶϵͲϳͬϴ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϱϬϬ͛D DĂǆtĞůůďŽƌĞŶŐůĞсϵϯ͘ϬĚĞŐΛϳ͕Ϭϱϯ͛D ϲϬĚĞŐΛϲ͕Ϭϯϴ͛D t>>, tĞůůŚĞĂĚ &DdƵďŝŶŐ,ĂŶŐĞƌ͕ϭϭ͟ǆϰͲϭͬϮ͟dͲ//dŽƉΘŽƚƚŽŵ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϮϮϰͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚŽŵƉůĞƚĞĚďǇŽǇŽŶϭϰʹϭϬͬϭϯͬϮϬϬϰ ^WZĞƉůĂĐĞŵĞŶƚďǇEĂďŽƌƐϰ^ʹϭϮͬϬϵͬϮϬϬϰ ^WZĞƉůĂĐĞŵĞŶƚďǇEĂďŽƌƐϰ^ʹϮͬϮϬͬϮϬϬϱ ŽŶǀĞƌƚƚŽ:ĞƚWƵŵƉďǇEĂďŽƌƐϰ^ʹϭϭͬϮϰͬϮϬϬϱ >dZ>t/EKtd/> dŽƉŽĨ͞E͟tŝŶĚŽǁΛϲ͕ϬϳϮ͛D͖ŽƚƚŽŵΛϲ͕Ϭϴϰ͛D͖ŶŐůĞΛƚŽƉŽĨǁŝŶĚŽǁŝƐϲϭĚĞŐ dŽƉŽĨ͞K͟tŝŶĚŽǁΛϲ͕ϱϱϰ͛D͖ŽƚƚŽŵΛϲ͕ϱϲϲ͛D͖ŶŐůĞΛƚŽƉŽĨǁŝŶĚŽǁŝƐϳϱĚĞŐ /ƐŽůĂƚĞK tĞůů͗DWh,Ͳϭϴ ĂƚĞ͗ϵͬϴͬϮϮ ŽŝůĞĚdƵďŝŶŐKWƐ /ƐŽůĂƚĞK tĞůů͗DWh,Ͳϭϴ ĂƚĞ͗ϵͬϴͬϮϮ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽǇŵĞŶƚ /ƐŽůĂƚĞK tĞůů͗DWh,Ͳϭϴ ĂƚĞ͗ϵͬϴͬϮϮ ƋƵŝƉŵĞŶƚ>ĂǇŽƵƚŝĂŐƌĂŵ THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU H-18 Permit to Drill Number: 204-174 Sundry Number: 319-100 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a ogcc.a laska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, X9; 4 Daniel T. Seamount, Jr. Commissioner DATED this L day of March, 2019. 'p STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 MAR G 1 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑� * Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CT FCO ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 204-174 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23224-00-00 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 ❑ No ❑� MILNE PT UNIT H-18 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025906 MILNE POINT / SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,639' 4,226' 8,639' 4,226' 1,211 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 4,562' 10-3/4" 4,562' 3,199' 5210psi 2,480psi Production 6,910' 7-5/8" 6,910' 4,180' 6,890psi 4,790psi Liner'NB' 2,507' 4" 8,597' 4,220' 7,910psi 6,590psi Liner'OA' 1,993' 4-1/2" 8,565' 4,215' 8,430psi 7,500psi Liner'OB' 1,911' 4-1/2" 8,639' 4,226' 8,430psi 7,500psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4-1/2" 12.6# / L-80 / TDS 6,038' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 5,946MD/ 3,838TVD, 6,042MD/ 3,885TVD, 6,113MD/ 3,920TVD, 6,199MD/ 3,962TVD & 7-5/8" x 4-1/2" Premier, ZXP LTP, Swell, ZXP LTP & ZXP LTP and N/A 6,692MD/ 4,137TVD and N/A 12. Attachments: Proposal Summary U� Wellbore schematic 4 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑Q Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9 3`1,/0 %q OIL ❑✓ I WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. �1f STP Authorized Name: Chad Helgeson Contact Name: Stan Pothole Authorized Title: Operations Manager Contact Email: S Orhola f hilcor .Com I Contact Phone: 777-8412 Authorized Signature: Date: 3lhj COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I 0 D Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Farm Required: /LI .-Lf 0 Ll APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 2 G 1p ��((.. v ? s-11 Submit Fonn and ,.(Form 10-403 Revised 4/2017 Approved application is fa%d. 0©1� i1O11ifttr��e�Iate of approval. Attachments in Duplicate M w V R V 'v n �,jyB�s(r9 K Hilmr Alaska, LD Well Prognosis Well: MPU H-18 Date: 2/20/2019 Well Name: MPU H-18 API Number: 50-029-23224-00 Current Status: SI Oil Well [Jet Pump] Pad: Milne Point H -Pad Estimated Start Date: March 7th, 2019 Rig: Coil Tubing 0-7— .rReg. Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 204-174 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE Number: lob Type: Plugback Current Bottom Hole Pressure: 1,611 psi @ 4,000' TVD (Last BHP measured 6/30/2015) Maximum Expected BHP: 1,611 psi @ 4,000' TVD (No new perfs being added, EMW = 7.8 ppg) MPSP: 1,211 psi (Based on 0.10 psi/ftgas gradient) Brief Well Summary: MPU H-18 was drilled in 2004 using Doyon 141 and completed as a tri -lateral in the Schrader Bluff NB, OA and OB sands with an ESP completion. The original ESP was changed out in December 2004 using Nabors 4ES. An isolation sleeve was set across the NB sand and the ESP was changed out in February 2005 using Nabors 4ES. The well was converted to Jet Pump using Nabors 4ES in November 2005. A Coil Tubing cleanout of the OA and OB laterals was performed in February 2008. The well has had several jet pump change -outs since 2008. A cleanout in 2016 was successful and we were able to bring the well back online. The well was recently shut-in due to high solids production. A N2 cleanout in January 2018 resulted in the well being cleaned out to 8,624' MD. Subsequent production resulted in the well plugging off with solids again and the jet pump getting pulled in May 2018. Notes Regarding Wellbore Condition • Deviation at pump is 61.0°. • Deviation at upper window into the NB lateral is 61.00 . • Deviation at upper window into the OA lateral is 75.0". • Deviation at liner hanger into the OB lateral is 76.0°. • Casing last tested to 3,500 psi for 30 min down to 5,946' on 6/04/2016. • Tubing last tested to 4,000 psi for 30 min down to 6,014' on 11/24/2005. • Jet Pump currently pulled. Well offline due to high solids production. • Tubing Grade is L-80. Min ID is 3.813" in the 4-1/2" and 2.62" thru the Isolation Sleeve. • Last Fill Depth: 8,624' MD tagged on 1/04/2018. Objective: The purpose of this work is to pull the isolation sleeve across the Schrader NB, plugback the Schrader OA and OB with a Magna Range Bridge Plug, and reestablishing production from the Schrader NB. I ' Brief Procedure: Coiled Tubing Procedure: n fld .nom,,w Well Prognosis Well: MPU H-18 Date: 2/20/2019 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/ 8.5 ppg 1% KCI. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. ok- c. Record BOPE test results on 10-424 form. 3� MU 4" GS pulling tool BHA. p � X04 RIH w/ 2.00" coil and cleanout to isolation sleeve at+/- 6,067' MD POOH. Lay down isolation sleeve. 5. MU wash nozzle BHA. 6. RIH w/ 2.00" coil and cleanout to +/- 6,400' MD. POOH. 7. MU 2.75" OD Magna Range Bridge Plug BHA. S. RIH w/ 2.00" coil and set bridge plug at +/- 6,400' MD. POOH. 9. PU to 2,500' and freeze protect well. POOH w/ coil. 10. RD Coiled Tubing and ancillary equipment. 11. Turn well over to production. Wireline Procedure: 12. MIRU Eline. PT lubricator to 1,500 psi Hi 250 Low. 13. RIH and dump bail 15' of 15.8 ppg cement on top of the bridge plug at +/- 6,400' MD. POOH. G' a. 15' of cement= 10 gallons inside 4-1/2" 12.6# tubing. BHT = 80°F. ck 14. RD Eline. 15. Turn well over to production. 'IlUt SAND °N'J Wireline Procedure: 16. MIRU Slickline. PT lubricator to 1,500 psi Hi 250 Low. 17. RIH and tag cement at+/- 6,385' MD. POOH. 18. RIH and run static bottom hole survey at+/- 6,050' MD. Hold on bottom for 30 min. POOH. J` 19. RIH and shift sliding sleeve open at+/- 5,922' MD. POOH. 20. RIH and set jet pump in sliding sleeve profile at+/- 5,922' MD. POOH. 21. RD Slickline. 22. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. Coil BOPE Schematic n Hilwrn Alaska. LLC Orig. KB Elev.: 69.6/ Orig. GL Elev.: 35.6 RKB- Hanger: 20.07' (Nabors 4ES) MnID=3813" E 2 3 Mn ID=3813' -,ego OM 5 7 8 15Le413 Mn ID=2.620- 9 14 15 4 1. "NB' Lateral r�r 12 ,�-J 19tu-- 21 OB' L�eral TD= 8,639' (MD) /TD= 4,226'MO) PBTD= 8,639' (ND) / PB1D= 4,226 MO) Cleanout OB lateral to 8,624' CiM 1/4/2018 SCHEMATIC 23 25 27 Milne Point Unit Well: MPU H-18 Last Completed: 11/24/2005 PTD: 204-174 WELLHEAD Wellhead FMC Tubing Hanger, 11" x 4-1/2" TC -II Top & Bottom OPEN HOLE/ CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42" Hole 10-3/4" Cmt w/ 653 sx AS Lite, 257 sx Class "G" in 13-1/2" Hole 7-5/8" Cmt w/ 604 sx Class "G" in 9-7/8" Hole WELL INCLINATION DETAIL KOP @ 500' MD Max Wellbore Angle = 93.0 deg @ 7,053' MD 60 deg @ 6,038' MD CASING DETAIL Size Type Wt/Grade/Conn DriftlD Top Btm 20" Conductor 92/H-40/Welded N/A Surface 112' 30-3/4" Surface 45.5 / L-80/ BTC 9.794 Surface 4,562' 7-5/8" Production 29.7/L-80/BTC-MOD 6.750 Surface 10,228- 4- -Liner "A" 9.5/L-80/IBT 3.423 6,090' 8,597' 4-1/2" Liner "B" 12.L-80/IBT 6/ 3.833 6,572' 8,565' 4-1/2" Liner"C" 12.6/ L-80/IBT 3.833 6,728' 8,639' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TDS3.958 Surface 6,038' JEWELRY DETAIL No Depth Item 1 2,062' 4-1/2" X Profile (3.813" Packing Bore ID) 2 2,479' KBG2 GLM 4.500" x 1" (Dummy Valve Set 12/02/05) 3 5,922' 4-1/2" XD Sliding Sleeve (Jet Pump Pulled/Closed 5/16/18 4 5,946' 7-5/8" x 4-1/2" Baker Premier Packer 5 6,014' 4-1/2" X Profile (3.813" Packing Bore ID) 6 6,038' Wireline Entry Guide 7 6,031' NB Lateral Tie Back Sleeve 8 6,042' NB Lateral ZXP Liner Top Packer 9 6,058' NB Lateral LEM #2 (Lateral Entry Module) 10 6,067' NB Lateral Hook Wall, Hanger above 7-5/8" Window 11 6,084' NB Lateral Hook Wall, Hanger below 7-5/8" Window 12 6,113' NB Lateral Swell Packer 13 6,067' NB Lateral Isolation Sleeve (6,067'-6,0861) 14 6,188' OA Lateral Tie Back Sleeve 15 6,199' OA Lateral ZXP Liner Top Packer 16 6,539' OA Lateral LEM #1 (Lateral Entry Module) 17 6,549' OA Lateral Hook Wall, Hanger above 7-5/8" Window 18 6,566' OA Lateral Hook Wall, Hanger below 7-5/8" Window 19 6,681' 1 OB Lateral Tie Back Sleeve 20 6,692' OB Lateral ZXP Liner Top Packer 21 6,702' OB Lateral 7-5/8" x 5-1/2" HMC Liner Hanger 22 8,552' NB Lateral 4-1/2" Pack -off Bushing 23 $597' NB Lateral 4-1/2" Btm of Guide Shoe 24 8,520' OA Lateral 4-1/2" Pack -off Bushing 25 8,565' OA Lateral 4-1/2" Btm of Guide Shoe 26 8,595' OB Lateral 4-1/2" Pack -off Bushing 27 8,639' OB Lateral 4-1/2" Btm of Guide Shoe LATERAL WINDOW DETAIL Top of "NB" Window @ 6,072' MD; Bottom @ 6,084' MD; Angle (@ too of window is 61 dee GENERAL WELL INFO API: 50-029-23224-00-00 Drilled and Completed by Doyon 14 - 10/13/2004 ESP Replacement by Nabors 4ES -12/09/2004 ESP Replacement by Nabors 4ES - 2/20/2005 Convert to Jet Pump by Nabors 4ES -11/24/2005 Revised By: STP 2/20/2019 n HBcmm M.A.. Lt.0 Orig. KB Elev.: 69.6/ Orig. GL Elev.: 35.6 RKB-Hanger: 20.07' (Nabors 4ES) I za lu 2 ' 103/4" L, MnID=3.813' . 4 r e Mn ID &81T 5 .� 6 t 7 81 . 10 MnID=3.6W' 9 PI „A ,3 ,4 15, PROPOSED 22 l 23 ..,ytOA" Lala& 4 _.. , a 21 9 "GB Latera 7-5/8 Cleanout OB lateral to TD= 8,639'(IVD)/ P91 =4,26'M 8,624'CTM 1/4/2018 PBTD= 8,639' (ND) / PBTD=4,226'(TVD) 25 27 Milne Point Unit Well: MPU H-18 Last Completed: 11/24/2005 PTD: 204-174 WELLHEAD Wellhead FMC Tubing Hanger, 11" x 4-1/2" TC -II Top & Bottom OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42" Hole 30-3/4" Cmt w/ 653 sx AS Lite, 257 sx Class "G" in 13-1/2" Hole 7-5/8" Cmt w/604 sx Class "G" in 9-7/8" Hole WELL INCLINATION DETAIL KOP @ 500' MD Max Wellbore Angle = 93.0 deg 60 deg @ 6,038' MD CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 92/H-40/Welded N/A Surface 112' 103/4" Surface 45.5 / L-80 / BTC 9.794 Surface 4,562' 7-5/8" Production 29.7/L-80/BTC-MOD 6.750 Surface 10,228' 4" Liner "A" 9.5 / L-80 / IBT 3.423 6,090' 8,597' 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 6,572' 8,565' 4-1/2" Liner"C" 12.6/L-80/IBT 3.833 6,728' 8,639' TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TDS 1 3.958 1 Surface 6,038' JEWELRY DETAIL No Depth Item 1 2,062' 4-1/2" X Profile (3.813" Packing Bore ID) 2 2,479' KBG2 GLM 4.500" x 1" (Dummy Valve Set 12/02/05) 3 5,922' 4-1/2" XD Sliding Sleeve (let Pump Pulled/Closed 5/16/18) 4 5,946' 7-5/8" x 4-1/2" Baker Premier Packer 5 6,014' 4-1/2" X Profile (3.813" Packing Bore ID) 6 6,038' Wireline Entry Guide 7 6,031' NB Lateral Tie Back Sleeve 8 6,042' NB Lateral ZXP Liner Top Packer 9 6,058' NB Lateral LEM #2 (Lateral Entry Module) 10 6,067' NB Lateral Hook Wall, Hanger above 7-5/8" Window 11 6,084' NB Lateral Hook Wall, Hanger below 7-5/8" Window 12 6,113' NB Lateral Swell Packer 13 6,188' OA Lateral Tie Back Sleeve 14 6,199' OA Lateral ZXP Liner Top Packer 1s 6,400' Magna Range Bridge Plug capped w/ 1S' of cement 16 6,539' OA Lateral LEM #1 (Lateral Entry Module) 17 6,549' OA Lateral Hook Wall, Hanger above 7-5/8" Window 18 6,566' OA Lateral Hook Wall, Hanger below 7-5/8" Window 19 6,681' OB Lateral Tie Back Sleeve 20 6,692' OB Lateral ZXP Liner Top Packer 21 6,702' OR Lateral 7-5/8" x 5-1/2" HMC Liner Hanger 22 8,552' NB Lateral 4-1/2" Pack -off Bushing 23 8,597' NB Lateral 4-1/2" Btm of Guide Shoe 24 8,520' OA Lateral 4-1/2" Pack -off Bushing 25 8,565' OA Lateral 4-1/2" Btm of Guide Shoe 26 8,595' OB Lateral 4-1/2" Pack -off Bushing 27 8,639' OB Lateral 4-1/2" Btm of Guide Shoe LAI tKAL,N I N UUW Utl Window @ 6,072' MD; Bottom @ 6,084' MD; F Window @ 6,554' MD; Bottom @ 6,566' MD; l GENERAL WELL INFO API: 50-029-23224-00-00 Drilled and Completed by Doyon 14 - 10/13/2004 ESP Replacement by Nabors 4ES-12/09/2004 ESP Replacement by Nabors 4ES-2/20/2005 Convert to Jet Pump by Nabors 4ES -11/24/2005 window is 75 Revised By: STP 2/20/2019 COIL BOPE MILNE POINT UNIT MPU H-18 2/20/2019 MPU H-18 20X 10%X 7%X 4Y= Coil Tubing BOP Lubricator to injection head Crossover spool 4 1/1610M X 41/16 SM Valve, Swab, WKM-M, 4 1/16 5M FE �a��e,b1116 Valve, Upper Master, Baker, 4 1/16 SM FE, w/ Hydraulic Valve, Lower Master, WKM-M, 41/16 5M FE Tubing Adapter, 41/16 5M 1502 Union STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMISSS REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulatdj Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other StimulateD Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Wel❑ Re-enter Susp Well❑ Other:CT FCO w/N2 Q 2.Operator 4.Well Class Before Work: Name: Hilcorp Alaska LLC 5.Permit to Drill Number: Development Q Exploratory ❑ 204-174 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-23224-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 MILNE PT UNIT SB H-18 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 8,639 feet Plugs measured N/A feet RECEIVE true vertical 4,226 feet Junk measured N/A feet 5,946,6,042, 6,113,6,199& JAN 17 2018 Effective Depth measured 8,624 feet Packer measured 6,692 feet 3,838,3,885, AOGCC 3,920,,3,,962,& true vertical 4,224 feet true vertical 4,137 feet Casing Length Size MD TVD Burst Collapse Structural 112' 20" 112' 112' N/A N/A Surface 4,562' 10-3/4" 4,562' 3,199' 5,210psi 2,480psi Production 6,910' 7-5/8" 6,910' 4,180' 6,890psi 4,790psi Liner'NB' 2,507' 4" 8,597' 4,220' 7,910psi 6,590psi Liner'OA' 1,993' 4-1/2" 8,565' 4,215' 8,430psi 7,500psi Liner'OB' 1,911' 4-1/2" 8,639' 4,226' 8,430psi 7,500psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/TDS 6,038' 3,883' Premier,ZXP LTP,Swell,ZXP Packers and SSSV(type,measured and true vertical depth) LTP&ZXP LTP N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A ��(py Treatment descriptions including volumes used and final pressure: N/A SCANY�3� t v -'�!'•'' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 240 0 Subsequent to operation: 43 8 254 1,819 215 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development Q Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL 0 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: 317-532 Authorized Name: Bo York Contact Name: Stan PorholaSl Authorized Title: Operations Manager Contact Email: sporhola@hllcorp.corn Authorized Signature: Date: 1/11/2018 Contact Phone: 777-8412 1-orm ii u-404 Kevisea 4/2iyr auom¢vngmai uniy — #,(/// /`i?r t e RBDMS Uu-JA►! 18 • Milne Point Unit • Well: MPU H-18 SCHEMATIC Last Completed: 11/24/2005 >� Alaska,LLC PTD: 204-174 WELLHEAD Wellhead FMC Tubing Hanger,11"x 4-1/2"TC-II Top&Bottom Orig.KBEIev.:69.6'!Orig.GLEIev.:35.6' OPEN HOLE/CEMENT DETAIL RKB-Hanger:20.07'(Nabors 4ES) 20" Cmt w/260 sx of Arcticset I in 42"Hole .x lit 10-3/4" Cmt w/653 sx AS Lite,257 sx Class"G"in 13-1/2"Hole 1.0 i r'a 20'� €" 1 7-5/8" Cmt w/604 sx Class"G"in 9-7/8"Hole WELL INCLINATION DETAIL 4 KOP@500'MD it e Max Wellbore Angle=93.0 deg @ 7,053'MD cm) 1 60 deg @ 6,038'MD CASING DETAIL 0 2 Size Type Wt/Grade/Conn Drift ID Top Btm * 20" Conductor 92/H-40/Welded N/A Surface 112' 10-3/4" do 10-3/4" Surface 45.5/L-80/BTC 9.794 Surface 4,562' Vin lD=3.813' 7-5/8 Production 29.7/L-80/BTC-MOD 6.750 Surface 10,228' 4" Liner"A" 9.5/L-80/IBT 3.423 6,090' 8,597' 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 6,572' 8,565' 4-1/2" Liner"C" 12.6/L-80/IBT 3.833 6,728' 8,639' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TDS 3.958 Surface 6,038' JEWELRY DETAIL No Depth Item 1 2,062' 4-1/2"X Profile(3.813"Packing Bore ID) 2 2,479' KBG2 GLM 4.500"x 1"(Dummy Valve Set 12/02/05) 3 5,922' 4-1/2"XD Sliding Sleeve(8C Jet Pump 4 5,946' 7-5/8"x 4-1/2"Baker Premier Packer 5 6,014' 4-1/2"X Profile(3.813"Packing Bore ID) 6 6,038' Wireline Entry Guide 1)1)1)) 3 7 6,031' NB Lateral Tie Back Sleeve 0 io 14 8 6,042' NB Lateral ZXP Liner Top Packer 9 6,058' NB Lateral LEM#2(Lateral Entry Module) ip 10 6,067 NB Lateral Hook Wall,Hanger above 7-5/8"Window 04 t -r _'9 11 6,084' NB Lateral Hook Wall,Hanger below 7-5/8"Window 4 12 6,113' NB Lateral Swell Packer ' 13 6,067' NB Lateral Isolation Sleeve(6,067'-6,086') sa 14 6,188' OA Lateral Tie Back Sleeve M M 15 6,199' OA Lateral ZXP Liner Top Packer Mn ID=3.813" y 5 16 6,539' OA Lateral LEM#1(Lateral Entry Module) - 17 6,549' OA Lateral Hook Wall,Hanger above 7-5/8"Window a 6 k0, 18 6,566' OA Lateral Hook Wall,Hanger below 7-5/8"Window 7 19 6,681' OB Lateral Tie Back Sleeve 811 illig ,," 20 6,692' OB Lateral ZXP Liner Top Packer 13; ,4+,10 21 6,702' OB Lateral 7-5/8"x 5-1/2"HMC Liner Hanger 1 22 8,552' NB Lateral 4-1 Pack-off Bushing N1nID=2.620" �� 11 22 / 23 8,597' NB Lateral 4-1/2"Btm of Guide Shoe 9 f 24 8,520' OA Lateral4-1/2"Pack-off Bushing - NB' 2"Lateral 1 �' _� 25 8,565' OA Lateral 4-1/2"Btm of Guide Shoe r* 12 26 8,595' OB Lateral 4-1/2"Pack-off Bushing 14 27 8,639' OB Lateral 4-1/2"Btm of Guide Shoe 15 s p 17 LATERAL WINDOW DETAIL s 18 24 111 ffr:i Top of"NB"Window @ 6,072'MD;Bottom @ 6,084'MD;Angle @ top of window is 61 deg # = ' , ,• 4- Top of"OA"Window @ 6,554'MD;Bottom @ 6,566'MD;Angle @ top of window is 75 deg 16 OA„Lateral 25 GENERAL WELL INFO 19 a.' -- 0 API:50-029-23224-00-00 21 26 Drilled and Completed by Doyon 14-10/13/2004 4 ESP Replacement by Nabors 4ES-12/09/2004 7.5/8" OB"Laterd 27 ESP Replacement by Nabors 4ES-2/20/2005 Cleanout OB lateral to Convert to Jet Pump by Nabors 4ES-11/24/2005 TD=8,639'(MD)/TD=4,226'(TVD) 8,624'CTM 1/4/2018 PBTD=8,639'(MD)/PBTD=4,226'(TVD) Revised By:TDF 1/11/2018 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP H-18 CTU 50-029-23224-00-00 204-174 1/3/18 1/4/18 Daily Operations: ' m'o ` 1/3/2017-Wednesday Perform BOP TEST-250 psi low/3500 psi High - Full body and all rams. Draw down. IRV test. Complete form 10-424. MU BHA for FCO operation tomorrow. 1/4/2017-Thursday Arrive on location. PJSM. PU and stab injector with C/O BHA on to BOPE. PT low 300 psi/high 3,690 psi. Displace 60/40 from coil to LRS tanker with SLK 1%. Recovered 38 bbls. MIRU SLB N2 pumper. Open well to 688 psi SITP. IAP- 213 psi/ OAP- 1 psi. RIH with 2.0" OD internal dimple connector, 2.13" OD DBPV, 2 x stingers, 2.25" OD DJN. OAL= 10.6'. Open choke to take returns to tanks, bleed down gas cap. Well will flow to surface. At 3,500', online with N2 down coil at 1,500 scf/m for 20,000 scf and SLK 1%at .3 bpm.Then stabilize rate down the coil at 1.75 bpm fluid/500 scf/m N2. Continue RIH. Start FCO from 6,700' ctmd. WHP maintaining between 200- 300 psi. Good returns.Alternate pumping 30-40 bbls SLK 1%and 5 bbls N-Vis Gel. Encountered fill bridges at 6,940'- 6,981', 8,467', 8,508', 8,511',8,582', and final TAG depth of 8,624' Made 50'to 100' short trips after C/O of 50'to 400' bites depending on amt of fill encountered. Increased N2 rate to 700 scf/m at 8,500'. Pumped 22 bbl Gel sweep off bottom at 8,624'. When slugs of fill hit surface, WHP would drop to^'100 psi. Once clear, WHP increased back to 250-300 psi. POOH at 80 fpm chasing returns pumping 1.5 bpm fluid/700 scf/m N2. At 4,600',SD N2.Swap to 60/40 meth down coil. Meth at nozzle at 2,200'. FP well while POOH Tag up at surface. Close SV. BD and blow down surface lines to tanks. Remove fusible cap and close SSV. RDMO. 1/5/2017- Friday No activity to report. 1/6/2017-Saturday No activity to report. 1/7/2017-Sunday No activity to report. 1/8/2017- Monday No activity to report. OF Tit, THE STATE Alaska Oil and Gas ojALAsKA Conservation Commission 4triti - 333 West Seventh Avenue - GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 •A'ALAS*1.' Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations ManagerSCAED f! .zr NN ; t) . Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU H-18 Permit to Drill Number: 204-174 Sundry Number: 317-532 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, Hollis S. French Chair DATED this day of November, 2017. REE: 3 1 2017 , RECEIVED STATE OF ALASKA N O V 1 3 017 ALASKA OIL AND GAS CONSERVATION COMMISSION O y5 t l APPLICATION FOR SUNDRY APPROVALS A Cl 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well El Alter Casing ❑ Other: CT FCO w/N2 0' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC ' Exploratory ❑ Development Q• 204-174 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23224-00-00 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 ❑ No ❑., i MILNE PT UNIT H-18 - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 • MILNE POINT/SCHRADER BLUFF OIL a 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): 8,639' - 4,226'• 8,639' - - 4,226' 1,211 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 1,211' N/A N/A Surface 4,562' 10-3/4" 4,562' 3,199' 5,210psi 2,480psi Production 6,910' 7-5/8" 6,910' 4,180' 6,890psi 4,790psi Liner'NB' 2,507' 4" 8,597' 4,220' 7,910psi 6,590psi Liner'OA' 1,993' 4-1/2" 8,565' 4,215' 8,430psi 7,500psi Liner'OB' 1,911' 4-1/2" 8,639' 4,226' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 4-1/2" 12.6#/L-80/TDS 6,038' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 7-5/8"x 4-1/2"Premier,ZXP LTP,Swell,ZXP LTP&ZXP LTP and N/A 5,946MD/3,838TVD,6,042MD/3,885TVD,6,113MD/3,920TVD,6,199MD/3,962TVD& •6,692MD/4,137TVD and N/A 12.Attachments: Proposal Summary Q Wellbore schlatic 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: Commencing Operations: 11/16/2017 OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR El SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Stan Porhola Si-fl Authorized Title: Operations Manager Contact Email: sporholaahiIcorp.com Contact Phone: 777-8412 Authorized Signature: Date: 1 3 NA; 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3i1 — E 32 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Fk n ^+ Spacing Exception Required? Yes ❑ No 12r. Subsequent Form Required: Eu gar i' ` {° 2.617 APPROVED BY 11 116 I Approved by: COMMISSIONER THE COMMISSION Date: (k s l � /� / bmit Form and 1Y1 J\\4orm 10-403 Revised 4/21117 Approved application is 9cf J2GnJhJPJte of approval. 1- 1 ''Attachments in Duplicate • . Well Prognosis Well: MPU H-18 Ala4a Date: 11/09/2017 Well Name: MPU H-18 API Number: 50-029-23224-00 Current Status: SI Oil Well [Jet Pump] Pad: Milne Point H-Pad Estimated Start Date: November 16th, 2017 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 204-174 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number, , k.'.. Job Type: 1 Coil Foam Cleanout',,? Current Bottom Hole Pressure: 1,611 psi @ 4,000' TVD (Last BHP measured 6/30/2015) Maximum Expected BHP: 1,611 psi @ 4,000' TVD (No new perfs being added, EMW= 7.8 ppg) MPSP: 1,211 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU H-18 was drilled in 2004 using Doyon 141 and completed as a tri-lateral in the Schrader Bluff NB, OA and OB sands with an ESP completion. The original ESP was changed out in December 2004 using Nabors 4ES. An isolation sleeve was set across the NB sand and the ESP was changed out in February 2005 using Nabors 4ES.The well was converted to Jet Pump using Nabors 4ES in November 2005.A Coil Tubing cleanout of the OA and OB laterals was performed in February 2008. The well has had several jet pump change-outs since 2008. A cleanout in 2016 was successful and we were able to bring the well back online. The well was recently shut-in due to high solids roduction. Notes Regarding Wellbore Condition • Deviation at pump is 61.0°. • Deviation at upper window into the NB lateral is 61.0°. • Deviation at upper window into the OA lateral is 75.0°. • Deviation at liner hanger into the OB lateral is 76.0°. • Casing last tested to 3,500 psi for 30 min down to 5,946' on 6/04/2016. • Tubing last tested to 4,000 psi for 30 min down to 6,014' on 11/24/2005. • Jet Pump currently inactive. Well offline due to high solids production. • Tubing Grade is L-80. Min ID is 3.813" in the 4-1/2" and 2.62" thru the Isolation Sleeve. • Last Fill Depth: 8,551' MD tagged on 6/12/2016. Objective: The purpose of this work is to cleanout the lower lateral (OB), and run a new Jet Pump on slickline. t Brief Procedure: L.W ��.E—ec�c:_s� 5 :)7 C'% -. Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. ✓ a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. • Well Prognosis Well: MPU H-18 Ilileorp Alaska,LL+ Date:11/09/2017 b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. 3. RIH w/2.00" coil and cleanout to jet pump at+/-4,970' MD (if not pulled by slickline). POOH. 4. RIH w/2.00" coil and pull jet pump at+/-4,970' MD (if not pulled by slickline). POOH. a. Keep pumping down coil tubing and moving coil while bullheading thru the sliding sleeve. 5. RIH w/2.00" coil and shift sliding sleeve closed at+/-4,970' MD (if not closed by slickline). 6. Test backside to 3,500 psi for 5 min to confirm closed (if shifted closed by coil). POOH. 7. RIH w/2.00" coil w/2.00" to 2.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-8,639' MD. POOH. a. This multi-lateral is a Baker Hughes Level 3 Hook Hanger with Lateral Entry Modules (LEMs)that require a lateral entry diverter to provide selective entry of the laterals. No diverter is planned to be run (would require removal of the Isolation Sleeve) to selectively enter the OA lateral. b. Min ID is 2.620" (Isolation Sleeve across NB sand) in the LEM #2. c. Circulate out fill using 8.5 ppg 1% KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. d. Contingency: If unable to wash down with nozzle, RIH w/2.0"to 2.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/-8,639' MD. POOH. 8. RIH w/2.00" coil w/2.0"to 2.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-8,639' MD. POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. b. Contingency: If unable to wash down with nozzle, RIH w/2.0" to 2.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/-8,639' MD using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen. POOH. (See attached nitrogen procedure and diagram). 9. RIH and shift sliding sleeve open at+/-4,970' MD (if not to be opened by slickline). 10. Pump 8.5 ppg 1% KCI or 8.4 ppg power fluid to confirm open (if shifted open). POOH. 11. PU to 2,500' and freeze protect well. POOH w/coil. 12. RD Coiled Tubing and ancillary equipment. 13. Turn well over to production. Wireline Procedure: 14. MIRU Slickline. PT lubricator to 1,500 psi Hi 250 Low. 15. RIH and shift sliding sleeve open at+/- 5,922' MD. 16. RIH and set jet pump in sliding sleeve profile at+/-5,922' MD. POOH. 17. RD Slickline. 18. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen Flow Diagram • • • Milne Point Unit II Well: MPU H-18 SCHEMATIC Last Completed: 11/24/2005 Hamra Alaska.LU; PTD: 204 174 WELLHEAD Wellhead FMC Tubing Hanger,11"x 4-1/2"TC-II Top&Bottom Orig.KB Elev.:69.6'/Orig.GL Elev.:35.6' OPEN HOLE/CEMENT DETAIL RKB-Hanger:20.07'(Nabors 4ES) 20" Cmt w/260 sx of Arcticset I in 42"Hole ii 10-3/4" Cmt w/653 sx AS Lite,257 sx Class"G"in 13-1/2"Hole 2011 0 , 7-5/8" Cmt w/604 sx Class"G"in 9-7/8"Hole WELL INCLINATION DETAIL ...1 KOP@500'MD r c Max Wellbore Angle=93.0 deg @ 7,053'MD cg t t 1 60 deg @ 6,038'MD i. CASING DETAIL h 2 Size Type Wt/Grade/Conn Drift ID Top Btm 10-3/4" 20" Conductor 92/H-40/Welded N/A Surface 112' 10-3/4" Surface 45.5/L-80/BTC 9.794 Surface 4,562' 7-5/8" Production 29.7/L-80/BTC-MOD 6.750 Surface 10,228' 4" Liner"A" 9.5/L-80/IBT 3.423 6,090' 8,597' 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 6,572' 8,565' 4-1/2" Liner"C" 12.6/L-80/IBT 3.833 6,728' 8,639' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TDS 3.958 Surface 6,038' JEWELRY DETAIL No Depth Item 1 2,062' 4-1/2"X Profile(3.813"Packing Bore ID) 2 2,479' KBG2 GLM 4.500"x 1"(Dummy Valve Set 12/02/05) 3 5,922' 4-1/2"XD Sliding Sleeve(8C Jet Pump installed 6/18/16) C t, 4 5,946' 7-5/8"x 4-1/2"Baker Premier Packer t./ Y.'1 5 6,014' 4-1/2"X Profile(3.813"Packing Bore ID) Y 6 6,038' Wireline Entry Guide Q i is 3 ,t 7 6,031' NB Lateral Tie Back Sleeve 8 6,042' NB Lateral ZXP Liner Top Packer © 9 6,058' NB Lateral LEM#2(Lateral Entry Module) rt 10 6,067' NB Lateral Hook Wall,Hanger above 7-5/8"Window 11 .1;I' 4 11 6,084' NB Lateral Hook Wall,Hanger below 7-5/8"Window =f= - 12 6,113' NB Lateral Swell Packer 13 6,067' NB Lateral Isolation Sleeve(6,067'-6,086') 14 6,188' OA Lateral Tie Back Sleeve ° 15 6,199' OA Lateral ZXP Liner Top Packer Mn ID=3.813" - , -► 16 6,539' OA Lateral LEM#1(Lateral Entry Module) 17 6,549' OA Lateral Hook Wall,Hanger above 7-5/8"Window 18 6,566' OA Lateral Hook Wall,Hanger below 7-5/8"Window 7 19 6,681' OB Lateral Tie Back Sleeve 8 "�� IIIIIIIr 1 20 6,692' OB Lateral ZXP Liner Top Packer 13 1. F. 10 21 6,702' OB Lateral 7-5/8"x 5-1/2"HMC Liner Hanger Mn I0=2.620 "- ,:' 11 22 , ' a4-1/ " ;' .a; 2322 88,597552' NN LL 4-1/22"Btm ofPack-off GuidBushingoe e Sh 9 N6 Lateral 23 24 8,520' OA Lateral 4-1/2"Pack-off Bushing .w_., 25 8,565' OA Lateral 4-1/2"Btm of Guide Shoe 12 26 8,595' OB Lateral 4-1/2"Pack-off Bushing 1a � , ° 27 8,639' OB Lateral 4-1/2"Btm of Guide Shoe 15 m N17 LATERAL WINDOW DETAIL 18 24 Top of"NB"Window @ 6,072'MD;Bottom @ 6,084'MD;Angle @ top of window is 61 deg -a+�•� 4. Top of"OA"Window @ 6,554'MD;Bottom @ 6,566'MD;Angle @ top of window is 75 deg 16 `CA"Lateral 25 w;„, GENERAL WELL INFO API:50-029-23224-00-00 19i 2126 Drilled and Completed by Doyon 14-10/13/2004 Ail ESP Replacement by Nabors 4ES-12/09/2004 eral 27 ESP Replacement by Nabors 4ES-2/20/2005 7-5/8" ' Cleanout OB lateral to Convert to Jet Pump by Nabors 4ES-11/24/2005 TD=8,639'(MD)/TD=4,226'(TVD) g,549'CTM 6/13/2016 PBTD=8,639'(MD)/PBTD=4,226'(TVD) Downhole Revised:6/18/2016 Revised By:TDF 11/7/2017 • . COIL ROPE MILNE POINT UNIT MPU H-18 iI liiirp A Tzpika.LI.0 11/09/2017 MPU H-18 20 X 10% X 7% X4' Coil Tubing BOP ILubricator to injection head N i t.1Ilk IMM 2.00"Single Stripper NEM01 II Blind/ShearV 1/1610 -Blind/Shear I,I,'•� NM• It $ : Blind/ShearI,I )., 1• 1* Slip .® Mil,'• `'1111 Pipe : =I Pipe 1114 -- gni 111111861 MIEN ml Crossover spool 4 1/16 10M X 4 1/16 5M OM 1l1 1111 1;11 '. Pump-In Sub j 4 1/16 5M III : ° 0. \ (- 41502 Union Iot ma- i G - IIMMINI Manual Gate Manual Gate Valve,Swab,WKM-M, .. .. 2 1/8 5M 2 1/8 SM 4 1/16 5M FE _° ,,ALO , L � II �a\�e'K.0- I : MIValve,Upper Master,Baker, 4 1/16 5M FE,w/Hydraulic O IIIIIIIMIIM MI WI I•1 Valve,Lower Master,WKM-M, Pi o 4 1/16 5M FE ` 1111111Mili Tubing Adapter,4 1/16 5M • • STANDARD WELL PROCEDURE Hi!carp Alaska,LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 - .