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Home My WebLink About195-201MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC F-22 MILNE PT UNIT F-22 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 F-22 50-029-22632-00-00 195-201-0 W SPT 6959 1952010 1740 2830 2830 2830 2928 143 245 242 240 4YRTST P Adam Earl 5/10/2025 MIT IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT F-22 Inspection Date: Tubing OA Packer Depth 1213 1945 1932 1931IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250512092406 BBL Pumped:1.1 BBL Returned:1.1 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 99 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 15:31:40 -08'00' 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Prep for CTD 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 16,070 feet N/A feet true vertical 7,280 feet N/A feet Effective Depth measured 15,876 feet 15,688 feet true vertical 7,118 feet 6,959 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2"12.6# / L-80 / TXP 15,762' 7,022' Packers and SSSV (type, measured and true vertical depth)4-1/2"x 7" Production Packer N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: Hilcorp Alaska LLC 777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 3,090psi 5,410psi 5,410psi7,240psi 20" 9-5/8" 7" 7" 5,146' 110' 8,842' 13,437' Burst N/A 5,750psi 7,240psi Surface Production N/A measured 2,617' N/A measured 6,992' 9,419' Length Tubing Pressure 0 Junk Production Casing Conductor Size 80 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-029 2,067 Authorized Signature with date: Authorized Name: David Gorn dgorm@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-201 50-029-22632-00-00 Plugs ADL0025509 & ADL0355018 5. Permit to Drill Number: Milne Point / Kuparuk River Oil 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 3320 MILNE PT UNIT F-22 Gas-Mcf 360 0 Oil-Bbl measured true vertical Packer 16,054' 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Casing Pressure WINJ WAG 0 Water-Bbl MD 110' 8,842' 13,437' TVD 110' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:19 am, May 26, 2021 Chad Helgeson (1517) 2021.05.25 16:09:58 - 08'00' SFD 5/26/2021MGR30JUL2021DSR-5/26/21 RBDMS HEW 6/10/2021 _____________________________________________________________________________________ Revised By: DH 5/13/2021 SCHEMATIC Milne Point Unit Well: MP F-22 Last Completed: 3/23/2021 PTD: 195-201 TD =16,070(MD) / TD =7,279(TVD) 20” Orig. KB Elev.: 45.85’/ Orig. GL Elev.: 12.0’ RT toCasing Spool = 33.1’ (Nabors 27E) 7” 3 5 9-5/8” 1 2 KUP A Sands PBTD =16,010’(MD) / PBTD =7,229’(TVD) 4 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / NT80LHE N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 8,842’ 7" Production 26 / L-80 / BTC 6.276 Surface 13,437’ 7" Production 26 / NT80S / NSCC 6.276 13,437’ 16,054’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP 3.958 Surface 15,762’ JEWELRY DETAIL No Depth Item 1 2,294’ X Nipple, 3.813” 2 15,688’ 4-1/2” x 7” Premier Production Packer 3 15,718’ X Nipple, 3.813” 4 15,744’ Magnum Burst Disk 5 15,755’ WLEG Mule Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 15,901’ 15,961’ 7,139’ 7,189’ 60 2/15/1996 Open Ref Log: 2/12/1996 AWS Gr/CC. 22gm Jumbo Jet Charges @ 60 de. Phasing, random orientation, 0.76” EHD, 6.4” TTP. OPEN HOLE / CEMENT DETAIL 34" Cmt w/ 260 sx of Arcticset (Approx) 12-1/4" Cmt w/ 1,691 sx PF “E”, 250 sx “G”, 250 sx PF “G” 8-1/2” Cmt w/ 499 sx Class “G” WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = 72 to 75 deg. f/ 3,810’ to 14,100’ Hole Angle through perforations = 34 deg. DLS = 7.3 deg./ 100’ @ 15,600’ TREE & WELLHEAD Tree Cameron 4-1/16” 5M Wellhead 11” x 11” 5K FMC Gen 5A, w/ 4-1/2” Atlas Bradford hgr. Tbg Hanger 4-1/2” TC-1A-EMS 11 x 4-1/2” Atlas Bradford TC-II, 12.6# top & bottom GENERAL WELL INFO API: 50-029-22632-00-00 Drilled and Cased by Nabors 27E - 1/14/1996 Perforations – 2/15/1996 Frac – 2/27/1996 ESP Install w/ Nabors 4-ES – 4/1/1996 ESP RWO w/ Nabors 4-ES – 8/14/2000 ESP RWO w/ Nabors 4-ES – 6/22/2006 ESP to Jet Pump conversion w/ Doyon 14 - 3/2021 STIMULATION SUMMARY 2/27/1996 120 M# of 16/20 mesh carbolite behind pipe. Design plus small excess – no indication of TSO. Well Name Rig API Number Well Permit Number Start Date End Date MPU F-22 Doyon 14/ CDR2 50-029-22632-00-00 1952010 3/18/2021 4/26/2021 3/19/2021 Jack up and move off F-18. Spot and center and shim rig over F-22 / surface = zero / annulus =650 psi (gas) & TBG = BPV installed. Skid floor into drill position. Hook up air, water & steam and warm floor, work on rig acceptance check list, continue r/up and spotting out building and equipment, safe out stairs and landing, swap to high line power, R/up and pull BPV tbg = 450 psi (gas). Prep pits for fluid. Continue work on rig acceptance check list. PJSM. R/up squeeze manifold and lines and test same. Take on KWF to pits and build lubed spacer pill. Accept rig @ 1500 hrs. Start loading pipe shed. PJSM on well kill. Kill well: Pump 280 bbls heated seawater w/ Deepclean down tubing taking returns to flow back tank @ 3 BPM, 690 PSI ICP / 800 PSI FCP, holding 250 PSI on choke. 1st 100 bbls of returns were 50% gas. Pump 25 bbl 8.7 ppg high vis pill w/ 4% lube. Chase with 121 bbls 8.7 ppg brine with 0.4% lube, 3 BPM, 850 PSI ICP, 440 PSI FCP, holding 260 PSI on choke. Calculate 34 bbls of kill weight fluid around the corner. Bull head 33 bbls 8.7 ppg brine (calculated volume from GLM to bottom perforations) @ 1 BPM, 20 PSI ICP, 100 PSI FCP, 180 PSI on OA. 459 bbls pumped, 205 bbls returned, 254 bbls losses (including 33 bbls bullheaded). Empty flow back tank with vac truck. Monitor well - both tubing and IA on a vacuum slowing to slight vacuum in 15 minutes. Continue well kill. Pump 8.7 ppg brine, 3 BPM, 370 PSI while initially holding 260 PSI on choke. Pumped 27.5 bbls before fluid returns. Continue to pump at 3 BPM, 400 PSI with choke full open - 170 PSI IA.- seawater with 2% to 5% oil. At 739 bbls total pumped, saw diesel in 50 bbls of the returns. At 789 bbls pumped, saw seawater with Deepclean returns observed for 130 bbls. At 959 bbls pumped, high vis spacer returns. Spacer was 110 bbls late w/ initial 8.6 ppg out & was strung out over 96 bbls. Pumped until out of fluid at 1055 bbls pumped w/ 8.7 ppg brine and trace spacer returns. 3 BPM, 525 GPM FCP with 60 PSI on IA with full open choke. 140 PSI final pressure on OA. 444 bbls returned to the flow back tank of 596 pumped after bullheading, 152 bbls losses. 373 bbls seepage losses + 33 bbls bullheaded = 406 bbls total during well kill. Flow check - both tubing and OA on a vacuum, slowing to slight vacuum in 15 minutes. Blow down and rig down circulating lines and squeeze manifold. R/U injection line to IA to monitor fluid losses. Sim-ops: Offload flow back tank and load pits with 290 bbls 8.7 ppg brine. Wellhead representative install BPV then N/D tree. Inspect hanger threads good and verify M/U with 3" LH Acme XO - 8-1/2 turns. Install CTS plug in BPV. Install plugs in control line ports and pack graphite around all penetrations. Install new ring gasket. M/U 11" x 7-1/16" adapter flange and N/U BOP stack, kill line, choke hard line and riser. Fill IA with 15.5 bbls 8.7 ppg brine over 2.33 hours since pumps off = 6.65 BPH static losses. Monitor losses with charge pump running, initial 21 bbls in 30 minutes (42 BPH), 90 bbls total losses in 2.25 hours = 40 BPH average. Shut off pump at 05:00 to allow the fluid level to drop. Function test rams - good. M/U test subs to top drive. Install 2-7/8" test plug. R/U test manifold. Hilcorp Alaska, LLC Weekly Operations Summary 3/18/2021 Refer to F-18 Pre-Drill for Details, Clear & clean cellar area. Blow down service lines to rig floor & prep to skid floor. Rig down & move rockwasher & cuttings box. Skid Rig floor into moving position. Well Name Rig API Number Well Permit Number Start Date End Date MPU F-22 Doyon 14/ CDR2 50-029-22632-00-00 1952010 3/18/2021 4/26/2021 Hilcorp Alaska, LLC Weekly Operations Summary Finish rigging up test equipment. Flood stack and lines with fresh water. Choke line Oteco connection leaking. Tighten clamp, still leaking. Remove old clamp and install new clamp, still leaking. Take fluid level shot with Echometer: 3.25 sec = 2031'.,Blow down choke line, change Oteco gasket on choke line connection under the rig floor, then flood choke line.,Perform BOP shell test with annular closed on 2-7/8" test joint to 250 PSI low / 3000 PSI high. Also Preformed weekly derrick inspection,Test BOPs as per AOGCC, Sundry Approval & Hilcorp requirements. AOGCC notified of at 13:58 on 19 March 2021. AOGCC rep Guy Cook waived the right to witness test at 14:02 on 19 March 2021. Test with 2-7/8” & 4.5'' Test jts. All test performed with fresh water against a test dart installed in BPV. All test 250/3000 psi, Tests held for 5 min each and charted. Perform accumulator draw down. Test gas alarms and PVT, 1) Annular on 2-7/8" test joint, choke valves 12, 13, 14, kill line Demco & 3-1/2" dart, 2) Upper 2-7/8" x 5" VBR on 2-7/8" test joint, Choke valves 9, 11, HCR kill & 3-1/2" TIW#1, 3) Choke valves 5, 8, 10 & manual kill , 4) Choke valves 4, 6 & 7", 5)Choke valve 2, upper IBOP, 6) Lower IBOP, 7) LPR 2-7/8" JT,8) 2-7/8" X5" UPR, w/ 4-1/2" test jt, choke HCR, 9) Manual choke A, 10) Choke valve #1, 11) Lower 2-7/8" x 5" VBR w/ 4-1/2" jt , 12) Choke valve #3, Blinds, 13)Manual choke B, 14) Super choke A. Perform accumulator test, 3100 psi system pressure, 1600 psi after closure, 200 psi attained in 40 sec, full pressure in 193 sec. 6 N2 bottle avg = 2120 psi. R/dn test equipment pull dart and BPV and took 2nd fluid shot @ 13:45 w/ fluid level @ 1562' (Rise of 469' from last fluid level shot), Close blind rams. Rig up to take returns from IA to full open choke. Pump down kill line, down tubing at 3 BPM, 80 PSI. Took 32 bbls to fill hole - fluid level at 1058'. and sweep minimual oil cap to pits. R/D and blow down lines. M/U 2- 7/8" landing joint w/ 2-7/8" XO & FOSV to hanger. BOLDS and pull hanger to the rig floor from 15,326'. Hanger free at 90K, hoist to rig floor with 105K P/U with max 115K P/U. L/D landing joint & hanger. 3/20/2021 POOH laying down 8 joints of 2-5/8", 1 GLM & 6 LaSalle clamps t/ 15070'. Cut ESP cable & secure to tubing with Cannon clamp. PJSM. P/U Baker 7" TST-3 retrievable packer, XO & 2 joints of 4-1/2" 12.6# L-80 TXP-BTC tubing to 15,169'. Attempt to set multiple times w/ 2 turns right in 1/4 turns. Begin to fill hole. Hoist packer to the rig floor while filling hole. J-slot was in set position. RIH and set once hole was full: 65 bbls = 2150' fluid level depth. 100K PU / 75K SO. Center of packer element at 92.43'. Top of twin thread at 78.97'. L/D 2 joints of 4-1/2" & running tool. Close blind rams and test to 250 PSI for 5 min / 1500 PSI for 15 min - good. Blow down choke & kill lines. N/D BOP stack and remove 7-1/16" x 11" tubing spool. Install new O-rings on upper 7" pack-off and re-torque LDS. Install new 11" tubing spool. Set stack on tubing spool and torque bolts. Test pack-off void to 500 PSI for 5 min & 5000 PSI for 10 min. - good test. Sim-ops: Hanger ESP cable trunk from sheave to spooling unit. Finish N/U BOPs -tighten BOP bolts, install turnbuckles, kill line and riser. Install test plug in tubing hanger. Fill stack, close blind rams and purge kill and choke lines. Pressure test BOP stack to tubing spool break, kill line connection and 3.5" FOSV #2 to 250 PSI low / 3000 PSI high - good tests. Test performed with fresh water, held for 5 min. each and charted. R/D test equipment, pull test joint and blow down lines. M/U Baker overshot on 3-1/2" pup joint and RIH with 2 joints of 4-1/2" TXP-BTC tubing. M/U XO and FOSV. Engage retrievable packer at 78.97'. Open equalizing valve with closed FOSV. Open FOSV to verify well on a vacuum. Close annular, release storm packer with 100K PU, 75K SO. Verify no pressure & open annular. Break down FOSV & XO. Pull packer to the rig floor and L/D. All Baker components looked good. Clear rig floor. Wellhead: Set 2.5" BPV bleed void N/D adaptor and tree. Install CTS plug, plug C/L ports standby BOP testing. Pull CTS plug, and BPV from rig floor. M/U 3" LH acme lift sub to L/J. BOLDS hanger broke at 90K high of 115K and travel at 105K. Lay down hanger. Well Name Rig API Number Well Permit Number Start Date End Date MPU F-22 Doyon 14/ CDR2 50-029-22632-00-00 1952010 3/18/2021 4/26/2021 Hilcorp Alaska, LLC Weekly Operations Summary Wellhead: N/D 7" tubing spool, install new pack off seals, RX-54 ring gasket. N/U 11" tubing spool and test. 500/5 5K/10 Good test. Continue R/D ESP and 2-7/8" handling equipment / clear clean floor and demobe spooling unit and move to M-pad / Mobilize 4-1/2" casing equipment to the rig floor / adding 3 BPH hole fill. Spot and r/up HES E-line unit / mobilize well tech tractor and HES CBL tools to rig floor / M/up logging tools and test same / adding 3 BPH hole fill. RIH free fall w/ HES CBL w/ well tech tractor in tow / tag fluid level 1550' wlm / Deploy tractor F/ 4980' t/ tag @ 15,948' 'wlm / Log up and repeat f/ 15,948' t/ 15,700' wlm and main pass f/ 15,948' t/14,200' wllm ETOC @ 15.272' wlm / Pooh chk tools. (Log is all un corrected depth no-tie in) adding 3 BPH hole fill. L/D tractor and e-line tools - everything in good condition. R/D sheave & clear rig floor. Notified AOGCC of upcoming MIT-IA at 18:39 on 22 March 2021. Inspectors Lou Laubenstein and Matthew Herrera waived the right to witness. Mobilize tubing hanger & 7.85' 4-1/2" pup joint to the rig floor. R/U tongs, elevators and slips to run 4-1/2" completion. Adding 3 BPH hole fill. Send CBL to engineer for evaluation. Cement at 15272' - good to proceed. M/U 4-1/2" cut mule shoe pup joint, Magnum Burst Disk with pup joints, 7.85' pup joint, 3.813" X nipple with pup joints, Baker 4-1/2" x 7" Premier Packer with pup joints to 84.36'. Fill pipe - holding. Run 4-1/2" 12.6# L-80 TXP-BTC tubing f/ 84' t/ 2,059'. Torque to 6,170 ft/lbs with Doyon double stack tongs. Fill pipe on the fly & top off every 10 joints. Adding 3 BPH hole fill. Run 4-1/2" 12.6# L-80 TXP-BTC tubing f/ 2,089' t/ 7,889'. 92K PU / 82K SO. Torque to 6,170 ft/lbs with Doyon double stack tongs. Fill pipe on the fly & top off every 10 joints. Adding 3 BPH hole fill. 3/21/2021 String rope through ESP sheave to spooling unit. Pull 2-7/8" 6.5# L-80 EUE tubing f/ 15070'. Crimp on cable pull to cut ESP cable and pull over sheave as continuing to POOH and M/U to spooler. POOH l/dn inspecting 2-7/8" ESP completion string , spooling cable and removing LaSalle clamps and adding 3 bbls every 15 jts f/ 14,894' t/ 11,560' Up/Dn /wt 85k/65k (668 fph avg ). Continue POOH l/dn inspecting 2-7/8" ESP completion string , spooling cable and removing LaSalle clamps and adding 3 bbls every 15 jts f/ 11,560' t/ 7,787' Up wt 70k (628 fph). Change out ESP spool, cut cable at previous splice. Continue POOH l/dn inspecting 2-7/8" ESP completion string , spooling cable and removing LaSalle clamps and adding 3 bbls every 15 jts f/ 7,787' t/ 2,500' Up wt 60k (961 fph). Continue POOH l/dn inspecting 2-7/8" ESP completion string , spooling cable and removing LaSalle clamps and adding 3 bbls every 15 jts f/ 2,500' t/ 72' Up wt 41k (809 fph). Mobilize Centrilift equipment to the rig floor. Cut ESP cable and lower to the spooling unit. Lay down ESP assembly. No oil observed in the pumps or seals, but all shafts rotated freely. Moderate scale observed on pup joint above ESP and minimal scale on ESP. 105 bbls total added to the hole while pulling 2-7/8" ESP string. 251 LaSalle clamps recovered (248 recorded on tally), 5 Protectolizers, 3 flat guards, 479 joints, 2 GLMs w/ pups and XN nipple. R/D 2-7/8" tubing equipment and Centrilift equipment. 3/22/2021 Well Name Rig API Number Well Permit Number Start Date End Date MPU F-22 Doyon 14/ CDR2 50-029-22632-00-00 1952010 3/18/2021 4/26/2021 Hilcorp Alaska, LLC Weekly Operations Summary 4/24/2021 CDR2 Rig: Swapped reports from C-11A. Continue with final rig down checklists. Nipple down BOPE. Nipple up tree cap. PT to 3500#. No leaks. Rig released at 10:30. Completed rig down. Move pits away from rig. Install jeeps on pits. Move sub off and install jeeps. Move rig from MPC-11 to MPF-22. Set mats around cellar and lay Containment. Spot Sub & Pits. Set mats. Secure walk ways and landings. Rig on company time at 2100. Spot Sub & Pits. Set mats. Secure walk ways and landings. Rig on company time at 2100. Hook up interconnect & Electrician check. Good. N/U BOPs & adaptor flanges. Install choke hose. Take on fresh water in pits. Baker re head coil connector on rig floor. Prep for BOP test. Grease valves. 3/26/2021 WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/1500H. DRIFT TBG WITH 20'x3.70"" DUMMY WHIPSTOCK, 3.75"" CENT TO 15768' SLM (unable to pass, tools stick) WHIPSTOCK TARGET DEPTH 15876' MD. tools sit down in 2 spots on the way in 8855' SLM and 12425' SLM, continue RIH with a couple light jar licks at both spots. RDMO, CLOSE PERMIT W/PAD-OP. Continue Run 4-1/2" 12.6# L-80 TXP-BTC tubing f/ 7,889' t/ 13,721'. 122K PU / 92K SO. Torque to 6,170 ft/lbs with Doyon double stack tongs. Fill pipe on the fly & top off every 10 joints. Adding 3 BPH hole fill. Continue Run 4-1/2" 12.6# L-80 TXP- BTC tubing f/ 13,721' t/ 15,720' Torque to 6,170 ft/lbs with Doyon double stack tongs. Fill pipe on the fly & top off every 10 joints. Adding 3 BPH hole fill. / Install hanger w/ BPV installed and plug ports while blowing dn lines / 140K PU / 104K SO. w/ blocks @ 40k RIH and land hanger w/ 64k w/ Mule @ 15, 762' and top of prk @ 15,688' / RILDS,Back out landing jt / R/dn 4-1/2" handling equipment / clear and clean floor / nip/dn bopes and stump back same, Clean hanger Install dart in bpv / N/up tree and test void to 250L / 5000H 5/10min good and shell test tree 250L / 5000H 5/5min good. Pull test dart and BPV with tee bar. PJSM. Rig up circulating lines and squeeze manifold. Flood lines with fresh water and pressure test lines to 250 PSI / 3000 PSI. Pressure test line to tubing to 4500 PSI. Line up to IA. Attempt to pump 8.4 ppg corrosion inhibited source water, but was seeing 200 PSI at 1 SPM. Shut down, blow down lines. Found 2" high pressure hose lining had delaminated & plugged hose. Hose which delaminated was borrowed from the flow bank tank trailer. Retest lines - 3000 PSI. Pump 8.4 ppg CI source water at 3 BPM, 200 PSI. Caught pressure at 26 bbls pumped, 2 BPM, 1150 PSI. Slow pump to 1 BPM, 780 PSI bull heading down IA. Pressure appeared high. Note: had 100 PSI when bull heading during well kill. Shut down, inspect remaining hoses & valves for obstructions, none. Retest lines - 3000 PSI. Continue to bull head 8.4 ppg corrosion inhibited source water 1 BPM, 70 PSI, caught pressure 6 bbls in and pressure increased to 660 PSI ICP,1090 PSI FCP, 250 bbls total. Bull head 43 bbl diesel freeze protection, 1090 PSI ICP, 1130 PSI FCP. Line up to pump down the tubing. Pressure up to 3500 PSI with 3.3 bbls and hold for 15 min as per Baker rep. No indication of set observed, but no indication was expected. Bleed off tubing and line up on IA. Perform 4-1/2" x 7" MIT-IA test to 2000 PSI. Packer set at 15691.52' MD / 6961' TVD. Pump 3.0 bbls. Hold test for 30 min and chart. Bleed off IA, shut in & line up on tubing. Pressure test tubing to 3000 PSI for 30 min on chart - good. Pressure up down the tubing with the test pump and rupture Magnum Burst Disk at 4750 PSI. Rig released at 06:00. Last report for F-22, see M-26 reports for final details. 