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Home My WebLink About202-1731. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Tubing Cut Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Swap, Scab 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 8,390 feet N/A feet true vertical 4,136 feet N/A feet Effective Depth measured 8,390 feet feet true vertical 4,136 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2 / L-80 / TCII 4,486' 4,136' D&L Hydrretrieve ISO D&L Perm. Hyd. ISO Packers and SSSV (type, measured and true vertical depth)Baker S-3 N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: 4,382, 4,566 & 4,616' 4,089, 4,164 & 4,181 324-273 & 324-327 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 330 Gas-Mcf MD 112' 265 Size 112' 5,090' 898 340195 0 680 216 measured TVD 4-1/2" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 202-173 50-029-23115-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0380109 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT S-17 Plugs Junk measured Length Liner "OB" 3,424' 3,212' Casing Conductor 4,093' 4,136' 8,225' 8,387' 4,613' 5,090'Surface Tieback Liner "OA" 20" 7-5/8" 5-1/2" 78' 5,179' 7,500psi 7,500psi 6,890psi 7,740psi 8,430psi 8,430psi 4,613' 4,180' Burst N/A Collapse N/A 4,790psi 6,390psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:05 am, Sep 10, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.09.06 15:37:16 - 08'00' Taylor Wellman (2143) DSR-9/13/24WCB 12-3-2024 RBDMS JSB 091724 _____________________________________________________________________________________ Revised By: TDF 9/5/2024 SCHEMATIC Milne Point Unit Well: MP S-17 Last Completed: 8/3/2024 PTD: 202-173 17 18 TD =8,390’(MD) / TD = 4,136’(TVD) 20” Orig. KB Elev.: 65.9’/ Orig. RT Elev.: 25.53’ (Doyon 141) 7-5/8” 8 9 12 13 1415 16 “OA” Lateral PBTD =8,390’(MD) / TD = 4,136’(TVD) “OB” Lateral 5 3 7 4 10 11 2 1 6 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 7-5/8" Surface 29.7 / L-80 / IBT-M 6.875 Surface 5,090’ 5-1/2” TIeback 17 / L-80 / JBEAR 4.892 Surface 4,613’ 4-1/2” Liner “OA” 12.6 / L-80 / IBT 3.958 4,758’ 8,225' 4-1/2” Liner “OB” 12.6 / L-80 / BTC 3.958 5,070’ 8,387’ TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / TCII 2.992 Surface’ 4,486’ SLOTTED LINER DETAIL 4-1/2” Liner “OA” 12.6 / L-80 / IBT 3.958 4,801’ 8,225’ 4-1/2” Liner “OB” 12.6 / L-80 / BTC 3.958 5,175’ 8,387’ JEWELRY DETAIL No Depth Item 1 4,358 Champion X Forward Circulating Ported Pump - Min ID: 2.668” 2 4,382’ 5-1/2" x 3- 1/2" D&L Hydratrieve. ISO Packer - 36K Release 3 4,444’ 2-7/8" X-Nipple - 2.313'' 4 4,456’ Muleshoe –Btm @4,486’ 5 4,507’ 4-1/2” NCS Multi-Cycle HP2 FRAC Sleeve 6 4,566’ 7-5/8" x 4-1/2", 24-39# D&L PERM. HYD. ISO Packer 7 4,585’ XN-Nipple: Min ID - 2.75'' 8 4,604’ 3.5" Non sealing overshot w/ shear pins in 10K shear –Btm @ 4,613’ 9 4,616’ 7-5/8”” x 4-1/2” Baker S-3 Packer (3.875” ID) 10 4,660’ 3-1/2” HES XN Nipple (2.750” Min ID) 11 4,666’ Wireline Entry Guide 12 4,775’ Baker Hook Wall, Hanger above 7-5/8” Window 13 4,774’ Baker Hook Wall, Hanger below 7-5/8” Window 14 5,070’ Baker Tie Back Sleeve 15 5,077’ Baker ZXP Liner Top Packer 16 5,083’ Baker 7-5/8” x 5-1/2” HMC Liner Hanger 17 8,225’ Btm Baker 4-1/2” Guide Shoe (OA Lateral) 18 8,387’ Btm Baker 4-1/2” Guide Shoe (OB Lateral) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset in 42” Hole 7-5/8" Cmt w/ 906 sx PF ‘L’, 337 sx Class “G” in 9-7/8” Hole 4-1/2” Uncemented Liner in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 2,500’ MD 30° to 50° - 3,300’ to 4,300’ Hole Angle Passes 70° @ 4,500’ 70° at Sliding Sleeve TREE & WELLHEAD DETAIL Tree 4-1/16 – 5M FMC Wellhead 11” x 4-1/2” 5M Gen 6 w/ 4.5” TCII T & B Tubing Hanger 4” CIW ‘H” BPV Profile GENERAL WELL INFO API: 50-029-23194-00-00 Drilled and Completed by Doyon 14 – 4/03/2004 ESP Repair by Nabors 3S – 5/19/2006 ESP Repair by Nabors 3S – 6/09/2008 ESP Repair by Nabors 4ES – 8/31/2008 Convert to Jet Pump by Doyon 16 – 3/16/2013 Tieback Install & Tubing Swap by ASR – 7/28/2024 LATERAL WINDOW DETAIL Top of “OA” Window @ 4,780’ MD; Bottom @ 4,792’ MD; Angle @ Window is 75 deg Well Name Rig API Number Well Permit Number Start Date End Date MP S-17 ASR#1 50-029-23115-00-00 202-173 7/16/2024 8/6/2024 7/12/2024 - Friday No operations to report. 7/10/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 7/11/2024 - Thursday No operations to report. Function test BOPs, Hook up lines to flowback tank. Bleed 80 psi from IA. Hook up fluid lines around rig. Torque up HCR lines make up test mandrels. Rig accepted 09:30 7/16/2024. Swap out handling equipment. P/U M/U 2-7/8 test joint. Fill stack. Shell test BOP ¿ good. Begin testing BOPs 250 low / 2500 high as per approved sundry. AOGCC waived witness. During test #7, find weep holes on blind rams leaking (both sides). Yellowjacket replaced both mud seals on blind rams. Retest BOPE. No operations to report. 7/13/2024 - Saturday No operations to report. 7/16/2024 - Tuesday 7/14/2024 - Sunday No operations to report. 7/15/2024 - Monday Begin testing BOPs 250 low / 2500 high as per approved sundry. AOGCC waived witness During test #7, find weep holes on blind rams leaking (both sides). Yellowjacket replaced both mud seals on blind rams. Retest BOPE Well Name Rig API Number Well Permit Number Start Date End Date MP S-17 ASR#1 & SL 50-029-23115-00-00 202-173 7/16/2024 8/6/2024 Cont. to M/U 5-1/2" scab liner BHA. overshot, XN, XO, 7-5/8" PKR, JT, NCS Frac Sleeve, RIH w/ 5-1/2" 17# L-80 JFEBear. Scab liner F/ 162' T/ 1,045'. Work through tight spot @1,045'. Continue RIH w/ 5-1/2" 17# L-80 JFEBear Scab liner to 4,608' swallowing 3.5¿ tubing to nogo. P/U and tag same. P/U M/U Pups and hanger. Land hanger. RILDS. B/O landing joint. Clear rig floor of 5-1/2" Handling equip. P/U slick line tools & equip. P/U SL 2.70" drift. RIH. SL unable to pass 2.75" XN nipple. POOH. Switch drift to 2.60" RIH. SL unable to pass 2.75" XN nipple. POOH. Switch drift to 2.0" RIH. Drift through XN. Cont. RIH. Tagging TOT at 4,603' Set dw & jar down. Overpull while picking up. POOH for smaller tools. 7/20/2024 - Saturday 7/21/2024 - Sunday Cont. SL in attempting to pass through 3-1/2" tubing below Non-sealing overshot. RIH w/ 1.91" OD drift Tagging up at 4603' P/U no overpull. POOH. RIH w/ sample bailer w/ 1.75" OD. Tag at 4,603' POOH. OOH No sand or scale in bailer. Bailer has indication of tubing tag. P/U LIB & RIH. Tag TOT at 4,603'. POOH OOH w/ LIB. Good indication of off center tubing. P/U 1.25" OD slick weight bar & assy. RIH. SL unable to pass TOT at 4,603' w/ 1.25" OD assy. POOH. Decision made to Pull 5-1/2" scab liner. L/D slick line tools & equip. Change over handling equip. to 5-1/2" Rig up casing crews. P/U M/U Landing joint and kelly hose. BOLDS. Pull hanger to the floor. 74K PUW. L/D hanger. Begin POOH f/4,606' POOH w/ 5-1/2 JFE Bear pumping double displacement. T/ 3,500' 60K PUW. Rig encountered a carriage maintenance issue and staff evaluated and inplemented corrective action plan. During all operations pump 5 BPH of 8.4 ppg to well. 7/19/2024 - Friday M/U dress off BHA dress off mill, 2x boot baskets, string magnet, bumper sub & oil jar. Begin RIH w/ dress off assy. on 3-1/2" WS. Pump double displacement. Tag TOT at 4,600'. Set dw 2K. P/U. Retag same depth. P/U, establish parameters. Dress over TOT Observed expected psi & TQ increases. Nogo at 4,603'. B/D pump lines. POOH. OOH, L/D Dress off BHA & inspect. Mill showing "work". Change handling equip. Load 5-1/2" JFE in pipe shed. Rig up CSG crew. Fly rig tongs off rig floor & rig up casing tongs. Strap & tally 5-1/2" JFE bear. Remove shipping grease/dope. P/U 5-1/2" Scab liner BHA. Overshot & XN nipple. 7/17/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Test BOPE as per approved sundry. Repair BOPE, Valve replaced, Finish testing BOPs 250 low/ 2500 P/U T bar. Pull CTS plug. Pressure under BPV. Pump 1.5 X TBG volume. 100 BBLs @ 2.5 BPM 120 psi. Pull BPV. TBG on a vac. P/U M/U landing joint W/ TIW and kelly hose connected. BOLDS.Pull hanger to the floor. 57 K PUW. Cont. to POOH w/ 4-1/2" tubing from cut at 4,603' t/ 1,540' P/U wt = 19K Pump double displacement of 8.4 SW for pipe pulled, no returns. At cut joint, Recovered all 62 CC clamps. Clean & clear rig floor. Change handling equip. Prep for SL. P/U sheave & tie off. p/U 6.74 " GR & JB. Open well. Attempt to fill well with 30 bbls of 8.4 ppg Source water. No returns. RIH w/ 6.74" GR & JB. on slick line. Fill well at 5 BPH. 8.4 ppg SW 7/18/2024 - Thursday Cont. RIH w/ SL 6.74" GR. Tag at 1,044' Unable to pass. POOH Change over to 6.1" GR & JB. RIH. Tag TOT at 4,602' w/ 6.1" GR. POOH. Out of hole with GR & JB. Long strip of rubber in JB. RIH w/ same assy. to ensure wellbore free of debris. Tag TOT at 4,602' SLM. POOH. OOH w/ GR & JB. JB empty. Remove tools. M/U Read caliper, RIH. Log f/ 4602' SLM to surface. M/U 6.74" GR and JB. RIH unable to pass 1,044'. POOH. R/D SL. P/U & M/U 7-5/8" test packer. RIH and tag at 4,598' TOT. Set Packer, COE = 4,592'. Fill hole w/ 34 BBLs. Pressure up on casing to 2,100 psi. Fail POOH 100'. Attempt same test. Fail. Bleed off pressure. POOH w/ 7-5/8" test PKR & set PKR at 2017'. Test to 2,000 psi & hold for 20 mins ensure PKR operation. Good test. Cont. POOH w/ 7-5/8" test PKR f/ 2,017' T/ surface. Inspect PKR condition. Good. Clean & clear rig floor. Tag TOT at 4,602' SLM. POOH. BOLDS.Pull hanger to the floor P/U M/U Pups and hanger. Land hanger. RILDS Decision made to Pull 5-1/2" scab liner. P/U 5-1/2" Scab liner BHA. Overshot & XN nipple Test BOPE as per approved sundry. Repair BOPE, Valve replaced, Finish testing BOPs 250 low/ 2500 Cont. to POOH w/ 4-1/2" tubing from cut at 4,603' t/ 1,540' P/U wt = 19K RIH w/ 5-1/2" 17# L-80 JFEBear. Scab liner F/ 162' T/ 1,045'. Work through tight spot @1,045'. Continue RIH w/ 5-1/2" 17# L-80 JFEBear Scab liner to 4,608' swallowing 3.5¿ tubing to nogo. RIH and tag at 4,598' TOT. Set Packer, COE = 4,592'. M/U Read caliper, RIH. Log f/ 4602' SLM to surface Caliper data was submitted to AOGCC as per COA on Sundry 324-327 - WCB BOLDS. Pull hanger to the floor. 74K Well Name Rig API Number Well Permit Number Start Date End Date MP S-17 ASR#1 & SL 50-029-23115-00-00 202-173 7/16/2024 8/6/2024 Hilcorp Alaska, LLC Weekly Operations Summary Continue carriage maintenance repair. Continue to pump 5 BPH of 8.4 ppg to well. Continue carriage maintenance repair. Continue to pump 5 BPH of 8.4 ppg to well. 7/23/2024 - Tuesday 7/22/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP S-17 ASR#1 & SL 50-029-23115-00-00 202-173 7/16/2024 8/6/2024 Cont. adjust & re-wrap service loop lines. P/U string mill BHA. Bullnose, Smooth OD string mill, Bumper sub, Jar, 9x 4-3/4" DC. RIH w/ string mill BHA on 3-1/2" G-105 workstring T/ 1,020' Pump at 5 BPH. No returns from well. Work string mill through ovalled CSG. F/ 1,020' T/ 1,055'. Pass through with no rotation. Cont. RIH to 1,095' No issues. POOH w/ string mill BHA on 3- 1/2" G-105 workstring F/ 1,095' Pump at 5 BPH. OOH L/D BHA, no damage. P/U & M/U 5-1/2" scab liner. Change handling equip. Rig service. Check equip. fluid levels. Clear pipe shed of work string. Load & tally 5-1/2" 17# L-80 JFE Bear CSG. Adjust service loop. Rig down time due to Rig main air line hose failure. Replace. P/U & M/U 5-1/2" scab liner BHA. RIH w/ 5-1/2" T/ 1,296' S/O wt = 21K. No issues. Pump 5 BPH to well. No returns. 7/27/2024 - Saturday 7/28/2024 - Sunday RIH w/ 5-1/2" 17# L-80 JFE Bear T/ 4,525'. Pump double displacement. No returns from well. RIH swallow over 3-1/2" tubing stub, locator brass shear screws. Shear out. Cont to nogo. POOH w/ 1 x JT. Make up hanger. No space out pups needed for 5.65' off Nogo. M/U landing joint & land hanger on seat. Final P/U wt = 73K & S/O wt = 63 K. RILDS. Pull landing Jt & L/D. R/U slick line. M/U sample bailer w/ 2.5" centralizer. RIH to 4,700'. (Good drift) OOH w/ sample bailer & 2.5" cent. No debris in bailer. RIH w/ PXN plug body SD at 4583' SLM. Set plug & shear off. POOH. RIH w/ PXN prong SD at 4,575' SLM. Set prong. POOH, no overpull. OOH w/ running tools. PX prong set. Fill 5-1/2" w/ 20 bbls of 8.4 ppg source water. Purge air out of lines. Pressure up to set PKR & MIT 5-1/2" Pressure up to 4000 psi & hold for 30 charted mins. (good). R/U slick line & P/U sheave. Load dump bailer w/ 1.5 gal of sluggets SD at 4572' SLM, WORK TOOL, POOH. OOH w/ tools. Bailer sheard. Load dump bailer w/ 1.5 gal of sluggets RIH w/ dump bailer. SD at 4572' SLM, WORK TOOL, POOH. 7/26/2024 - Friday Replace elevators with spare set. P/U & M/U 5-1/2" scab liner BHA. 3.5" WLEG, XN, 7-5/8" x 4-1/2" perm PKR, 4-1/2" JT, NCS frac sleeve, 4-1/2" JT XO. RIH w/ 5-1/2" 17# L-80 JFE Bear F/ 156' - T/ 1,048' Tagging ovalized casing. Unable to work past. Pump 20 bbl of 2% NXS lube pill dw backside. Cont. to work pipe setting down full string wt = 19K. Seeing overpull of 12K. Unable to pass. POOH to turn down overshot WLEG to 6.5". POOH w/ 5-1/2" 17# L-80 JFE Bear F/ 1,048'. L/D 5-1/2" Scab liner BHA. No damage to BHA. Send out non-sealing overshot to be reduced in OD. Clear pipe shed of 5-1/2" & load w/ workstring. Load string mill BHA . in pipe shed & load 9 x 4-3/4" drill collars. Load 3-1/2" WS. Rack & tally all pipe. Service loops found to need adjustment. Service loops handing up in derrick while descending. Adjust & re-wrap lines. 7/24/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Begin POOH. Observed no overpull, Cont. POOH w/ 3,500'. Change slips to E-type. Service rig. Check all equip. fluid levels. Cont. POOH w/ 5-1/2" 17# L-80 JFEBear scab Liner f/ 3,497'. To BHA. L/D 5-1/2" Scab liner BHA. NCS frac sleeve, 7-5/8" PKR. & XN nipple. 7-5/8" PKR is shear released & elements are damaged. WLEG in slips. 7/25/2024 - Thursday L/D last BHA component. Test H2S & LEL gas alarms. P/U test tools. Test BOPE as per sundry. Testing witnessed by AOGCC inspector. Test to 250 psi low & 2,500 psi high for 5/5 charted mins. Perform accumulator drawdown, Completed BOPE testing with one fail/pass test. L/D test tools. Blow down lines. R/U slick line. Hang sheave & connect secondary retention. WLIH w/ 5.5 LIB. Tag TOT at 4,603' POOH. OOH w/ LIB. Good impression of partial 3-1/2" tubing stump. P/U & M/U 6.1" GR & JB. RIH. No issues. OOH w/ GR & JB, Junk basket empty. R/D slick line. Clean & clear rig floor. Change handling equip. for 5- 1/2" scab liner. Prep BHA & place in order. Re-strap 5-1/2" CSG. Prep for packer arrival. PKR on location. Place in order. P/U WLEG New elevators not latching correctly. Secondary latch not latching. Lay down elevators & mobilize spare set. P/U & M/U 5-1/2" scab liner BHA. RIH Test BOPE as per sundry. Testing witnessed by AOGCC inspector. Change handling equip. for 5- 1/2" scab liner. Prep BHA & place in order. Re-strap 5-1/2" CSG. Prep for packer arrival Pressure up to set PKR & MIT 5-1/2" Pressure up to 4000 psi & hold for 30 charted mins. (good) Well Name Rig API Number Well Permit Number Start Date End Date MP S-17 ASR#1 & SL 50-029-23115-00-00 202-173 7/16/2024 8/6/2024 Hilcorp Alaska, LLC Weekly Operations Summary Pressure up on frac sleeve to 1200 psi. Sleeve not open. Bleed off. Open annular & relocate. Shut bag. Being pumping down tubing. Returns seen at 7-5/8" x 5-1/2" (Sleeve open). Pump a 1.5 x bottoms up of the 7-5/8" x 5-1/2" for a total of 124 bbls at 2.2 BPM w/ 450 psi. Returns are clean source water. R/U Halliburton cementers to pump down work string. Hold PJSM. PT cement lines to 6,000 psi. good test. Cemetn as per detail. Cement seen at surface as calculated. for 25 bbls of cement back. Max rate = 2.5 Bpm w/ max pressure = 1,850 psi. Monitor pressure in 5-1/2" x 2-7/8", No issues. Obtain cement samples. Shift sleeve closed. PT 5-1/2" to 2,000 psi while monitoring 7-5/8" x 5-1/2" = 0 PSI. Bleed off at cement unit , monitor bleeder, no flow. (Sleeve shut) Reverse out 2-7/8" PH-6 , removing 1 bbl of cement & spotted contam pill. P/U & shear wedging cone on shifting BHA, ensuring sleeve not manipulated. RIH to 4,568' Tagging sluggets. Reverse out sluggets at 4,568'. Pump at 2.6 BPM w/ 300 psi for 64 bbls. Retrieve 3 gallons of sluggets. POOH w/ Shifting BHA, laying down 2-7/8" PH-6 to pipe shed. F/ 4,568' T/ surface. L/D BHA. Install TWC & test to 2000 psi. Suck out & N/D BOP stack for tubing spool install. Cont. to make dump bail runs. Tagging in at same depth of 4572' SLM. Dumping a total of 10.5 gallons of sluggets. Tagging at 4571' R/D slick line. With crane support. R/D CSG tongs & R/U ASR rig tongs. P/U & M/U Frac sleeve shifting BHA for a total of 21'. RIH w/ Frac sleeve shifting BHA. Picking up singles of 2-7/8" PH-6 from pipe shed. Single in hole T/ 4,555' P/U wt = 32K Monitor returns. Pump down work string spotting 40 bbls of gel pill & 30 bbls of 8.4 ppg contam pill in 2-7/8" x 5-1/2" in preparation of cement job. Pump at 2.6 BPM w/ 350 psi. P/U to locate frac sleeve with locator. Pull into Slack off to open. Prep to pressure up to ensure open. Shut annular. 7/30/2024 - Tuesday 7/29/2024 - Monday No issues. Obtain cement samples. Shift sleeve closed R/U Halliburton cementers to pump down work string. Hold PJSM. PT cement lines to 6,000 psi. good test. Cemetn as per detail. Cement seen at surface as calculated. for 25 bbls of cement back Well Name Rig API Number Well Permit Number Start Date End Date MP S-17 ASR#1 & SL 50-029-23115-00-00 202-173 7/16/2024 8/6/2024 T/I/O=60/40/0 Assist Slickline Pumped a total of 1.2 bbls diesel to verify Plug and packer are holding. SL reset sleeve. MIT-T Passed to 3748 psi. Pressured up TBG to 3872 psi with .6 bbls diesel. 15 min TBG lost 93 psi. 2nd 15 min TBG lost 31 psi for a total loss of 124 psi in 30 min. Bled back ~ .8 bbls. Final Whps=500/500/0 Continue swapping handling equipment to 3-1/2" EUE. Tally Joints and Jewelry. PU/MU and RIH w/ 3-1/2",9.3#,L, EUE R2 FWD Circulating Jet Pump completion while maintaining 2x displacement. Tag 5-1/2" x 4-1/2" Crossover w/ Muleshoe Joint coupling at 4,455'MD. Figure space-out. Install pups and JT# 134. Install Hanger, pull slips. Land hanger placing EOT at 4,486.46'. RILDS. Pump 50BBLS corrosion inhibitor followed by 5BBLS diesel down IA. Drop B&R, remove landing joint, close blind rams. Fill TBG w/ 18bbls diesel. Pressure TBG to 4100psi to set packer. Unable to hold pressure. Bleed off and allow air to migrate to surface and fill well w/ 4bbls. 2nd attempt at TBG test failed. Bleed down and fill IA w/ 14bbls. 3rd attempt failed. MIT-IA to 2,000psi - Good. Bleed off all pressure. Install BPV. Rig Down ASR-1. Release rig 8/3/2024 at 23:59 8/3/2024 - Saturday WELL S/I ON ARRIVAL. PULL BLANKING SLEEVE FROM FORWARD CIRC PORTED SUB @4,358' MD. PULLED BALL & ROD FROM RHC @4,444' MD - 1 FLAT SPOT ON THE BALL. PULLED RHC PLUG BODY FROM X-NIP @4,444' MD. SET 2.31" XX PLUG (=23" oal, x4 1/8" eq ports) IN X-NIP @4,444' MD. SET BLANKING SLEEVE (=37") IN FORWARD CIRC PORTED SUB @4,358' MD. ATTEMPT SEVERAL MIT-T'S - FAILED. WELL S/I ON DEPARTURE. 8/6/2024 - Tuesday 8/4/2024 - Sunday WELLHEAD: BOP stack removed, clean hgr void, RX 54 gasket and SBMS seal installed. PU and land tree/adapter, torque to spec and test 500/5000 (PASS). Pull Bpv with dry rod. Well secured;. 8/5/2024 - Monday 8/2/2024 - Friday Slickline continue working 2.25" DD and Pump Bailers at 4,577' SLM. No cement recovery, bailer bottoms have metal marks indicating G-Fishing Neck. Latch Plug body at 4,580' SLM w/ 3-1/2" GR. Jar up/down for 2hrs without success. Drop cutter bar and POOH w/ wire. SL RIH and recover cutter bar. RD Slickline. PU/MU YJOS Overshot BHA w/ 1.750" Grapple and RIH on 2- 7/8" PH6 workstring pumping 2x displacement T/ 4,541' MD. RU Kelly hose, fill WS w/ 10bbls. Latch SL Rope Socket at 4,548' MD. Fill CSG w/ 20bbls. Pull PXN plug body w/ 1500# overpull, fluid in CSG dropped immediatly. RD Kelly hose. POOH pumping 5bbls every 15 JTS. Recover all tools and plug body. Swap handling equipment to 3-1/2"EUE. 7/31/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue ND BOP. Install new tubing spool & stab BOPE on top. Torque tubing spool bolts. Test Packoff to 500 psi low & 5,000 psi high f/ 5/10 mins (good test). N/U BOPE. Install bolts & torque. Reset flow & spacer spools. Remeasure RKB heights. Slickline RU and RIH w/ 2.5" JUS, SD ~10' high above prong 4,565' SLM. Multiple SL runs with Bailers - recovered ~2 gal Cement. RD Slickline. LD Gilroy riser. Install Test Plug in TBG spool.Test BOPE 250/2500psi. AOGCC witness waived. Pull test plug. PU/MU and RIH w/ Cleanout BHA T/ 768' MD. 8/1/2024 - Thursday Continue RIH w/ 2.70" Cleanout BHA F/ 768' - TOC at 4,565'. Establish parameters, wash/ream to 4,576'. Reverse 2x BU followed with 1x workstring vol. conventional. Recovered ~5gal fill. POOH and LD BHA. RU Slickline and recover Prong from 4,577' SLM. Work various DD and Pump Bailers with cement returns. MIT-T Passed to 3748 psi. MIT-IA to 2,000psi - Good Test BOPE 250/2500psi. AOGCC witness waived PU/MU and RIH w/ 3-1/2",9.3#,L, EUE R2 FWD Circulating Jet Pump completion while maintaining 2x displacement. Tag 5-1/2" x 4-1/2" Crossover w/ Muleshoe Joint coupling at 4,455'MD. Figure space-out. Install pups and JT# 134. Install Hanger, pull slips. Land hanger placing EOT at 4,486.46'. RILDS. A passing MIT-IA is a COA on Sundry 324-327. -WCB Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 7/30/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240730 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14B 50133205390200 222057 5/22/2024 YELLOW JACKET PERF BCU 14B 50133205390200 222057 6/11/2024 YELLOW JACKET GPT-PLUG-PERF BCU 19RD 50133205790100 219188 7/17/2024 AK E-LINE Perf BRU 222-26 50283201950000 224035 7/1/2024 AK E-LINE CBL BRU 222-26 50283201950000 224035 7/11/2024 AK E-LINE PressureTemp CLU 16 50133207200000 224021 5/16/2024 YELLOW JACKET SCBL CLU 16 50133207200000 224021 5/31/2024 YELLOW JACKET SCBL END 2-14 50029216390000 186149 5/9/2024 YELLOW JACKET PLUG KU 33-08 50133207180000 224008 5/9/2024 YELLOW JACKET GPT-PLUG-PERF MPU H-08B 5.00292E+13 201047 7/14/2024 READ CaliperSurvey MPU I-40 50029236890000 220071 7/6/2024 AK E-LINE TubingCut MPU R-101 50029237930000 224078 7/16/2024 YELLOW JACKET SCBL MPU S-17 50029231150000 202173 7/12/2024 AK E-LINE TubingCut MPU S-17 5.00292E+13 202173 7/18/2024 READ CaliperSurvey PBU NK-43 50029229980000 201001 6/11/2024 YELLOW JACKET PL PBU PTM P1-13 50029223720000 193074 7/4/2024 YELLOW JACKET PL Pearl 11 50133207120000 223032 7/10/2024 AK E-LINE Plug/Perf Please include current contact information if different from above. T39310 T39310T T39311T T39312T T39312 T39313 T39313 T39314 T39315 T39316 T39317 T39318 T39319 T39319 T39320 T39321 T39322 MPU S-17 50029231150000 202173 7/12/2024 AK E-LINE TubingCut MPU S-17 5.00292E+13 202173 7/18/2024 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.30 13:09:33 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT S-17 JBR 08/30/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 2-7/8", 3-1/8" 5-1/2" TJ's 12 Accumulator bottles with 1062 psi precharge FP on 5-1/2" fixed rams cycled and flushed and passed Test Results TEST DATA Rig Rep:Greub/CooperOperator:Hilcorp Alaska, LLC Operator Rep:Hiem/Gallen Rig Owner/Rig No.:Hilcorp ASR 1 PTD#:2021730 DATE:7/25/2024 Type Operation:WRKOV Annular: 250/2500Type Test:WKLY Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopKPS240725232104 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 9.5 MASP: 942 Sundry No: 324-327 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 11"P #1 Rams 1 5-1/2" Fixed FP #2 Rams 1 2-7/8" X 5" V P #3 Rams 1 Blinds P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2-1/16"P HCR Valves 1 2-1/16"P Kill Line Valves 3 2-1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3150 Pressure After Closure P1800 200 PSI Attained P15 Full Pressure Attained P63 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4 @ 2312 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P12 #1 Rams P7 #2 Rams P6 #3 Rams P7 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill NA0 9 9 9 9 À 9999 9 9 FP on 5-1/2" fixed rams 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 Tubing Cut Other: Tubing Swap, Scab 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,390'N/A Casing Collapse Conductor N/A Surface 4,790psi Liner "OA"7,500psi Liner "OB"7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7-5/8" x 4-1/2" Baker S-3 and N/A 4,616 MD/ 4,181 TVD and N/A Todd Sidoti todd.sidoti@hilcorp.com 777-8443 4-1/2" 12.6 / L-80 / IBT 4,620' 9.2 / L-80 / TCII 4,666' Perforation Depth MD (ft): 8,387' See Schematic See Schematic 3-1/2" 78' 20" 7-5/8" 4-1/2" 5,179' 4-1/2"3,212' 3,424' MD N/A 8,430psi 6,890psi 8,430psi 5,090' 4,093' 4,136' 5,090' 8,225' Length Size Proposed Pools: 112' 112' TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 202-173 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23115-00-00 Hilcorp Alaska LLC C.O. 477.05 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 6/20/2024 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT S-17 MILNE POINT SCHRADER BLUFF OIL N/A 4,136' 8,390' 4,136' 942 N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.06.03 13:54:14 - 08'00' Taylor Wellman (2143) 324-327 By Grace Christianson at 2:37 pm, Jun 03, 2024 SFD 6/5/2024 DSR-6/4/24 10-404 * BOPE test to 2000 psi. * Caliper log to AOGCC upon completion. * MIT-IA to 2000 psi to be charted and recorded. * Approved for forward circulating jet pump in compliance with CO 808. MGR03JUL24 * SSVs required on IA and injection tubing. *Approved variance to 20 AAC 25.265 (c)(1) SSV on producing IA will not be in vertical run of the tree. &':IRU-/& Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.07.03 12:45:57 -08'00'07/03/24 RBDMS JSB 070924 RWO – Tubing Swap Well: MPU S-17 Date: 25 Mar 2024 Well Name: MPU S-17 API Number: 50-029-23115-00-00 Current Status: SI Producer [T x IA] Pad: S-Pad Estimated Start Date: June 20, 2024 Rig: ASR 1 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-173 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Brian Glasheen (907) 564-5277 (O) (907) 545-1144 (M) Current Bottom Hole Pressure: 1342 psi @ 4000’ TVD 5/12/24 SPBPS | 6.5 PPGE MPSP: 942 psi Gas Column Gradient (0.1 psi/ft) Inclination at SS: 70 @ 4569’ Min Restriction: 2.225” @ 4569’ SS Reducer Brief Well Summary: MPU S-17 was drilled in September 2002 as a dual lateral Oa and Ob producer. TxIA communication was verified in September February 2023. Troubleshooting was performed but due to the compromised tubing (patched at 4110’) and jet pump configuration a tubing swap and possible tie-back liner is required. Notes Regarding Wellbore Condition x MIT-IA Passed to 4,200 psig on 3/10/2014. x CMIT-TxIA to 1000 psi failed on 3/6/2024. x Ultrasonic leak detect tool detected an anomaly at ~4000’. There is known TxIA communication at this depth, but the log interpretation looks like a casing leak. Objective: Pull 4-1/2” upper completion, install a 3-1/2” completion and return well to production. We will be installing a forward-circulating jet pump as this well is a monobore completion, and we do not want to subject the production casing to power fluid header pressure. A contingency plan is outlined in the case that the production casing is leaking at ~4000’. Pre-Rig Procedure (No sundry required): Eline & Fullbore 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU reverse out skid and 500 bbl returns tank. 4. MIRU eline and pressure test PCE to 250 psi low / 2000 psi high. 5. RIH with mechanical tubing cutter. 