• • • MI < I § § k4 MN d d'.%. •"8„ § t; .>"'' •c5 c-4 c.-.5 -78 2- •—, 1 i 111 • › 0 — .•:::-.. .-, >' _ E- .: .. E —' ce 2 ce d ce z w ti ,„„ c, L. L. o ...., .. •-. : 4. c. 40 ,jo 0 > < Ouo °Z$ 2 0 , - a iiiXZZO E gi a_ : ••• • • 1_6-- 2 ....1 ••.. 'il > bp D 1... M ;.... 0 0 a 0 . a , .i F E.5 _. a E D D o q n ,.., ,.. m r„, 4., =LT. 0 co co 2 li F411-... ce • -.. (.7 - 2 •°2 10 0 ,9 5 =-S,' •or cr . riiir Nal : C.,.)c.,t.... 41 t° z 0 D 0 ...1 2 5 II i L) ! 0 .0 u mu i pm A „ ' ..- Imismia.Z- Sow —144—>- ,-. A , II - 0 I c .111... 17 1 ,—; ...7 —: -- i IC 0 NNIIIIS -r.- ; ; 1 0 -, I- 70 gala it- -------,, II ..., .a. 111.. el e • 411 t ' —• .41 1111 1111 11111 1h1 .0o c:7: .-..._••••••• gaga i t t Ci a w -0 119 •,5. I' re a 0 ;'• ,.- t.' co 1-- ,:o 0 c, cr .., Q. V 1 Z-C>-- ce w .., .., 1—• 2 3 0 .4 .- vl o 1- 2 I- I _. co 0 m R 0 o. o D w co co 0 0 •or 0-f, E. i z STATE OF ALASKA ' ALA OIL AND GAS CONSERVATION COMMINN REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon L1 Plug Perforations LI Fracture Stimulate LJ Pull Tubing L Operations shutdown L] Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill 0 erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CTU FCO Q 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory ❑ 204-174 3.Address: Stratigraphic El Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-23224-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED ADL0025906 MILNE PT UNIT SB H-18 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): SEP 20 2015 N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: AOGCC Total Depth measured 8,639 feet Plugs measured N/A feet true vertical 4,226 feet Junk measured N/A feet 5,946,6,042, 6,113,6,199& Effective Depth measured 8,639 feet Packer measured 6,692 feet 3,838,3,885, 3,920,3,962,& true vertical 4,226 feet true vertical 4,137 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 1,211' N/A N/A Surface 4,562' 10-3/4" 4,562' 3,199' 5,210psi 2,480psi Production 6,910' 7-5/8" 6,910' 4,180' 6,890psi 4,790psi Liner 8,639' 4-1/2" 8,639' 4,226' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/TDS 6,038' 3,883' 7-5/8"x 4-1/2" Premier,ZXP LTP,Swell,ZXP Packers and SSSV(type,measured and true vertical depth) LTP&ZXP LTP N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A tt ,, r Intervals treated(measured): N/A �� t '— " p`L.,,t 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: 113 42 490 2,535 207 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-277 Contact Stan Porhola Email sporhoIaehilcorD.con�v� Printed Name Bo York Title Operations Engineer Signature '+ Phone 777-8345 Date 9/16/2016 Form 10.A0456' ed 5r9n15 Si.Ibmit Original Only de(9%A 24 /0"/0 16 RBDMS (A" SEP-1 2 2016 • • Milne Point Unit Well: MPU H-18 SCHEMATIC Last Completed: 11/24/2005 HiWora Alaska,LL(: PTD: 204-174 CASING DETAIL Size Type WV Grade/Conn Drift ID Top Btm Orig.KB Elev.:69.6'/Orig.GL Elev.:35.6' 20" Conductor 92/H-40/Welded N/A Surface 112' RKB-Hanger:20.07'(Nabors 4ES) 10-3/4" Surface 45.5/L-80/BTC 9.794 Surface 4,562' 7-5/8" Production 29.7/L-80/BTC-MOD 6.750 Surface 10,228' 4" Liner"A" 9.5/L-80/IBT 3.423 6,090' 8,597' 20 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 6,572' 8,565' 4-1/2" Liner"C" 12.6/L-80/IBT 3.833 6,728' 8,639' TUBING DETAIL 1 4-1/2" Tubing 12.6/L-80/TDS 3.958 Surface 6,038' "14 JEWELRY DETAIL 16 2 No Depth Item 10-3/4" 1 2,062' 4-1/2"X Profile(3.813"Packing Bore ID) Mn ID=3.813" 2 2,479' KBG2 GLM 4.500"x 1"(Dummy Valve Set 12/02/05) 3 5,922' 4-1/2"XD Sliding Sleeve(8C Jet Pump installed 6/18/16) 4 5,946' 7-5/8"x 4-1/2"Baker Premier Packer 5 6,014' 4-1/2"X Profile(3.813"Packing Bore ID) 6 6,038' Wireline Entry Guide 7 6,031' NB Lateral Tie Back Sleeve 8 6,042' NB Lateral ZXP Liner Top Packer 9 6,058' NB Lateral LEM#2(Lateral Entry Module) 10 6,067' NB Lateral Hook Wall,Hanger above 7-5/8"Window 11 6,084' NB Lateral Hook Wall,Hanger below 7-5/8"Window 12 6,113' NB Lateral Swell Packer 13 6,067' NB Lateral Isolation Sleeve(6,067'-6,086') 14 6,188' OA Lateral Tie Back Sleeve 15 6,199' OA Lateral ZXP Liner Top Packer 16 6539' OA Lateral LEM#1(Lateral Entry Module) 17 6,549' OA Lateral Hook Wall,Hanger above 7-5/8"Window 18 6,566' OA Lateral Hook Wall,Hanger below 7-5/8"Window 0`, 3 19 6,681' OB Lateral Tie Back Sleeve 20 6,692' OB Lateral ZXP Liner Top Packer 21 6,702' OB Lateral 7-5/8"x 5-1/2"HMC Liner Hanger 22 8,552' NB Lateral 4-1/2"Pack-off Bushing Laimuit- 23 8,597' NB Lateral 4-1/2"Btm of Guide Shoe 24 8,520' OA Lateral 4-1/2"Pack-off Bushing 25 8,565' OA Lateral 4-1/2"Btm of Guide Shoe 26 8,595' OB Lateral 4-1/2"Pack-off Bushing Mn ID=3813' ' 5 27 8,639' OB Lateral 4-1/2"Btm of Guide Shoe LATERAL WINDOW DETAIL 1 6 Top of"NB"Window @ 6,072'MD;Bottom @ 6,084'MD;Angle @ top of window is 61 deg Top of"OA"Window @ 6,554'MD;Bottom @ 6,566'MD;Angle @ top of window is 75 deg 13^r-ro '10 t .I WELL INCLINATION DETAIL Mn ID=2620 . 11 22 KOP @ 500'MD Max Wellbore Angle=93.0 deg @ 7,053'MD NB'Lateral 23 4 60 deg @ 6,038'MD 12 14 � OPEN HOLE/CEMENT DETAIL 15 p, M.°"g,17 20" Cmt w/260 sx of Arcticset I in 42"Hole 31<= 30-3/4" Cmt w/653 sx AS Lite,257 sx Class"G"in 13-1/2"Hole ' 18 2� 7-5/8" Cmt w/604 sx Class"G"in 9-7/8"Hole 16 "0,4 Lateral 25 WELLHEAD 19* ' Wellhead MMC Tubing Hanger,11"x 4-1/2"TC-II Top&Bottom 21 26 GENERAL WELL INFO OB Latera 27 API:50-029-23224-00-00 7-5/8" Drilled and Completed by Doyon 14-10/13/2004 TD=8,639'(MD)/TD=4,226'(TVD) Cleanout OB lateral to ESP Replacement by Nabors 4E5-12/09/2004 PBTD=8,639'(MD)/PBTD=4,226'(TVD) 8,549'CTM 6/13/2016 ESP Replacement by Nabors 4ES-2/20/2005 Downhole Revised:6/18/2016 Convert to Jet Pump by Nabors 4ES-11/24/2005 Revised By:STP 9/16/2016 • S Hilcorp Alaska, LLC Weekly Operations erations Summar Y Well Name Rig API Number Well Permit Number Start Date End Date MP H-18 Coil 50-029-23224-00-00 204-174 6/11/16 6/14/16 Daily Operations: 6/8/2016-Wednesday No activity to report. 6/9/2016-Thursday No activity to report. 6/10/2016-Friday No activity to report. 6/11/2016-Saturday Hold safety meeting. Discuss Demobe and rig down. Demobe equipment and upright anks from F-29. Hold safety meeting discuss RU. RU Halliburton CTU with 1.75" CT. Spot return tank, choke trailer, build containment for uprights. Spot upright tanks. Fill with fluids. Pick injector head and stab on well.Start BOPE test.Test all rams and valves to 250/3,500 psi. Draw down test complete. 24 hr bope test witness notification sent 6/10/16 @ 16:36. Witness waived by Charles Scheve on 6/10/16 2 17:11. BOPE test complete. Blow down stack. Pop off and Rig back CTU. Shut down for night. 6/12/2016-Sunday Hold safety meeting. Discuss JSA and job procedure/plan forward with crews. Fire equipment. Pick injector head. Make up 10' lubricator. Install BHA. CC, DFCV, DISCO, x2 Weight bars,jet swirl nozzle. Stab on well. Fluid pack. Pressure test 250/3,500 psi. Bleed down. Master swab open. RIH. 5,500' RIH wt 1,400lbs. Pick up weight 5,800lbs.Wt Check 6,500' 13.3k. Start stacking weight at 6,550'. Pick up and come online with pump at 1.5 bbls/min.Wash throught tag at 6,550'. Send gel sweeps. 5bbls gel 10bbls of 1% KCI. RIH WT @ 6,550' 3,100Ibs. 7,000' make wiper trip up to 6,500'. Rlh 7,650' WT chk 14.8k. Returns have small amount of sand. Circulating 1:1 at 1.6 bbls/min and 4,200psi. 7,500' pick up and wiper trip to 7,000' gel at nozzle.TIH, 8,000' pick up clean at 14.7k. TIH 8,583' Light tag. Washing off.Weight coming back. Pick up 100'. TIH,tagg PBTRD 8,625'. Pick up and re-tag to confirm.,Start 15 bbl gel sweep and circulate bottoms up at 8,625'. Call out HES N2 unit. PU and chase sweep OOH. Park CT at 6,000'. Bottoms up complete. N2 on location. Rigging up. PT N2 lines to 250/4,500 psi. Online with N2 down CT to draw down formation. 1,500 scf/min. Returns at tank.Slowly RIH and park CT at 6,156'. Move pipe up and down while lifting well with N2/ First N2 bubble hit surface.Walk down N2 rate to 1,000 scf/min. Continue to lift. Start POOH with Coil while lifting wellbore. Shut down N2 pump at 4,500'. Continue OOH,Tagged up at surface 16:30. Bleed down CT. Master swab closed 23.5 turns. SSV valve dumped. 6/13/2016- Monday • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP H-18 Coil 50-029-23224-00-00 204-174 6/11/16 6/14/16 Daily Operations:, Hold safety meeting. Discuss JSA and Job procedures. Fire equipment. Pick injector head. Make up 10' lubricator and BHA. CC, DFCV, DISCO, 2x straight Bar, Pulsonics Nozzle.ALL BHA OD 1.75"Total lenght 8.6'. Stab on well. Pressure test stack 250/3,500psi. Bleed down. Open well. Fuseable cap installed on SSV. Master swab opened 23.5 turns. 0 PSI WHP.Slight tag at 6,659'. PU. Start Circulating at 1.1 bbls/min. Good returns to surface. 1:1. 6,700' WT check 14.2k.TIH, 7,000' WT Check 15.1k. 7,500' Stack weight, 7,700' bobble. Could be sand bridges. Wiper trip back to 7,000'. Continue IH, Returns look heavy oil.Trace of sand. 7,000' WT check, 15.1k.TIH, Stack 3k donw at 7,500'weight broke back. Continue in hole. Stacking weight at 7,700' and breaking back. Looks like fill. Perform 100'wiper trip. Continue ciruclating at 1.5 bbls/min getting 1:1 returns at surface. 7,721'tag fill and wash off. 7,782' Stack 4k down. Pick up clean. Rlh and wash through 7,721'. Continue in hole Pick up at 8,050' 15.7k clean.TIH to 8,500'. RIH stack weight at 8,551' Hard tag. Not washing off. PU 100' and attempt to make hole, no luck, could be PBTD. Previous day tagged at 8,625'. No indication counter was slipping on either day. 10 bbl gel sweep and pump bottoms up of 132bbls. Pu to 6,000', waiting on fluids.Vac truck on location with 290 bbls of 1% KCL. Wash down from 5,899'to PBTD. Washing slotted liner.Tagged at 8,549'. 9 bbl gel pill circulated. Chase out of hole at 30 ft/min washing slotted liner. 6,000' increase POOH speed to 80 ft/min AV 120 ft/min. Wash all the way OOH. N2 cooling down. Online N2 at 1,500 scf/min. Close master swab valve. Blow down coil and surface lines to OT tank. Reel bleed down. Pop off well and start rigging down HES CTU. 526 bbls pumped for cleanout. 300 gallons of N2 used for blow down. Pump in sub,flowback iron to choke and tank left rigged up. Night cap installed on pump in sub. SSV closed. 6/14/2016-Tuesday No activity to report. • ti0F �� • • h \��y��sTHE STATE Alaska Oil and Gas • r� v OfA LAsKA Conservation Commission f i}t_= 333 West Seventh Avenue '' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF � . Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC ;k+ 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB H-18 Permit to Drill Number: 204-174 Sundry Number: 316-277 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, Cathy P Foerster �. _ Chair DATED this day of May, 2016. RBDMS t,'- MAY 2 6 2016 • RECEIVED • STATE OF ALASKA MAY 1 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION riZS!/6 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CT Fill Clean-out(Q' 2.Operator Name: 4.Current Well Class: 5. Permit to Dnll Number:,, V. -;- Hilcorp Alaska, LLC' Exploratory ❑ Development Q • 204-174 t 3.Address. Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK,99503 50-029-23224-00-00 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 ❑ No 0 MILNE PT UNIT SB H-18 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 • MILNE POINT/SCHRADER BLUFF OIL . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,639 , 4,226 - 8,639 • 4,226 1,211 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 4,562' 10-3/4" 4,562' 3,199' 5,210 psi 2,480 psi Production 6,910' 7-5/8" 6,910' 4,180' 6,890 psi 4,790 psi Liner 8,639' 4-1/2" 8,639' 4,226' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6/L-80/TC-II 6,038' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker 7-5/8"Premier and N/A 5,946(MD)/3,838(TVD)and N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 2 Exploratory ❑ Stratigraphic ❑ Development 2 Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 6/2/2016 Commencing Operations: OIL R WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved ''...-11' herein will not be deviated from withoutprior written approval. pp Contact Stan Porhola Email sporhola@hilcorp.com Printed Name Bo York Title Operations Manager Signature �/:"/.,"*./ - (lD yv^t Phone 907-777-8345 Date 5113/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. c.,--(- 3\L-e - 2-7-7 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ CILocation Clearance Other: 1(-- 3500 p5. f/ Cr"----;fr- C C'- Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: `0 — 1 a`( RBDMS (--k-/ MAY 2 6 2016 APPROVED BY Approved by: f 4.4._444....._64fiecti COMMISSIONER i13 -.SI/4 COMMISSION Date:�LS-/ o .5.25‘4,Z: t' �f4 i1 g 1 (44'4 6 OfitG Submit Form and Form 10-403 Revised 11/2015 I o s alid for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MPU H-18 Hilcorp Alaska,LL Date: 5/02/2016 Well Name: MPU H-18 API Number: 50-029-23224-00 Current Status: SI Oil Well [Jet Pump] Pad: Milne Point H-Pad Estimated Start Date: June 2"d, 2016 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 204-174 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,611 psi @ 4,000' TVD (Last BHP measured 6/30/2015) Maximum Expected BHP: 1,611 psi @ 4,000' TVD (No new perfs being added, EMW= 7.8 ppg) MPSP: 1,211 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU H-18 was drilled in 2004 using Doyon 141 and completed as a tri-lateral in the Schrader Bluff NB, OA and OB sands with an ESP completion. The original ESP was changed out in December 2004 using Nabors 4ES. An isolation sleeve was set across the NB sand and the ESP was changed out in February 2005 using Nabors 4ES.The well was converted to Jet Pump using Nabors 4ES in November 2005. A Coil Tubing cleanout of the OA and OB laterals was performed in February 2008. The well has had several jet pump change-outs since 2008.The well has been offline due to high solids production. Notes Regarding Wellbore Condition • Deviation at pump is 61.0°. • Deviation at upper window into the NB lateral is 61.0°. • Deviation at upper window into the OA lateral is 75.0°. • Deviation at liner hanger into the OB lateral is 76.0°. • Casing last tested to 3,500 psi for 30 min down to 5,946' on 11/24/2005. • Tubing last tested to 4,000 psi for 30 min down to 6,014' on 11/24/2005. • Jet Pump currently inactive. Well offline due to high solids production. • Tubing Grade is L-80. Min ID is 3.813" in the 4-1/2" and 2.62" thru the Isolation Sleeve. • Last Fill Depth: 6,062' MD tagged on 9/20/2014. Objective: The purpose of this work is to cleanout the middle and lower laterals (OA/OB), and run a new Jet Pump on slickline. Brief Procedure: Pre-Coil Procedure: 1. MIRU Pump Truck. PT lines to 4,000 psi. 2. Pressure test 7-5/8" x 4-1/2" annulus to 3,500 psi for 30 min (sliding sleeve currently closed). 3. RD Pump Truck. • if • 410 Well Prognosis Well: MPU H-18 lliI(orp,Alaska,LL' Date:5/02/2016 Coiled Tubing Procedure: 4. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg seawater. 5. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. Notify AOGCC 24 hours prior to testing BOPE. c. Submit 10-424 form within 5 days. 6. RIH w/ 1.75" coil w/2.25" to 2.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-8,639' MD (in OB lateral). POOH. a. This multi-lateral is a Baker Hughes Level 2 Hook Hanger with Lateral Entry Modules (LEM) that require a lateral entry diverter to provide selective entry of the laterals. No diverter is planned to be run (would require removal of the Isolation Sleeve) to selectively enter the OA lateral. b. Min ID is 2.620" (Isolation Sleeve across NB sand) in the LEM #2. c. Circulate out fill using 8.5 ppg seawater w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. � - Contingency: If unable to circulate fluid to surface without significant losses (<50% returns or little to no solids circulated to surface). Circulate out fill using 8.5 ppg seawater w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). 7. Contingency: If unable to cleanout fill w/wash nozzle, RIH w/ 1.75" coil w/2.25" to 2.50" max OD motor and mill and extended reach cleanout BHA and cleanout to PBTD at+/-8,639' MD. POOH. a. Circulate out fill using 8.5 ppg seawater w/friction reducer. Pump 5-10 bbl Gel Sweeps to help to remove solids from the liner. b. Contingency: If unable to circulate fluid to surface without significant losses (<50% returns or little to no solids circulated to surface). Circulate out fill using 8.5 ppg seawater w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). 8. PU to 2,500' and freeze protect well. POOH w/coil. 9. RD Coiled Tubing and ancillary equipment. 10. Turn well over to production. Wireline Procedure: 11. MIRU Slickline. PT lubricator to 1,500 psi Hi 250 Low. 12. RIH and shift sliding sleeve open at+/-5,922' MD. 13. RIH and set jet pump in sliding sleeve profile at+/- 5,922' MD. POOH. 14. RD Slickline. 15. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil BOPE Schematic 4. Nitrogen Operations Procedure 5. Nitrogen Flow Diagram • • ne WelMill: MPU H-18Unit II SCHEMATIC Last Completed:Point 11/24/2005 111 ileum Alaska,LLC PTD: 204 174 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm Orig.KB Elev.:69.6'/Orig.GL Elev.:35.6' 20" Conductor 92/H-40/Welded N/A Surf 112' RKB-Hanger:20.07'(Nabors 4ES) 10-3/4" Surface 45.5/L-80/BTC 9.794 Surf 4,562' „ a 7-5/8" Production 29.7/L-80/BTC-MOD 6.750 Surface 10,228' 2D V 4 4" Liner"A" 9.5/L-80/IBT 3.423 6,090' 8,597' 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 6,572' 8,565' r" "„1 Z 4-1/2" Liner"C" 12.6/L-80/IBT 3.833 6,728' 8,639' 54- TUBING DETAIL p 1 fi 4-1/2" Tubing 12.6/L-80/TDS 3.958 Surf 6,038' y. 0 p JEWELRY DETAIL IIII 2 No Depth Item 10-3/4" A 4 1 2,062' 4-1/2"X Profile(3.813"Packing Bore ID) 2 2,479' KBG2 GLM 4.500"x 1"(Dummy Valve Set 12/02/05) 3 5,922' 4-1/2"XD Sliding Sleeve(Jet Pump removed) 4 5,946' 7-5/8"x 4-1/2"Baker Premier Packer 5 6,014' 4-1/2"X Profile(3.813"Packing Bore ID) 6 6,038' Wireline Entry Guide 7 6,031' NB Lateral Tie Back Sleeve 8 6,042' NB Lateral ZXP Liner Top Packer 9 6,058' NB Lateral LEM#2(Lateral Entry Module) 10 6,067' NB Lateral Hook Wall,Hanger above 7-5/8"Window 11 6,084' NB Lateral Hook Wall,Hanger below 7-5/8"Window 12 6,113' NB Lateral Swell Packer 13 6,067' NB Lateral Isolation Sleeve(6,067'-6,086') 14 6,188' OA Lateral Tie Back Sleeve 15 6,199' OA Lateral ZXP Liner Top Packer �� 16 6,539' OA Lateral LEM#1(Lateral Entry Module) C P't' 17 6,549' OA Lateral Hook Wall,Hanger above 7-5/8"Window O_�, 18 6,566' OA Lateral Hook Wall,Hanger below 7-5/8"Window I t I 3 ,{- 19 6,681' OB Lateral Tie Back Sleeve to 20 6,692' OB Lateral ZXP Liner Top Packer 21 6,702' OB Lateral 7-5/8"x 5-1/2"HMC Liner Hanger 22 8,552' NB Lateral 4-1/2"Pack-off Bushing IMIA-1' `1 23 8,597' NB Lateral 4-1/2"Btm of Guide Shoe .'. 24 8,520' OA Lateral 4-1/2"Pack-off Bushing 25 8,565' OA Lateral 4-1/2"Btm of Guide Shoe z# 26 8,595' OB Lateral 4-1/2"Pack-off Bushing 27 8,639' OB Lateral 4-1/2"Btm of Guide Shoe " f. Fill Depth LATERAL WINDOW DETAIL @ 6,062' + 1 1 !' Top of"NB"Window @ 6,072'MD;Bottom @ 6,084'MD;Angle @ top of window is 61 deg 7 ' Top of"OA"Window @ 6,554'MD;Bottom @ 6,566'MD;Angle @ top of window is 75 deg 13 z �.ti '10 �� _ WELL INCLINATION DETAIL 4. ,:.4 11 22 KOP @ 500'MD "NB Lateral 23 Max Wellbore Angle=93.0 deg @ 7,053'MD ,, rThaw . 60 deg @ 6,038'MD � 12 14; , ' OPEN HOLE/CEMENT DETAIL 15 4,rr 141 ,,,, 17 20" Cmt w/260 sx of Arcticset I in 42"Hole °" I :1' 10-3/4" Cmt w/653 sx AS Lite,257 sx Class"G"in 13-1/2"Hole # s - '" 1 24 7-5/8" Cmt w/604 sx Class"G"in 9-7/8"Hole 164M14,',11 741." F 25 WELLHEAD v,•' r0 r Wellhead FMC Tubing Hanger,11"x 4-1/2"TC-ll Top&Bottom is ,"', ,„t � ,� 21 �CA, 26 GENERAL WELL INFO ,.. ± :: •�'nr�"%9 ,�`»3?1?r� 27 API:50-029-23224-00-00 7-5/8' `-1,1,44* Drilled and Completed by Doyon 14-10/13/2004 TD=8,639'(MD)/TD=4,226'(TVD) ESP Replacement by Nabors 4E5-12/09/2004 PBTD=8,639'(MD)/PBTD=4,226'(TVD) ESP Replacement by Nabors 4ES-2/20/2005 Convert to Jet Pump by Nabors 4ES-11/24/2005 Revised By:STP 5/02/2016 • • Milne Point Unit Well: MPU H-18 II PROPOSED Last Completed: 11/24/2005 Hamra Alaska,LL( PTD: 204 174 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm Orig.KB Elev.:69.6'/Orig.GL Elev.:35.6' 20" Conductor 92/H-40/Welded N/A Surf 112' RKB-Hanger:20.07'(Nabors 4ES) 10-3/4" Surface 45.5/L-80/BTC 9.794 Surf 4,562' 7-5/8" Production 29.7/L-80/BTC-MOD 6.750 Surface 10,228' L4" Liner"A" 9.5/L-80/IBT 3.423 6,090' 8,597' 20"j 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 6,572' 8,565' 4-1/2" Liner"C" 12.6/L-80/IBT 3.833 6,728' 8,639' TUBING DETAIL 1 4-1/2" Tubing 12.6/L-80/TDS 3.958 Surf 6,038' JEWELRY DETAIL i 2 No Depth Item 10-3/4" a c 1 2,062' 4-1/2"X Profile(3.813"Packing Bore ID) 2 2,479' KBG2 GLM 4.500"x 1"(Dummy Valve Set 12/02/05) 3 5,922' 4-1/2"XD Sliding Sleeve(Jet Pump removed) 4 5,946' 7-5/8"x 4-1/2"Baker Premier Packer 5 6,014' 4-1/2"X Profile(3.813"Packing Bore ID) 6 6,038' Wireline Entry Guide 7 6,031' NB Lateral Tie Back Sleeve 8 6,042' NB Lateral ZXP Liner Top Packer 9 6,058' NB Lateral LEM#2(Lateral Entry Module) 10 6,067' NB Lateral Hook Wall,Hanger above 7-5/8"Window 11 6,084' NB Lateral Hook Wall,Hanger below 7-5/8"Window 12 6,113' NB Lateral Swell Packer 13 6,067' NB Lateral Isolation Sleeve(6,067'-6,086') 14 6,188' OA Lateral Tie Back Sleeve 15 6,199' OA Lateral ZXP Liner Top Packer 16 6,539' OA Lateral LEM#1(Lateral Entry Module) _ 17 6,549' OA Lateral Hook Wall,Hanger above 7-5/8"Window 18 6,566' OA Lateral Hook Wall,Hanger below 7-5/8"Window 4001 3 19 6,681' OB Lateral Tie Back Sleeve 20 6,692' OB Lateral ZXP Liner Top Packer 21 6,702' 08 Lateral 7-5/8"x 5-1/2"HMC Liner Hanger 22 8,552' NB Lateral 4-1/2"Pack-off Bushing r r ri 23 8,597' NB Lateral 4-1/2"Btm of Guide Shoe s z m 4 24 8,520' OA Lateral 4-1/2"Pack-off Bushing 25 8,565' OA Lateral 4-1/2"Btm of Guide Shoe 26 8,595' 08 Lateral 4-1/2"Pack-off Bushing 5 27 8,639' OB Lateral 4-1/2"Btm of Guide Shoe LATERAL WINDOW DETAIL 1'6 Top of"NB"Window @ 6,072'MD;Bottom @ 6,084'MD;Angle @ top of window is 61 deg 8 Top of"OA"Window @ 6,554'MD;Bottom @ 6,566'MD;Angle @ top of window is 75 deg 13-4-1-s, '10, WELL INCLINATION DETAIL 1 *] 11 22 KOP@500'MD NB Lateral 23 Max Wellbore Angle=93.0 deg @ 7,053'MD f, �ii F....-� 60deg@6,038'MD 12 14,¢;. OPEN HOLE/CEMENT DETAIL 15 17 18 20" Cmt w/260 sx of Arcticset I in 42"Hole 10-3/4" Cmt w/653 sx AS Lite,257 sx Class"G"in 13-1/2"Hole 24 7-5/8" Cmt w/604 sx Class"G"in 9-7/8"Hole r 'Lateral 25 WELLHEAD Wellhead FMC Tubing Hanger,11"x 4-1/2"TC-II Top&Bottom 19,'" 21 26 GENERAL WELL INFO "OB"Lateral 27 API:50-029-23224-00-00 7-5/8" Drilled and Completed by Doyon 14-10/13/2004 TD=8,639'(MD)/TD=4,226'(TVD) ESP Replacement by Nabors 4ES-12/09/2004 PBTD=8,639'(MD)/PBTD=4,226'(TVD) ESP Replacement by Nabors 4ES-2/20/2005 Convert to Jet Pump by Nabors 4ES-11/24/2005 Revised By:STP 5/02/2016 . • • • iliMilne Point Unit COIL BOPE MPU 11-18 5/02/2016 ff4frorp \fn.kr.1.1,C MPU H-18 20 x 10% x 7% x 4'A Coil Tubing BOP S Lubricator to injection JJ head I I 1.75"Single Stripper 1lio 1 f _ •I1I� Blind �'1/1615 Blind 'I'I1 0.111111EINI 114 Shear 11111 0 Ii- €_ —_ SlipSlip .Iui �- `\` Mil Mile •Iow Pipe � , Pipe 11111477711 - Crossover spool re sv 4 1/16 15M X41/1610M ; Crossover spool uu fag 41/16 10M X 4 1/16 5M 111.161m$94 Pump In Sub �(; e4 1/16 5M ;11 o ; Mill l 1502 Union t ' Bmf X '' Im , , Manuual Gate Manual Gate Valve,Swab,WKM-M, -�� 2 1/8 5M 2 1/8 5M 4 1/16 5M FE ( * \14\L;- R �1 �F ,,,\,,e, tib`' ■ C`°JCS; • • • STANDARD WELL PROCEDURE iiilcorpAlaska,LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. r/ 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • I f a -'z o o e > o a a G t„, 3 a ,) o > > (5 R I- W H W UwU 33a 33a .•"1 °a ¢ Q W Q �� ••• •• 1/1 VI ) > a A • WE Zi": Ww • W 0. d • N > > N> ( 7 0. O N � a > X ti Z C > aP ; ai•••• ••• w > C7 = U r inn,lb" r � x �� v , w 1 41 c R 0 u i Via`` r INN O TMw A o V - 12v o " f 1 —" 111::: : RI �IV•- �° 141141111 •i. ' ki iii 11 ii G O O N Z d W Q R a w c c LL r V O O O O m m .. a �7 V Y Z Q F J J Y m LG 8 LA . Image Project Well History File Cover Page . XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. clQ Lt - L 7- Lf Well History File Identifier Organizing (done) o Two-sided 1111111111111I1111I o Rescan Needed III 1/1111/1 II 11I11/ RESCAN ¢olor Items: ~reYSCale Items: o Poor Quality Originals: DIGITAL DATA ~skettes No. ~ o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: Date LIlt (p 10 tp o Other:: NOTES: BY: ~aria~ 151 lML 111111111111111111I l&tP Project Proofing BY: ~ 151 Scanning Preparation BY: Date: Production Scanning Stage 1 Page Count from Scanned File: q"3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES BY: ~ Date: " / I W I 0 ~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 1111111111111111111 NO 151 vvtP NO BY: Maria Date: 151 1IIIIIII11111111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 11111 BY: Maria Date: 151 Comments about this file: Quality Checked 11I1111111111111111 10/6/2005 Well History File Cover Page.doc • • ~~ ~~ ~- dA°" r ~r= MICRQFILMED 03/01/2008 DO NOT P LAC E ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertslMicrofilm Marker.doc 13 tJ\J ^~~b DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041740 Well Name/No. MILNE PT UNIT SB H-18 Operator BP EXPLORATION (ALASKA) INC S¡1'L-L ?v^1~~ API No. 50-029-23224-00-00 MD 8639 /' NO 4226 /' Completion Date 1 0/13/2004 ~ Completion Status 1-01L Current Status 1-01L UIC N _,. _____.___.,._. _"'____...__._____._ _u_____._...______.___._______ _______ ._____._... __u_.._ .~_ __ ___ ~___._._..__,____.______._. __.__..._.__._______ .._ ._ .._._______ _ . ~..._~.. ._._ .__ __. _.._ . "-'---'''''..'--' ---. _._--------_.--,,------ - ---..--.---.--.--. _._-_.~..._-_._-_._---_.__._-~._---~._-----. -.---- ---..----- --..-- ---_...-,-_.-.---~ -------.- ..- -..-.-.--.- -....- -. --.- - - -- .-.------.-----"----- _.._.~--~------- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ..- -- ~._--_._-_.__._-_._----_._--_._.._--_._"----,,--_.__.__.----.,---,------~--_._---,_.._._- ......-.---.- --_._-_..-._._-----~------_._---,-_.- - ----------- -.---.-----.-.-----.-.".-----..-,--------..--------.--'--.-------_.~._--_._--------_...._-----_.-.._,_._---~----._- .- ----.-.-- ...- .-.- -.-.-----.. .-.--- - -. - .-.. ..-------.-...--... _..__._--_..._..~_._-_.._- _._--'-------------_._-_._~.. .-.-.- DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, IFR/CASANDRA, lAB, GYRO Well Log Information: Electr Digital Dataset Med/Frmt Number _____·_h.___~_.._ o Asc (data taken from Logs Portion of Master Well Data Maint t Name Directional Survey Log Log Run Interval Scale Media No Start Stop .--.--------.----.--.--------.------.--.-- o 8639 o 8639 OH/ CH Received Comments _ _ _._·____h.___.._.____ ___ IIFR IIFR ------ o TIF Directional Survey Directional Survey Directional Survey 12820 Gamma Ray h"> I f ~ Ù~~~tL.~ ~ a R=1 R=I a Ra¥ Ý". ~ 11/9/2004 11/9/2004 o Asc C Lis 13522 Induction/Resistivity 0 8639 11/9/2004 MWD 0 8639 11/9/2004 MWD 69 8582 Open 11/9/2004 GR/EWR4/ABI/ROP/MWD 69 8582 Open 11/9/2004 GR/EWR4/ABI/ROP/MWD/ DSN 12820 114 8639 Open 2/22/2006 ROP DGR EWR plus Graphics --,----_._-------------- - - -.---- ~-_.._~-_..'"_.._-,._-._.,- -...- ._---, --..- -.._..._----_.~_._...__._--_.._. -.---.----- ._._.~- -..----..-.,,- .,,,.._."~' Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ( ADDITIONAL INFORMATION Well Cored? Y Œ:> Daily History Received? Æ: Chips Received? -.:J..JJ;J-. Formation Tops Analysis Received? ~ ·_____·__________·_..~___.___..,,_..__..~~,_._.._.h_____..___...·__h________,~.__..__..___.._._____,,_~.__.__._..'.__..,~.____..__.___._..____....__.._._ ..___._.__.___..._.___ _.._...__. _"._.___.._..._....".. ..__ __. ___..__ __._.__.____.._...._._.___.___.______.,_....__.." ."._.,__..__._._____.~._._....______. .____.._.._......__. ..-...-----.--,----.-..,,----..-,..-'".---."'"'------.-..-._____.._...._~_.__4.__.___.._______._._____.___~._.___ ._..__·_____·.__,__..__h__'_·_...._._________._.__......... __.._'""'..._""..,__.__,.._....~.._____.._..,..__~__..._____..._______._________.___..~~.__..___..__..~_~______._._._....._._,.._..,,_._ "'_"'_'_'_"".'_.__...h._.._._ Comments: ---.-...-..---.---...--.---,-,.-.------..--....-.--.--...........-.--.---.--------..-.--..---.-.---..---.---...-,-_.-._....,..-...,--.-..~-,_._..-_..----"---"._,.-,---.---.--,..-------........-.--..., .-.-.... _._'._._,,--_..,-......~,_.._._--_..._..._._--_.._.-"'--~---_._---------_._-~---------,_..._---~._.._. . _....~.-_..,-_. --.--------.--.-.--.-------------"-.--..---...---.-----,_.__._._._----~..__.__.-.-_._._----._~---.---_....-----.._....__.~.__.._.......- ....- -..----- .. -..---..-.-,,-,.-----....,-....-.....----- ----"_.._'''_._~_...._.._".._...._..__..__.._-_._---- -_.,----~.__._-_._--~..__._--,-_._._.._._..._---_...-..- ..--....-..------..---... ...-"..-.....-.--.--.....--.-.- DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041740 Well Name/No. MILNE PT UNIT SB H-18 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23224-00-00 ~~mPIì:::: ReViewe:~: :22~ ...J:t¿ãion~a:~:1::4 Completion Status 1-01 L Current Status 1-01L ~ . UIC N Oate: __~__ __J~__~~ ( l ---..-- \ WELL LOG TRANSMITTAL cQD4-J74-- To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16,2006 l~9, RE: MWD F01111ation Evaluation Logs MPH-18, The tec1mical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob J(alish, Speny Drilling Services, 6900 Arctic Blvd., Anchorage, AI( 99518 907-273-3500 MPH-18: LAS Data & Digital Log Images: 50-029-23224-00 1 CD Rom ~/l (Y1HJ]J2J-{\ ~ ~\0fð \Dlo STATE OF ALASKA JAN 0 9 2006 ALASKA~L AND GAS CONSERVATION CO~ISSIOf1".lra n REPORT OF SUNDRY WELL OPERA TIORS'iI & Gas Cons. Commission Anchorage " 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program Convert to Jet Pump o Suspend 0 Operation Shutdown 0 Perforate II Other II Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): KBE = 69.60' 8. Property Designation: ADL 025906 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 8639 4226 8639 4226 Casing Length Structural Conductor 78' Surface 4527' Intermediate Production 6877' Liner 1958' 4. Current Well Class: II Development 0 Exploratory o Stratigraphic 0 Service 5. ermit To Drill Number: 204-174 6. API Number: 50-029-023224-00-00 99519-6612 9. Well Name and Number: MPH-18 10. Field / Pool(s): Milne Point Unit 1 Schrader Bluff feet feet Plugs (measured) NIA feet Junk (measured) NIA feet Size MD TVD Burst Collapse 20" 112' 112' 1490 470 10-3/4" 4562' 3199' 5210 2480 7-5/8" 6910' 4180' 6890 4790 4-1/2" 6681' - 8639' 4135' - 4226' 8430 7500 Perforation Depth MD (ft): Slotted Liner 6933' - 8595' Perforation Depth TVD (ft): Slotted Liner 4183' - 4220' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 4-1/2", 12.6# L-80 6038' None Treatment description including volumes used and final pressure: RBDMS BFL JAN 1 0 2006 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run II Daily Report of Well Operations II Well Schematic Diagram 17. I hereby certl Contact Sig~ure Form 10-404 Revised 04/2004 Oil-Bbl Re resentative Dail Avera e Production or In'ection Data Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure II Development 0 Service o WINJ 0 WDSPL Sundry Number or N/A if C.O. Exempt: Title Technical Assistant Phone Date 0 f -OS' - Prepared By NameINumber. Sondra Stewman, 564-4750 Submit Original Only 564-4750 Tree. 4 1/16" - SM FMC Wellhead' 11" x 11" SM FMC Gen S, w/4 1/2" Tbg Hgr. 41~; TC-II T&B, CIW "H" BPV Profile 20", 92#/ft, H-40 c::TIÐ 103/4" L-80 45.5 #/ft Howco Float Shoe4562' I KOP @ 600' 50+ degree from 2,378' Max hole angle = 64 degrees @ 3915' MD DATE 10/15/04 12/9/04 2/20/05 11/24/05 75/8" 29.7 ppf, L-80, BTC-M casing (Drift ID = 6.750", cap = 0.0459 bpf) (Cap w/4 1/2" tubing inside = .0262) 4 1/2" 12.6 ppf, L-80 TC-II tbg. ( drift id = 3.833" cap = .0152 bpf) Window for NB 6072' to 6084' 4-1/2" Hook Hanger inside casing 6,067' outside hook point 6,084' LEM #2 liner Baker tie back sleeve Baker ZXP Pkr 4.5" seal assy. 6,031' 6,042' 6,215' LEM Isolation Sleeve set across NB Sands ISO Sleeve 6067' - 6086' Min 10 through Sleeve is 2.62". 