3/23/2021 Well Name Rig API Number Well Permit Number Start Date End Date MPU F-22 Doyon 14/ CDR2 50-029-22632-00-00 1952010 3/18/2021 4/26/2021 Hilcorp Alaska, LLC Weekly Operations Summary Rih w/ closed choke . Check goose neck alignment, Saddle clamps. Inner reel iron and bulkhead. Continue in hole to 3100'. Start getting some wellhead pressure. Rih to 5000' MD. Up weight 30K / 7. Break circulation. Rate In: 0.50 bpm, Rate out: 0.83 bpm. MW in: 8.34 ppg, MW out: 6.50 ppg. Attempt to take returns to tiger tank. Line froze. Cleared line. Continue in hole. Taking returns to tiger tank. PU weight 15600' MD 52K. Rih through tailpipe without issue. Rih to 15975' MD (Below bottom perf). Rate in: 2.09 bpm, Rate out: 1.77 bpm out. MW in: 8.4 ppg, MW out: 8.42 ppg. Circulate bottoms up. Perform 10 min flow check. Well is static. POOH F/ 15600' T/ surface. Tag up. Rate in: 1.49 bpm, Rate out: 0.79 bpm. MW in 8.34 ppg, MW out: 8.4 ppg. Tag up. Flow Check. Well on slight Vac. Monitor losses. L/D 3.70 Jet tool and BHA. M/U BHA #2 with Baker Gen II Delta Whipstock. 3 5/8 OD X 7''. Set BHA in rams & Strip over . Open rams and tag up for deployment measurements. Fill hole. Took 14 bbl. Fluid level at 900' +/-. 7 BPH Static. RIH Test MWD. Good. RIH from Surface to 15525'. Log down to 15663 Tie in to PDC marker with Geologist. Set depth +28.5'. RIH to 15900 & Log down to 15960'. Unable to see good indication of collars on CCL. POOH & Lod down from 15772' T/ 15960. Log 4.5 completion & two 7'' casing collars. 7'' On depth. 4.5 Shoe logged 26' deep from completion tally. Discus & review logs. Set whipstock on depth. Close EDC & Set whipstock on depth high side with top at 15876' & pinch point at 15881'. Saw & felt good indication of tool setting at 3100 psi. Release from whipstock without issue. POOH to 15749'. Open EDC. Displace coil with power plus at 2 BPM. Close choke and bullhead 15 bbl away. 1130 psi on wellhead while bulheading. Shut down and monitor. Bled to 0 in 12 min. Open choke and displace well to 9.4 ppg power pro mud. 2 BPM at 2-3 BPM. Shut down and monitor losses. Losses at 25 BPH. 4/25/2021 4/26/2021 Swap upper riser for deploying 3" MWD. BHI installed UQC. Service choke manifold and stack. Fluid pack MT coil reel. Fluid pack stack. Purge air out of bleeders. Initial BOPE test . 7-1/16" 5K Stack Annular, Blind /Shear, 2-3/8" Pipe /Slip, 3.0" Pipe / Slip, 2-3/8" Pipe / Slip. All tests 250# / 3500# held for 5 min each. Test-1: Packoff, C7, C9, C10, C16- Passed. IRV Fail / Grease/ Fail. Will replace. Test-2: Blind / Shear, R2, BL2, C15 - Passe. Remove Night Cap, Install 2-3/8" Test joint with test cap. Test-3: Annular (2-3/8"), TIW#1, B4, B1- Annular Fail / Cycle/ Pass. B4 Fail / Grease / Pass. Test-4:Upper 2-3/8" Pipe/Slip, TIW#2, B2, B3 - Pass. Test-5:Lower 2-3/8" Pipe / Slip, C5, C6,C8 - Pass. Test-6: Choke A, Choke C - Pass. Perform Accumulator performance test. Swap to 3" test joint. Test-7: Annular (3.0"), C1, C4 , TV1- Leaking. Re-Test-7: 3.0" Pipe / Slip, C1, C4, Door seal leaking on 3" Pipe ram. Change 3'' pipe ram door seal. Re-Test -7 3.0" pipe/Slip, C1,C4, . Leaking on TV#1. Grease TV1&2. Re test and fail. Change out TV 1 & #2. Re-test-7, 3.0'' Pipe/Slip, C1,C4. T1, Pass Test #8 Annular on 3'' pipe, TV2, C2 & C3. Pass;R/D testing equipment. Install two check valves in coil connector. Stab in and test check valves to 3500 psi. Test Hard line to kill tank to 2500 psi. Install coil counter on horses head. Open SSV & Install fusible cab. Bleed hyd presser to 0.;M/U Baker BHA & 3.70 OD Jet Nozzle. Stab in & RIH to master valve. Displace out FW from real. Load 20 bbl Meth spear and chase with 50 bbl % KCL 140 deg Brine. Open up master valve. Check pressures. 0 pressure on the well. RIH from surface with a closed choke T/ 800'. Inspect new reel & iron while running in the hole. Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 03/31/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-22 (PTD 195-201) CBL Cement Bond Log 03/23/2021 Please include current contact information if different from above. PTD: 1952010 E-Set: 34860 Received by the AOGCC 03/31/2021 03/31/2021 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Prep for CTD 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? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 16,070'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Production 5,410psi 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 Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng dgorm@hilcorp.com 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 16,054' Authorized Signature: 3/11/2021 2-7/8" Perforation Depth MD (ft): See Schematic 7"2,617' See Schematic MILNE PT UNIT F-22 N/A and N/A N/A and N/A Authorized Title: 110'20" 9-5/8" 7" 8,842' 13,437'7,240psi 5,146' 6,992' 8,842' 13,437' 110'110' 6.5# / L-80 / EUE 8rd TVD Burst 15,327' MD N/A 7,240psi 5,750psi 50-029-22632-00-00 Hilcorp Alaska LLC Length Size 7,279'16,010'7,229'2,473 N/A C.O. 432D Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355018 195-201 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 MILNE POINT / KUPARUK RIVER OIL 9,419' COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:56 am, Jan 15, 2021 320-029 Chad Helgeson (1517) 2021.01.15 08:28:44 - 09'00' DSR-1/19/21 ADL 025509, mgr21jan21 321 SFD 1/19/2021 BOPE test to 3000 psi. Annular to 2500 psi. MIT-IA to 2000 psi after setting packer. SFD 1/19/2021 SFD 1/19/2021 10-407 2,473 MGR25JAN21Comm. 1/25/21 dts 1/25/2021 JLC 1/25/2021 mgr25jan21 RBDMS HEW 1/27/2020 WINJ Conversion Well: MPU F-22 Date: 1-14-2021 Well Name:MPU F-22 API Number:50-029-22632-00 Current Status:ESP Producer Pad:F-Pad Estimated Start Date:March 11th , 2021 Rig:Doyon 14 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:195-201 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:Ian Toomey (907) 777-8520 (O) (907) 903-3987 (M) AFE Number:Well EZ Entries Required Yes Current Bottom Hole Pressure:3,184 psi @ 7,120’ TVD SBHP:8.6 PPG Maximum Expected BHP:3,184 psi @ 7,120’ TVD SBHP:8.6 PPG MPSP:2,473 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 75° @ 3,810’- 14,100’ MD Min ID:2.205” ID XN at 15,222’ MD Brief Well Summary: MPU F-22 was drilled in 1996 and completed as a Kuparuk River jet pumped producer. The first ESP was installed 1996. MP F-22 has had multiple ESPs installed: August, 2000 and June, 2006. Notes Regarding Wellbore Condition x No Recent Production CSG tests. x F-42 Offset Injector Support Objective: x Replace TBG Spool x Pull existing ESP completion. x Obtain CBL, Confirm CMT Isolation x Install new 4-1/2” water injection completion. x Set whipstock for coiled tubing drilling Sundry Procedure (Approval Required to Proceed) Pre-Rig Procedure 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Review well kill plan with Engineer based on current well conditions. 6. Circulate wellbore volume (~545 BBLS) with calculated kill fluid based on updated well pressures, down tubing, taking returns up casing to 500 bbl open top returns tank. Monitor well for returns during the well kill. 7. Confirm well is dead. 8. RD Little Red Services and reverse out skid. SFD 1/19/2021 injection c (Flow-through whipstock, per D. Gorm) WINJ Conversion Well: MPU F-22 Date: 1-14-2021 RWO Procedure: 9. MIRU Doyon 14 Rig, ancillary equipment, and lines to returns tank. 10. If needed, bleed off any residual pressure off the IA. Check for pressure and if 0 psi, pull BPV. If needed, kill well w/updated Kill Fluid. Pull BPV 11. Set TWC. 12. Test BOPE to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR ram on 2-7/8” and 4-1/2” test joints. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. e. If TBG hanger leak, conduct a rolling BOP test until Hanger can be pulled repaired and re-test. 13. Bleed any pressure off casing. Pull TWC. Kill well w/updated Kill Fluid as needed. 14. Rig up spoolers for ESP cable. 15. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. Estimate 120 K-lbs PU Wt. w/ no lubricated fluid (Note: Max Pull on 2-7/8” Connection: 144 K-lbs) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 16. Lay down tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH 10 jts of 2-7/8” TBG 18. PU 7” RTTS, MU packer to 2-7/8” String 19. RIH and set the packer at +/- 60’ below the WH 20. Verify Well is isolated. 21. ND BOP, ND TBG Spool 22. NU New TBG Spool, Wellhead Specialist will test pack-off and lower flanged connection to 5000#. 23. NU BOP, set test plug, shell Test BOPE to 250 psi Low/ 3,000 psi High to test connection to the new spool. 24. Pull the Test Plug, RIH release and pull the RTTS packer. 25. POOH and lay down the 2-7/8” tubing while spooling ESP cable. Lay down ESP and motor. a. Note any sand or scale inside or on the outside of the ESP in WSR. Pulled Equipment Disposition Tubing hanger Visually inspect on site then re-stock Tubing & Pup joints Junk ESP Cable Junk GLMS Visually inspect on site then re-stock ESP Equipment Visually inspect on site then provide to Baker for scrap Clamps Visually inspect on site then re-stock XN Nipple Visually inspect on site then re-stock Assure well is dead before setting packer. , Cut ESP cable and tie-off to existing tubing. WINJ Conversion Well: MPU F-22 Date: 1-14-2021 26. RU E-line 27. RIH Tractor/CBL and Log out from 15,901’ MD. (Review CBL Results with OE before running completion.) 28. RD E-line 29. PU and RIH w 4.5” 12.6# L-80 TXP injection completion and packer. Ensure Bust Disk is run below the packer. Confirm the well is static before TIH with BHA. (Note: Top Fill the 4.5” TBG while TIH, Burst disk will prevent circulation down the TBG.) 30. Proposed Running Order a. WLEG b. Magnum Burst Disk (4,500 psi) c. 2 Full Joints of 4-1/2” 12.6# L-80 TBG d. 4-1/2” X Nipple (3.813” ID) e. 1 Joint 4-1/2”, 12.6# L-80 tubing f. Packer set @ +/- 15,670’ MD (200’ MD above the planned Whipstock set depth for CTD) g. ~ 417 jts of 4-1/2”, 12.6# tubing h. 4-1/2” X Nipple (3.813” ID) @ ±2,300’ MD i. ~ 72 jts of 4-1/2”, 12.6# tubing 31. Bullhead 280 bbls clean source water w/corrosion inhibitor and 43 bbls diesel freeze protect down the IA prior to setting the packer a. Freeze protect annular volume = .026 bpf*2,300’ = 43 bbls. 32. Space out to set packer at ±15,670’ and land the tubing into the hanger. RILDS. Lay down landing joint. a. Packer set within 200’ MD of the planned window at 15,870’ MD. b. Note PU (Pick Up) and SO (Slack Off) weights on tally. 33. Test tubing hanger to 250psi low/ 5,000psi High. 34. Pressure up the TBG to hydraulically set the packer per manufacturer’s setting procedure (estimated 3,200 psi). 35. Conduct MIT-IA to 2,000 psi (0.25 psi/ 7,280’ Shoe TVD). i. Notify AOGCC at least 24 hours prior to performing Pre Injection MIT-IA ii. Submit completed Pre-Injection MIT-IA on 10-426 form 36. Confirm passing IA pressure test, pressure up the TBG to pump off the Magnum disk (estimated 4,500 psi). 37. Set TWC. Post-Rig Procedure: 38. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 39. Pull TWC. 40. Replace gauge(s) if removed. 41. Slickline to drift for whipstock setting (high inclination well) 42. Eline to set 4-1/2” x 7” whipstock at 15,470’ and 0 ROHS. If unable to set due to high wellbore deviation the WS will be set with the CTD rig. 43. See PTD for F-22 Coil Tubing Sidetrack for the remainder of the procedure. CBL to AOGCC for review. 15,775' WINJ Conversion Well: MPU F-22 Date: 1-14-2021 Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic 4. 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KB Elev.: 45.84’/ Orig. GL Elev.: 12.0’ RT toCasing Spool = 33.1’ (Nabors 27E) 7” 3 5 6 7 8 9 10 9-5/8” 1 2 KUP A Sands PBTD = 16,010’ (MD) / PBTD =7,229’(TVD) 4 9 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / NT80LHE N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 8,842’ 7" Production 26 / L-80 / BTC 6.276 Surface 13,437’ 7" Production 26 / NT80S / NSCC 6.276 13,437’ 16,054’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 15,327’ JEWELRY DETAIL No Depth Item 1 139’ Sta 2: 2-7/8” x 1” KBMM GLM w/DSOV 2 15,079’ Sta 1: 2-7/8” x 1” KBMM GLM w/DSOV 3 15,222’ 2-7/8” HES XN-Nipple (2.205 No-go ID) 4 15,264.9’ Discharge Head 5 15,265’ Pump 6 15,282’ Gas Separator 7 15,288’ Tandem Seal Section 8 15,302’ Motor 9 15,321’ Pumpmate Sensor 10 15,325’ Centralizer – Bottom @ 15,327’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 15,901’ 15,961’ 7,120’ 7,171’ 60 2/15/1996 Open Ref Log: 2/12/1996 AWS Gr/CC. 22gm Jumbo Jet Charges @ 60 de. Phasing, random orientation, 0.76” EHD, 6.4” TTP. OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset (Approx) in 34” Hole 9-5/8" Cmt w/ 1,691 sx PF “E”, 250 sx “G”, 250 sx PF “G” in 12-1/4” Hole 7” Cmt w/ 499 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = 72 to 75 deg. f/ 3,810’ to 14,100’ Hole Angle through perforations = 34 deg. DLS = 7.3 deg. / 100’ @ 15,600’ TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME on top and 2-7/8” EU 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22773-00-00 Drilled and Cased by Nabors 27E - 1/14/1996 Perforations – 2/15/1996 Frac – 2/27/1996 ESP Install w/ Nabors 4-ES – 4/1/1996 ESP RWO w/ Nabors 4-ES – 8/14/2000 ESP RWO w/ Nabors 4-ES – 6/22/2006 STIMULATION SUMMARY 2/27/1996 120 M# of 16/20 mesh carbolite behind pipe. Design plus small excess – no indication of TSO. _____________________________________________________________________________________ Revised By: TDF 1/6/2020 PROPOSED Milne Point Unit Well: MP F-22 Last Completed: 6/21/2006 PTD: 195-201 TD = 16,070(MD) / TD = 7,279(TVD) 20” 7” 1 3 4 9-5/8” KUP A Sands PBTD = 16,010’ (MD) / PBTD =7,229’(TVD) 2 5 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / NT80LHE N/A Surface 110' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 8,842’ 7" Production 26 / L-80 / BTC 6.276 Surface 13,437’ 7" Production 26 / NT80S / NSCC 6.276 13,437’ 16,054’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP 3.958 Surface ±15,775’ JEWELRY DETAIL No Depth Item 1 ±2,300’ 4-1/2” X-profile (ID 3.813”) 2 ±15,670’ 7” x 4-1/2” Packer 3 ±15,702’ 4-1/2” X-profile (ID 3.813”) 4 ±15,774’ WLEG – Bottom @ ±15,775’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 15,901’ 15,961’ 7,120’ 7,171’ 60 2/15/1996 Open Ref Log: 2/12/1996 AWS Gr/CC. 22gm Jumbo Jet Charges @ 60 de. Phasing, random orientation, 0.76” EHD, 6.4” TTP. OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset (Approx) in 34” Hole 9-5/8" Cmt w/ 1,691 sx PF “E”, 250 sx “G”, 250 sx PF “G” in 12-1/4” Hole 7” Cmt w/ 499 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = 72 to 75 deg. f/ 3,810’ to 14,100’ Hole Angle through perforations = 34 deg. DLS = 7.3 deg./ 100’ @ 15,600’ TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME on top and 2-7/8” EU 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22632-00-00 Drilled and Cased by Nabors 27E - 1/14/1996 Perforations – 2/15/1996 Frac – 2/27/1996 ESP Install w/ Nabors 4-ES – 4/1/1996 ESP RWO w/ Nabors 4-ES – 8/14/2000 ESP RWO w/ Nabors 4-ES – 6/22/2006 STIMULATION SUMMARY 2/27/1996 120 M# of 16/20 mesh carbolite behind pipe. Design plus small excess – no indication of TSO. 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 Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: January 11th, 2021Subject: Changes to Approved Sundry Procedure for Well MP F-22Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAKPreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Operations Manager DatePrepared:Operations Engineer Date Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the Original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: 8 Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Dia?~"~athan TO RE-SCAN Lowell Date:~/~C~ Notes: Re-Scanned by: Begedy Dianna Vincent Nathan Lowell Date: Is~ • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 StigtikEt) FEB 7 December 30, 2011 Mr. Tom Maunder a � Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 1 e F Anchorage, Alaska 99501 ( Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 . BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF -02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 822011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 02 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF-38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/52011 MPF -41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF -45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A WA MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -61 1951170 50029225820000 62 Need top job MPF -62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF-69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF -80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF-81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF -82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF-83 2000930 50029229630000 1.2 N/A 12 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 1.2 N/A 12 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A _ 11.9 8/11/2011 . STATE OF ALASKA a ALA OIL AND GAS CONSERVATION COM"ION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JUl 1 9 2006 1. Operations Performed: Alaska Oil & Gas Cons. Commission o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-~dløgeended Well o Alter Casing 181 Pull Tubing r o Perforate New Pool o Waiver 181 Other Change Out ESP " o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 195-201 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22632-00-00 7. KB Elevation (ft): 45.85 9. Well Name and Number: MPF-22 8. Property Designation: 10. Field / Pool(s): ADL 355018' Milne Point Unit / Kuparuk River Sands' 11. Present well condition summary Total depth: measured 16070 feet true vertical 7280 feet Plugs (measured) None Effective depth: measured 16010 feet Junk (measured) None true vertical 7230 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 8806' 9-5/8" 8842' 4513' 5750 3090 Intermediate Production 16021' 7" 16054' 7266' 7240 5410 Liner c'~',r, " ,"'~ "-I" f r~ ~~. ,1 ~'\.;\i"~, \;~, ~t::;;./ . Perforation Depth MD (ft): 15901' - 15961' Perforation Depth TVD (ft): 7139' - 7189' 2-7/8",6.5# L-80 15327' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Fl AUG 0 9 2006 13. ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casin!: Pressure Tubina Pressure Prior to well operation: 0 0 0 1240 0 Subsequent to operation: 113 . 431 230 400 395 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil' o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant ~~~ ß Prepared By Name/Number: Sign5i.Ìure '"" ~ Phone 564-4750 Date O1-l'l)-:{)l.