6. Cut tubing on top of 3.5” short joint above packer ~4,605’. POOH and RDMO eline. a. SL drifted with 3.70” to 4603’ on 5/14/24. RWO – Tubing Swap Well: MPU S-17 Date: 25 Mar 2024 7. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. 8. Confirm well is dead. Contact the operations engineer if freeze protection is needed depending on ASR arrival. 9. RD fullbore pumpers and reverse out skid. 10. RU crane. Set BPV. ND tree and tubing head adapter. NU BOPE. 11. NU BOPE house. Spot mud boat. Brief RWO Procedure (Sundry Approval Required): 12. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines. 13. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ produced water prior to setting CTS. 14. Test BOPE to 250 psi Low/ 2,000 psi High, annular to 250 psi Low/ 2,000 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 4-1/2” test joint. e. Test fixed ram’s and annular with 5-1/2’’ test joint. f. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 15. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV, run lubricator as required for pressure management. 16. MU landing joint or spear, PU and recover tubing hanger. a. Recorded PU weight was 75k and SO was 70k. 17. POOH and lay down the 4-1/2” tubing. 18. MIRU SL and pressure test lubricator to 250 psi low / 2000 psi high. 19. Pull memory caliper from 4-1/2” tubing stub @4605’ to surface. RDMO SL. a. Send caliper field print to AOGCC engineer: melvin.rixse@alaska.gov. 20. RIH with test packer and test 7-5/8” casing to 2000 psi. a. Test above tubing stub @ 4605’. b. If this fails, move uphole in 100’ intervals and test until leak depth is determined. 21. Consult with OE with results during or after testing to determine if Scab Contingency needs to be executed. 22. PU new 3-1/2” completion and run: A 3-1/2” Non-Sealing Overshot with Dual Pins @ ~4605’ Pup Joint, 3-1/2" B Pup Joint, 3-1/2” 2-7/8” XN Nipple with RHC Installed Pup Joint, 3-1/2” 1 Joint Tubing, 3-1/2" 30 minute charted/recorded test to 2000 psi. - mgr RWO – Tubing Swap Well: MPU S-17 Date: 25 Mar 2024 C Pup Joint, 3-1/2" 7-5/8” x 3-1/2” Packer @ ~4525’ Pup Joint, 3-1/2" 1 Joint Tubing, 3-1/2" D Pup Joint, 3-1/2" Gauge Carrier, Baker, Zenith Gauge Installed Pup Joint, 3-1/2" 1 Joint Tubing, 3-1/2" E Pup Joint, 3-1/2" 3-1/2” Champion X Forward-Circulating Ported Pump Pup Joint, 3-1/2" ~150 Joints Tubing, 3-1/2" 23. Shear out on 3.5” tubing stub at 4,614’. Space out and land tubing hanger. Note pickup and slack- off weights on tally. 24. Pump 100 bbls inhibited source water followed by 80 bbls FP down 3-1/2” x 7-5/8” IA. 25. Pump 30 bbls FP down tubing. 26. Drop ball & rod (Sized for 2-7/8” RHC) and pressure up on tubing to set packer as per manufacturer procedures. Perform MIT-T to 3650 psi for 30 minutes charted. Perform MIT-IA to 2000 psi for 30 minutes charted. 27. Set BPV. Post-Rig Procedure: Slickline & Well Support 28. RD mud boat. RD BOPE house. Move to next well location. 29. RU crane. ND BOPE. 30. NU 3-1/8” 5M tree. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 31. RD crane. Move 500 bbl returns tank and rig mats to next well location. 32. MIRU SL and PT lubricator to 250 psi low / 2000 psi high. 33. Pull Ball & Rod and RHC plug from 2-7/8” XN. RDMO SL. 34. Turn well over to production. RU well house and flowlines. w/ tubing hanger - mgr RWO – Tubing Swap Well: MPU S-17 Date: 25 Mar 2024 Scab Liner Contingency: 1. RIH with 5-1/2” tie-back assembly. A 3-1/2” Non-Sealing Overshot with Dual Pins @ ~4605’ Pup Joint, 3-1/2” 3-1/2” XN Nipple XO Pup Joint, 4-1/2 x 3-1/2” C Pup Joint, 4-1/2" 7-5/8” x 4-1/2” Packer @ ~4575’ Pup Joint, 4-1/2" 1 Joint Tubing, 4-1/2" D Pup Joint, 4-1/2" 4-1/2” NCS Multi-Cycle HP2 Frac Sleeve @ ~4500’ Pup Joint, 4-1/2" 1 Joint Tubing, 4-1/2" E Crossover 5-1/2” x 4-1/2” Tubing 5-1/2” Joints Tubing, 5-1/2" 2. Shear out on 3.5” tubing stub at 4,605’. Space out and land tubing hanger. RILDS. 3. RU SL and set PX plug in 3-1/2” XN Nipple. 4. Load tieback and perform MIT-T to 2000 psi for 30 minutes charted. 5. RIH with SL and cover plug with 5 gallons of river sand. RDMO SL. 6. Make up NCS sleeve shifting BHA + drill collar(s) on 2-7/8’’ workstring and TIH to sleeve to cement tieback. Capacity Volume to NCS sleeve @ ±4500’ MD 2-7/8” workstring 0.0052 bbl/ft 23.5 bbl 7-5/8” x 5-1/2” annulus 0.0165 bbl/ft 74 bbl 5-1/2” x 2-7/8” annulus 0.0152 bbl/ft 68.5 bbl 7. Circulate a 5 bbl gel pill inside the 5-1/2” x 2-7/8’’ annulus to be above the sleeve and assist in reversing out. 8. Shift NCS sleeve open per vendor recommendation. a. It should have shear pins installed requiring a total force of per vendor recommendation down to open. This is light enough that slacking off the workstring should open the sleeve, however it is possible to pressure up the backside of the workstring to help shift the sleeve. 9. Circulate a bottoms up taking returns from the 7-5/8” x 5-1/2” annulus casing valve, and verify 1 for 1 returns. a. Monitor 2-7/8” x 5-1/2” annulus to verify no leakage past the NCS sleeve. 10. Cement the 7” x 5-1/2” annulus with the following: a. 5 bbl fresh water b. 5 bbl mudpush c. 94 bbl 13ppg cement (20 bbl excess) w/ tubing hanger - mgr RWO – Tubing Swap Well: MPU S-17 Date: 25 Mar 2024 d. 22.5 bbl fresh water spacer and displacement, this should leave 1 bbl of cement in the workstring. 11. Shift sleeve closed with straight pull per vendor. 12. Bleed off pressure from 5-1/2”X 2-7/8’’ workstring annulus to verify sleeve is closed. a. Pressure should bleed off very quickly and if it does not bleed off quick sleeve is likely still open and we need to pressure up to keep cement from swapping. 13. RU to start reversing out. a. Begin reversing out at max rate to 10’ above XN Nipple at ±4595’. b. Space out from NCS tool so that we don’t tag the prong. c. Reciprocate pipe back up to 4450’ and back down to 10’ above 3-1/2” XN nipple at ±4595’. 14. Test 5-1/2” tieback to 2000 psi to ensure sleeve has closed. POOH. 15. RU SL and pull PX prong and plug from 3-1/2” XN Nipple ±4595’. RDMO SL. 16. Open the 7” x 5-1/2” casing valve to verify 5-1/2” primary packoff integrity. 17. Set TWC and pressure test to 2000 psi. 18. Confirm no flow, then break off BOPs and stack new tubing spool with secondary packoff. 19. Test packoffs to 3500psi. 20. NU BOPs, Test break to 2000 psi, then pull TWC. 21. PU new 3-1/2” completion and run: A 3-1/2” WLEG @ ~4400’ Pup Joint, 3-1/2" B Pup Joint, 3-1/2” 2-7/8” XN Nipple with RHC Installed Pup Joint, 3-1/2” 1 Joint Tubing, 3-1/2" C Pup Joint, 3-1/2" 5-1/2” x 3-1/2” Packer @ ~4320’ Pup Joint, 3-1/2" 1 Joint Tubing, 3-1/2" D Pup Joint, 3-1/2" Gauge Carrier, Baker, Zenith Gauge Installed Pup Joint, 3-1/2" 1 Joint Tubing, 3-1/2" E Pup Joint, 3-1/2" 3-1/2” Champion X Forward-Circulating Ported Pump Pup Joint, 3-1/2" ~150 Joints Tubing, 3-1/2" 22. Tag up on 5-1/2” x 4-1/2” crossover at ~4400’. Space out and land tubing hanger. Note pickup and slack-off weights on tally. 23. Pump 50 bbls inhibited source water followed by 30 bbls FP down 3-1/2” x 5-1/2” IA. 24. Pump 30 bbls FP down tubing. w/ tubing hanger - mgr RWO – Tubing Swap Well: MPU S-17 Date: 25 Mar 2024 25. Drop ball & rod (Sized for 2-7/8” RHC) and pressure up on tubing to set packer as per manufacturer procedures. Perform MIT-T to 3650 psi for 30 minutes charted. Perform MIT-IA to 2000 psi for 30 minutes charted. 26. Set BPV. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Contingent Proposed Schematic 4. BOPE Schematic Window in 7 5/8“ Casing @ 4780‘-4792’ Well Angle @ window = 75° Camco 4.5“ x 1” w/ BK latch sidepocket KGB-2 GLM DATE REV. BY COMMENTS HILCORP ALASKA LLC MPS-17 78 jts - 4 1/2“, 12.6#/ft. Slotted Liner 12.6# L-80 IBT (5175‘-8386’) Btm. Baker 4 1/2” Guide Shoe 8387’ 6 1/8“ Hole td @ 8390’ OB Lateral Btm. 4 1/2” Float Shoe 8225‘ 82 jts. - 4 1/2” Slotted Liner 12.6# L-80 IBT (4801‘-8185’) 6 1/8“ Hole td @ 8280‘ Baker Hook Wall Hanger above 7 5/8“ Window 25.41‘ Baker Hook Wall Hanger outside 7 5/8“ Window 5.85‘ 55‘ Rat holeOA Lateral MILNE POINT UNIT WELL S-17 API NO: 50-029-23115 20" x 34“ insulated, 215 #/ft. A-53 Tree: 4-1/16“ - 5M FMC Wellhead: 11” x 4.5“ 5M Gen 6 w/ 4.5” TCII T&B Tubing Hanger 4“ CIW “H” BPV profile 7 5/8“ HES Float Collar 5106‘ 7 5/8” HES Float Shoe 5188’ Baker 7“ Tie Back Sleeve 5070‘ Baker ZXP Liner Top Packer 5077’ Baker 7 5/8“ x 5 1/2“ HMC Liner Hanger 5083‘ Orig. KB Elev. = 65.90’ (Doyon 141) Orig. RT Elev.= 25.53’ (Doyon 141) API NO: 50-029-23115-60 1993‘ Phoenix Discharge gauge 4552‘ 4.5“ HES “XD” Dura sliding sleeve (3.850” id ) 4569‘ Phoenix Jet Pump gauge sensor 4588‘NOTE: ID change min. 2.840“ 4.5“ x 3.5” X-Over 4603‘ 4614‘ 7 5/8“ x 4.5” Baker S-3 PKR. 3.875“ ID 4616‘ 3.5“ HES XN-Nipple ( 2.750” No Go ) 4620‘ WLEG 4666‘ 3‘ Rat hole 9/29/02 Lee Hulme Drilled & Completed Doyon 141 KOP @ 2500‘ 30 to 50 degrees 3300’ - 4300‘ Hole angle passes 70 degrees @ 4500’ 70 degrees at sliding sleeve 3.5“ x 4.5” X-Over 4.5“ x 3.5” X-Over 4660‘ Min. ID through tubing 2.840“ @ 4588‘ Min. ID through XN 2.750“ @ 4660’ 3.813“ ID ( Opens down ) 1/28/10 - Nipple reducer set in sleeve 3.813” x 2.31“ (3.80” OD x 2.25“ ID) OAL = 58” 112‘ 7 5/8“ 29.7# L-80 IBT-M casing ( drift ID = 6.75”, cap = .0262 BPF w/ tbg. ) 4.5“ 12.6# L-80 IBT-M tubing ( ID = 3.958”, cap = .0152 BPF ) 3.5“, 9.2# L-80 NSCT tubing ( ID = 2.992”, cap = .0087 BPF ) (4172‘ tvd) (4136‘ tvd) “Reverse Circulation” Jet Pump Configuration Power FluidPower FluidReservoir FluidSliding Sleeve BodySliding Sleeve10/21/02 B. Hasebe Addition of Jet Pump Schematic Caliper survey on 7/5/09 indicates possible buckling in the tbg at 4534‘X 3/28/2010 - 9 CHR Flo-Gaurd 45 KB Upper/Lower Straddle Pkr./ 4“ GS Fish Neck/30K release Top = 4110‘ Top Element = 4112’ Btm Element = 4132‘ WLEG = 4136’ Min ID thru patch = 2.45” 3/28/10 REH TBG patch set Note: Differential PSI ratings: SSD Reducer (top down) = 4000 psi KB Packoff - 3500 psi _____________________________________________________________________________________ Revised By: TDF 5/1/2024 PROPOSED Milne Point Unit Well: MP S-17 Last Completed: 9/29/2002 PTD: 202-173 15 16 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 92 / H-40 / Welded N/A Surface 112' 7-5/8"Surface 29.7 / L-80 / IBT-M 6.875 Surface 5,090’ 4-1/2”Liner “OA”12.6 / L-80 / IBT 3.958 4,758’8,225' 4-1/2”Liner “OB”12.6 / L-80 / BTC 3.958 5,070’8,387’ TUBING DETAIL 3-1/2”Tubing 9.2 / L-80 / TCII 2.992 Surface’±4,666’ SLOTTED LINER DETAIL 4-1/2”Liner “OA”12.6 / L-80 / IBT 3.958 4,801’8,225’ 4-1/2”Liner “OB”12.6 / L-80 / BTC 3.958 5,175’8,387’ JEWELRY DETAIL No Depth Item 1 ±X,XXX’Champion X Forward Circulating Ported Pump (min ID: 2.668”) 2 ±X,XXX’Gauge Carrier, Zenith Gauge Installed 3 ±4,525’7-5/8” x 3-1/2 Packer 4 ±X,XXX’2-7/8” XN Nipple (2.250” Min ID) 5 ±4,605’3-1/2” Non-Sealing Overshot 6 4,616’7-5/8”” x 4-1/2” Baker S-3 Packer (3.875” ID) 7 4,620’4-1/2” X 3-1/2” X-Over 8 4,660’3-1/2” HES XN Nipple -2.750” No-Go Min ID 9 4,665’Wireline Entry Guide -Btm at ±4,666’ 10 4,775’Baker Hook Wall, Hanger above 7-5/8” Window 11 4,774’Baker Hook Wall, Hanger below 7-5/8” Window 12 5,070’Baker Tie Back Sleeve 13 5,077’Baker ZXP Liner Top Packer 14 5,083’Baker 7-5/8” x 5-1/2” HMC Liner Hanger 15 8,225’Btm Baker 4-1/2” Guide Shoe (OA Lateral) 16 8,387’Btm Baker 4-1/2” Guide Shoe (OB Lateral) OPEN HOLE / CEMENT DETAIL 20"Cmt w/ 260 sx of Arcticset in 42” Hole 7-5/8"Cmt w/ 906 sx PF ‘L’, 337 sx Class “G” in 9-7/8” Hole 4-1/2”Uncemented Liner in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 2,500’ MD 30° to 50° - 3,300’ to 4,300’ Hole Angle Passes 70° @ 4,500’ 70° at Sliding Sleeve TREE & WELLHEAD DETAIL Tree 4-1/16 – 5M FMC Wellhead 11” x 4-1/2” 5M Gen 6 w/ 4.5” TCII T & B Tubing Hanger 4” CIW ‘H” BPV Profile GENERAL WELL INFO API: 50-029-23194-00-00 Drilled and Completed by Doyon 14 – 4/03/2004 ESP Repair by Nabors 3S – 5/19/2006 ESP Repair by Nabors 3S – 6/09/2008 ESP Repair by Nabors 4ES – 8/31/2008 Convert to Jet Pump by Doyon 16 – 3/16/2013 LATERAL WINDOW DETAIL Top of “OA” Window @ 4,780’ MD; Bottom @ 4,792’ MD; Angle @ Window is 75 deg _____________________________________________________________________________________ Revised By: TDF 5/1/2024 CONTINGENT PROPOSED Milne Point Unit Well: MP S-17 Last Completed: 9/29/2002 PTD: 202-173 18 19 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 92 / H-40 / Welded N/A Surface 112' 7-5/8"Surface 29.7 / L-80 / IBT-M 6.875 Surface 5,090’ 5-1/2”Scab 17 / L-80 / JBEAR 4.892 Surface ±4,500’ 4-1/2”Liner “OA”12.6 / L-80 / IBT 3.958 4,758’8,225' 4-1/2”Liner “OB”12.6 / L-80 / BTC 3.958 5,070’8,387’ TUBING DETAIL 3-1/2”Tubing 9.2 / L-80 / TCII 2.992 Surface’±4,666’ SLOTTED LINER DETAIL 4-1/2”Liner “OA”12.6 / L-80 / IBT 3.958 4,801’8,225’ 4-1/2”Liner “OB”12.6 / L-80 / BTC 3.958 5,175’8,387’ JEWELRY DETAIL No Depth Item 1 ±X,XXX’Champion X Forward Circulating Ported Pump (min ID: 2.668”) 2 ±X,XXX’Gauge Carrier, Zenith Gauge Installed 3 ±X,XXX’5-1/2” x 3-1/2 Packer 4 ±X,XXX’2-7/8” X Nipple (2.313” Min ID) 5 ±4,400’3-1/2” WLEG 6 ±4,500’4-1/2” NCS Multi-Cycle Frac Sleeve 7 ±X,XXX’7-5/8” x 4-1/2” Permanent Packer 8 ±X,XXX’3-1/2” XN Nipple (2.750” Min ID) 9 ±4,605’3-1/2” Non-Sealing Overshot 10 4,616’7-5/8”” x 4-1/2” Baker S-3 Packer (3.875” ID) 11 4,660’3-1/2” HES XN Nipple (2.750” Min ID) 12 4,666’Wireline Entry Guide 13 4,775’Baker Hook Wall, Hanger above 7-5/8” Window 14 4,774’Baker Hook Wall, Hanger below 7-5/8” Window 15 5,070’Baker Tie Back Sleeve 16 5,077’Baker ZXP Liner Top Packer 17 5,083’Baker 7-5/8” x 5-1/2” HMC Liner Hanger 18 8,225’Btm Baker 4-1/2” Guide Shoe (OA Lateral) 19 8,387’Btm Baker 4-1/2” Guide Shoe (OB Lateral) OPEN HOLE / CEMENT DETAIL 20"Cmt w/ 260 sx of Arcticset in 42” Hole 7-5/8"Cmt w/ 906 sx PF ‘L’, 337 sx Class “G” in 9-7/8” Hole 4-1/2”Uncemented Liner in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 2,500’ MD 30° to 50° - 3,300’ to 4,300’ Hole Angle Passes 70° @ 4,500’ 70° at Sliding Sleeve TREE & WELLHEAD DETAIL Tree 4-1/16 – 5M FMC Wellhead 11” x 4-1/2” 5M Gen 6 w/ 4.5” TCII T & B Tubing Hanger 4” CIW ‘H” BPV Profile GENERAL WELL INFO API: 50-029-23194-00-00 Drilled and Completed by Doyon 14 – 4/03/2004 ESP Repair by Nabors 3S – 5/19/2006 ESP Repair by Nabors 3S – 6/09/2008 ESP Repair by Nabors 4ES – 8/31/2008 Convert to Jet Pump by Doyon 16 – 3/16/2013 LATERAL WINDOW DETAIL Top of “OA” Window @ 4,780’ MD; Bottom @ 4,792’ MD; Angle @ Window is 75 deg Updated 5/25/2024 11” BOPE Shaffer 11'’-5000 CIW-U 4.30'Hydril GK 11" - 5000 2-7/8" x 5" VBR Blind 11'’- 5000 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManual Stripping Head ManualManual 2-7/8" x 5" VBR Milne Point ASR 11” BOP w/ Jacks 05/17/2017 Milne Point ASR 11” BOP (Triple) 2024 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/31/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240531 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 1/25/2024 AK E-LINE JB/GR/RBP MPI 2-14 50029216390000 186149 5/8/2024 READ CaliperSurvey MPS-17 50029231150000 202173 5/14/2024 READ LeakPointSurvey PBU GNI-03 50029228200000 197189 5/21/2024 READ PressureTemperatureLog PBU GNI-04 50029233670000 207117 5/22/2024 READ CaliperSurvey PBU GNI-04 50029233670000 207117 5/20/2024 READ PressureTemperatureLog TBU K-12RD2 50733201560200 208088 5/17/2024 READ CaliperSurvey TBU K-17 50733202480000 173001 5/16/2024 READ CaliperSurvey Please include current contact information if different from above. T38865 T38866 T38867 T38868 T38869 T38869 T38870 T38871 MPS-17 50029231150000 202173 5/14/2024 READ LeakPointSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.31 13:00:13 -08'00' From:Rixse, Melvin G (OGC) To:Todd Sidoti - (C) Cc:Tom Fouts; Christianson, Grace K (OGC); Coldiron, Samantha J (OGC); Taylor Wellman Subject:Sundry 324-188, PTD 202-173 MPU S-17, CO808 Compliance Date:Monday, April 8, 2024 9:36:39 AM Attachments:Hilcorp_MPU_S-17_received_0040124_review.pdf Todd, Sundry approval for well MPU S-17, PTD 202-173 is denied. Well MPU S-17 does not comply to CO808 Rule 2. Reconsideration and Appeal Notice As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Grace Christianson, Samantha Coldiron, Tom Fouts, Taylor Wellman 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 Tubing Cut Other: Tubing Swap 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,390' N/A Casing Collapse Conductor N/A Surface 4,790psi Liner "OA"7,500psi Liner "OB"7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE POINT SCHRADER BLUFF OIL N/A 4,136' 8,390' 4,136' 942 N/A Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT S-17 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 4/15/2024 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 202-173 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23115-00-00 Hilcorp Alaska LLC C.O. 477.05 4,136' 5,090' 8,225' Length Size Proposed Pools: 112' 112' TVD Burst 4-1/2"3,212' 3,424' MD N/A 8,430psi 6,890psi 8,430psi 5,090' 4,093' Perforation Depth MD (ft): 8,387' See Schematic See Schematic 3-1/2" 78' 20" 7-5/8" 4-1/2" 5,179' 7-5/8" x 4-1/2" Baker S-3 and N/A 4,616 MD/ 4,181 TVD and N/A Todd Sidoti todd.sidoti@hilcorp.com 777-8443 4-1/2" 12.6 / L-80 / IBT 4,620' 9.2 / L-80 / TCII 4,666' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:18 am, Apr 01, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.04.01 07:56:23 - 08'00' Taylor Wellman (2143) RWO Tubing Swap Well: MPU S-17 Date: 25 Mar 2024 Well Name: MPU S-17 API Number: 50-029-23115-00-00 Current Status: SI Producer [T x IA] Pad: S-Pad Estimated Start Date: April 15, 2024 Rig: ASR 1 Reg. Approval Reqd? Yes Date Reg. Approval Recvd: Regulatory Contact: Tom Fouts Permit to Drill Number: 204-020 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Brian Glasheen (907) 564-5277 (O) (907) 545-1144 (M) Current Bottom Hole Pressure: 1342 psi @ 4000 TVD 7/27/12 SPBPS | 6.5 PPGE MPSP: 942 psi Gas Column Gradient (0.1 psi/ft) Inclination at SS: 70 @ 4569 Min Restriction: 2.225 @ 4569 SS Reducer Brief Well Summary: MPU S-17 was drilled in September 2002 as a dual lateral Oa and Ob producer. TXIA communication was verified in September February 2023. Troubleshooting was performed but due to the compromised tubing (patched at 4110) and jet pump configuration a tubing swap is in order. Notes Regarding Wellbore Condition MIT-IA Passed to 4,200 psig on 3/10/2014. CMIT-TxIA to 1000 psi failed on 3/6/2024. Objective: Pull 4-1/2 upper completion, install a 3-1/2 completion and return well to production. Pre-Rig Procedure (No sundry required): Slickline & Fullbore 1. MIRU SL and fullbore, pressure test lubricator to 250 psi low / 2000 psi high. 2. RIH and pull blanking sleeve from SS @ 4569. 3. RIH and pull KB patch assembly @ 4110. a. 4 GS fish neck pinned to release at 30,000#. 4. RIH and set XX plug in XN @ 4660. POOH. 5. Perform CMIT-TxIA to 3650 psi. 6. RIH and pull plug. 7. POOH and RDMO SL. Eline & Fullbore 8. Clear and level pad area in front of well. Spot rig mats and containment. 9. RD well house and flowlines. Clear and level area around well. 10. RU reverse out skid and 500 bbl returns tank. RWO Tubing Swap Well: MPU S-17 Date: 25 Mar 2024 11. MIRU eline and pressure test PCE to 250 psi low / 2000 psi high. 12. RIH with mechanical tubing cutter. 13. Cut tubing on top of 3.5 short joint above packer ~4,605. POOH and RDMO eline. 14. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. 15. Confirm well is dead. Contact the operations engineer if freeze protection is needed depending on ASR arrival. 16. RD fullbore pumpers and reverse out skid. 17. RU crane. Set BPV. ND tree and tubing head adapter. NU BOPE. 18. NU BOPE house. Spot mud boat. Brief RWO Procedure (Sundry Approval Required): 19. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines. 20. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ produced water prior to setting CTS. 21. Test BOPE to 250 psi Low/ 2,000 psi High, annular to 250 psi Low/ 2,000 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 3-1/2 and 4-1/2 test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 22. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. 23. MU landing joint or spear, PU and recover tubing hanger. a. Recorded PU weight was 75k and SO was 70k. 24. POOH and lay down the 4-1/2 tubing. 25. PU new 3-1/2 completion and run: A 3-1/2 x 4-1/2 Overshot with Dual Pins Pup Joint, 3-1/2" B Pup Joint, 3-1/2 3-1/2 XN Nipple with RHC Installed Pup Joint, 3-1/2 1 Joint Tubing, 3-1/2" C Pup Joint, 3-1/2" 7-5/8 x 3-1/2 Packer @ ~4,520 Pup Joint, 3-1/2" 1 Joint Tubing, 3-1/2" D Pup Joint, 3-1/2" Gauge Carrier, Baker, Zenith Gauge Installed RWO Tubing Swap Well: MPU S-17 Date: 25 Mar 2024 Pup Joint, 3-1/2" 1 Joint Tubing, 3-1/2" E Pup Joint, 3-1/2" Sliding Sleeve, 2.813" X profile, covered ports for I-wire bypass (closed) Pup Joint, 3-1/2" ~150 Joints Tubing, 3-1/2" 26. Shear out on 3.5 tubing stub at 4,614. Space out and land tubing hanger. Note pickup and slack- off weights on tally. 27. Pump 100 bbls inhibited source water followed by 80 bbls FP down 3-1/2 x 7-5/8 IA. 28. Pump 30 bbls FP down tubing. 29. Drop ball & rod and pressure up on tubing to set packer as per manufacturer procedures. Perform MIT-IA to 3650 psi (charted). 30. Set BPV. Post-Rig Procedure: Slickline & Well Support 31. MIRU SL and PT lubricator to 250 psi low / 2000 psi high. 32. Pull Ball & Rod and RHC plug from XN @ ~4570. RDMO SL. 33. RD mud boat. RD BOPE house. Move to next well location. 34. RU crane. ND BOPE. 35. NU 3-1/8 5M tree. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 36. RD crane. Move 500 bbl returns tank and rig mats to next well location. 37. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic Window in 7 5/8 Casing @ 4780-4792 Well Angle @ window = 75° Camco 4.5 x 1 w/ BK latch sidepocket KGB-2 GLM DATE REV. BY COMMENTS HILCORP ALASKA LLC MPS-17 78 jts - 4 1/2, 12.6#/ft. Slotted Liner 12.6# L-80 IBT (5175-8386) Btm. Baker 4 1/2 Guide Shoe 8387 6 1/8 Hole td @ 8390 OB Lateral Btm. 4 1/2 Float Shoe 8225 82 jts. - 4 1/2 Slotted Liner 12.6# L-80 IBT (4801-8185) 6 1/8 Hole td @ 8280 Baker Hook Wall Hanger above 7 5/8 Window 25.41 Baker Hook Wall Hanger outside 7 5/8 Window 5.85 55 Rat holeOA Lateral MILNE POINT UNIT WELL S-17 API NO: 50-029-23115 20" x 34 insulated, 215 #/ft. A-53 Tree: 4-1/16 - 5M FMC Wellhead: 11 x 4.5 5M Gen 6 w/ 4.5 TCII T&B Tubing Hanger 4 CIW H BPV profile 7 5/8 HES Float Collar 5106 7 5/8 HES Float Shoe 5188 Baker 7 Tie Back Sleeve 5070 Baker ZXP Liner Top Packer 5077 Baker 7 5/8 x 5 1/2 HMC Liner Hanger 5083 Orig. KB Elev. = 65.90 (Doyon 141) Orig. RT Elev.