4 1/2" GS Fish Neck Window for OA 6,555' to 6,567' 4-1/2" Hook Hanger inside casing 6,549' outside hook point 6,566' LEM #1 liner Baker tie back slv. 6,188' Baker ZXP top pkr. 6,199' Baker 190-47 seal bore 6,207' 4.5" seal assy. 6,721' Baker Tie Back Sleeve Baker ZXP Packer Baker HMC Liner hanger Baker 190-47 seal bore ex!. 6,680' 6,691' 6,702' 6,709' 7-5/8" Weatherford Float Collar 6826' 7-5/8" Weatherford Float Shoe 6910' REV. BY MPH-18 NB Lateral OA Latera! COMMENTS MOO Drilled & Completed Doyon 14 Lee Hulme ESP Changeout Nabors 4ES Lee Hulme ESP C/O & Isolate NB Sands Nabors 4ES Lee Hulme Convert to Jet Pump Nabors 4ES ~rig. OF elev. = 69.60' (Doyon 14) g. GL elev. = 35.60' (Doyon 14) '-~ HES 4 1/2" X Nipple 3.813 Packing Bore 10 I 2062' Camco 4 1/2" x 1" KBG-2 Gas lift mandrel I 2479,1 HES 41/2" XD Duro Sleeve 3.813 Packing Bore 10 1 5922' I Baker 7 5/8" x 4 1/2" Premier Packer 15946' I HES 4 1/2" X Nipple 3.813 Packing Bore ID 16014' I 16038' I WLEG (bottom) 63/4" Hole td @ 'Btm Baker Dbl Float Shoe 8,598' 7 jts. 4.5 L-80 18T -M , Swell Packer @ 6,113' 28 jts. - 4 1/2" C27 Baker med. Excluder 34 jts, 9.5# L-80 IBT 63/4" Hole td @ 9,910' Btm Baker Fioat Shoe 8,565' 46 jts. - 4 1/2" Slotted Liner 1 jts, 12.6# L-80 IBT 6 3/4" Hole td @ 8,639' 8tm HES Type V Float Shoe 8,639' 40 jts. - 4 1/2" Slotted Liner 4 jts, 12.6# L-80 IBT MILNE POINT UNIT WELL MPH-18 API NO: 50-029-23224-00 50-029-23224-60 50-029-23224-61 BP EXPLORATION (AK) OperatiønsSl.lmrnªryB~p()rl. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 11/15/2005 Rig Release: 11/25/2005 Rig Number: Spud Date: 9/24/2004 End: 11/25/2005 Date From - To Hours Task Code NPT Phase Description of Operations 11/18/2005 06:00 - 10:30 4.50 RIGD P PRE RDMO from MPE-30. 10:30 - 12:30 2.00 MOB P PRE Move to MPH-18. 12:30 - 17:00 4.50 RIGU P PRE Spot Rig over well. Spot, RlU Pits and Pipe Shed. Take on Hot Seawater to Pits. Accept Rig @ 1700 hours. 17:00 - 22:00 5.00 RIGU P PRE Install second Annulus Valve. Hook up lines to Tree and Tiger 1 Tank. Blow down line to tiger Tank to make sure it's open. P/U Lubricator and Pull BPV. 22:00 - 23:00 1.00 KILL P DECOMP Repair leaking manifold on Rig Pump discharge. 23:00 - 23:30 0.50 KILL P DECOMP Test lines to 3500 psi. 23:30 - 00:00 0.50 KILL I: DECOMP Pre-Job Safety Meeting on Well Kill procedures. 11/19/2005 00:00 - 03:00 3.00 KILL DECOMP Check Wellhead pressures: 500 psi Tbg, 670 psi Csg. Take on 435 Bbls, 140 F seawater. Pump 260 Bbls of hot seawater (Tbg Avg 500-1000 psi Csg Avg 50-600 psi Circulating). Monitor well for 10 min, 80 psi on Tbg, 100 psi on Csg. Pump 260 Bbls of hot seawater (Tbg Avg 370 psi, Csg Avg 30 psi circulating) until well returns are clean and warm. 03:00 - 04:00 1.00 KILL P DECOMP Monitor well: 20 psi on Tbg, 40 psi on Csg. Take on hot seawater and build 435 Bbls of 8.9 ppg brine. 04:00 - 05:30 1.50 KILL P DECOMP Circulate 262 Bbls, 140 F, 8.9 ppg seawater at 4 BPM (Tbg 400-600 psi, Csg 30 psi circulating) and see 8.9 ppg clean seawater returns to Pits. Well took 50 Bbls of seawater during Well Kill ops; total Fluid hauled to Well, 900 Bbls; 430 Bbls shipped to disposal; 420 Bbls in Pits. 05:30 - 06:30 1.00 KILL P DECOMP Monitor well. Well on slight vacuum, Set and test TWC. RID Surface Lines. Drain Tree. 06:30 - 07:30 1.00 WHSUR P DECOMP Nipple Down Tree and Adaptor Flange. 07:30 - 11 :00 3.50 BOPSU P DECOMP N/U BOP Stack and Lines. RlU Test Pump. 11 :00 - 14:30 3.50 BOPSU P DECOMP PJSM for BOPE testing. Pressure test BOPE to 250 psi low, 3,500 psi per AOGCC and BP requirements. Test witnessed by I Toolpusher and BP Co Rep. Jeff Jones and John Spaulding, I I AOGCC, waived AOGCC's right to witness BOPE tests. 114:30 - 15:00 0.50 BOPSU~ P IDECOMP RID BOPE test equipment. P/U Lubricator and extension and pull TWC, UD same. 15:00 - 16:00 I 1.00 PULL P IDECOMP P/U 2-7/8" Landing Joint, BOLDS, stab into hanger and pull I Hanger free with 50K, pull to floor w/ 48K. Well is on slight vacuum. Check ESP Cable conductivity--good. 16:00 - 17:00 1.00 PULL P DECOMP POOH and UD Hanger and 3 jts 2-7/8" tubing. Getting back heavy oil at surface 17:00 - 18:00 1.00 PULL P DECOMP Circulate out heavy oil at surface. Spool up Centrilift ESP I I Cable. Safety meeting held with on-coming rig crew. 118:00 - 00:00 I 6.00 PULL P DECOMP P.O.O.H. 2-7/8" 6.5# L-80 8rd EUE Tbg. Lay down 183 Jts., I 100 La Salle clamps, 3 Flat Gaurds, 5 Protectolizers, 3 GLM,s, XN Nipple. Recovered all Completion components. 11/20/2005 100:00 - 02:30 2.50 PULL P DECOMP Lay Down ESP Pump; found pump motor full of sand. Also pup above ESP was full of sand also. 02:30 - 03:30 1.00 PULL P DECOMP Clear and Clean rig floor. 03:30 - 04:00 0.50 CLEAN P DECOMP Pre- Job Safety Meeting for tripping Drill Pipe. 04:00 - 05:00 1.00 CLEAN P DECOMP Pick up and Make up BHA as follows: 6-1/8" Bit, 5-3/8"Scraper, X-O Reg. to IF, Bumper Jar, Oil Jar, 9 Jts 4-1/2" Drill Collars. 05:00 - 06:00 1.00 CLEAN P DECOMP RIH BHA #1 on 3-1/2" Drill Pipe from Pipe Shed. 06:00 - 06:30 0.50 CLEAN P DECOMP Service Rig. 06:30 - 11 :00 4.50 CLEAN P DECOMP Continue RIH w/ Cleanout BHA. 111 :00 - 16:30 5.50 CLEAN P DECOMP Soft tag at 5905'. Reverse circulating in hole. Can't make Printed: 11/28/2005 12:58:38 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 11/15/2005 Rig Release: 11/25/2005 Rig Number: Spud Date: 9/24/2004 End: 11/25/2005 Date From - To Hours Task Code NPT Phase 11/20/2005 11 :00 - 16:30 5.50 CLEAN P 17:30 - 19:00 1.50 I RUNcoi I RUNCO~ I I RUNCOJp I i I DECOMP progress; realign valves and circ Long Way and wash down to 5928' RKB. Pump Hi-Vis pill and reverse circulate clean. Use "Stuff and Huff" to wash to 6027' RKB. Pump 25 Bbl Hi-Vis sweep at 3/5 BPM, 500/900 psi. DECOMP Reverse Circulate 260 Bbls at 5 BPM I 900 psi until clean. DECOMP POOH and SIB DP and DC in Derrick. DECOMP B/O and UD BHA #1. DECOMP M/U BHA #2: 2-7/8", EUE, 8rd, 15' pup with Mule Shoe, 1-Jt 2-7/8", EUE 8rd Tbg, 3-1/2' IF x 2-7/8", EUE 8rd XO. DECOMP RIH wI BHA #2 on 3-1/2" DP to top of sand @ - 6023". DECOMP RIH RlU Circulating lines. Reverse Circulate and soft tag at 6049' RKB. DECOMP Ciirculate and Wash 5.75 BPM I 1000 psi to 6052' RKB. Pipe packed off; P/U 2' and pump 25 Bbl Hi-Vis sweep and continue to circulate from 6050'. DECOMP Realign valves and Reverse Circulate from 6050' @ 4/5 BPM until returns clean. Recovered sand. Well loses of 147 bbls during reversing. Monitor well; well on slight vacuum. DECOMP POOH and UD DP and DCs through Pipe Shed. B/O and UD full joint of 2-7/8", 8Rd, pup joint, and Mule Shoe. DECOMP RID DP handling equipment. RID Centrilift Double Sheave. RlU Torque Turn equipment and wait on machined 4-1/2" TDS x 4-1/2" TCII XO pup joint from Baker Machine. RUNCMP P/U 4.5" WLEG, M/U to HES 'X'-Nipple and begin RIH wI 4.5" used tubing (148 jts 4.5",12.6#, TDS; 2 jts 4.5",12.6#, TCII completion; 2 X-Nipples; 7-5/8" Baker Premier Packer; HES 4-1/2" XD Durasleeve) RUNCMP While RIH with the 12th joint, well fluids started coming to the surface consisting of thick, foamy oil. About 114 to 112 Bbl of foamy oil slowly roled over the top of the open tubing which was only 3-4 feet above the floor. Floorhands stabbed in the floor valve and Driller closed the Hydril. Circulated 70 Bbls of 8.9 ppg brine and took 65 Bbls of oily returns to the Tiger Tank. SII the well and pressures were 20 psi tubing and 30 psi casing. Confer with town and decide to pump a 40 -Bbls, 9.1 ppg pill. Pumped 7-Bbls down tubing and remainder down annulus. SII and monitored: 120 psi on tubing and casing, but quickly dropped to 40- 50 psi. Opened tubing and pressure quickly went to 0 psi; opened casing and it dropped to 10 psi then to 0 on the gauge. Well flowed 4 Bbls to the pits, but became a very small amount. Opened Hydril to allow well to equalize and to monitor fluid level. Called AOGCC to tell them circumstances of the event and they were pleased that we informed them, but said we didn't have to call on this particular event. RUNCMP I Mix 60-Bbl, 9.1 ppg pill in Pits. Close Hydril and circulate around, taking returns to Pits. Stop pump and monitor flow. ,Fluid level began to drop slowly, but some small gas bubbles ¡were still breaking out then stopped. Decide to continue RIH. RUNCMP I Continue RIH and circulate fluid hrough BOP stack to ensure fluid balance. RUNCMP I Running in hole to depth 3223' set down. Picked up and soft I taged again. Picked up and bobed through. Picked up and I i 16:30 - 17:30 1.00 CLEAN P 17:30 - 20:00 2.50 CLEAN P 20:00 - 20:30 0.50 CLEAN P 20:30 - 21 :00 0.50 CLEAN P 21 :00 - 00:00 3.00 CLEAN P 11/21/2005 00:00 - 00:30 0.50 CLEAN P 00:30 - 01 :30 1.00 CLEAN P 01 :30 - 02:30 1.00 CLEAN P I 02:30 - 06:00 3.50 CLEAN Ip I 06:00 - 12:00 6.00 CLEAN Ip I I 12:00 - 15:00 3.00 RUNCO~ 15:00 - 17:30 2.50 RUNCOrvP I 19:00 - 11 :30 16.50 11 :30 - 00:00 12.50 Printed: 11/28/2005 12:58:38 PM "-- BPEXPL0RAT.ION OperationS>SUITUl'larYllepørt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From - To Hours Task Code NPT Phase 11/21/2005 11 :30 - 00:00 12.50 RUNCO 11/22/2005 00:00 - 01 :30 1.50 RUNCOr I 01 :30 - 06:00 4.50 RUNCO 06:00 - 14:30 I I 8.50 RUNCOr I i I 14:30 - 15:30 1.00 RUNcor 2.50 RUNCO 15:30 - 18:00 18:00 - 19:00 1.00 19:00 - 22:30 3.50 Start: 11/15/2005 Rig Release: 11/25/2005 Rig Number: Spud Date: 9/24/2004 End: 11/25/2005 Description of Operations RUNCMP never saw problem again? Continue RIH carefully! DPRB RUNCMP Running 4-1/2" 12.6# L-80 Completion, watching hole and wieght. At 4440' in, stacked out again and could not proceed. Decide to POOH and string is pulling w/2-5K overpull. DPRB RUNCMP Confer with Eng. Mr Reem and will pull completion. Well giving up bubbles of gas with oil. R/U circulating line and circulate 182 bbls @ 2 BPM 1100 psi 9.1 brine around to condition and clean hole. Monitor Well not stable; gas bubbles on the surface of fluid in the BOP Stack. Circulate 182 bbls @ 3 BPM I 100 psi 9.1 brine. After pumping, the fluid level dropped. Took 17 bbls to fill. Cirulate 182 bbls @ 3 BPH 1100 psi 9.1 brine. Had losses of 21 Bbls. Monitor well. RUNCMP POH slowly to prevent swabbing, continue out wI 50K pull. Get stuck @ 3543'. Discuss with town and Baker; decide to increase overpull, but to NOT circulate to avoid setting the packer. Pull free wI 15K and continue POOH. Packer sticks several times until 75 Joints remaining in hole, then pulls free, but will pull very slowly to avoid the sticking problem. Each time the Packer "sticks", we stop pulling and relax the string for 5-10 minutes. Each time we resume POOH string comes free with 1 0-15K, then continues on out with 2-5K overpull. Welcome back, Lee! DPRB RUNCMP I Well flowed 1-2 Bbls of viscous oil out the tubing while slowly I P/U jt #60. Lowered the tubing and stabbed TIW valve. Filled the backside with 14 Bbls 9.0 ppg fluid. SII Hydril, and tubing: 90 psi Tubing, 0 psi Casing. Clean Rig floor. DPRB RUNCMP I Reverse Circulate 2.7 BPM wI 90 psi Csg, 50 Tbg for 120 Bbls, I taking returns to Tiget tank. SII wI 30 psi Csg, 90 psi Tbg. Open Casing and Tubing and pressures bleed quickly to 0 psi. Fluid level dropping in Casing and no blow after the TIW removed. Look down Tubing and see fluid slowly rising in Tubing. Decide to re-stab TIW valve and circulate Long Way for 120 Bbls. DPRB RUNCMP Circulate 120 Bbls @ 2.5 BPM wI 50 psi returns to pits. Monitor well, find it stable. DPRB RUNCMP POOH 4-1/2" Completion slowly, double displacement monitoring well. Recovered all assemblies. Baker Premier Packer has gouging on upper and lower body, with upper slip holding-pins sheared. Element Expander ring dinged up also. Mule Shoe with tail pipe was in good condition. RUNCMP RID 4-1/2" handling equipment. RlU 3-1/2" handling equipment. I I DPRB 22:30 - 00:00 1.50 DPRB 11/23/2005 00:00 - 00:30 0.50 CLEAN N DPRB 00:30 - 02:00 1.50 CLEAN N DPRB 02:00 - 08:00 6.00 CLEAN N DPRB 08:00 - 09:30 1.50 CLEAN N DPRB 09:30 - 12:00 2.50 CLEAN IN DPRB I CLEAN I CLEAN I CLEAN I CLEAN i CLEAN I I I ! i i i Clear and Clean Rig Floor Pick up Make up BHA #3 2-7/8" Mule Shoe Pup, 2-7/8" Pups, XO, Scraper, XO Sub, Bumper Sub, Jar, 9 x Drill Collars. RIH BHA #3 on 3-1/2" DP. Stop at -4,170-ft. Reverse Circulate 4-Drill Pipe volumes (28 Bbls, each) at 4 bpm/100 psi. Very small amount of Formation Sand recovered. Reverse Circulate full wellbore volume. Monitor Well and fluid is falling very slowly so decide to continue on into the hole. RIH slowly to 6,007' (full jt #179) without incident. Fluid level dropped -10'. P/U #180 and slowly lower into top of Tieback Sleeve @ 6,027' (4ES RKB), see slight bobble, continue in for Printed: 11/28/2005 12:58:38 PM BP EXPLORATION OperationSSlJmrnary<Be.pe>rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Spud Date: 9/24/2004 End: 11/25/2005 Start: 11/15/2005 Rig Release: 11/25/2005 Rig Number: Date From - To Hours Task Code NPT Phase 2.50 CLEAN N DPRB CLEAN full jt #180, 6,039'. P/U Jt 181 and continue in until tagging @ 6,053'. Let the tag take 5K, then P/U 5' and install Floor Valve and Circulating Line to prepare to Reverse Circulate HiVis Sweep. Mix 20-Bbl Hi-Vis Sweep and Reverse Circulate 4-BPM @ 560-psi throughout Wellbore. Very small amount of Formation Sand recovered. Circulate 9.0 ppg throughout Wellbore to condition Well. Monitor Well. Fill pits with 9.0 ppg brine and wt. up to 9.2 ppg. Circulate 4 BPM 1 500 psi 9.2 ppg Brine. Circulate and spot 40 bbl Hi- Vis Kill Pill at 6050' Monitor Well. Fluid dropping at slow rate 14 bbl hour. TOH with BHA #3 on 3-1/2" DP, double displace. TOH with BHA #3 on 3-1/2" DP Lay down BHA. RID 3-1/2" equip. RlU 4-1/2" Torque Turn equip. Clear and Clean Rig Floor. Pre-Job Safety Meeting for running Completion held with all personnel. P/U M/U Completion Equipment Baker-Lok connections below Baker Premier Pkr. RIH, monitoring fluid level. P/U Jt #151 and RIH 17' for tag @ 6,042'. P/U 15' and rotate 1/2-turn and RIH to tag @ 6,042'. Mark Jt #151, POH and UD for Space-out measurement. POH and UD top TCII jt, XO pup, and top TDC jt. Calculate Space-out. Will need 4-pup joints and the TCII jt to land the bottom of the Mule Shoe @ 6,038', which is 9' inside the top of the Tieback Sleeve found @ 6,027'. 11/23/2005 09:30 - 12:00 2.50 CLEAN N DPRB CLEAN I I DPRB CLEAN DPRB CLEAN DPRB CLEAN 12:00 - 14:30 1.00 CLEAN N 2.50 CLEAN N 3.00 CLEAN N I I 3.00 CLEAN IN 2.00 CLEAN IN 1.00 CLEAN ! P 0.50 RUNco1 11.00 RUNcol I 2.50 RUNCO~ I I I I 3.001 RUNcot 1.001 RUNCO! 2.50 RUNCOfVP I 0.50 RUNCO~ 2.00 I BOPSU P 2.00 WHSUR P 0.50 WHSUR P 2.50 WHSUR N 14:30 - 15:30 15:30 - 18:00 ! 18:00 - 21 :00 DPRB CLEAN DPRB CLEAN CLEAN 21 :00 - 00:00 11/24/2005 00:00 - 02:00 02:00 - 03:00 RUNCMP 03:00 - 03:30 RUNCMP 03:30 - 14:30 RUNCMP 14:30 - 17:00 I I I 117:00 - 20:00 I 120:00 - 21 :00 121 :00 - 23:30 RUNCMP Reverse Circulate 3-BPM @ 140 psi, 100 Bbls of 9.2 brine followed by 200 Bbls mixed with one drum of Corexit EC-1124 Corrosion Inhibitor. RUNCMP Land Tbg Hanger S/O Wt. 42K P/U Wt. 62K. RILDS Teast Packoff to 5000 psi RUNCMP Drop Rod and Ball. Wait. Pressure up on Tbg to 4000 psi hold for 30 min. Charted Bleed to 2000 psi. Pressure up on annulus to 3500 psi hold for 30 min. Charted. Bleed Tbg. Shear DCK valve. Pump both ways from AnnufTbg. Tbg/Annu. RUNCMP Set and test TWC 1000 psi RUNCMP Call out Hot Oil. N/D BOPE and remove valves. RUNCMP N/U Adaptor FlangeTree and test to 5000 psi RUNCMP Pick Lubricator and pull TWC UD same WAIT RUNCMP WO Hot Oil to arrive on Location. Problems at Fuel Dock loading out required amount of Diesel needed for the job. RUNCMP Hot Oil arrived on Location. PJSM. PT Lines to 3,500 psi. Freeze Protect Well with 110 bbls of Diesel. RUNCMP Set and test BPV. Secure Well and Cellar. Prep to Rig down. Released Rig at 10:00 hrs. 23:30 - 00:00 11/25/2005 00:00 - 02:00 02:00 - 04:00 04:00 - 04:30 04:30 - 07:00 2.00 WHSUR P 07:00 - 09:00 I 09:00 - 10:00 I 1.00 WHSUR P Printed: 11/28/2005 12:58:38 PM STATE OF ALASKA ALASKA___ AND GAS CONSERVATION CO,,,-)SSIO~.r;.JCEIVED REPORT OF SUNDRY WELL OPERATioNS -~- MAR 1 7 Z005 f" 1. Operations Performed: - - J::QD Alaska Oil ~ À!'fàïii-' o Abandon 181 Repair Well o Plug Perforations o Stimulate A J ge o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Time Extension o Change Approved Program o Operation Shutdown o Perforate o Re-Enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 204-174 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-023224-00-00 7. KB Elevation (ft): KBE = 69.60' 9. Well Name and Number: MPH-18 8. Property Designation: 10. Field I Pool(s): ADL 025906 Milne Point Unit I Schrader Bluff 11. Present well condition summary Total depth: measured 8639 feet true vertical 4226 feet Plugs (measured) NIA Effective depth: measured 8639 feet Junk (measured) NIA true vertical 4226 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1490 470 Surface 4527' 10-3/4" 4562' 3199' 5210 2480 Intermediate Production 6877' 7-5/8" 6910' 4180' 6890 4790 Liner 1958' 4-1/2" 6681' - 8639' 4135' - 4226' 8430 7500 Perforation Depth MD (ft): Slotted Liner 6933' - 8595' Perforation Depth TVD (ft): Slotted Liner 4183' - 4220' 2-7/8",6.5# L-80 5923' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDfrAS 8FL f4AR 1 8 2005 Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation: 0 0 784 4000 350 Subsequent to operation: 457 29 441 350 324 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 181 Well Schematic Diagram 16. Well Status after proposed work: 181 Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant $~ø;l ~-^-~ Phone c::. Prepared By Name/Number: 564-5803 Date/.J3 -\ l-é>.....; Sondra Stewman, 564-4750 -- ~-- ~~". t: , . . Form 10-404 Revised 04/2004 --'·f<'Al t ~ F ~~ l¡j¡\11- ~ , : \. Submit Onglnal Only .. Tree: 2-9/16" - 5MFMC &yellh~ad' 11" x 11" 5ty! FM..·· Gen 5, W 2-7/8" FMC Tbg. EU 8rd on t&b, 2.5" CIW-H BPV Profile 20", 92#/ft, H-40 ~ 103/4" L-SO 45.5 #/ft Howco Float Shoe4562' I KOP @ 600' 50+ degree from 2,37S' Max hole angle = 64 degrees @ 3915' MD 7 5/S" 29.7 ppf, L-80, BTC-M casing (Drift 10 = 6.750", cap = 0.0459 bpf) 2-7/S" 6.5 ppf, L-SO Srd eue tbg. (drift id = 2.347" cap = .00592 bpf) Window for NB 6072' to 6084' 4-1/2" Hook Hanger inside casing 6,06T outside hook point 6,084' M PH-1.dLl \ L. 7,.¡¡¡)g· DF elev.: 69.60' (Doyon 14) 0\ l . Wig. GL elev. - 35.60' (Doyon 14) 6,031' 6.042' 6,215' Window for OA 6.555' to 6,56T 4-1/2" Hook Hanger inside casing 6,549' outside hook point 6,566' LEM #1 liner Baker tie back slv. Baker ZXP top pkr. Baker 190-47 seal bore 4.5" seal assy. 6,188' 6,199' 6,20T 6,721' Baker Tie Back Sleeve Baker ZXP Packer Baker HMC Liner hanger Baker 190-47 seal bore ex!. 6,680' 6,691' 6,702' 6.709' 7-5/8" Weatherford Float Collar 6S26' 7-5/S" Weatherford Float Shoe 6910' DATE 10/15/04 12/9/04 2120105 NB Lateral OA Lateral REV. BY COMMENTS MDO Drilled & Completed Doyon 14 Lee Hulme ESP Changeout Nabors 4ES Lee Hulme ESP C/O & Isolate NB Sands Nabors 4ES Camco 2-7/S" X 1" KBMM Gas lift mandrel I 138' I Camco 2-7/8" x 1" KBMM Gas lift mandrel 1 2125' I Camco 2-7/S" x 1" KBMM Gas lift mandrel I 5661' I HES 2-7/S" XN-Nipple (2.250" id) I 5813' I 15866' I Centrilift Pump 151 stg. / GC1700 GPMTAR 1:1 Centrilift Gas Separator Model - GRSFTXARH6 Centrilift Tandem Seal section 513 GSB3 DB UT/L T AB/HSN FSA CL5 1 5,883'1 15,888' I 15,902' I Centrilift Motor 125 HP / KMH-A (Rerated Motor) 2390 volt / 44 amps. PumpMate w/6 fin centralizer I 5,917' I PumpMate TVO = 3824' 6 3/4" Hole td @ 'Btm Baker Dbl Float Shoe 8,598' 7 jts. 4.5 L-80 IBT-M , Swell Pac;ker @ 6,113' 2S jts. - 4 1/2" C27 Baker med. Excluder 34 jts, 9.5# L-SO IBT 63/4" Hole td @ 9,910' Btm Baker Float Shoe 8,565' 46 jts. - 41/2" Slotted Liner 1 jts, 12.6# L-SO IBT 6 3/4" Hole td @ 8,639' Btm HES Type V Float Shoe 8,639' 40 jts. - 4 1/2" Slotted Liner 4 jts, 12.6# L-SO IBT MILNE POINT UNIT WELL H-18 API NO: 50-029-23224-00 50-029-23224-60 50-029-23224-61 BP EXPLORATION (AK) p Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: O.perati.o.I1S·.$~..I'I\1."'êi~..IR~.~~t.··..... MPH-18 MPH-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/16/2005 Rig Release: 2/19/2005 Rig Number: Spud Date: 9/24/2004 End: 2/19/2005 2/16/2005 12:00 - 18:00 Date From - To Hours Task Code NPT Phase P 18:00 - 19:00 19:00 - 00:00 2/17/2005 00:00 - 00:30 00:30 - 01 :30 01 :30 - 05:00 05:00 - 06:00 06:00 - 07:00 07:00 - 08:30 08:30 - 13:30 13:30 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 21 :00 21 :00 - 00:00 2/18/2005 00:00 - 02:30 02:30 - 03:30 03:30 - 04:30 04:30 - 06:00 06:00 - 08:30 08:30 - 10:00 6.00 RIGD PRE Rig down from MPH-16 Well. PJSM and move rig to MPH-18. 1.00 KILL P Rig accepted for well work at 18:00 hours. DECOMP PJSM. Take on heated seawater. Rig up hardline to tiger tank. Install secondary valve on ItA. DECOMP Pull BPV, OA = 0 psi, SITP=310 psi, SICP=350 psi. Pressure test lines to 3,500 psi. good test. Bleed Gas off IA and tubing. Circulate 36 bbls down tubing. Bullhead 118 bbls down tubing. Circulate down tubing up IA at 3.5 bpm, 510 psi. Take crude oil returns to tiger tank. DECOMP Continue to circulate down tubing up IA at 3.5 bpm, 480 psi. Take crude oil returns to tiger tank. Pumped a total of 526 bbls. 118 bbls during bullhead and 408 to the hole. Got 225 bbls crude back to tiger tank. Lost 183 bbls to formation. DECOMP Returns clean. Shut in and monitor well pressures. SITP=50 psi. SICP=50 psi. Open well and bleed pressure off to tiger tank (37 bbls). DECOMP Shut in well and monitor. SITP=10 psi. SICP=O psi. Well flowing back. Continue to flow well and monitor while waiting for additional sea water. Flowed back addtional 34 bbls. Got traces of crude back. DECOMP Circulate well with 8.5 ppg sea water. Well cleaned up after first 10 bbls pumped. DECOMP Finish circulating Well at 3.5 bpmt360 psi. Return losses were 1 bpm. DECOMP Shut down Pump. Monitor Well. Flowed back 13.7 bbls in 35 minutes. Shut in Well. Monitored no recordable pressure after 45 minutes. Open Well. A slight flow continues. Shut in Well. Order 8.75 ppg Brine. DECOMP Wait on Brine. Clean Rig Floor. Maintain Rig. DECOMP Take on 8.75+ ppg brine. Pump same down tubing taking returns to tiger tank. 8.75+ ppg brine to surface after 470 bbls pumped. Shut down pump. Monitor well. Well dead. DECOMP Set TWC and test to 1,500 psi. Good test. DECOMP NO tree. Inspect hanger and LOS. DECOMP NU BOPE. DECOMP PJSM. Conduct full BOPE test, 250 psi low pressure, 3,500 psi high pressure, 5 minutes charted on each test. Witnessing of test waived by AOGCC rep John Crisp. Testing of BOP components witnessed by Company Man. DECOMP Continue to conduct full BOPE test, 250 psi low pressure, 3,500 psi high pressure, 5 minutes charted on each test. Witnessing of test waived by AOGCC Rep., John Crisp. Testing of BOP components witnessed by Company Man. DECOMP RU lubricator, pull TWC, RD lubricator. DECOMP RU to pull completion equipment. Pull hanger to floor (40K Up Wt.). LD same. DECOMP Pull tubing and ESP cable. Circ to clean pipe. Thick crude with gas at surface. Circulate to tiger tank. DECOMP Order additional Brine. Continue to circulate and conditon Well with 8.75 Brine until out of fluid in Pits. Returns mostly clean. DECOMP Wait on additional Brine. Service and maintain Rig. Fluid level slowly dropping in Annulus...however it is just below surface. 5.00 KILL P 0.501 KILL I P 1.00 KILL P 3.50 KILL P 1.00 KILL P 1.00 KILL P 1.50 KILL P 5.00 KILL 3.50 KILL P P 1.00 DHB P 1.00 WHSUR P 2.00 BOPSU P 3.00 BOPSU P 2.50 BOPSU P 1.00 PULL P 1.00 PULL P 1.50 PULL P 2.50 PULL P 1.50 PULL P Printed: 2/23/2005 11 :55:54 AM .i "" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2/18/2005 2/19/2005 Date From - To 1 0:00 - 11 :00 11 :00 - 16:00 16:00 - 17:30 17:30 - 18:00 18:00 - 18:30 18:30 - 19:00 19:00 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 03:00 03:00 - 03:30 03:30 - 04:30 04:30 - 06:00 06:00 - 08:00 08:00 - 11 :30 11 :30 - 12:00 12:00 - 13:30 13:30 - 14:00 14:00 - 16:30 16:30 - 17:30 17:30 - 18:00 18:00 - 19:00 -- ---- F>age.....2.of.·2·. BPEXRLC)RA+I<DN O.perat.i().I1S..·.$LI.A"t·lJI}j.~..·.Reø~~' .' Phase DECOMP 5.00 PULL P DECOMP 1.50 PULL P DECOMP 0.50 PULL P DECOMP 0.50 PULL P DECOMP 0.50 PULL P DECOMP 4.00 PULL P DECOMP 1.00 PULL 0.50 PULL P P MPH-18 MPH-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Hours I Task· Code NPT 1.00 PULL P 2.50 PULL P 0.50 PULL P 1.00 RUNCO~ 1.50 RUNCO~ 2.00 RUNCOí 3.50 RUNCOI 0.50 RUNCOr 1.50 RUNCO~ 0.50 RUNCO~rP 2.50 BOPSUF P 1.00 WHSUR P 0.50 WHSUR P 1.00 WHSUR P DECOMP DECOMP DECOMP DECOMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP POST POST POST POST Start: 2/16/2005 Rig Release: 2/19/2005 Rig Number: Spud Date: 9/24/2004 End: 2/19/2005 I Des¢ription.··ofQþeration$ ..<..< ....... ... . ..... .<..< ................. Off-load 9.0 ppg Brine in Pits. Circulated 50 bbls down Tubing. Returns mostly clean. Fluid level dropping below surface. Continue POOH with 2 7/8" Tubing and ESP Completion. 183 jts tbg pulled. Inspect and LD ESP assembly. Clear and clean rig floor. PJSM with Co Reps, TP, and all crew. PU isolation sleeve, XO's and 3 jts 2-7/8" PAC pipe. RIH with isolation sleeve assembly on 2-7/8" tubing. Tagged latch profile and latched isolation sleeve. Verified latch. Release running tool. Top of isolation sleeve at 6,067'. Bottom of isolation sleeve at 6,086'. Circulate bottoms up at 3 bpm, 1,200 psi. CBU prior to POH with isolation sleeve setting tool. Cease circulation, monitor well. OK. POOH with setting tool. Stand back 2-7/8" tubing in derrick. LD setting tool and 3 joints 2-7/8" PAC pipe. Clear and clean rig floor RU to PU/Run ESP completion assembly. PU and service new pump Continue to pick-up and service new ESP Assembly. Pull ESP Cable over Sheave. TIH with ESP Assembly, XN-Nipple, 3 ea GLM, and 183 Jts 2 7/8" 6.5 Ibltt, L-80, EUE 8rd Tubing. Protecolizers 5,f lat guards 3, LaSalle Clamps 100. Pick-up Landing Joint. Make-up Tubing Hanger. Install Penetrater. Test. Splice upper ESP Cable Connector. Test. Land Tubing Hanger. RILDS. NO BOP's. Test spool, DSA and 2nd fA valve. NU adapter flange and tree. Test adapter flange and tree to 5,000 psi. Pull TWC, set BPV, secure tree. RIG RELEASED FROM WELLWORK AT 19:00 HRS Printed: 2/23/2005 11 :55:54 AM STATE OF ALASKA R ALASI<À-dIL AND GAS CONSERVATION COMi-6SION ECEIVEO WELL COMPLETION OR RECOMPLETION REPORT AND LOG DEC 1 Revision" 12/17/04 St~rt P~OO~tion -¡U~~Ìt-~ nif r>.',,_ ... 1a. Well Status: 181 Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. Well Class: ....'HJ~ ~ºmm, 20AAC 25.105 20AAC 25.110 181 Development ~~BflØory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 10-13-2004 204-174 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9-24-2004 50- 029-023224-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 1 0/3/2004 MPH-18 3026' NSL, 3986' WEL, SEC. 34, T13N, R10E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 745' NSL, 2088' WEL, SEC. 28, T13N, R10E, UM (OB) KBE = 69.60' Milne Point Unit 1 Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 2134' NSL, 2713' WEL, SEC, 28, T13N, R10E, UM (OB) 8639 + 4226 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+ TVD) 16. Property Designation: Surface: x- 556658 y- 6010178 Zone- ASP4 8639 + 4226 Ft ADL 025906 TPI: x- 553247 y- 6013152 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 552609 y- 6014537 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DYes 181 No N/A MSL 1800' (Approx.) 21. Logs Run: MWD DIR, GR, RES, IFR/CASANDRA, lAB, GYRO 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD S~ING DEPTH TvD HOLE I· .. .... ......- .. . AMOUNT I........ ...CEM~NTINGREGOR[) ..... SIZE WT. PER FT. GRADE Top BOTTOM Top .. . BOTTOM rStZE .. .. ... PULLED 20" 92# H-40 34' 112' 34' 112' 42" 260 sx Arctic Set (Approx.) 10-314" 45.5# L-80 35' 4562' 35' 3199' 13-1/2" 653 sx Arctic Set Lite, 257 sx 'G' 7-518" 29.7# L-80 33' 6910' 33' 4180' 9-7/8" 604 sx Class 'G' 4-1/2" 12.6# L-80 6681' 8639' 4135' 4226' 6-3/4" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of T o,e and 24. . . TI;JBlNGRECORD .. ... . . . . . . .. ... Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 2-7/8", 12.6#, L-80 5936' N/A MD TVD MD TVD 6933' - 8595' 4183' - 4220' 25. . ActD,FRÁ(;TlJgE/CEMENT SaUEEZE,ETC, .-. ... ..... DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Crude and 3 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): November 22,2004 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF W A TER-BSl CHOKE SIZE I GAS-Oil RATIO 11/27/2004 6 TEST PERIOD -+ 159 11 107 50 Flow Tubing Casing Pressure CALCULATED -+ OIL-BBL GAs-McF W ATER-BBl OIL GRAVITY-API (CORR) Press. 325 24-HoUR RATE 836 42 429 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS BFl jAN 0 7 2005 ( ,; {'-~ ," sion Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE .--...~-.. 28. GEOLOGIC MARKERS--- NAME MD TVD TUZC MA MB1 MB2 MB2-3 MB2-2 MB2-1 MC SBF2-NA SBF21 SBF24-MF SBF1-NB SBF12 SBE4-NC SBE41 SBE3-ND SBE2-NE SBE1-NF TSBD-OA TSBC TSBB-OB SBA5 5150' 5622' 5641' 5764' 5885' 5895' 6042' 6068' 6137' 6156' 6192' 6205' 6251' 6271' 6283' 6293' 6318' 6424' 6553' 6694' 6872' 8569' 3467' 3684' 3693' 3751' 3808' 3813' 3885' 3898' 3932' 3941' 3958' 3964' 3987' 3996' 4002' 4007' 4019' 4064' 4103' 4138' 4174' 4216' 30. List of Attachments: 29. ',_""ORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra ~&~- Title Technical Assistant - 204-174 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. MPH-18 Well Number Date ll-ll-C'l-l Prepared By Name/Number: Drilling Engineer : Sondra Stewman, 564-4750 Skip Coyner, 564-4395 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating~Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 20: True vertical thickness. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only STATE OF ALASKA ALASKA',-,- AND GAS CONSERVATION CO~,-,,¡SSION DECEIVED REPORT OF SUNDRY WELL OPERATION~' DEC ~ 1 2004 1. Operations Performed: . t ChÆl98. Q.,t ¡::~p r.nml1' I o Abandon I8J Repair Well o Plug Perforations o Stimulate AlaSK~ 'II 'ðæër ...-, nchorsge o Alter Casing I8J Pull Tubing o Perforate New Pool o Waiver o Time Extension o Change Approved Program o Operation Shutdown o Perforate o Re-Enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. a Development o Exploratory 204-174 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-023224-00-00 7. KB Elevation (ft): KBE = 69.60' 9. Well Name and Number: MPH-18 8. Property Designation: 10. Field 1 Pool(s): ADL 025906 Milne Point Unit I Schrader Bluff 11. Present well condition summary Total depth: measured 8639 feet true vertical 4226 feet Plugs (measured) NIA Effective depth: measured 8639 feet Junk (measured) NIA true vertical 4226 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1490 470 Surface 4527' 10-3/4" 4562' 3199' 5210 2480 Intermediate Production 6877' 7-5/8" 6910' 4180' 6890 4790 Liner 1958' 4-1/2" 6681' - 8639' 4135' - 4226' 8430 7500 Perforation Depth MD (ft): Slotted Liner 6933' - 8595' Perforation Depth TVD (ft): Slotted Liner 4183' - 4220' 2-7/8",6.5# L-80 5920' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: RBDMS BFL DEC 222004 Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: I8J Daily Report of Well Operations o Exploratory I8J Development o Service I8J Well Schematic Diagram 16. Well Status after proposed work: aOil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Skip Coyner. 564-4395 Printed Name Sondra Stewman Title Technical Assistant --'- --, / ~~~ , '7 ~( Prepared By Name/Number: ( _ Phone Date -... -/l-u ondra Stewman, 564-4750 Sigoature 564-5803 :', ¡ . . ssion Form 10-404 RevIsed 04/2004 Submit Onglnal Only Tree: 2-9/16" - 5M FMC Wellhead' 11" x 11" 5M FMC, Gen 5, W 2-7/8" FMC Tbg. 2':'r,.tf' EU 8rd on t&b, 2.5" CIW-H BPV Profile 20", 92#/ft, H-40 [IJÐ 10 3/4"L-80 45.5 #/ft Howco Float Shoe I 4562' I KOP @ 600' 50+ degree from 2,378' Max hole angle = 64 degrees @ 3915' MD 75/8" 29.7 ppf, L-80, STC-M casing (Drift 10 = 6.750", cap = 0.0459 bpf) 2-7/8" 6.5 ppf. L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf ) Window for NB 6072' to 6084' 4-1/2" Hook Hanger inside casing 6,067' outside hook point 6,084' LEM #2 liner Baker tie back sleeve Baker ZXP Pkr 4.5" seal assy. 6,031' 6,042' 6,215' Window for OA 6,555' to 6,567' 4-1/2" Hook Hanger inside casing 6,549' outside hook point 6,566' LEM #1 liner Baker tie back slv. 6,188' Baker ZXP top pkr. 6,199' Baker 190-47 seal bore 6,207' 4.5" seal ass by. 6,721' Baker Tie Back Sleeve Baker ZXP Packer Baker HMC Liner hanger Baker 190-47seal bore ex!. 6,680' 6,691' 6,702' 6,709' 7-5/8" Weatherford Float Collar 6826' 7-5/8" Weatherford Float Shoe 6910' DATE 10/15/04 12/9/04 MPH-18 N S Lateral OA Lateral Orig. OF elev. = 69.60' (Doyon 14) ¡g. GL elev. = 35.60' (Doyon 14) C__' Cameo 2-7/8" x 1" KSMM Gas lift mandrel I 139' I Cameo 2-7/8" xi" KSMM Gas lift mandrel I 2,126' I Cameo 2-7/8" x 1" KBMM Gas lift mandrel 15,662' I HES 2-7/8" XN-Nipple (2.250" id) I 5.814'1 15,866' I Centrilift Pump 112 stg. / GC2900 GPMTAR 1:1 Centrilift Tandem Gas Separator Model - GRSFTXARH6 15,887'1 Centrilift Tandem Seal section 513 GSB3 DB UT/L T HL H6 PFS AFLAS/HSN 15,888' I 15,902' 1 Centrilift Motor 190 HP / KMH 2415 volt / 48 amps. PumpMate w/6 fin centralizer PumpMate 1VD = 3823' 15,915' I 6 3/4" Hole td @ 'Btm Baker Obi F!oat Shoe 8,598' 7 jts. 4.5 L-80 IBT -M , Swell Packer @ 6,113' 28 jts. - 41/2" C27 Saker med. Excluder 34 jts, 9.5# L-80 1ST 63/4" Hole td @ 9,910' Btm Baker Float Shoe 8,565' 46 jts. - 4 1/2" Slotted Liner 1 jts, 12.6# L-80 1ST REV. SY COMMENTS MOO Drilled & Completed Doyon 14 Lee Hulme ESP Changeout Nabors 4ES 6 3/4" Hole td @ 8,639' Btm HES Type V Float Shoe 8,639' 40 jts. - 4 1/2" Slotted Liner 4 jts, 12.6# L-80 1ST MILNE POINT UNIT WELL H-18 API NO: 50-029-23224-00 50-029-23224-60 50-029-23224-61 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date r-- 12/8/2004 12/9/2004 12/10/2004 \~ ~ BP EXPLORATION Operation~ Summary Report Page 1 of 1 " , ",', " ,', '. MPH-18 MPH-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Spud Date: 9/24/2004 End: 12/10/2004 Task Code Start: 12/8/2004 Rig Release: 12/10/2004 Rig Number: NPT I Phase I Ðescripti()tlqf;@W~rªtl()n$ I PRE i RD. Lower & scope down derrick. Move from MPH-13 to i ,MPH-18. f PRE I Spot rig sub over well. Raise & scope up derrick. RIU pipe I 1 shed & pits. Move & spot camp. I'DECOMP ! Accepted rig@0300hrs.RIUlinestotigertank&X-mastree. j DECOMP ¡ M/U lubricator pull BPV. UD lubricator. 'I DECaMP I' Hold Pre-spud & PJSM wI all hands. DECaMP ,Open well. SITP 190 psi. SICP 280 psi. Blow down well & I !begin kill operation. Pump down tubing @ 4 BPM, 630 psi. I ! Pumped Tubing volume, then SI ~ bullheaded 50 bbls into I wellbore. BH @ 4 BPM wI 21 0 pSI on annulus. Open well & ! I con't kill operation. Order out more fluid..., significant loss rate. IDECOMP I Monitor well while waiting on more seawater. DECOMP I PJSM. Line up & bullhead 250 bbls down IIA @ 6 1/2 bpm I ! 375 psi. Bullhead 50 bbls down tbg @ 5 bpm 1400 psi. Both I ¡ sides on vacuum. I DECaMP i PJSM. Set & test two way check valve. NID tree. DECaMP i PJSM. N/U BOPE. I DECaMP ! PJSM, pressure test BOPE as per BP/AOGCC requirements. I I LP 250 psi. HP 3500 psi. BOP test witnessing waived by John ! Crisp wI AOGCC. DECaMP ! P/U lubricator & pull TWC. UD lubricator. DECaMP ! M/U landing jt. BOLDS. Pull hanger to floor. P/U wt = 40K. : Disconnect ESP cable & check same. UD hanger & landing jt. DECaMP i POOH w/ ESP completion. Recoverd 183 Jts, 3 GLMs, XN I Nipple assy. 3 Flat Guards, 5 Protectolizers & 101 LaSalle i Clamps. DECaMP 1 Break down, inspect & UD ESP. Motor is good. Pump was I bo . ¡locked up wI a twisted shaft 10" from ttom In gas separator. DECaMP ¡Clear & clean rig floor. Swap out cable reels. RIU to P/U & RIH Iw/ new ESP. DECaMP ! Finish clear & clean rig floor. Change out reels. RIU to run new . I completion. RUNCMP ! P/U & M/U new ESP. Service & Check same. RUNCMP I RIH w/ ESP on 2 7/8" completion. RUNCMP PJSM. P/U landing joint & hanger. Make up penetraqtor & splice ESP cable, test same, OK. RUNCMP PJSM. Land hanger. RILDS. Set @ way check valve. RUNCMP PJSM. N/D BOPE. RUNCMP PJSM. N/U & test tree @ 5000 psi, OK. Secure well. Rig released @ 13:00 hrs, 12/10/2004. 21 :00 - 00:00 From - To Hours '. P 00:00 - 03:00 103:00 - 04:00 104:00 - 04:30 04:30 - 05:00 105:00 - 08:00 ! i ! ¡ i 08:00 - 09:30 109:30 - 11 :00 I ¡ 111 :00 - 13:00 113:00 - 14:30 14:30 - 17:30 I I I 117:30 - 18:00 I 118:00-19:00 I 19:00 - 22:00 I 22:00 - 23:30 23:30 - 00:00 00:00 - 00:30 00:30 - 03:00 03:00 - 07:00 07:00 - 09:30 09:30 - 10:00 10:00 - 11 :30 11 :30 - 13:00 3.00 MOB 3.00 MOB P 1.00 RIGU P 0.50 WHSUR P 0.50 KILL P 3.00 KILL P 1.50 KILL 1.50 KILL P P 2.00 WHSUR P 1.50 BOPSUF P 3.00 BOPSUF P 0.50 WHSUR P 1.00 PULL P 3.00 PULL P 1.50 PULL P 0.50 PULL P 0.50 PULL P 2.50 RUNCO~ P 4.00 RUNCO~ P 2.50 RUNCO~ P 0.50 RUNCO~ P 1.50 BOPSUF P 1.50 WHSUR P Printed: 1211412004 8:22:22 AM '~ ~ði-/7'f j¿S20 '- WELL LOG TRANSMI'ITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 08, 2004 RE: MWD Fonnation Evaluation Logs MPH-18, AK-MW-33 02792 1 LIS formatted Disc with verification listing. API#: 50-029-23224-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: /zlf 1 ,(, 1a. Well Status: a Oil DGas D Plugged D Abandoned o Suspended o WAG 1 P&g'EeU¡ClaSS; 20AAC 25.105 20AAC 25.110 Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 10-13-2004 204-174 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9-24-2004 / 50- 029-023224-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: , Surface: , 10/3/2004 MPH-18 3026' NSL, 3986' WEL, SEC. 34, T13N, R10E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 745' NSL, 2088' WEL, SEC. 28, T13N, R10E, UM (OB) KBE = 69.60' Milne Point Unit / Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 2134' NSL, 2713' WEL, SEC, 28, T13N, R10E, UM (OB) 8639 + 4226 Ft 4b. Location of Well (State ~e Plane coo¡z;ates): 10. Total Depth (MD+ TVD) 16. Property Designation: Surface: x- 55Ei-~ y- 6010178~, one- ASP4 8639 + 4226 Ft ADL 025906 TPI: x- 55 y- 60131~ Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 5526 9' y- 601453i'7Lone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey aVes DNo N/A MSL 1800' (Approx.) 21. Logs Run: MWD , DIR , GR , RES, IFRlCASANDRA , lAB, GVRO 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTHMD . SETTING DEPTH TVD "'HOLE ~. .' . .c· AMOUNT SIZE Wr. PER FT. GRADE Top BOTTOM Top .... BOTTOM SIZE;-' CEMENTING RECORD . . PULLED 20" 92# H-40 34' 112' 34' 112' 42" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# L-80 35' 4562' 35' 3199' 13-1/2" 653 sx Arctic Set Lite, 257 sx 'G' 7-5/8" 29.7# L-80 33' 6910' 33' 4180' 9-7/8" 604 sx Class 'G' 4-1/2" 12.6# L-80 6681' 8639' 4135' 4226' 6-3/4" Uncemented Slotted Liner 23. Perforations op'en to Production (MD + TVD of To,e and 24. .' . TUBING RECORD. .' . Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 2-7/8", 12.6#, L-80 5936' N/A MD TVD MD TVD 25.. '.' '... . c'.: ..' .... '. .,' '. ... 6933' - 8595' 4183' - 4220' . ACID, FRACTURE, CEMENT SaUEEZE,ETG. .......... .' DEPTHINJERVAL(MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Crude and 3 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not On Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL-BBL GAs-McF WATER-BeL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". -- -- ... ~_.- RBDMS BFL NOV 1 2 70D4 - , None j ='~i~~~~º r npí~lr'ljH &r '~ ' .~ Ie ~ .~~-::;;.; ~-........ ,~-,...-..-~~ i 1...-' , .. ¡ ~j . ; \. . ":-~~,!: -=-_":-;.i-¿"~?L--;'--~-~---<-~.'-~ ~-:., . ~ ! ..¡ , STATE OF ALASKA . J ALASKA'CIL AND GAS CONSERVATION COMfV¡j'SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ NOV u 9 2004 Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. .~ GEOLOGIC MARKERS NAME MD TVD TUZC MA MB1 MB2 MB2-3 MB2-2 MB2-1 MC SBF2-NA SBF21 SBF24-MF SBF1-NB SBF12 SBE4-NC SBE41 SBE3-ND SBE2-NE SBE1-NF TSBD-OA TSBC TSBB-OB SBA5 5150' 5622' 5641' 5764' 5885' 5895' 6042' 6068' 6137' 6156' 6192' 6205' 6251' 6271' 6283' 6293' 6318' 6424' 6553' 6694' 6872' 8569' 3467' 3684' 3693' 3751' 3808' 3813' 3885' 3898' 3932' 3941' 3958' 3964' 3987' 3996' 4002' 4007' 4019' 4064' 4103' 4138' 4174' 4216' 29. --' FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Well Service Report and a Leak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Technical Assistant Date ! ( - 0 ~ -04 MPH-18 Well Number :(-2.ro.. 204-174 Permit No. I A roval No. Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Skip Coyner, 564-4395 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ~ 2-9/16" - SM FMC Wellhead' 11" x 11" SM F, Gen S, W 2-7/8" FMC Tbg~7/8" EU 8rd on t&b, 2.S" CIW-H SPV Profile 20", 92#/ft, H-40 o:IÐ 10 3/4"L-80 45.5 #/ft Howeo Float Shoe I 4562' I KOP @ 600' 50+ degree from 2,378' Max hole angle = 64 degrees @ 3915' MD 75/8" 29.7 ppf, L-80, BTC-M casing (Drift 10 = 6.750", cap = 0.0459 bpf) 2-7/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf) Window for NB 6072' to 6084' 4-1/2" Hook Hanger inside casing 6,067' outside hook point 6,084' LEM #2 liner Baker tie back slv. Baker ZXP top pkr. 4.5· seal ass by. 6,031' 6,042' 6,215' Window for OA 6,555' to 6,567' 4-1/2" Hook Hanger inside casing 6,549' outside hook point 6,566' LEM #1 liner Baker tie back slv. 6,188' Baker ZXP top pkr. 6,199' Baker 190-47 seal bore 6,207' 4.5" seal assby. 6,721' Baker Tie Back Sleeve Baker ZXP Packer Baker HMC Uner hanger Baker 190-47seal bore ext. 6,680' 6,691' 6,702' 6,709' 7-5/8" Weatherford Float Collar 6826' 7-5/8" Weatherford Float Shoe 6910' MPH-18 NB Lateral OA Lateral DATE 10/1S/04 REV. BY MDO COMMENTS Drilled & Completed Doyon 14 Orig. OF elev. = 69.60' (Doyon 14) , Orig. GL elev. = 35.60' (Doyon 14) '- Cameo 2-7/8" x1" KBMG Gas lift mandrel I 149' I Cameo 2-7/8" x1" KBMG Gas lift mandrel I 2,136" Cameo 2-7/8" x1" KBMG Gas lift mandrel I s,672'1 HES 2-7/8" XN-Nipple (2.250" id) I 5,824'1 I 5,877' 1 Centrilift Pump 122 stg. / GC2200 GPMTAR 1:1 Centrilift Intake 400 intemals Model - GRSTXARH6 I 5,897' I Centrilift Tandem Seal section 513 GSB3DBUTILH6PFSA GSB3DBL TH6FSA 1 5,902'1 15,916' I Centrilift Motor 152 hp / KMH 2325 volt / 40 amps. PumpMate w/6 fin centralizer 15,934' I 6 3/4- Hole td @ 'Btm Baker Obi Float Shoe 8,598' 7 jts. 4.5 L-80 IBT-M , Swell Packer @ 6,113' 28 jts. - 4 1/2" C27 Baker med. Excluder 34 jts, 9.5# L-80 IBT 6 3/4" Hole td @ 9,910' Btm Baker Float Shoe 8,565' 46 jts. - 4 1/2" Slotted Liner 1 jts. 12.6# L-80 IBT 6 3/4" Hole td @ 8,639' BIm HES Type V Float Shoe 8,639' 40 jts. - 4 1/2" Slotted Liner 4 jts, 12.6# L-80 IBT MILNE POINT UNIT WELL H-18 API NO: 50-029-23224-00 50-029-23224-60 50-029-23224-61 BP EXPLORATION (AK) BP EXPLORATION Operations Summary Report Legal Well Name: MPH-18 Common Well Name: MPH-18 Spud Date: 9/24/2004 Event Name: DRILL+COMPLETE Start: 9/23/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1 0/13/2004 Rig Name: DOYON 14 Rig Number: Date From - To Hours ·Task Code NPT Phase 9/23/2004 07:00 - 08:00 1 .00 MOB P PRE Skid rig floor 08:00 - 10:00 2.00 MOB P PRE Move rig off well, spot on pad 10:00 - 11 :30 1.50 MOB P PRE Shuffle mating boards around comer due to poor pad conditions 11 :30 - 12:00 0.50 MOB P PRE Move rig around corner and spot rig for booster installation 12:00 - 15:30 3.50 MOB P PRE Install front and real booster wheels and mobilize rig mats from I pad 15:30 - 18:00 2.50 MOB P PRE Move rig to H-pad 18:00 - 20:00 2.00 MOB P PRE Remove booster weels,install stairs and cellar doors 20:00 - 21 :30 1.50 MOB P PRE Spot rig over MPH-18, (RIG ACCEPT AT 21:00 HRS DUE TO POOR PAD CONDITIONS AND DOUBLE MATTING.) 21 :30 - 23:00 1 .50 MOB P PRE Rig up floor, spot tiger tank, rock washer 23:00 - 00:00 1.00 RIGU P PRE Nipple up diverter 9/24/2004 00:00 - 03:00 3.00 RIGU P PRE Nipple up Diverter and diverter line, taking on spud mud 03:00 - 12:00 9.00 DRILL P SURF Picking up drill pipe and standing in derrick, total 88 stands, 6 stands HWDP 12:00 - 14:30 2.50 DRILL P SURF Picking up BHA #1 14:30 - 15:30 1.00 DRILL P SURF Rig up Sperry sun Gyro, Pre spud meeting, Preform Diverter test, the right to witness test was wavier by John Spaulding AooGC, fill hole check for leaks 15:30 - 16:30 1.00 DRILL P SURF Drilling 112 to 256' 16:30 - 17:30 1.00 DRILL P SURF Poh and pick up 3 flex dc, run gyro 17:30 - 00:00 6.50 DRILL P SURF Drilling 258' to 760' with 80 rpms, 420 gpm, 1250 psi, running gyros ever 100ft to 600 ft. AST 1.6, ART 3.12 9/25/2004 00:00 - 12:30 12.50 DRILL P SURF Drilling 760' to 1861' with 80 rpms, 500 gpm, 1500 psi 12:30 - 13:00 0.50 DRILL N SURF Change out shaker screens, lost Shaker motor 13:00 - 15:00 2.00 DRILL N SURF Change out shaker motor, worked out dog leg 15:00 - 21 :00 6.00 DRILL P SURF Drilling 1861' to 2627' with 80 rpms, 544 gpm, 2750 psi 21 :00 - 22:00 1.00 DRILL P SURF Circ, two bottoms up with 544 gpm, 2750 psi, 80 rpms 22:00 - 23:00 1.00 DRILL P SURF Pump out to HWDP with full drilling rate 23:00 - 23:30 0.50 DRILL P SURF RIH wash 90 ft to bottom 23:30 - 00:00 0.50 DRILL P SURF Drilling 2627' to 2725' with 80 rpms, 544 gpm, 2750 psi, AST 10.58, ART 8.45 9/26/2004 00:00 - 13:30 13.50 DRILL P SURF Drilling 2725' to 4573' with 80 rpms, 544 gpm, 3440 psi 13:30 - 15:30 2.00 DRILL P SURF Circ, Two bottoms up with 80 rpms, 544 gpm 3400 psi 15:30 - 17:00 1.50 DRILL P SURF Pump out to 1564' with full drilling rate 17:00 - 17:30 0.50 DRILL P SURF Circ bottoms up, no clay balls 17:30 - 19:00 1.50 DRILL P SURF Rih, washed 90 ft. to bottom, bridges @ 1559 and 1608' 19:00 - 21 :00 2.00 DRILL P SURF Circ, 2.5 bottoms up with 80 rpms, 544 gpm, 3400 psi 21:00 - 23:30 2.50 DRILL P SURF Pumping out to HWDP, with full drilling rate 23:30 - 00:00 0.50 DRILL P SURF Stand back HWDP,laying down BHA 9/27/2004 00:00 - 01 :00 1.00 CASE P SURF Laying down BHA 01:00 - 03:00 2.00 CASE P SURF PJSM, clear floor, Rig up to run 103/4 CSG 03:00 - 08:00 5.00 CASE P SURF Picking up 103/4, L-80, 45.5#, BTC, csg, Total 109 jts, shoe 4561', float 4477' 08:00 - 08:30 0.50 CASE P SURF Rig down franks tool, rig up cement head 08:30 - 10:30 2.00 CASE P SURF Circ and thin mud for cement job, 420 gpm, 460 psi 1 0:30 - 15:00 4.50 REMCM P SURF PJSM, Cement with Schlumberger, with 5 bbls water, test lines to 3,500 psi, 20 bbls water, 20 bbls CW 100,75 bbls 10.6 mud push, drop bottom plug, 620 sxs. ASL 497 bbls, mixed @ 10.7, yeild 4.45, tail 257 SXS. Class G 53.7 bbls, mixed @ 15.8 yeild 1.17, drop top plug, kicked out with 30 bbls water, displace with rig pumps 401 bbls of 9.6 mud displace @ 7 bbls min., bump Printed: 1011812004 9:57:31 AM ~o ~- Bp·EXPLORATION Page 2 of9 Operatiol1sSummary Report ~ ~ . ~ .. ~ Legal Well Name: MPH-18 Common Well Name: MPH-18 Spud Date: 9/24/2004 Event Name: DRILL+COMPLETE Start: 9/23/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1 0/13/2004 Rig Name: DOYON 14 Rig Number: . ~ . .~ . Date From - To Hours Task Code NPT Phase Description ofOperéltiöns . . .. ~. . ~ ~ ~.~ . ~~. .H 9/27/2004 10:30 - 15:00 4.50 REMCM P SURF plug with 1800 psi, float held, full return thru out job, 298 bbls of bad cement to surface. 15:00 - 15:30 0.50 CASE P SURF Rig down cement head, flush out diverter and flow lines 15:30 - 16:30 1.00 CASE P SURF Lay down long bales and clear floor of Csg tools 16:30 - 17:00 0.50 CASE P SURF Nipple down Diverter 17:00 - 18:00 1.00 CASE P SURF Nipple up csg head and adapter and test to 1000 psi for ten min. 18:00 - 20:30 2.50 CASE P SURF Nipple up BOPS, Change out saver sub on top drive 20:30 - 00:00 3.50 CASE P SURF Rig up and test Bops and manifold, 250-3500 psi for 5 min per test, Hydril 250-2500 psi for 5 min per test, the right to witness test was wavier by Jeff Jones AOOGC 9/28/2004 00:00 - 01 :30 1.50 CASE P SURF Finish BOP test, install wear ring 01 :30 - 03:30 2.00 CASE P SURF Picking up BHA #2, Test Mwd tool 03:30 - 05:30 2.00 CASE P SURF Trip in to 4355' 05:30 - 06:30 1.00 CASE P SURF Cut and slip drilling line,service top drive 06:30 - 07:30 1.00 CASE P SURF Rig up to test casg - test casing to 2000 psi for 30 mins - 07:30 - 08:00 0.50 CASE P SURF Rig down testing equipment 08:00 - 10:00 2.00 DRILL P SURF Con't RIH - Drill float equipment to 4561' - Clean out rat hole to from 4561' to 4573' - Drill 20' new hole to 4593' - 400 GPM - 1790 psi - Circ hole clean 10:00 - 11 :00 1.00 CASE P SURF Pump 40 bbl spacer - Displace hole with 10 ppg LSND mud 11 :00 - 11 :30 0.50 EVAL P SURF Rig up testing equipment - Perform FIT test to 12.4 EMW 11 :30 - 13:30 2.00 DRILL P INT1 Directional Drill from 4593' to 4900' - WOB 25K - RPM 80 - TO 5K - GPM 500 - PP 2700 - PU 125 - SO 75 - ROT 105 13:30 - 15:30 2.00 DRILL N HMAN INT1 Excessive weight put on bit bending top joint 4" Drill pipe - As string picked up pipe parted - Lay down remaining section of joint from top drive - Cut drill pipe off below rotary table 15:30 - 17:00 1.50 DRILL N HMAN INT1 Change out saver sub on top drive 17:00 - 18:30 1.50 FISH N HMAN INT1 Make up overshot - Latch onto 4" drill pipe - Pick up to 5K over string weight - Break circulation - Circulate hole clean hole up around BHA - Pull 1 0 to 15K in steps as circulating hole - String free @ 220K 78K over normal pick up weight - Lay down overshot and crossover 18:30 - 19:30 1.00 DRILL N HMAN INT1 Lay down 3 joints 4" DP - Pump out 4 stands of 4" DP to shoe 4561' 19:30 - 21 :00 1.50 DRILL N HMAN INT1 CBU - Conduct investigation - Flow check - Pump dry job 21:00 - 22:30 1.50 DRILL N HMAN INT1 POH from 4550' to HWT 22:30 - 23:30 1.00 DRILL N HMAN INT1 Rack back HWT - Flex DC's - Lay down MWD / Motor 23:30 - 00:00 0.50 EVAL N HMAN INT1 Pull wear ring and Install Test plug 9/29/2004 00:00 - 01 :30 1.50 EVAL N HMAN INT1 Rig up testing equipment -Test Top pipe rams to 250 low 3500 high for 5 mins each test - Test Annular 250 low 2500 high for 5 mins each test - Rig down testing equipment - Pull test plug - Install wear ring - Shut annulus valve - 01 :30 - 03:30 2.00 DRILL N HMAN INT1 Pick up new motor - Make up bit - MWD - Orient - BHA to 715' - Test MWD - No signal or pulse on MWD 03:30 - 04:00 0.50 DRILL N DFAL INT1 POH from 715' to MWD 04:00 - 08:00 4.00 DRILL N DFAL INT1 Trouble shoot MWD - Down load MWD - Attempt programming with no sucess - Change out MWD - Program new MWD - RIH with HWT - Surface test MWD 08:00 - 11:00 3.00 DRILL N HMAN INT1 Con't RIH - Lay down 12 bent jts 4" DP - Wash to bottom from 4810' to 4900' 11 :00 - 00:00 13.00 DRILL P INT1 Directional Drill from 4900' to 6608' - WOB 25 - RPM 80 - TO on 10 - off 8.5 - GPM 525 - PP on 3300 - off 3150 - PU 160- Printed: 1011812004 9:57:31 AM ....---- BP . EXPLORATION OperationsSlJmmary Report Page 3 of9 Legal Well Name: MPH-18 Common Well Name: MPH-18 Spud Date: 9/24/2004 Event Name: DRILL+COMPLETE Start: 9/23/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1 0/13/2004 Rig Name: DOYON 14 Rig Number: Date From - T~ I Hours 9/29/2004 11 :00 - 00:00 13.00 DRILL P INT1 SO 90 - ROT 115 9/30/2004 00:00 - 04:30 4.50 DRILL P INT1 Directional Drill from 6608' to 6920' - TD 9 7/8" hole - WOB 25 - RPM 80 - TO on 10 - off 8 - GPM 525 - PP on 3425 - off 3300- I PU 160 - SO 90 - ROT 105 - (Top "NSn Sand 6199' - Top for window of "NS" Lateral 6072' - Top MOAN Sand 6555') 04:30 - 06:00 1 .50 CASE P INT1 CBU 2 X - GPM 525 - PP 3350 - RPM 100 - TO 10k - Flow check - Well static 06:00 - 08:00 2.00 CASE P INT1 Pump out to shoe from 6920' to 45550' - (Ratty from 6800' to 5700') 08:00 - 09:00 1.00 CASE P INT1 10 min flow check - RIH from 4550' to 6920' - Ream last stand down 09:00 - 12:00 3.00 CASE P INT1 CBU 1 X - @ 375 GPM - PP 2900 - RPM 100 - excessive cuttings coming over shakers - CSU 2 X - @ 525 GPM - PP 3360 - RPM 100 12:00 - 13:30 1.50 CASE P INT1 Pump out to shoe from 6920' to 4550' at drlg rate 13:30 - 14:30 1 .00 CASE P INT1 CSU 1 X at shoe - GPM 525 - PP 3000 - RPM 80 - Flow check - Pump dry job 14:30 - 15:30 1.00 CASE P INT1 POH from shoe @ 4550' to HWT @ 715' 15:30 - 18:00 2.50 CASE P INT1 Lay down HWT - SHA 18:00 - 18:30 0.50 CASE P INT1 Pick up Franks fill up tool - Change out bails - Rig up casg equipment 18:30 - 20:00 1 .50 CASE P INT1 Change out top pipe rams to 7 5/8" casing rams - test door seals to 1500 psi 20:00 - 21 :00 1.00 CASE P INT1 Finish rigging up casing tools 21 :00 - 00:00 3.00 CASE P INT1 PJSM - (Running casing) - Pick up float equipment - Check floats - Con't picking up and running 7 5/8" 29.7# L-80 STC-M casing to 2114' 10/1/2004 00:00 - 01 :30 1.50 CASE P INT1 Con't RIH with 7 5/8" casing to 4530' 01 :30 - 02:00 0.50 CASE P INT1 Circ casing volume @ 4530' - 208 bbls @ 6 bpm - PP 02:00 - 04:00 2.00 CASE P INT1 Con't RIH with 7 5/8" casing from 4530' to 6829' - Break circulation - wash last joint down - Make up Landing joint and RIH landing on hanger @ 6909' - PU 250 - SO 100 without pump 04:00 - 04:30 0.50 CASE P INT1 Break and lay down Franks fill up tool - Make up Schlumberger cementing head and lines 04:30 - 06:30 2.00 CASE P INT1 Circulate two casing volumes 635 bbls staging up pump rate from 3 bpm to 6 bpm @ 400 psi - PU 225 - SO 110 with pump - Condition mud for cement job 06:30 - 08:30 2.00 CEMT P INT1 Give to Schlumberger Dowell Pump 5 bbl water Test lines to 3000 psi Pump 25 bbl CW-1oo - 5 bpm @ 160 psi Pump 45 bbls Mud Push mixed at 11 ppg - 3.5 bpm @ 415 psi Drop bottom plug Pump 124.7 bbls - 603.5 sxs - Class "G" cement - Mixed at 15.8 - Yield 1.16 cu/ft sx - 5 bpm @ 580 psi Drop top plug Displace with 322 bbl10 ppg OBM -7.5 bpm @ 750 psi Sump plug with 2000 psi - Hold for 2 mins - Bleed off pressure - Floats holding CI P 08:30 hrs 08:30 - 10:00 1.50 CASE P INT1 Close annular - Pump 20 bbls mud in annulus at 2 bpm @ 880 to 1200 psi - shut down well holding 450 psi - Slowdown Printed: 1011812004 9:57:31 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To ... 10/1/2004 08:30 - 10:00 10:00 - 10:30 10:30 - 11 :30 11 :30 - 14:30 14:30 - 17:00 17:00 - 19:00 19:00 - 20:00 20:00 - 21 :30 21 :30 - 22:00 22:00 - 22:30 22:30 - 00:00 10/2/2004 00:00 - 04:00 04:00 - 05:30 05:30 - 06:00 06:00 - 09:30 09:30 - 11 :00 11 :00 - 11 :30 11 :30 - 12:00 12:00 - 15:30 15:30 - 16:30 16:30 - 00:00 10/3/2004 00:00 - 10:30 10:30 - 12:00 ..... ..... BP EXPLORATION Operations Summary Report MPH-18 MPH-18 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Hours l2"ask Code 1.501 CASE P 0.50 I WHSUR P I NPT Phase . INT1 INT1 1.00 CASE P INT1 3.00 BOPSUF P I I 2.50 ¡CASE P INT1 INT1 2.00 CASE P 1.00 CASE P INT1 INT1 1.50 DRILL P INT1 0.50 CASE P 0.50 EVAL P INT1 INT1 1.50 DRILL P PROD1 4.00 DRILL P PROD1 1.50 DRILL P PROD1 0.50 DRILL P PROD1 3.50 DRILL P 1.50 DRILL P 0.50 DRILL P 0.50 DRILL P PROD1 PROD1 PROD1 PROD1 3.50 DRILL P PROD1 1.00 DRILL P 7.50 DRILL P PROD1 PROD1 10.50 DRILL P PROD1 1.50 CASE P PROD1 Page 4 of 9 ,., .... . . Start: 9/23/2004 Rig Release: 10/13/2004 Rig Number: Spud Date: 9/24/2004 End: .. Description of Operations .,. .... ":' ....... .. circulating lines - Flush stack - Void out landing joint and 7 5/8" casing to 45' Install pack-off - test to 5K - Pump down annulus 17.5 bbls mud at 2 bpm @ 1580 psi - shut down holding 900 psi - Pumped additional 8 bbls at 2 bpm @ 1580 psi - Shut down pressure at 570 Break out and lay down Schlumberger cementing head - Cementing lines - Clear rig floor of casing and cementing tools PJSM - Install test plug - Open annulus valve - Change 7 5/8" casing rams to 2 7/8" X 5" Pipe rams - Test 250 low 3500 high each test 5 mins - Shut annulus valve - Pull test plug - Install wear ring - (Freeze protect 7 5/8" X 10 3/4" annulus with 88 bbls diesel- @ 1.5 bpm 1650 psi - increase to 2 bpm 1850 psi) PJSM - PU Bit / Motor - Make up - MU MWD - Orient - Make up Flex DC's - HWT - Flush pumps - Surface test MWD Con't RIH to 6786' Break circulation - Rig up testing equipment - Test casing to 2500 psi for 30 mins - Record on chart Con't RIH tag float collar @ 6826' - Drill shoe tract to 6909' - Clean out rat hole to 6920' - Drill 20' new hole to 6940' CBU for FIT Rig up for FIT - Perform FIT - MD 6909' - TVD 4180' - Mud weight 9.9 ppg - Surface pressure 550 psi - EMW = 12.43 ppg - Rig down testing equipment - Directional Drill from 6940' to 7003 - WOB 5 ro 10 - RPM 80 - TO on 5 - off 3 - GPM 275 - PP on 2950 - off 28400 - PU 125- SO 88 - ROT 102 Directional Drill from 7003' to 7303' - WOB 20 to 30 - RPM 80 - TO on 4 - off 3 - GPM 275 - PP on 3040 - off 2940 - PU 120- SO 90 - ROT 105 - After sliding 90' and no turn well getting close to drillers poloygon stop and consult with town about IFR corrections Circ - GPM 275 - PP 2910 - RPM 80 - TO 3K - Clean hole while consulting with town on IFR corrections - Circ bottoms up for trip to increase bend on motor to 1.83 degree from 1.5 degree on motor Pump to shoe from 7303' from 7303' to 6890' - Pump at dr1g rate Flow check well - POH to 1100' Cut dr1g line - Service Top Drive Con't POH to BHA Stand back HWT / BHA - Change motor setting from 1.5 degree to 1.76 degree - Change bits PJSM - Rig service - Make up BHA - RIH to stand # 25 - Fill pipe - Test MWD - Con't RIH to 7265' Fill every 25 stands Survey 12 X - Wash to 7303' Directional Drill from 7303' to 7650' - WOB 20 to 30 - RPM 80 - TO on 4.5 - off 3 - GPM 275 - PP on 3200 - off 3030 - PU 120 - SO 85 - ROT 104 Directional Drill from 7650' to 8639' - TD OB Lateral - WOB 5 to 20 - RPM 60 - TO on 5 - off 3.5 - GPM 275 - PP On 3300 - off 3150 - PU 125 - SO 82 - ROT 101 CBU 2 X - GPM 300 - PP 3550 - RPM 60 - TO 4K - Flow check Printed: 1011812004 9:57:31 AM " - .... BP EXPLORATION Page 5 of 9 Operations Summary Report ... : : .: . Legal Well Name: MPH-18 Common Well Name: MPH-18 Spud Date: 9/24/2004 Event Name: DRILL+COMPLETE Start: 9/23/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2004 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Ico~~ NPT I Phase· . ···Dèscriþtiönof Operations :.:..::.. .:.; .... .: ...... .. ! 10/3/2004 10:30 - 12:00 1.50 CASE P , PROD1 - Well static 12:00 - 14:00 2.00 CASE P PROD1 PJSM - Pump out to shoe from 8639' to 6873' - Pump at drlg rate 14:00 - 15:00 1.00 CASE P PROD1 CBU 1 X - GPM 300 - 3200 - RPM 60 - TO 3.5 15:00 - 16:00 1.00 CASE P PROD1 RIH - Taking weight @ 7277' - Make up top drive - Orient pipe- I RIH - No obstruction seen - Con't RIH to 8639' 16:00 - 18:30 2.50 CASE P I PROD1 CBU 4 X - CBU 3 X with GPM 300 - RPM 60 - TO 5 - Very little cuttings coming over shakers - Increase RPM to 85 - TO 5K - I Increase cuttings return 25 to 30% more - Hole clean after 4 CBU - Flow check well - Well static 18:30 - 20:00 1.50 CASE P PROD1 Pump to shoe from 8639' to 6873' - Pump at drlg rate 20:00 - 21 :00 1.00 CASE P PROD1 CBU - GPM 300 - PP 3200 psi - Flow check - Well static- I Pump dry job I 21 :00 - 23:30 2.50 CASE P PROD1 POH - From 6873' to HWT @ 268' 23:30 - 00:00 0.50 CASE P PROD1 Stand back BHA - Lay down MWD - Flush motor - break off bit 10/4/2004 00:00 - 01 :00 1.00 CASE P PROD1 Clear rig floor 01 :00 - 01 :30 0.50 CASE P PROD1 PJSM - Rig up to run 4 /2- slotted liner 01 :30 - 03:30 2.00 CASE P PROD1 PJSM - Pick up and run 45 joints 41/2- slotted liner 12.6# L-80 J - Make up Baker seal bore extension - Baker HMC liner hanger - Baker ZXP liner top packer - PU weight 75K - SO weight 72K 03:30 - 06:30 3.00 CASE P PROD1 RIH with 4 1/2- Slotted liner from 1,957' to 8,639' 06:30 - 07:30 1.00 CASE P PROD1 Break Top Drive connection and drop ball pump same down @ 4 bpm. Once the ball was on seat pressure up to 2200 psi. I Slack off to 60K to verify HMC liner hanger is set. Increase pressure to 4,000 psi. To set the ZXP liner top packer with the pusher tool. Bleed off pressure to zero. - Close the Hydril - Pump down kill line and pressure up annulus to 1500 psi to verify that ZXP liner top packer is set. Bleed off pressure and open Hydril. Pull the liner running tool above the top of the liner tie back sleeve. 07:30 - 08:00 0.50 CASE P PROD1 Circulate bottoms up while reciprocating drill string and liner running tool 9 BPM with 2,100 psi. 08:00 - 10:30 2.50 CASE P PROD1 Monitor well (Static) - POH with liner running tool from top of liner tie back sleeve at 6,680' 10:30 - 11:00 0.50 CASE P PROD1 Service liner running tool and lay down same - Clear rig floor 11 :00 - 12:00 1.00 STWHIP P PROD2 Pick up and RIH with (10) 43/4- Steel Drill Collars and (11) 3 1/2- HWDP To 643' 12:00 - 12:30 0.50 STWHIP P PROD2 POH with HWDP And Steel Drill Collars Standing Back In Mast 12:30 - 14:30 2.00 STWHIP P PROD2 Pick up and RIH with Baker seal assembly, 3 joints of space out drill pipe, un-loader sub, blank sub, double pin cross over, bottom trip anchor, shear disconnect, debris barrier sub, and 7 5/8- whip stock - Pick up Sperry Sun MWD Tools, float sub, 1 joint of 31/2- HWDP, upper mill, lower mill, and starter mill. Attach starter mill to whip stock slide with 35K lug bolt. Orient to whip stock to MWD Tool- RIH with bumper sub, (10) 4 3/4- Steel Drill Collars, and (11) 3 1/2- HWDP To 878' - Surface test MWD Tools 14:30 - 18:00 3.50 STWHIP P PROD2 RIH with whip stock and milling assembly on 4- drill pipe from 878' To 6,628' - Fill drill string every 25 stands 18:00 - 18:30 0.50 STWHIP P PROD2 Break Circulation - Orient and Con't RIH to 6692' - Set whip stock slide 8 to 10 degrees left of high side with Sperry Sun MWD. Set whip stock as per Baker Representative. Set Printed: 10/18/2004 9:57:31 AM ~ . -..