çSondra Stewman, 564-4750 . . Form 10-404 Revised 04/2006 0 R \ G \ N A L ~sub~t Onglnal Only ,/S.D 7·ZO.4>-6 d 74.,4 Tree: Cameron 2 9/16" 5M Wellhead: 11" x 7 1/16" 5M FMC Gen 5A, w/2 7/8" FMC tbg. hng., 3" LH acme on top and 2 7/8" EUE 8 rd on bottom, 2.5" CIW BPV profile 20", 91.1 ppf, NT80LHE I 115' 9 5/8", 40#/ft, L-80 Btrc. 18842' md I KOP @ 400' Max. hole angle = 72 to 75 deg. fl 3810' to 14,100' Hole angle through perfs = 34 deg. DLS = 7.3 deg/100' @ 15,600' 27/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, production casing NSCC connections fl TD to 1976' md and BTRC connections to surface. (drift ID = 6.151", cap. = 0.0383 bpf) Stimulation Summary 02/27/96 - 120 M # 16-20 mesh Carbolite proppant behind casing. Design plus sma excess - no indication of TSO. Perforation Summary Ref loa: 2/12/96 AWS ar/cc Kuparuk "A" Sand SIZE SPF INTERVAL (TVD) 33/8" 6 15,901-15,961 7120-7171 22 gm Jumbo Jet charges@ 60 deg. phasing, random orientation, 0.76" EHD, 6.4" TIP mid-perf = 7145' tvd 15941' md MPU F-22 Orig.RTElev. = 45.85' (N 27E) Orig. GL Elev. = 12.0' RT To csg. spool = 33.01' (N 27E) Cameo 2 7/8" x 1" sidepoeket KBMG GLM I 139' I Cameo 2 7/8" x 1" sidepoeket KBMG GLM 115,079' I 115,222' I 2-7/8" HES XN Nipple ( 2.025 Centrilift Pump GPMTAR 1:1 151 stg. 1 GC1700 115,265' I Centrilift Gas Separator GRSFTXAR 400 Internals Centrilift Tandem Seal Section GSB3DBUT AB/HSNPFSA GSB3DBL TAB/HSN FSA CL5 15,283' I 15,288' I Centrilift KMH Motor, 228 HP, 2305 volt,60 amp, KME-1 195 ~"p~~e1d45 volt, 52 ampI15,302' I Centrilift I ' I Pump Mate w/6 fin Centralizer 15,321 7" short joint from 15,413' to 15,433' md 7" float collar (PBTD) 7" float shoe 7184' tvd 116.010' md 116,054' mdl DATE REV. BY COMMENTS MILNE POINT UNIT 01 /14/ 96 JBF Drilled and Cased b Nabors 27E WELL F-22 03 / 31 I 9 JBF Initial ESP Completion by Nabors 4E API NO: 50-029-22632 8/14/00 GMH RWO C/O ESP Nabors 4ES 6/21/06 MDO ESP RWO 4-ES BP EXPLORATION AK Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-22 MPF-22 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/18/2006 Rig Release: 6/22/2006 Rig Number: 4ES Spud Date: 8/12/2000 End: 6/22/2006 6/19/2006 01 :00 - 03:00 2.00 RIGD P PRE Lower Derrick. Disconnect services and rig-down modules. 03:00 - 04:30 1.50 MOB P PRE Move Rig and modules from MPF-45 to MPF-22. 04:30 - 06:00 1.50 MOB P PRE Spot Sub Base. Spot Pipe Shed and Pits. 06:00 - 07:00 1.00 MOB P PRE Raise and scope up Derrick. 07:00 - 07:30 0.50 MOB P PRE Pick-up Lubricator and pull BPV. Lay down same. Tbg = 500 psi. Csg = 1240 psi. 07:30 - 08:30 1.00 MOB P PRE Spot Tiger Tank. Lay lines to Tiger Tang. Hook-up lines to Tree. Ready to take-on Sea Water in Pits. Begin WO Vae Trucks. Accepted Rig at 08:30 hrs. 08:30 - 12:00 3.50 KILL N FLUD DECOMP First Vac Truck arrives on Location at Noon. Continue to wait on additional Sea Water. 12:00 - 13:00 1.00 KILL P DECOMP Take on 120 deg Sea Watr in Pits. 13:00 - 13:30 0.50 KILL P DECOMP Test Lines at 250/3500 psi. 13:30 - 14:00 0.50 KILL P DECOMP Hold PJSM for Well Kill. Notify MPU Pad Operator, MPU Front Desk, and NAbors Rig 3 that we will be venting Gas. 14:00 - 18:00 4.00 KILL P DECOMP Circulate 120 deg Sea Water at 3 bpm/1050 - 2100 psi. Return were Gas, heavy gas cut oil. Unable to clean-up Well before we ran out of Sea Water. Pumped 700 plus bbls. Discussed with MPU to find out if some other Well might be supporting MPF-22. SITP = 350 SICP = 610 psi. 18:00 - 23:00 5.00 KILL P DECOMP Monitor well Pressure dropped as follows: SITP 350 psi down to 130 psi. SICP 610 psi down to 460 psi. in 2 hrs. Open well & bleed off pressure. TP 0 psi, CP 230 psi. Wait on seawater. Clean & maintain rig. SI well TP increased to 50 & CP 280 psi. bled again TP 0 psi & CP 200 psi. 23:00 - 00:00 1.00 KILL P DECOMP Take on seawater. TP 0 psi, CP 160 psi. 6/20/2006 00:00 - 01 :30 1.50 KILL P DECOMP Circulate well wI seawater ( wt = 8.4 ppg) Pumped 4 BPM @ 1500 psi. Had Disel returns immediately. After 60 bbls had warm seawater. Pumped total of 210 bbls. No gas 100% seawater. SD & monitor well. 01 :30 - 02:00 0.50 KILL P DECOMP Monitor well. Well flowed slightly & decreased to dribble. SIW no pressure on gauges. Open well wI very slight flow. 02:00 - 07:30 5.50 KILL P DECOMP Weight up system to 8.7 ppg. Circulate well @ 3 BPM 980 psi. 07:30 - 08:00 0.50 KILL P DECOMP Monitor well, well dead. 08:00 - 09:30 1.50 WHSUR P DECOMP PJSM. Set two way check valve, NID tree. 09:30 - 11 :00 1.50 BOPSU P DECOMP PJSM. NIU 13 5/8" x 5M BOPE. 11 :00 - 14:30 3.50 BOPSU P DECOMP PJSM. Full test on BOPE, choke & associated components. Witnessing of test waived by AOGCC State Rep John Spaulding. 14:30 - 15:00 0.50 BOPSU DECOMP PJSM. PIU lubricator, pull two way check valve. 15:00 - 15:30 0.50 PULL DECOMP PJSM. Pick up landing joint, BOLDs. Pull hanger to florr, 99K up wt & steady. Fill hole, 6 bbls to fill. 15:30 - 16:30 1.00 PULL P DECOMP Wait on ESP cable spooler. 16:30 - 17:00 0.50 PULL P DECOMP PJSM. Rig up spooler. 17:00 - 22:00 5.00 PULL P DECOMP PJSM. POOH w/2 7/8" ESP completion. Pulled & stood back 78 stands of 2 7/8' tubing. 22:00 - 23:00 1.00 PULL P DECOMP Cut cable & change out spools in spooling unit. 23:00 - 00:00 1.00 PULL P DECOMP Cont to POOH & stand back 2 7/8" tubing. 6/21/2006 00:00 - 03:30 3.50 PULL P DECOMP Con't to POOH & standbaek 2 7/8" tubing. pulled total of 158 stands, UD 5 singles. Jt #1 had 8 punched holes in it at the top. Holes fully penetrated tubing. 10' pup above pump had single hole punched in it. 03:30 - 06:00 2.50 PULL P DECOMP Pull, drain, UD & inspect ESP. Printed: 6/26/2006 7:13:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF·22 MPF·22 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/18/2006 Rig Release: 6/22/2006 Rig Number: 4ES Spud Date: 8/12/2000 End: 6/22/2006 06:00 - 06:30 06:30 - 07:00 07:00 - 09:30 09:30 - 10:30 10:30 - 11 :30 11 :30 - 12:30 12:30 - 18:30 18:30 - 22:30 4.00 22:30 - 00:00 1.50 6/22/2006 00:00 - 04:00 4.00 04:00 - 04:30 0.50 04:30 - 07:00 2.50 07:00 - 07:30 0.50 07:30 - 09:00 09:00 - 11 :00 Lube & service rig. Clear I clean rig floor. PJSM. P/U & make up ESP pump assembly. Service pump. Wait on Centrilift. PJSM. RIH wi 2 7/8" ESP completion. Check conductivity on motor, test failed. POOH. RUNCMP PJSM. CIO sensor in pump motor & test same, OK. RUNCMP PJSM. RIH w/2 7/8" ESP completion, checking conductivity & pumping down tbg every 2000' @ 1 bpm I 1600 psi, OK. Ran in hole wI 80 stands. RUNCMP Make reel to reel splice. Check & test same. RUNCMP Con't to RIH wI ESP on stands of 2 7/8" DP. Pump thru ESP & check cable every 2000'. Pimp in 1 BPM @ 1700 psi. RUNCMP Can't to RIH w/2 7/8" ESP completion. Ran 479 jts. Used 3 flat guards, 6 proteetolizers & 428 LaSalle clamps. RUNCMP P/U landing jt & hanger. M/U hanger & Install penetrator. P/U wt = 84k, S/O wt = 39K. RUNCMP Cut cable & Make field connection. Test same. Lay excess cable & elephant trunk. Install brass cap on penetrator. RUNCMP PJSM. Land tubing hanger. RILDs. Install two way check valve. RUNCMP PJSM. N/D BOPE. RUNCMP PJSM. N/U tree. Pressure test tree & hanger to 5000 psi, OK. Pull two way check valve & set BPV. Make final check on ESP, OK. Secure well. Rig released @ 11 :00 hrs, 06/22/2006. Printed: 6/26/2006 7:13:10 AM A h¢sred i .c-es ri-.! IJln g TO: Blair Wondzell FROM: Chris West DATE: October 27, 1995 SUBJECT: MPB-24 Well Suspension APl # 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose Setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8" x 7" annulus available for the injection of liquid 'wastes. There are no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if I maY be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 ANNULAR INJECTION DATA ENTRY SCREEN SCANNED NOV ! :t 2002 Asset MJlD.e. .......................................... Legal Desc [;.f]I;..Ot~.,.'[.13H,.B.1.0J[..I,I.[VI ....................................................................... Research Rig Name ~.~iI~.~.r.~..2Z.F~ ............................. Inj Well Name M..P...F.:~2 .............................. '. ...... Permit Start ....... .12L.1.2[.~.~ ....... Permit End ....... !2/..1.~.~t.~ ....... Sur Csg Dep {~.8..~.1 ................. , Cumulative Data Rig completion Formation Intermittant Final, Well Total Mud/Ctg Wash Fluids FlUids Freeze Freeze ......... .6~,,5.3.~ .................. .6..,.4.fi.6. ......... ' ............ 7..0. ............ Daily Data :~' Da~O~ ~n~ed I R~w~ ~ ~':~-"::' ~ ...._ Well I~ ~ ; : Tc~31 Rate ~ ~ ~~ .~,~'~ ................ ................................................................................................................................................................. MPF-14 01/15/96 ~ r~ MPF-14 01/16/96 242 242 MPF-~'~ ......... ~'~'~ .......... ~ ..................................... 430 ~ -- .................................... MPF-14 01/18/96 600 600 MPF-14 01/19/96 1,535 1,535 . ..................................................................................................................................................................................... MPF-14 01/20/96 310 310 MPF-14 01/21/96 255 255 MPF-14 01/2~96 628 628 '~'~ ......................... 6'~'~ .................. ~'~'~' ............................................................................................................................................................................................................................................................................................... ~ '~"~ 6~/~6 ............ ~ ~ '~ ~ ~'~'~:'~'~ ...................... ~6'~"~'~ ................... ~"~'~6~ ~ .......................................................................................................................... ~6 ........................................ ~'"~'~6 I 1 - ................................................................................................................................................. .......................................................................................................................... ................... .~2.'.'.'.".'2 ~..'.'.','.'2.'.'.'2. ','.'.'.'.",'.'.T,'.'.".'~"..'2'-.'T,''~ ~'~'," '",'2',",','2.'.'.'.'.".".'.'.-2. '22.'2.','2'~'~'.'..'~.'22.'.','2.'2~','.' ~2.'.'.',',"2.¥,'~2,'.".','.'.',' .............................................. .'.',T,'.'~','~'.','.".'.',".',".'.'.','.'~.".'.".'2,'.'.' ........ .'"'"-.",",."'",'.'~','.".'2, red rvices rilling 900 East Benson Boulevard, MB 8'1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 RECEIVED Re: Annular Disposal Information Request Dear Ms. Mahan: DEC 141998 Alaska 0il & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular Disposal Records from July 25, 1995 through present time. We compared your list with Our records and are able to provide you with the following data: · Individual Annular Disposal Logs from the SSD database which coincide with the approved wells on your attached AOGCC Annular Log. The SSD records are provided to you in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified as follows: · Endicott wells 1-037P-16, 1-65/N-25, 1-59/0-24 · Exploration well Pete's Wicked #1 · Milne Point wells E-22, E-23, F-O1, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & #2, K-05, K-02, H-07, K-25, K-37, E-17, F-21, K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11-38 The reason many of these annuli were not used is because the waste materials generated frOm these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disPosal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a Sundry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. We also provide you with a cumulative report from our database of recOrds from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular dispOsal: -. ,Annular Disposal Letter 12/14/98 ~4 · I~_~ q4- ~ 4z.- q4-15'2~ I I / · Endicott wells 1-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdough #3 - ~.~oo ~ ,~ ' · Mihe Point wells F-06, ~-05, ~-06, J'13, L-24 - qs-~ ~ · PBU wells-18-30, 18-31, 14~,~-4~, -~-34, E-36, G-~A, ~d S-33- · hdividual logs are provided to ~ou f6? these ~gs tis w'e~l. · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) $C;ANNED NOV 1 B 2002 RECEIVED AiasF. a^ '-niiu &GasCons. Commissio~ Anchorag~ 86HI l :330 ~ e6ed uedo. 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INrl :lo,El 'N£~1';90 oeS ' ~_~6' I~ :10 H:I 'NE:~/'90'~)eS lelo± wno oseQ le§e-1 6 L 6/. 0Z-_-IdlAI :1~ sJoqel~ 0699 lz [--'ld~l :1~ sJoqel~ 99Z8 g0--Idln/ =1~ sJoqel~ qldec] IleM !Ul §!E §u!s~o eoepns ~ode~l e^!lelntuno I]66 [ Jeqtuaoea IRun S66 L 'g~: ~lnr setunloA uo!loelul Jelnuuv 6U!ll!ZO ao!~S I~'JeqS Shared 9ei~vice Dr, illing Ann'bl~'r injection VolUmes July 25, 1995. until December 1998 Cumulative Report Surface Casing Rig Inj Well Depth Nabors 28E B-33 3504' Nabors 28E E-34 3664 Nabors 28E E-36 3648 Nabors 28E E-37 3810 Cum Mud Legal Desc Cum Total & Ctgs 969'SNL, 1898'EWL, Sec 31, T11N, R 14E 3,974 2,842 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 7,228 1706'SNL 822'WEL, Sec 6,T11N, R14E 9,271 4,417 3391'NSL 881'WEL, Sec 6,T11N, R14E 4,695 4,241 Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Wash Fluids Fluids Freeze Freeze Starl End Status 857 195 80 5/1/96 12/31/96 Broached 1,420 858 40 110 8/23/95 12/31/95 Open 1,293 3,096 365 100 7/25/95 12/31/95 Open 374 80 9/16/95 12/31/95 Open Nabors 28E E-39 3638 3358'NSL 501'WEL, Sec 6,T11N, R14E 2,250 928 220 1,022 80 8/28/95 12/31/95 Open Nabors 28E G-04A 3509 2917'NSL 1974'WEL, Sec 12,T11N, R13E 5,937 1,798 1.824 2,315 10/20/95 12/31/95 Open Nabors 28E G-21 3509 2911'NSL 2368'WEL. Sec 12,T11N, R14E 11,430 3,956 3.072 4.270 70 '62 9/8/95 12/31/95 Open Nabors 28E S-24 2750 1633'SNL 4228'WEL, Sec 35,T12N, R12E 20,261 11,773 2,177 5,751 275 285 12/9/95 12/9/96 O3en Nabors 28E S-33 2958 1639'SNL 1487'WEL, Sec 35,T12N, R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 12/1/96 O3en Nabors 28E S-41 3331 4152' NSL, 4504' WEL, Sec 35,T12N, 8,062 4,159 2.034 1,754 115 2/8/96 2/8/97 O ~en Nabors 28E S-42 3077 Sec 35, T12N, R12E 168 100 68 3/13/96 3/13/97 O )en Nabors 2ES H-35 3157 4535'NSL, 1266'WEL, Sec 21,T11N, R13E 4,860 3,725 555 480 20 80 10/26/95 12/31/95 O)en N.aI~.0.[~..~.E.~ ........... H;~.6 .................................... 3~..0. ............................. ~7?.N...S..!~!...!.~.5'.v~!~..L.,....~C2...!..!..T_.~..!..!~.,_!~.3.E. ...................... .1...,..4.5..~ ...................................... ~.5...7_ .................................... ?)..0.. ................................ .4...1...0. ............................................................................................................................................. ~ ............. 1....~!~6..!~.5 ..................... !.2!3..!.!.9.~ .......................... ?_).~.~ .............. Page 3 Og gg O g 0.3 O0 W c:LO~-'~]:LM.DOC STATE OF ALASKA ALASK,;-, ~IL AND GAS CONSERVATION COMM,o°ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 45.85 [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1897' NSL, 2802' WEL, SEC. 06, T13N, R10E MPF-22 At top of productive interval 9. Permit Number / Approval No. 195-201 3604' NSL, 1813' WEL, SEC. 25, T14N, R09E 10. APl Number At effective depth0 GII I/ L_ 50- 029-22632-00 3666' NSL, 1815' WEL, SEC. 25, T14N, R09E 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 3699' NSL, 1816' WEL, SEC. 25, T14N, R09E Sands 12. Present well condition summary Total depth: measured 16070 feet Plugs (measured) true vertical 7280 feet Effective depth: measured 16010 feet Junk (measured) true vertical 7230 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 260 sx Arcticset (Approx.) 110' 110' Surface 8806' 9-5/8" 1691 sx PF 'E', 250 sx 'G', 250 sx RE 'C' 8842' 4513' Intermediate Production 16021' 7" 499 sx Class 'G' 16054' 7266' Liner Perforation depth: measured 15901' - 15961' .~ true vertical 7139' - 7189' ,,/~.!.~ i': .i~ -'i Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 15282' . .... ............. · · Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the forpgoing is true and correct to the best of my knowledge Signed TerrieHubble"~/~¢~ I~~ Title TechnicalAssistant Date Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Le0al Well Name: MPF~22 Common Well Name: MPF-22 Spud Date: 8/12/2000 Event Name: WORKOVER Start: 8/12/2000 End' Contractor Name: NABOR$ Rio Release: Group: RIG Ri9 Name: NABOR$ 4E8 Rig Number: iate ::~:~ -z}:~O.:: ty of Operations 8/12/2000 i10:00 - 17:00 7.00 MOB DEGOMP R/D from MPF-81 & move on & R/U on MPF-22. 17:00 - 18:00 1.00 KILL DECOMP R/U HCR & kill line to annulus. Pull BPV. 18:00 - 19:00 1.00 KILL DECOMP Test hard lines to 2500 psi, OK. 19:00 - 21:30 2.50 KILL DEGOMP Take on kill fluid. Hang elephant hose & tongs. SICP 800 psi, SITP 500 psi. 21:30 - 00:00 2.50 KILL DECOMP Bleed off gas. Pump 40 bbl EP sweep in seawater to kill well. 8/13~2000 00:00 - 02:30 2.50 KILL DECOMP Kill well w/seawater (8.5 PPG) Took returns to tiger tank. 02:30 - 04:00 1.50 KILL DECOMP Monitor well, well dead. shot FL in annulus - 2475' Wait 30 min re-shot FL -3300'. Fill hole, took 36 bbls. 04:00- 04:30 0.50 WHSUR DEOOMP Set TWO. 04:30 - 05:30 1.00 WHSUR DECOMP N/D X-mas tree. 05:30- 07:30 2.00 BOPSUF~ DECOMP N/U BOPE. 07:30 - 08:30 1.00 BOPSUR DECOMP Perform body & function test on BOPE. LP 300 psi, HP 3500 psi, OK. 08:30- 09:00 0.50 WHSUR DEGOMP Pull TWO. 09:00 - 10:00 1.00 WHSUR DECOMP Pull tbg hanger. Work pipe pull wt. down to 115K. 10:00 - 10:30 0.50 KILL DECOMP Fill hole w/57 Bbls (FL @ 1585') L/D hanger. 10:30 - 19:30 9.00 PULL DEOOMP POOH w/completion string. 19:30 - 21:00 1.50 PULL DECOMP Inspect, break out & I/d ESP pump assy. 21:00 - 22:00 1.00 RUNCO~ DECOMP L/D old pump & pack in shipping containers. Lay out replacement its. Change out reels in spooling unit. 22:00 - 00:00 2.00 RUNCO~4 DECOMP P/U new ESP assy & assemble same. Service motor. Fluid losses for day 270 bbls. 8/14/2000 00:00 - 15:30 15.50 RUNCOI~I DECOMP Run in hole w/completion string, ran 479 its. 15:30 - 16:00 0.50 RUNCOI~I DECOMP P/U landing jt & M/U in hanger. P/U wt 78K, SIC wt 40K. Completion I string set @ 15282'. (see tbg detail report) 16:00- 17:00 1.00 RUNCOI~ DECOMP Make BIW splice. 17:00 - 17:30 0.50 RUNCOI~I DECOMP Land tbg hanger & L/D landing it. 17:30 - 18:00 0.50 WHSUR DECOMP Install TWC & test to 2500 psi, OK. 18:00- 19:30 1.50 BOPSUF DECOMP N/D BOPE. 19:30 - 21:00 1.50 WHSUR DECOMP N/U X-mas tree. Test adapterflange & tree to 5000 psi, OK. 21:00 - 22:30 1.50 WHSUR DECOMP PJU & pull TWC. Install BPV. R/D lubricator. 22:30 - 00:00 1.50 DEMOB DECOMP PJD cellar & secure well. Clean tanks. RELEASE RIG @ 1159 HRS 8-14-00. !-'' ''.: -~ i ' · ', .. . .. Printed: 8/29/2000 2:58:00 PM P E RM I T DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS 95-201 7041 ~t~MWD SPERRY'S FM EVAL 95-201 DGR/CNO/SLD ~/SPERRY MWD/TVD ~1'o~ ~ 7~-)~- 95-201 DGR/CN0/SLD ~m/SPERRY MWD/~ 95-201 DGR/EWR~ ~! ~SPERRY MWD/TVD 95-201 DGR/ROP/EWR~~! ~SPERRYMWD/MD 95-201 GR/CCL </z~'SEPIA 95-201 GR/CCL Cf~ ~ ~L~SEPIA 95-201 PLS-STAT ~/SEPIA 95-201 6995 /~~W[AT~S Page: Date: RUN 1 04/20/98 RECVD 04/23/96 05/07/96 05/07/96 05/07/96 05/07/96 02/20/96 03/01/96 03/01/96 03/11/96 T 10-407 ~R~ COMPLETION DATE DAILY WELL OPS R IX/2ff/9'J-/ TO ~/// /~/ Are dry ditch samples required? yes ~ And received? Was the well cored? yes ~ Are well tests required? yes Well is in compliance ~5 I~itial COMMENTS Analysis & description received? :~------~_ Received? eQL~S.~:~no ~ ~ STATE OF ALASKA ALAS;,,-, OIL AND GAS CONSERVATION C~,vlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 95-201 96-003 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~~ 50-029-22632 4. Location of well at surface ~ ~"~'-'~' ~ '*~ 9. Unit or Lease Name ........................ ,~ Y~-t~.~-.:.~:~:~. Milne Point Unit 1897' NSL, 2802' WEL, SEC. 6, T13N, R10E; At top of productive interval i ./..,a!'~-~ i ,~['~''~¢f''?--"L¢~ / 10. Well Number 3591' NSL, 1811' WEL, SEC. 25, T14N, RS i'.E.,?/'_~.~//~_~=~ ~ ~.~ MPF-22 ~ ' ~ !11 Field and Pool At total depth ~ ~-i~,IF.iE0 ~ . . 