= 25.53 (Doyon 141) API NO: 50-029-23115-60 1993 Phoenix Discharge gauge 4552 4.5 HES XD Dura sliding sleeve (3.850 id ) 4569 Phoenix Jet Pump gauge sensor 4588NOTE: ID change min. 2.840 4.5 x 3.5 X-Over 4603 4614 7 5/8 x 4.5 Baker S-3 PKR. 3.875 ID 4616 3.5 HES XN-Nipple ( 2.750 No Go ) 4620 WLEG 4666 3 Rat hole 9/29/02 Lee Hulme Drilled & Completed Doyon 141 KOP @ 2500 30 to 50 degrees 3300 - 4300 Hole angle passes 70 degrees @ 4500 70 degrees at sliding sleeve 3.5 x 4.5 X-Over 4.5 x 3.5 X-Over 4660 Min. ID through tubing 2.840 @ 4588 Min. ID through XN 2.750 @ 4660 3.813 ID ( Opens down ) 1/28/10 - Nipple reducer set in sleeve 3.813 x 2.31 (3.80 OD x 2.25 ID) OAL = 58 112 7 5/8 29.7# L-80 IBT-M casing ( drift ID = 6.75, cap = .0262 BPF w/ tbg. ) 4.5 12.6# L-80 IBT-M tubing ( ID = 3.958, cap = .0152 BPF ) 3.5, 9.2# L-80 NSCT tubing ( ID = 2.992, cap = .0087 BPF ) (4172 tvd) (4136 tvd) Reverse Circulation Jet Pump Configuration Po w e r F l u i d Po w e r F l u i d Reservoir Fluid Sl i d i n g S l e e v e B o d y Sl i d i n g S l e e v e 10/21/02 B. Hasebe Addition of Jet Pump Schematic Caliper survey on 7/5/09 indicates possible buckling in the tbg at 4534X 3/28/2010 - 9 CHR Flo-Gaurd 45 KB Upper/Lower Straddle Pkr./ 4 GS Fish Neck/30K release Top = 4110 Top Element = 4112 Btm Element = 4132 WLEG = 4136 Min ID thru patch = 2.45 3/28/10 REH TBG patch set Note: Differential PSI ratings: SSD Reducer (top down) = 4000 psi KB Packoff - 3500 psi _____________________________________________________________________________________ Revised By: TDF 3/26/2024 PROPOSED Milne Point Unit Well: MP S-17 Last Completed: 9/29/2002 PTD: 202-173 15 16 TD =8,390(MD) / TD = 4,136(TVD) 20 Orig. KB Elev.: 65.9/ Orig. RT Elev.: 25.53 (Doyon 141) 7-5/8 10 11 10-3/4 2 1213 14 OA Lateral PBTD =8,390(MD) / TD = 4,136(TVD) OB Lateral 6 4 7 5 8 9 Min ID =3.725 ID 3 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 7-5/8" Surface 29.7 / L-80 / IBT-M 6.875 Surface 5,090 4-1/2 Liner OA 12.6 / L-80 / IBT 3.958 4,758 8,225' 4-1/2 Liner OB 12.6 / L-80 / BTC 3.958 5,070 8,387 TUBING DETAIL 3-1/2 Tubing 9.2 / L-80 / TCII 2.992 Surface ±4,666 SLOTTED LINER DETAIL 4-1/2 Liner OA 12.6 / L-80 / IBT 3.958 4,801 8,225 4-1/2 Liner OB 12.6 / L-80 / BTC 3.958 5,175 8,387 JEWELRY DETAIL No Depth Item 1 ±X,XXX Sliding Sleeve. 2.813 X Profile, Covered Ports for I-Wire Bypass (Closed) 2 ±X,XXX Gauge Carrier, Zenith Gauge Installed 3 ±X,XXX 7-5/8 x 3-1/2 Packer 4 ±X,XXX 3-1/2 XN Nipple w/ RHC Installed 5 ±X,XXX 3-1/2 Overshot with Dual Pins 6 4,616 7-5/8 x 4-1/2 Baker S-3 Packer (3.875 ID) 7 4,620 4-1/2 X 3-1/2 X-Over 8 4,660 3-1/2 HES XN Nipple -2.750 No-Go Min ID 9 4,665 Wireline Entry Guide -Btm at ±4,666 10 4,775 Baker Hook Wall, Hanger above 7-5/8 Window 11 4,774 Baker Hook Wall, Hanger below 7-5/8 Window 12 5,070 Baker Tie Back Sleeve 13 5,077 Baker ZXP Liner Top Packer 14 5,083 Baker 7-5/8 x 5-1/2 HMC Liner Hanger 15 8,225 Btm Baker 4-1/2 Guide Shoe (OA Lateral) 16 8,387 Btm Baker 4-1/2 Guide Shoe (OB Lateral) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset in 42 Hole 7-5/8" Cmt w/ 906 sx PF L, 337 sx Class G in 9-7/8 Hole 4-1/2 Uncemented Liner in 6-1/8 Hole WELL INCLINATION DETAIL KOP @ 2,500 MD 30° to 50° - 3,300 to 4,300 Hole Angle Passes 70° @ 4,500 70° at Sliding Sleeve TREE & WELLHEAD DETAIL Tree 4-1/16 5M FMC Wellhead 11 x 4-1/2 5M Gen 6 w/ 4.5 TCII T & B Tubing Hanger 4 CIW H BPV Profile GENERAL WELL INFO API: 50-029-23194-00-00 Drilled and Completed by Doyon 14 4/03/2004 ESP Repair by Nabors 3S 5/19/2006 ESP Repair by Nabors 3S 6/09/2008 ESP Repair by Nabors 4ES 8/31/2008 Convert to Jet Pump by Doyon 16 3/16/2013 LATERAL WINDOW DETAIL Top of OA Window @ 4,780 MD; Bottom @ 4,792 MD; Angle @ Window is 75 deg Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 S CANNED FEB 2 4 2012 December 30, 2011 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue �f Anchorage, Alaska 99501 a,� � 1 / 3 Subject: Corrosion Inhibitor Treatments of MPS -Pad l 1 17 0 p Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, r„,. Mehreen Vazir BPXA, Well Integrity Coordinator III • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPS -Pad 10/11/2011 Corrosion • Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPS-01A 2070340 50029231410100 0.25 NA 0.25 NA 5.1 9/6/2011 MPS-02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/30/2011 MPS-03 2021460 50029231050000 Open Flutes - Treated MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/3/2009 MPS-08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/30/2011 MPS-09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS -10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -11 2021130 50029230920000 1 NA 1 NA 10.2 7/29/2011 MPS -12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7/29/2011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS-14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 7/29/2011 MPS -15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS -16 2030650 50029231510000 1.2 NA 1.2 NA 10.2 7/29/2011 ---- MPS -17 2021730 50029231150000 Open Flutes - Treated MPS -18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7/29/2011 MPS-20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS -22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 7/28/2011 MPS-23 2021320 50029230980000 Open Flutes - Treated MPS -24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 7/28/2011 MPS -25 2021030 50029230890000 Open Flutes - Treated MPS-26 2030610 50029231500000 1 NA 1 NA 8.5 7/28/2011 MPS -27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7/28/2011 MPS -28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7/28/2011 MPS -29 2021950 50029231190000 Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS -31 2020140 50029230660000 Open Flutes - Treated MPS-32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 - 7/28/2011 MPS -33A 2061720 50029231230100 1 NA 1 NA 6.8 7/28/2011 MPS -34 2031300 50029231710000 6 NA 6 NA 49.3 7/28/2011 MPS-35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-37 2070520 50029233550000 13.9 Need top job NA MPS-39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS -41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS -43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/11/2011 MPS -90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB-04 500299990799 0.6 NA 0.6 NA 3.4 7/30/2011 ~~'~~ STATE OF ALASKA APR A SK~L AND GAS CONSERVATION COMMIS ~ ~RT OF SUNDRY WELL OPERATIONS 1. Operations ~~~ yell ^ Plug Perforations ^ Stimulate^ Other Q TUBING Performed: Alter Casi~ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ PATCH Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-ente Suspended Well ^ 4112' - 4132' 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory ^ 202-1730 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-23115-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-380109 MPS-17 10. Field/Pool(s): MILNE POINT FIELD / SCHRADER BLUFF OIL POOL 11. Present Well Condition Summary: Total Depth measured 8390 feet Plugs (measured) None feet true vertical 4135.96 feet Junk (measured) None feet Effective Depth measured 8390 feet Packer (measured) 4616' true vertical 4135.96 feet (true vertical) 4181' Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20" 215.5# A-53 34 - 112 34 - 112 Surface 5179 7-5/8"29.7# L-80 31 - 5190 31 - 4290 6890 4790 Intermediate Production 3316 4-1/2", 12.6# L-80 5070 - 8386 4282 - 4136 8430 7500 Liner Liner Perforation depth: Measured depth: OH 8387' - 8390' SL 5175' - 8386' _ _ _ True Vertical depth: 4136' - 4136 4290' - 4136' Tubing: (size, grade, measured and true vertical depth) 4-1 /2" 12.6# L-80 SURFACE - 4666 SURFACE - 4197 Packers and SSSV (type, measured and true vertical depth) 7-5/8"X4.5" BAKER S-3 PKR 4616' 4181' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~},;, i ~ ~ ~ 6~1~~r[, v ~ ~ .w tk v. U'~ek~.-.' ~~. [ t ~' ~ -L. ~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 122 12 975 227 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ 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: N!A Contact Gary Preble Printed Name Gary Pre le Title Data Management Engineer Signature Phone 564-4944 Date 4/8/2010 ~~,~,~ IV-9VY ~~„CU „~~~~ RBDMS APR 0 9 ZOO ~f~ "u~""` ~'"y"'°~ ~'~~~, ~i- tl-~•rb ~f/moo • MPS-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY "-- ~-- ~ ~~ ""WELL SHUT IN ON ARRIVAL"'"" (E-LINE PATCH) INITIAL T/I 200/200 `RUN 1: HEAD/UPCT/FIRING HEAD/#10 SETTING TOOL/PATCH. 9 CHR Flo- Guard 45 KB STRADDLE PKR./4" GS FISH NECK/30K RELEASE TOP=4110' TOP ELEMENT=4112' BTM ELEMENT=4132' WLEG=4136' LENGTH 38' MAX OD 3.7" MIN ID THRU PATCH=2.45" SET PATCH FROM 4112'-4132' FINAL T/I 0/200 ***JOB COMPLETED*** FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL ,Tree: 4-1/16" - 5M FMC Wellhead: 11" x 4.5" 5M Gen 6 w/ 4.5" TCII T&B Tubing Hanger 4" CIW "H" BPV profile 20" x 34" insulated, 215 #!ft. A-53 112` MPS-~ ~ Orig. R~v.= 25.53' (Doyon 141) Min. ID through tubing 2.840" @ 4588` Min. ID through XN 2.750" @ 4660' KOP @ 2500' 30 to 50 degrees 3300' - 4300' Hole angle passes 70 degrees @ 4500' 70 degrees at sliding sleeve 7 5/8" 29.7# L-80 IBT-M casing (drift ID = 6.75", cap = .0262 BPF w/ tbg. ) 4.5" 12.6# L-80 IBT-M tubing ( ID = 3.958", cap = .0152 BPF ) 3.5", 9.2# L-80 NSCT tubing ( ID = 2.992", cap = .0087 BPF ) Camco 4.5" x 1" w/ BK latch 1993' sidepocket KGB-2 GLM 3/28/2010 - 9 CHR Flo-Gaurd 45 KB Upper/Lower Straddle Pkr./ 4" GS Fish Neck/30K release Top = 4110' Top Element = 4112' Btm Element = 4132' WLEG = 4136' Min ID thru patch = 2.45" Caliper survey on 7/5/09 indicates possible buckling in the tbg at 4534' Phoenix Discharge gauge (3.850" id) 4552' 'Reverse Clrculetlon' Jat Pump Conllguratlon s i - - ---~ LLl ~ prod~~aFU~d =1 I ~ ~ ~ I ~I ~ ~I I ~ °I I I I I 1 "1 , ~, ~ I I '~ ~. :~j~~~ ;~~~- 1~ - - Reservdr Flultl 4.5" HES "XD" Dura sliding sleeve 3.813" ID (Opens down) 4569` 1 /28/10 -Nipple reducer set in sleeve 3.813" x 2.31" (3.80" OD x 2.25" ID) OAL = 58" Phoenix Jet Pump gauge sensor 4588' 840" (4172' tvd) NOTE ID h i 2 : c ange m n. . 4.5" x 3.5" X-Over 4603' 3.5" x 4.5" X-Over 4614` 7 5/8" x 4.5" Baker S-3 PKR. 3.875" ID 4616' 4.5" x 3.5" X-Over 4620' 3.5" HES XN-Nipple (2.750" No Go) 4660` WLEG 4666` Window in 7 5/8" Casing @ 4780`-4792' Well Angle @ window = 75° Baker 7" Tie Back Sleeve 5070` Baker ZXP Liner Top Packer 5077' Baker 7 5/8" x 5 1/2" HMC Liner Hanger 5083' 7 5/8" HES Float Collar 5106' 7 5/8" HES Float Shoe 5188' DATE I REV. BY I COMMENTS Baker Hook Wall Hanger above 7 5/8° Window 25.41' Baker Hook Wall ~ Hanger outside 7 5/8° Window 5.85' `~ 6 1/8" Hole td @ 8280' OA Lateral 82 jts. - 4 1/2" Slotted Liner 55' 12.6# L-80 IBT (4801 `-8185') Rat hole Btm. 4 1!2" Float Shoe 8225' 6 1/8" Hole td @ 8390' (4136' tvd) OB Lateral 78 jts - 4 1/2", 12.6#/ft. Slotted Liner 3' 12.6# L-80 IBT (5175'-8386') Rat hole Btm. Baker 4 1/2" Guide Shoe 8387' 9/29/02 'Lee Hulme I Drilled & Completed Doyon 141 I 10/21/02 B. Hasebe Addition of Jet Pump Schematic ~ 3/28/10 I REH I TBG patch set I MILNE POINT UNIT WELL S-17 API NO: 50-029-23115 API NO: 50-029-23115-60 BP EXPLORATION • ~~~f~~fQ ,,. PaoA~ivE D'u-gNOSric Semis, INC. To: A013CC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-9 225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ~. ~. ~ '~~ ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 boa-i~-3 ~9i~9 1) Leak Detection - STP 25-Aug-09 MPU S-17 BL / EDE 50-029-23115-00 2) ,, ~~ _ ~ _ Signed : Date _.. Print Name; PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL. _ sr~ 7, _~ .~`; WEBSRE ~~~----_---- C:\Documents and Settings\Diane Milliams~Desktop\t'ransmit_BP.docx e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CVrPgs _ Inserts\Microfihn _ Marker.doc ~q ö~ ;ì~~ DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Jp¿ !~ Y)vN)1-- API No. 50-029-23115-00-00 Permit to Drill 2021730 Well Name/No. MILNE PT UNIT SB S-17 Operator BP EXPLORATION (ALASKA) INC MD 8390 ~ TVD 4136 ..-/ Completion Date 9/29/2002 /- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES,ABII. IFR/ CASANDRA Well Log Information: Log/ Data Digital Type Med/Frmt L§ÇV/ !:> ~ ~ ~P- ~ ~~ LED C C Pdf C Pdf Well Cores/Samples Information: Name (data taken from Logs Portion of Master Well Data Maint) Electr Dataset Number Name 'àirectíò-nal Survey Directional Survey Lu390 LIS Verification LIS Verification . -..-r Log Log Run Interval OHI Scale Media No Start Stop CH Received Comments 1 0 8390 Open 10/15/2002 MWD 1 0 8390 Open 1 0/15/2002 239 8336 Case 12/13/2002 239 8336 Case 12/13/2002 0 8390 Open 1 0/15/2002 1 0 8390 Open 1 0/15/2002 MWD 1,2,3 228 8390 Open 6/2/2003 25 Final 228 8390 Open 6/2/2003 MWD-ROP, DGR, EWR- MD 25 Final 228 4136 Open 6/2/2003 MWD-DGR, EWR- TVD Sample Set Sent Received Number Comments - JJirêctional Survey Directional Survey [1964 LIS Verification 11964 Induction/Resistivity 1964 Induction/Resistivity Interval Start Stop ADDITIONAL INFORM(~I.. TION Well Cored? Y(!V Chips Received? ~ Analysis Received? Comments: Daily History Received? Ø/N (£)tN Formation Tops ~ DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Permit to Drill 2021730 Well Name/No. MILNE PT UNIT SB $-17 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23115-00-00 MD 8390 TVD 4136 Completion Date 9/29/2002 Completion Status 1-01L Current Status 1-01L UIC N Compliance Reviewed By: - 'J-u ! Date: ;2¿f O~~ ( --...-v' '-' ) §Od- /13 )~ JIC(LoL{ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 15, 2003 RE: MWD Formation Evaluation Logs: MPS-17, AK-MW-22158 MPS-17: Digital Log Images: 50-029-23115-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. AnChRE'ðmêo JUN 0 2 2003 Jij_à Oil & Gø Cons. Gommieeion AnctrOf'lge dO;;)-(/3 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Sign~~^" b,-~ Kß~m~ ) ð09--113 !13Qo WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 33 3 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 12, 2002 RE: MWD Fonnation Evaluation Logs MPS-17, AK-MW-22158 1 LIS fonnatted Disc with verification listing. PùPI#: 50-029-23115-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Signed: ~(,OdP~ . 1,:\ ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised 11/07/02 Start Production 1. Status of Well IBI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3315' NSL, 165' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 4450' NSL, 1115' WEL, SEC. 12, T12N, R10E, UM (OB) At total depth 308' NSL, 4236' WEL, SEC. 01, T12N, R10E, UM (OB) 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. KBE= 65.9' ADL 380109 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 9-16-2002 9-23-2002 9-29-2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8390 4136 FT 8390 4136 FT 0 Yes IBI No 22. Type Electric or Other Logs Run MWD , GR , RES, ABI / IFR / CASANDRA 23. CASING SIZE 20" 7-5/8" 4-1/2" CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE 34' 112' 42" 31' 5190' 9-7/8" 5070' 8386' 6-1/8" CEMENTING RECORD 260 sx Arctic Set (Approx.) 906 sx PF 'L', 337 sx Class 'G' Uncemented Slotted Liner WT. PER FT. 92# 29.7# 12.7# GRADE H-40 L-80 L-80 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Liner 25. SIZE 4-1/2", 12.6#, L-80 MD MD TVD TVD Classification of Service Well 7. Permit Number 202-173 8. API Number 50-029-23115-00 9. Unit or Lease Name Milne Point Unit 10. Well Number MPS-17 11. Field and Pool Milne Point Unit / Schrader Bluff 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost N/A MD 1800' (Approx.) AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 4666' PACKER SET (MD) 4616' 4290' - 4136' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 40 Bbls of Diesel 5175' - 8386' 26. 27. Date First Production October 28,2002 Date of Test Hou rs Tested 1 0/29/2002 6 Flow Tubing Casing Pressure Press. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD 2281 WATER-BBL 0 WATER-BBL GAs-McF 1182 GAs-McF CALCULATED 24-HoUR RATE OIL-BBL CHOKE SIZE GAS-OIL RATIO 518 OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. No core samples were taken. R~iG~ I~E D NOV 082002 ?BDMS 8FL N(JV - , ! ("',t.').; ') ,r.: (j/7') "AlasRa Oil & Gas Gons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Sondra ~7.n ...7 -I-~' Title Technical Assistant ~ewma~~,(:::-<:-~L--. MPS-17 202-173 Well Number Permit No. / Approval No. '" ) 29. Geologic Markers Marker Name Measured Depth SBF2-NA 4410' SBF1-NB 4458' SBE4-NC 45361 SBE2-NE 4579' SBE1-NF 4697' TSBD-OA 4778' TSBC 4889' TSBB-OB 5018' SBA5 5193' I 31. List of Attachments: ) 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 4103' 4124' 41541 4169' 4207' 4230' 4253' 42751 4290' RE€eIVED NOV 0 8 2002 Alaska on,& Gas Qons~ commlsSton . AnchOf8!1Je Date t \ - ù"l- 0 '2..- Prepared By Name/Number: Sondra Stewman, 564-4750 Drilling Engineer: Matt Green, 564-5581 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells; Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 28: If no cores taken, indicate 'none', ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection. Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ') ") f 1. Status of Well 181 Oil 0 Gas 0 Suspended D. Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface f.""::';:~';"~';~:''^'" 3315' NSL, 165' WEL, SEC. 12, T12N, R10E, UM ¡ \).J!Vh'Ld! At top of productive intervalJ. iJA re i. 4450' NSL, 1115' WEL, SEC. 12, T12N, R10E, UM (OB) }:~,1'2-~"~"¡i At ,total depth I ~ væ~! í 308 NSL,4236 WEL, SEC. 01, T12N, R10E, UM (OB) ~-¿-:~"'-¡~¡ t,,!.. ,Ui/.'f.! ::.î;.\¡:,<¡¡r::::rt 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 65.9' ADL 380109 12. Date SpuddeSi 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 9-16-2002 9-23-2002 9-29-2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8390 4136 FT 8390 4136 FT IBI Yes 0 No 22. Type Electric or Other Logs Run MWD , GR , RES, ABI I IFR I CASANDRA 23. CASING SIZE 20" 7-5/8" 4-1/2" Classification of Service Well 7. Permit Number 202-173 8. API Number 50- 029-23115-00 9. Unit or Lease Name Milne Point Unit 1 O. Well Number MPS-17 11. Field and Pool Milne Point Unit I Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1800' (Approx.) WT. PER FT. 92# 29.7# 12.7# GRADE H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE 34' 112' 42" 31' 5190' 9-7/8" 5070' 8386' 6-1/8" CEMENTING RECORD 260 sx Arctic Set (Approx.) 906 sx PF 'L', 337 sx Class 'G' Uncemented Slotted Liner AMOUNT PUllED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Liner SIZE 4-1/2", 12.6#, L-80 TUSING RECORD DEPTH SET (MD) 4666' PACKER SET (MD) 4616' 25. MD TVD MD TVD 5175' - 8386' 4290' - 4136' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 40 Bbls of Diesel 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR Oll-BSl TEST PERIOD GAs-McF WATER-Bsl CHOKE SIZE GAS-Oil RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE Oll-Bsl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or wat'R. ~r~rV'\!Ð No core samples were taken. 28. nCT 2 9 2002 Form 10-407 Rev. 07-01-80 ~ ~ ~ ~Iasl<a Oil & Gas Gons. Co~ ~ Anchorage ~"B OMS B F l NO\/ ¡ (,y Submit In Duplicate ') 29. Geologic Markers Marker Name Measured Depth SBF2-NA 4410' SBF1-NB 4458' SBE4-NC 4536' SBE2-NE 4579' SBE1-NF 4697' TSBD-OA 4778' TSBC 4889' TSBB-OB 50181 SBA5 5193' 31. List of Attachments: ) 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 4103' 4124' c 4154' 4169' 4207' 4230' 4253' 4275' 4290' RECEIVED OCT 2 92002 Alaska OU& Gas Gons. CommIssIon Anchorage Summary of Daily Drilling Reports, Surveys, Leak-Off Test Summary and a Post Rig Work Summary. 32. I hereby certify that the fQJ:epoing is true and correct to the best of my knowledge Signed sondr~wma~~ Title Technical Assistant Date Lo,....aC}-OZ. MPS-17 202-173 Prepared By Name/Number: Sandra Stewman, 564-4750 Well Number Permit No. / Approval No. Drilling Engineer: Matt Green, 564-5581 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 ) ) BP EXPLORATION Operations Summary Report Page 1 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-17 MPS-17 DRILL +COMPLETE DOYON DOYON 141 Start: 9/16/2002 Rig Release: 9/29/2002 Rig Number: 141 Spud Date: 9/16/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/15/2002 09:00 - 13:00 4.00 MOB P PRE MOVE CAMP - SHOP - SDU - FROM MPH-PAD TO MPS-PAD - SET UP CAMP - SDU - SHOP ON S-PAD 13:00 - 13:30 0.50 MOB P PRE PREP RIG FOR MOVE - TRUCKS - FROM H-PAD TO S-PAD - PJSM 13:30 -14:30 1.00 MOB P PRE MOVE PIPE SHEDS - UTILITY MODULES 14:30 - 15:00 0:50 MOB P PRE MOVE ROCK WASHER - LOAD MATTS FOR S-PAD 15:00 - 16:00 1.00 MOB P PRE MOVE SUB MODULE OFF MPH-13A 16:00 - 18:00 2.00 MOB P PRE MOVE PIPE SHEDS - PIT - PUMP - SUB MODULES FROM MPH-13A TO MPS-PAD 18:00 - 20:00 2.00 MOB P PRE MOVE SUB MODULE ONTO MPS-17 WELL - LEVEL SAME 20:00 - 21 :30 1.50 MOB P PRE SET PIT MODULE - PUMP MODULE - PIPE SHEDS 21 :30 - 23:00 1.50 MOB P PRE HOOK UP SERVICE LINES TO SUB - PITS - PUMPS - LEVEL PIPE SHEDS - (TRUCKS RETURNED ROUND TRIP FROM 21 :30 TO 23:00 HRS WITH MOTOR - BOILER - ROCK WASHER MODULES) 23:00 - 00:00 1.00 MOB P PRE SET MOTOR MODULE - BOILER MODULES - RIG UP SERVICE LINES 9/16/2002 00:00 - 01 :00 1.00 MOB P PRE CON'T HOOK UP SERVICE LINES - BERM ROCK WASHER - 01 :00 - 04:00 3.00 RIGU P PRE (ACCEPT RIG @ 01 :00 HRS ON 09/16/2002) - NIPPLE UP RISER TO FLOW LINE - ADD ONE SECTION TO DIVERTOR LINE - SECURE DIVERTOR LINE - TAKE ON WATER IN PITS - LOAD PIPE SHED WITH 4" DRILL PIPE 04:00 - 11 :30 7.50 DRILL P INT1 PICK UP 4" DRILL PIPE FROM PIPE SHED - STAND IN DERRICK 11 :30 - 12:30 1.00 DRILL P INT1 CHANGE OUT HANDLING TOOLS FOR 5" HWDP AND PULLED STABS AND SUBS TO RIG FLOOR. LOADED PIPE SHED WITH 5" HWDP AND JARS. DRIFTED AND STRAPPED IN PIPE SHED. 12:30 - 13:00 0.50 RIGU P PRE TESTED DIVERTER. ACCUMULATOR PRESSURE 3000 PSI. 1900 PSI AFTER CLOSURE. BUILT UP 200 PSI IN 22 SECS AND FULL PRESSURE IN 2 MIN 48 SECS. 5 NITROGEN BOTTLES AT 2000 PSI. 13:00 - 14:00 1.00 DRILL P INT1 MADE UP 17 JTS OF 5" HWDP AND JARS AND STAND IN DERRICK. 14:00 - 14:30 0.50 DRILL P INT1 RIG UP HALLIBURTON SLICK LINE UNIT. 14:30 - 15:00 0.50 DRILL P INT1 HELD PRE SPUD MEETING WITH RIG CREW AND SERVICE PERSONNEL. 15:00 - 16:00 1.00 DRILL P INT1 MAKE UP - BIT - MOTOR - XO - 2 JOINTS 5" HWDP 16:00 - 16:30 0.50 DRILL P INT1 SURFACE TEST - FILL CONDUCTOR - CHECK FOR LEAKS 16:30 - 18:30 2.00 DRILL P INT1 SPUD IN WELL MPS-17 - DRLG 9 7/8" HOLE FROM 110' TO 275' - WOB 5K TO 8K - RPM 70 - GPM 390 - PP 800 - PU 50K - SO 50K - ROT 50K 18:30 - 19:00 0.50 DRILL P INT1 POH - PICK UP MWD - TOP DRIVE DOWN - POH 19:00 - 00:00 5.00 DRILL N RREP INT1 TROUBLE SHOOT TOP DRIVE - TOP DRIVE PIPE HANDLER ROTATING HEAD WON'T ROTATE - REBUILD HYD MOTOR - NO GO - TROUBLE SHOOT SHOT PIN HYD MOTOR ASSY - REMOVE GEAR - MOTOR STILL WILL NOT TURN - REMOVE MOTOR 9/17/2002 00:00 - 01 :00 1.00 DRILL N RREP INT1 REBUILD MOTOR WITH USED AND NEW PARTS - REINSTALL MOTOR - OPERATIONAL 01 :00 - 03:00 2.00 DRILL P INT1 PICK UP BHA - MAKE UP BIT - MOTOR - ORIENT MWD - PULSE TEST Printed: 9/30/2002 9: 15:23 AM ') J ) BP EXPLORATION Operations Summary Report Page 2 of6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-17 MPS-17 DRILL +COMPLETE DOYON DOYON 141 Start: 9/16/2002 Rig Release: 9/29/2002 Rig Number: 141 Spud Date: 9/16/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/17/2002 03:00 - 23:30 20.50 DRILL P INT1 DRILLING FROM 275' TO 3109' WITH 80-90 RPM 475 GALS PER MIN, 2350 PSI 20-25K BIT WT. AST 3.25 ART 10.5 23:30 - 00:00 0.50 DRILL P INT1 CIRC FOR THREE BOTTOMS UP WITH 90 RPMS 475 GALS MIN 2350 PSI, STANDING BACK ONE STAND EVER BOTTOMS UP 9/18/2002 00:00 - 01 :00 1.00 DRILL P INT1 CIRC FOR THREE BOTTOMS UP WITH 90 RPMS 475 GALS MIN 2350 PSI, STANDING BACK ONE STAND EVER BOTTOMS UP 01 :00 - 03:00 2.00 DRILL P INT1 PUMP OUT TO HWDP WITH FULL DRILLING RATE 03:00 - 03:30 0.50 DRILL P INT1 SERVICE TOP DRIVE 03:30 - 05:00 1.50 DRILL P INT1 TRIP TO BOTTOM 05:00 - 10:30 5.50 DRILL P INT1 DRILLING FROM 3109' TO 3760' WITH 80-90 RPM 475 GALS PER MIN, 2600 PSI 20-25K BIT WT. AST 1 HR ART 3.5 HR 10:30 - 18:30 8.00 DRILL N RREP INT1 TROUBLE SHOOT TOP DRIVE FOR GROUND FAUL T- FOUND IN TRAC. MOTOR B-PHASE CABLE, REMOVE AND REPAIR B-PHASE PIGTAIL CABLE CONNECTORS, WHILE WE WERE WORKING ON TOP DRIVE WE CIRC AT RATE 2 BBLS MIN. 289 PSI, MOVED PIPE FREQUENTLY TO KEEP FREE, PIU 108K SIO 91 K 18:30 - 00:00 5.50 DRILL P INT1 DRILLING FROM 3760' TO 4367' WITH 90-100 RPM 475 GALS PER MIN, 2650 PSI, 20-25K BIT WT. AST 1.5 HR ART 2 HR 9/19/2002 00:00 - 08:30 8.50 DRILL P INT1 DRILLING FROM 4367' TO 4834' WITH 90-100 RPM 475 GALS PER MIN, 2650 PSI, 20-25K BIT WT. 08:30 - 10:00 1.50 DRILL P INT1 CIRC TWO BOTTOMS UP WITH 475 GALS MIN, 2700 PSI, 100 RPMS 10:00 - 13:30 3.50 DRILL P INT1 PUMP OUT TO HWP, WITH FULL DRILLING RATE 13:30 - 14:30 1.00 DRILL P INT1 TRIPPING OUT WITH BHA 14:30 - 16:00 1.50 DRILL P INT1 TRIP IN WITH BHA# 2, BIT SECURTY XL 1CN WITH 3-15 1-10 JETS, 7" SPERRY DRILL LOBE 1.5 BEND, STAB, FLOAT SUB, 6 3/4 GRIRES, 6 314 OM, HANG OFF SUB., UBHO SUB, STAB, 2 FLEX COLLAR, STAB, FLEX COLLAR, 12 HWDP, JAR, 5 HWDP 16:00 - 18:00 2.00 DRILL P INT1 TRIP IN, WASH 90 FT TO BOTTOM 18:00 - 00:00 6.00 DRILL P INT1 DRILLING FROM 4834 TO 5208'TD WITH 90-100 RPM 475 GALS PER MIN, 3050 PSI, 20-25K BIT WT. TOP OF O-A SAND 4780 TOP OF O-B SAND 5,020' AST 2.5 ART 2 9/20/2002 00:00 - 01 :00 1.00 CASE P INT1 CIRC FOR 1.5 BOTTOMS UP WITH 475 GALS, 3000 PSI, 100 RPMS 01 :00 - 01 :30 0.50 CASE P INT1 SHORT TRIP UP TO 4700 PUMPED OUT, TRIP BACK TO BOTTOM. NO PROBLEMS 01 :30 - 04:30 3.00 CASE P INT1 CIRC 4 BOTTOMS UP WITH 475 GALS MIN 3000 PSI,1 00 RPMS STANDING BACK ONE STAND PER BOTTOMS UP 04:30 - 08:00 3.50 CASE P INT1 TRIPPING OUT, PUMPING WITH FULL DRILLING RATE 08:00 - 09:00 1.00 CASE P INT1 LAID DOWN HWDP AND JARS 09:00 - 11 :30 2.50 CASE P INT1 LAID DOWN NMDC'S AND STABILIZERS. FLUSH MOTOR AND MWD. DOWNLOAD MWD. LAID DOWN MWD, MOTOR AND BIT. 11 :30 - 12:30 1.00 CASE P INT1 CLEARED FLOOR. RIGGED UP CASING FILL UP TOOL AND CASING TONGS AND SCAFFOLDING. 