-- BP EXPLORATION Operations Summary Report . .. ... .. .:. .. .. Page 6 of 9 Legal Well Name: MPH-18 Common Well Name: MPH-18 Spud Date: 9/24/2004 Event Name: DRILL+COMPLETE Start: 9/23/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2004 Rig Name: DOYON 14 Rig Number: Date From -To Hours Task COd~1 NPT Phase Description of Operations ........ . ... 1 0/4/2004 18:00 - 18:30 0.50 STWHIP P PROD2 bottom trip anchor with 10K additional down weight and verify that whip stock is set by picking up an additional 8K above nOnTIal upward drag. Shear the 35K shear bolt from the milling BHA from the whip stock 18:30 - 22:00 3.50 STWHIP P PROD2 Mill window from 6554' to 6566' - Drill from 6566' to 6580' - (TOW 6554 - BOW 6566') - WOM 0 to 2 milling casing - 4 drilling formation - RPM 80 - GPM 300 - PP 2470 22:00 - 22:30 0.50 STWHIP P PROD2 CBU - Pump hi-vis sweep - Circulate clean up well - Flow check - Well Static 22:30 - 00:00 1.50 STWHIP P PROD2 POH 5 stands checking fill - Pump dry job - Con't POH to milling assy 10/5/2004 00:00 - 01 :00 1.00 STWHIP P PROD2 Con't POH with milling assy 01 :00 - 02:00 1.00 STWHIP P PROD2 Stand back DC's - HWT - Lay down Baker milling assy 02:00 - 03:00 1.00 DRILL P PROD2 Clear rig floor - Pull wear ring - Flush BOP stack - Reinstall wear ring 03:00 - 04:00 1.00 DRILL P PROD2 Pick up Drlg assy for OA Lateral- Surface test MWD @ 275 GPM - PP 1800 psi 04:00 - 06:00 2.00 DRILL P PROD2 RIH with BHA from 269' to 6500' 06:00 - 00:00 18.00 DRILL P PROD2 Orient to high side - Shut down pumps - Slide through window - Directional Drill OA Lateral from 6580 to 8415' - WOB 5 to 10 - RPM 60 - TO on 6 - off 5 - GPM 275 - PP on 3100 - off 2960- PU 145 - SO 65 - ROT 100 1 0/6/2004 00:00 - 02:00 2.00 DRILL P PROD2 Directional Drill from 8415' to 8595' - TD OA Lateral - WOB 5 to 10 - RPM 60 - TO on 6 - off 5 - GPM 275 - PP on 3120 - off 2960 - PU 145 - SO 65 - ROT 100 02:00 - 04:00 2.00 CASE P PROD2 CBU 3 X - GPM 300 - PP 3300 - RPM 90 - TQ 7 04:00 - 06:30 2.50 CASE P PROD2 Pump to shoe at drlg rate from 8595' to 7850' Hole tight - Back ream from 7850' to 6580" - Shut down pump - Pull thru window from 6580' to 6550' 06:30 - 08:00 1.50 CASE P PROD2 Cut drlg line - Rig service - Inspect saver sub 08:00 - 08:30 0.50 CASE P PROD2 RIH from 6550' to 8595' 08:30 - 10:30 2.00 CASE P PROD2 CBU 3 X - RPM 90 TO 5K - GPM 300 - PP 3400 - Flow check - Well static 10:30 - 13:00 2.50 CASE P PROD2 Pump out from 8595' to 6580' - Shut down pump - Pull thru window from 6580' to 6550' 13:00 - 14:00 1.00 CASE P PROD2 CBU 1 X - GPM 275 - PP 2650 - Blow down top drive - Flow check - Well static - Pump dry job 14:00 - 15:30 1.50 CASE P PROD2 Con't POH from 6550' to BHA @ 269' 15:30 - 16:30 1.00 CASE P PROD2 Stand back HWT - DC's - Lay down MWD - Motor - Break Bit - Flush motor 16:30 - 18:00 1.50 CASE P PROD2 Make up Baker Whip stock retrieving tool - BHA - RIH with BHA - Surface test MWD 18:00 - 20:30 2.50 CASE P PROD2 RIH with retrieving assy from 747' to 6500' - Break Circulation - Orient hook - Can't RIH - Engage hook with whip stock - Jar loose - PU 142 - SO 92 - Flow check - Well static 20:30 - 22:00 1.50 CASE P PROD2 CBU 1 X - Pull 3 stands - Over pull 60K to 200K -Slack off to string weight - Make up top drive - Break circulation - Pulled free @ 225k 83k over string weight - Pull 2 more stands with no over pull- checking displacement - Flow Check - Well static - Pump dry job 22:00 - 00:00 2.00 CASE P PROD2 POH with Baker whip stock from 6120' to BHA @ 750' 10n /2004 00:00 - 00:30 0.50 CASE P PROD2 Con't POH to BHA @ 750' 00:30 - 02:00 1.50 CASE P PROD2 Stand back DC's - HWT - Lay down Whip stock - Retrieving Printed: 1011812004 9:57:31 AM '- ",,- -' BP EXPLORA TION Page 7 of 9 Operations Summary Report .. c..> .. c'. . Legal Well Name: MPH-18 Common Well Name: MPH-18 Spud Date: 9/24/2004 Event Name: DRILL+COMPLETE Start: 9/23/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1 0/13/2004 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT I Phase DescriRtigh öfOpetatiöns ---- '.' ........ 'Cc '..: . 1 0/7/2004 00:30 - 02:00 1.50 CASE P PROD2 tool 02:00 - 03:00 1.00 CASE P PROD2 Clear floor - Rig up tubing tools 03:00 - 05:00 2.00 CASE P PROD2 PJSM - Pick up 41/2" slotted liner - Make up Baker hook hanger - Liner PU weight 72K - SO 70K 05:00 - 07:30 2.50 CASE P PROD2 RIH with 4 1/2" Liner to 8540' 07:30 - 09:00 1.50 CASE P PROD2 Hang Hook wall hanger at BOW 6566' - Release anchor and run past BOW to 6576' to ensure anchor was set in window - Pull up and reset hanger on BOW @ 6566' - Drop ball pump ball on seat @ 4 bpm 925 psi - Pressure up to 2250 psi to release from liner - Con't pressure up to 3600 psi to blow setting ball - PU 145 - SO 80 - Bottom of liner set @ 8565 - Top liner set @ 6549.43 09:00 - 09:30 0.50 CASE P PROD2 CBU @ 9 bpm - 2100 psi - Flow check - Pump dry job 09:30 - 11 :30 2.00 CASE P PROD2 POH - Lay down Baker liner running tools 11 :30 - 12:00 0.50 CASE P PROD2 Pick up test joint - Pull wear ring - Open annulus valves - Install test plug - Rig up testing equipment - 12:00 - 16:00 4.00 CASE P PROD2 Test BOP's - Annular 250 low 2500 high 5 mins each test - Pipe rams - Blind rams - Choke manifold - HCR choke / Kill - Manual Choke / Kill - Upper / Lower I BOP - Floor safety valves - 250 low 3500 high 5 mins each test - Accumulator test performed - John Crisp with AOGCC waived witness of BOP test - Rig down testing equipment - Close annulus valves - Pull test plug - Install wear ring 16:00 - 17:30 1.50 CASE P PROD2 PJSM - Rig up tubing tools - PU LEM assy 17:30 - 21 :00 3.50 CASE P PROD2 RIH to 6650' - Con't RIH slowly to 6718' - PU weight 132 - SO 90 - 21 :00 - 22:30 1.50 CASE P PROD2 Sting into seal assy - SO 30K - PU 15K over string weight - LEM latched - Slack off 30K to confirm hook still landed - Break Connection drop 29/32" ball - Pump ball on seat - @ 4 bpm 870 psi - Slow down pump to 2 bpm @ 510 psi - Ball on seat - Presure up to 3300 psi to set ZXP pcker - Con't pressure up to release "GS" running tool - Running tool pressure set for 3800 psi - (Ball sheared out @ 3500 psi) - Bleed off remaining pressure @ 680 psi - Close Pipe rams - Pressure up annulus to test ZXP packer to 2350 psi - Held for 15 mins - good test - Bleed off pressure - Open rams - Pick up to confirm release from assy - PU weight 135 - Released from LEM assy 22:30 - 23:30 1.00 CASE P PROD2 CBU - Row check - Well static - Pump dry job 23:30 - 00:00 0.50 CASE P PROD2 POOH with Baker LEM running tools 10/8/2004 00:00 - 01 :30 1.50 CASE P PROD2 Con't POH with Baker LEM running tool 01 :30 - 02:00 0.50 CASE P PROD2 Lay down LEM running tool 02:00 - 02:30 0.50 STWHIP P PROD3 Mobilize Baker whip stock BHA to rig floor 02:30 - 04:30 2.00 STWHIP P PROD3 Make up Baker whip stock Assy - Orient whipstock with MWD - RIH DC's - HWT - Surface test MWD @ GPM 268 790 psi 04:30 - 06:30 2.00 STWHIP P PROD3 RIH with Baker whipstock from 867' to 6140' 06:30 - 07:30 1.00 STWHIP P PROD3 Orient whipstock 5 degree left - Land dummy seals in liner tie-back sleave - Set whipstock anchor with 17K down weight - Pick up 10K over string weight to insure anchor is set - Shear mill off whipstock with 35K down weight - PU 130 - SO 88 07:30 - 11 :30 4.00 STWHIP P PROD3 Mill NB Window - TOW 6072 - BOW 6084 - TD 6098' - Full gauge hole to 6090' - WOM 2 to 4 milling window - Drlg formation 5 - RPM 95 - 100 - GPM 300 - PP 2250 - Retrieving slot @ 6077' (5 degree left) Printed: 10/1812004 9:57:31 AM '-c ... ~ BP EXPLORATION Page 8 of 9 Operations Summary Report .... Legal Well Name: MPH-18 Common Well Name: MPH-18 Spud Date: 9/24/2004 Event Name: DRILL+COMPLETE Start: 9/23/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1 0/13/2004 Rig Name: DOYON 14 Rig Number: Date From-To Hours Task Code NPT I Phase Description <öfOperatiöns . .. .. .. . . 10/8/2004 11 :30 - 12:30 1.00 STWHIP P PROD3 CBU - Pump sweep surface to surface - RPM 90 - TO 4 - GPM 300 - PP 2030 psi - Work mills through window while pumping sweep 12:30 - 14:00 1.50 STWHIP P PROD3 Flow check - Well static - Pump dry job - POH to from 6050 to 750' 14:00 - 15:00 1.00 STWHIP P PROD3 Stand back DC's - HWT - Lay down MWD, 1 joint 31/2-, Mills, Upper mill in gauge 15:00 - 15:30 0.50 STWHIP P PROD3 Clear rig floor of milling tools 15:30 - 16:00 0.50 STWHIP P PROD3 Flush stack - Activate rams - Flush stack 16:00 - 17:30 1.50 DRILL P PROD3 BHA - Make up bit to motor - (Motor set 1.76 degree) - MWD- Orient - RIH with Flex DC's - Jars - HWT - Surface test MWD - 17:30 - 20:00 2.50 DRILL P PROD3 RIH from 270' to 6020' - Fill pipe @ 2666', 5062' 20:00 - 21 :30 1.50 DRILL P PROD3 PJSM - Cut Dr/g Line - Rig service - Inspect saver sub 21 :30 - 22:00 0.50 DRILL P PROD3 Orient to 5 degree to left of high side - Slide thru window at 6072' - No pump or rotating 22:00 - 00:00 2.00 DRILL P PROD3 Directional Drill from 6098' to 6305' - WOB 5 to 10 - RPM 80 - TO on 5 - off 4 - GPM 254 - PP on 2400 - off 2300 - PU 130- SO 90 - ROT - 105 10/9/2004 00:00 - 00:00 24.00 DRILL P PROD3 Directional Drill from 6305' to 8630' - TD NB Lateral - WOB 3 to 4 - RPM 80 - TO on 5.5K - off 4.5K - GPM 254 - PP on 2500 - off 2410 - PU 140 - SO 60 - ROT 100 10/10/2004 00:00 - 02:30 2.50 CASE P PROD3 CBU 4 X - GPM 300 - PP 3050 - RPM 90 - TO 6.5 02:30 - 05:00 2.50 CASE P PROD3 Pump to shoe @ drlg rate - Tight - Packing off @ 6320' to 6107' - Pull from 6107' to 6012' thru window without pump or rotating 05:00 - 06:00 1.00 CASE P PROD3 CBU 2 X - GPM 300 - PP 2750 - RPM 40 - TO 4 06:00 - 07:00 1.00 CASE P PROD3 RIH from 6012' to 8630' 07:00 - 09:30 2.50 CASE P PROD3 CBU 4 X - RPM 90 - TO 5K - GPM 300 - PP 3200 09:30 - 11 :30 2.00 CASE P PROD3 Pump to shoe @ drlg rate - from 8630' to 6107' - Pull from 6107' to 6012' thru window without pump or rotating 11 :30 - 12:00 0.50 CASE P PROD3 CBU - GPM 300 - PP 2820 - RPM 40 - TO 3 12:00 - 12:30 0.50 CASE P PROD3 Flow Check - Well static - Pump dry job - Blow down top drive 12:30 - 14:30 2.00 CASE P PROD3 POH from 6019' to 270' 14:30 - 15:30 1.00 CASE P PROD3 Stand back 31/2" HWT / Jars - LD 4 3/4- flex DC's - MWD- Break bit - Flush motor - LD motor 15:30 . 17:30 2.00 CASE P PROD3 MU Baker WS retrieving tool assy - Orient MWD to hook - RIH 31/2" HWT / 43/4" DC's from derrick - Surface test MWD 17:30 - 19:30 2.00 CASE P PROD3 RIH from 750' to 6020' - Fill pipe @ 3142',6020' 19:30 - 20:00 0.50 CASE P PROD3 Break Circulation - Orient hook - RIH from 6020' to 6084'- Latch onto Whipstock - Jar - (PU 132K - SO 92K) - Pull free 230K - 93K over string weight - 20:00 - 21 :00 1.00 CASE P PROD3 CBU - GPM 254 - PP 1800 - Flow check - Well static - Pull 5 stands from 6040' to 5634' - Check displacement - Pump dry job 21:00 - 00:00 3.00 CASE P PROD3 POH from 5634' to 1322' 10/11/2004 00:00 - 00:30 0.50 CASE P PROD3 Con't POH from 1322' to 750' @ BHA 00:30 - 02:00 1.50 CASE P PROD3 BHA - Stand back 31/2- HWT - 4 3/4- DC's - LD MWD- Whipstock - WS retrieving tools 02:00 - 02:30 0.50 CASE P PROD3 Clear floor of all tools 02:30 - 03:00 0.50 CASE P PROD3 RU tubing running tools 03:00 - 07:30 4.50 CASE P PROD3 PJSM - PU 4" Baker Excluder Screen Liner - Make up Baker Hook Wall Hanger 07:30 - 10:00 2.50 CASE P PROD3 Run liner to 8596' - PU 140 - SO 75 Printed: 1011812004 9:57:31 AM '" ' '--' Page 90f9 BP EXPLORATION Operations Summary Report Legal Well Name: MPH-18 Common Well Name: MPH-18 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date l_~~~~_- To I Hours Task Code NPT 10/11/2004 . 10:00 - 11 :00 1.00 CASE P I I 111 :00 - 11 :30 11 :30 - 12:00 12:00 - 12:30 12:30 - 14:30 114:30 - 15:00 15:00 - 15:30 i 15:30 - 20:00 20:00 - 20:30 20:30 - 23:30 1 0/12/2004 23:30 - 00:00 00:00 - 00:30 00:30 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 08:00 10/13/2004 08:00 - 23:00 23:00 - 00:00 00:00 - 01 :00 01 :00 - 03:30 03:30 - 13:00 13:00 - 13:30 13:30 - 14:00 14:00 - 15:30 15:30 - 19:00 19:00 - 20:00 0.50 CASE 0.50 CASE 0.50 CASE 2.00 CASE 0.50 CASE 0.50 CASE 4.50 CASE 0.50 CASE 3.00 CASE 0.50 CASE 0.50 CASE 1.50 CASE 1.00 CASE 1.00 CASE 4.00 CASE 15.00 CASE 1.00 CASE 1.00 RUNCO 2.50 RUNCO 9.50 RUNCO 0.50 RUNCO 0.50 RUNCO 1.50 RUNCO 3.50 RUNCO 1.00 RUNCO P P P P P P P P P P P P P P P PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 Start: 9/23/2004 Rig Release: 10/13/2004 Rig Number: Spud Date: 9/24/2004 End: Hang hook in BOW @ 6084' - Pick up release from BOW - Run in hole to 6094' to insure hook was set in BOW - Pick up and reset hook in BOW @ 6084' - Drop ball - Pump down with 4 bpm for 44 bbls @ 840 psi - 2 bpm for 6 bbls @ 420 psi - .5 bpm for 4.5 bbls 200 psi ball on seat - Pressure up to 3K to release liner - Con't pressure up to 4K to blowout ball - Liner shoe @ 8596' Liner top @ 6067' - PU 120 - SO 75 CBU - 6 bpm @ 900 psi Flow check - Dry job - POH Rig service - Top drive service - Crown Service - Traveling blocks Service POOH from 5368' to running tool- Change out to 3 1/2M handling equipment - service break tool RU 4 1/2M tubing equipment - PJSM (on running LEM) MU LEM # 2 Assy - RD 4 1/2M tubing equipment RIH from 197' to 6215' - PU 120K - SO 92K - Work LEM through hook wall hanger @ 6067 - Latch LEM with 35K SO weight - PU to 130 10K over string weight to confirm latched up - Drop ball - Pump down - 49 bbls at 4 bpm 800 psi - 2.8 bbls At .5 bpm 11 0 psi - Ball on seat - Pressure up to 3000 psi to set ZXP packer hold for 2 mins - Con't Pressure up to 4000 to release from hanger hold for 1 min - Close rams - Test Annulus to 2500 psi for 15 mins - Good test - Bleed off pressure - Open rams - PU to 6043' Confirmed off hanger CBU - GPM 250 - PP 1130 - Flow check - Well static POH from 6043' to Baker running tool - Service break tool - LD tools Clear rig floor of all tools MU BHA RIH to 6013' Cut Drlg Line - Rig Service Break Circulation - PJSM - (Displacement of OBM) - Displace to Brine - Pump 20 bbls L VT - Pump 30 bbls Brine DuoVis Spacer - 15 bbls Safe Surfo Spacer - 10 bbls Brine DuoVis Spacer - 10.2 ppg Brine - RPM 90 - TQ 3K - GPM 335 - PP 2100 Stand back 7 stands in derrick for total of 40 stands - Lay down remaining 4 M DP - Repairing pipe skate Laying down Drill pipe Pull wear ring, PJSM on running tubing, Rig up to run tubing picking up ESP assembly, rig up spool unit, attach cable and test Picking up 2 7/8 tubing, test conductivity and circ tubing ever 2,000 ft, centralizer 5935, pump 5876.90, XN nipple 5823, GLM 5672,2136,149', total of 183 jts of 2 7/8 6.5# L-80 Land hanger test 2-way check 2,500 psi, lay down centrilift eqp. Nipple down BOPS Nipple up 11' x 2 7/8 adapter and 2 9/16 CIW tree, test both to 5,000 psi for 10 min. Install BPV, Secure well, rig release for rig move @ 2000 hrs 10/13/ 2004 N P RREP PROD3 PROD3 RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP Printed: 10/1812004 9:57:31 AM Legal Name: MPH-18 Common Name: MPH-18 ·"esfDšte 9/28/2004 1 0/1/2004 .. Test Depth (TMD) 4,561.0 (ft) 6,909.0 (ft) FIT FIT BP EXPLORATION leak-Off Test Summary Test Depth (TVD) 3,177.0 (ft) 4,180.0 (ft) AMW 10.00 (ppg) 9.90 (ppg) Surface Pressure 400 (psi) 550 (psi) Page 1 of 1 Leak Off Pressure (BHP) 2,050 (psi) 2,700 (psi) EMW 12.42 (ppg) 12.43 (ppg) Printed: 10/18/2004 9:57:26 AM WELL SERVICE REPORT WELL JOB SCOPE UNIT MPH-18 NEW WELL POST LRS 40 DATE DAILY WORK DAY SUPV 10/13/2004 FREEZE PROT O'MALLEY AFE KEY PERSON NIGHT SUPV MSD337409 LRS - WILSON O'MALLEY MIN ID I DEPTH TIL SIZE 0" OFT 0" '- ~ DAILY SUMMARY [Freeze protect] Pumped 15 bbls crude, 1 bbl diesel down tubing. Pumped 65 bbls crude, 2 bbls diesel down IA to freeze protect well. Initial WHP=O, 0, no gauge. Final WHP=400, 600, no au e. Init-> 0 0 0 TIME BPM -- BBLs FLUID TEMP TBG IA OA COMMENTS -". --------- DisoatchedJload fluids 20:35 21:48 AOURiQ up 22:08 Diesel 3500 PT Lines 22:12 1.0 0 crude 110 1400 Start down tubinQ 22:28 swap 15 II 1850 swao to diesel 22:29 shut 1 diesel 800 shut down, ru to ia down 22:40 1 start II II 400 start oumpina down ia 23:01 1.5 30 980 23:25 swap 65 II II 1000 swap to diesel 23:27 shut 2 diesel 1000 shut down, rdmo down Final-> 400 600 0 FLUID SUMMARY 80 bbls crude. 3 bbls from revious load. SERVICE COMPANY - SERVICE DAILY COST CUMULTOTAL BP $0 $0 LITTLE RED $823 $823 FESCO $0 $390 WAREHOUSE $0 $1,600 TOTAL FIELD ESTIMATE: $823 $2,813 '- '-" o 1-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPH-18 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,639.00' MD 0.00' MD 0.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 /J 1 J ) / j I Date q ¡1J~u)J-t~ Signed .~ 1JjJ/t;vJ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ÅÓ r.{-- /7~1 Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPH MPH-18 (' Job No. AKZZ3302792, Surveyed: 3 October, 2004 Survey Report 25 October, 2004 Your Ref: API 500292322400 Surface Coordinates: 6010178.19 N, 556657.51 E (70026' 18.4369" N, 149032' 16.8646" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ( Surface Coordinates relative to Project H Reference: 1010178.19 N, 56657.51 E (Grid) Surface Coordinates relative to Structure Reference: 1196.73 N, 1261.73 E (True) Kelly Bushing Elevation: 69.60ft above Mean Sea Level Kelly Bushing Elevation: 69.60ft above Project V Reference Kelly Bushing Elevation: 69. 60ft above Structure Reference SP:E!'r--"-'Y-,SU:1! i5Fni:1:TNG"-Se'R-vTEë"'s A Halliburton Company Survey Ref: svy1464 Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18 Your Ref: API 500292322400 Job No. AKZZ3302792, Surveyed: 3 October, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 0.00 0.000 0.000 -69.60 0.00 0.00 N 0.00 E 6010178.19 N 556657.51 E 0.00 CB-SS-GYRO 114.00 0.000 0.000 44.40 114.00 0.00 N 0.00 E 6010178.19 N 556657.51 E 0.000 0.00 169.00 0.650 125.000 99.40 169.00 0.18 S 0.26 E 6010178.01 N 556657.77 E 1.182 -0.31 260.00 0.600 140.000 190.39 259.99 0.84 S 0.98 E 6010177.36 N 556658.50 E 0.187 -1.29 350.00 0.800 107.000 280.39 349.99 1.38 S 1.89 E 6010176.82 N 556659.41 E 0.490 -2.30 (" 442.00 1.300 91.000 372.37 441.97 1.59 S 3.55 E 6010176.63 N 556661.07 E 0.625 -3.58 534.00 1.500 60.000 464.35 533.95 1.01 S 5.63 E 6010177.23 N 556663.15 E 0.840 -4.58 MWD+IIFR+MS 560.04 1.600 46.410 490.38 559.98 0.59 S 6.19 E 6010177.65 N 556663.71 E 1 .459 -4.65 650.25 3.480 7.460 580.50 650.10 3.00 N 7.46 E 6010181.24 N 556664.95 E 2.717 -2.89 747.95 5.630 0.290 677.89 747.49 10.73 N 7.87 E 6010188.98 N 556665.30 E 2.272 2.48 845.99 7.770 348.640 775.25 844.85 22.04 N 6.59 E 6010200.28 N 556663.93 E 2.575 11.63 942.31 11.730 336.580 870.17 939.77 37.42 N 1.41E 6010215.61 N 556658.64 E 4.604 26.40 1038.61 16.350 327.740 963.58 1033.18 57.87 N 9.72W 6010235.99 N 556647.35 E 5.276 48.96 1133.05 18.140 324.840 1053.78 1123.38 81.14 N 25.29 W 6010259.13 N 556631.61 E 2.102 76.58 1229.41 17.370 319.050 1145.55 1215.15 104.26 N 43.35 W 6010282.12 N 556613.37 E 1.998 105.82 1325.57 20.940 321.690 1236.37 1305.97 128.60 N 63.42 W 6010306.30 N 556593.12 E 3.819 137.30 1420.76 22.230 322.060 1324.89 1394.49 156.15 N 85.04 W 6010333.69 N 556571.29 E 1.363 172.19 1517.16 21.470 320.250 1414.36 1483.96 184.09 N 107.53 W 6010361.46 N 556548.59 E 1.053 207.97 1612.18 23.510 318.540 1502.15 1571.75 211.67 N 131.20 W 6010388.86 N 556524.71 E 2.254 244.28 1706.91 26.670 317.710 1587.93 1657.53 241.56 N 158.02 W 6010418.55 N 556497.66 E 3.356 284.44 1804.05 30.820 317.630 1673.08 1742.68 276.09 N 189.47 W 6010452.83 N 556465.94 E 4.272 331 .14 ( 1898.27 32.220 318.620 1753.40 1823.00 312.77 N 222.35 W 6010489.26 N 556432.79 E 1.584 380.39 1994.80 34.050 318.750 1834.23 1903.83 352.40 N 257.18 W 6010528.63 N 556397.66 E 1.897 433.13 2090.65 37.330 319.010 1912.07 1981.67 394.52 N 293.94 W 6010570.47 N 556360.58 E 3.426 489.01 2186.02 42.130 319.450 1985.39 2054.99 440.68 N 333.73 W 6010616.33 N 556320.44 E 5.042 549.90 2282.27 47.120 320.330 2053.87 2123.47 492.39 N 377.26 W 6010667.70 N 556276.52 E 5.224 617.40 2378.70 50.580 321.830 2117.32 2186.92 548.89 N 422.85 W 6010723.85 N 556230.51 E 3.774 689.81 2466.02 55.680 323.080 2169.70 2239.30 604.27 N 465.38 W 6010778.91 N 556187.55 E 5.952 759.32 2563.51 60.240 322.800 2221 .40 2291.00 670.20 N 515.17W 6010844.45 N 556137.26 E 4.684 841.50 2663.20 61 .730 323.070 2269.76 2339.36 739.76 N 567.71 W 6010913.62 N 556084.19 E 1.513 928.21 2762.10 61 .440 323.510 2316.82 2386.42 809.49 N 619.71 W 6010982.95 N 556031.67 E 0.489 1014.67 2857.85 62.830 323.650 2361.57 2431.17 877.61 N 669.96 W 6011050.68 N 555980.90 E 1 .457 1098.76 2954.36 63.380 321.070 2405.23 2474.83 945.75 N 722.53 W 6011118.43 N 555927.82 E 2.451 1184.44 3050.89 62.930 320.730 2448.82 2518.42 1012.59 N 776.84 W 6011184.85 N 555873.00 E 0.562 1270.37 3147.01 63.870 321 .1 00 2491.86 2561 .46 1079.30 N 831.03 W 6011251.15N 555818.31 E 1.037 1356.11 25 October, 2004 - 13:07 Page2of6 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18 Your Ref: API 500292322400 Job No. AKZZ3302792, Surveyed: 3 October, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3242.98 63.260 321.620 2534.58 2604.18 1146.42 N 884.69 W 6011317.86 N 555764.14 E 0.800 1441.80 3338.99 62.690 321.360 2578.21 2647.81 1213.35 N 937.94 W 6011384.38 N 555710.38 E 0.641 1527.06 3433.62 62.420 321.810 2621.82 2691.42 1279.15 N 990.12 W 6011449.78 N 555657.70 E 0.509 1610.77 3530.56 63.020 322.970 2666.26 2735.86 1347.40 N 1042.70 W 6011517.63 N 555604.60 E 1.231 1696.55 3626.52 62.660 323.590 2710.06 2779.66 1415.84N 1093.75 W 6011585.68 N 555553.04 E 0.686 1781.41 3722.53 62.350 323.600 2754.39 2823.99 1484.38 N 1144.29 W 6011653.84 N 555501.97 E 0.323 1866.01 3817.40 63.790 323.180 2797.35 2866.95 1552.27 N 1194.74 W 6011721.34 N 555451.02 E 1.568 1950.07 3913.62 64.020 323.820 2839.68 2909.28 1621.74 N 1246.13 W 6011790.41 N 555399.09 E 0.643 2035.93 4009.88 63.820 323.600 2881.99 2951.59 1691.43N 1297.31 W 6011859.71 N 555347.39 E 0.292 2121.79 4105.14 63.390 323.520 2924.34 2993.94 1760.07 N 1347.99 W 6011927.97 N 555296.19 E 0.458 2206.56 4201.08 63.070 323.290 2967.55 3037.15 1828.84 N 1399.06 W 6011996.35 N 555244.60 E 0.396 2291.68 4296.14 63.680 321.870 3010.16 3079.76 1896.33 N 1450.69 W 6012063.44 N 555192.45 E 1 .482 2376.26 4392.32 63.560 322.490 3052.89 3122.49 1964.39 N 1503.53 W 6012131.10 N 555139.10 E 0.591 2462.07 4487.93 63.100 322.010 3095.81 3165.41 2031.95 N 1555.83 W 6012198.26 N 555086.28 E 0.658 2547.15 4513.94 63.300 322.190 3107.53 3177.13 2050.27 N 1570.09 W 6012216.47 N 555071.88 E 0.986 2570.27 4577.81 62.700 321 .450 3136.53 3206.13 2095.00 N 1605.27 W 6012260.94 N 555036.37 E 1.396 2626.98 4673.89 62.970 320.910 3180.40 3250.00 2161.60 N 1658.86 W 6012327.13 N 554982.28 E 0.574 2712.23 4769.64 62.630 319.960 3224.16 3293.76 2227.25 N 1713.10 W 6012392.36 N 554927.54 E 0.951 2797.24 4866.25 63.120 317.230 3268.22 3337.82 2291.73 N 1769.96 W 6012456.41 N 554870.19 E 2.566 2883.18 4961.79 62.650 315.580 3311.77 3381.37 2353.32 N 1828.60 W 6012517.55 N 554811.09 E 1.614 2968.21 5058.74 62.830 314.970 3356.17 3425.77 2414.55 N 1889.24 W 6012578.32 N 554749.97 E 0.589 3054.35 ( 5154.91 63.420 312.060 3399.65 3469.25 2473.60 N 1951.45 W 6012636.90 N 554687.32 E 2.768 3139.96 5250.48 63.580 310.950 3442.30 3511.90 2530.28 N 2015.50 W 6012693.09 N 554622.84 E 1.053 3225.10 5347.07 62.000 308.170 3486.47 3556.07 2584.99 N 2081.70 W 6012747.29 N 554556.23 E 3.038 3310.26 5441.30 62.770 304.480 3530.16 3599.76 2634.43 N 2148.96 W 6012796.22 N 554488.59 E 3.565 3392.29 5537.20 62.150 300.170 3574.52 3644.12 2679.89 N 2220.79 W 6012841 .13 N 554416.42 E 4.037 3474.52 5633.68 61.570 294.450 3620.05 3689.65 2718.91 N 2296.33 W 6012879.58 N 554340.59 E 5.262 3554.58 5729.95 62.560 290.630 3665.16 3734.76 2751.50 N 2374.87 W 6012911.56 N 554261.80 E 3.653 3631.97 5825.75 61.580 287.330 3710.04 3779.64 2779.03 N 2454.89 W 6012938.49 N 554181 .58 E 3.211 3706.68 5922.06 60.650 286.410 3756.56 3826.16 2803.50 N 2535.59 W 6012962.35 N 554100.70 E 1.277 3779.62 6017.09 60.120 284.760 3803.53 3873.13 2825.70 N 2615.16 W 6012983.94 N 554020.96 E 1.609 3850.12 6113.08 61.250 283..140 3850.53 3920.13 2845.87 N 2696.38 W 6013003.49 N 553939.58 E 1.884 3920.27 6207.91 61.070 282.090 3896.27 3965.87 2864.01 N 2777.44 W 6013021.02 N 553858.39 E 0.988 3988.82 6302.77 61.100 281.360 3942.14 4011.74 2880.89 N 2858.75 W 6013037.27 N 553776.96 E 0.674 4056.61 6398.37 66.050 279.880 3984.67 4054.27 2896.64 N 2942.87 W 6013052.38 N 553692.72 E 5.360 4125.49 25 October, 2004 - 13:07 Page 3 of 6 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18 Your Ref: API 500292322400 Job No. AKZZ3302792, Surveyed: 3 October, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6494.92 73.750 280.710 4017.83 4087.43 2912.84 N 3032.00 W 6013067.91 N 553603.46 E 8.016 4198.14 6544.28 75.210 281.970 4031.03 4100.63 2922.20 N 3078.63 W 6013076.91 N 553556.76 E 3.847 4236.78 6589.73 75.530 283.820 4042.51 4112.11 2932.01 N 3121.50W 6013086.40 N 553513.82 E 4.001 4273.19 6638.13 75.530 283.710 4054.61 4124.21 2943.16 N 3167.02 W 6013097.20 N 553468.22 E 0.220 4312.39 6684.47 76.490 284.880 4065.81 4135.41 2954.26 N 3210.59 W 6013107.98 N 553424.57 E 3.208 4350.23 (' 6733.04 76.740 284.090 4077.05 4146.65 2966.08 N 3256.34 W 6013119.45 N 553378.73 E 1.664 4390.07 6780.29 77.240 284.210 4087.69 4157.29 2977.34 N 3300.98 W 6013130.36 N 553334.01 E 1.087 4428.75 6830.18 79.520 283.580 4097.74 4167.34 2989.07 N 3348.41 W 6013141.73 N 553286.48 E 4.734 4469.68 6855.69 80.580 284.710 4102.15 4171.75 2995.21 N 3372.78 W 6013147.69 N 553262.07 E 6.025 4490.79 6906.84 81 .140 284.710 4110.27 4179.87 3008.03 N 3421.62 W 60131 60.14 N 553213.13 E 1.095 4533.48 6960.27 85.550 282.970 4116.46 4186.06 3020.72 N 3473.14 W 6013172.44 N 553161.52 E 8.865 4577.89 7003.03 89.880 283.560 4118.17 4187.77 3030.52 N 3514.71 W 6013181.92 N 553119.87 E 10.220 4613.41 7052.99 93.020 284.720 4116.90 4186.50 3042.72 N 3563.14 W 6013193.75 N 553071.36 E 6.700 4655.36 7098.60 92.340 286.590 4114.77 4184.37 3055.02 N 3607.00 W 6013205.71 N 553027.40 E 4.358 4694.27 7147.35 91.910 287.180 4112.96 4182.56 3069.17 N 3653.62 W 6013219.51 N 552980.68 E 1 .497 4736.41 7208.48 89.440 290.750 4112.24 4181.84 3089.03 N 3711.41 W 6013238.93 N 552922.73 E 7.101 4790.35 7231.84 88.460 291.150 4112.67 4182.27 3097.38 N 3733.23 W 6013247.11 N 552900.86 E 4.531 4811.33 7290.60 87.780 297.830 4114.60 4184.20 3121.71 N 3786.64 W 6013271.04 N 552847.26 E 11.421 4865.56 7352.32 89.630 309.120 4116.00 4185.60 3155.69N 3838.02 W 6013304.63 N 552795.62 E 18.531 4925.45 7386.42 91 .730 313.840 4115.60 4185.20 3178.26 N 3863.56 W 6013327.01 N 552769.91 E 15.148 4959.38 7419.79 87.900 318.920 4115.70 4185.30 3202.41 N 3886.57 W 6013350.98 N 552746.72 E 19.063 4992.73 7482.82 87.960 324.960 4117.98 4187.58 3251.98 N 3925.38 W 6013400.25 N 552707.53 E 9.577 5055.45 ( 7532.49 90.740 331.910 4118.55 4188.15 3294.27 N 3951.36 W 6013442.34 N 552681.23 E 15.068 5104.10 7578.43 92.410 339.980 4117.28 4186.88 3336.17 N 3970.07 W 6013484.10 N 552662.21 E 17.931 5147.50 7626.85 92.280 348.390 4115.30 4184.90 3382.67 N 3983.24 W 6013530.50 N 552648.69 E 17.356 5190.49 7674.81 89.380 354.330 4114.60 4184.20 3430.06 N 3990.44 W 6013577.83 N 552641 .13 E 13.780 5230.06 7722.01 89.440 359.630 4115.09 4184.69 3477.17 N 3992.92 W 6013624.93 N 552638.28 E 11.229 5266.21 7770.25 88.020 2.450 4116.16 4185.76 3525.39 N 3992.05 W 6013673.15 N 552638.79 E 6.544 5300.88 7818.02 87.470 2.960 4118.04 4187.64 3573.07 N 3989.80 W 6013720.84 N 552640.68 E 1.570 5334.21 7865.82 89.320 3.620 4119.38 4188.98 3620.77 N 3987.05 W 6013768.56 N 552643.06 E 4.109 5367.23 7915.05 91.420 5.650 4119.06 4188.66 3669.83 N 3983.08 W 6013817.65 N 552646.67 E 5.933 5400.40 7961.93 89.810 1.820 4118.55 4188.15 3716.60 N 3980.02 W 6013864.44 N 552649.36 E 8.862 5432.52 8010.02 89.440 0.180 4118.87 4188.47 3764.68 N 3979.18 W 6013912.53 N 552649.84 E 3.496 5467.11 8058.36 89.140 359.000 4119.47 4189.07 3813.01 N 3979.53 W 6013960.86 N 552649.12 E 2.519 5502.69 8107.60 89.200 358.210 4120.18 4189.78 3862.23 N 3980.73 W 6014010.07 N 552647.55 E 1.609 5539.51 25 October, 2004 - 13:07 Page 4 of 6 DrillQuest 3.03.06.006 DrillQuest 3.03.06.006 Page 5 of 6 25 October, 2004 - 13:07 ( Based upon Minimum Curvature type calculations, at a Measured Depth of 8639.00ft., The Bottom Hole Displacement is 5949.46ft., in the Direction of 317.548° (True). The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 317.000° (True). All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18 Your Ref: AP/500292322400 Job No. AKZZ3302792, Surveyed: 3 October, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 8153.34 91.730 358.840 4119.81 4189.41 3907.95 N 3981.91 W 6014055.78 N 552646.03 E 5.700 5573.75 8195.64 92.100 358.240 4118.40 4188.00 3950.21 N 3982.98 W 6014098.03 N 552644.63 E 1.666 5605.39 8249.77 89.810 356.980 4117.49 4187.09 4004.28 N 3985.24 W 6014152.08 N 552641.96 E 4.828 5646.48 8296.75 87.590 356.610 4118.56 4188.16 4051.18 N 3987.87 W 6014198.95 N 552638.98 E 4.791 5682.56 8345.53 87.840 356.820 4120.50 4190.10 4099.84 N 3990.66 W 6014247.59 N 552635.82 E 0.669 5720.05 ( 8392.27 86.290 356.450 4122.90 4192.50 4146.43 N 3993.40 W 6014294.16 N 552632.72 E 3.409 5756.00 8441.24 82.380 355.920 4127.73 4197.33 4195.05 N 3996.64 W 6014342.75 N 552629.11 E 8.057 5793.76 8489.78 81.960 354.830 4134.34 4203.94 4242.98 N 4000.52 W 6014390.65 N 552624.87 E 2.387 5831 .46 8537.43 81.080 353.990 4141.37 4210.97 4289.88 N 4005.11 W 6014437.52 N 552619.93 E 2.540 5868.90 8567.94 81.570 353.930 4145.97 4215.57 4319.87 N 4008.28 W 6014467.49 N 552616.52 E 1.618 5893.00 8639.00 81.570 353.930 4156.39 4225.99 . 4389.77 N 4015.71 W 6014537.33 N 552608.56 E 0.000 5949.19 Tie On Point Milne Point Unit Comments Measured Depth (ft) 8639.00 4225.99 Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18 Your Ref: API 500292322400 Job No. AKZZ3302792, Surveyed: 3 October, 2004 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 4389.77 N 4015.71 W Tie On Point Survey tool program for MPH-18 Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 534.00 0.00 533.95 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 534.00 8639.00 533.95 CB-SS-GYRO 4225.99 MWD+IIFR+MS (' 25 October, 2004 - 13:07 Page 6 of 6 DrillQuest 3.03.06.006 ~-""'" -' 01-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPH-18 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 8,639.