3699' NSL, 1814' WEL, SEC. 25, T14N, RD~E_~ Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16: Lea%'l~-esignation and Serial No. Sands KBE = 45.85I ADL 355018 12. Date Spudded12/25/95 I13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if OffshOre 116' NO' Of COmpletiOns01/10/96 03/31/96 N/A MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Surveyl20. Depth where SSSV set,.1. Thickness of Permafrosl 16070 7279 FT 16010 7229 FT []Yes [] No I N/A MD! 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, Gyro, LWD, GR, CCL, RES, NEU, DEN, SLD, EWR4 23. CASING, LINER AND CEMENTING RECORD CASING SE'FrING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# NT80LHE Surface 110' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 36' 8842' 12-1/4" 1691 sx PF 'E', 250 sx 'G', 250 sx PF 'C' 7" 26# L-80 33' 16054' 8-1/2" 499 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 2-7/8", 6.5#, L-80 15273' -- M D TVD M D TVD 15901' - 15961' 7138' - 7188' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 15901' - 15961' Frac'd w/120,000# 16/20 Carbolite Behind Pipe Freeze Protect with 85 Bbls of Diesel 27. PRODUCTION TEST lDate First Production Method of Operation (Flowing, gas lift, etc.) May 10, 1996 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED ]~ [OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED ORIGINAL Alaska 011 & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 30. Formation Tests Geologic Mar!: Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Kuparuk D 15728' 6993' Kuparuk C 15874' 7116' Kuparuk B 15874' 7116' Kuparuk A 15874' 7116' Kuparuk A3 15874' 7116' Kuparuk A2 15874' 7116' Kuparuk A1 Miluveach 15958' 7186' SL~P ~ 0 Alaska 011 & (~as Cons. Commission Anchorage 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report the fore oing is true and cor'~e~t~,~ to the best of my knowledge//'/~-~-~/~ 32.1hereby certify that ~ Signed -nm Schofield " ¢ Title Senior Drilling Engineer Date · Prepared By Name/Number: Terrie Hubbl¢, 5~4-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 /A~NL~ILA[R ~INJEQTF~oO~ ID/ATAI~ASE AINID L.©~ Rig Name Surf Csg Dep 3405' MD Well Cum Total Cum Mud/Ctg Legal Desc (Sec, T, R) Cum Brine Cum Water Cum Dies/FP VOLUME (BBLS' Method of displosal=pumping down outer annulus SOURCE WELL DATE OF MUD/CTGS BRINE WATER DIESEL/FREEZE Ii Daily Cum. Total COMPLICATIONS, COMMENTS NUMBER INJECTION PROT. MP F-25 3,9/95 80 I MP F-25 3/1 0/95 75 110 . M P F-22 1 2 / 2 9 / 9 5 5 2 7 MP F-22 12/30/95 21 73 UP F-22 1 2 / 31 / 95 2 77 oo, lO M P F-22 1 / 2 / 9 6 335 1 2 MP F-22 1/8/95 70 UP F-22 1/9/95 120 10 U P F-22 1 / 1 0 / 9 5 7 5 1 0 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX ! ARCO Well Name: M PF-22 Rig Name: N-27E AFE: 330205 Accept Date: 1 2/24/95 Spud Date: 1 2/25/95 Release Date: 01/1 3/96 Dec 24 1995 (1) Rig moved 100 %. Dec 25 1995 (2) Rigged up Divertor. Tested Well control. Fill pits with Water based mud. Made up BHA no. 1 . Drilled to 500 ft. Dec 26 1995 (3) Drilled to 3020 ft. Circulated at 3020 ft. Pulled out of hole to 300 ft. Serviced Block line. R.I.H. to 3020 ft. Dec 27 1995 (4) R.I.H. to 3020 ft. Drilled to 4724 ft. Circulated at 4724 ft. Pulled out of hole to 3352 ft. R.I.H. to 4724 ft. Drilled to 5400 ft. Dec 28 1995 (5) Drilled to 6235 ft. Circulated at 6235 ft. Pulled out of hole to 855 ft. Pulled BHA. Made up BHA no. 2. R.I.H. to 6235 ft. Drilled to 7350 ft. 1995 (6) Drilled to 7926 ft. Circulated at 7926 ft. Pulled out of hole to 7926 ft. R.I.H. to 7926 ft. Drilled to 8870 ft. Dec 30 1995 (7) Circulated at 8870 ft. Pulled out of hole to 900 ft. R.I.H. to 8870 ft. Circulated at 8870 ft. Pulled out of hole to 8870 ft. Rigged up Casing handling equipment. Ran Casing on landing string to 8500 ft. Dec 29 Operations Summary for: Dec 31 1995 (8) Ran Casing on landing string to 9.625 ft. Circulated at 8841 ft. Batch mixed slurry - 706 bbl. Rigged down Divertor. Mixed and pumped slurry- 150 bbl. Held safety meeting. Installed Casing spool. Installed Casing hanger. Rigged up BOP stack. Rigged up Choke manifold. Rigged up High pressure lines. Tested BOP stack. Rigged up Drillstring handling equipment. Made up BHA no. 3. Jan I 1996 (9) R.I.H. to 5806 ft. R.I.H. to 8990 ft. Pulled out of hole to 5806 ft. R.I.H. to 7412 ft. Held drill (Stripping). R.I.H. to 8743 ft. Tested Casing. Drilled cement to 8880 ft. Circulated at 8880 ft. Performed formation integrity test. Drilled to 9788 ft. Jan 2 1996 (10) Drilled to 10261 ft. Circulated at 10261 ft. Pulled out of hole to 8739 ft. R.I.H. to 10261 ft. Circulated at 10261 ft. Ran electric logs. Drilled to 10829 ft. Jan 3 1996 (11) Drilled to 12241 ft. Circulated at 12241 ft. Pulled out of hole to 10356 ft. R.I.H. to 12241 ft. Drilled to 12650 ft. Jan 4 1996 (12) Drilled to 14105 ft. Circulated at 14105 ft. Pulled out of hole to 12241 ft. R.I.H. to 14105 ft. Drilled to 14229 ft. Jan 5 1996 (13) Drilled to 15369 ft. Jan 6 1996 (14) Drilled to 15369 ft. Circulated at 15707 ft. Pulled out of hole to 891 ft. Pulled BHA. Made up BHA no. 4. Jan 7 1996 (15) Made up BHA no. 4. Serviced Top drive. Serviced Block line. R.I.H. to 17607 ft. Drilled to 15725 ft. Flow check. Drilled to 15783 ft. Functioned downhole tools at 15783 ft. Circulated at 15725 ft. Drilled to 15852 ft. Jan 8 1996 (16) Drilled to 15916 ft. Monitor well pressures. Circulated closed in well at 15916 ft. Drilled to 16010 ft. Circulated at 8840 ft. Pulled out of hole to 8800 ft. Repaired Top drive. R.I.H. to 16010 ft. Page 2 Operations Summary for: Jan 9 1996 (17) Drilled to 16064 ft. Worked toolstring at 16064 ft. Circulated at 16064 ft. Reamed to 16064 ft. Pulled out of hole to 892 ft. Pulled BHA. Jan 10 1996 (18) Pulled BHA. Tested High pressure lines. Made up BHA no. 5 . R.I.H. to 15831 ft. Reamed to 16067 ft. Pulled out of hole to 0 ft. Jan 11 1996 (19) Pulled out of hole to 0 ft. Pulled BHA. Made up BHA no. 6 . R.I.H. to 15841 ft. Reamed to 16070 ft. Drilled to 16070 ft. Circulated at 16070 ft. Laid down 6400 ft of 5 in OD drill pipe. Jan 12 1996 (20) Laid down 8729 ft of 5 in OD drill pipe. Serviced Block line. Pulled BHA. Removed Bore protector. Rigged up Casing handling equipment. Ran Casing to 8800 ft (7 in OD). Circulated at 8800 ft. Ran Casing to 9200 ft (7 in OD). Jan 13 1996 (21) Ran Casing to 16054 ft (7 in OD). Circulated at 16054 ft. Mixed and pumped slurry - 92 bbl. Displaced slurry - 611 bbl. Tested Casing. Wait on cement. Flow check. Jan 14 1996 (22) Flow check. Installed Seal assembly. Rigged down BOP stack. Installed Xmas tree integral components. Tested All tree valves. Installed Hanger plug. Rig Release. Feb 15 - 16, 1996 Rigged up Western Atlas Wireline Service. Perforated 60' MD of Kuparuk 'A' sand. Ran static pressure survey. Well is ready for frac. Total perf interval is 15901' - 15961' MD BKB, referenced to 2/12/96 AWS GR/CCL. GR/CCl 22' shallow to 01/09/96 Sperry DGR LWD Icg. Perf Gun Information: All guns 3-3/8" Jumbo Jet, 22.0 gm charges, 0.76" EHD, 6.4" TTP, 6 SPF, 60 degree phasing, random orientation. Page 3 SEP s 0 ' 996 Gas Con~. commission Anchorage Operations Summary for: Feb 27, 1996 Rig up BJ Frac equipment. Performed an Injectivity Test, Data Frac and Frac. Pumped 120,000 lbs 16/20 Carbolite behind pipe through perforations. Rig down. Mar 3, 1996 Rig up coil tubing unit for post frac clean out. Run in to 10050 ft without tagging (slickline tag 9980 ft). Pick up to 9950 ft and RIH reversing. Mostly clean returns. Coil clogged at 14960 ft. Unable to circulate or reverse. POOH. Unable to complete wrapos as coil hitting the base of the reelhouse. Run back to 13980 ft and POOH with better wraps. Cut 655 ft of coil. The cut sections were full of unbroken gel with carbolite. Mar 8, 1996 Rig up coil tubing unit for post frac clean out. Tagged dry at 14905 ft, which is where we reversed to last attempt. Started reversing from here. Bottoms up was partly broken gel with carbolite. We continued to recover carbolite even though slurry should have been displaced to 15400 ft and top of sand at 15620 ft. Reversed down to 15990 ft. Losses were difficult to quantify as the densiometer was not reading correctly, but we only took significant losses of 1-1.2 bpm when the perfs were uncovered. Well Name: M PF-22 Rig Name: N-4ES AFE: 330205 Accept Date: 0 3/2 6/9 6 Spud Date: Release Date: 0 3/31/9 6 Mar 27, 1996 Move in and rig up, raise derrick and level, berm and safe out. Check well for pressure and rig lines. Test RBP to 500 psi. Nipple down tree and nipple up BOP's. Test BOP's to 250 Iow and 5000 high. Rig floor and install wear rings. Set tiger tank. Make up RBP retrieve tool and RIH to 600 ft, circulate out MECH. Continue RIH with tool, picking up pipe from shed. Mar 28, 1996 Reverse circulate 7.9 ppg fluid out of drill pipe. Continue to RIH to 15450 ft. Displace well with 9.8 ppg vis. system and liquid casing. RIH and engage RBP at 15542 ft. Pull and release plug, and RIH to 30 ft below setting point. Reverse circulate bottoms up, through choke. Page 4 Operations Summary for: Mar 29, 1996 Continue to circulate and balance mud. Well making a little gas and oil. POOH and lay down Baker Retrieval Tool and RBP. Make up BHA and RIH with same to 15845 ft, tag fill. Wash frac sand out of 7" casing from 15845 ft to 15910 ft. Hard spot at 15910 ft. Pick up kelly and wash through. Mar 30, 1996 Wash and ream through perfs at 15901 ft to 15961 ft. Reverse circulate sand and circulate bottoms up. Spot liquid casing pill. Circulate and perform casing wash. Monitor returns flowing slightly, stabilize well. POOH and lay down drill pipe. Mar 31, 1996 Pull wear ring and set test plug, change rams and test. Make up ESP assembly, RIH. Apr 1, 1996 Continue RIH with ESP completion, land tubing. Nipple down BOP and nipple up tree and test. Freeze protect tubing and annulus. Set BPV and secure well. Page 5 BP EXPLORATION MPF-22/MILNE PT 500292263200 NORTH SLOPE BOROUGH COMPUTATION DATE: SPER~._-SUN DRILLING SERVICES ANCHORAGE ALASKA RECEIVED SEP 0 1996 PAGE DATE OF SURVEY: 010996 MWD SURVEY JOB NUMBER: AK-MM-951268 KELLY BUSHING ELEV. = 45.85 FT. 2 / 1~(~,3~a 0tl & (~s Oo,~. Gommissio, OPERATOR: BP EXPLORATION Anchorage TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -45.85 0 0 110.00 110.00 64.15 0 7 210.00 210.00 164.15 0 8 310.00 310.00 264.15 0 12 410.00 409.98 364.13 1 21 N .00 E .00 .00N .00E N 52.75 E .12 .08N .10E N 53.37 E .00 .22N .29E N 23.78 E .10 .45N .46E N 16.29 W 1.20 1.74N .20E .00 .04 .11 .28 1.58 510.00 509.93 464.08 2 24 610.00 609.81 563.96 3 0 710.00 709.56 663.71 4 53 810.00 809.12 763.27 5 50 910.00 908.36 862.51 8 6 N 14.99 W 1.05 4.89N .68W N 17.28 W .61 9.41N 1.99W N 26.01 W 1.98 15.74N 4.64W N 23.74 W .97 24.23N 8.56W N 23.74 W 2.27 35.35N 13.45W 4.85 9.56 16.40 25.70 37.79 1010.00 1110.00 1210.00 1310.00 1410.00 1007.07 961.22 10 13 1105.16 1059.31 12 8 1202.45 1156.60 14 30 1298.67 1252.82 17 0 1393.83 1347.98 18 45 N 23.79 W 2.11 49.92N 19.86W N 22.54 W 1.94 67.75N 27.47W N 21.79 W 2.38 89.09N 36.15W N 21.46 W 2.49 114.33N 46.15W N 23.94 W 1.91 142.63N 58.02W 53.66 72.99 95.99 123.10 153.71 1510.00 1560.00 1610.00 1660.00 1710.00 1488.18 1442.33 19 55 1535.00 1489.15 21 1581.47 1535.62 22 1627.40 1581.55 24 23 1672.62 1626.77 26 5 N 21.12 W 1.50 173.21N 70.68W N 21.16 W 2.54 189.58N 77.01W N 21.80 W 1.88 206.74N 83.77W N 23.13 W 4.72 224.97N 91.32W N 22.90 W 3.39 244.59N 99.65W 186.74 204.28 222.70 242.39 263.66 1760.00 1810.00 1860.00 1910.00 1960.00 1717.45 1671.60 26 28 1762.07 1716.22 27 8 1806.64 1760.79 26 46 1851.38 1805.53 26 14 1896.17 1850.32 26 34 N 22.89 W .78 264.99N 108.27W N 22.15 W 1.48 285.82N 116.90W N 23.21 W 1.20 306.74N 125.64W N 26.16 W 2.85 327.01N 134.96W N 24.42 W 1.68 347.12N 144.45W 285.74 308.25 330.86 353.05 375.14 2010.00 2060.00 2110.00 2160.00 2210.00 1940.68 1894.83 27 36 1984.69 1938.84 29 2 2028.30 1982.45 29 31 2071.56 2025.71 30 40 2114.34 2068.49 31 38 N 25.19 W 2.20 367.78N 154.01W N 25.24 W 2.86 389.24N 164.11W N 25.94 W 1.18 411.30N 174.68W N 26.07 W 2.32 433.83N 185.67W N 24.53 W 2.51 457.22N 196.72W 397.79 421.36 445.64 470.52 496.22 2260.00 2310.00 2360.00 2410.~0 2460.00 2156.64 2110.79 32 46 2197.95 2152.10 35 46 2238.08 2192.23 37 27 2277.11 2231.26 39 54 2315.15 2269.30 41 0 N 23.32 W 2.58 481.59N 207.52W N 22.12 W 6.17 507.56N 218.39W N 21.26 W 3.49 535.27N 229.40W N 21.34 W 4.92 564.37N 240.75W N 21.09 W 2.20 594.62N 252.49W 522.76 550.85 580.63 611.84 644.25 SPERk~-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MPF-22/MILNE PT 500292263200 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 1/96 DATE OF SURVEY: 010996 MWD SURVEY JOB NUMBER: AK-MM-951268 KELLY BUSHING ELEV. = 45.85 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 2510.00 2352.56 2306.71 2560.00 2389.21 2343.36 2610.00 2425.01 2379.16 2660.00 2459.97 2414.12 2710.00 2494.34 2448.49 42 7 43 35 44 55 46 20 46 48 N 20.67 W 2.33 625.61N 264.31W N 19.60 W 3.26 657.54N 276.02W N 20.13 W 2.78 690.36N 287.87W N 19.92 W 2.86 723.94N 300.11W N 19.38 W 1.21 758.14N 312.32W 677.40 711.40 746.29 782.03 818.34 2960.00 2528.14 2482.29 2810.00 2561.28 2515.43 2860.00 2593.90 2548.05 2910.00 2625.79 2579.94 2960.00 2657.25 2611.40 48 5 48 52 49 40 51 3 50 55 N 19.75 W 2.64 792.85N 324.66W N 19.72 W 1.56 828.09N 337.30W N 20.03 W 1.67 863.73N 350.19W N 20.99 W 3.13 899.79N 363.68W N 20.67 W .56 936.11N 377.50W 855.17 892.60 930.49 968.98 1007.81 3010.00 2688.74 2642.89 3060.00 2720.13 2674.28 3110.00 2751.32 2705.47 3160.00 2781.56 2735.71 3210.00 2810.52 2764.67 51 0 51 13 51 34 53 58 55 13 N 20.47 W .35 972.47N 391.14W N 19.69 W 1.29 1009.03N 404.51W N 20.03 W .86 1045.78N 417.78W N 19.41 W 4.92 1083.25N 431.21W N 19.87 W 2.59 1121.63N 444.91W 1046.63 1085.54 1124.61 1164.41 1205.16 3260.00 2838.33 2792.48 3310.00 2865.07 2819.22 3360.00 2890.85 2845.00 3410.00 2915.22 2869.37 3460.00 2938.15 2892.30 57 11 58 8 59 46 61 52 63 30 N 20.59 W 4.12 1160.61N 459.28W N 20.96 W 2.00 1200.11N 474.26W N 21.60 W 3.46 1240.02N 489.81W N 22.11 W 4.29 1280.54N 506.06W N 22.62 W 3.38 1321.62N 522.97W 1246.69 1288.91 1331.71 1375.29 1419.63 3510.00 2959.63 2913.78 3560.00 2979.76 2933.91 3610.00 2998.71 2952.86 3710.00 3033.08 2987.23 3810.00 3064.79 3018.94 65 35 66 55 68 31 71 15 71 45 N 22.47 W 4.17 1363.31N 540.27W N 22.94 W 2.81 1405.53N 557.94W N 22.81 W 3.21 1448.16N 575.92W N 23.34 W 2.77 1534.54N 612.73W N 23.47 W .52 1621.57N 650.40W 1464.68 1510.33 1556.48 1650.12 1744.65 3910.00 3094.49 3048.64 73 40 4010.00 3122.12 3076.27 74 15 4110.00 3150.06 3104.21 73 18 4210.00 3179.33 3133.48 72 39 4310.00 3208.27 3162.42 73 41 N 23.72 W 1.93 1709.06N 688.62W N 23.45 W .63 1797.14N 727.07W N 25.00 W 1.77 1884.70N 766.46W N 23.31 W 1.74 1971.93N 805.59W N 23.17 W 1.04 2059.88N 843.35W 1839.78 1935.56 2031.13 2126.32 2221.75 4410.00 3236.65 3190.80 4510.00 3265.13 3219.28 4610.00 3292.04 3246.19 4710.00 3317.57 3271.72 4810.00 3343.64 3297.79 73 20 73 33 75 13 75 11 74 35 N 22.63 W .62 2148.21N 880.67W N 22.49 W .26 2236.73N 917.44W N 22.81 W 1.69 2325.61N 954.53W N 22.79 W .03 2414.74N 992.00W N 23.14 W .69 2503.63N 1029.66W 2317.39 2413.04 2509.12 2605.57 2701.85 SPERm,s-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 BP EXPLORATION MPF-22/MILNE PT 500292263200 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 1/96 DATE OF SURVEY: 010996 MWD SURVEY JOB NUMBER: AK-MM-951268 KELLY BUSHING ELEV. = 45.85 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 4910.00 3370.10 3324.25 74 43 N 22.21 W .91 2592.60N 1066.84W 2798.06 5010.00 3396.76 3350.91 74 21 N 20.62 W 1.57 2682.32N 1102.03W 2894.33 5110.00 3423.44 3377.59 74 41 N 19.86 W .80 2772.74N 1135.37W 2990.67 5210.00 3450.02 3404.17 74 28 N 19.52 W .39 2863.51N 1167.85W 3087.06 5310.00 3477.11 3431.26 74 5 N 19.14 W .53 2954.34N 1199.71W 3183.32 5~10.00 3504.02 3458.17 74 40 N 17.74 W 1.47 3045.70N 1230.17W 3279.62 5510.00 3530.84 3484.99 74 12 N 20.50 W 2.70 3136.71N 1261.72W 3375.94 5610.00 3558.09 3512.24 74 10 N 20.54 W .06 3226.83N 1295.45W 3472.12 5710.00 3586.02 3540.17 73 23 N 20.99 W .89 3316.61N 1329.49W 3568.08 5810.00 3615.02 3569.17 72 54 N 20.74 W .55 3406.03N 1363.57W 3663.72 5910.00 3643.82 3597.97 73 37 N 21.10 W .80 3495.48N 1397.77W 3759.41 6010.00 3671.48 3625.63 74 15 N 21.40 W .70 3585.04N 1432.59W 3855.42 6110.00 3699.55 3653.70 73 8 N 21.10 W 1.16 3674.49N 1467.38W 3951.30 6210.00 3728.53 3682.68 73 10 N 21.65 W .53 3763.62N 1502.26W 4046.92 6310.00 3758.47 3712.62 71 58 N 21.67 W 1.19 3852.28N 1537.48W 4142.20 6410.00 3789.48 3743.63 71 53 N 21.37 W .30 3940.73N 1572.35W 4237.16 6510.00 3821.23 3775.38 71 4 N 19.63 W 1.84 4029.53N 1605.56W 4331.93 6610.00 3852.62 3806.77 72 19 N 18.80 W 1.48 4119.18N 1636.80W 4426.87 6710.00 3883.36 3837.51 71 52 N 20.12 W 1.34 4208.90N 1668.50W 4522.01 6810.00 3914.44 3868.59 71 54 N 18.24 W 1.79 4298.66N 1699.72W 4617.04 6910.00 3944.85 3899.00 72 41 N 18.25 W .78 4389.13N 1729.55W 4712.30 7010.00 3974.15 3928.30 73 13 N 18.35 W .55 4479.91N 1759.57W 4807.91 7110.00 4002.94 3957.09 73 18 N 19.20 W .82 4570.57N 1790.39W 4903.67 7210.00 4032.00 3986.15 72 54 N 19.31 W .42 4660.91N 1821.94W 4999.35 7310.00 4062.12 4016.27 72 2 N 19.37 W .86 4750.88N 1853.52W 5094.70 7410.00 4093.09 4047.24 71 52 N 19.39 W .16 4840.57N 1885.07W 5189.78 7510.00 4123.51 4077.66 72 41 N 19.97 W .98 4930.26N 1917.15W 5285.02 7610.00 4153.72 4107.87 72 8 N 20.00 W .55 5019.85N 1949.73W 5380.33 7710.00 4183.50 4137.65 73 12 N 20.37 W 1.13 5109.45N 1982.67W 5475.76 7810.00 4212.07 4166.22 73 35 N 20.08 W .47 5199.37N 2015.80W 5571.56 7910.00 4241.17 4195.32 72 34 N 20.69 W 1.17 5289.05N 2049.12W 5667.19 8010.00 4269.92 4224.07 74 0 N 20.33 W 1.46 5378.75N 2082.68W 5762.92 8110.00 4297.75 4251.90 73 40 N 20.56 W .39 5468.74N 2116.23W 5858.93 8210.00 4326.15 4280.30 73 19 N 20.66 W .37 5558.49N 2149.98W 5954.76 8310.00 4355.55 4309.70 72 28 N 20.66 W .84 5647.92N 2183.70W 6050.29 SPER~f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MPF-22/MILNE PT 500292263200 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 1/96 DATE OF SURVEY: 010996 MWD SURVEY JOB NUMBER: AK-MM-951268 KELLY BUSHING ELEV. = 45.85 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANG~ COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8410.00 4385.86 4340.01 8510.00 4415.76 4369.91 8610.00 4445.03 4399.18 8710.00 4474.54 4428.69 8810.00 4503.54 4457.69 72 14 72 57 73 0 72 40 73 36 N 20.22 W .48 5737.22N 2216.98W N 20.85 W .94 5826.57N 2250.45W N 21.27 W .40 5915.80N 2284.81W N 20.61 W .71 6005.04N 2318.96W N 20.97 W 1.00 6094.50N 2352.93W 6145.54 6240.92 6336.46 6431.94 6527.58 ~910.00 4531.59 4485.74 73 48 9010.00 4560.00 4514.15 73 10 9110.00 4589.38 4543.53 72 39 9210.00 4619.22 4573.37 72 37 9310.00 4647.78 4601.93 74 10 N 21.60 W .64 6183.94N 2387.77W N 22.13 W .81 6272.92N 2423.48W N 21.44 W .85 6361.68N 2458.95W N 21.47 W .03 6450.51N 2493.86W N 20.59 W 1.76 6539.95N 2528.25W 6623.47 6719.21 6814.67 6910.01 7005.76 9410.00 4675.22 4629.37 9460.00 4689.18 4643.33 9490.00 4697.70 4651.85 9520.00 4706.25 4660.40 9550.00 4714.64 4668.79 73 58 73 35 73 22 73 31 73 58 N 20.81 W .30 6629.91N 2562.24W N 20.64 W .81 6674.81N 2579.23W N 20.74 W .80 6701.72N 2589.39W N 20.36 W 1.31 6728.65N 2599.49W N 20.10 W 1.72 6755.67N 2609.45W 7101.87 7149.85 7178.60 7207.34 7236.14 9580'.00 4722.92 4677.07 9610.00 4731.34 4685.49 9640.00 4739.85 4694.00 9670.00 4748.38 4702.53 9700.00 4756.98 4711.13 73 57 73 26 73 35 73 20 73 20 N 20.30 W .64 6782.73N 2619.40W N 19.86 W 2.21 6809.78N 2629.29W N 20.08 W .86 6836.81N 2639.11W N 19.48 W 2.09 6863.88N 2648.85W N 19.29 W .61 6890.99N 2658.39W 