12:30 - 13:00 0.50 CASE P INT1 HELD PJSM ON RUNNING CASING 13:00 - 17:30 4.50 CASE P INT1 PICKING UP CSG. 75/829# L-80 BTC TOTAL OF 124 Printed: 9/30/2002 9: 15:23 AM ) ) BP EXPLORATION Operations Summary Report Page 30f6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-17 MPS-17 DRILL +COMPLETE DOYON DOYON 141 Start: 9/16/2002 Rig Release: 9/29/2002 Rig Number: 141 Spud Date: 9/16/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/20/2002 13:00 - 17:30 4.50 CASE P INT1 JOINTS P/U WT. 165K S/O WT 115K SHOE @ 5189.97 FLOAT 5106 17:30 - 18:00 0.50 CASE P INT1 RIG DOWN FRANKS TOOL, RIG UP CEMENTING HEAD 18:00 - 21 :00 3.00 CASE P INT1 CIRC WITH 5.5 BBLS MIN 350 PSI AND THIN MUD FOR CEMENT JOB, PJSM 21 :00 - 23:30 2.50 CASE P INT1 TEST LINE TO 3,500, CEMENT WITH 20 BBLS WATER AHEAD, 50 BBLS OF ALPHA SPACER 10.2, MIXED AND PUMPED 920 SX 670 BBLS CLASS L MIXED @ 10.7, TAIL WITH 335 SX 69 BBLS CLASS G MIXED @ 15.8 23:30 - 00:00 0.50 CASE P INT1 DISPLACED WITH RIG PUMPS @ 5.5 BBLS MIN, BUMP PLUG WITH 2,000#, FLOATS HELD, FULL RETURNS TRU OUT JOB. 365 BBLS OF GOOD CEMENT TO SURFACE, CEMENT IN PLACE @ 00:15 9/21/2002 9/21/2002 00:00 - 00:30 0.50 CASE P INT1 DISPLACED WITH RIG PUMPS @ 5.5 BBLS MIN, BUMP PLUG WITH 2,000#, FLOATS HELD, FULL RETURNS TRU OUT JOB. 400 BBLS OF GOOD CEMENT TO SURFACE, CEMENT IN PLACE @ 00:15 9/21/2002 00:30 - 02:00 1.50 CASE P INT1 LAY DOWN CEMENT HEAD AND LANDING JT. FLUSH OUT DIVERTER AND LINES 02:00 - 04:00 2.00 CASE P INT1 NIPPLE DOWN DIVERTER 04:00 - 05:00 1.00 CASE P INT1 INSTALL HEAD AND TEST TO 1000 PSI FOR 10 MINUTES 05:00 - 08:00 3.00 CASE P INT1 NIPPLE UP BOPS 08:00 - 13:30 5.50 BOPSUR P INT1 TEST BOPS, 250/4000 FOR 5 MIN. PER TEST, TEST ANNULAR 250/3000 PSI, WITNESS OF TEST WAS WAIVED BY JOHN SPAULDING AOGCC 13:30 - 16:30 3.00 CASE P INT1 PICK UP BHA #3 6.125 SEC. FM2643 WITH 3/12 JETS, 4 3/4 SPERRYDRILL LOBE WITH 1.5 BEND, FLOAT SUB, 4 3/4 GAM/RES, 43/4 OM, 4 3/4 TM, 3 FLEX COLLARS, JAR, X OVER 16:30 - 18:00 1.50 CASE P INT1 TRIP IN TO 5060 18:00 - 19:30 1.50 CASE P INT1 CIRC. AND TEST CSG TO 4,000 PSI FOR 30 MIN. 19:30 - 21 :00 1.50 CASE P INT1 DRILL CEMENT FLOAT AND SHOE, DRLG 30 FT NEW HOLE TO 5238 21 :00 - 22:00 1.00 CASE P INT1 CIRC BOTTOMS UP FOR FIT TEST 22:00 - 22:30 0.50 CASE P INT1 FIT TEST WITH 9.0 MUD WT AND 500 PSI, TVD 4280= 11.2 EMW 22:30 - 23:00 0.50 CASE P INT1 CIRC AND DISPLACE HOLE WITH 9.1 FLOW-PRO MUD 23:00 - 00:00 1.00 DRILL P PROD1 DRILLING 5238' TO 5300' WITH 2-10K BIT WT, 60 RPMS, 250 GALS MIN., 1400 PSI, AST .5, ART.1 9/22/2002 00:00 - 00:00 24.00 DRILL P PROD1 DRILLING 5300' TO 7700' WITH 2-10K BIT WT, 70-90 RPMS, 250 GALS MIN., 1480 PSI, ART 12.4 AST 3 ..: 9/23/2002 00:00 - 07:30 7.50 DRILL P PROD1 DRILLING 7700' TO 8390' WITH 2-10K BIT WT, 70-90 RPMS, 250 GALS MIN., 1600 PSI AST 1.5 ART 3.25 07:30 - 10:30 3.00 CASE P COMP CIRC. FOUR BOTTOMS UP WITH 275 GALS MIN 1750 PSI, 100 RPMS 10:30 - 13:30 3.00 CASE P COMP PUMPING OUT TO 5,189 CSG SHOE, DISPLACING HOLE WITH NEW MUD 13:30 - 15:30 2.00 CASE P COMP FLOW CHECK, SLUG PIPE, TRIP OUT 15:30 - 16:00 0.50 CASE P COMP SAFETY MEETING WITH MIKE MILLER 16:00 - 17:00 1.00 CASE P COMP LAY DOWN BHA Printed: 9/30/2002 9:15:23 AM ) ') BP EXPLORATION Operations Summary Report Page 4 of6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-17 MPS-17 DRILL +COMPLETE DOYON DOYON 141 Start: 9/16/2002 Rig Release: 9/29/2002 Rig Number: 141 Spud Date: 9/16/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/23/2002 17:00 - 18:00 1.00 CASE P COMP PICKING UP 78 JTS OF SLOTTED LINER AND 2 BLANKS TOTAL 80 JTS, 3292' 4.512.6# L-80 LINER 18:00 - 22:00 4.00 CASE P COMP PICK UP BAKER HMC LINER HANGER,BAKER ZXP PACKER, TIE BACK SLEEVE, TRIP TO BOTTOM 22:00 - 23:00 1.00 CASE P COMP DROP BALL SET BAKER HANGER AND PACKER AND RELEASE FROM LINER ( SHOE AT 8387.00, TOP OF TIE BACK SLEEVE 5069.74) 23:00 - 00:00 1.00 CASE P COMP PUMP SLUG, CUT DRILLING LINE 9/24/2002 00:00 - 02:00 2.00 CASE P COMP TRIP OUT WITH LINER RUNNING TOOL, LAY DOWN SAME 02:00 - 05:00 3.00 STWHIP P PROD2 PICK UP, SPACE OUT JTS, WHIPSTOCK AND BHA 05:00 - 07:00 2.00 STWHIP P PROD2 TRIP IN WITH WHIPSTOCK 07:00 - 07:30 0.50 STWHIP P PROD2 ORIENT AND SET WHIPSTOCK 6 DREGEE TO LEFT 07:30 - 11 :30 4.00 STWHIP P PROD2 MILL WINDOW TOP OF WINDOW 4780 BOTTOM 4792 TOP OF O-A 4780 11 :30 - 12:30 1.00 STWHIP P PROD2 CIRC, PUMP SWEEPS, WORK WINDOW 12:30 - 14:00 1.50 STWHIP P PROD2 TRIP OUT TO BHA 14:00 - 15:00 1.00 STWHIP P PROD2 LAYING DOWN BHA 15:00 - 15:30 0.50 STWHIP P PROD2 PICK UP JOHNNY WACKER AND FLUSH OUT BOPS 15:30 - 17:30 2.00 STWHIP P PROD2 PICKING UP BHA #5 SEC FM2643 WITH 3/12 JETS, 4 3/4 MOTOR 1.5 BEND, FLOAT SUB,4 3/4 GAM/RES, 4 3/4 OM, 4 3/4 TM, 3 FLEX COLLARS, JARS, XOVER 17:30 - 19:00 1.50 STWHIP P PROD2 TRIP IN TO 4693 19:00 - 19:30 0.50 STWHIP P PROD2 ORIENT TO HIGH SIDE AND WENT THRU WINDOW ( NO PROBLEMS) 19:30 - 00:00 4.50 DRILL P PROD2 DRILLING 4805' TO 5300' WITH 250 GALS MIN, 1450 PSI, 100 RPMS 5-8K ON BIT, AST .75 ART 1.75 TQ 3,000 9/25/2002 00:00 - 00:00 24.00 DRILL P PROD2 DRILLING 5300' to 7960' WITH 250 GALS MIN, 1800 PSI, 100 RPMS 5-8K ON BIT, TQ 5,000 AST 3.5 ART 11.5 9/26/2002 00:00 - 02:30 2.50 DRILL P PROD2 DRILLING 7960' TO TO @ 8280' WITH 250 GALS MIN, 1800 PSI, 100 RPMS 5-8K ON BIT, TQ 5,000 AST .25 ART 1.5 WENT OUT TOP OF O-A @ 8220 02:30 - 05:30 3.00 CASE P COMP CIRC BOTTOMS UP WITH 280 GALS MIN, 2050 PSI, 100 RPMS 05:30 - 09:00 3.50 CASE P COMP PUMPING OUT TO ONE STAND BELOW WINDOW, WITH FULL DRILLING RATE, PULL THRU WINDOW, NO PUMP 09:00 - 09:30 0.50 CASE P COMP MONITOR WELL, SLUG PIPE 09:30 - 11 :30 2.00 CASE P COMP TRIP OUT OF HOLE 11 :30 - 13:00 1.50 CASE P COMP PICK UP WHIPSTOCK RETRIEVING TOOL AND BHA 13:00 - 14:00 1.00 CASE P COMP HOOK WHIPSTOCK, PULLED FREE WITH 50,000# OVERPULL 14:00 - 20:00 6.00 CASE P COMP TRIP OUT WITH WHIPSTOCK, LAY DOWN HWDP AND SPACE OUT JTS 20:00 - 23:30 3.50 CASE P COMP PJSM, PICKING UP 83 JTS 4.5 SLOTTED LINER 12.6# L-80 TOTAL 3423 FT. AND BAKER HOOK WALL HANGER AND TIE BACK SLEEVE 23:30 - 00:00 0.50 CASE P COMP TRIP IN TO TOP OF O-B LINER @ 5070 9/27/2002 00:00 - 04:30 4.50 CASE P COMP ATTEMPT TO GET LINER OUT WINDOW @ 4780 TO 4792, MADE 15 ATTEMPTS 04:30 - 05:30 1.00 CASE N COMP TRIPPING OUT TO REMOVE BAKER TENSION LOCK SWIVEL OFF LINER 05:30 - 06:00 0.50 CASE N COMP REMOVE BAKER SWIVEL FROM LINER 06:00 - 06:30 0.50 CASE N COMP TRIP IN TO WINDOW @ 4780 06:30 - 10:00 3.50 CASE N COMP 12 ATTEMPTS TO EXIT WINDOW WITH LINER, TRYED Printed: 9/30/2002 9:15:23 AM ) ) BP EXPLORATION Page 5 of6 Operations Summary Report Legal Well Name: MPS-17 Common Well Name: MPS-17 Spud Date: 9/16/2002 Event Name: DRILL +COMPLETE Start: 9/16/2002 End: Contractor Name: DOYON Rig Release: 9/29/2002 Rig Name: DOYON 141 Rig Number: 141 Date From - To Hours Task Code NPT Phase Description of Operations 9/27/2002 06:30 - 10:00 3.50 CASE N COMP EVERTHING KNOWN TO EXIT WINDOW 10:00 - 11 :00 1.00 CASE N COMP TRIP OUT TO TOP OF LINER 11 :00 - 15:00 4.00 CASE N COMP PJSM, LAY DOWN 4.5 SLOTTED LINER, LAYED DOWN 3 DEGREE BEND JT. THAT WAS BENT AT 16 FT. BENT TO 10 IN. 15:00 - 15:30 0.50 CASE N COMP SERVICE RIG 15:30 - 18:00 2.50 CASE N COMP PJSM, PICKING UP NEW 4 DEGREE BEND JT. BENT AT 14 FT BENT TO 12 IN. AND 82 JTS 4.5 12.6 # L-80 SLOTTED LINER, TOTAL 3423 FT, AND BAKER HOOKWALL HANGER, NO SWIVEL 18:00 - 20:30 2.50 CASE P COMP TRIP IN WITH LINER, TO 8224, WENT THRU WINDOW, NO PROBLEM, PICK UP WT OF LINER 95,000, SLACK OFF WT 75,000, LINER SHOE @ 8224, TOP OF LINER 4,757 20:30 - 21 :30 1.00 CASE P COMP HOOKED LINER HANGER, DROP BALL PRESSURE UP TO 2500#,RELEASE FROM LlNER,SHEARED BALL WITH 3400 PSI 21 :30 - 00:00 2.50 CASE P COMP PUMPED SLUG, TRIPPING OUT WITH RUNNING TOOL, LAY DOWN EXCESS DRLG PIPE. 9/28/2002 00:00 - 01 :00 1.00 CASE P COMP TRIPPING OUT WITH RUNNING TOOL, LAY DOWN EXCESS DRLG PIPE. 01 :00 - 01 :30 0.50 CASE P COMP LAYING DOWN BAKER RUNNING TOOLS 01 :30 - 03:30 2.00 CASE P COMP PICK UP MULE SHOE, TRIPPING IN TO 4738 03:30 - 05:30 2.00 CASE P COMP CIRC AND DISPLACE HOLE WITH 8.8 SEA WATER, HIGH VIS SPACER, 8.8 SEAWATER, FOLLOW BY 9.2 COMPLETION FLUID WITH ONE DRUM OF CORROSION INHIBITOR 05:30 - 09:00 3.50 CASE P COMP LAYING DOWN DRILL PIPE 09:00 - 09:30 0.50 CASE P COMP PULL WEAR RING 09:30 - 10:30 1.00 CASE P COMP PJSM, RIG UP TO RUN TUBING 10:30 - 14:30 4.00 CASE P COMP PICKING UP TAIL PIPE,PACKER,PHOENIX JET PUMP SENSOR,SLlDING SLEEVE, PHOENIX DISCHARGE PRESSURE GAUGE, RIG UP I-WIRE, PICK UP 25 JTS 4.5 TUBING, I WIRE READING BAD 14:30 - 16:30 2.00 CASE N COMP PJSM, LAY DOWN 25 JTS 4.5 TUBING 16:30 - 18:00 1.50 CASE N COMP TROUBLE SHOOT JET PUMP SENSOR AND I-WIRE SPOOL 18:00 - 20:00 2.00 CASE N COMP LAYING DOWN, PUMPS SENSOR, SLIDING SLEEVE, PRESSURE GAUGE 20:00 - 00:00 4.00 CASE N COMP PICKING UP NEW,PHOENIX JET PUMP SENSOR,SLlDING SLEEVE, PHOENIX DISCHARGE PRESSURE GAUGE, RIG UP I-WIRE AND TESTING 9/29/2002 00:00 - 04:30 4.50 CASE P COMP PICKING UP 4.5 TUBING, TOTAL 113 JTS, 4489 FT 12.6# L-80 IBT, WIRE LINE SHOE @ 4665, XN NIPPLE, @ 4660, S-3 BAKER PACKER @ 4616, PHOENIX PUMP SENSOR@ 4588,SLlDING SLIDING SLEEVE @ 4566,PHOENIX DISCHARGE GAUGE @ 4552, KGB-2 GLM @ 1992, PICKUP WT 77,000, S/O WT 74,000 04:30 - 05:00 0.50 CASE P COMP PICK UP FMC GEN-6 TUBING HANGER, HOOKING UP I-WIRE AND TEST 05:00 - 05:30 0.50 CASE P COMP LAND TUBING, WITH TWO WAY CHECK IN PLACE 05:30 - 06:00 0.50 CASE P COMP TEST 2 WAY CHECK TO 1000 PSI 06:00 - 07:00 1.00 RIGD P COMP NIPPLE DOWN BOPS 07:00 - 08:00 1.00 RIGD P COMP NIPPLE UP FMC 11 BY 41/165,000 ADAPTOR FLANGE AND CIW 41/165,000 # TREE Printed: 9/30/2002 9: 15:23 AM ) ') BP EXPLORATION Operations Summary Report Page 6 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-17 MPS-17 DRILL +COMPLETE DOYON DOYON 141 Start: 9/16/2002 Rig Release: 9/29/2002 Rig Number: 141 Spud Date: 9/16/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/29/2002 08:00 - 09:00 1.00 RIGD P COMP TEST ADAPTOR FLANGE TO 5,000 PSI, TEST I-WIRE, TEST TREE TO 5,000PSI HELD TESTS FOR 10 MIN. 09:00 - 10:00 1.00 RIGD P COMP DROP BALL, PRESSURE UP ON TUBING TO 4,000 PSI, SET PACKER, HELD TEST FOR 30 MIN. 10:00 - 11 :00 1.00 RIGD P COMP BLEED TUBING TO 2,500 PSI, PRESSURE UP ON ANNLUS TO 4,500 PSI HELD TEST FOR 30 MIN., BLEED PRESS ON TUBING TO SHEAR RP VALVE 11 :00 - 13:00 2.00 RIGD P COMP PUMP 83 BBLS OF DIESEL DOWN ANNLUS AND LET U-TUBE TO TUBING. 13:00 - 14:00 1.00 RIGD P COMP R/U LUBRICATOR SET BPV .. RELEASE RIG FOR RIG MOVE @ 1400 HRS 9/29/2002 Printed: 9/30/2002 9: 15:23 AM Legal Name: MPS-17 Common Name: MPS-17 Test Date 9/21/2002 Test Type FIT Test Depth (TMD) 5,239.0 (ft) BP EXPLORATION Leak-Off Test Summary Test Depth (TVD) 4,289.0 (ft) AMW 9.00 (ppg) Surface Pressure 500 (psi) Leak Off Pressure (BHP) 2,505 (psi) Page 1 of 1 EMW 11.24 (ppg) .~ '-' Printed: 9/30/2002 9:15:09 AM Well: Field: API: Permit: ') ) MPS-17 & MPS-17L 1 Milne Point Unit / Schrader Bluff 50-029-23115-00 & 50-029-23115-60 202-173 & 202-174 Rig Accept: 09-16-02 Rig Spud: 09-16-02 Rig Release: 09-29-02 Drilling Rig: Doyon 141 POST RIG WORK 10-05-02 Pulled BPV, Pulled RP, Set DGLV, Pulled RHC, attempted opening SSD. 10-06-02 Due to doglegs around SSD, Tool string combination for opening SSD needs to be as noted. Knuckle joint every 10' is imperative. Opened SSD, Set Jet Pump (13B ratio). 10-12-02 HB&R rigged up and pumped 40 Bbls diesel down inner annulus to freeze protect it. Pumped form 2 BPM from 450 to 1350 psi. 10-25-02 PJSM Rigged up triplex pump to power fluid line and tested to 5000 psi for 10 minutes, good test. Tested production line to1150 psi for 10 minutes good test. Thawed the power fluid line with Neet MeOH and thawed the production line with heater and heat sock. Well was put on production. \) AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPS-17 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , M D (if applicable) 8,390.00' MD ) aoa- J73 10-0ct-02 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVE~) OCT 1 5 2002 Ala8k~ 0;1 & t;a$ Com:. 0Qmlr~!$iOn AnchOOìn~ Sperry-Sun Drilling Services Milne Point Unit BPXA Milne. Point MPS MPS.17 Job Ho. AKZZ22158, Surveyed: 23 September, 2002 Survey Report 7 October, 2002 Your Ref: API 500292311500 Surface Coordinates: 5999982.58 H, 565845.04 E (700 24' 37.4172" H, 1490 27' 49.8246" W) Grid Coordinate System: HAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 999982.58 H, 65845.04 E (Grid) Surface Coordinates relative to Structure: 11.99N, 499.87 W(True) Kelly Bushing: 65.90ff above Mean Sea Level Elevation relative to Project V Reference: 65.90ft Elevation relative to Structure: 65.90ff !Spe......y-.u., OR ILL. fNG SfEAVn: E S A Halliburton Company ):F N - VE Survey Ref: 5vy10187 Sperry-Sun Drilling Services Survey Report for Milne Point IfPS -MPS..17 Your Ref: API 500292311500 Job No. AKZZ22158, Surveyed: 23 September, 2002 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -65.90 0.00 O.OON O.OOE 5999982.58 N 565845.04 E 0.00 Tolerable Gyro 135.00 0.750 210.000 69.10 135.00 0.77 S 0.44 W 5999981.81 N 565844.60 E 0.556 0.01 225.00 0.600 254.000 159.09 224.99 1.418 1.19W 5999981.16 N 565843.86 E 0.583 0.36 AK-6 BP_JFR-AK 293.97 0.220 63.760 228.06 293.96 1.45 8 1.42W 5999981.12 N 565843.64 E 1.185 0.54 384.18 0.720 74.420 318.27 384.17 1.228 0.72W 5999981.36 N 565844.33 E 0.560 0.03 476.04 0.830 85.610 410.12 476.02 1.01 8 0.50E 5999981.57 N 565845.55 E 0.203 -0.93 ~ 566.66 1.070 93.790 500.73 566.63 1.028 2.00E 5999981.58 N 565847.05 E 0.304 -2.24 657.71 1.230 99.320 591.76 657.66 1.238 3.81 E 5999981.38 N 565848.87 E 0.214 -3.93 753.54 0.740 94.250 687.57 753.47 1.44 8 5.45E 5999981.18 N 565850.50 E 0.519 -5.46 845.16 0.680 292.660 779.19 845.09 1.288 5.53E 5999981.35 N 565850.59 E 1.530 -5.46 939.68 1.080 290.920 873.70 939.60 0.748 4.19 E 5999981.87 N 565849.23 E 0.424 -4.02 1033.96 0.250 67.280 967.97 1033.87 0.358 3.54E 5999982.26 N 565848.59 E 1.350 -3.27 1127.85 0.620 79.680 1061.86 1127.76 0.188 4.23E 5999982.44 N 565849.27 E 0.404 -3.79 1220.20 O.AOO 94.51 0 1154.20 1220.10 0.148 5.37 E 5999982.49 N 565850.41 E 0.277 -4.76 1314.44 0.920 238.410 1248.44 1314.34 0.598 5.38E 5999982.04 N 565850.42 E 1.736 -4.99 1409.60 1.310 250.280 1343.58 1409.48 1.358 3.70E 5999981.26 N 565848.76 E 0.474 -3.90 1501.06 0.310 200.620 1435.03 1500.93 1.948 2.63E 5999980.67 N 565847.69 E 1.240 -3.24 1594.83 0.570 114.050 1528.80 1594.70 2.378 2.97E 5999980.24 N 565848.03 E 0.674 -3.75 1688.45 0.870 119.830 1622.41 1688.31 2.918 4.01 E 5999979.71 N 565849.08 E 0.329 -4.92 1782.34 0.580 262.920 1716.30 1782.20 3.328 4.16E 5999979.29 N 565849.23 E 1.468 -5.25 1876.64 0.990 269.020 1810.59 1876.49 3.40 8 2.87E 5999979.21 N 565847.94 E 0.443 -4.16 1967.51 1.090 264.010 1901.45 1967.35 3.508 1.23 E 5999979.09 N 565846.30 E 0.149 -2.77 2061.49 1.000 0.870 1995.42 2061.32 2.778 0.35E 5999979.81 N 565845.41 E 1.665 -1.65 2155.31 1.520 14.940 2089.21 2155.11 0.758 0.68E 5999981.84 N 565845.73 E 0.641 -0.96 '- 2247.90 0.190 354.910 2181.79 2247.69 0.59N 0.99E 5999983.18 N 565846.02 E 1.451 -0.57 2341.95 0.370 255.530 2275.84 2341.74 0.67N 0.68E 5999983.25 N 565845.71 E 0.471 -0.27 2435.80 0.560 256.650 2369.69 2435.59 0.49 N 0.06W 5999983.07 N 565844.97 E 0.203 0.29 2529.37 1.810 323.050 2463.24 2529.14 1.56 N 1.40 W 5999984.13 N 565843.63 E 1.781 1.98 2622.20 4.300 322.000 2555.93 2621.83 5.48 N 4.42 W 5999988.02 N 565840.57 E 2.683 6.53 ~~715.32 6.610 320.600 2648.62 2714.52 12.37 N 9.97W 5999994.86 N 565834.96 E 2.485 14,73 2809.53 8.670 324.500 2741.99 2807.89 22.34 N 17.54 W 6000004.77 N 565827.31 E 2.254 26.19 2903.05 12.510 323.760 2833.90 2899.80 36.25 N 27.62 W 6000018.59 N 565817.10 E 4.109 41.77 2996.45 16.190 331.940 2924.38 2990.28 55.91 N 39.73 W 6000038.14 N 565804.82 E 4.489 61.91 3088.89 19.540 331.070 3012.35 3078.25 80.82 N 53.28 W 6000062.93 N 565791.05 E 3.635 85.86 ~~ 183.45 24.820 325.220 3099.89 3165.79 110.99 N 72.26 W 6000092.93 N 565771.80 E 6.046 117.12 7 October, 2002 - 14:52 Page 20f6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPS . MPS-17 Your Ref: AP/500292311600 Job No. AKZZ22158, Surveyed: 23 September, 2002 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings. Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3276.99 28.640 322.450 3183.42 3249.32 144.90 N 97.13 W 6000126.62 N 565746.63 E 4.295 155.34 3370.59 30.800 322.640 3264.71 3330.61 181.74 N 125.35 W 6000163.20 N 565718.09 E 2.310 197.91 3463.32 33.560 322.790 3343.18 3409.08 221.03 N 155.26 W 6000202.23 N 565687.83 E 2.978 243.16 3556.77 35.330 321.800 3420.25 3486.15 262.84 N 187.60 W 6000243.75 N 565655.13 E 1.987 291.74 3650.28 35.920 321.960 3496.26 3562.16 305.69 N 221.22 W 6000286.30 N 565621.13 E 0.639 341.96 3742.50 36.610 320.340 3570.61 3636.51 348.16 N 255.44 W 6000328.48 N 565586.54 E 1.280 392.52 .~ 3838.11 39.030 319.830 3646.13 3712.03 393.12 N 293.06 W 6000373.10 N 565548.53 E 2.552 447.26 3931.27 39.310 319.820 3718.36 3784.26 438.08 N 331.02 W 6000417.73 N 565510.17 E 0.301 502.29 4025.14 40.750 319.400 3790.23 3856.13 484.06 N 370.14 W 6000463.36 N 565470.64 E 1.561 558.84 4118.54 43.760 321.190 3859.36 3925.26 532.39 N 410.24 W 6000511.33 N 565430.13 E 3.471 617.37 4212.14 48.540 319.580 3924.19 3990.09 584.35 N 453.29 W 6000562.91 N 565386.62 E 5.255 680.26 4305.22 54.130 320.610 3982.32 4048.22 640.09 N 499.87 W 6000618.24 N 565339.54 E 6.067 748.08 4397.89 60.960 319.680 4032.02 4097.92 700.07 N 549.97 W 6000677.77 N 565288.91 E 7.419 821.02 4491.36 68.040 319.010 4072.23 4138.13 764.02 N 604.91 W 6000741.24 N 565233.41 E 7.602 900.13 4585.28 70.820 319.500 4105.23 4171.13 830.63 N 662.30 W 6000807.34 N 565175.44 E 3.000 982.66 4678.70 71.130 316.820 4135.69 4201.59 896.42 N 721.21 W 6000872.61 N 565115.96 E 2.732 1066.13 4771.84 74.690 315.230 4163.06 4228.96 960.47 N 783.02 W 6000936.11 N 565053.59 E 4.156 1151.29 4865.58 80.360 316.960 4183.30 4249.20 1026.39 N 846.45 W 6001001.47 N 564989.58 E 6.311 1238.78 4959.56 79.790 315.880 4199.50 4265.40 1093.46 N 910.26 W 6001067.97 N 564925.17 E 1.284 1327.15 5052.47 81.910 316.240 4214.27 4280.17 1159.50 N 973.91 W 6001133.45 N 564860.95 E 2.314 1414.88 5145.55 87.230 316.580 4223.08 4288.98 1226.59 N 1037.78 W 6001199.98 N 564796.49 E 5.727 1503.32 5233.19 90.680 315.470 4224.67 4290.57 1289.64 N 1098.61 W 6001262.49 N 564735.11 E 4.135 1587.13 5277.55 93.690 314.980 4222.98 4288.88 1321.11 N 1129.83 W 6001293.67 N 564703.61 E 6.875 1629.71 5325.30 96.670 309.580 4218.67 4284.57 1353.09 N 1164.99 W 6001325.34 N 564668.17 E 12.875 1675.99 ~. 5370.32 96.230 308.110 4213.61 4279.51 1381.14 N 1199.83 W 6001353.09 N 564633.08 E 3.389 1720.08 5.419.97 97.290 302.570 4207.76 4273.66 1409.65 N 1240.03 W 6001381.25 N 564592.63 E 11.284 1769.07 5.464.22 95.490 300.210 4202.84 4268.74 1432.55 N 1277.57 W 6001403.82 N 564554.89 E 6.681 1813.00 5513.68 96.790 296.520 4197.55 4263.45 1455.91 N 1320.83 W 6001426.79 N 564511.43 E 7.870 1862.17 5557.60 96.600 295.650 4192.42 4258.32 1475.09 N 1360.01 W 6001445.63 N 564472.08 E 2.014 1905.73 5608.11 96.530 290.840 4186.65 4252.55 1494.89 N 1406.10 W 6001465.02 N 564425.82 E 9.461 1955.63 5;650.34 96.170 285.400 4181.97 4247.87 1507.94 N 1445.97 W 6001477.71 N 564385.83 E 12.831 1996.81 5;701.25 92.520 283.010 4178.12 4244.02 15?0.39 N 1495.17 W 6001489.73 N 564336.52 E 8.562 2045.86 5744.54 91.780 282.030 4176.49 4242.39 1529.77 N 1537.40 W 6001498.74 N 564294.21 E 2.835 2087.32 5793.29 91.420 280.860 4175.13 4241.03 1589.44 N 1585.16 W 6001507.98 N 564246.37 E 2.510 2133.76 5837.58 93.020 280.760 4173.41 4239.31 1547.74 N 1628.63 W 6001515.90 N 564202.82 E 3.620 2175.77 -_.._--- 7 October, 2002 - 14:52 Page 30f6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-17 Your Ref: API 500292311500 Job No. AKZZ22158, Surveyed: 23 September, 2002 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5886.54 93.080 280.510 4170.81 4236.71 1556.76 N 1676.68 W 6001524.50 N 564154.70 E 0.524 2222.15 5930.91 93.020 280.220 4168.45 4234.35 1564.73 N 1720.27 W 6001532.09 N 564111.04 E 0.667 2264.11 5980.56 93.200 279.700 4165.75 4231.65 1573.31 N 1769.10 W 6001540.23 N 564062.14 E 1.107 2310.94 6025.40 94.060 280.950 4162.92 4228.82 1581.33 N 1813.12 W 6001547.86 N 564018.05 E 3.379 2353.31 6073.58 93.330 285.020 4159.81 4225.71 1592.13 N 1859.96 W 6001558.25 N 563971.11 E 8.565 2399.49 6118.66 94.310 286.170 4156.81 4222.71 1604.22 N 1903.29 W 6001569.96 N 563927.69 E 3.347 2443.23 -- 6165.59 94.440 286.050 4153.23 4219.13 1617.21 N 1948.24 W 6001582.55 N 563882.62 E 0.376 2488.82 6211.78 94.500 286.560 4149.63 4215.53 1630.13 N 1992.44 W 6001595.08 N 563838.31 E 1.108 2533.73 6260.78 94.680 286.590 4145.71 4211.61 1644.07 N 2039.25 W 6001608.60 N 563791.37 E 0.372 2581.41 6305.42 93.200 287.080 4142.64 4208.54 1656.96 N 2081.88 W 6001621.13 N 563748.64 E 3.492 2624.93 6354.19 90.490 286.520 4141.07 4206.97 1671.05 N 2128.54 W 6001634.80 N 563701.86 E 5.674 2672.55 6398.67 90.800 286.610 4140.57 4206.47 1683.73 N 2171.17 W 6001647.11 N 563659.11 E 0.726 2715.96 6448.31 93.020 287.360 4138.91 4204.81 1698.22 N 2218.61 W 6001661.18 N 563611.54 E 4.720 2764.47 6492.22 93.450 287.260 4136.43 4202.33 1711.27 N 2260.47 W 6001673.85 N 563569.57 E 1.005 2807.38 6556.84 93.080 288.630 4132.75 4198.65 1731.15N 2321.84 W 6001693.19 N 563508.03 E 2.193 2870.68 6585.08 92.160 288.940 4131.46 4197.36 1740.23 N 2348.55 W 6001702.04 N 563481.24 E 3.437 2898.43 6634.74 91.720 288.340 4129.78 4195.68 1756.09 N 2395.58 W 6001717.48 N 563434.07 E 1 .498 2947.24 6678.96 91.780 287.920 4128.43 4194.33 1769.85 N 2437.58 W 6001730.87 N 563391.95 E 0.959 2990.63 6726.96 92.090 288.180 4126.81 4192.71 1784.71 N 2483.19 W 6001745.33 N 563346.21 E 0.843 3037.71 6773.06 92.090 288.010 4125.13 4191.03 1799.02 N 2526.98 W 6001759.25 N 563302.29 E 0.369 3082.94 6820.61 92.220 288.190 4123.34 4189.24 1813.78 N 2572.15 W 6001773.61 N 563257.00 E 0.467 3129.58 6865.43 92.280 287.950 4121.58 4187.48 1827.67 N 2614.73 W 6001787.13 N 563214.30 E 0.552 3173.54 6913.79 92.210 287.820 4119.69 4185.59 1842.51 N 2660.71 W 6001801.56 N 563168.19 E 0.305 3220.94 6959.17 92.220 287.570 4117.93 4183.83 1856.30 N 2703.91 W 6001814.97 N 563124.87 E 0.551 3265.39 '- 7010.06 92.090 287.310 4116.02 4181.92 1871.54 N 2752.43 W 6001829.78 N 563076.22 E 0.571 3315.19 7052.88 91.790 287.400 4114.57 4180.47 1884.30 N 2793.28 W 6001842.18 N 563035.26 E 0.731 3357.09 7101.66 92.090 287.330 4112.92 4178.82 1898.85 N 2839.81 W 6001856.32 N 562988.60 E 0.632 3404.82 7146.34 92.460 287.320 4111.15 4177.05 1912.15 N 2882.43 W 6001869.24 N 562945.87 E 0.828 3448.53 7198.58 90.860 286.990 4109.63 4175.53 1927.55 N 2932.32 W 6001884.20 N 562895.84 E 3.127 3499.62 7239.75 91.480 287.950 4108.79 4174.69 1939.91 N 2971.58 W 6001896.21 N 562856.47 E 2.775 3539.93 7282.10 89.750 287.270 4108.34 4174.24 1952.72 N 3011.94 W 6001908.67 N 562816.00 E 4.389 3581.43 7333.30 89.690 286.820 4108.59 4174.49 1967.72 N 3060.89 W 6001923.24 N 562766.92 E 0.887 3631.50 7381.76 90.680 286.330 4108.43 4174.33 1981.55 N 3107.34 W 6001936.66 N 562720.35 E 2.279 3678.80 7421.90 90.060 285.000 4108.17 4174.07 1992.39 N 3145.99 W 6001947.15 N 562681.61 E 3.656 3717.84 7476.35 89.750 286.390 4108.26 4174.16 2007.12 N 3198.40 W 6001961.42 N 562629.06 E 2.616 3770.81 _._._.-._-------~-- 7 October, 2002 - 14:52 Page 4 of6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-17 Your Ref: API 600292311600 Job No. AKZZ22158, Surveyed: 23 September, 2002 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°11 OOft) 7520.01 89.570 285.630 4108.52 4174.42 2019.16 N 3240.37 W 6001973.09 N 562586.99 E 1.789 3813.33 7569.82 91.290 285.250 4108.15 4174.05 2032.42 N 3288.38 W 6001985.93 N 562538.87 E 3.536 3861.73 7612.79 91.720 285.510 4107.02 4172.92 2043.81 N 3329.80 W 6001996.95 N 562497.36 E 1.169 3903.46 7662.64 91.290 285.260 4105.71 4171.61 2057.03 N 3377.84 W 6002009.75 N 562449.19 E 0.998 3951.87 7703.58 91.420 285.720 4104.74 4170.64 2067.96 N 3417.28 W 6002020.33 N 562409.66 E 1.167 3991.65 7757.92 91.850 285.750 4103.19 4169.09 2082.69 N 3469.57 W 6002034.60 N 562357.25 E 0.793 4044.50 '- 7798.49 92.400 285.760 4101.69 4167.59 2093.70 N 3508.59 W 6002045.27 N 562318.13 E 1.356 4083.94 7850.46 92.590 284.860 4099.42 4165.32 2107.41 N 3558.66 W 6002058.53 N 562267.94 E 1.768 4134.37 7893.05 92.710 284.650 4097.46 4163.36 2118.24 N 3599.80 W 6002069.01 N 562226.70 E 0.567 4175.59 7942.02 94.190 286.450 4094.51 4160.41 2131.35 N 3646.89 W 6002081.69 N 562179.50 E 4.753 4223.10 7986.46 94.680 287.220 4091.07 4156.97 2144.18 N 3689.30 W 6002094.15 N 562136.98 E 2.049 4266.40 8037.42 93.820 287.490 4087.29 4153.19 2159.34 N 3737.81 W 6002108.88 N 562088.34 E 1.768 4316.15 8080.25 91.720 289.410 4085.23 4151.13 2172.88 N 3778.38 W 6002122.06 N 562047.65 E 6.640 4358.19 8130.17 91.170 288.280 4083.97 4149.87 2188.99 N 3825.61 W 6002137.76 N 562000.28 E 2.517 4407.30 8172.81 92.960 288.060 4082.43 4148.33 2202.28 N 3866.10 W 6002150.69 N 561959.68 E 4.229 4449.14 8222.29 92.900 287.650 4079.90 4145.80 2217.43 N 3913.13 W 6002165.43 N 561912.51 E 0.836 4497.60 8266.04 92.710 287.530 4077.76 4143.66 2230.64 N 3954.79 W 6002178.27 N 561870.74 E 0.513 4540.42 8323.39 93.820 287.330 4074.49 4140.39 2247.79 N 4009.41 W 6002194.94 N 561815.96 E 1.967 4596.49 8390.00 93.820 287.330 4070.06 4135.96 2267.59 N 4072.86 W 6002214.17 N 561752.35 E 0.000 4661.56 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). ~. Vertical Section is from Well and calculated along an Azimuth of 299.100° (True). Magnetic Declination at Surface is 25.749°(16-Sep-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 8390.00ft., The Bottom Hole Displacement is 4661.56ft., in the Direction of 299.107° (True). -----_.