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date~nv ~V\ Signed ~1 ðLW Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Su rvey Manager Attachment(s) Ä~<1-/7Y Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPH MPH-18 (mwd) ( Job No. AKMW3302792, Surveyed: 3 October, 2004 Survey Report 25 October, 2004 Your Ref: API 500292322400 Surface Coordinates: 6010178.19 N, 556657.51 E (70026' 18.4369" N, 149032' 16.8646" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ( Surface Coordinates relative to Project H Reference: 1010178.19 N, 56657.51 E (Grid) Surface Coordinates relative to Structure Reference: 1196.73 N, 1261.73 E (True) Kelly Bushing Elevation: 69.60ft above Mean Sea Level Kelly Bushing Elevation: 69.60ft above Project V Reference Kelly Bushing Elevation: 69. 60ft above Structure Reference SP:Ear"""'V-5Uil'l b R ILL I Ñ"G-SEÃ'VTE'"Ë§ A Halliburton Company Survey Ref: svy1484 Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18 (mwd) Your Ref: API 500292322400 Job No. AKMW3302792, Surveyed: 3 October, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -69.60 0.00 0.00 N 0.00 E 6010178.19 N 556657.51 E 0.00 CB-SS-GYRO 114.00 0.000 0.000 44.40 114.00 0.00 N 0.00 E 6010178.19 N 556657.51 E 0.000 0.00 169.00 0.650 125.000 99.40 169.00 0.18 S 0.26 E 6010178.01 N 556657.77 E 1.182 -0.31 260.00 0.600 140.000 190.39 259.99 0.84 S 0.98 E 6010177.36 N 556658.50 E 0.187 -1.29 350.00 0.800 107.000 280.39 349.99 1.38 S 1.89 E 6010176.82 N 556659.41 E 0.490 -2.30 ( 442.00 1.300 91.000 372.37 441.97 1.59 S 3.55 E 6010176.63 N 556661.07 E 0.625 -3.58 534.00 1.500 60.000 464.35 533.95 1.01 S 5.63 E 6010177.23 N 556663.15 E 0.840 -4.58 MWD Magnetic 560.04 1.600 46.640 490.38 559.98 0.59 S 6.19 E 6010177.65 N 556663.71 E 1 .436 -4.65 650.25 3.480 7.700 580.50 650.10 2.99 N 7.47 E 6010181.24 N 556664.96 E 2.717 -2.91 747.95 5.630 0.530 677.89 747.49 10.72 N 7.92 E 6010188.97 N 556665.34 E 2.272 2.44 845.99 7.770 348.950 775.25 844.85 22.04 N 6.69 E 6010200.28 N 556664.03 E 2.571 11.56 942.31 11 .730 336.850 870.17 939.77 37.44 N 1.59 E 6010215.64 N 556658.82 E 4.607 26.30 1038.61 16.350 327.940 963.58 1033.18 57.94 N 9.46 W 6010236.06 N 556647.61 E 5.283 48.83 1133.05 18.140 324.610 1053.78 1123.38 81.19 N 25.03 W 6010259.19 N 556631.86 E 2.164 76.45 1229.41 17.370 319.350 1145.55 1215.15 104.34 N 43.09 W 6010282.20 N 556613.63 E 1.846 105.69 1325.57 20.940 321.800 1236.37 1305.97 128.74 N 63.07 W 6010306.45 N 556593.46 E 3.805 137.17 1420.76 22.230 322.280 1324.89 1394.49 156.35 N 84.61 W 6010333.89 N 556571.71 E 1.368 172.05 1517.16 21.470 320.440 1414.36 1483.96 184.38 N 107.00 W 6010361.75 N 556549.11 E 1.061 207.82 1612.18 23.510 318.850 1502.15 1571.75 212.06 N 130.55 W 6010389.25 N 556525.35 E 2.240 244.13 1706.91 26.670 318.310 1587.93 1657.53 242.17 N 157.13 W 6010419.16 N 556498.54 E 3.345 284.27 1804.05 30.820 317.630 1673.08 1742.68 276.85 N 188.42 W 6010453.60 N 556467.00 E 4.285 330.97 1898.27 32.220 319.110 1753.40 1823.00 313.67 N 221.13 W 6010490.17 N 556434.01 E 1.698 380.21 ( 1994.80 34.050 319.460 1834.23 1903.83 353.67 N 255.54 W 6010529.90 N 556399.29 E 1.906 432.93 2090.65 37.330 319.640 1912.07 1981.67 396.21 N 291.81 W 6010572.18 N 556362.70 E 3.424 488.79 2186.02 42.130 320.280 1985.39 2054.99 442.88 N 331.00 W 6010618.54 N 556323.15 E 5.051 549.64 2282.27 47.120 321.630 2053.88 2123.48 495.39 N 373.55 W 6010670.73 N 556280.21 E 5.277 617.07 2378.70 50.580 322.750 2117.32 2186.92 552.76 N 418.04 W 6010727.76 N 556235.28 E 3.693 689.37 2466.02 55.680 324.450 2169.70 2239.30 608.99 N 459.45 W 6010783.67 N 556193.45 E 6.044 758.73 2563.51 60.240 323.650 2221 .40 2291.00 675.86 N 507.96 W 6010850.17 N 556144.43 E 4.729 840.72 2663.20 61.730 323.810 2269.76 2339.36 746.14 N 559.54 W 6010920.06 N 556092.32 E 1.501 927.30 2762.10 61.440 323.860 2316.82 2386.42 816.37 N 610.87 W 6010989.89 N 556040.46 E 0.297 1013.66 2857.85 62.830 324.750 2361.57 2431.17 885.11 N 660.25 W 6011058.26 N 555990.55 E 1.668 1097.62 2954.36 63.380 322.440 2405.23 2474.83 954.38 N 711.33 W 6011127.14 N 555938.95 E 2.209 1183.12 3050.89 62.930 321.750 2448.82 2518.42 1022.34 N 764.24 W 6011194.69 N 555885.52 E 0.790 1268.90 3147.01 63.870 321.820 2491.86 2561 .46 1089.86 N 817.41 W 6011261.81 N 555831.84 E 0.980 1354.55 25 October, 2004 - 13:10 Page2of6 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18 (mwd) Your Ref: API 500292322400 Job No. AKMW3302792, Surveyed: 3 October, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3242.98 63.260 322.770 2534.59 2604.19 1157.85 N 869.97 W 6011329.40 N 555778.77 E 1.091 1440. 11 3338.99 62.690 321.950 2578.21 2647.81 1225.57 N 922.20 W 6011396.72 N 555726.03 E 0.965 1525.26 3433.62 62.420 322.410 2621.83 2691.43 1291.91 N 973.69 W 6011462.67 N 555674.03 E 0.517 1608.90 3530.56 63.020 323.370 2666.26 2735.86 1360.62 N 1025.67 W 6011530.98 N 555621.53 E 1.076 1694.60 3626.52 62.660 323.920 2710.06 2779.66 1429.38 N 1076.28 W 6011599.35 N 555570.40 E 0.633 1779.41 ( 3722.53 62.350 324.530 2754.39 2823.99 1498.48 N 1126.07 W 6011668.07 N 555520.09 E 0.650 1863.90 3817.40 63.790 324.030 2797.35 2866.95 1567.14 N 1175.45 W 6011736.36 N 555470.18 E 1.589 1947.79 3913.62 64.020 324.950 2839.68 2909.28 1637.48 N 1225.64 W 6011806.31 N 555419.46 E 0.891 2033.47 4009.88 63.820 323.980 2882.00 2951.60 1707.84 N 1275.89 W 6011876.29 N 555368.68 E 0.929 2119.19 4105.14 63.390 324.050 2924.35 2993.95 1776.89 N 1326.03 W 6011944.95 N 555318.02 E 0.456 2203.88 4201.08 63.070 323.780 2967.56 3037.16 1846.11 N 1376.48 W 6012013.79 N 555267.04 E 0.418 2288.92 4296.14 63.680 322.820 3010.16 3079.76 1914.24N 1427.27 W 6012081.53 N 555215.74 E 1.108 2373.38 4392.32 63.560 322.850 3052.89 3122.49 1982.91 N 1479.32 W 6012149.80 N 555163.17 E 0.128 2459.10 4487.93 63.100 323.060 3095.81 3165.41 2051 .1 0 N 1530.79 W 6012217.60 N 555111 .18 E 0.520 2544.08 4513.94 63.300 323.300 3107.54 3177.14 2069.68 N 1544.71 W 6012236.08 N 555097.12 E 1.127 2567.16 4577.81 62.700 322.430 3136.53 3206.13 2115.05 N 1579.06 W 6012281.18 N 555062.43 E 1.535 2623.77 4673.89 62.970 321.750 3180.40 3250.00 2182.49 N 1631.58W 6012348.22 N 555009.39 E 0.690 2708.91 4769.64 62.630 321.060 3224.17 3293.77 2249.05 N 1684.70 W 6012414.38 N 554955.77 E 0.733 2793.82 4866.25 63.120 319.010 3268.22 3337.82 2314.95 N 1739.93 W 6012479.85 N 554900.04 E 1.955 2879.68 4961.79 62.650 316.760 3311.77 3381.37 2378.03 N 1796.95 W 6012542.50 N 554842.54 E 2.153 2964.70 5058.74 62.830 316.490 3356.17 3425.77 2440.67 N 1856.14 W 6012604.69 N 554782.88 E 0.309 3050.88 5154.91 63.420 312.740 3399.66 3469.26 2500.90 N 1917.19W 6012664.45 N 554721.37 E 3.532 3136.57 ( 5250.48 63.580 312.450 3442.30 3511.90 2558.79 N 1980.16 W 6012721.86 N 554657.97 E 0.319 3221.84 5347.07 62.000 309.620 3486.47 3556.07 2615.18N 2044.93 W 6012777.76 N 554592.77 E 3.076 3307.26 5441.30 62.770 305.640 3530.17 3599.77 2666.14 N 2111.04 W 6012828.21 N 554526.27 E 3.831 3389.62 5537.20 62.150 301.660 3574.52 3644.12 2713.25 N 2181.80W 6012874.79 N 554455.15 E 3.736 3472.33 5633.68 61.570 296.150 3620.05 3689.65 2754.36 N 2256.23 W 6012915.33 N 554380.41 E 5.071 3553.16 5729.95 62.560 290.900 3665.17 3734.77 2788.27 N 2334.19 W 6012948.65 N 554302.21 E 4.926 3631.12 5825.75 61.580 288.290 3710.05 3779.65 2816.66 N 2413.91W 6012976.43 N 554222.27 E 2.615 3706.26 5922.06 60.650 287.700 3756.57 3826.17 2842.72 N 2494.11 W 6013001.88 N 554141.87 E 1.105 3780.01 6017.09 60.120 285.980 3803.54 3873.14 2866.65 N 2573.18 W 6013025.21 N 554062.63 E 1.669 3851 .44 6113.08 61.250 286.490 3850.53 3920.13 2890.05 N 2653.54 W 6013048.00 N 553982.09 E 1.265 3923.36 6207.91 61.070 283.340 3896.29 3965.89 2911.43 N 2733.79 W 6013068.77 N 553901.68 E 2.916 3993.73 6302.77 61.100 283.110 3942.15 4011.75 2930.43 N 2814.62 W 6013087.15 N 553820.70 E 0.215 4062.75 6398.37 66.050 280.870 3984.69 4054.29 2948.17 N 2898.34 W 6013104.26 N 553736.85 E 5.586 4132.82 25 October, 2004 - 13:10 Page 3 of 6 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18 (mwd) Your Ref: AP/500292322400 Job No. AKMW3302792, Surveyed: 3 October, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coord inates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6494.92 73.750 282.380 4017.84 4087.44 2966.46 N 2987.07 W 6013121.87N 553647.98 E 8.109 4206.71 6544.28 75.210 283.250 4031.05 4100.65 2977.01 N 3033.45 W 6013132.06 N 553601.53 E 3.411 4246.05 6589.73 75.530 284.950 4042.53 4112.13 2987.72 N 3076.10 W 6013142.45 N 553558.80 E 3.687 4282.97 6638.13 75.530 285.760 4054.63 4124.23 3000.13 N 3121.29 W 6013154.52 N 553513.52 E 1.620 4322.87 6684.47 76.490 287.230 4065.83 4135.43 3012.90 N 3164.40 W 6013166.96 N 553470.31 E 3.710 4361.61 ( 6733.04 76.740 285.280 4077.07 4146.67 3026.12 N 3209.76 W 6013179.84 N 553424.85 E 3.940 4402.22 6780.29 77.240 285.010 4087.71 4157.31 3038.15 N 3254.20 W 6013191.53 N 553380.32 E 1.196 4441.32 6830.18 79.520 285.180 4097.76 4167.36 3050.88 N 3301.38 W 6013203.89 N 553333.05 E 4.582 4482.80 6855.69 80.580 287.140 4102.17 4171.77 3057.87 N 3325.51 W 6013210.70 N 553308.86 E 8.633 4504.38 6906.84 81.140 284.710 4110.29 4179.89 3071.72 N 3374.07 W 6013224.19 N 553260.20 E 4.816 4547.63 6960.27 85.550 288.810 4116.49 4186.09 3087.03 N 3424.86 W 6013239.11 N 553209.30 E 11 .233 4593.46 7003.03 89.880 291.490 4118.19 4187.79 3101.74N 3464.95 W 6013253.52 N 553169.09 E 11.906 4631.56 7052.99 93.020 294.140 4116.93 4186.53 3121.10N 3510.98 W 6013272.53 N 553122.92 E 8.223 4677.11 7098.60 92.340 296.070 4114.79 4184.39 3140.43 N 3552.24 W 6013291.54 N 553081.52 E 4.482 4719.39 7147.35 91.910 295.910 4112.99 4182.59 3161.78N 3596.03 W 6013312.56 N 553037.57 E 0.941 4764.86 7208.48 89.440 299.870 4112.27 4181.87 3190.37 N 3650.04 W 6013340.73 N 552983.34 E 7.634 4822.61 7231 .84 88.460 301.520 4112.69 4182.29 3202.29 N 3670.12 W 6013352.50 N 552963.17 E 8.214 4845.02 7290.60 87.780 307.310 4114.62 4184.22 3235.47 N 3718.55 W 6013385.31 N 552914.49 E 9.916 4902.31 7352.32 89.630 313.040 4116.02 4185.62 3275.26 N 3765.67 W 6013424.74 N 552867.06 E 9.753 4963.55 7386.42 91 .730 317.410 4115.61 4185.21 3299.45 N 3789.68 W 6013448.76 N 552842.87 E 14.217 4997.62 7419.79 87.900 322.520 4115.72 4185.32 3324.99 N 3811 .13 W 6013474.13 N 552821.22 E 1 9. 135 5030.93 7482.82 87.960 327.990 4118.00 4187.60 3376.73 N 3847.02 W 6013525.59 N 552784.95 E 8.673 5093.24 (' 7532.49 90.740 334.020 4118.57 4188.17 3420.15 N 3871.08 W 6013568.83 N 552760.56 E 13.366 5141.41 7578.43 92.410 341 .200 4117.30 4186.90 3462.58 N 3888.56 W 6013611 .12 N 552742.75 E 16.040 5184.36 7626.85 92.280 348.850 4115.32 4184.92 3509.28 N 3901.05 W 6013657.73 N 552729.91 E 15.788 5227.04 7674.81 89.380 354.960 4114.62 4184.22 3556.73 N 3907.80 W 6013705.13 N 552722.80 E 14.100 5266.34 7722.01 89.440 0.480 4115.11 4184.71 3603.87 N 3909.68 W 6013752.25 N 552720.56 E 11.695 5302.10 7770.25 88.020 3.230 4116.18 4185.78 3652.07 N 3908.12 W 6013800.46 N 552721.76 E 6.414 5336.28 7818.02 87.470 3.790 4118.06 4187.66 3699.71 N 3905.20 W 6013848.12 N 552724.32 E 1.642 5369.13 7865.82 89.320 4.080 4119.40 4189.00 3747.38 N 3901.92 W 6013895.81 N 552727.23 E 3.918 5401.76 7915.05 91.420 6.410 4119.08 4188.68 3796.39 N 3897.42 W 6013944.86 N 552731.36 E 6.371 5434.54 7961.93 89.810 2.250 4118.57 4188.17 3843.12 N 3893.88 W 6013991.62 N 552734.54 E 9.514 5466.30 8010.02 89.440 0.690 4118.89 4188.49 3891.20 N 3892.65 W 6014039.70 N 552735.41 E 3.334 5500.62 8058.36 89.140 359.500 4119.49 4189.09 3939.53 N 3892.57 W 6014088.03 N 552735.13 E 2.539 5535.91 8107.60 89.200 358.490 4120.20 4189.80 3988.76 N 3893.43 W 6014137.25 N 552733.89 E 2.055 5572.51 25 October, 2004 - 13:10 Page 4 of 6 DrillQuest 3.03.06.006 DrillQuest 3.03.06.006 Page 5 of 6 25 October, 2004 - 13:10 ( Based upon Minimum Curvature type calculations, at a Measured Depth of 8639.00ft., The Bottom Hole Displacement is 5984.90ft., in the Direction of 318.993° (True). The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 317.000° (True). All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18 (mwd) Your Ref: API 500292322400 Job No. AKMW3302792, Surveyed: 3 October, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8153.34 91.730 359.640 4119.83 4189.43 4034.49 N 3894.18 W 6014182.97 N 552732.79 E 6.076 5606.46 8195.64 92.100 358.850 4118.42 4188.02 4076.76 N 3894.73 W 6014225.24 N 552731.92 E 2.061 5637.75 8249.77 89.810 356.820 4117.51 4187.11 4130.84 N 3896.78 W 6014279.30 N 552729.46 E 5.653 5678.70 8296.75 87.590 356.710 4118.58 4188.18 4177.73 N 3899.43 W 6014326.17 N 552726.45 E 4.731 5714.80 8345.53 87.840 356.710 4120.52 4190.12 4226.39 N 3902.22 W 6014374.81 N 552723.29 E 0.513 5752.29 ( 8392.27 86.290 356.410 4122.92 4192.52 4272.98 N 3905.03 W 6014421.38 N 552720.13 E 3.378 5788.28 8441.24 82.380 355.810 4127.75 4197.35 4321.59 N 3908.33 W 6014469.96 N 552716.46 E 8.077 5826.08 8489.78 81.960 354.960 4134.36 4203.96 4369.52 N 3912.20 W 6014517.86 N 552712.23 E 1.939 5863.78 8537.43 81 .080 354.020 4141.39 4210.99 4416.43 N 3916.72 W 6014564.73 N 552707.35 E 2.687 5901.17 8567.94 81.570 354.130 4145.99 4215.59 4446.43 N 3919.84 W 6014594.71 N 552704.00 E 1.645 5925.24 8639.00 81.570 354.130 4156.41 4226.01 4516.35 N 3927.03 W 6014664.58 N 552696.28 E 0.000 5981.28 Projected Survey Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18 (mwd) Your Ref: API 500292322400 Job No. AKMW3302792, Surveyed: 3 October, 2004 BPXA Milne Point Unit Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8639.00 4226.01 4516.35 N 3927.03 W Projected Survey ( Survey tool program for MPH-18 (mwdJ Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 534.00 0.00 533.95 534.00 8639.00 533.95 CB-SS-GYRO 4226.01 MWD Magnetic ( 25 October, 2004 - 13:10 Page 6 of 6 DrillQuest 3.03.06.006 ~ -~"=\ ~u~1rŒ (ID~ fd n n '1lJ ji f1 /71 I ~ \ ! i 'I ß \ ~~_ I t ( I r\.\ I \ I ¡ t - . ì ' 1\ l ! '=' ~ Jrì \ I L, f {'Ul rlJ} 11\ \ 1 r\ \ b'U~~ ~b..4'~=*~ / í f I j I I ¡ i ! ¡ l FRANK H. MURKOWSKI. GOVERNOR AI,ASIiA OIL AlÐ) GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPH-18 BP Exploration (Alaska) Inc. Permit No: 204-174 Surface Location: 3026' NSL, 3987' WEL, SEC. 34, T13N, RI0E, (As Planned) Bottomhole Location: 2127' NSL, 2750' WEL, SEC. 28, TI3N, RIOE, UM (OB) Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations . until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 7 (pager). BY ORDER 01} THE COMMISSION DATED this~day of September 2004 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~- ""-"" bp September 8, 2004 Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Request for a maximum 14-day BOPE test frequency for Doyon 14 MPH-18 Mr. Maunder: BP Exploration (Alaska) Inc. ("BP") hereby to requests an exception to 20 AAC 25.035(e)(10)(A) per 20 AAC 25.035(h)(l) for a maximum14-day BOPE test frequency for the Doyon 14 drilling rig. The requested exception pertains to the drilling ofMPH-18, a Tri-Iateral in the OB, OA & NB sands. In the fust 6 months 2004, Doyon 14 performed 21 successful BOPE tests. In these tests, auxiliary equipment failed on three occasions as previously documented. During the 3rd quarter of 2004, the BOPE has been tested four (4) more times with only one notable failure: that being the HCR valve which was changed out and re-tested. If you have any questions or require any additional information, please contact the undersigned at 564-4395. Sincerely, s~(T-- - Drilling Engineer BP Exploration (Alaska) Inc. RECE\VEO SEP 101004 . .", omffi\SS\on 0'\ & Gas Cans. ~ ~\aSKa \ ~nc"ofa¡e ORIGINAL STATE OF ALASKA c, '-' ALA5'1\Á OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 Á'1(1 ~ 1 a. Type of work II Drill o Redrill 1 b. Current Well Class o Exploratory II Development Oil o Multiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone 2. Operator Name: 5. Bond: iii Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 MPH-18 3. Address: 6. Proposed Depth: ,/ 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 8557' / TVD 4192' Milne Point Unit / Schrader Bluff 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 025906 ¡/ 3026' NSL, 3987' WEL, SEC. 34, T13N, R10E, (As Planned) j Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 707' NSL, 4573' WEL, SEC. 28, T13N, R10E, UM (OB) 09/21/2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2127' NSL, 2750' WEL, SEC, 28, T13N, R10E, UM (OB) 2560 5800' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 556658 v" y- 6010178 v Zone- ASP4 (Height above GL):KBE = 72' feet 285' away from MPJ-07 16. Deviated Wells: Kickoff Depth: 583' feet / 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 2100 .I Surface: 1685 '" 18. Casing Program: Specifications ..... </ ..' ..>J:S~tting[)èpJn;·c>·:<~~' " ;Çll.lal1tityof~m.ent:·..·. " Size . c..> .Top;:.< .'.~<"=BoftQm..~" ' ....' (cLorsack$l···.·.' < Hole Casinq Weiqht Grade Couplinq Lenqth MD TVD MD TVD (includina staae data) 42" 20" 92# H-40 Welded 80' 34' 34' 114' 114' 260 sx Arctic Set (Approx.) 13-1/2" 10-3/4" 45.5# L-80 BTC-M 4447' 30' 30' 4477' 3172' 645 sx Arctic Set Lite, 255 sx 'G' 9-7/8" 7-5/8" 29.7# L-80 BTC-M 6770' 30' 30' 6800' 4160' 580 sx Class 'G' 6-3/4" 4-1/2" 12.6# L-80 IBT 1950' 6607' 4136' 8557' 4192' Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMMARY(TQ:~corripleted·f()["Redr'iIFANPR~entrY'OPØratiöns) ..... .... <» . . Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effective Depth MD (ft): I Effective Depth TVD (ft): I Junk (measured): Casing Length Size ..: ...,............ 1;-" c ,."'.'< ..2" IV»·.·.·....,,·...... ...<..... / ".: '.:< < ..' :" ~....,. ............ Structural Conductor Surface Int ,. . Production Liner Perforation Depth MD (ft): ¡rerfOratiDn Depth TVD (ft): 20. Attachments iii Filing Fee, $100 o BOP Sketch iii Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis D Property Plat o Diverter Sketch o Seabed Report iii Drilling Fluid Program iii 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Skip Coyner, 564-4395 Printed Name Pat Archey Title Senior Drilling Engineer Pc. r:~L.A Date '1 Ie; It; Y Prepared By Name/Number: Signature Phone 564-5803 Sondra Stewman, 564-4750 . - / ". '. _": " <- ._: _ " '.'_'' :__. _-.'_ :', :--.-_ ':',':: '- :~:~:__.._:<,' __ 0 '::_: ~,;', __'~ _-:__'.\-_--:: _:,-"- ·;;r::.M).:··· . .'.' CC)"'ìrnJs~ic)n~"I.J$!F'()f1IY'}:t '.. '. Permit To Drill '" ( '7,-/ I API Number: o 2-9 .~ 2. 32-Z 0/ -¿;(j I Permit Approval / I ,See cover letter for Number: ZOL -I 50- Date: ~ 1/'/0 t..f other requirements Conditions of Approval: Samples Required D Yes }~D Mud Log Required ~es ~No Hydrogen Sulfide Measures D Yes No Directional Survey Required Yes DNo Other: ~~~"">-\-·~CË1VË'D~~~ \ f: \ 4~ù...'(S.. íJ SEP 1 0 2004 APPROVED BY tt/b-t)~ Aooroved Bvr-lt a' I'\~I 0 f"_... ('\",nco í' " ....... Tblt: f'("u..UAI is ~Na Date . ,." . - Form 10-401 ~ed ~004 fUiI:Sl\ö un ~ UUtl vV"-· UKI\jII~I-\L ' Submit In OOplicate I1n~hOr8Qe --' bp I Well Name: I MPH-18 Primary Well bore & OB Lateral Drilling Plan Summary I Type of Well (service I producer I injector>.:.j Schrader Bluff Tri-Lateral Producer ./ 0/ Surface Location: 30261 FSL, 2254' FNL, 39871 FEL, 1293' FWL 34 T13N R10E (As Proposed) E 556,658' N 6,010,178' / = = Target Loc'n: "08 Heel" 707' FSL, 4573' FNL, 2045' FEL, 3235' FWL 28 T13N R10E 7-5/8" Shoe at 6,800' MD E = 553,291 ' N = 6,013,113' Z = 4160' TVD Target Loc'n: "08 Toe" 2127' FSL, 3153' FNL, 2750' FEL, 2530' FWL 28 T13N R10E 08 8HL at 8,557' MD E = 552,572' N = 6,014,529' Z = 4192' TVD Target Loc'n: "OA Heel" 625' FSL, _ 4655' -FNL, _ __1721'--·F~L'i3559JFWL 28T13NR10E Whipstock & Window E = 553,616' N= 6,013,034'.Z=4,092'TVD -- ---- > Target Loc'n: "OA Toe" 2127' FSL, 3153' FNL,2750'FEL,.2530'FWL ---. 28 T13NR10E OA BHL - at 8,550' MD E = 552,572' N _=6,014,52B'--_Z=4,122'[V[) < -..----- Target Loc'n: 536' FSL,4744' FNL, -1329'FEL,3951'FY/L 28T13N.-'R10E NB Whipstock & Window E = 554,009' N = 6,012,948' Z= 3,895' TV[:> - -- - .- . .--.- Target Loc'n: "NB Entry" 577' FSL,4703' FNL, 1706' FEL/3574'FWL 28 Tt3NR10E T/NB Sand at 6,400' MD E = 553,631' N =6,012,986' <.z=3,972'TVQ .---- Target Loc'n: "NB Heel" 2127' FSL, .3153' FNL,2818'FEL,24ß2'FWL --- 28T13NR10E NB BHL at 8,628' MD E = 552,504' N = 6,014,582' Z ::::3,992'TVD --- --- - Distance to Property line 5800' Distance to nearest pool 285' from MPJ-07 (Shut In) AFE Number: I Estimated Start Date: 121 Sept 04 Rig: Doyon 14 Rig days to complete: 1 - LSND APIFiltrate LGSölids < 6 < 15 4477 - 6800' : VP HTHP 25 - 30 1 0 - 11 LSND API<Filtrate LGSólids < 6 < 15 MOBM API Filtrate LGSòlids < 6 < 15 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. ./ Cement Program: Casing Size 10-3/4", 45.5#, L-80, BTC Surface Casing at 4,477' MD Basis Excess from B/Permafrost to Surface = 150°1<> over gauge hole. Use 40°1<> excess below the B/Permafrost. Tail cement = 500' MD. Total Cement Wash 10 bbl water Volume: 563 bbl 25 bbl CW 100 Spacer 75 bbl of MudPush Lead 510 bbl, 645 sx of Arctic Set Lite: 10.7 ppg and 4.44 ft"/sx Tail 53 bbl, 255 sx "G" mixed at 15.8 Ib/gal & 1.17 ft"/sx Temp Casing Point BHST 45° F (estimated by Dowell) Casing Size 7-5/8", 29.7#, L-80, BTC-M Intermediate Casing at 6,800' MD Basis Top of cement to be 500' MD above Ugnu sands: 40°1<> excess. Shoe Joint = 85 ft Total Cement Wash 5-bbl water Volume: 120 bbl 25 bbl CW 100 Spacer 40 bbl of MudPush Tail 120 bbl, 580 sx "G" mixed at 15.8 Ib/Qal & 1.16 ft"/sx Temp BHST ==80°F from SOR 2 9-7/8" Formation Markers: Formation Recommended Program: 3 CaSinQITUbin' Program . . Wt/Ft 20-in* 92# H-40 Welded 80' 114' / 114' 10.75-in 45.5# L-80 BTC-M 4,447' 4,477' / 3,172' 7.625-in 29.7# L-80 BTC-M 6,770' 6,800' / 4,160' 4.5-in Slotted L-80 IBT 1,950' 6,607' I 4,136' 8,557' / 4,192' 4" X 5" Screens and 4" Blanks Well Control: Intermediate hole: / · Maximum anticipated BHP: 2,100 psi at 4,152' TVD (Top of the OB sand) (9.8 ppg) · Maximum surface pressure: 1,685 psi at (Based on a full column of gas at 0.1 psi/ft) · Planned BOP test pressure: 3,500 psi v--- · BOP Test Interval: NOT TO EXCEED 14 DAYS / per AOGCC . · Integrity tests: FIT to 11.5 Iblgal 20' below the 10-3/4" shoe. Kick tolerance [10-3/4"]: 26-bbl with an 11.5 ppg FIT [minimum] and 10.0 Ib/gal mud Kick tolerance [10-3/4"]: 52-bbl with a 12.4 ppg FIT and 10.0 Ib/gal mud · Planned completion fluid: Kill Weight brine or MOBM 0/ Drilling Hazards & Contingencies: / · Hydrates have been encountered on H-Pad wells: 1,700' to 3,000' TVD. · Packing off due to clays and poor hole cleaning: 2300' to 3300' TVD. · Formation pressures in Hydraulic Unit #5 are above normal due to J-Pad injectors. / ,r- -- Lost Circulation · We do not expect losses while drilling this well, although it is possible when cutting faults in the three laterals while drilling with ~ 10.0 ppg MOBM. Expected Pressures / · The Schrader Bluff sands are pressured up to an EMW of 9.8 ppg as measured in MPJ-07 located near the landing point of the 7-5/8" intermediate casing. Pad Data Sheet · Please Read the H-Pad Data Sheet thoroughly. Breathing Hazards · Not expected or predicted. 4 . . Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Faults · One (1) fault (#3) is expected to be cut in the intermediate hole section. That fault (#3) should be cut near the TINB sand at ± 6175' MD. · Two (2) minor faults (#4 & #5) are expected in the OB lateral: both faults are expected to be cut between 7650' and 7750' MD. · The same two (2) minor faults (#4 & #5) are expected in the OA lateral [L-1]: both faults are expected to be cut between 7650' and 7700' MD. · The same two (2) minor faults (#4 & #5) are expected in the NB lateral [L-2]: both faults are expected to be cut between 7750' and 7800' MD. Hydrogen Sulfide · MPI Pad is not designated as an H2S Pad. ./ Anti-collision Issues · MPH-18 passes the Major Risk Criteria in the Mother Bore and all laterals. Gyro surveys will be run as needed for possible magnetic interference down to ± 600 ft MD. ~ · The intermediate hole section passes near MPJ-04 but passes "Major Risk": MPJ-04 is shut in. · All Three laterals pass near to MPJ-07: 350' to 285 away. Distance to Nearest Property · MPH-18 is 5,800 ft from the nearest Milne Point property line. Distance to Nearest Well Within Pool · MPH-18 is 285 ft from the nearest Schrader Bluff sand penetration in MPJ-07. ./ 5 · - . DRILL & COI\lfl5'LETION PROCEDURE Pre-Ria ODe rations 1 . The 20" conductor will be installed pre-rig. '\\-'~ , ~f Drillina 1. MIRT and NU Diverter 2. Function Test Diverter, PU DP and BHA. 3. Drill 13.5" surface hole. 4. Run and cement 10.75" surface casing. 5. ND diverter, install wellhead and NUrrest BOP. 6. Drill 9.875" intermediate hole. 7. Run and cement 7-5/8" intermediate casing. 8. Displace to MOBM. Drill 6-3/4" OB horizontal production hole. 9. Run 4.5" slotted liner and hang off in 7.625" casing with HGR. ZXP and PBR. t - 6 MPH-18 Motherbore 10-3/4", 40.5#, K-55 & L-80, BTC at 4477' MD, 3172' TVD MPH - 18 OB, OA & NB Tri-Lateral Producer e 9-7/8" Hole with LSND Mud ~ 10.0 ppg at T/Schrader Bluff ie 7-5/8" Shoe set at 870 6800' MD, 4160' TVD S Coyner, 9/8/2004 -18 " Lateral " K-55 & BTC 3172' TVD 9-7/8" Hole with Mud WIIIIIli!IIt ..... ..... ........fIIIIJIiII!@t..... _.._ __..... - .... --....... , I ¡ , I , , I I , , , , I I , I I I , , I I : I I I I , , , , , I , : I i 'H-12. ! )H-11. : H-lO. ! H-9 . I I I I ! I I I I I ! I / I / // / // /1 _ __ _ , , , / / / ¡/ II ¡/ / Ii / MPU H-PAD / " 1- , 15·40'59" ~r O~^ -~- I \ l_______ __ ________ ___ ______ _________, 1 , , I I I , , I I , , , I I I 1 I , I , \ I 1 I 1 I , , I I , I , , , I I I , H-14. H-13. -+- H-18 -+- H-17 1 -+- H-16 Å H-15 30' (TYP)T T · H-4 · H-5 · H-3 · H-6 · H-2 · H-8 · H-1 · H-7 I , , , , , I I I , , , I , , , , I , I I I -- - ---- ----- -- -- -- ------ -----.// LEGEND -+- PROPOSED WELL CONDUCTOR . EXISTING WELL CONDUCTOR VICINITY MAP N.T.S. NOTES 1. ALASKA STATE PLANE COORDINATES (A.s.P.) ARE ZONE 4 ALASKA, NAD 27. 2. PAD SCALE FACTOR IS 0.99990364 3. HORIZONTAL CONTROL IS BASED ON MPU H-PAD MONUMENTS H-1 AND H-2 LOCATED WITHIN PROTRACTED SECTION 34, T. 13 N., R. 10 E.,UMIAT MERIDIAN, ALASKA WELL A.s.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS H-15 y= 6,010,091.44 N= 1,410,00 70"26'17.585" 70.4382181" N/A 2,940' FSL X= 556,633.18 E= 880.00 149"32'17.598" 149.5382217" 4,012' FEL 6 Y= 6,010,120.32 N= 1,440.00 70"26'17,869" 70.4382969" N/A 2,969' FSL H-1 X= 556,641.29 E= 880.00 149"32'17.354" 149,5381538' 4,003' FEL H-17 Y= 6,010,149.20 N= 1,470,00 70"26'18,152" 70.4383755" N/A 2,997' FSL X= 556,649.40 E= 880.00 149"32'17.109" 149.5380858" 3,995' FEL H-18 Y= 6,010,178.08 N= 1,500,00 70"26'18.436" 70.4384544" N/A 3,026' FSL X= 556,657.51 E= 880,00 149"32'16.865" 149.5380181" 3,987' FEL o 5-17-04 ISSUED FOR INFORMATION NO. 014. TE REVISION ./ / ~~, DRAWN: O'NEIL CHECKED: "·bp SP EXPLORATION AlliSON DATE: 5-17-04 , DRAWING: SttEET: fRB04 MPH 01-00 MILNE POINT UNIT H-PAD ~ ffi~~[]Jœo JOB NO: SCALE: PROPOSED CONDUCTOR 1 or 1 MLO RF A Q;GINŒItSANOlAHOSIJR\O{1"()ftS WELLS MP H-15, H-16, H-17, H-18 110I _ST flR(WUD lANE: I" = 150' BY CHK ~AŒ. AUlSKA H~ MPH-18 MPH-18 Surface location Plan: WPM (Pian MPH~l&'Plan MPH~18 Created By: Troy Jwoo-sky Date: Siì 9f2004 Checked: _ Date:_ Reviewed: Date:_ Tool Cß.GYRO~SS M\VD+fFR+MS SURVEY PROGR.AM Depth Fm Depth To. Survey/Plan 35.00 1000.00 Planned: \\'1"04 V78 IOCìO.OO 85%li1 p¡~ WP04 V78 WELL DETAILS ""'" +NI-8 +El~W -... E&Jting w_ Loogíwde SI", Plan MPH~tß 1196,95 [261.65 6010171HJ8: 556651. 7Cr"26'J8.436N t49"J2'16.865W NlA REFERENCE iNFORMA nON -, -, -, -, """'" FORMATION TOP DETAILS TVDPath MDPath Formation OOMPANY DETAfLS BP Amoco TVD +N/-S +E/-W DLeg TFaee vSec Target MPH-18 T! Top NB MPH-18 T2 TopOB MPH-18 T3 MID OB MPH-18 T4 MID OB MPH-18 T5 MID OB Azi Ine MD Sec 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 11 18 19 20 21 22 4 '¡¡' :¡:¡ o o t::, J õ! " fj > ~ Plan: WP04(PIan MPH·!8IPiMlMPH·!ß Date:SfIS +N!-S +£/~w - .-.. Uti_ LOPgitude Slot 11%.95 1261.65 6010178.1 55665731 1O<'26'IU36N !4o/'32'16.