7264.96 7293.75 7322.51 7351.27 7380.00 9730.00 4765.65 4719.80 9760.00 4774.36 4728.51 9790.00 4783.05 4737.20 9820.00 4791.80 4745.95 9850.00 4800.58 4754.73 73 4 73 9 73 9 72 57 72 59 N 19.26 W .90 6918.10N 2667.87W N 19.89 W 2.03 6945.15N 2677.48W N 19.83 W .20 6972.15N 2687.24W N 19.61 W .95 6999.17N 2696.92W N 19.93 W 1.02 7026.16N 2706.62W 7408.72 7437.43 7466.14 7494.83 7523.51 9880.00 4809.38 4763.52 9963.93 4833.95 4788.10 10058.29 4861.14 4815.29 10153.07 4888.25 4842.40 10247.11 4914.42 4868.57 72 55 73 73 28 73 17 74 23 N 19.74 W .65 7053.14N 2716.36W N 19.94 W .26 7128.63N 2743.59W N 19.46 W .67 7213.70N 2774.05W N 20.75 W 1.32 7298.98N 2805.27W N 20.08 W 1.36 7383.62N 2836.77W 7552.19 7632.43 7722.77 7813.56 7903.84 10343.17 4940.40 4894.55 10436.75 4965.89 4920.04 10531.37 4991.75 4945.90 10626.23 5017.87 4972.02 10720.97 5044.30 4998.45 74 13 74 9 74 7 73 54 73 41 N 21.45 W 1.38 7470.09N 2869.56W N 21.76 W .33 7553.81N 2902.71W N 19.35 W 2.45 7639.01N 2934.66W N 18.06 W 1.33 7725.38N 2963.90W N 18.36 W .38 7811.80N 2992.33W 7996.26 8086.19 8177.15 8268.34 8359.31 SPEk~f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MPF-22/MILNE PT 500292263200 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 1/96 DATE OF SURVEY: 010996 MWD SURVEY JOB NUMBER: AK-MM-951268 KELLY BUSHING ELEV. = 45.85 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10815.35 5070.67 5024.82 73 51 10909.52 5097.59 5051.74 72 55 11003.85 5125.43 5079.58 72 45 11098.52 5153.83 5107.98 72 20 11193.01 5182.50 5136.65 72 19 N 17.09 W 1.30 7898.12N 3019.92W N 14.82 W 2.52 7984.86N 3044.73W N 16.56 W 1.77 8071.62N 3069.10W N 17.10 W .70 8158.06N 3095.24W N 14.84 W 2.28 8244.60N 3120.01W 8449.91 8540.02 8630.00 8720.26 8810.17 11~87.71 5211.32 5165.47 72 13 11380.83 5240.04 5194.19 71 50 11476.01 5269.29 5223.44 72 22 11569.81 5297.36 5251.51 72 48 11662.75 5325.15 5279.30 72 24 N 13.06 W 1.79 8332.14N 3141.75W N 13.69 W .77 8418.32N 3162.24W N 13.50 W .59 8506.35N 3183.53W N 13.72 W .51 8593.34N 3204.59W N 13.58 W .44 8679.52N 3225.52W 8900.04 8988.23 9078.43 9167.56 9255.89 11757.17 5352.67 5306.82 11851.83 5379.66 5333.81 11946.44 5407.51 5361.66 12040.72 5436.22 5390.37 12133.34 5464.00 5418.15 73 41 73 10 72 34 71 57 73 8 N 14.00 W 1.42 8767.23N 3247.05W N 14.09 W .55 8855.25N 3269.07W N 13.55 W .84 8943.05N 3290.67W N 13.57 W .66 9030.34N 3311.73W N 14.75 W 1.76 9116.01N 3333.34W 9345.86 9436.28 9526.36 9615.79 9703.84 12226.45 5491.55 5445.70 12320.00 5519.57 5473.72 12414.88 5546.94 5501.09 12507.79 5574.29 5528.44 12600.79 5603.36 5557.51 72 25 72 42 73 45 72 0 71 34 N 14.65 W .77 9202.03N N 14.37 W .41 9288.44N N 14.30 W 1.11 9376.46N N 15.49 W 2.26 9462.25N N 15.49 W .46 9547.38N 3355.91W 9792.56 3378.27W 9881.56 3400.76W 9972.13 3423.58W 10060.70 3447.17W 10148.90 12693.87 5632.08 5586.23 72 28 12786.56 5660.22 5614.37 72 10 12880.25 5688.40 5642.55 72 48 12976.13 5715.88 5670.02 73 54 13067.91 5741.73 5695.88 73 22 N 14.65 W 1.30 9632.87N N 15.36 W .80 9718.17N N 15.29 W .67 9804.34N N 15.64 W 1.20 9892.87N N 16.17 W .80 9977.56N 3470.19W 10237.24 3493.05W 10325.36 3516.67W 10414.55 3541.16W 10506.25 3565.29W 10594.20 13162.20 5769.21 5723.36 13255.44 5795187 5750.02 13345.91 5821.05 5775.20 13441.12 5848.01 5802.16 13534.81 5875.16 5829.31 72 45 74 1 73 39 73 26 72 51 N 16.34 W .68 10064.16N N 15.33 W 1.71 10150.10N N 15.74 W .60 10233.82N N 16.64 W .93 10321.51N N 17.36 W .97 10407.26N 3590.54W 10684.31 3614.92W 10773.53 3638.19W 10860.28 3663.65W 10951.49 3689.86W 11041.12 13627.32 5902.58 5856.73 13720.58 5930.61 5884.76 13810.59 5958.14 5912.29 13900.46 5986.05 5940.20 13995.64 6015.79 5969.94 72 39 72 21 72 71 48 71 47 N 18.29 W .98 10491.37N N 17.60 W .78 10575.99N N 16.48 W 1.24 10657.92N N 16.25 W .35 10739.89N N 12.79 W 3.45 10827.40N 3716.91W 11129.46 3744.31W 11218.39 3769.42W 11304.04 3793.49W 11389.40 3816.16W 11479.54 SPER~x'-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 BP EXPLORATION MPF-22/MILNE PT 500292263200 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 1/96 DATE OF SURVEY: 010996 MWD SURVEY JOB NUMBER: AK-MM-951268 KELLY BUSHING ELEV. = 45.85 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 14091.15 6046.08 6000.23 71 13 N 14.32 W 1.63 10915.45N 3837.38W 11569.74 14185.49 6078.60 6032.75 68 26 N 14.22 W 2.96 11001.26N 3859.21W 11658.01 14279.22 6114.72 6068.87 66 13 N 13.90 W 2.39 11085.14N 3880.22W 11744.19 14372.93 6153.98 6108.13 64 13 N 13.89 W 2.12 11167.73N 3900.65W 11828.95 14467.63 6196.34 6150.49 62 37 N 14.28 W 1.73 11249.87N 3921.26W 11913.35 14560.47 6240.17 6194.32 61 1 N 14.06 W 1.75 11329.21N 3941.29W 11994.92 14654.02 6286.77 6240.92 59 13 N 15.19 W 2.19 11407.69N 3961.76W 12075.81 14747.11 6335.70 6289.85 57 20 N 15.43 W 2.03 11484.05N 3982.67W 12154.83 14842.01 6387.70 6341.85 56 12 N 17.18 W 1.95 11560.23N 4004.94W 12234.13 14933.06 6439.36 6393.51 54 38 N 16.52 W 1.82 11631.98N 4026.68W 12309.05 15027.76 6495.41 6449.56 52 46 N 15.32 W 2.22 11705.36N 4047.62W 12385.27 15122.77 6554.13 6508.28 50 52 N 15.92 W 2.05 11777.28N 4067.72W 12459.83 15216.20 6614.10 6568.25 49 15 N 16.53 W 1.82 11846.06N 4087.73W 12531.39 15310.09 6676.42 6630.57 47 33 N 17.23 W 1.88 11913.24N 4108.11W 12601.56 15404.08 6740.72 6694.87 46 5 N 17.26 W 1.55 11978.71N 4128.43W 12670.08 15498.29 6807.59 6761.74 43 28 N 14.60 W 3.43 12042.50N 4146.67W 12736.34 15589.84 6877.19 6831.34 37 31 N 9.65 W 7.37 12100.53N 4159.30W 12795.35 15681.37 6952.55 6906.70 31 35 N 4.18 W 7.32 12151.98N 4165.73W 12846.13 15716.22 6982.40 6936.55 30 33 N 2.48 W 3.88 12169.94N 4166.78W 12863.47 15747.11 7008.94 6963.09 30 59 N .83 W 3.07 12185.74N 4167.23W 12878.57 15777.01 7034.48 6988.63 31 41 N .21 E 2.96 12201.29N 4167.32W 12893.32 15810.91 7063.14 7017.29 32 48 N 1.01 E 3.54 12219.37N 4167.12W 12910.38 15871.93 7114.16 7068.31 33 43 N .09 E 1.71 12252.84N 4166.80W 12941.96 15910.53 7146.26 7100.41 33 46 N .91 W 1.45 12274.28N 4166.96W 12962.31 15965.22 7191.83 7145.98 33 22 N 2.06 W 1.36 12304.51N 4167.74W 12991.18 16070.00 7279.32 7233.47 33 22 N 2.06 W .00 12362.13N 4169.81W 13046.39 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 13046.44 FEET AT NORTH 18 DEG. 38 MIN. WEST AT MD = 16070 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 341.21 DEG. SPEk..~-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MPF-22/MILNE PT 500292263200 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 1/96 DATE OF SURVEY: 010996 JOB NUMBER: AK-MM-951268 KELLY BUSHING ELEV. = 45.85 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -45.85 .00 N .00 E .00 1000.00 997.23 951.38 48.30 N 19.15 W 2.77 2.77 2000.00 1931.82 1885.97 363.59 N 152.03 W 68.18 65.41 3000.00 2682.45 2636.60 965.19 N 388.43 W 317.55 249.37 4~00.00 3119.40 3073.55 1788.31 N 723.24 W 880.60 563.05 5000.00 3394.06 3348.21 2673.31 N 1098.63 W 1605.94 725.34 6000.00 3668.77 3622.92 3576.08 N 1429.08 W 2331.23 725.29 7000.00 3971.26 3925.41 4470.82 N 1756.55 W 3028.74 697.51 8000.00 4267.16 4221.31 5369.73 N 2079.34 W 3732.84 704.10 9000.00 4557.11 4511.26 6264.05 N 2419.87 W 4442.89 710.05 10000.00 4844.48 4798.63 7161.06 N 2755.36 W 5155.52 712.63 11000.00 5124.29 5078.44 8068.10 N 3068.05 W 5875.71 720.19 12000.00 5423.61 5377.76 8992.71 N 3302.64 W 6576.39 700.68 13000.00 5722.49 5676.64 9914.96 N 3547.34 W 7277.51 701.12 14000.00 6017.15 5971.30 10831.44 N 3817.08 W 7982.85 705.34 15000.00 6478.62 6432.77 11684.04 N 4041.78 W 8521.38 538.53 16000.00 7220.87 7175.02 12323.64 N 4168.43 W 8779.13 257.75 16070.00 7279.32 7233.47 12362.13 N 4169.81 W 8790.68 11.55 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPER~__-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MPF-22/MILNE PT 500292263200 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 1/96 DATE OF SURVEY: 010996 JOB NUMBER: AK-MM-951268 KELLY BUSHING ELEV. = 45.85 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -45.85 45.85 45.85 .00 145.85 145.85 100.00 245.85 245.85 200.00 345.85 345.85 300.00 .00 N .00 E .00 N .00 E .12 N .16 E .27 N .36 E .56 N .51 E .00 .00 .00 .00 .00 .00 .00 .00 .00 445.87 445.85 400.00 545.95 545.85 500.00 646.08 645.85 600.00 746.42 745.85 700.00 846.92 845.85 800.00 2.55 N .04 W 6.35 N 1.07 W 11.22 N 2.56 W 18.53 N 6.00 W 27.67 N 10.07 W .02 .02 .10 . O8 .23 .13 .57 .33 1.07 .50 947.87 945.85 900.00 1049.41 1045.85 1000.00 1151.62 1145.85 1100.00 1254.83 1245.85 1200.00 1359.34 1345.85 1300.00 40.23 N 15.60 W 56.32 N 22.68 W 75.83 N 30.83 W 99.52 N 40.32 W 127.76 N 51.43 W 2.02 .95 3.56 1.54 5.77 2.22 8.98 3.21 13.49 4.51 1464.97 1445.85 1400.00 1571.64 1545.85 1500.00 1680.26 1645.85 1600.00 1791.78 1745.85 1700.00 1903.83 1845.85 1800.00 158.89 N 65.16 W 193.50 N 78.53 W 232.67 N 94.61 W 278.15 N 113.77 W 324.56 N 133.75 W 19.12 5.63 25.79 6.67 34.41 8.62 45.93 11.52 57.98 12.05 2015.84 1945.85 1900.00 2130.20 2045.85 2000.00 2247.17 2145.85 2100.00 2369.78 2245.85 2200.00 2500.95 2345.85 2300.00 370.23 N 155.16 W 420.29 N 179.05 W 475.21 N 204.77 W 540.81 N 231.56 W 619.93 N 262.17 W 69.99 12.00 84.35 14.36 101.32 16.97 123.93 22.62 155.10 31.17 2639.55 2445.85 2400.00 2786.59 2545.85 2500.00 2941.91 2645.85 2600.00 3101.20 2745.85 2700.00 3273.88 2845.85 2800.00 710.04 N 295.07 W 193.70 38.60 811.52 N 331.36 W 240.74 47.04 922.96 N 372.54 W 296.06 55.31 1039.30 N 415.42 W 355.35 59.29 1171.53 N 463.38 W 428.03 72.68 3477.26 2945.85 2900.00 3749.75 3045.85 3000.00 4095.36 3145.85 3100.00 4442.10 3245.85 3200.00 4818.32 3345.85 3300.00 1335.88 N 528.91 W 531.41 103.38 1569.10 N 627.64 W 703.90 172.49 1871.99 N 760.54 W 949.51 245.62 2176.60 N 892.50 W 1196.25 246.74 2511.00 N 1032.81 W 1472.47 276.21 SPER~-SUN DRILLING SERVICES ANCI~ORAGE ALASKA PAGE BP EXPLORATION MPF-22/MILNE PT 500292263200 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 1/96 DATE OF SURVEY: 010996 JOB NUMBER: AK-MM-951268 KELLY BUSHING ELEV. = 45.85 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANG~ COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5194.41 3445.85 3400.00 5565.13 3545.85 3500.00 5917.20 3645.85 3600.00 6269.20 3745.85 3700.00 6~87.68 3845.85 3800.00 2849.35 N 3186.40 N 3501.93 N 3816.23 N 4099.05 N 1162.83 W 1748.56 276.09 1280.30 W 2019.28 270.72 1400.25 W 2271.35 252.07 1523.15 W 2523.35 252.00 1629.95 W 2741.83 218.48 6913.38 3945.85 3900.00 7257.11 4045.85 4000.00 7584.33 4145.85 4100.00 7925.65 4245.85 4200.00 8277.77 4345.85 4300.00 4392.19 N 4703.40 N 4996.89 N 5303.01 N 5619.16 N 1730.56 W 2967.52 225.69 1836.83 W 3211.26 243.73 1941.38 W 3438.48 227.22 2054.40 W 3679.80 241.32 2172.86 W 3931.92 252.12 8612.80 4445.85 4400.00 8961.08 4545.85 4500.00 9302.93 4645.85 4600.00 9661.17 4745.85 4700.00 10004.76 4845.85 4800.00 5918.30 N 6229.55 N 6533.58 N 6855.90 N 7165.35 N 2285.79 W 4166.95 235.03 2405.84 W 4415.23 248.28 2525.86 W 4657.08 241.84 2646.02 W 4915.32 258.24 2756.90 W 5158.91 243.59 10363.22 4945.85 4900.00 10726.48 5045.85 5000.00 11072.23 5145.85 5100.00 11399.46 5245.85 5200.00 11732.87 5345.85 5300.00 7488.05 N 7816.82 N 8134.11 N 8435.51 N 8744.60 N 2876.61 W 5417.37 258.46 2994.00 W 5680.63 263.27 3087.88 W 5926.38 245.74 3166.43 W 6153.61 227.23 3241.41 W 6387.02 233.41 12071.81 5445.85 5400.00 12410.98 5545.85 5500.00 12739.60 5645.85 5600.00 13082.29 5745.85 5700.00 13433.52 5845.85 5800.00 9059.08 N 9372.83 N 9675.06 N 9990.80 N 10314.53 N 3318.66 W 6625.96 238.94 3399.84 W 6865.13 239.17 3481.22 W 7093.76 228.62 3569.13 W 7336.44 242.69 3661.56 W 7587.67 251.23 13770.73 5945.85 5900.00 14090.40 6045.85 6000.00 14354.23 6145.85 6100.00 14572.20 6245.85 6200.00 14765.91 6345.85 6300.00 10621.57 N 10914.76 N 11151.37 N 11339.17 N 11499.31 N 3758.62 W 7824.88 237.21 3837.21 W 8044.55 219.68 3896.61 W 8208.38 163.82 3943.79 W 8326.35 117.97 3986.88 W 8420.06 93.71 14944.27 6445.85 6400.00 15109.65 6545.85 6500.00 15264.71 6645.85 6600.00 15411.44 6745.85 6700.00 15549.57 6845.85 6800.00 11640.74 N 11767.49 N 11881.21 N 11983.75 N 12075.71 N 4029.27 W 8498.42 78.36 4064.93 W 8563.80 65.38 4098.20 W 8618.86 55.06 4129.97 W 8665.59 46.73 4154.51 W 8703.72 38.13 SPEk..~-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 10 BP EXPLORATION MPF-22/MILNE PT 500292263200 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 1/96 DATE OF SURVEY: 010996 JOB NUMBER: AK-MM-951268 KELLY BUSHING ELEV. = 45.85 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 15673.45 6945.85 6900.00 15790.42 7045.85 7000.00 15910.04 7145.85 7100.00 16029.92 7245.85 7200.00 1~060.00 7270.97 7225.12 12147.78 N 4165.37 W 12208.38 N 4167.27 W 12274.00 N 4166.95 W 12340.08 N 4169.02 W 12356.63 N 4169.61 W 8727.60 23.88 8744.57 16.96 8764.19 19.62 8784.07 19.88 8789.03 4.96 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS WELL LOG TRANSMITTAL To: State of Alaska May 06, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Records Keeper 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MP F-22, AK-MM-951268 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2"x 5" MD Resistivity and Gamma Ray Logs: 2" x 5" TVD Resistivity and Gamma Ray Logs: 2" x 5" MD Neutron and Density Logs: 2"x 5" TVD Neutron and Density Logs: 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia I r_,L;ci V lO MAY'O 7 1~J96 Alaska 011 & Gas Cons. C0mmi~n Anchorage 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Ino. Company ri F! I I_1_1 I~ G S ES I~IL/I r' E S WELL LOG TRANSMITTAL To: State of Alaska April 23, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs~apes - MPF-22 AK-MM-950268 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPF-22: 1 LDWG formatted LIS tape with verification listing. APIg: 50-029-22632-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company Date__ Nt~L~E pO~t~T FtELD, ALASKA G~rO ~u~tishot su~eY Of Oritt p~pe su~e~ date' 02 3anua~, 1996 SR3't6.DOC OOQ'9~IS 'S'-IOOJ~ df] QEF>IDVd QNV SVqJ~¥ 0£ NtIflJ.,EPd 'AE[A~IflS SSEI;DO'~Id qOOJ, NA~OQ 7>IV7t~I~[ QNV NA~OQ AVq ,00~9 ,.LV 0L86 £V EI'IOH NI DNINND~I Died ~IO~t X~t QN¥£S "IOOJ, ciD_ ~ '£INf'l J~OdS NOI£¥DO'I £¥ Q~tA1X'dV NOI£VDO"I O& ~IAPdQ 0£:£Z 0£:~ 0g:lZ 0Z:0Z 0£:6I LZ:LI gg:9I 0Z:9I 0~:II 96/I0/I 91,~O~6gl,51V : ~I3~I~AN 8or .L~lOd:i~l "IVOIIDO'IONOblHO Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 January 12, 1996 B.P. Exploraton (Alaska) Inc. Petrotechnical Data Center, MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 Re: P2 PAD, WELL MPF-22, MILNE POINT FIELD, ALASKA Enclosed please fred one (1) original and six (6) copies and one (1) disk of the completed survey of Well #VOgLL MPF-22 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely Robert J. Shoup Operations Manager RS/fcc Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data CONTENTS JOB NUMBER :AK1295G316 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR316.DOC gyro/data -1. DISCUSSION, SURVEY CERTIFICATION SHEET SR316.DOC gyro/data DISCUSSION JOB NUMBER: AK1295G316 Tool 080 was run in F-36 on ATLAS 5116" Wireline inside drillpipe. The survey was run without problems. SR316.DOC gy /data SURVEY CERTIFICATION SHEET JOB NUMBER: AK1295G316 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report'represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER SR316.DOC 00Q'91,8~1S S-i1¥.1.~Ci A:I^aNS gyro/data SURVEY DETAILS JOB NUMBER' AK1295G316 CLIENT: B.P. EXPLORATION RIG: F-PAD LOCATION: MILNE POINT FIELD WELL: F-22 LATITUDE: 70.505000 N LONGITUDE: 149 W SURVEY DATE: 02 JANUARY, 1996 SURVEY TYPE : DEPTH REFERENCE: MAX. SURVEY DEPTH: MULTISHOT IN 5.5" Drillpipe ROTARY TABLE ELEVATION 45.85 9880 SURVEY TIED ONTO: NA SURVEY INTERVAL: 100' From 110 feet to 1510 feet, 50' From 1510 feet to 3610 feet, 100' From 3610 feet to 9410 feet, 50' From 9410 feet to 9460 feet. 30' From 9460 feet to 9880 feet. UTM CO-ORDINATES: TARGET DIRECTION: 341.210 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD SR316.DOC gyro/data 3. OUTRUN SURVEY LISTING SR316.DOC A G y r o d a t a D i r.e c t i o n a 1 S u r v e y for B.P. EXPLORATION WELL: NUMBER MPF-22, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK1295G316 Run Date: 2-Jan-96 5:27:44 Surveyor: T. STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 45.85 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 341.210 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gy r o d a t a B.P. EXPLORATION WELL: NUMBER MPF-22, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK1295G316 Direct ional Survey MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 0.0 0.00 0.00 0.0 0.0 -45.9 0.00 0.'0 0.0 0 - 9880 FEET, GYRO MULTISHOT SURVEY RUN INSIDE DRILL PIPE ALL DEPTH REFERENCED TO F-PAD R.K.B. OF 45.85 FEET Page 1 HORIZONTAL COORDINATES feet 0.00 N 0.00 E 110.0 .13 52.75 110.0 .0 64.1 .12 210.0 .14 53.37 210.0 .1 164.1 .01 310.0 .20 23.78 310.0 .3 264.1 .10 410.0 1.35 343.71 410.0 1.6 364.1 1.20 510.0 2.40 345.01 509.9 4.8 464.1 1.06 610.0 3.00 342.72 609.8 9.5 564.0 .60 710.0 4.89 333.99 709.6 16.4 663.7 1.98 810.0 5.84 336.26 809.1 25.7 763.3 .97 910.0 8.11 336.26 908.4 37.8 862.5 2.27 1010.0 10.22 336.21 1007.1 53.7 961.3 2.11 1110.0 12.14 337.46 1105.2 73.0 1059.4 1.94 1210.0 14.51 338.21 1202.5 96.0 1156.7 2.37 1310.0 17.00 338.54 1298.7 123.1 1252.9 2.49 1410.0 18.75 336.06 1393.9 153.7 1348.1 1.91 1510.0 19.92 338.88 1488.3 186.8 1442.4 1.50 1560.0 21.19 338.84 1535.1 204.3 1489.2 2.54 1610.0 22.10 338.20 1581.6 222.7 1535.7 1.87 1660.0 24.40 336.87 1627.5 242.4 1581.7 4.72 1710.0 26.09 337.10 1672.7 263.7 1626.9 3.40 1760.0 26.48 337.11 1717.6 285.8 1671.7 .77 .1 52.7 .07 N .10 E .4 53.0 .21 N .28 E .6 45.3 .44 N .45 E 1.7 ~6.3 1.73 N .19 E 4.9 352.1 4.89 N .68 W 9.6 348.0 9.41 N 2.00 W 16.4 343.5 15.73 N 4.65 W 25.7 340.5 24.22 N 8.56 W 37.8 339.2 35.34 N 13.45 W 53.7 338.3 49.92 N 19.87 W 73.1 337.9 67.75 N 27.48 ~ 96.2 337.9 89.10 N 36.17 W 123.3 338.0 114.34 N 46.16 W 154.0 337.9 142.63 N 58.03 W 187.1 337.8 173.22 N 70.70 W 204.6 223.1 242.8 264.1 286.3 337.9 189.60 N 77.03 W 337.9 206.76 N 83.78 W 337.9 224.99 N 91.33 W 337.8 244.62 N 99.67 W 337.8 265.01 N 108.28 W A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: NUMBER MPF-22, 5" DRILLPIPE Location:.F PAD, MILNE POINT FIELD, Job Number: AK1295G316 ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet 1810.0 27.14 337.85 1762.2 1860.0 26.78 336.79 1806.7 1910.0 26°24 333.84 1851.5 1960.0 26°57 335.58 1896.3 2010.0 27.61 334o81 1940.8 VERTICAL SECTION feet 308.3 330.9 353.1 375.2 397.8 SUBSEA DEPTH feet 1716.3 1760.9 1805.6 1850.4 1894.9 DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. 1.47 308.8 337.8 1.19 331.5 337.7 2.85 353.8 337.6 1.69 376.0 337.4 2.20 398.8 337.3 HORIZONTAL COORDINATES feet 28B.84 N 116.92 W 306.76 N 125.66 327o03 N 134.97 W 347.14 N 144.47 W 367.80 N 154.03 W 2060.0 29.04 334.76 1984.8 2110.0 29.52 334.06 2028.4 2160.0 30.68 333.93 2071.7 2210.0 31.65 335.47 2114.5 ~ 2260.0 32.77 336.68 2156.8 421.4 445.7 470.5 496.2 522.8 1939.0 1982.6 2025.8 2068.6 2110.9 2.85 422.5 337.1 1.19 446.9 337.0 2.32 471.9 336.8 2.52 497.8 336.7 2.58 524.4 336.7 389.26 N 164.13 W 411.32 N 174.70 W 433.85 N 185.69 W 457.24 N 196.74 W 481.61 N 207.54 W 2310.0 35.78 337.88 2198.1 2360.0 37.45 338.74 2238.2 2410.0 39.91 338.66 2277.2 2460.0 41.00 338.91 2315.3 2510.0 42.13 339.33 2352.7 2560.0 43.59 340.40 2389.3 2610.0 44.93 339.87 2425.2 2660.0 46.35 340.08 2460.1 2710.0 46.81 340.62 2494.5 2760.0 48.10 340.25 2528.3 550.9 580.7 611.9 644.3 677.4 711.4 746.3 782.1 818.4 855.2 2152.2 2192.4 2231.4 2269.4 2306.8 2343.5 2379.3 2414.3 2448.6 2482.4 6.18 552.6 336.7 3.49 582.4 336.8 4.92 613.6 336.9 2.20 646.0 337.0 2.33 679.2 337.1 3.27 713.2 337.2 2.77 748.0 337.4 2.87 783.7 337.5 1.21 820.0 337.6 2.64 856.8 337.7 507.58 N 218.41 W 535.29 N 229.42 W 564.40 N 240.78 W 594.65 N 252.52 W 625.64 N 264.34 W 657.57 N 276.04 %. 