~-_.~_---._---~--- 7 October, 2002 - 14:52 Page 50'6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-17 Your Ref: AP/SOO292311S00 Job No. AKZZ22158, Surveyed: 23 September, 2002 BP EXPLORA TION (ALASKA) INC. Milne Point Unit BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8390.00 4135.96 2267.59 N 4072.86W Projected Survey '-yO Survey tool program for MPS-17 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 225.00 0.00 224.99 225.00 8390.00 224.99 Tolerable Gyro 4135.96 AK-6 BP _IFR-AK '~- ---- 7 October, 2002. 14:52 Page 60f6 DrillQuest 3.03.02.002 ') AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-17MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD I M D (if applicable) 8,390.00' MD '\ ) aDd-lId 10-0ct-02 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEiVED OCT 1 i-:: "þ!":f) v i.v'."f... AlaGka 0;'; & Ga~; C¡;ne. L~.;mmj!sion 1\t'lchOf!~~J Sperry-Sun Drilling Services Milne Point Unit BPXA Milne.Point MPS MPS..17 MWD ~ Job No. AKMW22158, Surveyed: 23 September, 2002 Survey Report 7 October, 2002 Your Ref: API 500292311500 Surface Coordinates: 5999982.58 N, 565845.04 E (700 24' 37.4172" N, 1490 27' 49.8246" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 999982.58 N, 65845.04 E (Grid) Surface Coordinates relative to Structure: 11.99 N, 499.87 W(True) Kelly Bushing: 65. 90ft above Mean Sea Level Elevation relative to Project V Reference: 65.90ft Elevation relative to Structure: 65.90ft SpE!I'r'Y-IILJr1 DAILLtNG. SErAVtt:::.SS A Halliburton Company SlIrvey Ref: 5vy10197 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-17 MWD Your Ref: API 500292311500 Job No. AKMW2215B, Surveyed: 23 September, 2002 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -65.90 0.00 O.OON O.OOE 5999982.58 N 565845.04 E 0.00 Tolerable Gyro 135.00 0.750 210.000 69.10 135.00 0.775 0.44 W 5999981.81 N 565844.60 E 0.556 0.01 225.00 0.600 254.000 159.09 224.99 1.41 5 1.19W 5999981.16 N 565843.86 E 0.583 0.36 MWD Magnetic 293.97 0.220 64.400 228.06 293.96 1.45 5 1.42W 5999981.12 N 565843.64 E 1.186 0.53 384.18 0.720 74.440 318.27 384.17 1.225 0.71 W 5999981.35 N 565844.34 E 0.560 0.03 476.04 0.830 85.980 410.12 476.02 1.025 0.50E 5999981.57 N 565845.55 E 0.207 -0.94 - 566.66 1.070 93.970 500.73 566.63 1.035 2.00E 5999981.57 N 565847.05 E 0.302 -2.25 657.71 1.230 99.710 591.76 657.66 1.265 3.82E 5999981.36 N 565848.87 E 0.216 -3.94 753.54 0.740 94.430 687.57 753.47 1.48 5 5.45E 5999981.15 N 565850.50 E 0.519 -5.48 845.16 0.680 292.720 779.19 845.09 1.31 8 5.53E 5999981.32 N 565850.59 E 1.530 -5.47 939.68 1.080 290.780 873.70 939.60 0.788 4.18 E 5999981.84 N 565849.23 E 0.424 -4.04 1033.96 0.250 67.390 967.97 1033.87 0.398 3.54E 5999982.23 N 565848.59 E 1.351 -3.28 1127.85 0.620 79.860 1061.86 1127.76 0.228 4.23E 5999982.40 N 565849.27 E 0.404 -3.80 1220.20 0.800 94.520 1154.20 1220.10 0.185 5.37E 5999982.45 N 565850.41 E 0.275 -4.78 1314.44 0.920 238.300 1248.44 1314.34 0.635 5.38E 5999982.00 N 565850.42 E 1.735 -5.01 1409.60 1.310 250.300 1343.58 1409.48 1.40 5 3.70 E 5999981.22 N 565848.76 E 0.476 -3.92 1501.06 0.310 201.190 1435.03 1500.93 1.985 2.63E 5999980.62 N 565847.69 E 1.237 -3.26 1594.83 0.570 114.160 1528.80 1594.70 2.41 5 2.97E 5999980.20 N 565848.03 E 0.677 -3.76 1688.45 0.870 120.230 1622.41 1688.31 2.968 4.00 E 5999979.66 N 565849.07 E 0.330 -4.94 1782.34 0.580 263.430 1716.30 1782.20 3.378 4.15 E 5999979.25 N 565849.22 E 1.469 -5.26 1876.64 0.990 269.590 1810.59 1876.49 3.43 8 2.86E 5999979.17 N 565847.93 E 0.443 -4.17 1967.51 1.090 264.640 1901.45 1967.35 3.528 1.21 E 5999979.07 N 565846.28 E 0.148 -2.77 2061.49 1.000 0.970 1995.42 2061.32 2.785 O.34E 5999979.80 N 565845.40 E 1.658 -1.65 2155.31 1.520 15.310 2089.21 2155.11 0.765 0.68E 5999981.82 N 565845.73 E 0.644 -0.96 ~~. 2247.90 0.190 355.230 2181.79 2247.69 0.58N 0.99 E 5999983.16 N 565846.03 E 1.451 -0.59 2341.95 0.370 255.850 2275.84 2341.74 0.66N 0.68E 5999983.24 N 565845.72 E 0.471 -0.28 2435.80 0.560 257.030 2369.69 2435.59 0.48N 0.06W 5999983.06 N 565844.98 E 0.203 0.28 2529.37 1.810 323.500 2463.24 2529.14 1.57 N 1.38W 5999984.13 N 565843.64 E 1.782 1.97 2622.20 4.300 322.540 2555.93 2621.83 5.51 N 4.37W 5999988.05 N 565840.62 E 2.683 6.50 2715.32 6.610 321.060 2648.62 2714.52 12.45 N 9.86W 5999994.94 N 565835.07 E 2.485 14.67 2809.53 8.670 325.010 2741.99 2807.89 22.48 N 17.34 W 6000004.91 N 565827.50 E 2.255 26.09 2903.05 12.510 324.350 2833.90 2899.80 36.49 N 27.29 W 6000018.83 N 565817.43 E 4.108 41.60 2996.45 16.190 332.480 2924.38 2990.28 56.27 N 39.21 W 6000038.50 N 565805.34 E 4.483 61.63 3088.89 19.540 331.300 3012.35 3078.25 81.27 N 52.59 W 6000063.38 N 565791.73 E 3.645 85.48 3183.45 24.820 325.250 3099.89 3165.79 111.47 N 71.52 W 6000093.41 N 565772.54 E 6.077 116.70 --_._- ------------- 7 October, 2002 - 14:55 Page 20f6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPS .. MPS-17 MWD Your Ref: AP/500292311500 Job No. AKMW22158, Surveyed: 23 September, 2002 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northings Eastlngs Rate Section. Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 3276.99 28.640 321.600 3183.43 3249.33 145.18 N 96.64 W 6000126.91 N 565747.12 E 4.443 155.05 3370.59 30.800 323.040 3264.71 3330.61 181.92 N 124.99 W 6000163.39 N 565718.45 E 2.430 197.68 3463.32 33.560 323.370 3343.19 3409.09 221.46 N 154.56 W 6000202.67 N 565688.53 E 2.982 242.75 3556.77 35.330 322.540 3420.25 3486.15 263.64 N 186.41 W 6000244.57 N 565656.32 E 1.960 291.10 3650.28 35.920 322.420 3496.26 3562.16 306.84 N 219.58 W 6000287.48 N 565622.76 E 0.635 341.09 3742.50 36.610 320.960 3570.62 3636.52 349.64 N 253.40 W 6000329.97 N 565588.57 E 1.199 391.46 ';..~......-' 3838.11 39.030 320.600 3646.14 3712.04 395.05 N 290.47 W 6000375.06 N 565551.10 E 2.542 445.93 3931.27 39.310 320.470 3718.36 3784.26 440.48 N 327.87 W 6000420.15 N 565513.30 E 0.313 500.70 4025.14 40.750 320.060 3790.24 3856.14 486.91 N 366.47 W 6000466.24 N 565474.30 E 1.560 557.01 4118.54 43.760 321.850 3859.36 3925.26 535.69 N 406.00 W 6000514.67 N 565434.33 E 3.471 615.28 4212.14 48.540 320.300 3924.19 3990.09 588.16 N 448.42 W 6000566.77 N 565391.45 E 5.244 677.86 4305.22 54.130 321.270 3982.32 4048.22 644.46 N 494.33 W 6000622.66 N 565345.04 E 6.060 745.36 4397.89 60.960 321.480 4032.02 4097.92 705.52 N 543.11 W 6000683.29 N 565295.73 E 7.373 817.68 4491.36 68.040 322.210 4072.24 4138.14 771.83 N 595.19 W 6000749.13 N 565243.07 E 7.607 895.42 4585.28 70.820 320.150 4105.23 4171.13 840.32 N 650.31 W 6000817.13 N 565187.35 E 3.602 976.90 4678.70 71.130 317.720 4135.69 4201.59 906.90 N 708.32 W 6000883.20 N 565128.75 E 2.481 1059.97 4771.84 74.690 319.400 4163.06 4228.96 973.63 N 767.22 W 6000949.41 N 565069.26 E 4.193 1143.89 4865.58 80.360 318.710 4183.30 4249.20 1042.73 N 827.18 W 6001017.98 N 565008.70 E 6.091 1229.89 4959.56 79.790 317.010 4199.50 4265.40 1111.38 N 889.29 W 6001086.07 N 564945.98 E 1.882 1317.54 5052.47 81.910 316.050 4214.28 4280.18 1177.94 N 952.40 W 6001152.08 N 564882.30 E 2.499 1405.05 5145.55 87.230 317.950 4223.08 4288.98 1245.69 N 1015.56 W 6001219.26 N 564818.54 E 6.066 1493.19 5233.19 90.680 315.870 4224.68 4290.58 1309.66 N 1075.41 W 6001282.71 N 564758.13 E 4.596 1576.60 5277.55 93.690 315.460 4222.99 4288.89 1341.37 N 1106.38 W 6001314.14 N 564726.87 E 6.848 1619.08 _c' 5325.30 96.670 310.130 4218.67 4284.57 1373.66 N 1141.26 W 6001346.13 N 564691.71 E 12.748 1665.26 5370.32 96.230 308.590 4213.62 4279.52 1402.03 N 1175.85 W 6001374.19 N 564656.88E 3.537 1709.28 5419.97 97.290 303.030 4207.77 4273.67 1430.87 N 1215.81 W 6001402.68 N 564616.66 E 11.323 1758.23 5464.22 95.490 300.670 4202.84 4268.74 1454.07 N 1253.16 W 6001425.55 N 564579.11 E 6.681 1802.15 5513.68 96.790 296.960 4197.55 4263.45 1477.77 N 1296.24 W 6001448.87 N 564535.82 E 7.907 1851.31 5557.60 96.600 296.150 4192.43 4258.33 1497.27 N 1335.26 W 6001468.02 N 564496.63 E 1.882 1894.89 51308.11 96.530 291.230 4186.65 4252.55 1517.43 N 1381.20 W 6001487.77 N 564450.52 E 9.678 1944.83 51350.34 96.170 285.750 4181.98 4247.88 1530.73 N 1420.98 W 6001500.72 N 564410.62 E 12.925 1986.07 5701.25 92.520 283.420 4178.12 4244.02 1543.51 N 1470.10W 6001513.07 N 564361.39 E 8.498 2035.20 5744.54 91.780 282.430 4176.50 4242.40 15q3.18 N 1512.26 W 6001522.37 N 564319.14 E 2.854 2076.74 5793.29 91.420 281.260 4175.14 4241.04 15Q3.19 N 1559.96 W 6001531.95 N 564271.36 E 2.510 2123.28 5837.58 93.020 281.500 4173.42 4239.32 1571.92 N 1603.34 W 6001540.30 N 564227.90 E 3.653 2165.44 ---~ -~-- ---_._._-_..~._--~--- 7 October, 2002 - 14:55 Page 3 of6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPS . MPS-11 MWD Your Ref: API 500292311500 Job No. AKMW22158, Surveyed: 23 September, 2002 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 5886.54 93.080 280.970 4170.81 4236.71 1581.44 N 1651.30 W 6001549.40 N 564179.87 E 1.088 2211.97 5930.91 93.020 280.660 4168.45 4234.35 1589.76 N 1694.82 W 6001557.33 N 564136.28 E 0.711 2254.04 5980.56 93.200 279.840 4165.76 4231.66 1598.58 N 1743.60 W 6001565; 73 N 564087.41 E 1.689 2300.96 6025.40 94.060 280.940 4162.92 4228.82 1606.65 N 1787.62 W 6001573.41 N 564043.33 E 3.110 2343.34 6073.58 93.330 284.640 4159.82 4225.72 1617.29 N 1834.49 W 6001583.64 N 563996.36 E 7.812 2389.48 6118.66 94.310 285.640 4156.81 4222.71 1629.04 N 1877.91 W 6001595.00 N 563952.84 E 3.102 2433.13 ~' 6165.59 94.440 285.460 4153.23 4219.13 1641.58 N 1922.99 W 6001607.15 N 563907.65 E 0.472 2478.62 6211.78 94.500 285.850 4149.63 4215.53 1654.01 N 1967.33 W 6001619.18 N 563863.20 E 0.852 2523.40 6260.78 94.680 285.560 4145.71 4211.61 1667.23 N 2014.35 W 6001631.99 N 563816.07 E 0.695 2570.92 6305.42 93.200 286.130 4142.64 4208.54 1679.39 N 2057.19 W 6001643.77 N 563773.12 E 3.552 2614.27 6354.19 90.490 285.310 4141.07 4206.97 1692.60 N 2104.11 W 6001656.56 N 563726.09 E 5.805 2661.68 6398.67 90.800 285.180 4140.57 4206.4 7 1704.29 N 2147.02 W 6001667.88 N 563683.08 E 0.756 2704.87 6448.31 93.020 285.660 4138.92 4204.82 1717.48 N 2194.85 W 6001680.64 N 563635.14 E 4.575 2753.07 6492.22 93.450 285.350 4136.44 4202.34 1729.20 N 2237.09 W 6001691.99 N 563592.79 E 1.207 2795.68 6556.84 93.080 286.520 4132.76 4198.66 1746.91 N 2299.13 W 6001709.16 N 563530.60 E 1.896 2858.50 6585.08 92.160 286.670 4131.47 4197.37 1754.97 N 2326.16 W 6001716.97 N 563503.50 E 3.301 2886.04 6634.74 91.720 285.930 4129.79 4195.69 1768.90 N 2373.80 W 6001730.48 N 563455.74 E 1.733 2934.44 6678.96 91.780 285.220 4128.44 4194.34 1780.77 N 2416.37 W 6001741.97 N 563413.06 E 1.611 2977.41 6726.96 92.090 285.320 4126.82 4192.72 1793.40 N 2462.65 W 6001754.20 N 563366.67 E 0.679 3023.99 6773.06 92.090 284.850 4125.14 4191.04 1805.39 N 2507.13 W 6001765.80 N 563322.09 E 1.019 3068.69 6820.61 92.220 284.880 4123.35 4189.25 1817.58 N 2553.06 W 6001777.58 N 563276.06 E 0.281 3114.75 6865.43 92.280 284.380 4121.59 4187.49 1828.89 N 2596.39 W 6001788.51 N 563232.62 E 1.123 3158.11 6913.79 92.210 284.100 4119.69 4185.59 1840.78 N 2643.23 W 6001799.98 N 563185.68 E 0.596 3204.82 6959.17 92.220 283.710 4117.94 4183.84 1851.68 N 2687.25 W 6001810.49 N 563141.57 E 0.859 3248.58 --c 7010.06 92.090 283.390 4116.03 4181.93 1863.59 N 2736.69 W 6001821.97 N 563092.03 E 0.678 3297.57 7052.88 91.790 283.320 4114.58 4180.48 1873.48 N 2778.32 W 6001831.49 N 563050.31 E 0.719 3338.76 7101.66 92.090 282.990 4112.92 4178.82 1884.57 N 2825.80 W 6001842.17 N 563002.74 E 0.914 3385.64 7146.34 92.460 283.040 4111.15 4177.05 1894.63 N 2869.29 W 6001851.84 N 562959.15 E 0.836 3428.53 7198.58 90.860 282.640 4109.64 4175.54 1906.23 N 2920.21 W 6001862.99 N 562908.14 E 3.157 3478.66 7239.75 91 .480 283.630 4108.80 4174.70 1915.58 N 2960.29 W 6001871.99 N 562867.98 E 2.837 3518.23 7282.10 89.750 282.980 4108.34 4174.24 1925.33 N 3001.50 W 6001881.37 N 562826.68 E 4.364 3558.98 7333.30 89.690 282.690 4108.59 4174.49 1936.70 N 3051.42 W 6001892.31 N 562776.67 E 0.578 3608.13 7381.76 90.680 282.760 4108.44 4174.34 194X.38 N 3098.69 W 6001902.56 N 562729.31 E 2.048 3654.62 7421.90 90.060 281.380 4108.18 4174.08 195. .77 N 3137.94 W 6001910.61 N 562689.98 E 3.769 3693.00 7476.35 89.750 282.780 4108.2"7 4174.17 196"1.16 N 3191.18 W 6001921.53 N 562636.64 E 2.633 3745.07 -_.~-~.._--_w- 7 October, 2002 - 14:55 Page 4 of6 Dri/lQllest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-17 MWD Your Ref: API 500292311500 Job No. AKMW22158, Surveyed: 23 September, 2002 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 7520.01 89.570 282.600 4108.53 4174.43 1976.75 N 3233.77 W 6001930.75 N 562593.97 E 0.583 3786.95 7569.82 91.290 281.820 4108.15 4174.05 1987.29 N 3282.45 W 6001940.85 N 562545.19 E 3.792 3834.61 7612.79 91.720 281.940 4107.02 4172.92 1996.13 N 3324.49 W 6001949.33 N 562503.08 E 1.039 3875.63 7662.64 91.290 281.610 4105.72 4171.62 2006.30 N 3373.27 W 6001959.06 N 562454.21 E 1.087 3923.21 7703.58 91.420 281.900 4104.75 4170.65 2014.64 N 3413.34 W 6001967.05 N 562414.07 E 0.776 3962.27 7757.92 91.850 281.440 4103.20 4169.10 2025.63 N 3466.54 W 6001977.57 N 562360.78 E 1.159 4014.10 7798.49 92.400 281.630 4101.69 4167.59 2033.73 N 3506.26 W 6001985.32 N 562320.99 E 1 .434 4052.75 7850.46 92.590 281.070 4099.43 4165.33 2043.95 N 3557.17 W 6001995.09 N 562269.99 E 1.137 4102.20 7893.05 92.710 280.860 4097.46 4163.36 2052.04 N 3598.93 W 6002002.82 N 562228.16 E 0.567 4142.63 7942.02 94.190 282.580 4094.51 4160.41 2061.97 N 3646.79 W 6002012.32 N 562180.21 E 4.629 4189.28 7986.46 94.680 283.730 4091.08 4156.98 2072.05 N 3689.94 W 6002022.02 N 562136.98 E 2.806 4231.88 8037.42 93.820 284.200 4087.30 4153.20 2084.32 N 3739.25 W 6002033.85 N 562087.56 E 1.922 4280.93 8080.25 91.720 284.480 4085.23 4151.13 2094.91 N 3780.70 W 6002044.08 N 562046.02 E 4.946 4322.30 8130.17 91.170 283.650 4083.97 4149.87 2107.04 N 3829.10 W 6002055.78 N 561997.51 E 1.994 4370.49 8172.81 92.960 283.800 4082.44 4148.34 2117.15 N 3870.50 W 6002065.53 N 561956.03 E 4.213 4411 .58 8222.29 92.900 283.120 4079.91 4145.81 2128.65 N 3918.56 W 6002076.61 N 561907.87 E 1.378 4459.17 8266.04 92.710 282.780 4077.77 4143.67 2138.45 N 3961.14 W 6002086.02 N 561865.20 E 0.889 4501.14 8323.39 93.820 282.830 4074.50 4140.40 2151.14N 4016.97 W 6002098.22 N 561809.26 E 1.937 4556.09 8390.00 93.820 282.830 4070.06 4135.96 - 2165:89 N 4081.78 W 6002112.41 N 561744.33 E 0.000 4619.89 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. ~ The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 299.100° (True). Magnetic Declination at Surface is 25.749° (16-Sep-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 8390.00ft., The Bottom Hole Displacement is 4620.82ft., in the Direction of 297.952° (True). _._-----~----~ 7 October, 2002 - 14:55 Page 5 of6 Dril/Quest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-17 MWD Your Ref: API 500292311500 Job No. AKMW22158, Surveyed: 23 September, 2002 BP EXPLORA TION (ALASKA) INC. Milne Point Unit BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8390.00 4135.96 2165.89 N 4081.78 W Projected Survey Survey toOllJrOflram for MPS-17 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 225.00 0.00 224.99 225.00 8390.00 224.99 Tolerable Gyro 4135.96 MWD Magnetic -~/ ~---'------ 7 October, 2002 - 14:55 Page 6 of6 Dri/lQuest 3.03.02.002 ) ~~JL~E :} !Æ:~fÆ~~«!Æ AI/ASIiA. OIL AlWD GAS CONSERVATION COMMISSION I / TONY KNOWLES, GOVERNOR 333 W. "fTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPS-17 BP Exploration (Alaska), Inc. Permit No: 202-173 Surface Location: 3315' NSL, 165' WEL, Sec. 12, TI2N, RI0E, UM Bottomhole Location: 295' NSL, 4228' WEL, Sec. 01, T12N, R10E, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above development well. The permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, Cä~()4U' ~QJ Cammy OtÞhsli Tayi~r-O" Chair BY ORDER OF THE COMMISSION DATED this~ay of August, 2002 cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Hole 42" 9-7/8" 6-1/8" ALASKA JIL AND ~~;~g:S~~;~ON COMÞ.JSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well D Exploratory D Stratigraphic Test II Development Oil D Service D Development Gas D Single Zone D Multiple Zone 5. Datum Elevation (DF or KB) 10. Fjeld and Pool Planned KBE = 66.5' /Milne Point Unit / Schrader 6. Property Designation Bluff ADL 380109 7. Unit or Property Name Milne Point Unit 8. Well Number / MPS-17 9. Approximate spud date/ 09-12-02 /' Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8360' MD / 4141' TVD 0 17. Anticipated pressure {S~20 AAC 25.035 (e) (2)} 95.32 Maximum surface 1465 psig, At total depth (TVD) 4270' / 1892 psig Setting Depth Top Bottom MD TVD MD TVD Surface Surface 112' 112' Surface Surface 5189' 4270' 5089' 4263' 8360' 41411 WGÂ- i/2~/OL $- ~~[~ 1 a. Type of work II Drill D Redrill D Re-Entry D Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3315' NSL, 165' WEL, SEC. 12, T12N, R10E, (As Staked) At top of productive interval 4587' NSL, 1245' WEL, SEC. 12, T12N, R10E, UM (OB) At total depth 295' NSL, 4228' WEL, SEC. 01, T12N, R10E, UM (OB) 12. Distance to nearest property line 13. Distance to nearest well . ADL 025637,295' MD No Close Approach I 16. To be completed for deviated wells Kick Off Depth 2500' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couplina 20" 92# H-40 WELD 7-5/8" 29.7# L-80 BTC 4-1/2" 12.7# L-80 BTC 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Lenath 80' 51891 3271' Quantitv of Cement (include staae data) 260 sx Arctic Set (Approx.) 566 sx PF 'L', 332 sx Class 'GI Uncemented Slotted Liner .¡ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Su rface Intermediate Production Liner Length Size Cemented MD TVD E ~: I ~.m; t§ ¡;- r £'"'l .'~ td. !(~ L t. i. t¡......--- Perforation depth: measured true vertical Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments II Filing Fee D Property Plat D BOP Sketch D Diverter Sketch II Drilling Program II Drilling Fluid Program D Time vs Depth Plot D Refraction Analysis D Seabed Report D 20 AAC 25.050 Requirements Contact Engineer Name/Number: Matt Green, 564-5581 Prepared By Name/Number: Sandra Stewman, 564-4750 21. Is~:~::Y c:.~:::tthep5ing ÇLfQ ï~ ;I~~;:::~~~:~:~:.;. D~te fJ/2 0 ~ Permit Number ' API Number . Approval D,te See cover letter .2.02-- / /3 50- 029- 2-3// 5 íI~()l.n¡:J. forotherreauirements Conditions of Approval: Samples Required 0 Yes 181 No Mud Log f{equired 0 Yes 181 No Hydrogen Sulfide Measures 0 Yes 1&1 No Directional Survey Required BI Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T~~tB() PE Þ ë./-tJOO fS; , Onglnal Signed By . . by order o! . CJmmy O3tJIsli TQy~~",\com~lsslo~e,r . r . the commiSSion t,J I 10\j¡~L Approved By Form 10-401 Rev. 12-01-85 , ¡. Date ~ 3() ()~ SJbmit In Triplicate ) Milne I } MPS-17 Well Permit IWell Name: IMPS-17 Drill and Complete Plan Summary I Type of Well (service / producer / injector): 1 Multi Lateral Producer "OA" & "OB" Surface Location: Target Location: TOP "OA" Target Location: BHL "OA" Well TD Target Location: TOP "08" Target Location: BHL "08" Well TD 19641 FNL, (33151 FSL), 1651 FEL, (5114' FWL), SEC. 12, T12N, R10E E=565844.98 N=5999982.84 6921 FNL, (45871 FSL), 1245' FEL, (40341 FWL), SEC. 12, T12N, R10E E=564754 N=6001246 Z=4165' TVD 49841 FNL, (2951 FSL), 4228' FEL, (10521 FWL), SEC. 1, T12N, R10E E=561763 N=6002208 Z=4030' TVD 692' FNL, (4587' FSL), 1245' FEL, (4034' FWL), SEC. 12, T12N,R10E E=564754 N=6001246 Z=4204' TVD 4984' FNL, (295' FSL), 4228' FEL, (1052' FWL), SEC. 1, T12N, R10E E=561763 N=6002208 Z=4074' TVD /' I AFE Number: I N/A 1 I Ria: I Doyon 141 / I I Estimated Start Date: 112 Sep 2002 1 / I Operatina days to complete: 116 / 1 I MD: 18,360 I 1 TVD: 14,141 I I Max Inc: 195 I I KOP: 12,500 I I KBE:166.5 I I Well Desian (conventional, slim hole, etc.): I Conventional Grass Roots ML Producer I I I Objective: I Schrader OB Sand Mud Program: 9-7/8" Surface Hole Mud Properties: Density (ppg} Funnel vise VP 8.6 - 9.20 75 -150 25 - 60 HTHP N/A Spud - LSND Freshwater Mud pH API Filtrate LG Solids 9.0-9.5 < 8 < 6.5 6-1/8" Production Hole Mud Properties: KCL-CaC03 Flow Pro Density (ppg) Funnel visc VP HTHP pH API Filtrate LG Solids 8.6 - 9.20 /' 40 - 55 22 - 27 <10 8.0 - 8.5 4 - 6 < 12 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. 1 ) Milne F } MPS-17 Well Permit Cement Program: Casinq Size 17.625-in 29.7-lb/ft L-80 BTC Intermediate Casing B . 250% excess over gauge hole in permafrost interval ,/ aSls 400/0 excess over gauge hole below permafrost Total Cement Volume: 487-bbl Wash 50 bbl water Spacer 50 bbl Spacer ~AI. ha Design) weighted to 1 0.50 p~/ Lead 419-bbl (566-sx e 10.7 Ib/gal Class L - 4.15 cuft/sx T 'I 68-bbl (332-sx 15.8 Ib/gal Prem G - 1.15 cuft/sx ./' '''i':ii:,:'':~m:i'))\\@ØHŒ''1,"\,1!~£¡,,~!,,!:~,!,~,@~!~,~':"~!'~lr::!:!:II,¡~~te,li:¡%i¡'¡¡ØI'¡¡:,wm:gl:%1:1:':\\:%nlm:@%@::':I;;":m\'¡%@%I%!@!i':%%!i',WI¡@jl"!l%@II%%~W%!::¡nli:I;1i'¡¡",:"",,,,,,,,, T BHST ==: 80° F from SOR, BHCT 85° F estimated by emp Halliburton Evaluation Program: 97/8" Hole Section: Open Hole: Cased Hole: 6-1/8" Hole section: Open Hole: MWD/GRlRES IFRlCASANDRA N/a MWD/GRlRES ABI/IFRlCASANDRA Formation Markers: Formation Tops MDrkb TVDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (Ib/gal)* Base Permafrost 1816 1816 788 8.65 Top Ugnu 3669 3586 1584 8.65 NA 4487 4110 1820 8.65 NB 4535 4129 1828 8.65 ^\) NC 4602 4153 1839 8.65 /.vA ~ NE 4638 4165 1845 8.65 1..¡I'- NF 4768 4207 1863 8.65 ~, Top OA 4859 4231 1874 8.65 Base OA 4961 4251 1883 8.65 Top OB 5189 4270 1892 8.65 2 ) Milne J) MPS-17 Well Permit CasingITubing Program: Hole Csgl WtlFt Gra~ Conn Length Top Bottom Size Tbg O.D. MD I TVDrkb MD I TVDrkb 42-in 20-in* 92# H-40 Weld 80-ft 30-ft 112-ft / 112-ft 9.875-in 7.625-in 29.7# L-80 BTC 5,159-ft 30- ft 5, 189-ft / 4,270-ft 6.125-in 4.5-in 12.7# L-80 BTC 3,501-ft 4,858 -ft / 4,231-ft 8,359-ft / OA 4,097-ft 6.125-in 4.5-in 12.7# L-80 BTC 3,271-ft 5,089-ft / 4,263-ft 8,360-ft / OB 4,141-ft *The 20" casing is insulated Recommended Bit Program: BHA Hole Size Depth (MD) 1 9.875-in 0 - 5, 189-ft 2 6.125-in 5,189 - 8,360-ft 3 6.125-in 4,858 - 8,360-ft Bit Type Nozzles Smith FGXiODPS 3 - 15, 1 - 10 Security FM2643 3 - 12 Security FM2643 3-12 Well Control: /' . Production hole will be drilled with a diverter. Surface Interval . 1,892-psi @ 4,270-ft TVDrkb - Top of OB sand. 1,465-psi @ surface (Based on BHP and a fy.tVcolumn of gas from TD @ 0.1 psi/ft) Diverter will be function tested. BOP's:Test annular 250 psi low / and 2500 psi high, and rams to 250 psi low and 4,000 psi high. N/A 9.2 ppg NaCI / 6.8 ppg Diesel . Maximum anticipated BHP: . Maximum surface pressure: . Planned BOP test pressure: . Kick tolerance: . Planned completion fluid: Drilling Hazards & Contingencies: Hydrates . Hydrates have not been seen on S pad, but have been encountered in the surface holes on other pads, especially nearby H-Pad. Hydrates generally occur just below the Permafrost (+/- 1800 ss) but may be present in shallower SV sands and also as deep as 3000 ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates; increase mud wt; maintain cool mud « 60 deg F); limit Rap, reduce pump rate while 3 ') Milne F ) MPS-17 Well Permit drilling hydrates; circulate connections thoroughly. See Well Program and Recommended Practices for specific information. . Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation . We do not expect losses while drilling this well. . Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Below is a list of the wells and the lost circulating problems associated with them. H-06 (1995): Lost 100-bbl running 9-5/8" casing, good returns during cementing except no returns for last 20-bbl, contaminated cement to surface, cement 12 ft down, no top job. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures . It is unlikely there will be unexpected overpres§l1re when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be (8.65 Ib/Qal EMW). In this well, the Schrader Bluff formation will be drilled with 9.1 ppg mud. Pad Data Sheet . Please Read the S-Pad Data Sheet thoroughly. Breathing . N/A Hydrocarbons . Hydrocarbons will be encountered in the NA through the Schrader Bluff. Faults . NA Hydrogen Sulfide . MPS Pad is not designated as an H2S Pad. Anti-collision Issues . MPS-17 has no anti-collision issues. 4 ) Milne r) MPS-17 Well Permit DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. The 20" insulated conductor is installed Procedure I 1. MIRU, NU diverter on 2011 conductor and function test, PU 411 drill pipe 2. Drill 9-7/8" surface hole as per directional plan. /' 3. Condition mud prior to 7 5/811 casing run. POOH /' 4. Run and cement 7 5/811 casing from TO to surface. 