ßi5SW NfA SURVEY PROGRAM Depth fm Depth To Sutwy!P1an Too! 35.00 IOOCtOO P1.oo:.ma.t WP04 V18 CB-GYRO..sS ¡(Ií}(I.OO 8556.51 J>1.anIr& WP04 V78 MWD+IFR+MS REFERENCE INfORMATION TVD +NI-S +EI-W DLeg TFac. VSee Target MPH-18T1 TopN3 MPH-18 T2 Top 03 MPH-18 T3 MID 03 MPH-18 T5 MID 03 -- -- Azi Ine MD See I 2 3 4 5 6 7 8 9 10 !I 12 13 14 15 16 17 18 19 2() 21 22 '"iF ~ <:> <:> ~ +' f ~ ;¡¡; g 00 . . BP BP Planning Report Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: M pt H Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: 6008971.91 ft From: Map Easting: 555404,91 ft Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Latitude: 70 26 6.665 N Longitude: 149 32 53,895 W North Reference: True Grid Convergence: 0.43 deg Slot Name: Latitude: 70 26 18.436 N Longitude: 149 32 16,865 W Well: Plan MPH-18 Morpheus Well Position: +N/-S 1196.95 ft Northing: 6010178,08 ft +E/-W 1261.65 ft Easting: 556657,51 ft Position Uncertainty: 0.00 ft Casing Points 1967.05 1872,00 BPRF 0,00 0,00 5123,19 3472,00 TUZC 0.00 0.00 5597,64 3702.00 Ugnu-MA 0.00 0.00 5639,20 3722.00 Ugnu-MB1 0.00 0,00 5733.55 3767.00 Ugnu-MB2 0,00 0,00 6013.40 3897.00 Ugnu-MC 0,00 0,00 6110.86 3942,00 SBF2-NA 0.00 0,00 6176.50 3972.00 SBF1-NB 0.00 0.00 6244.91 4002,00 SBE4-NC 0.00 0.00 6279.48 4017.00 SBE2-NE 0,00 0,00 6383.19 4062.00 SBE1-NF 0,00 0,00 6457.39 4092.00 TSBD-Top OA 0,00 0,00 6550.25 4122,00 TSBC-Base OA 0,00 0,00 6699.76 4152,00 TSBB-Top OB 0.00 0.00 7800,38 4177,00 SBA5-Base OB 0.00 0.00 Targets MPH-18 T1 Top NB 3972.00 2818.00 -2774,00 6012974.66 553862.45 70 26 46.145 N 149 33 38.315 W MPH-18 Fault 1 3972.00 2909,51 -4372,95 6013054.00 552263.00 70 26 47,038 N 149 34 25.265 W -Polygon 1 3972.00 2909.51 -4372.95 6013054,00 552263.00 70 2647,038 N 149 34 25.265 W -Polygon 2 3972.00 2534.07 -2478.57 6012693,00 554160.00 70 26 43,354 N 149 33 29,638 W -Polygon 3 3972.00 2176.45 -1481.16 6012343,00 555160.00 70 26 39.839 N 149 33 0.351 W -Polygon 4 3972.00 2534.07 -2478.57 6012693,00 554160.00 70 26 43.354 N 149 33 29.638 W MPH-18 Fault 2 3972.00 3533.86 -3750,13 6013683.00 552881,00 70 26 53.181 N 149 34 6.987 W -Polygon 1 3972.00 3533,86 -3750,13 6013683.00 552881.00 70 2653,181 N 149 34 6,987 W . . BP BP Planning Report ·Polygon 2 3972.00 3175.91 -2710,72 6013333.00 553923.00 70 26 49,665 N 149 33 36.461 W ·Polygon 3 3972,00 3156,77 -1638,73 6013322,00 554995.00 70 26 49.480 N 149 33 4.983 W ·Polygon 4 3972.00 3175.91 -2710.72 6013333,00 553923.00 70 26 49.665 N 149 33 36.461 W MPH-18 Fault 3 3972.00 2979,59 -2671,21 6013137,00 553964,00 70 26 47.735 N 149 33 35.299 W -Polygon 1 3972,00 2979.59 -2671.21 6013137,00 553964.00 70 26 47.735 N 149 33 35.299 W -Polygon 2 3972.00 2535.48 -2664.58 6012693.00 553974.00 70 26 43.367 N 149 33 35,099 W MPH-18 T2 Top OB 4157,00 2948,34 -3297,52 6013101.00 553338.00 70 26 47.425 N 149 33 53.689 W MPH-18 ONOB Poly 4157.00 2818.00 -2774.00 6012974.66 553862.45 70 26 46.145 N 149 33 38.315 W -Polygon 1 4157,00 4457,03 -3889.14 6014605.00 552735.00 70 27 2.260 N 149 34 11.083 W -Polygon 2 4157,00 4454.36 -4196.19 6014600.00 552428.00 70 27 2.232 N 149 3420.101 W -Polygon 3 4157.00 3179.19 -4062.86 6013326.00 552571.00 70 26 49,692 N 149 34 16,165 W -Polygon 4 4157,00 2946,79 -3488.56 6013098.00 553147.00 70 26 47.409 N 149 33 59.298 W -Polygon 5 4157.00 2746.99 -2860.00 6012903,00 553777.00 70 26 45.447 N 149 33 40.839 W -Polygon 6 4157.00 3036.85 -2836.79 6013193.00 553798.00 70 26 48.297 N 149 3340.161 W -Polygon 7 4157.00 3088,35 -3296.46 6013241.00 553338.00 70 26 48,802 N 149 33 53.659 W -Polygon 8 4157,00 3239.42 -3697.36 6013389.00 552936.00 70 26 50.286 N 149 34 5.433 W -Polygon 9 4157.00 3520.68 -3859.25 6013669.00 552772.00 70 26 53.051 N 149 3410.191 W MPH-18 T3 MID OB 4162,00 3279.71 -3867,08 6013428,00 552766,00 70 26 50.681 N 149 34 10.417 W MPH-18 Fault 4 4167.00 3569.64 -4378,94 6013714.00 552252.00 70 26 53,530 N 149 34 25.452 W -Polygon 1 4167.00 3569,64 -4378,94 6013714.00 552252,00 70 26 53.530 N 149 34 25.452 W -Polygon 2 4167,00 3440.93 -3760.84 6013590,00 552871.00 70 26 52.267 N 149 34 7.300 W MPH-18 Fault 5 4172.00 3549,51 -3968.04 6013697.00 552663.00 70 26 53,334 N 149 34 13.386 W -Polygon 1 4172,00 3549.51 -3968.04 6013697,00 552663.00 70 26 53.334 N 149 34 13.386 W -Polygon 2 4172.00 4351.21 -4045.96 6014498.00 552579.00 70 27 1,218 N 149 34 15,687 W MPH-18 T4 MID OB 4187,00 3813.52 -3965.03 6013961,00 552664.00 70 26 55.931 N 149 34 13.302 W MPH-18 T5 MID OB 4192.00 4382,00 -4053,00 6014528.74 552571,73 70 27 1.521 N 149 34 15.894 W MPH-18 Fault 6 4192.00 4796.80 -4379,61 6014941.00 552242.00 70 27 5.599 N 149 34 25.493 W -Polygon 1 4192.00 4796,80 -4379,61 6014941.00 552242,00 70 27 5.599 N 149 34 25.493 W -Polygon 2 4192,00 4786.53 -3028.52 6014941.00 553593.00 70 27 5.504 N 149 33 45.812 W Plan Section Information 35,00 0.00 0.00 35.00 0.00 0,00 0.00 0.00 0.00 0.00 450,00 0.00 0,00 450.00 0,00 0.00 0.00 0.00 0.00 0.00 583,33 2.00 322.30 583,31 1.84 -1,42 1.50 1,50 0,00 322,30 1821.49 32,95 322,30 1750.00 292.49 -226.06 2,50 2,50 0.00 0.00 1940.67 32,95 322,30 1850,00 343,78 -265.71 0,00 0.00 0.00 0.00 2679,01 62.49 322.32 2341,24 771,32 -595.99 4.00 4.00 0,00 0.04 4931,93 62.49 322.32 3381.94 2352.75 -1817.32 0,00 0,00 0.00 0.00 5859.07 62.50 280,30 3825.74 2766,21 -2497.09 4,00 0.00 -4.53 -100.04 6009.07 62,50 280,30 3895,00 2790,00 -2628.00 0.00 0.00 0,00 0.00 6111.26 62.50 280.30 3942.19 2806.21 -2717.18 0.00 0,00 0,00 0,00 6176.50 63,13 283,15 3972.00 2818,00 -2774.00 4,00 0,96 4.37 76.76 MPH-18 T1 Top NB 6211.27 64,28 284.01 3987.40 2825.32 -2804.29 4.00 3.33 2.47 33.87 6389,52 64.28 284.01 4064,75 2864.19 -2960.12 0.00 0.00 0,00 0,00 6751.45 86,00 284.00 4157.00 2948.34 -3297,52 6.00 6,00 0.00 -0,02 MPH-18 T2 Top OB 6955.96 90,29 295,50 4163,64 3017,31 -3489.52 6,00 2.10 5.63 69.79 7127.60 90.29 295.50 4162.77 3091,21 -3644.43 0.00 0.00 0,00 0.00 7422,57 90.00 325.00 4162.00 3279.71 -3867.08 10,00 -0.10 10.00 90,51 MPH-18 T3 MID OB 7793.43 85.68 1.87 4176.48 3628.68 -3971,06 10,00 -1,16 9.94 97.18 7879.47 85,68 1,87 4182,96 3714.43 -3968.26 0,00 0.00 0,00 0.00 . . BP BP Planning Report 35,00 0,00 0,00 35.00 -37.00 0,00 0.00 0.00 6010178.08 556657,51 CB-GYRO-SS 50.00 0,00 0.00 50,00 -22.00 0.00 0,00 0.00 6010178.08 556657,51 CB-GYRO-SS 75.00 0.00 0.00 75,00 3,00 0.00 0,00 0,00 6010178,08 556657.51 CB-GYRO-SS 100,00 0.00 0.00 100.00 28.00 0,00 0.00 0.00 6010178.08 556657.51 CB-GYRO-SS 125,00 0,00 0,00 125.00 53.00 0.00 0.00 0.00 6010178,08 556657.51 CB-GYRO-SS 150.00 0.00 0.00 150,00 78.00 0.00 0,00 0.00 6010178.08 556657,51 CB-GYRO-SS 175.00 0.00 0.00 175,00 103.00 0.00 0,00 0.00 6010178.08 556657,51 CB-GYRO-SS 200.00 0.00 0.00 200.00 128,00 0.00 0.00 0.00 6010178,08 556657.51 CB-GYRO-SS 225.00 0,00 0,00 225.00 153.00 0.00 0.00 0.00 6010178,08 556657.51 CB-GYRO-SS 250,00 0,00 0,00 250.00 178.00 0,00 0.00 0.00 6010178,08 556657.51 CB-GYRO-SS 275.00 0.00 0.00 275,00 203,00 0,00 0,00 0,00 6010178.08 556657.51 CB-GYRO-SS 300.00 0.00 0,00 300.00 228.00 0.00 0.00 0.00 6010178,08 556657.51 CB-GYRO-SS 325,00 0.00 0,00 325.00 253.00 0,00 0,00 0.00 6010178,08 556657.51 CB-GYRO-SS 350,00 0,00 0.00 350.00 278.00 0.00 0,00 0.00 6010178.08 556657,51 CB-GYRO-SS 375.00 0.00 0.00 375.00 303.00 0.00 0,00 0.00 6010178.08 556657,51 CB-GYRO-SS 400,00 0.00 0.00 400.00 328.00 0,00 0.00 0.00 6010178,08 556657.51 CB-GYRO-SS 425.00 0,00 0,00 425.00 353.00 0,00 0.00 0.00 6010178,08 556657.51 CB-GYRO-SS 450,00 0,00 0.00 450.00 378,00 0.00 0,00 0,00 6010178.08 556657,51 Start Dir 1.5/1 475.00 0.38 322.30 475,00 403,00 0.06 -0.05 1,50 6010178.14 556657.46 CB-GYRO-SS 500.00 0.75 322.30 500.00 428,00 0.26 -0,20 1.50 6010178.34 556657.31 CB-GYRO-SS ,.,. 525,00 1.13 322,30 525.00 453.00 0.58 -0.45 1.50 6010178,66 556657.06 CB-GYRO-SS 550,00 1,50 322.30 549.99 477.99 1.04 -0.80 1.50 6010179.11 556656,70 CB-GYRO-SS 575.00 1.88 322.30 574.98 502,98 1.62 -1,25 1,50 6010179.69 556656.25 CB-GYRO-SS 583.33 2.00 322.30 583.31 511.31 1.84 -1,42 1.50 6010179.91 556656.07 Start Dir 2.5/1 600.00 2,42 322,30 599.96 527.96 2,35 -1.82 2.50 6010180,42 556655.68 CB-GYRO-SS 625,00 3.04 322.30 624,93 552,93 3.29 -2,54 2,50 6010181.35 556654.94 CB-GYRO-SS 650.00 3.67 322.30 649.89 577,89 4.45 -3,44 2.50 6010182.50 556654.04 CB-GYRO-SS 675.00 4.29 322,30 674.83 602.83 5,82 -4,50 2.50 6010183,87 556652.97 CB-GYRO-SS 700.00 4.92 322,30 699.75 627.75 7.41 -5.73 2.50 6010185.44 556651,73 CB-GYRO-SS 725,00 5,54 322.30 724,64 652,64 9.21 -7.12 2,50 6010187.24 556650.32 CB-GYRO-SS 750.00 6.17 322.30 749.51 677.51 11,23 -8.68 2.50 6010189,24 556648.75 CB-GYRO-SS 775.00 6.79 322,30 774.35 702.35 13,46 -10.40 2.50 6010191.46 556647,01 CB-GYRO-SS 800.00 7.42 322,30 799.16 727.16 15.91 -12.29 2.50 6010193.89 556645,10 CB-GYRO-SS 825,00 8,04 322.30 823,93 751.93 18.57 -14.35 2.50 6010196.54 556643.02 CB-GYRO-SS 850,00 8,67 322.30 848,67 776,67 21.44 -16,57 2,50 6010199.39 556640.78 CB-GYRO-SS 875.00 9.29 322,30 873.36 801.36 24,53 -18,96 2.50 6010202.46 556638,37 CB-GYRO-SS 900,00 9.92 322,30 898.01 826.01 27.83 -21.51 2.50 6010205.74 556635,79 CB-GYRO-SS 925,00 10.54 322.30 922,61 850,61 31.34 -24.22 2,50 6010209.23 556633.05 CB-GYRO-SS 950.00 11,17 322.30 947,17 875,17 35.07 -27.10 2,50 6010212.94 556630.14 CB-GYRO-SS 975.00 11,79 322.30 971.67 899.67 39,00 -30,15 2.50 6010216,85 556627.07 CB-GYRO-SS 1000.00 12,42 322,30 996,11 924.11 43.15 -33.35 2,50 6010220,97 556623,84 MWD+IFR+MS 1025.00 13.04 322,30 1020,50 948,50 47.51 -36.72 2,50 6010225.30 556620.43 MWD+IFR+MS 1050,00 13.67 322.30 1044,82 972.82 52.08 -40.25 2,50 6010229,85 556616.87 MWD+IFR+MS 1075.00 14,29 322.30 1069.08 997.08 56.86 -43,94 2,50 6010234,60 556613,14 MWD+IFR+MS 1100.00 14,92 322,30 1093,27 1021.27 61,84 -47.80 2.50 6010239,55 556609,25 MWD+IFR+MS 1125.00 15.54 322,30 1117,39 1045,39 67.04 -51.81 2,50 6010244.72 556605.19 MWD+IFR+MS . . BP BP Planning Report 1150,00 16,17 322,30 1141.44 1069.44 72,44 -55.99 2.50 6010250.09 556600,98 MWD+IFR+MS 1175,00 16.79 322.30 1165.42 1093.42 78,05 -60,33 2.50 6010255.67 556596,60 MWD+IFR+MS 1200.00 17.42 322.30 1189,31 1117.31 83,87 -64.82 2.50 6010261,45 556592.06 MWD+IFR+MS 1225.00 18.04 322.30 1213,12 1141.12 89.90 -69.48 2,50 6010267,44 556587,36 MWD+IFR+MS 1250.00 18,67 322.30 1236.85 1164.85 96.12 -74,29 2.50 6010273.63 556582,50 MWD+IFR+MS 1275,00 19.29 322,30 1260.49 1188.49 102,56 -79,27 2.50 6010280.02 556577,48 MWD+IFR+MS 1300,00 19.92 322.30 1284,04 1212.04 109.19 -84.40 2,50 6010286,62 556572.30 MWD+IFR+MS 1325.00 20.54 322.30 1307,50 1235.50 116.03 -89.68 2,50 6010293.42 556566.96 MWD+IFR+MS 1350.00 21.17 322.30 1330.86 1258.86 123.08 -95.12 2,50 6010300,42 556561.46 MWD+IFR+MS 1375,00 21,79 322,30 1354.13 1282.13 130.32 -100.72 2.50 6010307.62 556555,81 MWD+IFR+MS 1400,00 22.42 322.30 1377.29 1305.29 137,76 -106.47 2.50 6010315.02 556550.00 MWD+IFR+MS 1425.00 23.04 322.30 1400.35 1328.35 145.40 -112.38 2.50 6010322,61 556544.04 MWD+IFR+MS 1450.00 23.67 322.30 1423,30 1351.30 153.25 -118.44 2.50 6010330.41 556537,92 MWD+IFR+MS 1475.00 24,29 322,30 1446.14 1374.14 161.28 -124.66 2.50 6010338.40 556531,65 MWD+IFR+MS 1500,00 24.92 322.30 1468.87 1396.87 169,52 -131,02 2.50 6010346.58 556525,22 MWD+IFR+MS 1525,00 25.54 322,30 1491.49 1419.49 177.95 -137.54 2,50 6010354.96 556518.64 MWD+IFR+MS 1550.00 26.17 322.30 1513,98 1441.98 186.58 -144.20 2,50 6010363,54 556511.91 MWD+IFR+MS 1575.00 26,79 322.30 1536,36 1464,36 195.40 -151.02 2,50 6010372,31 556505.02 MWD+IFR+MS 1600.00 27.42 322,30 1558.61 1486,61 204.41 -157,99 2.50 6010381.26 556497.99 MWD+IFR+MS 1625,00 28.04 322,30 1580.74 1508.74 213,61 -165,10 2.50 6010390.41 556490,81 MWD+IFR+MS 1650.00 28.67 322.30 1602,74 1530.74 223.01 -172.36 2.50 6010399,75 556483.48 MWD+IFR+MS 1675.00 29.29 322.30 1624,61 1552.61 232.59 -179.77 2.50 6010409,28 556476.00 MWD+IFR+MS 1700.00 29.92 322.30 1646.35 1574,35 242.36 -187.32 2.50 6010418,99 556468,37 MWD+IFR+MS 1725.00 30,54 322,30 1667.95 1595,95 252,32 -195,02 2.50 6010428.89 556460,60 MWD+IFR+MS 1750.00 31.17 322.30 1689.41 1617.41 262.47 -202.86 2.50 6010438,97 556452.69 MWD+IFR+MS 1775.00 31.79 322.30 1710,73 1638.73 272.79 -210.84 2,50 6010449,24 556444.62 MWD+IFR+MS 1800.00 32.42 322.30 1731.91 1659,91 283.31 -218.96 2.50 6010459,69 556436.42 MWD+IFR+MS 1821.49 32,95 322.30 1750.00 1678,00 292.49 -226.06 2.50 6010468.82 556429.25 End Dir : 1821 1825,00 32.95 322,30 1752.94 1680.94 294.00 -227.23 0.00 6010470.32 556428,08 MWD+IFR+MS 1850.00 32.95 322.30 1773,92 1701,92 304.76 -235.55 0,00 6010481,01 556419.68 MWD+IFR+MS 1875.00 32,95 322.30 1794.90 1722,90 315,52 -243,86 0.00 6010491,71 556411.28 MWD+IFR+MS 1900.00 32,95 322,30 1815.88 1743.88 326,28 -252,18 0.00 6010502.40 556402,88 MWD+IFR+MS 1925,00 32,95 322,30 1836.85 1764.85 337.04 -260.49 0.00 6010513.10 556394.49 MWD+IFR+MS 1940,67 32.95 322,30 1850,00 1778.00 343.78 -265.71 0,00 6010519,80 556389.23 Start Dir 4/1 00 1950.00 33.33 322.30 1857.81 1785,81 347.82 -268.83 4.00 6010523,81 556386.08 MWD+IFR+MS 1967.05 34.01 322.30 1872.00 1800,00 355,30 -274,60 4.00 6010531.25 556380,24 BPRF 1975.00 34,33 322,30 1878.58 1806.58 358,83 -277,34 4.00 6010534.76 556377.48 MWD+IFR+MS 2000,00 35.33 322,30 1899,10 1827.10 370.13 -286.07 4,00 6010545.99 556368.67 MWD+IFR+MS 2025.00 36.33 322.30 1919,37 1847.37 381.71 -295.02 4,00 6010557,50 556359.63 MWD+IFR+MS 2050.00 37,33 322.30 1939.38 1867,38 393,56 -304,18 4.00 6010569.28 556350.38 MWD+IFR+MS 2075.00 38.33 322,31 1959.13 1887.13 405.70 -313,55 4.00 6010581.34 556340.91 MWD+IFR+MS 2100,00 39.33 322,31 1978.61 1906.61 418.10 -323.14 4,00 6010593.67 556331.24 MWD+IFR+MS 2125,00 40,33 322,31 1997,80 1925.80 430.77 -332.93 4,00 6010606.27 556321.35 MWD+IFR+MS 2150,00 41.33 322.31 2016,72 1944.72 443.70 -342.92 4,00 6010619,12 556311.26 MWD+IFR+MS 2175.00 42,33 322.31 2035.35 1963.35 456,90 -353,11 4.00 6010632.24 556300,97 MWD+IFR+MS 2200.00 43,33 322,31 2053.69 1981.69 470,34 -363,50 4.00 6010645.60 556290.48 MWD+IFR+MS 2225,00 44,33 322,31 2071,72 1999.72 484.04 -374.09 4,00 6010659.22 556279.79 MWD+IFR+MS 2250,00 45.33 322,31 2089.45 2017.45 497.99 -384.86 4,00 6010673,08 556268.91 MWD+IFR+MS 2275,00 46.33 322.31 2106,87 2034.87 512.18 -395.82 4,00 6010687,19 556257.84 MWD+IFR+MS 2300.00 47.33 322.31 2123.98 2051,98 526,61 -406,97 4.00 6010701.53 556246,59 MWD+IFR+MS 2325.00 48,33 322,31 2140.76 2068.76 541.27 -418,30 4.00 6010716.10 556235.15 MWD+IFR+MS 2350,00 49,33 322,31 2157.22 2085.22 556.16 -429.80 4,00 6010730.91 556223.54 MWD+IFR+MS 2375.00 50.33 322,31 2173.35 2101.35 571.28 -441 .48 4.00 6010745,93 556211.75 MWD+IFR+MS . . BP BP Planning Report 2400,00 51.33 322.32 2189,14 2117.14 586.62 -453.33 4,00 6010761.18 556199.78 MWD+IFR+MS 2425.00 52,33 322,32 2204.59 2132.59 602,17 -465.34 4.00 6010776,64 556187,65 MWD+IFR+MS 2450.00 53,33 322,32 2219.69 2147.69 617.94 -477.52 4.00 6010792.31 556175,36 MWD+IFR+MS 2475.00 54.33 322,32 2234.45 2162.45 633.91 -489,86 4,00 6010808.19 556162,90 MWD+IFR+MS 2500.00 55.33 322.32 2248.85 2176.85 650.08 -502.35 4,00 6010824.26 556150.29 MWD+IFR+MS 2525,00 56.33 322.32 2262.89 2190,89 666.45 -514,99 4,00 6010840.53 556137.52 MWD+IFR+MS 2550.00 57,33 322,32 2276.57 2204.57 683,01 -527.78 4.00 6010856,99 556124,61 MWD+IFR+MS 2575.00 58,33 322,32 2289.88 2217.88 699.76 -540.72 4.00 6010873,64 556111,54 MWD+IFR+MS 2600.00 59,33 322,32 2302,82 2230.82 716.68 -553.79 4.00 6010890.47 556098,34 MWD+IFR+MS 2625.00 60.33 322.32 2315,39 2243,39 733.79 -567,00 4.00 6010907.47 556085.00 MWD+IFR+MS 2650,00 61.33 322.32 2327.57 2255,57 751,07 -580,35 4,00 6010924.64 556071.53 MWD+IFR+MS 2675,00 62.33 322.32 2339.38 2267.38 768,51 -593,82 4.00 6010941.98 556057.93 MWD+IFR+MS 2679.01 62.49 322,32 2341.24 2269.24 771.32 -595.99 4.00 6010944,78 556055.74 End Dir : 2679 2700.00 62.49 322,32 2350.93 2278.93 786.05 -607.37 0.00 6010959.42 556044,25 MWD+IFR+MS 2725.00 62.49 322.32 2362,48 2290,48 803.60 -620,92 0.00 6010976.87 556030,56 MWD+IFR+MS 2750,00 62.49 322.32 2374.03 2302,03 821,15 -634.47 0,00 6010994.31 556016.88 MWD+IFR+MS 2775.00 62.49 322.32 2385.58 2313.58 838.70 -648,03 0.00 6011011,75 556003.19 MWD+IFR+MS 2800.00 62.49 322,32 2397.12 2325.12 856.25 -661.58 0.00 6011029,20 555989.51 MWD+IFR+MS 2825.00 62.49 322,32 2408.67 2336.67 873.80 -675.13 0.00 6011046.64 555975,83 MWD+IFR+MS 2850.00 62.49 322.32 2420,22 2348,22 891.35 -688.68 0,00 6011064.08 555962,14 MWD+IFR+MS 2875.00 62.49 322.32 2431.77 2359,77 908.90 -702.24 0,00 6011081.53 555948.46 MWD+IFR+MS 2900,00 62.49 322,32 2443.32 2371.32 926,44 -715.79 0.00 6011098,97 555934.77 MWD+IFR+MS 2925.00 62.49 322,32 2454,87 2382.87 943,99 -729.34 0.00 6011116,41 555921,09 MWD+IFR+MS 2950.00 62.49 322,32 2466,41 2394.41 961.54 -742.89 0.00 6011133,86 555907.40 MWD+IFR+MS 2975.00 62.49 322.32 2477,96 2405,96 979.09 -756.45 0,00 6011151,30 555893.72 MWD+IFR+MS 3000,00 62.49 322.32 2489.51 2417,51 996,64 -770,00 0,00 6011168.74 555880.03 MWD+IFR+MS 3025.00 62.49 322,32 2501.06 2429.06 1014.19 -783.55 0.00 6011186,19 555866.35 MWD+IFR+MS 3050.00 62,49 322.32 2512,61 2440.61 1031.74 -797.11 0.00 6011203.63 555852,67 MWD+IFR+MS 3075.00 62,49 322.32 2524,16 2452,16 1049.28 -810.66 0.00 6011221.07 555838.98 MWD+IFR+MS 3100.00 62.49 322.32 2535.70 2463,70 1066,83 -824,21 0,00 6011238.52 555825.30 MWD+IFR+MS 3125,00 62.49 322,32 2547.25 2475.25 1084,38 -837,76 0.00 6011255.96 555811.61 MWD+IFR+MS 3150.00 62.49 322,32 2558,80 2486.80 1101.93 -851.32 0.00 6011273.40 555797.93 MWD+IFR+MS 3175.00 62.49 322.32 2570,35 2498,35 1119.48 -864.87 0.00 6011290.85 555784.24 MWD+IFR+MS 3200.00 62.49 322.32 2581.90 2509,90 1137,03 -878.42 0,00 6011308.29 555770.56 MWD+IFR+MS 3225,00 62.49 322.32 2593.45 2521.45 1154,58 -891,98 0,00 6011325.74 555756.87 MWD+IFR+MS 3250,00 62.49 322.32 2605.00 2533.00 1172.13 -905,53 0.00 6011343.18 555743.19 MWD+IFR+MS 3275.00 62.49 322.32 2616,54 2544,54 1189.67 -919.08 0,00 6011360.62 555729,51 MWD+IFR+MS 3300.00 62.49 322.32 2628,09 2556,09 1207,22 -932,63 0.00 6011378.07 555715.82 MWD+IFR+MS 3325,00 62.49 322.32 2639.64 2567.64 1224.77 -946,19 0,00 6011395.51 555702.14 MWD+IFR+MS 3350,00 62,49 322.32 2651.19 2579.19 1242,32 -959,74 0,00 6011412.95 555688.45 MWD+IFR+MS 3375,00 62.49 322,32 2662.74 2590.74 1259.87 -973.29 0.00 6011430,40 555674,77 MWD+IFR+MS 3400.00 62.49 322.32 2674.29 2602,29 1277 .42 -986,84 0.00 6011447,84 555661,08 MWD+IFR+MS 3425.00 62.49 322.32 2685.83 2613,83 1294,97 -1000.40 0.00 6011465,28 555647.40 MWD+IFR+MS 3450,00 62.49 322.32 2697.38 2625.38 1312,51 -1013,95 0,00 6011482.73 555633.72 MWD+IFR+MS 3475.00 62.49 322.32 2708.93 2636.93 1330,06 -1027,50 0,00 6011500.17 555620.03 MWD+IFR+MS 3500.00 62,49 322,32 2720.48 2648.48 1347.61 -1041,06 0.00 6011517.61 555606,35 MWD+IFR+MS 3525.00 62.49 322,32 2732,03 2660,03 1365,16 -1054.61 0.00 6011535,06 555592,66 MWD+IFR+MS 3550,00 62.49 322.32 2743,58 2671,58 1382,71 -1068,16 0.00 6011552.50 555578.98 MWD+IFR+MS 3575,00 62.49 322.32 2755.13 2683.13 1400,26 -1081,71 0.00 6011569.94 555565.29 MWD+IFR+MS 3600,00 62,49 322.32 2766.67 2694.67 1417,81 -1095,27 0.00 6011587.39 555551.61 MWD+IFR+MS 3625,00 62,49 322.32 2778.22 2706,22 1435,35 -1108,82 0,00 6011604.83 555537.92 MWD+IFR+MS 3650,00 62.49 322.32 2789,77 2717,77 1452.90 -1122.37 0.00 6011622,27 555524,24 MWD+IFR+MS . . BP BP Planning Report 3675.00 62,49 322,32 2801.32 2729,32 1470.45 -1135.93 0.00 6011639.72 555510,56 MWD+IFR+MS 3700.00 62,49 322,32 2812.87 2740.87 1488.00 -1149.48 0.00 6011657.16 555496,87 MWD+JFR+MS 3725.00 62.49 322,32 2824.42 2752.42 1505.55 -1163.03 0.00 6011674.61 555483.19 MWD+IFR+MS 3750,00 62.49 322.32 2835,96 2763.96 1523,10 -1176,58 0,00 6011692.05 555469.50 MWD+IFR+MS 3775.00 62.49 322,32 2847.51 2775,51 1540.65 -1190,14 0.00 6011709.49 555455,82 MWD+IFR+MS 3800.00 62.49 322,32 2859.06 2787,06 1558.20 -1203.69 0.00 6011726.94 555442,13 MWD+IFR+MS 3825.00 62,49 322,32 2870.61 2798.61 1575.74 -1217.24 0,00 6011744.38 555428.45 MWD+IFR+MS 3850.00 62.49 322,32 2882.16 2810.16 1593.29 -1230.80 0,00 6011761.82 555414.76 MWD+IFR+MS 3875.00 62.49 322.32 2893,71 2821.71 1610,84 -1244.35 0,00 6011779.27 555401.08 MWD+IFR+MS 3900,00 62.49 322.32 2905.25 2833,25 1628.39 -1257.90 0.00 6011796,71 555387.40 MWD+IFR+MS 3925.00 62,49 322.32 2916.80 2844,80 1645.94 -1271,45 0.00 6011814.15 555373,71 MWD+IFR+MS 3950.00 62,49 322.32 2928.35 2856,35 1663.49 -1285.01 0.00 6011831.60 555360.03 MWD+IFR+MS 3975.00 62.49 322.32 2939.90 2867.90 1681.04 -1298.56 0,00 6011849.04 555346.34 MWD+IFR+MS 4000,00 62.49 322.32 2951.45 2879.45 1698.58 -1312.11 0,00 6011866.48 555332.66 MWD+IFR+MS 4025,00 62.49 322.32 2963.00 2891.00 1716.13 -1325,66 0.00 6011883.93 555318.97 MWD+IFR+MS 4050.00 62,49 322.32 2974.55 2902,55 1733.68 -1339.22 0.00 6011901.37 555305.29 MWD+IFR+MS 4075.00 62.49 322,32 2986.09 2914.09 1751.23 -1352.77 0,00 6011918.81 555291.60 MWD+JFR+MS 4100.00 62.49 322.32 2997,64 2925.64 1768,78 -1366,32 0,00 6011936.26 555277.92 MWD+IFR+MS 4125.00 62.49 322.32 3009,19 2937.19 1786,33 -1379.88 0.00 6011953,70 555264.24 MWD+IFR+MS 4150,00 62,49 322.32 3020.74 2948.74 1803.88 -1393.43 0.00 6011971,15 555250,55 MWD+IFR+MS 4175.00 62,49 322,32 3032.29 2960,29 1821.43 -1406.98 0.00 6011988,59 555236,87 MWD+IFR+MS 4200.00 62,49 322,32 3043.84 2971.84 1838.97 -1420.53 0,00 6012006,03 555223.18 MWD+IFR+MS 4225.00 62.49 322.32 3055.38 2983.38 1856,52 -1434,09 0.00 6012023,48 555209.50 MWD+IFR+MS 4250.00 62.49 322.32 3066,93 2994.93 1874,07 -1447,64 0.00 6012040,92 555195.81 MWD+IFR+MS 4275,00 62.49 322.32 3078.48 3006.48 1891.62 -1461.19 0.00 6012058,36 555182,13 MWD+IFR+MS 4300.00 62,49 322,32 3090.03 3018,03 1909.17 -1474.75 0,00 6012075.81 555168.45 MWD+IFR+MS 4325.00 62.49 322,32 3101.58 3029.58 1926.72 -1488.30 0,00 6012093.25 555154.76 MWD+IFR+MS 4350.00 62.49 322.32 3113.13 3041.13 1944,27 -1501.85 0.00 6012110,69 555141.08 MWD+IFR+MS 4375,00 62.49 322.32 3124,68 3052.68 1961.81 -1515,40 0.00 6012128,14 555127.39 MWD+IFR+MS 4400.00 62,49 322,32 3136.22 3064,22 1979.36 -1528,96 0,00 6012145.58 555113.71 MWD+IFR+MS 4425.00 62.49 322,32 3147,77 3075.77 1996,91 -1542,51 0.00 6012163.02 555100.02 MWD+IFR+MS 4450.00 62.49 322.32 3159,32 3087.32 2014.46 -1556,06 0.00 6012180.4 7 555086.34 MWD+IFR+MS 4475.00 62.49 322.32 3170.87 3098.87 2032.01 -1569.61 0.00 6012197,91 555072.65 MWD+IFR+MS 4477,45 62.49 322.32 3172.00 3100,00 2033.73 -1570.94 0.00 6012199,62 555071,31 10314" 4500.00 62.49 322.32 3182.42 3110.42 2049.56 -1583.17 0,00 6012215.35 555058.97 MWD+IFR+MS 4525.00 62.49 322.32 3193.97 3121.97 2067,11 -1596.72 0.00 6012232.80 555045.29 MWD+IFR+MS 4550.00 62.49 322.32 3205,51 3133,51 2084,66 -1610,27 0.00 6012250,24 555031,60 MWD+IFR+MS 4575,00 62.49 322.32 3217.06 3145,06 2102.20 -1623.83 0.00 6012267,68 555017,92 MWD+IFR+MS 4600.00 62.49 322,32 3228.61 3156,61 2119.75 -1637.38 0,00 6012285,13 555004.23 MWD+IFR+MS 4625.00 62,49 322,32 3240.16 3168.16 2137,30 -1650,93 0.00 6012302.57 554990.55 MWD+IFR+MS 4650.00 62.49 322.32 3251,71 3179.71 2154,85 -1664,48 0.00 6012320,02 554976,86 MWD+IFR+MS 4675,00 62.49 322.32 3263,26 3191.26 2172,40 -1678,04 0.00 6012337,46 554963,18 MWD+IFR+MS 4700,00 62,49 322.32 3274.80 3202,80 2189.95 -1691.59 0.00 6012354,90 554949.49 MWD+IFR+MS 4725,00 62,49 322,32 3286.35 3214,35 2207.50 -1705.14 0.00 6012372.35 554935,81 MWD+IFR+MS 4750,00 62,49 322.32 3297.90 3225.90 2225,04 -1718,70 0.00 6012389.79 554922.13 MWD+IFR+MS 4775.00 62.49 322.32 3309.45 3237.45 2242.59 -1732,25 0.00 6012407.23 554908.44 MWD+IFR+MS 4800.00 62.49 322.32 3321,00 3249.00 2260,14 -1745.80 0.00 6012424,68 554894,76 MWD+IFR+MS 4825.00 62.49 322,32 3332,55 3260,55 2277.69 -1759.35 0,00 6012442,12 554881,07 MWD+IFR+MS 4850.00 62.49 322,32 3344.10 3272.10 2295.24 -1772.91 0,00 6012459,56 554867.39 MWD+IFR+MS 4875,00 62,49 322,32 3355.64 3283.64 2312,79 -1786.46 0.00 6012477.01 554853.70 MWD+IFR+MS 4900.00 62,49 322.32 3367.19 3295.19 2330,34 -1800,01 0.00 6012494.45 554840,02 MWD+IFR+MS 4925.00 62,49 322.32 3378.74 3306.74 2347,89 -1813,57 0.00 6012511,89 554826,33 MWD+IFR+MS 4931.93 62.49 322.32 3381.94 3309,94 2352.75 -1817.32 0.00 6012516.73 554822,54 Start Dir 4/100 . . BP BP Planning Report 4950.00 62.36 321,52 3390.31 3318.31 2365,36 -1827,20 4.00 6012529.26 554812.57 MWD+IFR+MS 4975,00 62.20 320.40 3401.93 3329.93 2382.55 -1841.14 4,00 6012546.34 554798,50 MWD+IFR+MS 5000.00 62.05 319.29 3413.62 3341.62 2399,44 -1855.39 4,00 6012563,12 554784.12 MWD+IFR+MS 5025.00 61,90 318.16 3425.37 3353.37 2416,02 -1869,95 4.00 6012579.59 554769.44 MWD+IFR+MS 5050.00 61,76 317.04 3437,17 3365,17 2432.30 -1884.81 4.00 6012595.75 554754.46 MWD+IFR+MS 5075.00 61.64 315.91 3449.03 3377,03 2448.26 -1899.97 4.00 6012611.60 554739,18 MWD+IFR+MS 5100.00 61,52 314.79 3460.92 3388.92 2463,90 -1915.42 4.00 6012627,12 554723.62 MWD+IFR+MS 5123.19 61.42 313.74 3472,00 3400,00 2478.12 -1930.01 4.00 6012641.23 554708.92 ruzc 5125.00 61.41 313.65 3472,87 3400,87 2479.22 -1931.16 4.00 6012642.32 554707,76 MWD+IFR+MS 5150,00 61.31 312.52 3484.85 3412.85 2494,21 -1947.18 4,00 6012657.18 554691,63 MWD+IFR+MS 5175.00 61.22 311,38 3496.87 3424.87 2508,86 -1963,48 4.00 6012671,71 554675.21 MWD+IFR+MS 5200.00 61,14 310.25 3508,92 3436,92 2523.18 -1980.06 4.00 6012685.90 554658,53 MWD+IFR+MS 5225,00 61.07 309.11 3521.00 3449.00 2537.15 -1996.91 4,00 6012699,74 554641,58 MWD+IFR+MS 5250.00 61.01 307,97 3533.10 3461.10 2550.78 -2014,01 4.00 6012713.24 554624.37 MWD+IFR+MS 5275.00 60.96 306.82 3545,23 3473.23 2564.06 -2031,38 4.00 6012726.38 554606.90 MWD+IFR+MS 5300.00 60,92 305.68 3557,37 3485,37 2576.98 -2049.00 4.00 6012739.17 554589.18 MWD+IFR+MS 5325,00 60.89 304,54 3569.53 3497.53 2589,54 -2066,87 4.00 6012751,59 554571.22 MWD+IFR+MS 5350.00 60.86 303,39 3581.70 3509.70 2601,74 -2084,99 4.00 6012763,66 554553.02 MWD+IFR+MS 5375.00 60.85 302.25 3593.88 3521.88 2613.58 -2103.34 4,00 6012775.35 554534.58 MWD+IFR+MS 5400,00 60.85 301,10 3606.05 3534,05 2625.04 -2121,92 4,00 6012786,67 554515,92 MWD+IFR+MS 5425,00 60.85 299,96 3618.23 3546.23 2636.13 -2140,72 4.00 6012797,62 554497,03 MWD+IFR+MS 5450.00 60,87 298.81 3630.40 3558.40 2646.85 -2159.75 4.00 6012808.19 554477.92 MWD+IFR+MS 5475.00 60.90 297.67 3642.57 3570.57 2657.18 -2178.99 4,00 6012818.38 554458.61 MWD+IFR+MS 5500,00 60.93 296,53 3654.72 3582.72 2667,13 -2198.44 4.00 6012828,18 554439.08 MWD+IFR+MS 5525.00 60.98 295,38 3666.86 3594.86 2676.70 -2218,09 4.00 6012837,59 554419.36 MWD+IFR+MS 5550.00 61,04 294.24 3678,98 3606.98 2685.88 -2237.94 4.00 6012846.62 554399.45 MWD+IFR+MS 5575.00 61.10 293,10 3691.07 3619.07 2694,66 -2257,98 4.00 6012855,25 554379.34 MWD+IFR+MS 5597.64 61,17 292.07 3702.00 3630,00 2702,27 -2276.28 4.00 6012862,72 554360.98 Ugnu-MA 5600.00 61,18 291.96 3703,14 3631,14 2703.05 -2278.20 4.00 6012863.48 554359.06 MWD+IFR+MS 5625.00 61.26 290.83 3715.18 3643.18 2711.04 -2298.60 4,00 6012871.32 554338,60 MWD+IFR+MS 5639.20 61.31 290,18 3722.00 3650.00 2715,41 -2310.27 4.00 6012875,59 554326.90 Ugnu-MB1 5650.00 61.35 289.69 3727,18 3655,18 2718.64 -2319.17 4.00 6012878.76 554317.97 MWD+IFR+MS 5675,00 61.46 288.56 3739.14 3667,14 2725.83 -2339.91 4,00 6012885.79 554297,18 MWD+IFR+MS 5700.00 61.57 287.43 3751.07 3679.07 2732,61 -2360,81 4.00 6012892,42 554276.24 MWD+IFR+MS 5725.00 61,69 286.30 3762,95 3690.95 2738.99 -2381.86 4.00 6012898,64 554255,14 MWD+IFR+MS 5733.55 61,73 285.91 3767,00 3695,00 2741.08 -2389.09 4,00 6012900.67 554247,89 Ugnu-MB2 5750,00 61.82 285,17 3774,78 3702.78 2744.97 -2403,06 4.00 6012904.45 554233.90 MWD+IFR+MS 5775.00 61,96 284.05 3786.56 3714,56 2750,53 -2424.40 4.00 6012909.85 554212.52 MWD+IFR+MS 5800.00 62,11 282.93 3798,28 3726,28 2755.68 -2445.87 4.00 6012914.84 554191,01 MWD+IFR+MS 5825,00 62.27 281.82 3809.95 3737.95 2760.42 -2467.47 4.00 6012919.41 554169.38 MWD+IFR+MS 5850,00 62.44 280.70 3821.55 3749.55 2764.74 -2489,19 4.00 6012923,57 554147.63 MWD+IFR+MS 5859.07 62,50 280.30 3825,74 3753,74 2766.21 -2497.09 4.00 6012924.97 554139,72 End Dir : 5859 5875.00 62,50 280.30 3833.09 3761,09 2768.74 -2511.00 0.00 6012927.39 554125,79 MWD+IFR+MS 5900,00 62.50 280,30 3844,64 3772.64 2772.70 -2532,81 0,00 6012931.19 554103.95 MWD+IFR+MS 5925,00 62.50 280,30 3856,18 3784.18 2776,67 -2554,63 0,00 6012934,99 554082.10 MWD+IFR+MS 5950.00 62,50 280,30 3867.73 3795.73 2780,63 -2576.45 0.00 6012938,79 554060,26 MWD+IFR+MS 5975,00 62.50 280.30 3879.27 3807.27 2784.60 -2598,27 0,00 6012942.59 554038.41 MWD+IFR+MS 6000,00 62.50 280,30 3890,81 3818.81 2788.56 -2620,09 0,00 6012946,39 554016.57 MWD+IFR+MS 6009,07 62.50 280,30 3895,00 3823.00 2790.00 -2628,00 0,00 6012947,77 554008,64 MWD+IFR+MS 6013.40 62.50 280.30 3897,00 3825.00 2790.69 -2631.78 0,00 6012948.42 554004,86 Ugnu-MC 6025,00 62.50 280,30 3902.36 3830.36 2792.53 -2641,90 0,00 6012950,19 553994,72 MWD+IFR+MS 6050,00 62.50 280,30 3913,90 3841.90 2796.49 -2663.72 0.00 6012953,98 553972,88 MWD+IFR+MS . . BP BP Planning Report 6075.00 62.50 280.30 3925.44 3853.44 2800,46 -2685.54 0.00 6012957.78 553951,03 MWD+IFR+MS 6100.00 62.50 280.30 3936.99 3864.99 2804,42 -2707,36 0.00 6012961,58 553929.19 MWD+IFR+MS 6110.86 62.50 280,30 3942.00 3870.00 2806.14 -2716,83 0.00 6012963.23 553919.70 SBF2-NA 6111,26 62,50 280.30 3942.19 3870.19 2806.21 -2717.18 0,00 6012963.29 553919,35 Start Dir 4/1 00 6125.00 62.63 280.90 3948,52 3876.52 2808.45 -2729,17 4.00 6012965.45 553907,35 MWD+IFR+MS 6150.00 62.87 281,99 3959.97 3887.97 2812.86 -2750.95 4,00 6012969.69 553885.53 MWD+IFR+MS 6175,00 63,11 283.08 3971.32 3899.32 2817.70 -2772.69 4,00 6012974.36 553863.76 MWD+IFR+MS 6176,50 63,13 283.15 3972.00 3900,00 2818,00 -2774.00 4,00 6012974.66 553862,45 MPH-18 T1 Top N 6200.00 63.91 283.73 3982.48 3910.48 2822,89 -2794.45 4.00 6012979,39 553841,96 MWD+IFR+MS 6211.27 64.28 284.01 3987.40 3915.40 2825.32 -2804.29 4.00 6012981,74 553832.10 End Dir : 6211 6225.00 64,28 284.01 3993.36 3921.36 2828.32 -2816.30 0,00 6012984.65 553820.08 MWD+IFR+MS 6244.91 64,28 284.01 4002,00 3930.00 2832,66 -2833,71 0.00 6012988,86 553802,64 SBE4-NC 6250.00 64.28 284.01 4004,21 3932.21 2833,77 -2838,15 0.00 6012989,93 553798,18 MWD+IFR+MS 6275.00 64.28 284,01 4015.05 3943.05 2839.22 -2860,01 0.00 6012995,22 553776.29 MWD+IFR+MS 6279,48 64,28 284.01 4017.00 3945,00 2840.20 -2863,93 0.00 6012996,16 553772,37 SBE2-NE 6300.00 64,28 284.01 4025,90 3953,90 2844,67 -2881,86 0.00 6013000,50 553754.40 MWD+IFR+MS 6325.00 64.28 284,01 4036.75 3964.75 2850.12 -2903,71 0.00 6013005,79 553732.51 MWD+IFR+MS 6350.00 64.28 284,01 4047.60 3975.60 2855.58 -2925.57 0,00 6013011.07 553710.61 MWD+IFR+MS 6375.00 64,28 284.01 4058.45 3986.45 2861.03 -2947,42 0,00 6013016.36 553688.72 MWD+IFR+MS 6383.19 64.28 284.01 4062,00 3990.00 2862,81 -2954,58 0.00 6013018,09 553681.55 SBE1-NF 6389.52 64.28 284,01 4064.75 3992.75 2864.19 -2960.12 0.00 6013019.43 553676.00 Start Dir 6/100 6400,00 64.91 284,01 4069.24 3997,24 2866.49 -2969.30 6.00 6013021.65 553666.80 MWD+IFR+MS 6425,00 66,41 284.01 4079.54 4007,54 2872,00 -2991,40 6,00 6013026.99 553644,66 MWD+IFR+MS 6450,00 67,91 284.01 4089,25 4017.25 2877.58 -3013,76 6.00 6013032.40 553622,27 MWD+IFR+MS 6457.39 68.36 284.01 4092.00 4020,00 2879.24 -3020.41 6.00 6013034,01 553615.60 TSBD-Top OA 6475,00 69.41 284.01 4098.34 4026,34 2883.21 -3036.35 6.00 6013037.86 553599.64 MWD+IFR+MS 6500,00 70,91 284.01 4106,83 4034,83 2888,90 -3059,17 6.00 6013043.38 553576,78 MWD+IFR+MS 6525.00 72.41 284.00 4114,69 4042.69 2894.65 -3082,19 6.00 6013048,95 553553.71 MWD+IFR+MS 6550.00 73.91 284,00 4121.93 4049.93 2900.44 -3105.41 6,00 6013054.56 553530.46 MWD+IFR+MS 6550,25 73.91 284.00 4122,00 4050.00 2900.49 -3105,64 0.00 6013054,62 553530,23 TSBC-Base OA 6575.00 75.41 284,00 4128.54 4056.54 2906.27 -3128,80 6,06 6013060,22 553507.02 MWD+IFR+MS 6600.00 76.91 284,00 4134.52 4062,52 2912.14 -3152.35 6,00 6013065.91 553483.43 MWD+IFR+MS 6625.00 78.41 284.00 4139.86 4067,86 2918,05 -3176,05 6.00 6013071.64 553459,69 MWD+IFR+MS 6650.00 79,91 284.00 4144.57 4072,57 2923,99 -3199,87 6.00 6013077,40 553435,82 MWD+IFR+MS 6675.00 81.41 284.00 4148.62 4076,62 2929.96 -3223.81 6,00 6013083.18 553411.85 MWD+IFR+MS 6699.76 82,90 284,00 4152.00 4080,00 2935,90 -3247.60 6.00 6013088.94 553388,01 TSBB- T op OB 6700,00 82,91 284.00 4152.03 4080.03 2935,95 -3247,84 6.00 6013088.99 553387,77 MWD+IFR+MS 6725,00 84.41 284.00 4154.79 4082.79 2941.97 -3271,95 6,00 6013094,82 553363.62 MWD+IFR+MS 6750.00 85.91 284,00 4156,90 4084,90 2947.99 -3296.12 6.00 6013100.66 553339.41 MWD+IFR+MS 6751.45 86,00 284.00 4157.00 4085,00 2948,34 -3297.52 6,00 6013101.00 553338,00 MPH-18 T2 Top 0 6775,00 86.49 285.33 4158,54 4086.54 2954.29 -3320.25 6,00 6013106,78 553315.23 MWD+IFR+MS 6800,00 87,01 286,74 4159,96 4087.96 2961.18 -3344.24 6,00 6013113.49 553291.19 7-5/8" 6825.00 87.53 288,14 4161.15 4089.15 2968,67 -3368,06 6,00 6013120.79 553267,31 MWD+IFR+MS 6850.00 88.06 289,55 4162.11 4090.11 2976,74 -3391,71 6,00 6013128,68 553243,62 MWD+IFR+MS 6875,00 88.58 290.96 4162,84 4090.84 2985.39 -3415.15 6.00 6013137,15 553220.11 MWD+IFR+MS 6900,00 89.11 292,36 4163.35 4091.35 2994.61 -3438.38 6,00 6013146.20 553196.81 MWD+IFR+MS 6925.00 89.64 293,77 4163.62 4091,62 3004.41 -3461,38 6,00 6013155,81 553173,74 MWD+IFR+MS 6950.00 90.17 295,17 4163.66 4091,66 3014,76 -3484,13 6,00 6013165,99 553150.91 MWD+IFR+MS 6955.96 90,29 295.50 4163.64 4091.64 3017.31 -3489,52 6,00 6013168,50 553145.51 End Dir : 6955 6975.00 90.29 295.50 4163.54 4091,54 3025,51 -3506.70 0,00 6013176.57 553128,26 MWD+IFR+MS 7000.00 90.29 295.50 4163.41 4091.41 3036,27 -3529,27 0,00 6013187.16 553105,62 MWD+IFR+MS 7025.00 90.29 295,50 4163.29 4091.29 3047.04 -3551.83 0,00 6013197.75 553082.98 MWD+IFR+MS 7050.00 90,29 295,50 4163,16 4091.16 3057,80 -3574,39 0.00 6013208,34 553060.33 MWD+IFR+MS . . BP BP Planning Report 7075.00 90.29 295.50 4163.03 4091.03 3068.57 -3596.96 0,00 6013218,94 553037.69 MWD+IFR+MS 7100,00 90.29 295,50 4162.91 4090,91 3079,33 -3619,52 0.00 6013229.53 553015.05 MWD+IFR+MS 7125.00 90.29 295.50 4162.78 4090.78 3090.09 -3642.08 0.00 6013240.12 552992.41 MWD+IFR+MS 7127.60 90.29 295.50 4162.77 4090.77 3091.21 -3644.43 0.00 6013241,22 552990,05 Start Dir 10/10 