690.39 N 287.90 W 723.98 N 300.14 W 758.18 N 312.36 W 792.89 N 324.69 W 2810.0 48.88 340.28 2561.4 2860.0 49.68 339.97 2594.0 2910.0 51.06 339.01 2625.9 2960.0 50.93 339.33 2657.4 3010.0 51.01 339.53 2688.9 892.6 930.5 969.0 1007.9 1046.7 2515.6 2548.2 2580.1 2611.5 2643.0 .57 894.2 337.8 .66 932.1 337.9 .13 970.6 338.0 .56 1009.4 338.0 .33 1048.2 338.1 828.13 N 337.34 W 863.77 N 350.22 W 899.83 N 363.71 W 936.15 N 377.53 W 972.52 N 391.17 W A Gyrodat a Di re c t iona I Survey B.P. EXPLORATION WELL: NUMBER MPF-22, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, Job Number: AK1295G316 ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 3060.0 51.23 340.31 2720.3 3110.0 51.57 339.97 2751.5 3160.0 53.98 340.59 2781.7 3210.0 55.22 340o13 2810o7 3260.0 57.19 339.41 2838.5 3310.0 58.14 339.04 2865.2 3360.0 59.78 338.40 2891.0 3410.0 61.88 337.89 2915.4 3460.0 63.51 337.38 2938.3 3510.0 65.59 337.53 2959.8 1085.6 1124.7 1164.5 1205.2 1246.8 1289.0 1331.8 1375.4 1419.7 1464.8 2674.4 1.30 1087.1 338.2 2705.6 .86 1126.2 338.2 2735.9 4.91 1166.0 338.3 2764.8 2.59 1206.7 338.4 2792.6 4.12 1248.2 338.4 2819.4 2.00 1290.5 338.4 2845.2 3.46 1333.3 338.4 2869.5 4.29 1377.0 338.4 2892.5 3.38 1421.4 338.4 2914.0 4.17 1466.5 338.4 1009.07 N 1045.82 N 1083.30 N 1121.68 N 1160.67 N 1200.17 N 1240.09 N i280.60 N 1321.69 N 1363.38 N 404.52 W 417.81 431.24 W 444.94 W 459.30 W 474.29 W 489,84 W 506.09 W 523.00 W 540.30 W 3560.0 66.93 337.06 2979.9 3610.0 68.53 337.19 2998.9 3710.0 71.26 336.66 3033.3 3810.0 71.76 336.53 3065.0 3910.0 73.68 336.28 3094.7 4010.0 74.25 336.55 3122.3 4110.0 73.30 335.00 3150.2 4210.0 72.66 336.69 3179.5 4310.0 73.69 336.83 3208.5 4410.0 73.34 337.37 3236.8 1510.4 1556.6 1650.2 1744.7 1839.9 1935.6 2031.2 2126.4 2221.8 2317.5 2934.1 2.81 1512.3 338.3 2953.0 3.21 1558.6 338.3 2987.4 2.77 1652.4 338.2 3019.1 .51 1747.2 338.1 3048.8 1.94 1842.7 338.1 3076.5 .63 1938.7 338.0. 3104.4 1.76 2034.7 337.9 3133.7 1.74 2130.2 337.8 3162.6 1.04 2225.9 337.7 3191.0 .62 2321.8 337.7 1405.60 N 1448.23 N 1534.61'N 1621.64 N 1709.14 N 1797.22 N 1884.78 N 1972.02 N 2059.97 N 2148.30 N 557.97 W 575.96 W 612.77 W 650.44 W 688.66 W 727.12 · 766.51 W 805.64 W 843.41 W 880.73 W 4510.0 73.56 337.51 3265.3 4610.0 75.22 337.19 3292.2 4710.0 75.19 337.21 3317.8 4810.0 74.59 336.86 3343.8 4910.0 74.72 337.79 3370.3 2413.1 2509.2 2605.7 2702.0 2798.2 3219.5 .26 2417.7 337.7 3246.4 1.69 2514.0 337.7 3271.9 .03 2610.7 337.7 3298.0 .69 2707.2 337.6 3324.4 .91 2803.6 337.6 2236.82 N 2325.70 N 2414.83 N 2503.72 N 2592.70 N 917.51 W 954.60 W 992.07 W 1029.74 W 1066.92 W A Gyrodat a D i r e c t i ona i Survey B.P. EXPLORATION WELL: NUMBER MPF-22, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, Job Number: AK1295G316 ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. H O R I.Z O N T A L COORDINATES feet 5010o0 74.36 339.38 3396.9 5110.0 74.69 340.14 3423.6 5210.0 74.48 340.48 3450.2 5310.0 74.09 340.86 3477.3 5410.0 74.68 342.26 3504.2 2894.5 2990.8 3087.2 3183.4 3279.8 3351.1 3377.8 3404.4 3431.4 3458.4 1.5'8 2900.0 337.7 .80 2996.3 337.7 .40 3092.6 337.8 .53 3188.8 337.9 1.47 3284.9 338.0 2682.42 N 1102.11 W 2772.85 N 1135.45' 2863.62 N 1167.92 ~, 2954.45 N 1199.78 W 3045.81 N 1230.24 W 5510.0 74.21 339.50 3531.0 5610.0 74.17 339.46 3558.3 5710.0 73.39 339.01 3586.2 5810.0 72.90 339.26 3615.2 5910.0 73.62 338.90 3644.0 3376.1 3472.3 3568.2 3663.9 3759.5 3485.2 3512.4 3540.3 3569.3 3598.2 .69 3381.1 338.1 .06 3477.3 338.1 .90 3573.3 338.2 .55 .3669.0 338.2 .80 3764.7 338.2 3136.83 N 1261.79 W 3226.94 N 1295.52 W 3316.72 N 1329.56 W 3406.15 N 1363.65 W 3495.60 N 1397.83 W 6010.0 74.26 338.60 3671.7 6110.0 73.14 338.90 3699.7 6210.0 73.17 338.35 3728.7 6310.0 71.98 338.33 3758.7 6410.0 71.89 338.63 3789.7 6510.0 71.08 340.37 3821.4 6610.0 72.33 341.20 3852.8 6710.0 71.87 339.88 3883.6 6810.0 71.91 341.76 3914.7 6910.0 72.69. 341.75 3945.1 3855.6 3951.4 4047.1 4142.3 4237.3 4332.1 4427.0 4522.2 4617.2 4712.5 3625.8 3653.9 3682.9 3712.8 3743.8 3775.6 3807.0 3837.7 3868.8 3899.2 .70 3860.8 338.2 1.15 3956.8 338.2 .53 4052.5 338.2 1.20 4147.9 338.2 .30 4243.0 338.2 1.83 4337.8 338.3 1.48 4432.6 338.3 1.33 4527.7 338.4 1.79 4622.7 338.4 .78 4717.8 338.5 3585.16 N 1432.66 W 3674.61 N 1467.46 W 3763.74 N 1502.34 W 3852.41 N 1537.56 W 3940.85 N 1572.44 W 4029.66 N 1605.65 '~ 4119.31 N 1636.89 W 4209.03 N 1668.59 W 4298.80 N 1699.81 W 4389.27 N 1729.64 W 7010.0 73.23 341.65 3974.4 7110.0 73.31 340.80 4003.2 7210.0 72.90 340.69 4032.2 7310.0 72.04 340.63 4062.3 7410.0 71.88 340.61 4093.3 4808.1 4903.8 4999.5 5094.9 5190.0 3928.5 3957.3 3986.4 4016.5 4047.5 .55 4813.2 338.6 .82 4908.9 338.6 .42 5004.5 338.6 .86 5099.8 338.7 .17 5194.8 338.7 4480.05 N 1759.66 W 4570.72 N 1790.49 W 4661.05 N 1822.05 W 4751.02 N 1853.63 W 4840.72 N 1885.18 W A Gy r o d a t a B.P. EXPLORATION WELL: NUMBER MPF-22, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK1295G316 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 7510.0 72.69 340°03 4123.~7 7610.0 72.14 340.00 4153.9 7710.0 73.21 339.63 4183.7 7810.0 73.59 339.92 4212.3 7910.0 72.58 339.31 4241.4 8010.0 74.00 339.67 4270.1 8110.0 73.68 339.44 4298.0 8210.0 73.32 339.34 4326.4 8310.0 72.48 339.34 4355.8 8410.0 72.24 339.78 4386.1 8510.0 72.96 339.15 4416.0 8610.0 73.00 338.73 4445.3 8710.0 72.67 339.39 4474.8 8810.0 73.61 339.03 4503.8 8910.0 73.81 338.40 4531.8 9010.0 73.18 337.87 4560.2 9110.0 72.65 338.56 4589.6 9210.0 72.63 338.53 4619.4 9310.0 74.18 339.41 4648.0 9410.0 73.97 339.19 4675.4 9460.0 73.60 339.36 4689.4 9490.0 73.38 339.26 4697.9 9520.0 73.53 339.64 4706.5 9550.0 73.98 339.90 4714.9 9580.0 73.96 339.70 4723.1 5285.2 5380.5 5475.9 5571.7 5667.4 5763.1 5859.1 5954.9 .6050.5 6145.7 6241.1 6336.7 6432.1 6527.8 6623.7 6719.4 6814.9 6910.2 7006.0 7102.1 7150.1 7178.8 7207.5 7236.3 7265.2 D i re c t i ona 1 Survey SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 4077.9 .98 5290.1 338.8 4108.1 .55 5385.4 338.8 4137.9 1.13 5480.8 338.8 4166.4 .47 5576.6 338.8 4195.5 1.17 5672.3 338.8 4224.3 1.46 5768.1 338.8 4252.1 .39 5864.1 338.8 4280.5 .37 5960.0 338.9 4309.9 .84 6055.6 338.9 4340.2 .49 6150.9 338.9 4370.1 .94 6246.3 338.9 4399.4 .40 6341.9 338.9 4428.9 .71 6437.4 338.9 4457.9 .99 6533.1 338.9 4486.0 .64 6629.1 338.9 4514.4 .82 6725.0 338.9 4543.8 .84 6820.6 338.9 4573.6 .03 6916.0 338.9 4602.2 1.76 7011.8 338.9 4629.6 .30 7108.0 338.9 4643.6 .81 7156.0 338.9 4652.1 .82 7184.8 338.9 4660.6 1.33 7213.5 338.9 4669.0 1.70 7242.3 338.9 4677.3 .64 7271.2 338.9 Page 5 H O R I Z 0 N T A L COORDINATES feet 4930.41 N 1917.26 W 5019.99 N 1949.84 .~ 5109.59 N 1982.78 ~ 5199.51 N 2015o91 W 5289.20 N 2049.23 W 5378.90 N 5468.90 N 5558.64 N 5648.07 N 5737.37 N 5826.73 N 5915.97 N 6005.20 N 6094.67 N 6184.11 N 6273.09 N 6361.84 N 6450.68 N 6540.12 N 6630.08 N 6674.98 N 6701.89 N 6728.81 N 6755.84 N 6782.90 N 2082.79 W 2116.35 W 2150.10 W 2183.83 W 2217.10 W 2250.57 W 2284.93 W 2319.08 W 2353.05 W 2387.89 W 2423.60 , 2459.08 W 2493.99 W 2528.38 W 2562.38 W 2579.37 W 2589.53 W 2599.63 W 2609.59 W 2619.54 W A Gyroda t a Dir e c t iona i Survey B.P. EXPLORATION WELL: NUMBER MPF-22, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK1295G316 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 9610.0 73.45 340.14 4731.6 9640.0 73.60 339.92 4740.1 9670.0 73.35 340.52 4748.6 9700.0 73.34 340.71 4757.2 9730.0 73.07 340.74 4765.9 7294.0 4685.7 2.22 7299.9 338.9 7322.7 4694.2 .86 7328.7 338.9 7351.5 4702.8 2.08 7357.5 338.9 7380.2 4711.4 .62 7386.2 338.9 7408.9 4720.0 .90 7414.9 338.9 6809.95 N 2629.43 W 6836.98 N 2639.25 6864.05 N 2648.98 W 6891.16 N 2658.52 W 6918.27 N 2668.00 W 9760.0 73.16 340.11 4774.6 9790.0 73.15 340.17 4783.3 9820.0 72.96 340.39 4792.0 9850.0 72.99 340.07 4800.8 9880.0 72.92 340.26 4809.6 7437.6 4728.7 2.03 7443.6 338.9 7466.3 4737.4 .21 7472.3 338.9 7495.0 4746.2 .92 7501.0 338.9 7523.7 4755.0 1.03 7529.7 338.9 7552.4 4763.8 .65 7558.3 338.9 6945.32 N 6972.32 N 6999.34 N 7026.33 N 7053.31 N 2677.62 W 2687.38 W 2697.06 W 2706.76 W 2716.50 W Final Station Closure: Distance: 7558.34 ft Az: 338.94 deg. A Gyroda t a D i re c t i ona i Survey for B.P. EXPLORATION WELL: NUMBER MPF-22, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK1295G316SS Run Date: 2-Jan-96 5:27:44 Surveyor: T. STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 45.85 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 341.210 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyrodat a Dire c~t i ona 1 Survey B.P. EXPLORATION WELL: NUMBER MPF-22, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, Job Number: AK1295G316SS ALASKA SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. -45.9 0.00 0.00 0o0 0.0 0.00 0 - 9880 FEET, GYRO MULTISHOT SURVEY RUN INSIDE DRILL PIPE ALL DEPTH REFERENCED TO F-PAD R.KoBo OF 45.85 FEET CLOSURE DIST. AZIMUTH feet deg. 0.0 0.0 Page HORIZONTAL COORDINATES feet 0.00 N '0.00 E 100.0 .13 52.97 145.9 .1 .08 200.0 .16 42.76 245.9 .2 .04 300.0 .61 9.42 345.9 .7 .50 400.0 1.73 344.18 445.9 2.8 1.15 500.0 2.62 344.18 545.9 6.5 .89 600.0 3.68 339.56 645.9 12.0 1.10 700.0 5.24 334.82 745.9 19.8 1.61 800.0 6.68 336.26 845.9 30.2 1.45 900.0 8.91 336.24 945.9 43.8 2.21 1000.0 10.98 336.70 1045.9 61.3 2.04 1100.0 13.13 337.77 1145.9 82.6 2.12 1200.0 15.63 338.36 1245.9 108.2 2.43 1300.0 17.87 337.31 1345.9 138.3 2.20 1400.0 19.40 337.62 1445.9 171.9 1.68 1500.0 21.40 338.69 1545.9 208.6 2.39 1600.0 25.09 336.96 1645.9 251.0 4.18 1700.0 26.89 337.58 1745.9 300.0 1.22 1800.0 26.31 334.21 1845.9 350.3 2.64 1900.0 27.78 334.80 1945.9 400.5 2.27 2000.0 29.98 334.01 2045.9 455.7 1.64 .4 52.8 .6 50.2 1.7 31.3 4.9 1.2 9.6 350.6 16.4 346.4 25.7 342.4 37.8 340.0 53.7 338.8 73.1 338.1 96.2 337.9 123.3 338.0 154.0 337.9 187.1 337.8 223.1 337.9 264.1 337.9 308.8 337.8 353.8 337.6 422.5 337.3 471.9 336.9 .12 N .16 E .30 N .34 E .91 N .36 E 2.86 N .37 ~W 6.51 N 1.16 W 11.69 N 2.96 W 18.83 N 6.07 W 28.33 N 10.37 W 40.87 N 15.89 W 56.96 N 22.88 W 76.67 N 31.11 W 100.46 N 40.67 W 128.34 N 52.04 W 159.47 N .65.00 W 193.57 N 78.59 W 232.95 N 94.72 W 278.22 N 113.76 W 324.47 N 133.80 W 370.27 N 155.19 W 420.40 N 179.13 W A Gyroda t a Di re c t i onal Survey B.P. EXPLORATION WELL: NUMBER MPF-22, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, Job Number: AK1295G316SS ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG SEVERITY deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2100.0 32.48 336.37 2145.9 2200.0 37.93 338.72 2245.9 2300.0 41.92 339.25 2345.9 2400.0 45.77 339.99 2445.9 2500.0 48.51 340.27 2545.9 515.9 586.8 671.4 767.5 875.1 .56 .77 .30 .83 .07 524.4 336.7 613.6 336.8 679.2 337.1 783.7 337.4. 894.2 337.8 475.32 N 204.76 W 540.99 N 231.65 W 619.97 N 262.18 W 710.28 N 295.15 W 811.57 N 331.39 W 2600.0 50.98 339.22 2645.9 2700.0 51.51 340.04 ~2745.9 2800.0 57.45 339.31 2845.9 2900.0 64.24 337.43 2945.9 3000.0 71.45 336.61 3045.9 993.6 1117.6 1258.4 1435.5 1687.7 1.50 .94 3.54 3.66 1.88 1009.4 338.0 1126.2 338.2 1290.5 338.4 .1466.5 338.4 1747.2 338.2 922.83 N 1039.22 N 1171.55 N 1336.31 N 1569.14 N 372.46 W 415.42 W 463.43 W 529.07 W 627.71 W 3100.0 73.45 335.24 3145.9 3200.0 73.41 337.41 3245.9 3300.0 74.60 336.93 3345.9 3400.0 74.51 340.43 3445.9 3500.0 74.19 339.48 3545.9 2016.2 2347.7 2709.3 3071.4 3428.4 1.59 .51 .71 .46 1.26 2034.7 337.9 2417.7 337.7 2803.6 337.6 3092.6 337.8 3477.3 338.1 1871.01 N 2176.30 N 2510.54 N 2848.75 N 3185.86 N 760.32 W 892.36 W 1032.59 W 1162.61 W 1280.14 W 3600.0 73.66 338.~8 3645.9 3700.0 72.49 338.34 3745.9 3800.0 72.05 341.01 3845.9 3900.0 72.70 341.75 3945.9 4000.0 72.51 340.66 4045.9 3766.0 4101.6 4405.9 4715.0 5042.7 .80 .91 1.56 .78 .62 3860.8 338.2 4147.9 338.2 4432.6 338.3 4813.2 338.5 5099.8 338.7 3501.58 N 3814.48 N 4099.37 N 4391.68 N 4701.76 N 1400.16 W 1522.50 W 1629.94 W 1730.43 W 1836.34 W 4100.0 72.29 340.01 4145.9 4200.0 72.80 339.37 4245.9 4300.0 72.77 339.34 4345.9 4400.0 73.00 338.74 4445.9 4500.0 73.50 338.14 4545.9 5355.0 5682.2 6018.2 6338.6 6671.0 .67 1.21 .68 .41 .73 5385.4 338.8 5768.1 338.8 6055.6 338.9 6437.4 338.9 6725.0 338.9 4995.99 N 5303.10 N 5617.90 N 5917.77 N 6228.07 N 1941.11 W 2054.44 W 2172.45 W 2285.62 W 2405.53 W A Gyrodat a Di re c t i onal Survey BoP. EXPLORATION WELL: NUMBER MPF-22, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AK1295G316SS Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG CLOSURE DEPTH DEPTH SECTION SEVERITY DIST. AZIMUTH feet deg. deg. feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4600.0 74.06 339.34 P4645.9 6998.7 1.63 4700.0 73.43 340.33 4745.9 7342.2 1.68 4763.8 72.92 340.26 4809.6 7552.4 .65 7011.8 338.9 7357.5 338.9 7558.3 338.9 6533.38 N 6855.30 N 7053.31 N 2525.79 W 2645.84 W 2716.50 W Final Station Closure: Distance: 7558.34 ft Az: 338.94 deg. gyro/data 4. QUALITY CONTROL SR316.DOC Quality Control Comparisons B.P. EXPLORATION WELL: NUMBER MPF-22, 5" DRILLPIPE Location: F PAD, MILNE POINT FIELD, ALASKA Job Number : AK1295G316 / AK1295G316 INRUN/OUTRUN Comparison INRUN OUTRUN INRUN Depth Inc Inc Delta Az 1010.0 9.85 10.22 -.370 336.02 2010.0 27.57 27.61 -.043 334.46 2510.0 42.25 42.13 .119 339.33 7710.0 73.00 73.21 -.207 339.49 9880.0 72.92 72.92 -.003 340.45 For Inclinations Greater than 5 degrees: Average Inclination Difference = -.1007 deg. Average Azimuth Difference = -.0964 deg. OUTRUN Az 336.21 334.81 339.33 339.63 340.26 Delta -.192 -.353 .001' -.135 .197 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK1295G316 TOOL NUMBER: MAXIMUM GYRO TEMPERATURE' 080 74.72 C MAXIMUM AMBIENT TEMPERATURE: 40.7 C MAXIMUM INCLINATION: 75.22 AVERAGE AZIMUTH: 339.536 WIRELINE REZERO VALUE: +10 REZERO ERROR / K: CALIBRATION USED FOR FIELD SURVEY: 1248 CALIBRATION USED FOR FINAL SURVEY: 1248 PRE JOB MASS BALANCE OFFSET CHECK: POST JOB MASS BALANCE OFFSET CHECK] : CONDITION OF SHOCK WATCHES -.11 -.10 USED -.10 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARI$1ONS M.D. INC AZIMUTH TVD NORTHING EASTING 'FIELD SURVEY 9880 72.92 340.26 4809.6 7053.3 N 2716.5 W FINAL SURVEY 9880 72.92 340.26 4809.6 7053.31 N 2716.5 W SR316.DOC gyro/data FUNCTION TEST JOB NUMBER · AK1295G316 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ff 1 2 3 4 5 2500 42.25 42.25 42.25 42.25 42.25 AZIMUTH M.D. ft I 2 3 4 5 2500 339.24 339.37 339.33 339.23 339.22 SR316.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR316.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK1295G316 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY ToOL No. 080 GYRO SECTION A0099 DATA SECTION C0031 POWER SECTION C0006 BACKUP TOOL No. 713 GYRO SECTION A0088 DATA SECTION C0023 POWER SECTION C0022 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0213 A0085 A0029 A0035 A0215 A0055 A0079 A0071 WIRELINE COMPANY: CABLE SIZE: ATLAS WIRELINE 5/16" RUNNING GEAR 2 1/2" SYSTEM TOTAL LENGTH OF TOOL: MAXIMUM O.d.: 17.5 feet 2.5 INCHES TOTAL WEIGHT OF TOOL: 240Lbs SR316.DOC MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David J , Chairman Blair Wo ndzell,'~"~'-' P. I. Supervisor'~'- FROM' Lou Grimaldi, ~ SUBJECT: Petroleum Inspector DATE: March 30, 1996 FILE NO: QWQJC5DD.DOC Rig/BOPE Inspection Nabors rig 4ES BPX well #F-22 MPU Kuparuk River Field PTD #95-201 Saturday, March 30, 1996: I made a Rig/BOPE inspection on Nabors rig 4ES which is working over BPX well F-22. I arrived at this rig very early in the morning so i did not get to speak with the Toolpusher or Company Man. I visited with the driller and then made my inspection. I found all BOP equipment to be in apparent good shape. There was one 4" high pressure collar on the choke line that was welded on one end but threaded on the other. I left a note for Dan Hebert to call me when he woke up. Dan assured me that this connection had been back welded (inside) as we had discussed in the office. There is no way to tell from outward appearance and should be checked on the next rig move. The area surrounding the rig was clean and provided adequate access. SUMMARY: I made a Rig/BOPE inspection on Nabors rig 4ES and found all equipment to be in compliance. ATTACHMENTS: QWQJC5DD.XLS cc: Tom Horten/Scott Sigurdsen (Prudhoe Bay drilling) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RIG / BPS INSPECTION REPORT OPERATION: Drig Contr: Operator: Location: Drilling Workover X Cmpl. Well Name: Nabors Rig No. 4ES BPX Rep. Section 6 T. 13N R. 10E M. U UIC F-22 Rep. Larry Myers DATE: 3/30/96 PTD# 95-201 Dan Hebert Rig Ph.# 659-4154 INSPECTION ITEMS (A.) B.O.P. STACK Wellhead fig wkg press Stack wkg press Annular preventer }e rams Blind rams Stack anchored Chke/kill line size turns targeted ( chke & kill Ln.) HCR valves (chke & kill Ln.) Manual valves (chke & kill Ln.) Connections (Flgd, Whd, Clamped Drilling spool Flow Nipple Flow monitor Control lines fire protected INSPECTION ITEMS (B.) CLOSING UNIT Working pressure Fluid level Operating pressure Pressure gauges Sufficient valves Regulator bypass 4-way valves (actuators) Blind rams handle cover Driller control panel Remote control panel Firewall Nitrogen power source (backup) Condition (leaks, hoses, ect.) IN COMPLIANCE IN COMPLIANCE INSPECTION ITEMS (C.) MUD SYSTEM Pit level floats installed Flow rate sensor Mud gas separator Degasser Separator bypass sensors Choke line connections Trip tank INSPECTION ITEMS (D.) RIG FLOOR Kelly cocks (upper, lower, IBOP) Floor valves (dart, ball, ect.) Kelly & floor valve wrenches Drillers console (flow monitor, rate indicator, pit level indicators, gauges) Kill sheet up-to-date Gas detection monitors (H2S & methane) ~Hydraulic choke panel ~ke manifold INSPECTION ITEMS IN COMPLIANCE IN COMPLIANCE IN COMPLIANCE REMARKS: Location clean and neat RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? OK Distribution: orig - Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector 3/23/96 AOGCC REP: OPERATOR REP: Kill Sheet Current? OK Louis R Grimaldi F1-022 (Rev. 3/93) QWQJC5DD.XLS 1, Type of Request'. 'STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon .__. Suspena Opera,lea Shutdown ~ Re-enter suspended well Nter ~slng ~ Repair well ~ Plu~in{] ~ Tlrne extension ~ Stimulate Change approved program X 2. Name of Operator BP Explo_ration (Alaska) lng. 8~ Address P, O. Box 1~881~, Anchorage, ~aska 4. ~c~lon of well at su~ace 1897' N~L, 2~2' WEL, SEC. ~, T13N, R10E At ~p ~ pmdu~ inte~[ 3~ N~L, 1912' WEL, SEC. 25, T14N, RgE At effe~ve depth At total depth 4074' NSLo 1978'WEL, SEC. 25, T14N, RgE 12. Present well condition summary Totsl depth: measured true vedical Effective depth; measured true vertical Puli [ubing Variance am ! m ,5. Type of D~velopment Ex~lotato~/ ORIGINAL feet Plugs (measured) feet feet Junk (measured) feet Perforate Other ~ 6~'-Datum elevation-(DF or I~) Plan RTE = 45 feet 7, Unit or Property name MIIne Point Unit 8, Well number MPF-22 9. Permit number 95.201 10. APl number ,50- 029-22632 11. Field/P~01'-- Milne Point/Kupan~k River ,. Casing Structural Oonduotor Intermediat~--- Liner Length Size Cemented Measured depth True vertical depth 0 Perforation depth; meaeured true vertical Tubing (size, grade, and measured depth) I. Packers and SSSV (type and measured depth) 13. Attachmer~'ts Description summary ~f proposal X Tko:, Detailed operations program BOP sket~ · 14. Estimated date for c~mencing operation 16. If proposal was verbally approved Name of approver .