5. NO Diverter 6. Install FMC 1111 5m horizontal wellhead 7. N/U and test 13 %11 5m BOP and test annular to 250 low and 2500 high. Test the rams to 255tlow and 4000 psi high / 8. Drill 6-1/8" OB horizontal production hole as per directional plan. 9. Run 4-1/2" slotted liner and hang off 100' inside 7-5/8" casing. /' 10. Make up Baker Window Master milling assembly with bottom trip anchor and MWD. a. RIH. Orient and set whipstock to place window at top of the OA interval. b. Shear off and mill window thru 7-5/8" casing. 11. Drill 6-1/8" OA lateral geosteering and short tripping as required. Maintain FloPro mud properties and POOH. 12. MU whipstock retrieving tool and pull whipstock 13. Run 4 Y2" slotted liner with Baker Hook Hanger and hang off in 7-5/8" casing 14. POOH / 15. TIH and displace out drilling mud with 9.2 ppg NaCI 16. POOH 17. Run in hole with 4-1/2" jet pump completion as per schematic 18. Land tubing hanger and test 19. Set BPV 20. NO BOP 21. Install and test tree 22. Pull BPV 23. Drop ball and set production packer 24. Test 7-5/8" x 4-1/2" annulus and packer to 3,500-psi 25. Freeze protect thru GLM 26. Install BPV and secure the well 27. RD/MO 5 TREE: Cameron 4-1/16" 5M """"'(H, UPUSI:::LJ c;UMPLI::: I I UN.,.),., . WELLHEAD: FMC Gen 6 11",5M .111 PS-1-- P~-17 1 Tubing Head: 11" x 4-1/2", ~ FMC Tubing Hanger . , 20" 92 Ib/tt, H-40 Welded Ý ~ 42" Hole Insulated 4-1/2" X 1" Gas Lift Mandrel @ 2,000' MD , 2000' TVD, Diesel Freeze protect to RP shear valve open position 750' MD KB. ELEV =66.5' Cellar Box ELEV = 38.0' 1121 9.2 KCI with corrosion inhibitor as packer fluid 4-1/2", 12.6Ib/ft, L-80, IBT-M Coupling 00: 5.2" Drift/ID: 3.833" Burst: 8,430, 80% 6,744 psi Collapse: 7,500, 80%=6,000 psi "BIW 1- Wire Phoenix Pressure Gauge (3.850" ID, W/BIW 1- wire down to lower sensor) Jet Pump Installed in Sliding Sleeve Post rig! III Halliburtion Dura Sleeve XD W/X Nipple (3.813" ID) Phoenix Pressure Gauge (2.840" ID) 7-5/8" 29.7#, L-80, BTC-M Casing Drift: 6.75 Casing ID: 6.875 Coupling 00: 8.5" Burst: 6,890 psi Collapse: 4,790 psi 7-5/8" x 4-1/2" 8-3 Packer /1 Set @ 4,800' MD, 4217' TVD I 3-1/2" HES 'XN' nipple 2.750" ID No Go W/RHC ball & rod Wireline Entry Guide Window in 7" casing @ 4,858' MD Well Inclination @ Window = 77 Degrees Multi-Lateral Junction 4,8581 \~ 6-1/8" OA Lateral TD 8,359' 6-1/8" OB Lateral TD 8,360' / ....... ---- - - - - - - - OA Horizontal 6-1/8" hole r--- --- - - - - - - - - 4-1/2" Slotted Liner W/Hookwall hanger 7.625" Casing Shoe @ 5,189' MD Well Inclination @ Shoe = 90 Degrees ~ .~ ~. <:::: , . ~~ 9-7/8" Hole " \ ~, ------- " '--- OB Horizontal 6-1/8" hole --------- PBTD TD 4-1/2" Slotted Liner & Hanger DATE 20 Aug 02 REV. BY MDG COMMENTS Level 3 Multi-Lateral, 4-1/2" Jet Pump Completion Milne Point Unit WF. I : MPS-17 API NO: Au¡-14-2002 05:41 F r om-MCC WIN G..Q )J ,. - -..-: ,- - -,~..-:::,~::;¡"":,, -: :::-, J r I I L J I I I I 1 . I I I I I r , I I f I I I I MPS-33 -+- I ~ ~ I . :31i I : 829i: I 827 I L 8 25 .J I 824i : 823. : I. 8211 I ~. MPS...19i +, ~ , MPS-17 -$- : .,~: I .1~ I '- ~I I . " . - I "'. I - 1-..-- . ..I I I . 7; I I '-'5--. ~ 1- -:"l Ste, - - - - T - - I , . 3 - S --- J 2 ì7 " ..., I ' I te.,. 7'::'-' 2¡y R I I r¡ "tv -..:.. 70E' I .. . IV I , -'-"'1 . ,. Co I - I I I I I "J I ~ . : # : Øl S . n..... I Iw'~ -_J.--____L--___J. r__~ I ,,° '" I tl I -~ .' I PLANT J'15'00'00" CF?{Q , +907-659-5065 T-Z73 P.OOZ/OOZ F-4Z9 . ) J2 2> ~-p~~ I. '-~y~ £-PAD ~'i) ~è.PAO 26 25. .,~) SITE 2~ 21 MPU S-PAD .; .34 H-PAD T13N T121'1 ) 28 35 ~....-'- -- , .1f'~.~~. , .33 11 9 10 1'1 . \ 17 " 15 VICINITY MAP N,T,S. 15 LEGEND -+ . AS-STAKED CONDUCTOR EXISTING CONDUCTOR --- ~ ~ ¡::: ~ NOTES: 1. DATE OF SuRVËY: AUGUST 06, 2002, 2. REFERENCE FIELD 800K; MP02-06 PAGES 41-42. 3. COORD¡NATES ^RE ALASKA STATE PLANE. ZONE-4 NAD-27. 4. GEODETIC COORDINA n:s ARE NAD-27, 5. MPU S-PAD AVERAGE SCALE FACTOR 1$: 0.999904923. 6, HORIZONTAL CONTROL IS eASED ON MPU CFP MONUMENT CFP-3 AND MPu H-PAD MONUMENT H-l. 7. E I...E VA TIONS ARE BPX MEAN SEA I...EVE!.. 8ASED ON MILNE POINT PIPELINE: VERTICAL CONTROl. ,,' C> '" .... .... '" '. cr. 1 co " 0/1 .1\ ,r LOCATED WITHIN PROTRACTED SEC. 12. T, 12 N" R. 10 E,. UMIAT MERIDIAN. ALASKA WELL A.S.P. PLANT GEODETIC .... GEODETIC PAD. 'SECTION NO. COORDINATES COORDIN¡\ T.E~ POSITION(DMS) POSITtON(D.DD)- ,ELEVATION OFFSETS PS 7 Y;,;;5,999.982.84 N= 2,237.00 70'24'37.420" 70.4103944" 38 O' 3,315' FSL M -1 x= 565,844,98 E=6.719.00 ,14~'27'49.826" 149.4638406' , 166' FEL . MPS-19i Y=5,999,975.07 N;::: 2,237.00 70'24'37,346" 70.4103739" 38.1' 3.308' FSL x= 565,816.01 E= 6,689.00 149-..2}'50.67T' 149.4640769' 195' FEL MPS-33 Y=5,999,920,72 N= 2,237.00 70"24'36.829" 70.4102303' 38,0' 3,255' FSt.. X-. 565,613.18 E= 6,479.00 149"27'56,637" 149.4657325" 398' FEL ... '" ~ ~ .. L n ,. ~ ~ CJ ... 1 Q on (v ... ... ,.. ~ 6:: , ~ ~ ::; 0 8/11/02 ISSuED ,OR 'NFOR~ATJON g NO. O...'TE .". ".., ~~<;,C)N -- -- - --. F 'f<o~~elt . ~R...."'k: JACOBS 1 . ¡;':;¡':-l:¡(I."" .-- ----.- .'. _. ON~LEý ---- . - II ßr ", : O.~~E~ 8/5/02 .- - -- n. ... (]~A\I"II4.C:' -- -. -.. . .. --- - -- . F'R502 Io4P~ 25-01 -- . -_.' -~_:: ~=-= '~ffi~mœo :~o -.. .-- JJC RF'/\ ...c..c...~-~..~.=:~ ~,.(41 ._~ """" By Ò"" ~ *&('~n.~~ ~ 10f'1 1"= ~ao' #Mtt bp fi~~ MILNE POINT UNIT S-PAD AS~STAKED CONDUCToRS MPS-17, 19i & 33 SnEET 08/14/02 WED 04:44 [TX/RX NO 6757] I4J 002 ~..:; " 800 1600 '" 2 0 ~ .<: ë. å 8 1: >- 2400 2 E- 3200 4000 4800 COMPANY DETAILS REFERENCE INFORMATION HI' Amocl1 Cn"ordjnat~ (N/E) Reference: Well ('entre: Piau MPS-I7. True North V~rtical (TVD) Rcferenœ; RU 6650 66.50 ~~til'ln (VS) Refercnc~: Slot. (O.DON.n.UO!:) Me<isured [)¡,:pth Rer~rence: RB 66.~O 6650 Calculation Method: Minimw11 Cucvatuæ ('akul~lion M~ttk."W.1: Minimum CUr\~dture I:rror S\'stem: IS('WSA Scan M~thod: Irav Cylind~r North l~rror Surtà:~c: E"j~tkal" ('a~jng Wamin¡;!. Methot.!: Ruks Basoo A IQQ(}.- ----- - ---8PRF .---- 2000. - CASING DETAILS No. TVD Name MD 4270.49 5189.11 75/8" 4140.50 8359.97 41/2" FORMATION TOP DETAILS No. TVDPath MDPath Formation I 1750.00 1:'.0).00 BPRF 2 3586.50 '...,'),15 T Ugnu 3 4110.50 .~~~?19 NA 4 4129.50 .~.. ";.22 NB 5 4153.50 .~, '''-~.13 NC 6 4165.50 ~" ':;.20 NE 7 4207.s0 ~ ~'.~.06 NF 8 4231.50 ~~..'.45 OA 9 4251.50 ~.",'1.90 Base OA 10 4270.49 ..1;0,').11 OB All TVD depths are ssTVD plus 66.5'for RKBE. Start Dir 3.31 I 00' : 2500' MD. 2500'TVD / 8° T 0 ",,° EndDir :3519.51'MD,3461.92'TVD ~ Start Dir 4/1 00' : 3676.42' MD, 3592.55'1VD /" - ~ End Dir : 4609.45' MD, 4155.95' TVD J Start Dir41100': 4709.45' MD, 4189.17'1VD -rP Start Dir 12/100': 5194.47' MD, 4270.5'1VD LOM"" ..,.0 EndDir : 5250.12'MD,4267.91'TVD NA ,~ I. I Start Dir 101100' :.5276,98' MD, 4265.42'1VD 'IB l:! ~ &., / I NC./" . ~ J I -I. '" NE N'" / I ~\ t: 6000 ~ QÞ. 5000 I '7 5/8' Base OA OB SOrt );,4'1 W , 5495.7;' MO,""SS'T"D I Ene Dir : 5524 87' \1D, 42J5.31' TVD Srart )ir4/1r': ';017.78 MD,4207.59'1'VD E,d ir: 60:;4.27' N D, L20~.491 TVD , 1 1 \ 800 1600 2400 Vertical Section at 299.10° [800ft/in] SURVEY PROGRAM Plan: MPS.!7 wp04 (Plan MI'S.!7/Plan MPS-17) fkpth Fm Depth To SUIVe)'/Pian Tool Created By: Ken Allen Date: 8/15/2002 27.60 900.00 Planned: Mps.17 wp04 V 10 900.00 8359.98 Plarmed: Mps.17 wp04 VIO CB-GYRO.SS MWD+IFR+MS Size Reviewed: --..--,------...-- Date: -"--~ WELL DETAILS Name +Ni.S +EJ.W Northing F.asring Latitude Longitude Slot Plan MPS.17 9.28 .,00.00 ,999982.84 56,844.98 70024'37.420N 149°27'49.826W NiA TARGET DETAILS Name lVD +N/.S ,EJ.W Northing Hasting Sha~ MPS.17 T6 4127.50 1940.38 .3058.28 6001896.00 562770.00 Point MPS-17 17 4137.50 2088.95 .3575.04 6002040.00 562252.00 Point MPS.17 T8 4140.50 2261:17 4062.59 6002208.00 561763.00 Point MPS.17 15 4162.50 1781.48 .2504.61 6001742.00 563325.00 Point - MPS.17 Poly 4166.50 1235.07 -1105.24 6001208.00 564729.00 Polygon MPS-17 14 4206.50 1597.57 .1837.14 6001564.00 563994.00 Point MPS.17 13 4245.50 1445.01 .1322.42 6OO14!6.00 564510.00 Point MPS-17 T2 4270.50 1272.85 .1079.90- 6OO1246.OU 564754.00 Poin; SECTION DETAILS - Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace. VSec - I 27.60 0.00 õ.õO 27.60 0.00 0.00 0.00 0.00 0.00 2 :"111.00 0.00 0.00 2500.00 0.00 0.00 0.00 0.00 0.00 3 \..1".51 33.64 323.96 3461.92 235.17 1;.1.09 3.30 - 0.00 263.87 ~ 4 ". ;,..42 33.64 323.96 3592.55 305.47 : ~ !..23 0.00 0.00 ~4?.. 74 5 ~'.".'.45 70.60 317.00 4155.95 855.89 ',"1.08 4.00 -10.87 1":1).10 6 ~ ¡"".45 70.60 317.00 4189.17 924.87 ;.'.;.41 0.00 0.00 11"".86 7 ~~"J.45 76.60 317.00 4231.50 1030.06 :.'.1.50 4.00 0.00 I ~~'¡.73 8 '.I'qA7 90.00 317.00 4270.50 1272.85 -1"~').90 ì-i. 00 0.00 1..'.:..63 MPS-17 T2 9 ..: ..".12 95.32 312.96 4267.91 1312.13 -111'1.20 .00 -37,08 1..1';.07 10 . .' ~',.98 95.32 312.96 4265.42 1330.35 -II ''i,.77 0.00 0.00 I '.~:..04 II .'~"...72 95.00 291.00 4245.50 1445.01 -I '~.~.42 10.00 -89.84 I "-.S.26 MPS-17 T3 12 . '.:~.87 94.04 285.91 4235.31 1485.75 .1~~~.51 4.00 -100.45 1""'¡.75 13 ',"17.78 94.04 285.91 4207.59 1593.17 -1"~1.43 0.00 0.00 .: "''1.33 14 ,," ..~..13 93.63 285.40 4206.50 1597.57 -1;0, .7.14 4.00 -129.35 -' '''-:.21 MPS-17T4 15 ,." '~..27 93.63 285.40 4206.49 1597.60 -I:.' :'.27 4.00 -28.17 -' ':"~..33 16 ,,:. I ~.03 93.63 285.40 4163.53 1777.20 -.:~"').39 0.00 0.00 '" ").48 17 ',~:?87 93.79 286.01 4162.50 1781.48 -.:. ".k61 4.00 75.79 ,II.. ~.86 MPS-17 T5 18 <:7.94 93.79 286.01 4162.50 1781.49 -.:.."t67 4.00 152.25 ,,,.. ~.92 19 :.~ 1').33 93.79 286.01 4130.63 1914.28 -:"..7.33 0.00 0.00 ": \.76 20 ~ '''.'.02 90.00 286.00 4127.50 1940,38 - ""~.28 4.00 -179.78 ".1 ~.92 MPS-I7T6 21 ~ . '. ".36 88.83 285.69 4127.81 1948.66 - '"" 7.47 4.00 - I 65.35 ",~~.45 22 n~',.25 88.83 285.69 4136.23 2059.78 -\1:-2.96 0.00 0.00 ~..~ ';.06 23 :.~~ :.87 89.67 289.47 4137.50 2088.95 -,. >;.04 4.00 77.45 ~ I ").71 MPS-17 T7 24 :-."."J.98 89.67 289.47 4140.50 2261.27 -~"'..:.59 0.00 0.00 ~~.~'1.52 MPS-17 T8 7.000 4.500 Total Depth: 8359.98' MD, 4140.5' TVD End Dir : 7842.87' MD, 4137.5' TVD ~ ° \ ° \ 7roo~~1 \ * \ i 8<00 ~ 4W' \\ -. .. . ..~tart Dir41 00': 7746.25' MD, 4136.23'1VD \ En,dDlr : 7331.36'M),4 27..8I'TVD Start U\r4f100 : "/;':1O.j3' MU, 41.-0.6.1'1 VD Eld Dir 6727.94' ND, 4162.5' -VD Srart mrcttO')':"(,;7t1:æ~Mr ð3.53'TVD 1 I ~/~ ~x ~ ;" ", " " ,. ~ 3200 4000 I 4800 bp 0"',' "'.. " .. ~ ;¡:: 0 0 r:. 1400 '+ :: 1:: ! ;; 0 C/) C:OMI'ANY IJEIAILS REFERENCE INFORMATION SURVEY PROGRAM BP^lIll~") Co-ordinare (N/E) Rel~rence: Well CentTe: Plan MPS.)7, Tnl~ North Vertical (lVD) Refèrence: RB 6650 66.50 Section (V$I Refcr~ncc: Slot. (O.OON.O.OOE) Measured !Xptb Reference: RB 66.50 66.50 Calculation Method: Minimum Curvature 'kpth I'm 'kpth To Survey/PI..\ Tool Cakulation Metl}l.'IlI: Minimum <. 'urvatul\!' En\)[ System: ISCWSA Scali Mcthl.."Id: Trav Cylinder North Error Surface: Elliptical ¡. Casing Wamil12. MethcJC.1: Rules Based 27.60 900.00 900.!KJ Planned: MPS.17 wp04 V 10 8359.98 Planned: MPS.17 "1'04 VIO ("ß-GYRO.SS MWD+IFR+MS CASING DETAILS +Nr.s Name Size MD Name No. TVD Plan MPS.17 9.28 .500.00 5999982.84 7.000 4.500 4270.49 5189.11 75/8" 4140.50 8359.97 41/2" Name MPS.17 T6 MPS.I7T7 MPS.17 T8 MPS.17 T5 Mps.l7 Poly MFS.1714 MPS.17 T3 MPS.17T2 See MD Ine Azi 2100 I 27.60 0.00 0.00 27.6Cf 2 2500.00 0.00 0.00 2500.00 3 3519.51 33.64 323.96 3461.92 4 3676.42 33.64 323.96 3592.55 5 4609.45 70.60 317.00 4155.95 6 4709.45 70.60 317.00 4189.17 7 4859.45 76.60 317.00 4231.50 8 5194.47 90.00 317.00 4270.50 9 5250.12 95.32 312.96 4267.91 10 5276.98 95.32 312.96 4265.42 I I 5495.72 95.00 291.00 4245.50 12 5624.87 94.04 285.91 4235.3 I 13 6017.78 94.04 285.91 4207.59 14 6034.13 93.63 285.40 4206.50 15 6034.27 93.63 285.40 4206.49 Total Depth: 8359.98' MD, 4140.5' TVD 16 6712.03 93.63 285.40 4163.53 \iPS-17 wp04 17 6727.87 93.79 286.01 4162.50 \iPS-I7T8 ¡~ ~iiò:jj ~n~ ~~~:g¡ ~¡~~:~~ ------- End "Jir : 7842.87' MD, 4137.5' TVD 20 7305.02 90.00 286.00 4127.50 .L.-.. 3taL Di- 4/100' . 774625' MD 413623'TVD 21 7335.36 88.83 285.69 4127.81 / ~ .. , . 22 7746.25 88.83 285.69 4136.23 .:-.....::' ----- 23 7842.87 89.67 289.47 4137.50 ---------- / ---- ---- MPS.17 T6 24 8359.98 89.67 289.47 4140.50 M:>S.717------- ~ MrS.7T5 Ene DiI : 7335.36' MD, 4127.81' ~VD~ ------ ~ Rnd Dir : 6034.27' MD, 4206.49' TVD Start Dir4/IOO, : 72IU3'MJ),4 30.63'TVD ......,~ ~ StartDir4/100': 6017.78' MD,4207.59'TVD Ene Dj¡ : 672794' MD, 4152.5' TVD ~ ------ 7------ Ene. Dir : 5624.87' MD, 4235.31' TVD Start Dir 4/100' : 6712.ü3' MC, 4163.HTVD -----------. ~ & Start Dir 4/100' : 5495.72' MD, 4245.5'TVD Start Dir 10/100': 5276.98' MD, 4265.42'TVD MPS-17 T4 M:>S ~ ~nd Dir : 5250.12' MD, 4267.91' TVD - MJlè-I4--T2. Star. Di~ 12/100': 5194.47' MD, 4270.5'TVD 75/8" .~ .~ ~~ . '~~/ .~ co '-..../ ~ #'I1tt, <-In" 700 All TVD depths are ssTVD plus 66.5'for RKBE. I I I I I I I I I I I I I I I I I I I Slall Dir 4/100' : 4709.45' MD, 4189.I7'TVD Ene Dir : 4609.45' MD, 4155.95' TVD Start Dir 4/100' : 3676.42' MD, 3592.55'TVD Enj Dir : 3519.51' MD, 3461.92' TVD Plan: MPS.l7 wp04 (Plan MPS.17/Plan MPS.17) Cœated By: Ken Allen Date: 8115/2002 Reviewed: Date: .----- Date: ---- WELL DETAILS +EI-W Easting Longitude Slot Northing Latitude 565844.98 70'24'37.420N 149'2T49.826W NiA TARGET DETAILS TVD +EJ.W EaSling Shape 562770.00 Poinl 562252.00 Point 561763.00 Point 563325.00 PoiUI 564729.00 Polygon 563994.00 Poiut 564510.00 Point 564754.00 Point Northin8 6001896.00 6002040.00 6002208.00 ..6001742.00 6001208.00 6001564.00 6001416.00 .6001246.00 +Nt.S 4127.50 1940.38. .3058.28 4137.50 2088.95 .3575.04 4140.5TF""2261.27 .4062.59 4162.50 1781.48 .2504.61 416650 1235.Q7 .1105.24 420650 1597.57 .1837.14 424550 1445.01 .1322.42 427050 1272.85 .1079.90 TVD SECTION.J;1ET AILS +N/-S +E/-W DLeg TFaee VSee Target 0.00 0.00 0.00 0.00 1).00 0.00 0.00 0.00 1>.00 ').00 235.17 -171.09 3.30 0.00 .',.1.87 .~ 305.47 -222.23 0.00 0.00 Q.:.74 855.89 -691.08 4.00 -10.87 1".'11.10 924.87 -755.41 0.00 0.00 11"'1.86 1030.06 -853.50 4.00 0.00 I :~';.73 1272.85 -1079.90 4.00 0.00 1.".~.63 MPS.17 T2 1312.13 -1119.20 12.00 -37.08 1',I.i.07 1330.35 -1138.77 0.00 0.00 I '.~_~.04 1445.01 .1322.42 10.00 -89.84 ,~. ~.26 MPS.17 T3 1485.75 -1444.51 4.00 -100.45 '''Q.75 1593.17 -1821.43 0.00 0.00 .' ",'i.33 1597.57 -1837.14 4.00 -129.35 : 1~.~.21 MPS.17T4 1597.60 -1837.27 4.00 -28.17 .' '~~.33 1777.20 -2489.39 0.00 0.00 '" ").48 1781.48 -2504.61 4.00 75.79 ¡"...t86 MPS.17 T5 1781.49 -2504.67 4.00 152.25 IIJ~.j..92 1914.28 -2967.33 0.00 0.00 ,'.' 1.76 1940.38 -3058.28 4.00 -179.78 \',1 'Í.92 MPS-17 T6 1948.66 -3087.47 4.00 -165.35 id'Í.45 2059.78 -3482.96 0.00 0.00 ~"h.06 2088.95 -3575.04 4.00 77.45 :¡ 11'1.71 MPS.17 T7 2261.27 -4062.59 0.00 0.00 :¡~:¡:J.52 MPS-17 T8 FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 1750.00 1750.00 BPRF 2 3586.50 3669.15 T Ugnu,,"" 3 41 10.50 4487.19 NA 4 4129.50 4535.22 NB 5 4153.50 4602.13 NC 6 4165.50 4638.20 NE ~ 7 4207.50 4768.06 NF 8 4231.50 4859.45 OA 9 4251.50 4960.90 BaseOA 10 4270.49 5189.11 OB Star. Dir 3.3/100': 2500' MD, 2500'TVD .4200 .3500 -2800 .2100 -1400 West( - )/East( +) [700ft/in] -700 I 700 ) BP My Planning Report MAP ) Company: Field: Site: Well: Wellpath: Field: BP Amoco Milne Point M Pt SPad Plan MPS-17 Plan MPS-17 Date: 8/15/2002 Time:.. 07:05:22 Page: Co,.ørdinate(NE) Reference: Well: Plan MPS-17, True North Vertical (fVQ) Reference: RB 66.50 66.5 Section(VS) Referénce: Well (0.00N,O.00E.299.10Azi) . Survey Calculati9D'Method: Minimum Curvature Db: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: M Pt S Pad Site Position: From: Map Position Uncertainty: Ground Level: Northing: 5999978.00 ft Easting: 566345.00 ft Latitude: Longitude: North Reference: Grid Convergence: 0.00 ft 0.00 ft Well: Plan MPS-17 Slot Name: +N/-S 9.28 ft Northing: 5999982.84 ft +E/-W -500.00 ,ft Easting: 565844.98 ft Position Uncertainty: 0.00 ft Well Position: Latitude: Longitude: Wellpath: Plan MPS-17 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: RB 66.50 6/29/2001 57481 nT Depth From (TVD) ft 0.00 Height 66.50 ft +N/-S ft 0.00 Plan: MPS-17 wp04 Date Composed: Version: Tied-to: Principal: Yes Casing Points Oracle Alaska, Zone 4 Well Centre BGGM2002 70 24 37.329 N 149 27 35.171 W True 0.51 deg 70 24 37.420 N 149 27 49.826 W Well Ref. Point 0.00 ft Mean Sea Level 26.21 deg 80.79 deg Direction deg 299.10 8/15/2002 10 From Well Ref. Point MD Diameter Hole Size Name ft in 5189.11 4270.49 7.000 9.875 75/8" 8359.97 4140.50 4.500 6.125 4 1/2" Formations MD Lithology DipA~gle Dip DireCtion. ft d~g deg 1750.00 1750.00 BPRF 0.00 0.00 3669.15 3586.50 T Ugnu 0.00 0.00 4487.19 4110.50 NA 0.00 0.00 4535.22 4129.50 NB 0.00 0.00 4602.13 4153.50 NC 0.00 0.00 4638.20 4165.50 NE 0.00 0.00 4768.06 4207.50 NF 0.00 0.00 4859.45 4231 .50 OA 0.00 0.00 4960.90 4251.50 Base OA 0.00 0.00 5189.11 4270.49 OB 0.00 0.00 Targets Map Map <- Latitude, -> <--Longkude--> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min. Sec Dip. Dir. ft ft ft ft ft MPS-17 T6 4127.50 1940.38 -3058.28 6001896.00 562770.00 70 24 56.497 N 149 29 19.490 W MPS-17 T7 4137.50 2088.95 -3575.04 6002040.00 562252.00 70 24 57.956 N 149 29 34.642 W MPS-17 T8 4140.50 2261.27 -4062.59 6002208.00 561763.00 70 24 59.648 N 149 2948.940 W ) Company: BP Amoco Field: Milne Point Site: M Pt S Pad Well: Plan MPS-17 Wellpath: Plan MPS-17 Targets BP My Planning Report MAP l ') Date: 8/15/2002 Time: 07:05:22 Page: Co-ordinate(NE) Reference: Well: Plan MPS-17, True North Vertical (fVD) Reference: RB 66.5066.5 Section (VS) Reference: Well (0.00N,0.00E,299.1 OAzi) Survey Calculation Method: Minimum Curvature Db: Oracle 2 Dès~tipti()n D~p. Dir. MPS-17 T5 4162.50 4166.50 4166.50 4166.50 4166.50 4166.50 4166.50 4166.50 MPS-17 Poly -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 MPS-17 T4 4206.50 MPS-17 T3 4245.50 MPS-17 T2 4270.50 1781.48 -2504.61 6001742.00 563325.00 70 24 54.936 N 149 29 3.256 W 1316.16 -1454.57 6001286.00 564379.00 70 24 50.363 N 149 28 32.468 W 1235.07 -1105.24 6001208.00 564729.00 70 24 49.566 N 149 28 22.227 W 1482.66 -941.04 6001457.00 564891.00 70 24 52.001 N 149 28 17.414 W 1612.03 -1434.96 6001582.00 564396.00 70 24 53.272 N 149 28 31.895 W 2382.82 -4122.53 6002329.00 561702.00 70 25 0.843 N 149 29 50.699 W 2101.81 -4125.00 6002048.00 561702.00 70 24 58.079 N 149 29 50.767 W 1316.16 -1454.57 6001286.00 564379.00 70 24 50.363 N 149 28 32.468 W 1597.57 -1837.14 6001564.00 563994.00 70 24 53.129 N 149 28 43.686 W 1445.01 -1322.42 6001416.00 564510.00 70 24 51.630 N 149 28 28.595 W 1272.85 -1079.90 6001246.00 564754.00 70 24 49.937 N 149 28 21.484 W Plan Section Information MD Incl Azim +E/-W OLS Build Turn l'FO Target ft deg deg ft deg/1 OOft deg/10()ffd~gf100ft dég 27.60 0.00 0.00 27.60 0.00 0.00 0.00 0.00 0.00 0.00 2500.00 0.00 0.00 2500.00 0.00 0.00 0.00 0.00 0.00 0.00 3519.51 33.64 323.96 3461.92 235.17 -171.09 3.30 3.30 0.00 0.00 3676.42 33.64 323.96 3592.55 305.47 -222.23 0.00 0.00 0.00 0.00 4609.45 70.60 317.00 4155.95 855.89 -691.08 4.00 3.96 -0.75 -10.87 4709.45 70.60 317.00 4189.17 924.87 -755.41 0.00 0.00 0.00 0.00 4859.45 76.60 317.00 4231.50 1030.06 -853.50 4.00 4.00 0.00 0.00 5194.47 90.00 317.00 4270.50 1272.85 -1079.90 4.00 4.00 0.00 0.00 MPS-17 T2 5250.12 95.32 312.96 4267.91 1312.13 -1119.20 12.00 9.57 -7.26 -37.08 5276.98 95.32 312.96 4265.42 1330.35 -1138.77 0.00 0.00 0.00 0.00 5495.72 95.00 291.00 4245.50 1445.01 -1322.42 10.00 -0.15 -10.04 -89.84 MPS-17 T3 5624.87 94.04 285.91 4235.31 1485.75 -1444.51 4.00 -0.74 -3.94 -100.45 6017.78 94.04 285.91 4207.59 1593.17 -1821.43 0.00 0.00 0.00 0.00 6034.13 93.63 . 285.40 4206.50 1597.57 -1837.14 4.00 -2.54 -3.10 -129.35 MPS-17 T4 6034.27 93.63 285.40 4206.49 1597.60 -1837.27 4.00 3.53 -1.89 -28.17 6712.03 93.63 285.40 4163.53 1777 .20 -2489.39 0.00 0.00 0.00 0.00 6727.87 93.79 286.01 4162.50 1781.48 -2504.61 4.00 0.98 3.89 75.79 MPS-17 T5 6727.94 93.79 286.01 4162.50 1781.49 -2504.67 4.00 -3.54 1.87 152.25 7210.33 93.79 286.01 4130.63 1914.28 -2967.33 0.00 0.00 0.00 0.00 7305.02 90.00 286.00 4127.50 1940.38 -3058.28 4.00 -4.00 -0.02 -179.78 MPS-17 T6 7335.36 88.83 285.69 4127.81 1948.66 -3087.47 4.00 -3.87 -1.01 -165.35 7746.25 88.83 285.69 4136.23 2059.78 -3482.96 0.00 0.00 0.00 0.00 7842.87 89.67 289.47 4137.50 2088.95 -3575.04 4.00 0.87 3.90 77.45 MPS-17 T7 8359.98 89.67 289.47 4140.50 2261.27 -4062.59 0.00 0.00 0.00 0.00 MPS-17 T8 Survey MD Incl Azim TVD Sys TVD MapN MapE VS OLS Tool/Comment ft deg deg ft ft ft ft ft deg/1 000 27.60 0.00 0.00 27.60 -38.90 5999982.84 565844.98 0.00 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 33.50 5999982.84 565844.98 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 133.50 5999982.84 565844.98 0.00 0.00 CB-GYRO-SS 300.00 0.00 0.00 300.00 233.50 5999982.84 565844.98 0.00 0.00 CB-GYRO-SS 400.00 0.00 0.00 400.00 333.50 5999982.84 565844.98 0.00 0.00 CB-GYRO-SS 500.00 0.00 0.00 500.00 433.50 5999982.84 565844.98 0.00 0.00 CB-GYRO-SS 600.00 0.00 0.00 600.00 533.50 5999982.84 565844.98 0.00 0.00 CB-GYRO-SS 700.00 0.00 0.00 700.00 633.50 5999982.84 565844.98 0.00 0.00 CB-GYRO-SS 800.00 0.00 0.00 800.00 733.50 5999982.84 565844.98 0.00 0.00 CB-GYRO-SS 900.00 0.00 0.00 900.00 833.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS 1000.00 0.00 0.00 1000.00 933.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS ) ) BP t My Planning Report MAP Cølllpany: BPAnioco FiêJd: Milne Point Site: M>PfSPad WeU: Plan MPS-17 Well (0.00N.0.00E,299.1 OAzi) Wellpath: PlånMPS-17 Minimum Curvature Db: Oracle Survey 1100.00 0.00 0.00 1100.00 1033.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS 1200.00 0.00 0.00 1200.00 1133.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS 1300.00 0.00 0.00 1300.00 1233.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS 1400.00 0.00 0.00 1400.00 1333.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS 1500.00 0.00 0.00 1500.00 1433.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS 1600.00 0.00 0.00 1600.00 1533.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS 1700.00 0.00 0.00 1700.00 1633.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS 1750.00 0.00 0.00 1750.00 1683.50 5999982.84 565844.98 0.00 0.00 BPRF 1800.00 0.00 0.00 1800.00 1733.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS 1900.00 0.00 0.00 1900.00 1833.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS 2000.00 0.00 0.00 2000.00 1933.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS 2100.00 0.00 0.00 2100.00 2033.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS 2200.00 0.00 0.00 2200.00 2133.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS 2300.00 0.00 0.00 2300.00 2233.