7150,00 90.27 297,74 4162.66 4090,66 3101.25 -3664.45 10.00 6013251,10 552969.95 MWD+IFR+MS 7175,00 90,25 300.24 4162,54 4090,54 3113,37 -3686,32 10.00 6013263.05 552948.00 MWD+IFR+MS 7200.00 90.22 302.74 4162.44 4090.44 3126.43 -3707.64 10,00 6013275,95 552926,59 MWD+IFR+MS 7225.00 90,20 305,24 4162.35 4090,35 3140.40 -3728.36 10.00 6013289,77 552905,76 MWD+IFR+MS 7250.00 90,18 307,74 4162.27 4090,27 3155,27 -3748.46 10.00 6013304.48 552885.55 MWD+IFR+MS 7275,00 90,15 310.24 4162,20 4090.20 3171,00 -3767.89 10.00 6013320,06 552866.01 MWD+JFR+MS 7300.00 90.13 312.74 4162.13 4090.13 3187.56 -3786.61 10.00 6013336.48 552847.16 MWD+IFR+MS 7325,00 90.10 315,24 4162.09 4090,09 3204,93 -3804,59 10.00 6013353.70 552829.04 MWD+IFR+MS 7350.00 90.07 317.74 4162,05 4090.05 3223.06 -3821.80 10,00 6013371.70 552811.70 MWD+IFR+MS 7375.00 90.05 320.24 4162.02 4090.02 3241.92 -3838.21 10,00 6013390,44 552795.16 MWD+IFR+MS 7400.00 90.02 322,74 4162.00 4090.00 3261.48 -3853,77 10.00 6013409,88 552779.44 MWD+IFR+MS 7422,57 90.00 325.00 4162.00 4090.00 3279.71 -3867,08 10.00 6013428.00 552766.00 MPH-18 T3 MID 0 7425.00 89.97 325.24 4162.00 4090.00 3281.71 -3868.47 10,00 6013429.99 552764,60 MWD+IFR+MS 7450.00 89.66 327.72 4162.08 4090.08 3302.55 -3882.27 10,00 6013450,72 552750,64 MWD+IFR+MS 7475.00 89,35 330.20 4162.30 4090,30 3323,96 -3895,16 10.00 6013472,04 552737.59 MWD+IFR+MS 7500.00 89,04 332.68 4162.65 4090,65 3345,92 -3907.11 10.00 6013493.90 552725.47 MWD+IFR+MS 7525.00 88.73 335.16 4163,14 4091.14 3368.37 -3918.09 10.00 6013516.26 552714.32 MWD+IFR+MS 7550.00 88.42 337,65 4163.76 4091,76 3391,27 -3928.10 10.00 6013539,08 552704.14 MWD+IFR+MS 7575,00 88.12 340.13 4164.52 4092.52 3414,58 -3937.10 10.00 6013562.32 552694.97 MWD+IFR+MS 7600.00 87,82 342.61 4165.40 4093.40 3438.25 -3945.08 10,00 6013585.93 552686.81 MWD+IFR+MS 7625.00 87.52 345.10 4166.42 4094.42 3462.24 -3952.02 10,00 6013609,87 552679,68 MWD+IFR+MS 7650.00 87,23 347.58 4167.56 4095,56 3486,51 -3957,92 10.00 6013634,08 552673.60 MWD+IFR+MS 7675.00 86.95 350.07 4168.83 4096.83 3511.00 -3962.76 10.00 6013658.54 552668.57 MWD+IFR+MS 7700.00 86.67 352.56 4170.23 4098,23 3535.67 -3966,53 10,00 6013683,18 552664.62 MWD+IFR+MS 7725,00 86.39 355,05 4171.74 4099,74 3560.48 -3969,22 10.00 6013707,96 552661.74 MWD+IFR+MS 7750,00 86.13 357.54 4173,37 4101.37 3585.37 -3970.83 10.00 6013732.84 552659.93 MWD+IFR+MS 7775.00 85.87 0.03 4175.12 4103.12 3610.30 -3971.36 10,00 6013757.76 552659,22 MWD+IFR+MS 7793.43 85,68 1.87 4176.48 4104.48 3628,68 -3971,06 10.00 6013776,14 552659.38 End Dir : 7793 7800.00 85,68 1.87 4176,97 4104.97 3635,23 -3970.84 0.00 6013782.69 552659,55 MWD+IFR+MS 7800.38 85,68 1.87 4177,00 4105.00 3635.61 -3970.83 0,00 6013783,07 552659,55 SBA5-Base OB 7825.00 85.68 1,87 4178.85 4106,85 3660,15 -3970,03 0,00 6013807.61 552660.17 MWD+IFR+MS 7850.00 85.68 1,87 4180.74 4108,74 3685,06 -3969.22 0.00 6013832.52 552660.79 MWD+IFR+MS 7875.00 85.68 1.87 4182.62 4110.62 3709.98 -3968.40 0,00 6013857.44 552661.42 MWD+IFR+MS 7879.47 85.68 1.87 4182.96 4110,96 3714.43 -3968,26 0,00 6013861,90 552661.53 Start Dir 4/100 7900,00 86,50 1,87 4184,36 4112,36 3734.90 -3967,59 4,00 6013882.37 552662.04 MWD+IFR+MS 7925,00 87,50 1.87 4185,66 4113.66 3759.85 -3966.78 4,00 6013907.33 552662.66 MWD+IFR+MS 7950.00 88,50 1.86 4186.54 4114.54 3784.83 -3965.97 4,00 6013932,30 552663,29 MWD+IFR+MS 7975.00 89,50 1,86 4186.97 4114,97 3809.81 -3965,15 4,00 6013957,29 552663.91 MWD+IFR+MS 7978,72 89.65 1,86 4187,00 4115,00 3813.52 -3965.03 4,00 6013961.00 552664.00 MPH-18 T4 MID 0 8000,00 89.64 1.01 4187,13 4115.13 3834.80 -3964.50 4,00 6013982.28 552664,37 MWD+IFR+MS 8025,00 89.62 0.01 4187.29 4115.29 3859,80 -3964.28 4,00 6014007.28 552664.40 MWD+IFR+MS 8050.00 89,61 359.01 4187.46 4115.46 3884,80 -3964.49 4.00 6014032,27 552664.00 MWD+IFR+MS 8075,00 89.59 358,01 4187,63 4115.63 3909.79 -3965.14 4.00 6014057,25 552663.16 MWD+IFR+MS 8100.00 89.58 357.01 4187,81 4115.81 3934.76 -3966,23 4,00 6014082,22 552661,88 MWD+IFR+MS 8125.00 89.57 356,01 4188.00 4116,00 3959,71 -3967,75 4,00 6014107.16 552660.17 MWD+IFR+MS 8150.00 89,55 355,01 4188.19 4116,19 3984,64 -3969.71 4,00 6014132.06 552658.03 MWD+IFR+MS 8175,00 89.54 354,01 4188.39 4116.39 4009,52 -3972.10 4.00 6014156.92 552655.45 MWD+IFR+MS 8200.00 89,53 353.01 4188.59 4116.59 4034.36 -3974.93 4.00 6014181.74 552652.43 MWD+IFR+MS . . BP BP Planning Report 8225.00 89.51 352.01 4188,80 4116,80 4059.14 -3978.19 4.00 6014206.49 552648.98 MWD+IFR+MS 8250.00 89.50 351.01 4189.02 4117.02 4083,87 -3981,88 4.00 6014231.19 552645,11 MWD+IFR+MS 8275,00 89.49 350.01 4189.24 4117.24 4108.53 -3986.00 4.00 6014255,81 552640,80 MWD+IFR+MS 8300,00 89.47 349,01 4189.47 4117.47 4133.11 -3990.55 4.00 6014280.35 552636,06 MWD+IFR+MS 8325.00 89.46 348.01 4189.70 4117.70 4157.60 -3995.53 4.00 6014304,81 552630.89 MWD+IFR+MS 8350.00 89.45 347,01 4189,94 4117.94 4182.01 -4000.94 4.00 6014329,17 552625,30 MWD+IFR+MS 8375,00 89.44 346,01 4190,18 4118.18 4206,32 -4006.77 4.00 6014353.43 552619,29 MWD+IFR+MS 8394.89 89.43 345.21 4190.38 4118.38 4225,59 -4011,71 4.00 6014372.66 552614.20 End Dir : 8394 8400.00 89.43 345.21 4190.43 4118.43 4230,53 -4013.02 0.00 6014377.59 552612.86 MWD+IFR+MS 8425,00 89.43 345.21 4190,68 4118,68 4254.70 -4019.40 0,00 6014401.71 552606,29 MWD+IFR+MS 8450.00 89.43 345.21 4190.93 4118.93 4278.87 -4025,78 0,00 6014425.83 552599.73 MWD+IFR+MS 8475.00 89.43 345.21 4191.18 4119,18 4303.04 -4032,15 0.00 6014449,95 552593.17 MWD+IFR+MS 8500.00 89.43 345.21 4191.43 4119.43 4327.21 -4038.53 0.00 6014474,07 552586.61 MWD+IFR+MS 8525,00 89.43 345,21 4191,68 4119,68 4351.38 -4044,91 0.00 6014498.19 552580,04 MWD+IFR+MS 8550.00 89.43 345.21 4191.93 4119.93 4375.55 -4051.29 0.00 6014522.31 552573.48 MWD+IFR+MS 8556.00 89.43 345,21 4191.99 4119,99 4381.35 -4052.83 0.00 6014528,09 552571,91 41/2" 8556,67 89.43 345.21 4192,00 4120,00 4382.00 -4053,00 0,00 6014528,74 552571,73 MPH-18 T5 MID 0 ./ WELL DET.--\lLS """, +w.s +EI·W Noon", -. Latit:l.u:k Loo¡¡i- 8101 PlanMPH·ig 11%.95 ¡161.65 6O!0178.œ 55665151 70"26'lM36N !49"3:2'16.865W NlA o 270 ANTI-COLLISION SETTINGS COMPANY DETAILS Dr Amoco Interpolation Method:MD Depth Range From: 35.00 Maximum Range: 1052.17 In""",,!: 25,00 To: 8556.67 Refffence: Pian: WP04 From Colour o o 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 8000 See MD Inc Ax! SURVEY PROGRAM lRpth Fm Depth To SurveylPlan CB.GYRO-SS MWD+tFR+MS ToMD o 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 8000 9000 Tool WELLPATH DETAILS 72'PrePlrm 72JJOft 317.23<> (toO 0.00 35.00 . BP-GDB Anticollision Report . Company: BP Amoco Date: 6130/2004 Time: 13:32:02 Page: 1 Field: Milne Point Reference Site: M pt H Pad Co-ordinate(NE) Reference: Well: Plan MPH-18, True North Reference Well: Plan MPH-18 Vertical (fVD) Reference: 72' Pre Plan 72.0 Reference Wellpath: Plan MPH-18 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 35.00 to 8556.67 ft Scan Method: Trav Cylinder North Maximum Radius: 1052.17 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 6/16/2003 Validated: No Version: 2 Planned From To Survey Toolcode Tool Name ft ft 35.00 1000.00 Planned: WP04 V78 CB-GYRO-SS Camera based gyro single shots 1000.00 8556.67 Planned: WP04 V78 MWD+IFR+MS MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in .'. '. L/ 1/17. PO 311).,00 10.750 }.S~t> 103/4" 6800.00 4159.96 7.625 9.875 7-5/8" 8556.00 4191.99 4.500 6.7S0 4 1/2" Summary < Offset Wellpath > Reference Offset Ctr-Ctr No-Go Allowable '. Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft M pt G Pad MPG-G-17 MPG-17 VS Out of range M pt H Pad MPH-02 MPH-02 V1 498.01 500.00 243.04 13.01 230.03 Pass: Major Risk M pt H Pad MPH-03 MPH-03 V1 783.80 800.00 180.14 17.42 162.72 Pass: Major Risk M pt H Pad MPH-04 MPH-04 V1 511.73 500.00 121.15 11.35 109.80 Pass: Major Risk M pt H Pad MPH-05 MPH-OS V1 605.75 600.00 151.38 11.41 139.97 Pass: Major Risk M pt H Pad MPH-06 MPH-06 V1 600.64 600.00 208.74 11.57 197.16 Pass: Major Risk M Pt H Pad MPH-10 MPH-10 V9 515.27 500.00 262.70 9.58 253.12 Pass: Major Risk M Pt H Pad MPH-11 MPH-11 V6 566.11 600.00 237.49 10.26 227.23 Pass: Major Risk M pt H Pad MPH-12 MPH-12 V2 804.01 800.00 201.97 15.96 186.01 Pass: Major Risk MPtHPad MPH-13 MPH-13 V4 989.58 1000.00 132.04 20.70 111.35 Pass: Major Risk M pt H Pad MPH-13 MPH-13A V4 984.64 1000.00 131.85 20.45 111.40 Pass: Major Risk M Pt H Pad MPH-14 MPH-14 V7 1000.94 1000.00 113.63 20.62 93.01 Pass: Major Risk M Pt H Pad Plan Chico Chico V2 Plan: Chico W 601.79 600.00 148.32 13.23 135.09 Pass: Major Risk M Pt H Pad Plan Groucho Groucho V1 Plan: Grouc 1501.45 1500.00 33.31 0.00 33.31 Pass: NO ERRORS M pt H Pad Plan Harpo Harpo V1 Plan: Harpo W 1186.97 1200.00 104.35 23.72 80.63 Pass: Major Risk M Pt H Pad Plan MPH-18 Plan MPH-18 L 1 VO Plan 6400.00 6400.00 0.00 0.00 0.00 FAIL: NOERRORS M pt H Pad Plan MPH-18 Plan MPH-18 L2 VO Plan 6000.00 6000.00 0.00 0.00 0.00 FAIL: NOERRORS M pt H Pad Plan Neo (MPH-16) MPH-16 L1 VO Plan: MPH 598.45 600.00 61.78 13.85 47.93 Pass: Major Risk M Pt H Pad Plan Neo (MPH-16 ) MPH-16 V1 Plan: MPH-16 598.45 600.00 61.78 13.92 47.86 Pass: Major Risk M Pt H Pad Plan Smith Smith V2 Plan: Smith W 399.98 400.00 148.55 9.S8 138.97 Pass: Major Risk M Pt H Pad Plan Trinity Trinity V1 Plan: Trini 400,00 400.00 147.30 0.00 147.30 Pass: NOERRORS M PtI Pad MPI-04 MPI-04A V5 6364.98 6600,00 647.38 149.68 497.70 Pass: Major Risk M Pt I Pad MPI-04 MPI-04AL 1 V2 6000.59 7207.00 620.91 159.89 461.02 Pass: Major Risk M pt J Pad MPJ-04 MPJ-04 V1 5518.75 5200.00 202.61 168.06 34.54 Pass: Major Risk M PtJ Pad MPJ-05 MPJ-05 V1 Out of range M Pt J Pad MPJ-07 MPJ-07 V1 8023.81 4300.00 305.31 129.93 175,38 Pass: Major Risk M pt J Pad Plan MPJ-Persphone Plan MPJ-Persphone VO Out of range _. ,..--<.+ -.+ 0.. 49 I 49 32 (){) N . SONDRA D STEWMAN BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 . 89-6/1252 108 "Mastercard Check" DATE PAY TO THE /' ;<""- r /, /1 $ n j'\,,,\ ~--'¡~--'- ORDER OF /-"..L-c ,--'::>,'\_..J'-- I ~,...J,...J 'UÙ-~~--~-· j~ -« \1' \, ~ ,",~.r~~', U-r1'€....~\...L-ý'&~ w-~ UtX\::t~ --~'-'-'---'------- -,,_uOOLLARS First National Bank Alaska Anchorage. AK 99501, , "-1A/"'\ T\ ¡ \ - \ ç- II \ \, \ ¡ 7 MEMO I I i,.... n l ~ \ Í"".. '. \, ¡.-.... '^- ~.--::-I 1..,-.,__ ,_ ""D ~ .:-.\ ~.....~\ T '€--~-c';:::, I: . 2 5 2000 b 0 I: qq. ~ III b 2 2 7111 . 5 b ~ II- 0.0 B . . TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRIA TE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME m¡?a. fI-/? PTD# 2-or!,.. 17 tf ~ eJ/Ð-L> pmEAJ-r-- CHECK WßA T ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI Tbe permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. . (If API number Production sbould continue to be reported as last two (2) digits a function of tbe original API number, stated are between 60-69) above. Pll.-OT HOLE In accordance witb 20 AAC 25.005(1), all (PH) records, data and logs acquired for tbe pilot bole must be dearly differentiated in botb name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to full EXCEPTJON compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumestbe liability of any protest to tbe spacing exception tbat may occur. DRY DITCH An dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals through target zones. Rev: 07/]0/02 C\jody\templates Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 Well Name: MILNE PT UNIT SB H-18 Program DEV Well bore seg PTD#: 2041740 Company BP EXPLORATION (ALASKA) INC Initial Classrrype DEV I PEND GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal 1 P~rmiUee attache~, , , , , , , , , y~s , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , 2Leas~ ,number appropriate , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , Yes, , El'!tire well JI'! .t\DL 02,5906, , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , 3 ,UÐique weltn_arn~_a!ld oumb_er _ _ , , _ , , , , _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ y~s _ _ _ _ _ _ _ _ _ , , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ 4 WelllQcat~d in_a_d_efil'!e~pool , , , , , , , , , _ , , _ _ , , , , , , , , , _ , y~s _ _ _ , , , , MiJnePoint Sc;hra,derJ3Iuff Oil I?Qol (5251~O), gQvemed by_CO 477, , , , , , , , _ , , , , , , _ , 5 WeJUQcated pr_operdistance from driJling ul'!itboUl'!d,ary_ _ , , _ _, _ _ _ _ _ , , , , , , , , _ _ _ y~s _ _ _ , _ _ , _ _ , , _ _ _ , , , , , _ _ _ _ _ , _ _ _ , , , , , _ _ , _ _ _ _ , , , , , , , , , , _ 6 WelllQcated proper ,distance_ from other welJs_ _ , , , _ , _ _ _ , , , , , y~s , , _ _ _ , _ CO ~77: !¡p~CifiesgpvemmentaJ Qtr-,Qtr:Qtr !¡eçtjo,n; proposed, well_col'!fortTlsto this req,uireme_nt. _ _ _ _ , , , , _ _ _ 7 ,S,utficieI'!Lacreag.e_ayail<lble indrilliog unjL , , , , , _ _ , , _ , , , _ _ _ _ _ _ _ _ _ , _ , , , , , , _ Yes _ _ _ _ _ , _ , _ , _ _ _ _ _ _ , , _ _ _ _ _, _ _ _ , _ , _ , _ _ , , _ , _ _ _ _ _ _ , , , , _ , 8 If deviated, js, wellbQre platil'!cJuded , , , , _ , , _ _ _ _ _ _ _ , , , , _ , , , , ,Y~s _ _ _ , , , , , , , _ , _ _ _ _ _ , _ , , _ _ _ _ _ _ _ _ _ , , , _ , 90J)erator Ol'!ly affected party _ _ , , , , , , _ , , _ _ , , _ _ , , _ _ _ _ y~s _ _ _ _ , _ , , , , , _ _ , , _ _ , _ _ , , , , _ _ , _ _ _ _ _ _ _ _ _ _ , , , , , , _ _ _ _ _ , , , _ _ , , _ _ 10 _OJ)erator has_apprppriate_bond inJorce , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ , _ , _ _ _ y~s _ _ _ _ _ , , , , , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ , , _ _ , _ _ _ _ _ _ _ _ , _ _ _ , _ _ _ _ _ _ _ _ _ _ , _, ,_ _ _ _ _ _ _ _ 11 P~lTT)it~!l Þe issued wjthout conservatiol'! order, , _ _ _ , , _ , , _ _ , , , _ _ _ _ y~s _ _ _ , , , , _ , , , , _ , , , , , _ _ _ _ , , _ , _ _ _ _ _ _ _ _ , , , , _ _ _ _ _ , , , , , _ , _ , Appr Date 12 P~lTT)itc_a!l Þe issued wjthQut ad,mil'!i!¡tratille_apprpval _ _ _ _ _ , , _ _ _ _ , , , , , _ _ _ _ _ _ y~s , , _ _ , _ _ _ _ _ _ _ _ _ _ , , , , , , , , , _ _ _ _ _ _ _ , _ , , , , _ _ _ , _ _ _ _ _, _'' _ _ , _ _ , SFD 9/15/2004 13 Can permit be approved before 15-day wait Yes 14 WeJIJQcated withil'! area al'ld strata authorized byJojectioo Ord~r # (puUO# incpmrnents1-(FQr_ NA _ , , , _ _ _ _ _ _ _ _ , _ _ _ , _ , _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ , , _ _ _ _ , , , , _ , , 15 _AJI welJs,withtnJl4J'uile_area_of review jd~olified (Fpr !iervj~we[l OI'!IYL _ _ _ _ _ _ _ , , , , _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , , _ _ _ _ _ _ _ _ _ _ _ _ _ , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre-produ~ed injector; ~ur<ltion_of pre-J)roduc;tiol'! teS!i than:3 mOl'!ths_ (Forservtce wel[ QnJy) , , NA _ , , _ , , , , , , , , _ _ _ _ _ _ , _ _ _ , _ , _ , _ , , , _ _ _ _ _ , _ _ , _ _ _ _ _ _ , , _ , _ , _ _ 17 ACMP_F:ïl'ldjng9fConsistenc;yh,asÞee,nJs.sued_forJhisproject _, _ _, _ _" _", _ _NA" _ _ _ _ _WelJdrilledfrom exjstiog pad '" _ _ _ _ _" _ _"', _ _", _ _ _ _ _ _" _'"" _ _ _ _ _ _"", _ __ Geologic ~:) I Engineering Commissioner: :, ,~:t Q'\~.D.'ï... '. C...ommissioner: S!gn~ tí}i .~.. ,ii".- ·f>'·r-I\I&··'-·~IIII.I"· . '. ...."... ~,=rwj~"~unl: .... .-'J~--~:'-/ Administration Engineering Appr Date TEM 9/15/2004 /r- Geology Appr SFD Date 9/14/2004 - - - - - - 18Condu_ct9r !¡tril'lgprovided , , , _ , , , , , , _ _ _ _ _ _ _ _ , , , , _ _ , , _ , _ _ , _ _ _ , , , y~s _ , _ _ _ , , _ _ _ _ _ _ _ _ _ _ _ , , , , , , , _ _ _ _ _ _ _ _ , , , , , _ , _ _ , _ _ _ _ _ _ , , , , , , , , _ _ _ _ _ _ _ , , , , _ _ _ 19 ,S,u(fac~,cas.il'lgprotec.ts.aILknown,USDW!¡ _ _ _ _ _ _ _ _, , _ , , , , , _, , , _ _ _ _ _ , , , _ "NA ,_ _ , _ _Maquife'!¡ex.empt~d,AOCFR1~7,:I02Jb)(3), , , , " _ , , _ _ _ _ _ _ _ _ , _, , , , , , _ _ _ _ _ _ _ _ , , _ , , 20 _CMTvoladequateJo circ,utate,oÐ_cOl'!d_uctoc& !¡uJfcsg , , , _ _ _ , _ _ _"""" y~s _ _ _ _ _ _ , , _ , _ , , , , , _ , _ _ _ , _ _ _ , _ , , , , _ , , , , , , _ _ _ _ , _ _ _ _ , _ _ _ _ _ _ _ _ , , , , , , , , 21 _CMTv_oladequateJotie-inJQngstringto,su(fç¡¡g_ _ _ , , , , , , , _ _ _ _ _ _ _, _ _ , , , No_ _ , _ _ , , _.t\l'!y_hydroc;arbon_z0l1eswjlLb~,cO\,lere_d_pJus_50Q'._ , _ _ _ _ _ _ _ _ _" _ , , , _ _ _ _ _ _ _ , , , , , _ , _ 22 _CMTwilJ c;over,aH !<l'!ow_n,pro_ductiYe horilon_s_ _ _ _ , , _ _ , , , _ _ _ _ , _ , _ _ No_ _ _ _ _ _ ,SloUedJiner_complelion!¡ plal1ned. , _ , _ _ _ _ _ _ , , _ _ , _ _ , , _ _ _ _ _ , _ _ , 23 _Casing desig!l!¡ ad_e(1ua_te fpr C,T, B&permafrpst , _ _ _ , _ _ _ _ _ , , , , , , , _ _ , _ _ , _ _ _ Yes _ _ _ _ _ _ _ _ _ , , , , _ _ , , _ , _ _ _ _ , , , , , , _ , _ _ _ _ _ 24 _Adequ<ltetankageor re_serve pit _ _ , _ _ , _ , _ , , _ _ _ _ , _ _ _ , , , , _ , , y~s _ _ _ _ _ _ ,Rig jsequippe,d,with st~eLpit!¡, _ No re!¡eJ'le_pjtJ)lanoe,d, All wa!ite toapprove~,djspos_al wells,_ _ 25 !fare-drill. has_a_ to:403 for <lbandOl1meÐt be~o approved, , , _ _ _ _, _ _ _ ,NA _'"" _ , , , , _ _ _ _ _ _ _ , , _ , _ _ ' , _ _ _ _ _ _ _ , , , , , , , , _ _ _ _ , , , , _ , _ _ 126 _Adequ<ltewellbore!ieparatjoÐ_proJ)O!ied, , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s, , , _ _ , _I?rp~imityan<lly!¡i!¡ pertorme,d, çJose approaçhe_sJdentjfi~d,_ TraveJiog.cylil'lderplotproyided_. _GyrOs_pp!¡sjbJe, _ _ _ 127 Ifdjverter required, dQes jt meet regulatioos_ , , _ , _ _ _ _ _ _ , _ , , , , _ _ _ _ _ _ _ , _ _ _ _ _ , y~s _ , , , , , , _ _ _ _ _ , _ _ _ _ _ _ _ _ _ , , , , , , , _ 28 _Drilling fJujdprogram schematic & eCl-uipJistadequate, _ , _ _ _"", _ _ _ , , , , , _ _ _ _ _ y~s _ _ _ _ , , Maximum expected fprma.tiOI1 pres.suœ,9,REMW._ Planl1e~MW jniotertTl_ediatea!ld 06 Jateralup to_ lO,6pJ)g. 29 ,BOPEs"dp_they meetregulatiol1, ,_ _ _ _ _ _ , , _ , , , , _ _ _ _ _ _ , _ _ , , , , y~s _ _ _ _ _ _ _ , _ , , , _ _ _ _ , _ , , , , _ _ _ _ _ _ _ _ , _ _ _ , _ _ , , , , _ , _ _ 30 _BOPE_pressratingapJ)ropriate;Jestto(putp!¡igiÐ,cOmmel'!tsL _ _" _ _, _" _ _, _ _ _ _ _ _ y~s_, _ _ _, ,M.t\SI? çalc;uJated_at 1685J)si. Planoe_dtestpress_ure350Qpsi. _ _ _, _" _ _ _ _ _"" __ 31 Choke manifold complies_ w/APIRf>-53 (May 64)_ _ _ _ _ _ _ _ _ , , _ _ , , _ _ _ _ _ _ _ Yes, , _ _ , _ _ _ _ _ , , , _ , , _ _ _ _ , _ _ _ _ _ _ _ _ , , , , , , _ _ _ 32 Work will oc;c,ur withoutoperatjonshutdown_ , _ _ _ _ _ _ _ , , , , , , , _ _ _ _ _ _ _ , _ _ , , , Yes _ , _ _ _ , , _ _ _ _ _ , , _ _ _ _ , , _ , _ , _ _ _ _ _ , , _ _ , , _ _ _ _ _ _ _ _ , , , , , , , , _ , _ _ , , , , , , , , _ _ 33 ls.pres.ence_QfH2Sgas_probaÞle, _", _ _ _ _ '_, _ _ _ _ _ _ _ No, _ _ _ _ _ _ ,,1:I2Sisnotexpe_cted._Rigis.equipped_with_sel1so(S_andalarms _ _ _ _ _ _ _""" _" _ _ _ "_" _ _ __ 34 MeçhanicaLcpodilionPfwellswithil'!.t\ORyerified(For_s_ervicewelJonly)"", _ _, _ _ _ _ _ _ NA """ _ _ _ _ ,_ _ _ _ _ _ _ _", _ _ _, _ _ _ _ "" _" _ _ _, 35 P~rmit can Þe issued w/o, hydrogen s_ulfide measures _ _ _ _ _ _ _ _ , , , " _ _ _ _ _ _ _ 36 Data,preseoted on_ potential pverpressure ,ZOl'!es _ _ _ _ _ , , , , , _ _ _ _ _ _ 37 _Seismic_analysjs Qf shallow gas,zpoes_ _ , , , _ _ _ _ _ 38 _S~abed _col'!djtipo survey (if off-shore) , , , _ _ _ _ , , , , , , _ , _ _ _ _ 39 ,Contact l1amelphOl1eJor_weekly progre!is,reports [exploratory only] , , _ _ _ _ , _ , Date y~s _ _ _ , _ , ,I?er ,S!<ip ,C_oYl1er,BP_o_n9lt4l0<:¡:, No H2S kl'!own jn_ SchraderBluff_res.ervoir!i atH-l?ad, . y~s . _ _ _ _ Gradiel'!t8,35 J)pg EMW to top ,S_cbrade.r Bluff, then raisesJo 9.a J)pg EMW~ wiJl be drjlled with tO~Q -10,6ppg, _ . . . _ _ _ , _ _NA . _ . . Hydrates, h_ave be_en eocouotered in H-I?ad_ weJI!¡ between 17QO & 3QOO'_lVD, Noted jn Drilling Ha2:ards_s~ctio(l. "NA_ _ _ _ _ _ _ _ _ _ _ _"" _ _ _ _ _ _" _ _ _"""" _" _ _ _ _ _ _ _ _ _ _, _ _"'" _ _, _" NA_ "'" _ _ _ _", _ _""", _ _ _ _ _ _ _ _ _"""" _ _ _ _ _""" _ __ Date Expect elevated reservoir pres$ure due to offset injection at J-Pad, ?-/¿-d~ o o . . - e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . ;(f) 'i -/7'/ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 05 08:16:53 2004 Reel Header . -tfl.. ' 1?-8;z. D Service name........... ..LISTPE Date.................... .04/11/05 Origin.................. .STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Previous Reel Name.... ...UNKNOWN Comments........... ... ...STS LIS Writing Library. Scientific Technical Services Tape Header Service name...... ..... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/05 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name... ............ .UNKNOWN Continuation Number..... .01 Previous Tape Name. . . . . . .UNKNOWN Comments...... .......... .STS I,IS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPH-18 500292322400 B.P.Exploration (Alaska) Inc. Sperry-Sun Drilling Services 05-NOV-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003302792 C.A. DEMOSKI D. GREEN MWD RUN 2 MW0003302792 C.A. DEMOSKI D. GREEN MWD RUN 4 MW0003302792 C.A. DEMOSKI D. GREEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0003302792 C.A. DEMOSKI D. GREEN MWD RUN 6 MW0003302792 C.A. DEMOSKI D. GREEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 34 13N 10E 3026 3986 MSL 0) 69.60 35.60 # WELL CASING RECORD OPEN HOLE CASING DRILLERS . 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT SIZE (IN) 13.500 9.875 6.750 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 114.0 4562.0 6910.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 2 - 6 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 5 & 6 ALSO INCLUDED AT-BIT INCLINATION (ABI). NO PROGRESS WAS MADE ON MWD RUN 3 DUE TO A TOOL FAILURE. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 10/20/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. LATERAL WELLBORES WERE SHIFTED/CORRECTED TO THE MAIN MPH-18 WELLBORE, IF APPROPRIATE. 6. MWD RUNS 1,2 4-6 REPRESENT WELL MPH-18 WITH API#: 50-029-23224-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8639'MD/4226'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS. $ File Header Service name..... ........STSLIB.001 Service Sub Level Name... Version Number.. ....... ..1.0.0 Date of Generation...... .04/11/05 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # 1 and clipped curves; all bit runs merged. .5000 FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ START DEPTH 69.5 114.5 4529.0 4529.0 4529.0 4529.0 4529.0 . STOP DEPTH 8582.5 8639.0 8590.0 8590.0 8590.0 8590.0 8590.0 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 4 5 6 MERGED MAIN PASS. $ MERGE TOP 69.5 4573.0 4901. 0 6920.0 7303.0 MERGE BASE 4573.0 4901. 0 6920.0 7303.0 8639.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type. ....0 Logging Direction.. ......... ......Down Optical log depth units......... ..Feet Data Reference Point...... ....... .Undefined Frame Spacing. ................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR MWD MWD MWD MWD MWD MWD MWD Min 69.5 0.79 21. 59 0.87 0.17 0.14 1. 03 0.09 Max 8639 3103.94 125.91 190.97 2000 2000 2000 46.62 Nsam 17140 17050 17027 8123 8123 8123 8123 8121 Mean 4354.25 209.168 67.4009 11.417 12.5306 23.136 36.1254 1.90162 First Reading For Entire File... ...... .69.5 Last Reading For Entire File.......... .8639 First Reading 69.5 114.5 69.5 4529 4529 4529 4529 4529 Last Reading 8639 8639 8582.5 8590 8590 8590 8590 8590 . File Trailer Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/11/05 Maximum Physical Record. .65535 File Type.. ... .......... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name..... ...... ..STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/11/05 Maximum Physical Record. .65535 File Type..... .......... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 69.5 114.5 STOP DEPTH 4527.5 4573.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 26-SEP-04 Insite 66.37 Memory 4573.0 114.0 4573.0 .0 64.0 TOOL NUMBER 061497 13 .500 .0 SPUD MUD 9.20 135.0 9.0 320 9.8 . MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 .000 . 86.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... ......... ....0 Data Specification Block Type.....O Logging Direction............. ... . Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWD010 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 4573 2321.25 9008 69.5 4573 ROP MWD010 FT/H 0.79 1244.58 199.654 8918 114.5 4573 GR MWD010 API 21.59 123.12 67.833 8917 69.5 4527.5 First Reading For Entire File......... .69.5 Last Reading For Entire File.......... .4573 File Trailer Service name........... ..STSLIB.002 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation. ......04/11/05 Maximum Physical Record..65535 File Type......... .......LO Next File Name.... ... ....STSLIB.003 Physical EOF File Header Service name........... ..STSLIB.003 Service Sub Level Name... Version Number... ...... ..1.0.0 Date of Generation..... ..04/11/05 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.002 . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 4528.0 4529.0 4529.0 4529.0 4529.0 4529.0 4573.5 STOP DEPTH 4864.0 4855.0 4855.0 4855.0 4855.0 4855.0 4901. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTRO MAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record 28-SEP-04 Insite 66.37 Memory 4901. 0 4573.0 4901. 0 62.6 63.0 TOOL NUMBER 149205 145654 9.875 4562.0 LSND 9.60 48.0 8.0 300 8.4 3.500 2.810 2.900 3.300 65.0 82.5 65.0 65.0 . . 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 4528 4901 4714.5 747 4528 4901 ROP MWD020 FT/H 13.37 968.56 350.377 656 4573.5 4901 GR MWD020 API 34.98 102.9 70.4438 673 4528 4864 RPX MWD020 OHMM 2.37 15.49 6.73436 653 4529 4855 RPS MWD020 OHMM 0.17 18.89 7.31265 653 4529 4855 RPM MWD020 OHMM 0.14 2000 22.5094 653 4529 4855 RPD MWD020 OHMM 1. 03 2000 118.846 653 4529 4855 FET MWD020 HOUR 0.09 46.62 6.66026 653 4529 4855 First Reading For Entire File......... .4528 Last Reading For Entire File.......... .4901 File Trailer Service name...... ..... ..STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.. .... .04/11/05 Maximum Physical Record..65535 File Type.. ............ ..LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name........... ..STSLIB.004 Service Sub Level Name. . . Version Number.... ..... ..1.0.0 Date of Generation...... .04/11/05 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: 4 header data for each bit run in separate files. 4 .5000 . # FILE SUMMARY VENDOR TOOL CODE RPX RPD RPM RPS FET GR ROP $ START DEPTH 4855.5 4855.5 4855.5 4855.5 4856.5 4864.5 4901. 5 STOP DEPTH 6874.5 6874.5 6874.5 6874.5 6874.5 6882.5 6920.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 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 . 30-SEP-04 Insite 66.37 Memory 6920.0 4901. 0 6920.0 60.1 80.6 TOOL NUMBER 124724 145654 9.875 4562.0 LSND 10.00 54.0 8.3 560 6.2 3.500 2.160 2.800 3.200 66.0 111.1 66.0 66.0 . . 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 MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4855.5 6920 5887.75 4130 4855.5 6920 ROP MWD040 FT/H 6.26 3103.94 224.801 4038 4901.5 6920 GR MWD040 API 22.07 125.91 68.7317 4037 4864.5 6882.5 RPX MWD040 OHMM 1. 95 190.97 10.3254 4039 4855.5 6874.5 RPS MWD040 OHMM 1. 94 210.52 10.9659 4039 4855.5 6874.5 RPM MWD040 OHMM 1. 93 139.41 10.888 4039 4855.5 6874.5 RPD MWD040 OHMM 2.04 128.31 11.2787 4039 4855.5 6874.5 FET MWD040 HOUR 0.12 22.17 0.886906 4037 4856.5 6874.5 First Reading For Entire File... ...... .4855.5 Last Reading For Entire File.......... .6920 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.... .... ...1.0.0 Date of Generation... ....04/11/05 Maximum Physical Record. .65535 File Type................ LO Next File Name...... .....STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.... .......1.0.0 Date of Generation.... ...04/11/05 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 RPX RPM FET 5 header data for each bit run in separate files. 5 .5000 START DEPTH 6875.0 6875.0 6875.0 6875.0 STOP DEPTH 7254.0 7254.0 7254.0 7254.0 . RPS GR ROP $ 6875.0 6883.0 6920.5 7254.0 7247.0 7303.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.......... ........0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point...... ....... .Undefined Frame Spacing...... .......... .....60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD050 . 02-0CT-04 Insite 66.37 Memory 7303.0 6920.0 7303.0 81.1 93.0 TOOL NUMBER 62456 130910 6.750 6910.0 Versa Pro 9.95 60.0 .0 44000 .0 .000 .000 .000 .000 .0 113.5 .0 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 . . GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6875 7303 7089 857 6875 7303 ROP MWD050 FT/H 6.48 1696.76 184.891 766 6920.5 7303 GR MWD050 API 33.29 85.06 60.6289 729 6883 7247 RPX MWD050 OHMM 0.87 36.94 13.4817 759 6875 7254 RPS MWD050 OHMM 1.11 2000 21.0401 759 6875 7254 RPM MWD050 OHMM 3.21 2000 121. 21 759 6875 7254 RPD MWD050 OHMM 4.62 2000 173.463 759 6875 7254 FET MWD050 HOUR 0.26 42.69 5.9614 759 6875 7254 First Reading For Entire File......... .6875 Last Reading For Entire File.... ...... .7303 File Trailer Service name........ .....STSLIB.005 Service Sub Level Name... Version Number... ...... ..1.0.0 Date of Generation...... .04/11/05 Maximum Physical Record. .65535 File Type........... .....LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name..... .... ....STSLIB.006 Service Sub Level Name... Version Number... ...... ..1.0.0 Date of Generation..... ..04/11/05 Maximum Physical Record. .65535 File Type........... .....LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 6 header data for each bit run in separate files. 6 .5000 START DEPTH 7247.5 7254.5 7254.5 7254.5 7254.5 7254.5 7303.5 STOP DEPTH 8582.5 8590.0 8590.0 8590.0 8590.0 8590.0 8639.0 # LOG HEADER DATA DATE LOGGED: 03-0CT-04 . SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. ...... ...........0 Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units..... ......Feet Data Reference Point............. . Undefined Frame Spacing. ................... .60 .1IN Max frames per record.. ......... ..Undefined Absent value..................... .-999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Insite 66.37 Memory 8639.0 7303.0 8639.0 81.1 92.4 TOOL NUMBER 62456 130910 6.750 6910.0 Versa Pro 10.00 65.0 .0 44000 .0 .000 .000 .000 .000 .0 113.5 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7247.5 8639 7943.25 2784 7247.5 8639 ROP MWD060 FT/H 0.87 688.98 189.59 2672 7303.5 8639 GR MWD060 API 43.05 90.93 65.0281 2671 7247.5 8582.5 RPX MWD060 OHMM 6.67 40.95 13.625 2672 7254.5 8590 RPS MWD060 OHMM 6.82 35.91 13.7538 2672 7254.5 8590 RPM MWD060 OHMM 6.97 36.01 13.9448 2672 7254.5 8590 RPD MWD060 OHMM 7.36 32.84 14.4562 2672 7254.5 8590 FET MWD060 HOUR 0.22 14.15 1.11855 2672 7254.5 8590 First Reading For Entire File...... ....7247.5 Last Reading For Entire File..... ..... .8639 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation...... .04/11/05 Maximum Physical Record. .65535 File Type........... ... ..LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/05 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........... ... ..UNKNOWN Continuation Number.. ... .01 Next Tape Name.......... . UNKNOWN Comments..... .... ...... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. .......... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/05 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