__ ii i 17. { hereby oen_~ that the foregoing is tru~ _Signed ~' Date approved 15, Status of well classification as: :Oil [ G~ , Suspended Service correct to the best of my knowledge. Title Sen/or Drift_lng Engineer ,, Date FOR COMMISSION USE ONLY Conditions of approval: Notify Co,mission so representative may witness Plug integrity__ BOP Test Location clearance __ Mechanical Integrity TeSt .. Subsequent form required 10- /-[d~ .7' Original Signed By Approved by order of the Commission 0avid W. Johnston Form 10-403 Rev 06/15/88- - rLApproval No. ?~ -00..~ .&pproved ,.,cpy Retu rned ' - C-~ommissi0ner .... .Date //~/~-- SUBMIT IN TRIPLICATE DMIqqI~ S~DIA~3S G3~UHS Nd~£:£0 96, ~0 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 28 February 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ECC No. ~-~O ~ MPF-22 1 LDWG TAPE+LIS Run # 1 6595.00 MPF-14 1 LDWG TAPE+LIS Run # 1 6596.00 Please sign and return to, Attn.Suite Rodney D.201 Paulson Western Atlas Logging Services 5600 B Street Anchorage, AK 99518 ~ ~AX t° (907) 563-7803 "~'~"~'~a~ Received b : Date: ALAS OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 12, 1995 Tim Schofield, Senior Ddlling Engineer BP Exploration (Alaska) inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Miine Point Unit MPF-22 BP Exploration (Alaska) lnc 95-201 1897'NSL, 2802'WEL, Sec 06, T13N, R10E, UM 3974'NSL, 1979'WEL, Sec 25, T14N, R09E, UM Dear Mr Schofield- Enclosed is the approved application for permit to drill the above referenced well. The permit to ddll does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION Ijb/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 '~. Type of work Drill [] RedrillFI lb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen[] Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 45 feet Milne Point / Kuparuk River 3. Address 6. Property Designation P. 0. Box 196612, Anchorage, Alaska 99519-6612 ADL 355018 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1897' NSL, 2802' WEL, SEC. 06, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 3727' NSL, 1912' WEL, SEC. 25, T14N, R9E MPF-22 2S100302630-277 At total depth 9. Approximate spud date Amount 3974' NSL, 1979' WEL, SEC. 25, T14N, R9E 12/15/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL355021 1306 feet MPF-46, 46'@ 1850'MD feet 5083 16346;MD/7235'TVD feet 16. To be completed for deviated wells ,/ 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 300 feet Maximum hole angle z2 o Maximum sudace 3005 psig At total depth (TVD) 7529'/3758 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.1# NT8OLHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 8794' 31' 31' 8825' 4503' 1691 sx PF 'E', 250 sx 'G', 250 sx PF 'C' 8-1/2" 7" 26# L-80 Btrc ~ Mod B16392' 30' 30' 16422' 7500' 434 SX Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor SurfaceRECEIVE Intermediate Production OEO 1 't ~995 Liner Perforation depth: measured Al~ka Oil& G~s Cons. Commission true vertical An, chorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify that the for?going is~ ti'de and correct to the best of my knowledge Signed f/% .~.~-~/'~¢-~2~ . Title Senior Drilling7 En~tineer i.,~_/~,~t/C~ ~ Date -- ~t Commission Use Only Permit Number IAP~'number Approval date See cover letter , ?,¢'-_ .~z:;:~ // 150-~-~?-~'-.~-~--~".,~.2_. ]¢_._/'~¢)../'~--" for other requirements Condibons of approval Samples required [] Yes ,1~ No Mud Icg required []Yes ')~ No Hydrogen sulfide measures ~ Yes [] No Directional survey required ,~1 Yes [] -No Required working pressure for BO( igi F igr . 5M; I--I10M; [-115M; Other: David W. Johnston by order of / ;" Approved by Commissioner me commission Date ;,_., ?.> Form 10-401 Rev. 12-1-85 Submit in triplicate NORTH SLOPE ERD WELL I Well Name: ]MPF-22 ] Well Plan Sttmmary I Type of Well (producer or injector): ] KuparukProducer I Surface Location: 1897' FSL 2802' FEL Sec 06 T13N R10E UM., AK. Target Location: 3727' FSL 1912 FEL Sec 25 T14N R09E UM., AK. Bottom Hole 3974' FSL 1979' FEL Sec 25 T14N R09E UM., AK. Location: Note: Target & BHL footages are based on assumed true and square sections and are not surveyed legal locations. [AFE Number: 1330205 ] [.Rig: ]Nabors27E [ Operating days to drill and case: IMD: I16422' I [TVD: 17500'BKB [ IKBE: 146. IWell Design (conventional, slimhole, etc.): Ultra Slimhole, 7" Longstring Formation Markers: Formation Tops MD TVD Formation Pressure/EMW Base permafrost 1847' 1795' n/a -- NA (Top Schrader) 6878' 3034' 1653 psig / 8.0 ppg OA ' ' 1744 psig / 8.0 ppg Base Schrader Bluff 8417' 4445' 1848 psig / 8.0 ppg Top HRZ 15488' 685 6' n/a Base HRZ ' ' n/a Kupark D Shale 15793' 7076' n/a Kuparuk C ' ' 3598 psig / 9.6 ppg Target KUP A3 16014' 7195' 3616 psig / 9.6 ppg Total Depth 16422' 75 00' n/a Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn IJel~,th Top Btm Size Tbg MD/TVD MD/TVD O.D. 30" 20" 91.1# NTS0LHE weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btm 8794' 31/31 8825/4503 8 1/2" 7" 26# L-80 Btrc & 13922' 30/30 16422/7500 ModB 2500' N/A (tbg) 2-7/8" 6.5# L-80 EUE 15819' 29/29 15848/7145 8rd Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7529' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3758 psi is 3005 psi, well below the i~;tcrnal yield pressure rating of the 7" casing. The Modified Buttress 7" 26# will be l'tll'l on bottom. ~:~ .~_t-. ~Ti. ~ V ~__..~ , Logging Program: I Open Hole Logs: Surface Intermediate Final Cased Hole Logs: LWD GR/Resistivity IHR Gyro LWD GR/Resistivity/Neutron/Density None Oil & Gas Cons. Co,mn An, cl~orage ssion A gamma ray log will be obtained from surface to TD with LWD tools. Mud~.._~Ic~,,~,in~, is not required. AP1 # 50-029-22xxx December 10, 1995 NORTH SLOPE ERD WELL Mud Program: Special design considerations LSND freshwater mud. Special attention to gravel and coal in the surface hole, with appropriate viscosity and weight to control each. The use of frequent short trips as per the updated pad data sheet are encouraged. Surface Mud Properties: [ Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss ,, 8.6 80 15 8 10 9 8 to to to to to to to 9.6 100 35 15 30 10 15 Pl:0duction Mud Properties: [ " Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 15 3 7 8.5 6-10 tO tO tO tO tO tO tO 10.2 50 20 10 20 9.5 4 - 6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1300' [ Maximum Hole Angle: Maximum Dog Leg: Inclination in target: Close Approach Well: 72 degrees < 4 degrees 40 Degrees See Traveling Cylinder report There are close approach wells for drilling MPF-22. Milne Poiut F-46, (No Point Well ) has a shut in close approach at 1800 to 2050 feet. This well has a bridge pulg in the casing which will not be removed before drilling this inteval in MPF-22. These wells will allow this path to be drilled as per BP's close approach guidelines and shut in procedures.. The well path should be followed as close as possible to ensure we do not compromise the proximity toleranxces. ERD Aspects: This well be ta high departure at this depth and should be drilled with due attention to drilling practices. API # 50-029-22xxx December 11, 1995 NORTH SLOPE ERD WELL Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas ($64-4305) with request. Fluid Handling: All drilling and completion fluids can be annular injected after allowing the cement on the 7" casing cement job to cure 6 hours following CIP. Request 1. 2. to AOGCC for Annular Pumping Approval for MPF-22: Approval is requested for Annular Pumping into the MPF-22, 9-5/8" x 7" casing annulus. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 8617' md (4506' tvd) which is below the Schrader Bluff Sands and into the Seabee formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# L80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Seabee formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 2302 psi for a 10.4 ppg fluid in this well. MASP - 4325 psig- ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD 5. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7-24-95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 6. Pumping into the hydrocarbon reservior will not occur. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED (BBL) VOL (BBL) Milne Point F-1 0 35,000 1/1/95 12/31/95 Milne Point F-13 3234 35,000 1/1/95 12/31/95 Milne Point F-62 0 35,000 10/13/95 - 10/13/96 Milne Point F-25 230 35,000 1/1/95 12/31/95 Milne Point F-37 7032 35,000 1/1/95 - 12/31/95 Milne Point F-38 0 35,000 10/26/95 - 10/26/96 Milne Point F-45 7524 35,000 1/1/95 - 12/31/95 Milne Point F-53 0 35,000 1/1/95 - 12/31/95 Milne Point F-61 0 35,000 1/1/95 - 12/31/95 Milne Point F-69 10032 35,000 8/31/95 8/31/96 Milne Point F-78 8053 35,000 9/12/95 9/12/96 Milne Point F-70 2483 35,000 9/28/95 9/28/96 Milne Point F-30 0 35,000 1/1/95 - 12/31/95 FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to avoid freezing. AP1 # 50-029-22xxx December 2, 1995 NORTH SLOPE ERD WELL DRILLING HAZARDS AND RISKS: See both the updated Milne Point F-Pad Data Sheet and L-Pad Data Sheet prepared by Pete Van Dusen for information on the No Point#1 (F-46), and review recent wells drilled on both F and L pads. Most of the trouble time on recent wells has been due to equipment mechanical problems with the BHA, rather than formation drilling problems. The MPU PE group will be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Lost Circulation: No Point #1 (MPF-46) did not experience any lost circulation while drilling on F- pad. The max mud weight reached on that well was 10.3 ppg. They did experience some mud losses while cementing 7" casing. Lost circulation while drilling the production interval has been a problem on 4 different L-pad wells, the closest pad to F-pad, although none of them have BHLs in the F-pad drilling area. The Kuparuk sands and a number of shallower intervals typically are highly fractured. Wells F-69, F-61, AND F-53 lost varying amounts of mud (from 70 to 220 bbls) drilling through or near the top of the Kuparuk sands, especially while running casing and cementing. Be prepared to treat these losses while drilling initially with LCM treatments. There has not been any appreciable amount of lost circulation in surface hole on any of the F Pad wellls to date. This is due to setting surface pipe deeper to cover the Schrader Bluff interval which might break down at the mud weights required to TD the well. Stuck Pipe Potential: Well MPF-53 was stuck coming out on the short trip at surface casing point. Proir to this incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. Subsequent fishing operations were not successful and a very expensive BHA was lost in the hole from 2516 - 3342. While drilling No Point #1 the 6" BHA was stuck in 8-1/2" hole section for several hours at 6882 ss (13608' MD) before jarring free. They became stuck after tripping back to bottom following a bit trip. Lack of proper hole cleaning parameters appears to have contributed to this problem. Stuck pipe has occurred on 3 L-pad wells at the interface between the Kalubik and D-shale (called the Kuparuk cap rock). These wells and the corresponding depths at which they were stuck were: L-06 @ 6871' ss, L-07 @ 6859' ss, L-11 @ 6835' ss. Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 97.5 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3594 psig (9.6 ppg equivalent MW). Trip Schedules are required for all trips. All trips will be performed with a trip tank or one pit isolated for use as a trip tank. Formation Pressure: The maximum expected pore pressure for this well is 9.6 ppg EMW (3594 psi @ 7200' ssTVD). There has been no injection in this region since then, therefore the reservoir pressure should not exceed this estimate. Several wells from F pad have exhibited "breathing" of mud, alternating loss and flow back of uncontaminated muds volume. No oil, gas, or other formation fluid influx have been confirmed even when large fluid influx have been measured. In spite of this we will continue to take the conservative approach to circulate the well until stable before tripping or before running casing. When this occurs, the drilling superintendent should always be quickly notified and kept appraised. WATER USAGE Have the water truck drivers track the water usage on a daily log. Send a copy of this log to Dennise Casey in the Anchorage Office on a monthly basis. AP1 # 50-029-22xxx December 2, 1995 NORTH SLOPE ERD WELL MP F-22 Proposed Summary of Operations 13360 Feet Displacement o ° . . . 10. 11. 12. 13. 14. 15. 16. 17. Drill and Set 20" Conductor. Weld an FMC landing ring for the FMC Gen 5A Wellhead on the conductor. PrePare location for rig move. MIRU Nabors 27E drilling rig. NU and function test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by AOGCC supervisor. Build Spud Mud. Drill a VERY SMOOTH "ERD" BUILD UP 12-1/4" surface hole to 8617' md (4506' tvd). (Note: This hole section will be LWD logged with GR/Res). Run and cement 9-5/8" casing. ND 20" Diverter, NU and Test 13-5/8" BOPE. Run Wear Bushing. RIH w/PDC bit and Double Power Section PDM (motor). Test the 9-5/8" casing to 3000 psig and plot pressure vs volume for LOT baseline. Drill out float equipment and 10 feet of new formation, Perform a LOT to a maximum of 12.5 ppg as per Recommended Practices Manual. Record pressure vs. cumulatrive volume for LOT test for well file. Ensure the mud is suited for ERD wells with lubrication, monitored for Torque and drag. Follow Pad Data Sheet short trip guidelines. Drill 8-1/2" hole to TD at 16346' MD (7499' TVD). (Note: This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing. Test casing to 3500 psi and freeze protect wellbore to 2000' TVD with diesel. Closely monitor casing running loads for drag. MAke sure there is a circulating head for the topdrive before starting to run casing. ND BOPE and NU dry hole tree. Release rig to MPF-14. Note: This well will be perforated, hydraulically fractured and cleaned out with a completion rig and prior to running the injection completion. Following the stimulation the well will be left with a retrievable bridge plug (RBP) set 500' above the perforations and kill weight brine in the wellbore. MIRU workover completion unit. ND dry hole tree. NU BOPs and test. PU and RIH with 2-7/8" EUE 8rd tubing with RBP retrieving tool. Release RBP and POH standing back tubing. RIH with Electric Submersible Pump (ESP) completion on 2-7/8" EUE 8rd tubing. Set 2 way check. ND BOPE and NU tree and test. Pull two way check, freeze protect, set BPV, close valves. Test tree. RDMO with workover/completion rig. POST RIG WORK . Complete the handover form and turn it and the well files over to production. Turn over the well files along with the handover form. . A SBT/GR/CCL is not required on this well and will only be run if there are problems on the production cement job. . An adequate volume to cover 2000' of diesel needs to be injected down the 7" X 9-5/8" annulus before moving the rig off the well. Please note type and volume of freeze protection pumped down the outer annulus on the morning report. . The rig will not complete this well. PEs will perforate, frac and clean out this well with a completion rig. API # 50-029-22xxx December 2, 1995 MPF-22 Cement Calculator Milne Point'Cement and Centralizer Calculations Well MPF-22 Surface (1 Stage) Cement Job cement Type E G Hole Size 12.25 Yeild (cfs) 2.17 1.1 5 Casing Size 9,625 Weight (ppg) 1 2 1 5.8 BPF 0.0558 BPF + 30% 0.0725 BPF + 100% 0.1116 - Depth BBLS Cu. Ft. Sacks Top of Cemenl Shoe Depth Calculated G Tail Volume 623 51.2 288 250 8202 E Lead Volume 1500 167.3 940 433 6702 E Tail Volume 6702 486.0 2729 1258 0 Total E 1 6 91 Total G 2 50 9-5/8" Bows I 0 Production 1-Stage Cement Job I Cement yeild Hole Size 8.5 G ST1 Slurry 1.15 Casing Size 7 BPF 0.0226~ BPF + 30% 0.0294! Top of Cemenl Stage 1 BBLS Cu. Ft. Sacks Calculated Formation mop~~ 89 l 499 434 13500 TD Centralizers 1 06 Turbulators Total G ST1 434 Total ST Blade~ 1 07 ~EC 1 1 1~95 Alask~ 0ii & G-~s Cons. C0m;nission Anchora,qe Page 2 NORTH SLOPE ERD WELL MPF-22 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 80 deg F at 4000' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: 1691 THICKENING TIME: Greater than 4 hrs at 50° F. 'TAIL CEMENT TYPE: Premium G ADDITIVES' 0.2% CFR-3, 0.2% Halad-344, 2.0% CaC12 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc YIELD:I.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Type C Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 cu ft/sk. MIX WATER: 11.63 gal/sk APPROX NO SACKS' 250 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on the bottom 10 joints above the FS. 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Do not overdisplace by more than 1/2 the shoe joint. Mix slurry on the fly -- batch mixing is not necessary. Make sure to fill the casing every joint to avoid having to shut down to fill the casing. This has stuck casing while we were shut down filling only 5 joints. CEMENT VOLUME: 1. The Tail Slurry volume is a standard 250 sacks is calculated to cover the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. AP1 # 50-029-22xxx December 2, 1995 NORTH SLOPE ERD WELL MPF-22 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON THIS WILL BE A SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL WITH TOC TO THE START OF THE DROP SECTION: CIRC. TEMP: 140° F BHST 170 deg F at 7260' TVDSS. SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS' 434 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS' < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7-1/8"" x 8-1/4" Straight Blade Turbulators -- two per joint on the bottom 17 joints of 7" Casing (34 total). Use stop collars to fasten centralizers to casing joints. This will cover 300' above the top of the Kupamk sands. 2. Run one 7-1/8" x 8-1/4" Straight Blade Turbulator a minimum of 60 feet inside the 9- 5/8"casing shoe to avoid hanging up on the shoe. This centralizer may be attached across a casing collar connection. 3. Total 7-1/8"" x 8-1/4" Straight Blade Turbulators needed is 35. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm until the plug bumps, but not more than to displace cement just above the production zone. Batch mixing is not necessary. Make sure to fill the casing every joint to avoid having to shut down to fill the casing. This has stuck casing while we were shut down filling only 5 joints. CEMENT VOLUME: 1. The cement volume is calculated to cover 1000' md above the top of the Kuparuk Sands with 30% excess over a guage hole. API # 50-029-22xxx December 2, 1995 o Gcz~ Doo~ OOgl LO'I:rC ,~V-Ic', ~3S Ill/1 ~ ~ I I : I i I I I i I I i I I ~ I I I I I N-J.L~nSi-i-iVH NEIiSTAZ([ / '%J OCg ~ IO..,,~ X IO:~ ~q3 S~ GAL a, ar4q YLVO .LK:3d "~'3U]~C) : I I AI~ paAoddd~ R H'-c:oR k N L~'ZCS~ 1 gUN BZ'OC~I SA Gg'lSt,91 aN j 8'lk51~l IIAl '!H8 O_-~3~d SJd~ £ct~ 2~-_4dN ~i!rl~-sv ~-3dA _4tin: ~ aUllN t~auoz -auold a~S ~t5~lV ~UllllW[[ sa~,~as Ioa~ou~-XdEi :BPX-$ho, r, ed Set~ vi ce~ Dr'i EEl n g A[clskcl S-t:o,-te P[o, ne: Zone4 Hilne P-t , MPF MPF-~ As-:Bui l-t: MPF-P2 WP3 WPFS I ' I t3:!:0 STATUS Dcd:e Survey Refexeace: WELLHEAD ReXexeac~ World Coordiaal~s: i. aL 70,30.27 N- Lo~. 