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS 2400.00 0.00 0.00 2400.00 2333.50 5999982.84 565844.98 0.00 0.00 MWD+IFR+MS 2500.00 0.00 0.00 2500.00 2433.50 5999982.84 565844.98 0.00 0.00 Start Dir 3.3/100' : 2500' MD, 2600.00 3.30 323.96 2599.94 2533.44 5999985.15 565843.27 2.61 3.30 MWD+IFR+MS 2700.00 6.60 323.96 2699.56 2633.06 5999992.08 565838.13 10.44 3.30 MWD+IFR+MS 2800.00 9.90 323.96 2798.51 2732.01 6000003.61 565829.59 23.46 3.30 MWD+IFR+MS 2900.00 13.20 323.96 2896.47 2829.97 6000019.69 565817.67 41.62 3.30 MWD+IFR+MS 3000.00 16.50 323.96 2993.12 2926.62 6000040.28 565802.41 64.87 3.30 MWD+IFR+MS 3100.00 19.80 323.96 3088.13 3021.63 6000065.30 565783.87 93.13 3.30 MWD+IFR+MS 3200.00 23.10 323.96 3181.19 3114.69 6000094.67 565762.10 126.31 3.30 MWD+IFR+MS 3300.00 26.40 323.96 3271.99 3205.49 6000128.30 565737.18 164.29 3.30 MWD+IFR+MS 3400.00 29.70 323.96 3360.23 3293.73 6000166.07 565709.19 206.95 3.30 MWD+IFR+MS 3500.00 33.00 323.96 3445.62 3379.12 6000207.86 565678.22 254.15 3.30 MWD+IFR+MS 3519.51 33.64 323.96 3461.92 3395.42 6000216.47 565671.84 263.87 3.30 End Dir : 3519.51' MD, 3461.9 3600.00 33.64 323.96 3528.93 3462.43 6000252.30 565645.29 304.33 0.00 MWD+IFR+MS 3669.15 33.64 323.96 3586.50 3520.00 6000283.07 565622.48 339.09 0.00 T Ugnu 3676.42 33.64 323.96 3592.55 3526.05 6000286.31 565620.08 342.74 0.00 Start Dir 4/100' : 3676.42' MD 3700.00 34.57 323.65 3612.08 3545.58 6000296.91 565612.18 354.76 4.00 MWD+IFR+MS 3800.00 38.51 322.47 3692.41 3625.91 6000344.14 565575.97 409.16 4.00 MWD+IFR+MS 3900.00 42.46 321.4 7 3768.45 3701.95 6000394.90 565535.52 468.98 4.00 MWD+IFR+MS 4000.00 46.41 320.62 3839.84 3773.34 6000448.92 565491.03 533.90 4.00 MWD+IFR+MS 4100.00 50.37 319.87 3906.24 3839.74 6000505.95 565442.71 603.63 4.00 MWD+IFR+MS 4200.00 54.34 319.20 3967.30 3900.80 6000565.71 565390.81 677.82 4.00 MWD+IFR+MS 4300.00 58.31 318.60 4022.74 3956.24 6000627.91 565335.56 756.10 4.00 MWD+IFR+MS 4400.00 62.28 318.04 4072.29 4005.79 6000692.25 565277.25 838.10 4.00 MWD+IFR+MS 4487.19 65.74 317 .59 4110.50 4044.00 6000749.84 565224.13 912.31 4.00 NA 4500.00 66.25 317.53 4115.71 4049.21 6000758.41 565216.15 923.41 4.00 MWD+IFR+MS 4535.22 67.65 317.36 4129.50 4063.00 6000782.08 565194.03 954.17 4.00 NB 4602.13 70.31 317.03 4153.50 4087.00 6000827.52 565151.19 1013.54 4.00 NC 4609.45 70.60 317.00 4155.95 4089.45 6000832.52 565146.45 1020.10 4.00 End Dir : 4609.45' MD, 4155.9 4638.20 70.60 317.00 4165.50 4099.00 6000852.19 565127.78 1045.91 0.00 NE 4641.21 70.60 317.00 4166.50 4100.00 6000854.25 565125.82 1048.61 0.00 MPS-17 Poly 4709.45 70.60 317.00 4189.17 4122.67 6000900.93 565081.52 1109.86 0.00 Start Dir 4/100' : 4709.45' MD 4768.06 72.94 317.00 4207.50 4141.00 6000941.30 565043.20 1162.83 4.00 NF 4800.00 74.22 317.00 4216.53 4150.03 6000963.52 565022.11 1191.98 4.00 MWD+IFR+MS 4859.45 76.60 317.00 4231.50 4165.00 6001005.24 564982.51 1246.73 4.00 OA 4900.00 78.22 317.00 4240.34 4173.84 6001033.94 564955.27 1284.39 4.00 MWD+IFR+MS 4960.90 80.66 317.00 4251.50 4185.00 6001077.36 564914.06 1341.35 4.00 Base OA 5000.00 82.22 317.00 4257.32 4190.82 6001105.40 564ß87.45 1378.14 4.00 MWD+IFR+MS 5100.00 86.22 317.00 4267.39 4200.89 6001177.54 564318.98 1472.80 4.00 MWD+IFR+MS ) ) BP My Planning Report MApt c:;ompany: BPArnoco Date:.. .8/15/2002 Thne: 07:05:22 Page: Fiêld: Milni:rPoint q~1>r<Jinat«NE)..'Refêr~q~: W~II:Plân MPS..17,Ttu~ NQrth Site: MPtSPad VertiCål(TVD) Reference: RB66.50 66.5 Well: Plan MPS-17 Section (VS) Reference: Well (0.00N,O.00E,299.1 OAzi) Wellpath: Plan MPS-17 Survey Calculation Method: Minimum Curvature Db: Oracle Survey loci Azim TVD Sys TVD MapN MapE VS DLS Tool/Comment deg deg ft ft ft ft ft deg/1 000 89.79 317.00 4270.49 4203.99 6001242.12 564757.68 1557.54 4.00 75/8" 5194.47 90.00 317.00 4270.'50 4204.00 6001246.00 564754.00 1562.63 4.00 MPS-17 T2 5200.00 90.53 316.60 4270.47 4203.97 6001250.00 564750.18 1567.90 12.00 MWD+IFR+MS 5225.00 92.92 314.79 4269.72 4203.22 6001267.72 564732.57 1591.85 12.00 MWD+IFR+MS 5250.12 95.32 312.96 4267.91 4201.41 6001284.93 564714.36 1616.07 12.00 End Dir : 5250.12' MD, 4267.9 5276.98 95.32 312.96 4265.42 4198.92 6001302.98 564694.63 1642.04 0.00 Start Dir 10/100' : 5276.98' M 5300.00 95.33 310.65 4263.29 4196.79 6001318.10 564677.41 1664.39 10.00 MWD+IFR+MS 5350.00 95.30 305.63 4258.65 4192.15 6001348.49 564638.00 1713.54 10.00 MWD+IFR+MS 5400.00 95.24 300.61 4254.06 4187.56 6001375.31 564596.08 1763.19 10.00 MWD+IFR+MS 5450.00 95.13 295.59 4249.54 4183.04 6001398.37 564551.97 1812.97 10.00 MWD+IFR+MS 5495.72 95.00 291.00 4245.50 4179.00 6001416.00 564510.00 1858.26 10.00 MPS-17 T3 5500.00 94.97 290.83 4245.13 4178.63 6001417.49 564506.00 1862.48 4.00 MWD+IFR+MS 5600.00 94.23 286.89 4237.10 4170.60 6001448.86 564411.42 1960.55 4.00 MWD+IFR+MS 5624.87 94.04 285.91 4235.31 4168.81 6001455.65 564387.57 1984.75 4.00 End Dir : 5624.87' MD, 4235.3 5700.00 94.04 285.91 4230.01 4163.51 6001475.56 564315.32 2057.71 0.00 MWD+IFR+MS 5800.00 94.04 285.91 4222.96 4156.46 6001502.05 564219.16 2154.83 0.00 MWD+IFR+MS 5900.00 94.04 285.91 4215.90 4149.40 6001528.54 564123.01 2251.95 0.00 MWD+IFR+MS 6000.00 94.04 285.91 4208.85 4142.35 6001555.03 564026.85 2349.07 0.00 MWD+IFR+MS 6017.78 94.04 285.91 4207.59 4141.09 6001559.74 564009.75 2366.33 0.00 Start Dir 4/100' : 6017.78' MD 6034.13 93.63 285.40 4206.50 4140.00 6001564.00 563994.00 2382.21 4.00 MPS-17 T4 6034.27 93.63 285.40 4206.49 4139.99 6001564.03 563993.87 2382.33 4.00 End Dir : 6034.27' MD, 4206.4 6100.00 93.63 285.40 4202.32 4135.82 6001580.89 563930.48 2446.07 0.00 MWD+IFR+MS 6200.00 93.63 285.40 4195.99 4129.49 6001606.54 563834.04 2543.03 0.00 MWD+IFR+MS 6300.00 93.63 285.40 4189.65 4123.15 6001632.18 563737.61 2639.98 0.00 MWD+IFR+MS 6400.00 93.63 285.40 4183.31 4116.81 6001657.83 563641.17 2736.94 0.00 MWD+IFR+MS 6500.00 93.63 285.40 4176.97 4110.47 6001683.48 563544.73 2833.90 0.00 MWD+IFR+MS 6600.00 93.63 285.40 4170.63 4104.13 6001709.12 563448.29 2930.86 0.00 MWD+IFR+MS 6700.00 93.63 285.40 4164.29 4097.79 6001734.77 563351.86 3027.82 0.00 MWD+IFR+MS 6712.03 93.63 285.40 4163.53 4097.03 6001737.85 563340.26 3039.48 0.00 Start Dir 4/100' : 6712.03' MD 6727.87 93.79 286.01 4162.50 4096.00 6001742.00 563325.00 3054.86 4.00 MPS-17 T5 6727.94 93.79 286.01 4162.50 4096.00 6001742.02 563324.94 3054.92 4.00 End Dir : 6727.94' MD, 4162.5 6800.00 93.79 286.01 4157.74 4091.24 6001761.24 563255.66 3124.96 0.00 MWD+IFR+MS 6900.00 93.79 286.01 4151.13 4084.63 6001787.92 563159.52 3222.15 0.00 MWD+IFR+MS 7000.00 93.79 286.01 4144.52 4078.02 6001814.60 563063.38 3319.34 0.00 MWD+IFR+MS 7100.00 93.79 286.01 4137.92 4071.42 6001841.28 562967.24 3416.53 0.00 MWD+IFR+MS 7200.00 93.79 286.01 4131.31 4064.81 6001867.96 562871.10 3513.72 0.00 MWD+IFR+MS 7210.33 93.79 286.01 4130.63 4064.13 6001870.71 562861.17 3523.76 0.00 Start Dir 4/100' : 7210.33' MD 7305.02 90.00 286.00 4127.50 4061.00 6001896.00 562770.00 3615.92 4.00 MPS-17 T6 7335.36 88.83 285.69 4127.81 4061.31 6001904.02 562740.75 3645.45 4.00 End Dir : 7335.36' MD, 4127.8 7400.00 88.83 285.69 4129.14 4062.64 6001920.95 562678.38 3708.32 0.00 MWD+IFR+MS 7500.00 88.83 285.69 4131.18 4064.68 6001947.14 562581.90 3805.57 0.00 MWD+IFR+MS 7600.00 88.83 285.69 4133.23 4066.73 6001973.34 562485.43 3902.82 0.00 MWD+IFR+MS 7700.00 88.83 285.69 4135.28 4068.78 6001999.53 562388.95 4000.08 0.00 MWD+IFR+MS 7746.25 88.83 285.69 4136.23 4069.73 6002011.64 562344.33 4045.06 0.00 Start Dir 4/100' : 7746.25' MD 7800.00 89.29 287.79 4137.11 4070.61 6002026.66 562292.74 4097.55 4.00 MWD+IFR+MS 7842.87 89.67 289.47 4137.50 4071.00 6002040.00 562252.00 4139.71 4.00 MPS-17 T7 7900.00 89.67 289.47 4137.83 4071.33 6002058.56 562197.98 4196.03 0.00 MWD+IFR+MS 8000.00 89.67 289.47 4138.41 4071.91 6002091.05 562103.41 4294.62 0.00 MWD+IFR+MS 8100.00 89.67 289.47 4138.99 4072.49 6002123.53 562008.85 4393.20 0.00 MWD+IFR+MS 8200.00 89.67 289.47 4139.57 4073.07 6002156.02 561914.29 4491.79 0.00 MWD+IFR+MS 8300.00 89.67 289.47 4140.15 4073.65 6002188.51 561819.72 4590.38 0.00 MWD+IFR+MS 8359.97.: 89.67 289.4 7 4140.50 4074.00 6002207.99 561763.01 4649.50 0.00 41/2" Company: BP Amoco Fiêld: Milne Point Site: M Pt S Pad Well: Plan MPS-17 Wellpath: Plan MPS-17 Survey MD Inel Azim ft deg deg 8359.98 89.67 289.47 ') ) BP ~ My Planning Report MAP Date: 8/15/2002 Time: 07:05:22 Page: Co-ordim\te(NE) Referênce: Well:. Plan MPS;'17, True North Vertical (TVD) Reference: RB 66,5066.5 Section(VS) Reference: Well (0.OON,0.00E,299.10Azi) Suryey Calculati(JD Method: Mh1imumCurvature Db: 5 Oracle TVD Sys TVD MapN ft ft ft 4140.50 4074.00 6002208.00 MapE VS DLS ft ft deg/10OO 561763.00 4649.52 0.00 MPS-17 T8 Tool/Comment ANTI-COLLISION SETTINGS WELL DETAILS N3m~ . Nf.S -['.I.W Northing Easting Latitude I.(tllginuk Slot Plan MPS.17 9.28 -500.00 ,999982.84 56,844.98 70024'~7.420N 149'27'49.826W NA -64 -60 -so -40 -30 -20 -10 -0 -10 Interpolation Method:MD Interval: 25.00 Depth Range From: 27.60 To: 8359.98 Maximum Range: 1033.24 Reference: Plan: MPS-17 wp04 ê' ~ 30 fg t:; ,!? & ~ r)¡ fg g t:J., 270. ~)J#f!# / ~ Plan MPS-17Ll plotted with "no errors" for clarity. - 18&4 COMPANY DETAILS BP Amoco Calculation Mcthod: Minimum Curvature Error System: ISCWSA Sean Method: Tmv Cylindor North Error Surface: Elliptical + Casing Waming Method: Ru~es Based Colour ~---~~' ...... ' - n. ---- ~ , I See MD 1 27.60 0.00 0.00 2 2500.00 0.00 0.00 3 3519.51 33.64 323.96 4 3676.42 33.64 323.96 5 4609.45 70.60 317.00 6 4709.45 70.60 317.00 7 4859.45 76.60 317.00 8 5194.47 90.00 317.00 9 5250.12 95.32 312.96 10 5276.98 95.32 312.96 11 5495.72 95.00 291.00 12 5624.87 94.04 285.91 13 6017.78 94.04 285.91 14 6034.13 93.63 285.40 15 6034.27 93.63 285.40 16 6712.Q3 93.63 285.40 17 6727.87 9~.79 286.01 18 6727.94 93.79 286.01 19 7210.33 93.79 286.01 20 7305.02 90.00 286.00 21 7335.36 88.83 285.69 22 7746.25 88.83 285.69 23 7842.87 89.67 289.47 24 8359.98 89.67 289.47 TråvelIing Cylinder Azimtith (TFO-f-AZI) [deg] vs Centre to Centre¡Seþaration [20ft/in] Depth I'm Depth To SurveyiPlan 27.60 900.00 Planned: MPS.17 wp04 V 10 900.00 8359.98 Planned: MPS-17 wp04 Vl0 SURVEY PROGRAM ToMD 300 600 900 1200 1500 2000 2500 3000 . 3500 4000 4500 5000 6000 8000 . 11 000 12000 15000 Inc Azi TVD ""'.'1 """'I 'Jcl'" JIIr."JI H I) ,) .J. -II J ". ~'J J ,,, "1 ..". .J.j ..II" I -II.. 'I -II. "'I -III", I JI" '1 Rig: Ref. Datum: V .Section Angle 299.10" Tool CB.(JYRO.SS MWD+IFR+MS WELLPA HI DEI AILS Plan MPS.17 RB 66.50 66.50ft Starting From TVD Origin +N/-S 0.00 Origin +fj-W 0.00 0.00 LEGEND - MPS-II\ I~H"~ '1\ M\\:11I1K MS}.MajorRisk - MPS '" Ik,t Mi"~II~1 1'-1'1"1 R.isk - MPS II'" I~H':-- "'1. M.JI"r ,.~, k -- MPS-"". l~ti".I,c,,1 II ~1.JI'" J',sk - MPS-''''' I~H'~ ""I"~III M"I'" Risk - MPS.1I7 1~1I" 1171. Mi.'I,.r k...k - MPS..frJlf\.'¡-:---II'II.MJI",I{...k -- MPS II t~H.~. II Moll'" K'.k - MPS'.\I~H~ 1\1 Mil'" k.,k - MPS.ICiIMi-:-- 1""1 MJI'" k,.k - MPS:I IPl.H'~ ~II M'JI"" ih.k - MPS ~\ 1~1i"' :' ~I "",I'" k...k - MPS:\IMI',.~llll MI'" .'isk - MPS.:"" 1I.n", :'"1 M.'I"¡ Jld - MPS ::"'tMI-~..'(,L II M.J!'" .~isk .- MPS.'7 IMi~ a'71 M.JI'" ih." ~ MPS :7IMI":'ro:"LII M.ol'" '(!sk - MPS.:' tMi'~ :'7"IU I. M_or'" Risk - MPS II 1M r-:--. 1 I I Mi.'I"1 K..." - Plan MJ":'I-uIIJ'wrl MJ",.IIII. "'1.JI'" kh" - Plan Mi~ II.' li"L.lfl ~H" 11.'1. M.JI"I k',-." - Plan ~U.'''..:s li'l.rrl fl., 1"'-1 a..¡ , M.tl'''' il,." - Plan fl.U":--.l".li"l.J[' p¡,,(-~ 111'1. M"I"r rl.." - Plan Mi-:--.-I'I\ I "Lil' MI".J.r.II.1 M.II'" k', k - Planfl.U":-- IlIli'I",~1i-:-- 1111 M_'I'-' il,.k ~-".-~-- Plan fl.H":-- I~ d'!.:Irl M" 1.'1 M.JI"" ~~I-k - PlanM¡"". 1.2 d"lll¡Mt"";; 1.:11. M""I"1 Ñ', '" - PlanMr'.lt.li'LI'Ip¡,'T'~ It". M"'I.1I (l...k -- Plan Mt.~ 17 (l'li.tf, p¡,n-~ 17L 11. N'-'f i:kORS - Plan Mi', I~ t['L'1I Mi,:" 1"'1. M"I'" J.l.... - Plan ~H"~ IIJ Ii'lim Mi~.I'JI. M.JI""I fl,.." - Pbm MI-:-- ~LlIJ'L.J1I M.'~.:'III. M.JI' '" RI". - Plan M~"='.~' Tn I:J'Ir"L,[, MI~,"II'1I. Major Risk - Plan Mi" ¡ 1Ir,.L;..IIJ'wrl f\.U'" ~'Tr, Lil Ll}MajorF - Plan Mr",.:, I In.L.1I (i"L.r¡ Mr", :"Tr, Lil £..2), MajorF! Plan M~":'I :.,:¡: IPldrl M(~'~'¡I. M~I'" ft'..... - Plan f\.H"~.':f'IJ"L,n MT"' ~r'J. M.JI""1I RJ..k - Plan fl.n-:, ~Oj li'L.tI, M';r.. '::01:1. M/II~" R..',k Plan Mi-S ~., Il'Lin Mi'~. ~ul" Mal'" HJ.k - PIanMi~ 111 I ['J...,r, MI;r...UII. M.JI'''' R,..k - Plan M.~ '~IHt-lr Mr~.("I. M""I'" k,.~ - PlanMi'~ HIl'L:.nMi~ ,~ M'l'" .tI.... - Plan Mi'~ 1.:1 ¡['L.rl ..U"~ 1.1, "h"1 kJ..~ - Plan Mi':' I' - - MPSI7v.pl¡J SECTION DETAILS +N!~S +EI.W DLeg TFace ~ (/) -20 ~ -30 24a -40 -SO --60 -64 0.00 0.00 235.17 305.47 855.89 924.87 1030.06 1272.8, 1312.13 1330.35 1445.01 1485.75 1593.17 159757 1597.60 1777.20 1781.48 1781.49 1914.28 1940.38 1948.66 2059.78 2088.95 2261.27 0.00 0.00 0.00 0.00 3.30 0.00 0.00 0.00 4.00 .10.87 0.00 0.00 4.00 0.00 4.00 0.00 12.00 .37.08 0.00 0.00 10.00 -89.84 4.00 -100.45 0.00 0.00 4.00 .12935 4.00 .28.17 0.00 0.00 4.00 75.79 4.00 15215 0.00 0.00 4.00 -179.78 4.00 .16535 0.00 0.00 4.00 77.45 0.00 0.00 0.00 0.00 .171.09 -22213 -691.08 -755.41 -853.50 -1079.90 -1119.20 -1138.77 -1322.42 .144451 .1821.43 .1837.14 -1837.27 .248939 -2504.61 .2504.67 -2967.33 .3058.28 -3087.47 .3482.96 .3575.04 -406259 ..~ ~ VSee Target 0.00 0.00 263.87 342.74 1020.10 1109.86 1246.73 1562.63 MPS-17 T2 1616.07 1642.04 185816 MPS.17 T3 1984.75 236633 238211 MPS-17 T4 238233 3039.48 3054.86 MPS. 1 7 15 3054.92 3523.76 3615.92 Mps.17 T6 3645.45 4045.06 4139.71 Mps.17 T7 464952 MPS.17T8 Name -+.N/.s 'E/.W Plan MPS. \1 9.28 .500,00 5999982.84 100 l=~~~' )/ . F..== .- .."'.~- ~"'î: = #- : = I 90 80 J 'C~- ,......., .S --- c:::: 0 ~ ¡::: .9 ~ ro $-< ro 0.. (]) VJ ~ +-' ¡::: (]) u B 70 J .,1 60 - l' 11"111-- - -- JU 50 40 f j. ., j . .i ;/ ~ +-' ¡::: (]) U 30 ./ ~ WELL DETAILS Northing Easting Latinl~ Longilud.> Slot 565844.98 70'24'37.420N 149'27'49.826W jlt~ l' ') !)q:<:::/c%~ 0.-. .t-t\[ag::: ~r/G-:~'&-:-arrX 20 = j .,9 10 0 1000 -\...----.......,..' -.........,.- rl._' '--~_rI""'_- ""fr- !--1y~/~1~-~-"-¡"-'''''-\~ ,...~-".......------Æ 4000 0 2000 3000 ANTI-COLLISION SETTINGS COMPANY DETAILS SURVEY PROGRAM BP Amoco Depth Fill Depth To Surwy/Plan Tool NfA Interpolation Method:MD Interval: 25.00 Depth Range From: 27.60 To: 8359.98 Maximum Range: 1033.24 Reference: Plan: MPS-17 wp04 CB-GYRO.SS MWD+IFR-MS ~I ,. .. fI 5000 6000 Calculation Method: Minimum Curvature Error System: ISCWSA S¡;,sn Method: Trav Cylh~r North Error Surtàce: EUiptica1 + Casing Waming Method: Rules n....", 27.60 900.00 900.00 Planned: MPS.17 wp04 VIO 8359.98 Planned: MPS.17 wp04 VIO WELLPATH DETAILS Plan Mps. \1 Rig: Re( Datum: RB 6650 6650fi V'section Angle 299.10' Origin +N.'.S 0.00 Origin tEJ.W Starting From TVD 0.00 0.00 , Interference estimated down . to -900' MD. This was discussed in the COVE planning session and a Photo Gyro was planned. LEGEND - MPS.03(MPS.o3 MWjLli R.~t'I, Mll'lrRisk - MPS.03 (Rig MPS."', ~1..,., k.., - MPS.05 (MPS-05). M ".. Ft,., -- MPS.05(MPS.Q5LII Ma¡"1 kl..]. - MPS.05 (MPS.o~Pf'II, f\t'JJ. 'I k I'~ - MPS.o7(MPS.o7),M.I"'1 UI"o - MPS-09 (MPS-09), M.,.., ¡'''' - MPS.II (MPS.II). Mu,-. I<..k MPS.13 (MPS.13). M""" ~". - Mps.15 (MPS.15), M.,,,, k". - Mps.21 (MPS.21), "1.,,,, ~,... - Mps.23 (MPS.23). "1w' "",.. - Mps.23 (MPS.23LI' M .,,,, k". - Mps.25 (MPS.25). '.1.,.., ~,,' - Mps.25 (MPS.25LII. M..,.., K..' - MPS.27 (MPS.27). ,.,,,,.,, k,.L -- Mps.27lMPS~27L11 M.I'''I [(1,10 - MPS-27 (MPS.27PfI" ...,.., ~,., - MPS-JI (MPS.31). M"... i(,.L - Plan Mps.Ot (plan MI~ "I, M..,." R..... - Plan MPS.02 (plan "'1'~ fl.'1 M....." 1<',.." - Plan MPS.04(plan MI"' IIJI, ~1,,,,'1 rId - Plan MPS.06 (plan Mr~ 1If'I, M.II..r FlI". - PlanMPS..08(ptanMhll:-'. M0I1"rk,-,,, - PlanMPS.lO(planMr~ 1111 ~br'lrl"" PlanMPS-12 (plan MI"" I~I M.""I .:1,10 ..... Plan Mps.14 (plan ~1i"" 1.11. M.I,"! kl-II. - PlanMPS-16(plan MF~ 1'.1, Moll' 'I J(..... .- PlanMPS.17(PlanM'''''.17111.Nllfi(RORS - PJanMPS.J8(PlanMI'S I'(I,M",,'.I ft,.. - PlanMPS.19(planMI....lul,MJ/.'IFI,... - PlanMPS.20(plan Mt:, ~III, M.lI"1 kl" - PlanMPS.23 Tri.lallf.l'lI Mr.,.:., Inl, Major Risk - Plan Mrs.23 Tri.lalti.I..rl ~.H"'..'\ln lur Ll), Major Risk ..... Plan MPS.23 1ri.lat 1'.1 JrJ fI.'¡.' .; 11 n LJI L2), Major Risk Plan ~1PS.24 (plan Mf,:, ':41. Moll". Iot.....k. - Plan MPS-26 (plan MI,:, .:'" M"I'" ~1"1o - Plan MPS-28 (p1an MF~.':"I" Moll'" K..1o Plan Mps.29 (plan I\1b ':"1, M.I!'.I 1-lI'," - PlanMPS-30(planMi"" 1111, M .,.., 'C..... - Plan MpS.32 (BHL MI;-. 1."" ~1.J1'" Ic"" - PlanMPS-33 (plan M.;-..ll M"'..I FCI." - PlanMPS.34(planMI~ lJJ,~bl.'lkl," - Plan Mrs.17 - MPS.17 wp04 ,~J ~ 7000 8000 9000 10000 11000 12000 13000 14000 15000 Measured Depth [1 OOOft/in] SECTION DETAILS See MD Inc Azi TVD +N/.S +FJ~W DLeg TFace I 27.60 0.00 111111 ,..) ,,,,,¡ 0.00 0.00 0.00 2 2500.00 0.00 """.) ...,,¡ 0.00 0.00 0.00 3 351951 33.64 1.;1'", IJ. ...t "7 .171.09 3.30 0.00 4 3676.42 33.64 1: ,.~,. ," -17 .222.23 0.00 0.00 5 4609.45 70.60 1171111 -II ..; ,.j -691.08 4.00 .10.87 6 4709.45 70.60 1171111 u"'"11 ", J)o7 .755.41 0.00 0.00 7 4859.45 76.60 117¡11I J 'I ,) 11'1"''', -853.50 4.00 0.00 8 5194.47 90.00 '171111 ../ .',-1) , ¡ .1079.90 4.00 0.00 9 5250.12 95.32 11:' "r, I Ii I ~ .1119.20 12.00 .37.08 10 5276.98 95.32 ":'J" J .-../, 'I".'i -1138.77 0.00 0.00 II 5495.72 95.00 :''1"11 J J II 1-i.1 "f .1322.42 10.00 .89.84 12 5624.87 94.04 .'''(' U I .I"'" IJ"¡ .144451 4.00 -100.45 13 6017.78 94.04 ::\"'1 J ",-'J 1"'11 -1821.43 0.00 0.00 14 6034.13 93.63 .1' " I"" " .1837.14 4.00 .129.35 15 6034.27 93.63 ..:-: ~ll J "."J.I I '. ,'I .1837.27 4.00 .28.17 16 6712.03 93.63 ~¡.,~, JII J I." , ., .2489.39 0.00 0.00 17 6727 87 91.79 ":'If, UI -III. '" 1;":11-: .2\04M 4.00 7q9 VSec Target 0.00 0.00 263.87 342.74 1020.1 0 1109.86 1246.73 1562.63 Mps.17 T2 1616.07 1642.04 1858.26 MPS.!7 T3 1984.75 2366.33 2382.21 MPS.17 T4 2382.33 3039.48 10<4 86 MPS.17 y; ') BP Anticollision Report ) GLOBAL SCAN APPLIED: All well paths within 200'+ 100/1000 of reference Interpolation Method: MD Ipterval: 25.00 ft Depth Range: 27.60 to 835~.98 ft Maximum Radius: 1033.24 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 6/29/2001 Validated: No Planned From To Survey ft ft 27.60 900.00 900.00 8359.98 Version: Toolcode 4 Tool Name Planned: MPS-17 wp04 V10 P~anned: MPS-17 wp04 V10 CB-GYRO-SS MWD+IFR+MS Camera based gyro single shots MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 5189.12 42,70.49 7.000 9.875 75/8" 8359.97 4140.50 4.500 6.125 4 1/2" Summary < Site Warning M Pt S Pad MPS-03 MPS-03 MWD-IFR-MS V18 350.29 350.00 210.79 7.02 203.77 Pass: Major Risk M Pt S Pad MPS-03 Rig MPS-03 V8 Plan: PL 350.29 350.00 209.30 7.79 201.51 Pass: Major Risk M pt S Pad MPS-05 MPS-05 V1 399.63 400.00 182.35 8.11 174.26 Pass: Major Risk M Pt S Pad MPS-05 MPS-05L1 V1 399.63 400.00 182.35 7.98 174.39 Pass: Major Risk M Pt S Pad MPS-05 MPS-05PB 1 V2 399.63 400.00 182.35 8.08 174.29 Pass: Major Risk M Pt S Pad MPS-07 MPS-07 V9 318.79 325.00 150.55 6.17 144.39 Pass: Major Risk M Pt S Pad MPS-09 MPS-09 V5 343.28 350.00 119.09 6.58 112.52 Pass: Major Risk M Pt S Pad MPS-11 MPS-11 V4 349.89 350.00 90.74 7.54 83.20 Pass: Major Risk M pt S Pad MPS-13 MPS-13 V6 449.52 450.00 53.30 8.50 44.85 Pass: Major Risk M pt S Pad MPS-15 MPS-15 V7 718.27 725.00 35.42 13.22 22.21 Pass: Major Risk M pt S Pad MPS-21 MPS-21 V15 318.21 325.00 61.36 6.58 54.79 Pass: Major Risk M Pt S Pad MPS-23 MPS-23 V11 1449.11 1450.00 88.98 22.15 66.85 Pass: Major Risk M Pt S Pad MPS-23 MPS-23L 1 V4 1449.11 1450.00 88.98 22.02 66.98 Pass: Major Risk M Pt S Pad MPS-25 MPS-25 V2 624.52 625.00 123.85 11.48 112.44 Pass: Major Risk M Pt S Pad MPS-25 MPS-25L 1 V9 624.52 625.00 123.85 11.37 112.54 Pass: Major Risk M Pt S Pad MPS-27 MPS-27 V8 599.16 600.00 147.48 11.02 136.47 Pass: Major Risk M Pt S Pad MPS-27 MPS-27L 1 V6 599.16 600.00 147.48 10.91 136.57 Pass: Major Risk M Pt S Pad MPS-27 MPS-27PB 1 V1 599.16 600.00 147.48 11.02 136.4 7 Pass: Major Risk M pt S Pad MPS-31 ~ MPS-31 V8 492.95 500.00 210.67 9.55 201.13 Pass: Major Risk M Pt S Pad Plan MPS-01 Plan MPS-01 V1 Plan: M 619.46 625.00 245.62 14.09 231.53 Pass: Major Risk M Pt S Pad Plan MPS-02 Plan MPS-02 V2 Plan: M 594.49 600.00 225.62 13.55 212.07 Pass: Major Risk M Pt S Pad Plan MPS-04 Plan MPS-04 V1 Plan: M 444.48 450.00 196.28 10.20 186.08 Pass: Major Risk M Pt S Pad Plan MPS-06 Plan MPS-06 VO Plan: M 743.99 750.00 165.20 16.42 148.78 Pass: Major Risk M pt S Pad Plan MPS-08 Plan MPS-08 VO Plan: M 469.46 475.00 136.59 11.39 125.20 Pass: Major Risk M Pt S Pad Plan MPS-10 Plan MPS-10 V3 Plan: M 494.43 500.00 106.53 11.91 94.62 Pass: Major Risk M Pt S Pad Plan MPS-12 Plan MPS-12 V1 Plan: M 644.48 650.00 75.93 14.76 61.17 Pass: Major Risk M pt S Pad Plan MPS-14 Plan MPS-14 VO Plan: M 694.43 700.00 46.28 15.61 30.67 Pass: Major Risk M Pt S Pad Plan MPS-16 Plan MPS-16 V1 Plan: M 444.43 450.00 17.54 10.89 6.65 Pass: Major Risk M pt S Pad Plan MPS-17 Plan MPS-17L1 VO Plan: 3675.00 3675.00 0.00 58.68 -51.72 FAIL: Major Risk M Pt S Pad Plan MPS-18 Plan MPS-18 V1 Plan: M 469.46 475.00 16.14 11.35 4.78 Pass: Major Risk M Pt S Pad Plan MPS-19 Plan MPS-19 V5 Plan: M 899.65 900.00 29.26 19.74 9.52 Pass: Major Risk M Pt S Pad Plan MPS-20 Plan MPS-20 V1 Plan: M 669.46 675.00 46.20 15.13 31.07 Pass: Major Risk M Pt S Pad Plan MPS-23 Tri-Iat Plan MPS-23 tri VO Pia 1474.27 1475.00 90.74 26.89 63.86 Pass: Major Risk M Pt S Pad Plan MPS-23 Tri-Iat Plan MPS-23Tri-lat L 1 1474.27 1475.00 90.74 26.85 63.89 Pass: Major Risk M Pt S Pad Plan MPS-23 Tri-Iat Plan MPS-23Tri-lat L2 1474.27 1475.00 90.74 26.79 63.96 Pass: Major Risk M Pt S Pad Plan MPS-24 Plan MPS-24 V3 Plan: M 294.48 300.00 105.73 7.04 98.69 Pass: Major Risk M Pt S Pad Plan MPS-26 Plan MPS-26 VO Plan: M 419.49 425.00 136.02 10.22 125.79 Pass: Major Risk M Pt S Pad Plan MPS-28 Plan MPS-28 VO Plan: M 594.49 600.00 165.67 13.78 151.89 Pass: Major Risk M Pt S Pad Plan MPS-29 Plan MPS-29 VO Plan: M 694.21 700.00 184.80 15.52 169.28 Pass: Major Risk M Pt S Pad Plan MPS-30 Plan MPS-30 V1 Plan: M 544.34 550.00 194.31 12.85 181 .46 Pass: Major Risk M Pt S Pad Plan MPS-32 BHL MPS-32 V2 Plan: BH 594.49 600.00 225.79 13.72 212.07 Pass: Major Risk M Pt S Pad Plan MPS-33 Plan MPS-33 V1 Plan: M 344.50 350.00 240.36 8.44 231.92 Pass: Major Risk M Pt S Pad Plan MPS-34 Plan MPS-34 V2 Plan: M 369.50 375.00 255.68 9.09 246.60 Pass: Major Risk Or'~P '~~::-"'I'~':'P; COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM Plan: MPS.17Ll wp02 (Plan MPS.17/Plan MPS.17Ll) UP AI11\,:~o Cû-\)rdinak: (N/E) Reference: w~n Centre: Plan MPS-17. Tru¿ North Vertical rrVD) Reference: RB 6650 6650 Section (VS) Reference: Slot. (O.OON.O.OOE) M~asured Depth Refe~nce: RB 6650 66.50 Calculation Method: Minimum ('wvature Depth Fm Deplh To SurveyIPlan 4858.00 8359.08 Planned: Mps.17L I "'1'02 VI Tool Cakulatk,n Method: Minimum Curvature Emlr System: ISCWSA Scan Method: Trav Cylilkkr Nonh Em'f SUfl.,c; Elliptical.' Casing Wamil1~ Method: Rukos Basoo MWD'IFR~MS Created By; Ken Allen Checked: _.~~-~.._. Date; 8/1512002 Reviewed: -~_.._---_..._--_.- Date: --~ Date: --..-.- WELL DETAILS All TVD d /). 1 I '- "'- ssTVD I epths are p us 665'fi / //~-~' . or RKBE. ///// ~ .//////~~~., -1///// ~ ~ :~jj:%~~ ~ ~ 1/<// ' ~~ I /X /:;/ 1// 1// 1/ :I I, #, , ø.ð> :V# ;-- #' Name +N/-S "E/.W Northing Easting Latitude Longitu", Slot Plan Mps.17 9.28 .500.00 5999982.84 565844.98 70024'37.420N 149°27'49.826W NIA TARGET DETAILS Name 1VD +N/-S +FJ.W Northing Eastiug Shape MPS.17L1 T6 408350 1940.38 .3058.2g" 6001896.00 562770.00 Point MPS.17L1 17 409350 2088.95 .3575.04 6002040.00 562252.00 Point MPS.17L1 T8 409650 2261.27 -406259 6002208.00 561763.00 Point Mps.17Ll T5 4118.50 1781.48 .2504.61 6001742.00 563325.00 Point MPS.17Ll T4 4162.50 159757 .1837.14 6001564.00 563994.00 Point MPS.17 Poly 416650 1316.16 .145457 6001286.00 564379.00 Polygon Mps.17Ll T3 4201.50 1445.01 .1322.42 6001416.00 564510.00 Point MPS.17Ll T2 423150 1272.85 .1079.90 6001246.00 564754.00 Point SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 4858.00 76.54 317.00 4231.16 1029.03 ~ ': .54 0.00 0.00 I;J 'Ì.39 2 4996.65 93.17 317.45 4243.55 1130.04 "J'.99 12.00 1.55 I Il'..J7 3 5134.43 93.17 317.45 4235.92 1231.37 - I II 1".03 0.00 0.00 1..'"j.74 "-,,,' 4 5192.85 95.50 313.38 4231.50 1272.85 - I """.90 8.00 -60.01 I. '.:..63 MPS-17L1 T2 5 5195.93 95.70 313.38 4231.20 1274.96 - I 11".'.14 6.50 -0.95 1'.".;.61 6 5216.42 95.70 313.38 4229.16 1288.96 - I ""°'.95 0.00 0.00 I '.:.'Ì.36 7 5493.06 95.69 296.00 4201.50 1445.01 -I .~~.42 6.25 -89.17 1"..~.26 MPS-17L1 T3 8 5864.38 93.27 281.30 4172.34 1562.98 - I ,.7:.19 4.00 -98.75 .': ~ 1.26 9 5965.21 93.27 281.30 4166.60 1582.70 -I ! 711.91 0.00 0.00 :\(7.10 10 6033.22 93.64 284.00 4162.50 1597.57 - I ~ \ 7.14 4.00 82.14 .' '~:..20 MPS-17L1 T4 II 6069.01 93.64 285.44 4160.23 1606.64 - I" ¡I .69 4.00 89.96 .'J I ';.80 12 6712.52 93.64 285.44 4119.42 1777.57 -.: ~. '". 74 0.00 0.00 '"~'¡.84 13 6726.97 93.64 286.01 4118.50 1781.48 -.~ -."¡.61 4.00 89.62 ""...\.86 MPS-17L1 T5 14 6730.67 93.79 286.01 4118.26 1782.50 -~ .."~.17 4.00 0.46 '''..~.46 IS 7209.40 93.79 286.01 4086.63 1914.28 -:"":'.31 0.00 0.00 ,'.~ \.74 16 7304.11 90.00 286.00 4083.50 1940.38 - ""~.28 4.00 -179.78 "" 'Ì.92 MPS-17L1 T6 17 7334.45 88.83 285.69 4083.81 1948.66 - UI" :'.47 4.00 -165.35 ".-1 ';.45 18 7745.34 88.83 285.69 4092.23 2059.78 -\j"~.96 0.00 0.00 JIIJ 'Ì.06 19 7841.96 89.67 289.47 4093.50 2088.95 - I'. ;...04 4.00 77.45 J 1\'1.71 MPS-17L1 T7 20 8359.08 89.67 289.47 4096.50 2261.27 -:"'..':..59 0.00 0.00 J~.J'I.52 MPS-17L1 T8 FORMATION TOP DETAILS No. TVDPath MDPath Formation I 4231.50 4859.45 OA CASING DETAILS No. TVD MD Name Size- 4096.50 8359.07 4 1/2" 4.500 Start Dir 12/100' : 4858' MD, 4231.16'TVD End Dir : 4996.65' MD, 4243.55' TVD - Start Dir 8/100' : 5134.43' MD, 4235.92'TVD ~ Start Dir 6.5/100': 5192.85' MD, 4231.5'TVD End Dir : 6730.67' MD, 4118.26' TVD End Dir : 7841.96' MD,4093.5' TVD .S 4000- f, EndDir :5195.93'MD,423U'TVD .. - StartDir4./100':6712.52'MD'4119.42'TVD \. ... Sta, rtDir4/100': 774534' MD,4092.23'TVD. ., ..-\ ~ ~artDir6.251l0)': 5216.42'MD,4~29. 6'TVD j I I \\ I ~ \ ,~ 41/2" :; / ' End)it: 6(69. 1'110, 41 G).2~' T~'D \ 'f¿ I / '-- ~ ~u ~- -- ~ '" -J:/ ß. ~ ~ 0 I I I -J-+ I d U.1: ~...l.-.---~"'~~ -- "7LOO 1 ¡ ~ -- ROOO ---:::1 0 - oõ <JJ ---,. .__._~ ~ I I ëõ OA =--..-':.. --.~.~-~ . 6000 St3rtDir'/IOO':720(4'MD,4086.63'T\D "ota DeJth 8359.(~n.D,~09b.5'TVU .2 ---.......... ....-- I / I bnc!J¡ :13344"'M1J,4æ3.~I'IV1J t: 5000 >- ---StaJt.DIf4t.'()Q'.;..$.<93.06' MD, 4201.5'TVD 2 4400 Ene Di' : ~ 864,38' ;\1[;. 417L4' TVD f- Start Dir 4/100': 5965.2 'M), 4166 6'TVD '~ 1200 1600 2000 2400 2WO 3WO Vertical Section at 299.100 [400ft/in] 3600 4000 4400 I 4800 bp 0;.".".'>.'..'. ::~: ,.,~ COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM Plan: MPS-17L1 wp02 (Plan MPS-17/Plan MPS-17L11 Created By: Ken Allen Date: 8/15/2002 Tool ßP ArnCM:~\ ('o-ordinale (N/E) R~ference: Well ('entr~: Plan MPS-17. True N.lrth Vertical (1VD) Reference: RB 66.50 66.50 Section (VS) Referen~~: Slot - (O.OON.O.OOE) Measured Depth Reference: RB 66.50 66.50 Calculation Meth(x1: Minimum Curvature Depth Fm lJep.h To SurveyiPlan 4858.00 8359.08 Planned: Mps.17L1 "']'02 VI Reviewed: ----~._-- --.-- Date: .~._..~_. CASING DETAILS Name MD No, TVD 4 1/2" I 4096.50 8359.07 ir : 6730.67' M?: 4~:~:;~: ~~ 4119.42'TVD - T~ ---- MPS-I'Ll T6 End 0 S,," 01,4/100 . 6 I' MD, 'I60~' TVD, 1 66.6'TVD --------------- "P",-I 71. 1 ------'=1 ~ I~ EndDi~.. t~~ ~rr'o. 4. /100':.5~6;8~~.~,D~m,4172.34'TVD 06'MD,4201.5TVD ------- ------- / End Dlr . . 4/100': 5493. ----- --------------- "--f<- 4~Start Dlr ---------- > ---------- Mi'S-7LI T5 --------- --- ------J \-- - - .,' ~ 0, .." '1' T 408""TVO --------------- ---------- MPS-I ,L T' {4--- - -~ . MP'- DLl 1'3 Fnc1 nir . .114. InO' 7'094' l\Jn. / ",rt 0,,4/ - -- MPS-I7Ll 1'2 3' MD, 4235.92'TVD --------------- ----- 100' - '134 A ----- ~M~I7FoIY .1/ Start")ir8/ . d ths are All TVD eP66 S'for RKBE. ssTVD plus. CalculatÌt'll\ Mcthcd: Minimum Curvarnæ à~~;~ ~¡~~:r \~~~~~nœr ~orth Em>r SlIrface: EIlip/ieaI + Casing WaminR Method: Rules Bas~d 2400- End Dir : 7841.96' MD, 4093.5' TVD Start Dir 4/1 00' : 7745.34' MD, 4092.23TVD 2000 E ;¡:: 0 0 ::'!. +' ::5 1:: 0 z i 1600 ..c: ::; 0 (fJ 1200 800 -~-,}~lffflHH~¡fffit! Ill! ! I-H -4000 -3600 -3200 -2800 FORMATION TOP DETAILS No. TVDPath MDPath Formation 4231.50 4859.45 OA MWD-IFR+MS Date: ._...~--- WELL DETAILS Name +N1-S +fj.W Northing r~ting Latitude Longitud~ Slot Plan MPS.17 9.28 -500.00 5999982.84 565844.98 70"24'37.420N 149°27'49.826W N/A TARGET DETAILS Name TVD +Ni-S +fj.W Northing Easting Shape MPS.17LI T6 4083.50 1940.38 -305818 6001896.00 562770.00 Point MPS.17LI T7 4093.50 2088.95 .3575.04 6002040,00 562252.00 Point MPS-17LI T8 4096.50 226117 4062.59 6002208.00 561763.00 Point MPS.17LI T5 4118.50 1781.48 -2504.61 6001742.00 563325,00 Poin. MPS. I 7LI T4 4162.50 1597.57 .1837,14 6001564.00 563994.00 Point MPS-I7 Poly 4166.50 1316,16 .1454.57 6001286.00 564379.00 Polygon MPS-I7LI 13 4201.50 1445.01 .1322,42 6001416.00 564510,00 Point MPS-17LI 12 4231.50 1272.85 -1079.90 6001246.00 564754.00 Point SECTION DETAILS See MD Ine Azi TVD +N/-S +E(-W DLeg TFaee VSee Target I 4858.00 76.54 317.00 4231.16 1029.Q3 ~',-',.54 0.00 0.00 1245.39 2 4996.65 93;17 317.45 4243.55 1130.04 "~~.99 12.00 1.55 1376.17 3 5134.43 93.17 317.45 4235.92 1231.37 -I I) ¡'J.03 0.00 0.00 1506.74 "-'" 4 5192.85 95.50 313.38 4231.50 1272.85 -1"~').90 8.00 -60.01 1562.63 MPS-17L1 T2 5 5195.93 95.70 313.38 4231.20 1274.96 -I "" _~.14 6.50 -0.95 1565.61 6 5216.42 95.70 313.38 4229.16 1288.96 -1"'''ì.95 0.00 0.00 1585.36 7 5493.06 95.69 296.00 4201.50 1445.01 -I <:2.42 6.25 -89.17 1858.26 MPS-17L1 T3 8 5864.38 93.27 281.30 4172.34 1562.98 -1,,7 !..19 4.00 -98.75 2221.26 9 5965.21 93.27 281.30 4166.60 1582.70 -I 7 ~11.91 0.00 0.00 2317.10 10 6033.22 93.64 284.00 4162.50 1597.57 -lx\7.14 4.00 82.14 2382.20 MPS-17L1 T4 II 6069.01 93.64 285.44 4160.23 1606.64 -I ~ 71 .69 4.00 89.96 2416.80 12 6712.52 93.64 285.44 4119.42 1777.57 -:~'''1.74 0.00 0.00 3040.84 13 6726.97 93.64 286.01 4118.50 1781.48 -.: '.11+.61 4.00 89.62 3054.86 MPS-17L1 T5 14 6730.67 93.79 286.01 4118.26 1782.50 -:..I)~.17 4.00 0.46 3058.46 15 7209.40 93.79 286.01 4086.63 1914.28 -,:.".7.31 0.00 0.00 3523.74 16 7304.11 90.00 286.00 4083.50 1940.38 - ""~.28 4.00 -179.78 3615.92 MPS-17L1 T6 17 7334.45 88.83 285.69 4083.81 1948.66 - "'" 7.47 4.00 -165.35 3645.45 18 7745.34 88.83 285.69 4092.23 2059.78 - \~ ;;.~.96 0.00 0.00 4045.06 19 7841.96 89.67 289.47 4093.50 2088.95 -<..i~.04 4.00 77.45 4139.71 MPS-17L1 T7 20 8359.08 89.67 289.47 4096.50 2261.27 -JI)'.2.59 0.00 0.00 4649.52 MPS-17L1 T8 Size 4.500 ~ Star Dir 6.25/00': ~216.42' tv' D, 4229.1 S'TVD /j End Dil' : : 19S.9~' MIJ, !l231.2 1 \ D Star: Dir 6.5/1)0' : 5192.f!S' MD, 4131.5'-:VD En:! Dir : 4996.65' MD, 4243.55' TVD Start )ir 12/1 Q(i' : 4853' MD, 423 I. '6'1 VD I . -400 -1600 -800 -2400 -2000 West( - )/East( +) [400ft/in] -1200 ) BP My Planning Report MApt ') çpn.pa'ny; Fiêld; Site; Well: Wellpath: Field: BP Amoco Milne Point MPtSPad Plan MPS-17 Plan MPS-17L 1 Milne Point North Slope UNITED STATES. Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level' Method: Map Zone: Coordinate System: Geomagnetic Model: Site: M pt S Pad Site Position: From: Map Position Uncertainty: Ground Level: Northing: 5999978.00 ft Easting: 566345.00 ft Latitude: Longitude: North Reference: Grid Convergence: 0.00 ft 0.00 ft Well: Plan MPS-17 Slot Name: +N/-S 9.28 ft Northing: 5999982.84 ft +E/-W -500.00 ft Easting: 565844.98 ft Position Uncertainty: 0.00 ft Latitude: Longitude: Well Position: Wellpath: Plan MPS-17L 1 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: RB 66.50 8/14/2002 57500 nT Depth From (TVD) ft 0.00 66.50 ft Height +N/-S ft 0.00 Plan: MPS-17L 1 wp02 Date Composed: Version: Tied-to: Principal: Yes Casing Points Oracle Alaska, Zone 4 Well Centre BGGM2002 70 24 37.329 N 149 2735.171 W True 0.51 deg 70 24 37.420 N 149 27 49.826 W Plan MPS-17 4858.00 ft Mean Sea Level 25.78 deg 80.80 deg Direction deg 299.10 8/15/2002 1 From: Definitive Path MD TVD Diameter ft ft in 8359.07 4096.50 4.500 6.125 41/2" Formations MD TVD Formations DipA~gle Dipl)irection ft ft deg døg 0.00 BPRF 0.00 0.00 0.00 T Ugnu 0.00 0.00 0.00 NA 0.00 0.00 0.00 NB 0.00 0.00 0.00 NC 0.00 0.00 0.00 NE 0.00 0.00 0.00 NF 0.00 0.00 4859.45 4231 .50 OA 0.00 0.00 0.00 Base OA 0.00 0.00 0.00 OB 0.00 0.00 Targets M~p Map <..-Latitude ..---,."> <..,- Longitude-> Name Description TVD +N/-S +E/-W Norl.:hing F;~sting Deg Min Sec Deg ,Min Sec Dip. Dir. ft ft ft ft ft MPS-17L1 T6 4083.50 1940.38 -3058.28 6001896.00 562770.00 70 24 56.497 N 149 29 19.490 W MPS-17L1 T7 4093.50 2088.95 -3575.04 6002040.00 562252.00 70 24 57.956 N 149 29 34.642 W MPS-17L1 T8 4096.50 2261.27 -4062.59 6002208.00 561763.00 70 24 59.648 N 149 29 48.940 W MPS-17L 1 T5 4118.50 1781.48 -2504.61 6001742.00 563325.00 70 24 54.936 N 149 29 3.256 W ) BP , My Planning Report MAP ) Company: BP Amoco Fiêld: Milne Point Site: MPfSPad Well: PlaI1MPS~17 Wellpatlp Plan MPS-17L 1 Date: 811512002 Tiine:1 t:01 :46 Page: Co,.ordinate(NE):Referenee: Well: Plan MPS,.17, True North Vertical (fVD) Reference: RB 66.50 66.5 Section (VS) Reference: . Well (0.OON,O.00E,299.1 OAzi) Survey Calculation Metho<i: Minimum Curvature Db: Oracle Targets MPS-17L 1 T4 4162.50 1597.57 -1837.14 6001564.00 563994.00 70 24 53.129 N 149 28 43.686 W MPS-17 Poly 4166.50 1316.16 -1454.57 6001286.00 564379.00 70 24 50.363 N 149 28 32.468 W -Polygon 1 4166.50 1235.07 -1105.24 6001208.00 564729.00 70 24 49.566 N 149 28 22.227 W -Polygon 2 4166.50 1482.66 -941.04 6001457.00 564891.00 70 24 52.001 N 149 28 17.414 W -Polygon 3 4166.50 1612.03 -1434.96 6001582.00 564396.00 70 24 53.272 N 149 28 31.895 W -Polygon 4 4166.50 2382.82 -4122.53 6002329.00 561702.00 70 25 0.843 N 149 29 50.699 W -Polygon 5 4166.50 2101.81 -4125.00 6002048.00 561702.00 70 24 58.079 N 149 29 50.767 W -Polygon 6 4166.50 1316.16 -1454.57 6001286.00 564379.00 70 24 50.363 N 149 28 32.468 W . MPS-17L 1 T3 4201.50 1445.01 -1322.42 6001416.00 564510.00 70 24 51.630 N 149 28 28.595 W MPS-17L 1 T2 4231.50 1272.85 -1079.90 6001246.00 564754.00 70 24 49.937 N 149 28 21.484 W Plan Section Information 4858.00 76.54 317.00 4231.16 1029.03 -852.54 0.00 0.00 0.00 0.00 4996.65 93.17 317.45 4243.55 1130.04 -945.99 12.00 12.00 0.32 1.55 5134.43 93.17 317.45 4235.92 1231.37 -1039.03 0.00 0.00 0.00 0.00 5192.85 95.50 313.38 4231.50 1272.85 -1079.90 8.00 3.98 -6.96 -60.01 MPS-17L 1 T2 5195.93 95.70 313.38 4231.20 1274.96 -1082.14 6.50 6.50 -0.11 -0.95 5216.42 95.70 313.38 4229.16 1288.96 -1096.95 0.00 0.00 0.00 0.00 5493.06 95.69 296.00 4201.50 1445.01 -1322.42 6.25 0.00 -6.28 -89.17 MPS-17L 1 T3 5864.38 93.27 281.30 4172.34 1562.98 -1672.19 4.00 -0.65 -3.96 -98.75 5965.21 93.27 281.30 4166.60 1582.70 -1770.91 0.00 0.00 0.00 0.00 6033.22 93.64 284.00 4162.50 1597.57 -1837.14 4.00 0.54 3.97 82.14 MPS-17L 1 T4 6069.01 93.64 285.44 4160.23 1606.64 -1871.69 4.00 0.00 4.01 89.96 6712.52 93.64 285.44 4119.42 1777.57 -2490.74 0.00 0.00 0.00 0.00 6726.97 93.64 286.01 4118.50 1781.48 -2504.61 4.00 0.03 4.00 89.62 MPS-17L 1 T5 6730.67 93.79 286.01 4118.26 1782.50 -2508.17 4.00 4.00 0.03 0.46 7209.40 93.79 286.01 4086.63 1914.28 -2967.31 0.00 0.00 0.00 0.00 7304.11 90.00 286.00 4083.50 1940.38 -3058.28 4.00 -4.00 -0.02 -179.78 MPS-17L 1 T6 7334.45 88.83 285.69 4083.81 1948.66 -3087.47 4.00 -3.87 -1.01 -165.35 7745.34 88.83 285.69 4092.23 2059.78 -3482.96 0.00 0.00 0.00 0.00 7841.96 89.67 289.47 4093.50 2088.95 -3575.04 4.00 0.87 3.90 77.45 MPS-17L1 T7 8359.08 89.67 289.47 4096.50 2261.27 -4062.59 0.00 0.00 0.00 0.00 MPS-17L 1 T8 Survey MD Incl Azim TVD SysIVD MapN Map~ Tool/Comment ft deg deg ft ft ft 4858.00 76.54 317.00 4231.16 4164.66 6001004.22 564983.48 1245.39 0.00 Start Dir 12/100' : 4858' MD, 4859.45 76.72 317.00 4231.50 4165.00 6001005.24 564982.51 1246.73 12.00 OA 4875.00 78.58 317.06 4234.83 4168.33 6001016.26 564972.06 1261.18 12.00 MWD+IFR+MS 4900.00 81.58 317.14 4239.13 4172.63 6001034.15 564955.14 1284.60 12.00 MWD+IFR+MS 4925.00 84.58 317.22 4242.14 4175.64 6001052.20 564938.12 1308.19 12.00 MWD+IFR+MS 4950.00 87.58 317.30 4243.85 4177.35 6001070.36 564921.03 1331.89 12.00 MWD+IFR+MS 4975.00 90.58 317.38 4244.26 4177.76 6001088.59 564903.94 1355.62 12.00 MWD+IFR+MS 4996.65 93.17 317.45 4243.55 4177.05 6001104.39 564889.15. 1376.17 12.00 End Dir : 4996.65' MD, 4243.5 5000.00 93.17 317.45 4243.36 4176.86 6001106.83 564886.87 1379.34 0.00 MWD+IFR+MS 5100.00 93.17 317.45 4237.83 4171.33 6001179.78 564818.71 1474.11 0.00 MWD+IFR+MS 5134.43 93.17 317.45 4235.92 4169.42 6001204.89 564795.24 1506.74 0.00 Start Dir 8/100' : 5134.43' MD 5150.00 93.80 316.36 4234.97 4168.47 6001216.14 564784.52 1521.54 8.00 MWD+IFR+MS 5192.85 95.50 313.38 4231.50 4165.00 6001246.00 564754.00 1562.63 8.00 MPS-17L 1 T2 5195.93 95.70 313.38 4231.20 4164.70 6001248.09 564751.75 1565.61 6.50 End Dir : 5195.93' MD, 4231.2 5200.00 95.70 313.38 4230.79 4164.29 6001250.84 564748.78 1569.53 O.pO MWD+IFR+MS ) ') BP I: My Planning Report MAP Cófupany: BP Ahibco natè:8/15/2002 'fime:il1:01:46 Page: 3 Field: Milne Point Co-ordinate(NE)..Referénce: Well: Plan MPS:-17, True North Site: M Pt S Pad V ertical(TVD). Reference: RB66.50 66.5 Well: Plan MPS:-17 Sectión (VS) Reference: Well (0,00N,O.00E,299.10Azi) Wellpath: Plan MPS-17L 1 Survey Calculation Mèthod: Minimum Curvature Db: Oracle Survey 5216.42 95.70 313.38 4229.16 4162.66 6001261.96 564736.81 1585.36 0.00 Start Dir 6.25/100' : 5216.42' 5250.00 95.73 311.27 4225.82 4159.32 6001284.23 564711.91 1617.89 6.25 MWD+IFR+MS 5300.00 95.75 308.13 4220.82 4154.32 6001315.66 564673.36 1666.78 6.25 MWD+IFR+MS 5350.00 95.76 304.99 4215.80 4149.30 6001344.93 564633.15 1716.10 6.25 MWD+IFR+MS 5400.00 95.75 301.85 4210.78 4144.28 6001371.96 564591.40 1765.71 6.25 MWD+IFR+MS 5450.00 95.73 298.70 4205.78 4139.28 6001396.65 564548.22 1815.44 6.25 MWD+IFR+MS 5493.06 95.69 296.00 4201.50 4135.00 6001416.00 564510.00 1858.26 6.25 MPS-17L 1 T3 5500.00 95.65 295.72 4200.81 4134.31 6001418.96 564503.76 1865.16 4.00 MWD+IFR+MS 5600.00 95.02 291.76 4191.51 4125.01 6001458.22 564412.30 1964.27 4.00 MWD+IFR+MS 5700.00 94.38 287.80 4183.31 4116.81 6001491.10 564318.24 2062.59 4.00 MWD+IFR+MS 5800.00 93.71 283.84 4176.26 4109.76 6001517.44 564222.06 2159.65 4.00 MWD+IFR+MS 5864.38 93.27 281.30 4172.34 4105.84 6001530.87 564159.23 2221.26 4.00 End Dir : 5864.38' MD, 4172.3 5900.00 93.27 281.30 4170.31 4103.81 6001537.53 564124.30 2255.11 0.00 MWD+IFR+MS 5965.21 93.27 281.30 4166.60 4100.10 6001549.72 564060.36 2317.10 0.00 Start Dir 4/100' : 5965.21' MD 6000.00 93.46 282.68 4164.56 4098.06 6001556.63 564026.33 2350.29 4.00 MWD+IFR+MS 6033.22 93.64 284.00 4162.50 4096.00 6001564.00 563994.00 2382.20 4.00 MPS-17L 1 T4 6069.01 93.64 285.44 4160.23 4093.73 6001572.77 563959.38 2416.80 4.00 End Dir : 6069.01' MD, 4160.2 6100.00 93.64 285.44 4158.26 4091.76 6001580.73 563929.50 2446.85 0.00 MWD+IFR+MS 6200.00 93.64 285.44 4151.92 4085.42 6001606.44 563833.08 2543.82 0.00 MWD+IFR+MS 6300.00 93.64 285.44 4145.58 4079.08 6001632.15 563736.66 2640.80 0.00 MWD+IFR+MS 6400.00 93.64 285.44 4139.24 4072.74 6001657.87 563640.24 2737.77 0.00 MWD+IFR+MS 6500.00 93.64 285.44 4132.90 4066.40 6001683.58 563543.82 2834.75 0.00 MWD+IFR+MS 6600.00 93.64 285.44 4126.55 4060.05 6001709.29 563447.40 2931.72 0.00 MWD+IFR+MS 6700.00 93.64 285.44 4120.21 4053.71 6001735.00 563350.98 3028.69 0.00 MWD+IFR+MS 6712.52 93.64 285.44 4119.42 4052.92 6001738.22 563338.91 3040.84 0.00 Start Dir 4/100' : 6712.52' MD 6726.97 93.64 286.01 4118.50 4052.00 6001742.00 563325.00 3054.86 3.99 MPS-17L1 T5 6730.67 93.79 286.01 4118.26 4051.76 6001742.99 563321.43 3058.46 4.00 End Dir : 6730.67' MD, 4118.2 6800.00 93.79 286.01 4113.68 404 7 .18 6001761.48 563254.78 3125.84 0.00 MWD+IFR+MS 6900.00 93.79 286.01 4107.07 4040.57 6001788.16 563158.65 3223.03 0.00 MWD+IFR+MS 7000.00 93.79 286.01 4100.47 4033.97 6001814.84 . 563062.51 3320.22 0.00 MWD+IFR+MS 7100.00 93.79 286.01 4093.86 4027.36 6001841.52 562966.37 3417.41 0.00 MWD+IFR+MS 7209.40 93.79 286.01 4086.63 4020.13 6001870.71 562861.19 3523.74 0.00 Start Dir 4/100' : 7209.4' MD, 7304.11 90.00 286.00 4083.50 4017.00 6001896.00 562770.00 3615.92 4.00 MPS-17L 1 T6 7334.45 88.83 285.69 4083.81 4017.31 6001904.02 562740.75 3645.45 4.00 End Dir : 7334.45' MD, 4083.8 7400.00 88.83 285.69 4085.15 4018.65 6001921.19 562677.51 3709.20 0.00 MWD+IFR+MS 7500.00 88.83 285.69 4087.20 4020.70 6001947.38 562581.03 3806.45 0.00 MWD+IFR+MS 7600.00 88.83 285.69 4089.25 4022.75 6001973.57 562484.55 3903.71 0.00 MWD+IFR+MS 7700.00 88.83 285.69 4091.30 4024.80 6001999.76 562388.07 4000.96 0.00 MWD+IFR+MS 7745.34 88.83 285.69 4092.23 4025.73 6002011.64 562344.33 4045.06 0.00 Start Dir 4/100' : 7745.34' MD 7800.00 89.30 287.83 4093.12 4026.62 6002026.93 562291.87 4098.44 4.00 MWD+IFR+MS 7841.96 89.67 289.47 4093.50 4027.00 6002040.00 562252.00 4139.71 4.00 MPS-17L 1 T7 7900.00 89.67 289.47 4093.84 4027.34 6002058.85 562197.12 4196.92 0.00 MWD+IFR+MS 8000.00 89.67 289.47 4094.42 4027.92 6002091.34 562102.56 4295.51 0.00 MWD+IFR+MS 8100.00 89.67 289.47 4095.00 4028.50 6002123.83 562007.99 4394.10 0.00 MWD+IFR+MS 8200.00 89.67 289.47 4095.58 4029.08 6002156.32 561913.43 4492.69 0.00 MWD+IFR+MS 8300.00 89.67 289.47 4096.16 4029.66 6002188.81 561818.86 4591.27 0.00 MWD+IFR+MS 8359.06 89.67 289.47 4096.50 4030.00 6002207.99 561763.01 4649.50 0.00 41/2" 8359.08 89.67 289.47 4096.50 4030.00 6002208.00 561763.00 4649.52 0.00 MPS-17L 1 T8 H 207035 DATE 8/01/02 c~~c~ t-!°.' H207035 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 8/01/02 H CK073102B Permit t6DriIl Fee $100.00 {)\PS- 17/ LI PIs contact Sondra Stewman X4750 for check picku~ '~ THE AnACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ $100.00 PAY 2002*** *****$100.00****** NOT VALID AFTER 120 DAYS ~' III 20 ? 0 j SUI I: 0... ~ 20 j 8 q 51: 00 a ~... ~ 11111 ç:. ".:,' :::: ..:: :::.:';':: ::::.::::::~.::;/:.. ::~.:.::~ :i.:~:::: ~.:~:::: i ::::,.::: ~ T """;""'~l~ ::""""'I"'"M''~'''''''''''''';''''' 0t;jf;§; ~/!X~;~:~:t:~~~i;;~;~:Öti;~; ) ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME;I1fJú h1S-/7 PTD# 2..d2-""/ /("i CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function. of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full. compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ;t1fJ &( WELL PERMIT CHECKLIST COMPANY /3P)( WELL NAME !1/.( -/7 PROGRAM: Exp - Dev ~Redrll- Re-Enter - Serv - Well bore seg- FIELD & POOL 5 ¿S /"1 0 INIT CLASS ,ð~ /-0:/ GEOL AREA ð'9 ~ UNIT# II .3 2.. <g ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . y.. N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N ¿t>/ f'? ~ ~'ð 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ~ '6(2 .....<-- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . . ~ N (Service Well Only) 13. Well located w/in area & strata authorized by injection order#_. Y x. ì<~ ~ , (Service Well Only) 14. All wells w/in X mile area of review identified. . . . . . . . .. /' N i ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . , œ N ¡~ II €J Ii z.. " 16. Surface casing protects all known USDWs. . . . . . . . . . . . N.J J - 4- 17. CMT vol adequate to circulate on conductor & surf csg. . . . . . N ~C() ~ I-( e( f'J2ç Ç. 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . '¥--N" ..d' 19. CMT will cover all know. n productive horizons. . . . . . . . . . ~~. .1. I? rre d . 20. Casing designs adequate for C, T, B & permafrost. . .. . . . N tì d 21. Adequate tankage or reserve pit.. . . . . . . . . . . . , . . . N VWjW\.- t'Tl. 22. If a re-drill, has a 10-403 for abandonment been approved. . . '- ""/A- 23. Adequate wellbore separation proposed.. . . . . . . . . . . . N 24. If diverter required, does it meet regulations. . . . . . . . . . N 0 25. Drilling fluid program schematic & equip list adequate. . . . . N 1hPt4 fJ1 (¡../ 1 t 2. POf, 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N . :. APPR DATE 27. BOPE press rating appropriate; test to Ljooo psig. N fU<..p I t./l:5 f~t " A- I 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N W4r- 8/2310 i... 29. Work will occur without operation Sh. utdown. . . . . . . . . . . ~ ii. 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y(bII 31. Mechanical condition of wells within AOR verified. . . . . . . . .-¥--N- ALIA- 32. Permit can be issued w/o hydrogen sulfide measures. . . , . (;) N 33. Data presented on potential overpressure zones. . . . . . .. )f 34. Seismic analysis of shallow gas zones. . . . . . . .. ., .. .. .. '. Yy ~ 11J. A. 35, Seabed condition survey (if off-shore). . . . . , . . . . . . . . 36. Contact name/phone for weekly progress reports. , GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER RPC~ TEM JDH ~ JBR APPR DATE (Service Well Only) GEOLOGY APPR DATE RP/- ~~¿ (E~ploratory Only) Rev: 07/12/02 ) ) COMMISSIONER: Comments/Instructions: SFD- WGA \¿J4ß-- COT j DTS a ~ 2!fJ 0 e.. MJW G:\geology\perm its\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simpHfy 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. ) ,) cR Od- ~ r73 113Cf 0 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Dec 05 14:37:17 2002 Reel Header Service name... ........ ..LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 12 / 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 Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 12 / 05 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Previous Tape Name..... ..UNKNOWN Comments...... ......... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-17 500292311500 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 05-DEC-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22158 J. STRAHAN E. VAUGHN MWDRUN 2 AK-MW-22158 J. STRAHAN E. VAUGHN MWDRUN 3 AK-MW-22158 B. ZIEMKE E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3315 165 65.90 38.40 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 20.000 112.0 6.125 7.625 5190.0 ) 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1, 2, AND 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 3 ALSO INCLUDED AT-BIT INCLINATION (ABI) . 4. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 10/03/02. MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1, 2, AND 3 REPRESENT WELL MPS-17 WITH API#: 50-029-23115-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8390'MD/4136'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name. ..... ..... ..STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/05 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX 1 clipped curves; all bit runs merged. .5000 START DEPTH 228.5 228.5 228.5 228.5 228.5 STOP DEPTH 8343.0 8343.0 8343.0 8343.0 8343.0 ) ') GR ROP $ 239.5 276.0 8336.0 8390.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MEB.GED DATA PBU TOOL MWD MWD MWD $ SOURCE CODE BIT RUN NO MERGE TOP 1 228.5 2 4834.0 3 5208.5 MERGE BASE 4834.0 5208.5 8390.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.. ...... ..... .....0 Data Specification Block Type. ....0 Logging Direction........... ... ...Down Optical log depth units......... ..Feet Data Reference Point.... .... .... ..Undefined Frame Spacing..... ........ .... ... .60 .1IN Max frames per record...... .......Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 228.5 8390 4309.25 16324 228.5 8390 ROP MWD FT/H 0.63 1304.09 231.95 16229 276 8390 GR MWD API 9 118.5 66.5343 16194 239.5 8336 RPX MWD OHMM 0.24 2000 109.396 16230 228.5 8343 RPS MWD OHMM 0.23 2000 107.84 16230 228.5 8343 RPM MWD OHMM 0.28 2000 88.1057 16230 228.5 8343 RPD MWD OHMM 0.15 2000 138.232 16230 228.5 8343 FET MWD HOUR 0.09 47.97 0.863477 16230 228.5 8343 First Reading For Entire File. ...... ...228.5 Last Reading For Entire File... ....... .8390 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number...... ... ..1.0.0 Date of Generation...... .02/12/05 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...... .02/12/05 Maximum Physical Record. .65535 File Type.. ............. .LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 2 ) header data for each bit run in separate files. 1 .5000 START DEPTH 228.5 228.5 228.5 228.5 228.5 239.5 276.0 # 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: # STOP DEPTH 4787.0 4787.0 4787.0 4787.0 4787.0 4797.0 4834.0 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: 19-5EP-02 Insite 66.37 Memory 4834.0 112.0 4834.0 .8 74.7 TOOL NUMBER 66093 103792 9.875 112.0 LSND 9.30 122.0 7.5 ) 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: 800 8.4 6.000 3.290 6.200 4.500 50.0 96.8 50.0 50.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.......... ...... . Down Optical log depth units.... ..... ..Feet Data Reference Point.. ...... ... ...Undefined Frame Spac ing. . . . . . . . . . . . . . . . . . . . . 60 . 1 IN 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 MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 228.5 4834 2531.25 9212 228.5 4834 ROP MWD010 FT/H 12.51 1304.09 262.745 9117 276 4834 GR MWD010 API 9 118.5 63.5954 9116 239.5 4797 RPX MWD010 OHMM 0.24 2000 175.344 9118 228.5 4787 RPS MWD010 OHMM 0.23 2000 169.159 9118 228.5 4787 RPM MWD010 OHMM 0.28 2000 129.057 9118 228.5 4787 RPD MWD010 OHMM 0.15 2000 217.189 9118 228.5 4787 FET MWD010 HOUR 0.09 8.56 0.545751 9118 228.5 4787 First Reading For Entire File........ ..228.5 Last Reading For Entire File........ ...4834 File Trailer Service name......... ... .STSLIB.002 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .02/12/05 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...... .02/12/05 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 FET RPD RPM RPS RPX GR ROP $ 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 4787.5 4787.5 4787.5 4787.5 4787.5 4797.5 4834.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 5161.5 5161.5 5161.5 5161.5 5161.5 5171.5 5208.5 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): 19-5EP-02 Insite 66.37 Memory 5208.0 4834.0 5208.0 79.8 87.2 TOOL NUMBER 66093 103792 9.875 112.0 LSND 9.40 110.0 8.0 500 ) ') 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: 5.6 5.900 3.510 6.000 4.500 58.0 102.2 54.0 58.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ...... .....0 Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units..... ..... .Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record....... ..... . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4787.5 5208.5 4998 843 4787.5 5208.5 ROP MWD020 FT/H 0.71 278.76 145.743 749 4834.5 5208.5 GR MWD020 API 44.28 102.81 71.713 749 4797.5 5171.5 RPX MWD020 OHMM 5.21 51.86 18.1523 749 4787.5 5161.5 RPS MWD020 OHMM 5.4 58.46 19.9948 749 4787.5 5161.5 RPM MWD020 OHMM 5.51 53.37 20.8133 749 4787.5 5161.5 RPD MWD020 OHMM 5.76 53.21 21.9015 749 4787.5 5161.5 FET MWD020 HOUR 0.26 9.72 1.89591 749 4787.5 5161.5 First Reading For Entire File....... ...4787.5 Last Reading For Entire File....... ... .5208.5 File Trailer Service name.... ........ .STSLIB.003 Service Sub Level Name. . . Version Number. ......... .1.0.0 Date of Generation... ... .02/12/05 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...... .02/12/05 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: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 4 ) header data for each bit run in separate files. 3 .5000 START DEPTH 5162.0 5162.0 5162.0 5162.0 5162.0 5172.0 5209.0 # 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 $ STOP DEPTH 8343.0 8343.0 8343.0 8343.0 8343.0 8336.0 8390.0 23-SEP-02 Insite 66.37 Memory 8390.0 5208.0 8390.0 89.6 97.3 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 91360 162742 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): 6.125 5190.0 Flo-pro 9.40 53.0 8.5 44000 5.0 ) ) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .110 .080 .100 .130 67.0 91.4 70.0 71.0 # 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 Uni t s. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5162 8390 6776 6457 5162 8390 ROP MWD030 FT/H 0.63 696.54 197.973 6363 5209 8390 GR MWD030 API 28.92 117.9 70.1546 6329 5172 8336 RPX MWD030 OHMM 1.81 2000 25.6362 6363 5162 8343 RPS MWD030 OHMM 2.42 2000 30.3109 6363 5162 8343 RPM MWD030 OHMM 0.94 2000 37.345 6363 5162 8343 RPD MWD030 OHMM 0.35 2000 38.781 6363 5162 8343 FET MWD030 HOUR 0.16 47.97 1.19724 6363 5162 8343 First Reading For Entire File..... .... .5162 Last Reading For Entire File........ ...8390 File Trailer Service name........ .... .STSLIB.004 Service Sub Level Name. . . Version Number.. ........ .1.0.0 Date of Generation. .... ..02/12/05 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO Next File Name.. ........ .STSLIB.005 ) Physical EOF Tape Trailer Service name....... .... ..LISTPE Date.................... .02/12/05 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.... ........... . UNKNOWN Continuation Number.... ..01 Next Tape Name. .... ..... . UNKNOWN Comments..... ........... .STS LIS Reel Trailer Service name... ......... .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 0 2 / 12 / 0 5 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... .......... ..UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments..... ........... .STS LIS Physical EOF Physical EOF End Of LIS File ) Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services