149.39.30 W Refeamce GRID $~'l~a: AlaO~a ~ Pla~ ~ Alaska 4 Refexanc~ GRID C0ordiaales: (fi): 6035348.30 N 541761,56 E North Aligned To: 'I'RU~ NORTH Vefllcal Section R~exeme: WELLHEAD TVD R~£e~eae~: WELLHEAD BPX-Shared Setwices Drilling Alaska .g~e Pig Zog4 MLLae l't: MFF MPF-22 As-l}uill MPF-22 WP3 W'PF~ Halliburton Energy Services - Drilling Systems PSL Proposal Report A~aska Oil & Gas Cons. Comm{ssion Calculoted using the Minimum Curvalure Method Computed using WItI-CADD8 RLqr2, I,B Vertical Seotkm Plane: 341,07 deg, rote: 12a,95 Time: 12'.43 gat Last ReMsion: 12r2~ © ~D F ~D .)212> Measure.3 ~ Dd.q. Sul~;e~ TVD Cm T O T A L Dep~ lya-. Oepm Leag~ Rectam~ar (r0 (deg.) (deg.) (r0 (r0 (n) (nj (a) Nmthiag Eastiag (n) (n) TIEIN O.00 0.00 0.00 -45.00 0.00 0.00 0.@ON KOP ISTARTOF BUILD @ 1.00deg/100 R 300.00 0.00 0.00 255.OO 3DO.O0 B00.00 0.00 N 400,00 1,00 338.00 354.99 399.99 100.00 0,81N 0.@OB 6035M8,30 541761.56 0.00E 6035M8.30 541761,56 0.3~V 6035349.11 541761.23 Closure Veaflcal Build Walg DLS (3u~ Fa4ncted Total Man Ho~ kiln Ho~ Dir, Verl DisC. Die, $<ti~n Rale Rag Dogleg m~-~m~c, oor~ ~ Error Max Err Eaor (fl) (de8.) (11) (dF/lOOfO (Og/iooR) (dg/iOOR) Cd,g) (fi.) (fi) (it) (it) (deB,.) (ft) 500,00 ZOO 338.OO 454,P6 499,96 100.00 3.24N STAKT OF BUILD @ 1.50 deg/lO0 l~ 600.00 3.00 338.00 554.86 509.86 100.00 7.ggN 700.00 4.50 338.00 654.65 699.65 100,OO 13.34N 0.00@ 0.00 0.00 0.00@ 0.00 0.00 0.00 0,00 0.87@ 338.00 0.87 1 ,OO 0.00 1.31W 60'35351.53 541760.2.3 3.49@ 338.OO 3.49 2.9-ohr 6035355,57 541958.58 7.8,5~338.00 7,84 5.396r 6035361,62 541756.09 14.39~338.00 14.37 Survey Tool 0,00 0.00 0.00 0.0 0,00N 0,00 E 0.00 0.00 0.00 0.00 B PHG-I~BD 0.00 0,0 O.00N 1.00 1.0 0.81N 0.00 E 2,29 2.29 0.00 0,64 BPHG-PBD 0,3=e~/ 2.53 2.53 68.00 0,89 BPHG-PBD l-O@ 0.00 1.00 2.0 3.24N 1.31W 2.82 2,82 68.00 1.14 BPHG.PBD 1.00 0.00 1.50 0.00 1.00 3.O 7.28N 1.50 4.5 13.34N 2.94W 3.14 3,14 68.00 1.39 BPHO-PBD 5.3~V 3.50 3,,18 68.00 1.65 BPHG-PBD 800.00 6,00 338.00 754.22 799,22 100,00 21.83N 8.82W 6035370,08 541752,62 23,54@338.OO 23.51 START OFBUILD ~ 2,00 deg/100 ft 900.00 7.50 338.00 853.53 898.53 100.00 32.73N 13.22W 6035380,95 541748.15 35.300338.00 35.25 10OO.00 9.50 338.00 952.42 997.42 100.OO 46.43N lS.TeW 6035394.62 541742.54 50.08@338.OO 50.00 1.5O 0.00 1.50 0.00 2.OO 0.00 1.50 6.0 21,83N 8.87W 3,88 3.84 68.00 1.92 B PHG-PBD !.50 7.5 32.73N 13.:~W 4,28 4.21 68.00 2,19 BPHO-PBD 2,00 9.5 46.43N 18,71W 4,7l 4.58 68.00 2.48 BPHO-PBD [-4 II00.@@ 11.50 338,00 1050,74 1095,74 1OO,00 63.33N' 25.5~N 6035411A8 541735.62 68.30@338.00 68,20 STAKT OF BUILD @ 2.50 deg/100 fl 1200.00 13.50 338.00 1148,37 1193.37 lo@.00 83.39N 33.68W 6035431.50 541727.40 89.940338,00 89,81 13OO.00 16,00 338.OO 1245.0q 1290.07 lo@.00 107.00N 43.2.~W 6035455.04 541'/17.73 115.4C@338,00 115.23 0.00 ZOO 0.00 2,50 0.00 2`00 ! 1.5 6333N 25.5~¥. 5.16 4.94 68,OO 2.78 BPHG-PBD 2'00 13.5 83,39 N 33.65W 5,64 5.31 68,00 3.10 BPHG-PBD 2.50 16.0 10'L00N 43.22W 6. I6 5.65 68.OO 3.46 B PHG-PBD 1400.00 18.50 338.00 1340.56 1385.56 100.00 134.49N 54.3ffw 6035482,47 541706.47 145,05@338.00 144.84 1500,00 21.00 338,00 I434.67 1479.67 lo@.00 165.82N 66.99W 6035513,73 541693.64 178.84@338.00 178.58 I600.00 23,50 338.00 1527.22 1572.22 10030 200.92N 81.16V 6035548,75 541679.26 216.711@338.00 21629 1700.00 26.00 338.00 1618.02 1663.02 100.00 Z59.74N 96.86V 6035587.47 541663.36 258.56@338.00 258.19 END OF BUILD 1740.OO 27.00 3-38.00 1653.82 I698,82 40,00 256.29N 103.5~V 6035603.98 541656.59 276.41@338.00 276.02 Base Pea~uoffos( 1847.94 27.00 338.00 1750.OO 1795.OO 107.94 301.7'2N 121.9~' 6035649.31 ~ 1637.98 325.42@ 338.00 324.95 2.5O 0,00 2.50 0,00 2,5O 0.00 2.50 0.00 2.50 0.00 0.00 0.00 2.50 18,5 134.49N 54.34W 6.73 5.98 68,OO 3.84 BPHO-PBD 2.50 21.0 165.82N 66.9~7 7.33 6.29 68.OO 4.24 BPHO-PBD 2.50 23.5 200.92N 8 I.l~V 8.OO 6.59 68.00 4,67 BPHG.PBD 2.50 26.0 239.74N 96.86V 8.72 6.86 68.00 5,13 BPHG-PBD 2.50 27.0 256.29 ~ 103.55W 9.02 6.97 68.00 5.32 B PHG-PBD 0.00 27.0 301.72N 121,9CW 9,85 ?.39 68.OO 5,64 BPHG-PBD \ O3 Halliburton Energy Services - Drilling Systems PSL Proposal Report Dale,: Wellp~l~ ID; MPF-~ Wp., Menmm~ ~ Drift 8ubsea TVD Couv~ T 0 T A L GRID Coardina~ (n) (~g.) (~g.) (n) (~) (n) (n) in) (a) 19~.~ ~.~ 338,~ 1832,~ 18~.~ ~.06 3~,47N 137.5~ ~56S7.96 5416~10 ~7.21~33B.~ 3~.68 0.~ 2~.~ .~.50 338,18 I~.lt 1~5.11 !~,~ 3~,38N 155.2~ ~5~1.77 54t~,20 414.540338,01 413.95 2,50 21~.~ 32,~ 338.33 ~6.~ ~1.~ l~,~ 431.87N 174.1~ ~5~.14 5415~.~ 4~.66~338,04 4~.01 2,50 22~,~ 34.50 338.46 ~.67 21M.67 1~,~ 48Z~N 194.~' ~5~.99 5415~.5~ 5~,48~338.08 519.~ 2,~ 2~0,~ 37.~ 338.~8 2170.82 ~215.82 1~,~ 537.19N 215.7~ ~358~,21 541542.~ ~.~90338,12 ~&13 2,~ 2440,~ 39,49 338.68 2~9.35 ~.35 1~,~ 594.~N 238.~ 6~59~1.73 541519.96 ~,~O338.17 639.97 2,50 2540.~ 41.~ 33837 23~,11 2370.11 1~.~ 655.65N ~61.~ ~3~,41 541495.95 ~06.05~338,~ 705.14 Z50 ~.~ ~.49 3~,86 23~.95 ~2~5 1~.~ 719.52N 286.~ ~3~,14 541470,~ ~4.55~.338,~7 ~3.63 2.50 ~.~ 46,~ 3M.93 ~67,73 2512,73 1~.~ ~863~N 31~51W ~36132.~ 541~4.~ ~6.16~338.33 ~5.19 ~50 ~0.~ 49.49 339.~ 2534.31 ~9.32 1~.~ ~S~6N 339.~W ~36202.~ ~1417.52 ~0.75~338.38 919,73 2.50 2~.~ 5~.~ 339.~ 2597.~ 2~2,~ i~.~ ~.~6N 366.9~V ~36274.~ ~13~.4~ ~8.17~338.43 ~.I1 ~50 3~.~ 54A9 339,13 2657.~ ~O2.~ 1~.~ I~3.10N 395.56V ~3~9.07 5413~.~ 1~8.2903~.~ I~.l? 2.50 31~,~ 5~99 339.19 2713,73 ~58.73 I~.~ !~.33N 424.9~ ~3~26.14 3413~.~ 11~.910338.53 1159,~ 2,50 ~.~ 59.49 339.~ 27~6.3~ '~l~,~ ~.00 ll~9.~N ~5.1~ ~36505.45 5413~.~ 1~5.92~338.57 1~,75 Z50 33~.~ 61.99 339,30 ~15.~ ~60.~ I~,~ I~I.41N ~6.0~ ~86.85 541~.~ 1333.15~33&62 1331.94 2,~ 3~.~ ~.49 339.34 ~.~ ~5.~ 1~,~ 13~.~N 517,~ ~6670.~ 541236.68 14~.43~338.66 1421.18 3~.~ ~9 339.39 ~1.34 2~6.34 1~,~ 1410.~N 549.~ ~55,32 5~.~ 1513.58033s,7~ ~5~30 3~.~ ~.49 339.~ 2~8A1 ~83.41 1~.~ 1497.19N 582.31W ~36842.~ 541170,96 1~.~338.75 1~.!3 2.50 37~.~ ~1.~ 339.48 297I.~0 3016,40 1~,~ 1585.58N 615.4~V ~3~30,27 5~1137.~ 17~,83~338.~ 1~9.48 37~_47 73,~ 339,50 29~,~ 30~.~ 40.47 1~1.74N 628.9fi~ ~3~66.35 ~1123.~ 1~9.4~338.80 1~8.~ 7017.54 73.~ 339,~ 3930.~ ~75,~ 3~7.~ 4521.32N 1713.~V ~3~59.~ 5~3.~ 48M.9~339.~ 4832,53 CASING ~T OD = 9 5/8 ~, ID = 8.84 ~, W~= ~.~ I~ 8617.~ 73.~ 339,50 4397,~ ~2.~ 15~.~6 5954.03N 2~8.7~ ~1~.35 53~.52 63~.53~339.31 6361,53 0.~ Ba~ 86~,~ 73.~ 339.50 ~.~ ~5.~ 8,08 5961.27N 2~1,4~ ~!~6.~8 53~77.~ ~72.2~339.31 6369.~ 0.~ 88~.~ 73.~ 339.~0 4458.45 ~03.45 199,~ 6140.34N 231~,35~ ~1475,~ 53~.~ ~,~339.32 ~60_37 0.~ C]~ Vertical Build Walk DLS ~ Expected Total M~x Hot Min H~r Dlr. Vc~t Dist. Dir. Scion Rate Rate Dogleg Rec/angul~ Cocads En~ E~or Max Er~ Errox (R) (deg.) (Il) (dg/lO0fl) (dg/iO~) (ag/J0011) (deg) (fi) (fi) (il) (il) (deg.) (fl) Sut-,,e,y T~ml 0,00 O.00 27,0 340.47N 137,50/ 10.57 7.75 68.00 5,92 BPHG-PBD 0.18 2.50 29,5 31~.38N 155.22W ! 1.41 7.98 68.06 6.4~ BPHG-PBD 0.15 2.50 32.0 431.87N 174.10/ 12.33 8.19 68.13 6.98 BPHG-PBD 0.13 0.12 0.10 0.09 O. O8 2.50 34.5 482.83N 19434W 1331 8.36 68.20 7.54 BPHG-I'BD 2.50 37.0 537.19N 2153~V 1438 8,50 68.27 8,12 BPHO-PBD 2,50 39.5 594.83N 238,2bAV 15.52 8.62 6833 8,72 BPHG-PBD · 2,50 42.0 655.65N 261,97%' 16.77 8.70 68.40 9.34 nPHG-PBD 2.50 44,5 719.52N 286.7.%V 18.11 8,75 68.46 9.98 B PHG-PBD 2.50 47.0 786,34N 312,51W 19.56 8,77 68.52 10.62 BPHG-PBD 0.07 0.0'/ 0.06 2.50 49.5 855.96N 339.28W 21,13 8.76 68,57 11.28 BPHO-PBD 2.50 52.0 928.26N 366,9~1/ 22.83 8.72 68,63 11.95 BPHO-PBD 2.50 54,5 1003.10N 395.50/ 24.68 8.65 68.68 12.62 BPHG-PBD 0,06 0.O5 0,05 2.50 57.0 10~0.33N 424.96V 26.71 8.55 68.74 13.30 BPHG.PBD 2,50 59.5 II59.82N 455.13W 28.92 8.43 68.79 13.98 BPHO-PBD 2,50 62.0 1241.41N 486.01W 31.35 8,28 68.83 14.65 BPHG-PBD O. O5 O. O5 0.05 2.50 64.5 1324,94~N 517.5,lW 34.05 8.12 68.88 I532 BPHG-PBD 2,50 67.0 1410.25N 549.60/ 37.07 7.93 68.93 15.99 BPHO-PBD 2.50 69.5 1497.19N 582,3M 40.48 '/.75 68.98 16,64 BPHG-PBD 2.50 0.04 2.50 72.0 1585.58N 615.43W 44,38 7.56 69,03 17.28 BPHO-PBD 2.50 0.04 2,50 73.0 1621.74N 628.9~V 46.06 7.49 69.05 17,54 BPHO-PBD 0.00 0.00 0.00 73.0 4521.32N 1713.06V 185.85 16.17 69.38 32.58 BPHG-Pi{D 0.00 0_00 0.00 0.00 73.0 5954,03R 2248.7_W/ 0.03 0,00 0.00 0.00 BPHG-PBD 0.00 73.0 5961.27N 2251.4.%V 255,94 20.62 69,42 `10.25 BPHO-PBD 0.03 73.0 6i40.34N 2318.3';W 264,66 21.17 69.42 41,21 BPHG-PBD 8825.01 73,00 339.50 4458.45 4503.45 0.01 6140.35N 2318.3~V 6041475.29 539409.87 6563.45@339.32 6560,38 0.00 9g25.00 73,00 339.50 4750,82 4795.82 999.99 7036,08N 2653.2~,V 6042369.15 5390q0.~.~/ 7519.74~ 339.34 7516,32 0.00 9825.0I 73.00 339,50 4750.42 4795.82 0.O1 7036.09N 2653.3CW 6042369.16 539070.27 7519.75@339,34 7516.33 0,00 STARTOF CURVE @ 1.00deg/100 R 9880.47 73_00 339.50 4767.04 4812.04 55.46 7085.77N 2671.85W 6042418.74 539051.43 7572.79@339.34 7569.35 0.03 9980.4'/ 72.99 340.55 4796.28 4841.28 103.00 7175.65N 2704.$~V 6042508.,13 539018.29 7668.41@339.35 766~.96 -0.01 10080.47 72.99 341.59 4825.53 4870.53 100.00 7266.10N 2735.53W 6042598.71 538986.79 7763,99@339.37 7760.58 -0.03 10180.47 73.00 342.64 4854.78 4899.78 100.00 7357.10N 2764.92Vv' 6042689.55 538956.95 7459.51~ 339.40 7856.19 0.03 0.00 0.00 73.0 6140.35N 2318.39W 26,1.66 21.17 69.42 41.2i BPHG-PBD 0.00 0.00 73.0 7036.08N 2653.293V 308.30 23.95 69.43 46.01 BPHG-PBD 0.03 0,00 73.0 7036,09N 2653.3[W 308.30 23,95 69.43 46.01 BPIHRMWD-PBD 0.00 1.05 1.05 0.00 73.0 708537N 2671.87W 308.68 24.08 69.43 46.35 BPIHR/vIWD-PBD 1.03 74.0 7175.65N 2704.54W 309.39 24.35 69.45 46.96 BPIHILMWI)-PBD 1.03 75.0 7266.10N 2735.5~V 310.14 24.63 69.48 47.59 BP[HP,3~VD-PBD ' 1.00 76.0 7357,10N 2764.93W 310.92 24.94 69.50 48.23 BPIHRMWD-PBD O3 T 3) I'- 0 \ Halliburton Energy Services - Drilling Systems PSL Proposal Report Date: 12/2~ wellOall~ ID: MPF-22 Wp3 Me. aau~edlncl Drift Sabsea TV~ Comae TOT A L t~*p,~ va-. t~.p~ t~atgth ~ec.t~la~ ~) (deg.) (,~.) (t~) (t~) (~) (n) GRID Coordinale~ Noalting Easthtg Ct@sure Vertical Build Walk DL$ Omc Expected Total Max Hot M'm Hot' Dir. V~nl D~'I. Dir. Section Ra~ Ra~e Dogleg Reclangula~ Co@ids Ea'or E~or Max Err Error (fl) (d~§.) (il) (dg/'{oof£) (dg/100fl) (dgyl00i't) (dcg) (Il) (f0 (it) (fi) (~8-) (it) Sm-vey 'fool END OF CURVE 10223.08 73.00 343.08 4867_24 4912.24 42.61 7396,04N 2776.94W '6042728.42 538944.74 7900,18~339.42 7896.92 0.0i START OF CURVE @ 200 deg/ioo fl 14011,94 73.00 343.0S 5975.00 6020.00 3788.86 10862.55N 3831.2~V 60'46189.08 537872.44 11518.41@340.57 11517,98 O. iX) 14111.94 7L00 343. i7 6005.90 6050.90 100.00 10953.55N 3858.9C*V 6046279.93 537844.36 11613.42@340.59 11613,02 -2.00 14211.94 69.00 343.25 6040.(F). 6085.09 100.00 11043.51N 3886.05W 6046369,74 537816.76' II707.28@340,61 11706,92 -ZOO 14311,94 67.00 343.34 6077.55 6122.55 IOO,OO 11132,32N 3912.7~V 6046458.40 537'/89.65 11799.90@340.63 11799,57 -ZOO 14411,94 65.01 343.43 6118.21 6163.21 100,00 11219.85N 39~.82W 6046545.80 537763.09 11891.15@340.66 11890.84 -2.00 145il.94 63.01 343.52 6162.03 6207.03 100,00 11306,02N 3964.3~/ 6046631.83 537737.08 11980'92@340.68 11980.65 -2.00 i4611.94 61.01 343.62 6208.96 6253.96 100.00 11390,72N 3989.31n# 6046716,38 53T/11.68 12069.11@340.70 12068.86 -2.00 i~Y/11.94 59,01 343.72 6258.94 6303.94 100.00 11473.83N 4013.71W 6046799,36 537686,90 12155.6~@340.72 12155.38 -2.00 14811.94 57.01 343.83 6311,91 6356.91 100.00 11555.26N 4037.41W 6046880.67 537662.79 12240.29~.-340.74 12240.09 -2.00 14911,94 55.02 343.94 6367,81 64iZ81 lO0.00 11634,92N 4060,4.'rW 604696039 537639.36 12323,08@340,76 12322,91 -2.00 15011.94 53.02 344.05 6426,56 6471,56 100.OO 11712.69N 4082.7&¥ 6047037.85 537616.66 12A03.87@340,78 12403.72 -2.00 15i11.94 51.02 344.17 6488,10 6533,10 100.00 11788.50N 4104.3:AV 6047113.54 537594.69 12482.56@ 340,80 12482.43 -2.OO 15211.94 49.02 344.30 6552.34 6597,34 I00.00 11862.24N 4125.14W 6047187.17 537573.49 12559.05@340.82 12558,93 -2,OO 15311.94 47.03 344,44 6619.22 6664,22 100.OO 11933_83N 4145.1%¥ 6047258.65 537553.10 12633.240340,85 12633.15 -2.00 154II.94 45,03 344.58 6688.65 6733,65 IO0,OO 12003.18N 4164,35W 6047327.89 537533.52 12705.060340.87 12704.98 -2.00 15511.94 43.03 3443,1 6760,54 6805,54 100.00 120qO.21N 418ZTL~W 6047394.81 537514.80 12q74.41@340,89 12774.35 -2.00 15580.2i 41.67 344.85 6811,00 6856.00 68.27 12114.59N 4194.84W 604743933 537502.51 12820,29@3'40.90 12820.24 -2.00. 15611.94 41.03 344.91 6834.82 6879.82 31.73 12134.82R 4200.31W 6047459.34 537496.94 i2841.20~340.91 128A'1.15 -2.00 END OF CURVE 15663,75 40.00 345.00 6874,20 69i9.20 51.81 12167.33N 4209,05W 6047491,79 537488.03 12874.78@340.92 12874.73 -ZOO TK'UD 15868.44 40.00 345.00 7031.00 3076,00 204.69 12294.41N 4243.1CW 6047618.69 537453.33 I3006.02@ 340.96 13006,00 0.00 0.00 0.0a 0.09 0.09 0.09 0.09 0,10 0.10 0.10 O. lt 0.12 0.12 I.OO 76.4 7396.04N 2776.94W 311,26 25.~ O~.51 48,$1 BPIIOIMWD-PBD 0.OO 76,4 10962,55N 3831.2~V 363.53 36.2~ '/0.23 78.46 BPI. HRMWD-PBD 2.OO 78,4 10953,55N 3858.9CW 365.39 37,41 '/0.25 78.95 BPI]tRIvlW~D 2.00 80.4 11043.51N 3886.0.q,V 367.24 38.62 70.28 79.38 BPE-IR,¥IWD-PI~D 2.OO 82.4 11132,32N 3912.7EW 369.08 39,90 70.30 79.77 BPII-I~-PBD 2,00 84.4 11219,85N 3938.87g/ 370.92 41,23 '/0.32 I~0.10 BP[HRMWD-PBD 2.OO 86.4 I 1~}6.02N 3964.3~/ 392,74 42.60 70,35 80,38 BPIHRMWD-PBD ZOO 88.4 { 1390.72N 3989.31'W 3'/4,54 44,0rZ 70,3'/ 80,61 BPIHRMWD-PBD ZOO 90.4 11473.83N 4013,71W 3'/6.33 45.46 '/0.39 80,79 BPIHRMWD-PBD 2.00 92,4 11555.26N 4037.41W 378,00 46.93 70.42 80.92 BPIHRMWD,-PBD ZOO 94,4 11634.60N 4061.52W 379.83 48,42 70.44 81.00 BPHM-PBD ZOO 96.4 IITIZOgN 4084.8~V 38134 49.91 70.46 81.03 BPI-IM-PBD 2,00 98.4 11787,62R 4107-41W 383.22 51,41 70.48 81.02 BPI-IM-PBD 0.{3 2,00 ' ioo,4 11861,11N 4129.14W 384.87 52.91 '/0.51 , 80,96 BPHM-PBD 0,14 ZOO 102.4 11932.46N 4lS0.01W 386.48 54.41 70.53 80,85 BPHM-PBD 0.15 0,16 0,17 0.17 0.18 0,00 2,OO 104.4 12001.59N 4170.02W 388,05 55.89 70,55 80.70 BPHM-PBD 2.OO 106.4 12068A2N 4189,13W 389,57 57.35 70.5'/ 80.51 BPHM-PBD 2.OO 107.8 12112-67N 4201.6C3V 39059 58.34 70.58 8037 BPHM-PBD ZOO 1ff8,4 1213Z85N 4207.3L~/~ 391.06 58.80 70.59 g0.Z9 BPH~i-PBD 2.00 I09.5 12165,27N 4216.4EW 391.82 59.53 70.60 80. i7 BPHld-?BD 0.00 109.5 12292.01N 4251.7,1W 394.81 60.46 70.65 81.14 BPHM-PBD rq o Fo F r Target (12/1/95) 16023.78 40.00 345.OO '/150.OO 7195.00 155.34 t2390.87N 4268.95W 6047715.OO 537427,00 i3105.63@M0.99 13105.6t TKUA3 16089.05 40.00 345.00 7200.00 7245.00 55.27 12431.39N 4279.1EW 6047755.47 537415.94 13147.48~, 341.00 i3147.47 16121.68 40.00 345.00 7225.00 7270.OO 32.63 12451.65N 4285.23W 6047T/5.70 537410.40 13i68.40@341.01 13168.40 .0.00 -0.00 0.00 0.00 0.00 0.00 0.OO 109.5 12388.20N 4278.5~V 397.11 61,1'/ '/0.68 81.88 BPI-IM-PBD 0.00 109.5 12428.61N 4289.8,~V 398.08 61.47 '/0.70 82.18 BPHIvI-PBD 0.00 109.5 12448,82N 4295,4'/W 398.57 61.62 70,70 82.34 BPHM-PBD CASING POINT OD =7 in, ID = 6.28 i~, Waigh! = 26.OO 16346.69 40.00 345.00 7397.36 7442.36 225.01 12391.36N 4322.67W 6~7915.20 5373?2.26 133i2.69@341.05 13312.69 16421.6g 40.00 345,00 7454.81 7499.81 74.99 IZ637.92N 4335.1~V 6047961,69 537359,55 13360.78@341.07 13360.78 0,00 0,00 0,00 0.00 0.00 1095 12591.36N 4322,679/ 0,00 0.00 0,00 0.OO BPHM-FBD 0. OO 109,5 12634.58N 4347.279/ 403.09 63.00 70.77 83.76 BPH~-PBD \ DEC 0~ '95 03:19PM ALASKa. HALLIBURTOM DRILLIM~ Halliburton Travellin~ Cylinder Report Cwnputfd u~ing WiN-CADDS 2~3/2.1.B P.13×E3 Page 4 Date: 12/2/95 Tlm~: 1:05 pm BPX-Sha~I Services Drilling Alaska State Plane: Zone4 Mi/~ Pt: MPF MPle-9.2 As-Buflt MPF-22 ~ WPFS COMPARISON WILL' Wetlpa~a: No Poha No.1 Slot : MPF-46 AS Built SWaC.r~: Milae Pt: MPF d,TVD, d-N/$ a~ a-E/W an: relive w th~ cmxmt l:Oha c~ th~ REFERENCE WELL Ali Directions uztng BP Highaiae, ~ in Dec,Deg, All positions ~ diata~es in Feet Ali po~ifiora are EXPE~ positions Ali d~stanc~ am SEPARATION Di~uumea Reference Well Compa~ Well Noami FLOW SHUT-IN TV'D MD N/$ E/W... PE { d-'rvo MD d-N/S d-E~V 1~ ! BP Safety Distance~ 50.00 50.00 0,OO 0.OO 0A 10O.00 loo.00 0,00 0.00 0.8 150.00 150.00 0,00 0,00 1.1 200.00 200.0O 0.OO 0,00 1,5 2~0,00 250.0O '0.0O 0.00 1,9 300,00 300.00 0.00 0.00 2,3 350.00 350,00 0.20 -0.08 2A · t9,98 450.OO 1.g2 -0,74 2.7 499.96 500,00 3.24 -1.3I 2.8 549.92 550,00 5.06 -2.04 3.0 599.86 600.00 7,28 -2,94 3.1 649.?8 650.00 I0,01 -4.04 3.3 699.65 .. 700.00 13,34 -~.39 3.5 749.46 ?50.00 17,28 -6.98 3.7 7~9.22 800.00 21.83 -8,82 3.9 848.91 850.00 26.98 -I0,90 4.1 898,53 .900.00 32.73 -13,22 4.3 948.04 950.00 39.18 -15,83 4.5 99%42 1000.00 -. 46.43 -18,76 4,7 10~6,66 1050.00 54.48 -22,01 a,9 1095,7,1 1100,00 63.33 -25.59 5.2 1144.65 1150,00 72.96 -29.48 5.4 1193.37 1200,00 $3,39 -33.69 5.6 1241,86 1250.OO 94.71 -38.26 5.9 ~290,07 1300.00 107.00 -43.23 6.2 1337,98 I350,00 120.26 -48.59 6.4 1385,56 1400o00 134.49 -54.~4 6.7 1,$32,80 1450.00 I49.68 -60.47 7.0 1479,67 1500.00 I65.82 -66.99 ?.3 1526.15. 1550,00 I82.90 -73.90 7.7 1572.22 1600,OO. 200,92 -81.18 &O ~617.85 1650.~0 219,87 -88o$3 8.4 1663.02 1700.0O 239.74 -96.86 g.7 1707,73 1750.00 260.49 -105.2~ 9. I 1'/9(;33 1850.00 302.~9 -122.2~. 9-9 0.01 4256 146.54 i04.85 0,8 -0.00 92,55 146.54 104.85 1.7 -0.00 1~Z55 146,53 104.81 2.0 -0.OO 192.55 I~6A9 104.63 2.0 -0.00 2A2.55 lg6.42 104,28 2.1 ,0.00 2.92.55 146,39 103,76 2.1 · 0,85 341.71 146.2~ 103,09 2.2 -1,70 390,87 145.86 102,27 2,2 -2~ 440.05 145A5 I01.17 23 ,3,36 489.9.2 144.5I 100,32 2.3 -4.17 538.40 143.2~ 99.57 2A -4,96 587,59 141.90 98.79 2,5 -6.11 636,40 140.15 97.90 2,6 -7.21 685,2a 138.02 96.94 2.7 -8.9.6 73~,11 135,70 95.94 2.8 -9.9.3 783.01 133,08 94.95 2.9 -10.11 831.96 130,0~ 94.06 3.0 -10.89 880.98 126,72 92.89 -11.96 929.69 123,04 91.21 3.4 -12.89 978.52 1~8,9~5 89.07 3.6 · 13.69 1027A3 114. a9 86,52 3.8 -14,31 1076.44 109.62 83,97 4,0 -14,7I 1125,54 104.35 81.62 4,2 -14,90 1174,73 98.78 79.43 -15,10 1223,75 92.83 77.43 4,8 ,I4,99 1272.94 86.48 75.38 5,1 -14,56 1322.31 79.75 73,12 5,4 · 13,92 I371.85 72.75 70,19 5,8 -13,03 I421.58 65.47 66.58 6,3 -11,68 1471.58 57.52 62.72 6,7 -9.80 1521,85 48.85 58.80 7,2 -7.25 1572,43 39.38 55.07 7.7 -4.08 1623.32 29,35 51.38 8.2 -0.48 1674A5 1~.1~ 47.52 8.8 3,60 1725.79 g.92 43.83 7.60 1776.98 -0.~/ ~0.$'/ 10.0 11.68 1828,16 -1036 3?.62 10.$ lg~l.,~ 1900.00 323.65 430.76 103'1 15-98 1879.42 4L16 34.89 IL1 1~5-92 1950,00 344,68 -139.32 10.7 19.93 1930.77 -~0,82 31.02 11.8 1930.].2 2000.00 366.2~ -148.31 11-1. 24..~ 1982.99 -39.7~ 25.76 1973.80 2050.00 388.74 -157.63 11,5 2016,94 21OO.OO 412.10 -167.29 12.I 2059,51 2150.00 436.1t4 -177.29 12.7 2101,50 2200,00 461.44 -187.62 1~.4 21a2,90 2250,00 487.39 -198.27 14.1 2183.67 23OO.00 514,17 -209.25 14.9 2223.79 2350.00 541.78 -220,,~i 15,8 2263.26 2400.00 570~.0 -232,15 16,7 2302.05 2450.00 599.41 -2.44.06 17.7 2~0, I5 2,500.00 629.41 -236. Z~ 18.8 2377,53 2550./)0 660.1~ -2e8.78 19.8 2414.17 2600./30 691.~0 -281.58 21.0 2a50,07 2650,OO 723.96 -204.66 22,2 2a8~,19 2700,00 756.94 -308.0~ 22.5 2519,.~1 2750,00 790.63 -321.65 24.7 2553,08 2800,00 82,5.01 -335.56 26.1 ~85.80 2850.00 8~,07 -349,71 27.4 2617.~9 2900.00 895,79 -364,12 28,9 264674 2950.00 9~2.14 -ST~.~ 30,3 26'78.92 30OO,00. 959,12 -393.67 2708.2~ 30~0,00 1006,7~ -408,79 33,3 2736.6~ $1OO.00 1044.~9 -~a, la 2754.1~ 3150.00 1083.64 -~39.70 35,5 2790.75 3200.00 1122.~ -455.48 38.1 2816,42 3250.00 1162.77 -471.45 $9.8 2841.14 3300,00 1203,11 -487,63 41.4 2864.91 2350.OO 12a3.9~ -503.98 2897.72 ~4OO.00 1285.28 -520.52 ~.9 2909.54 3450.OO 1327.05 -537.22. 46.6 2930,39 3500,00 1369.26 -554.09 48.4 2950.23 ~550,OO 1411.90 -571,11 50.2 29,02 2035.46 -48.69 19,83 13,4 33,97 2088.17 -57.71 1~.3~ 14,2 39,10 2141,16 -66.64 6.10 15,2 ~37 2194,40 -75-5~ -1.97 16.2 a9,72 22a7,91 -84.32 -10.91 17.3 55.04 2301.80 -93,16 -21.30 18.5 60.24 2356.15 -101.97 -33,37 I9,8 65,99 2410.85 -111.23 -45.86 21,1 72A3 2465.91 -121.08 -58.65 22.5 79,19 2521,45 -I31.20 -72.48 23.9 86,18 2577,39 -141.39 -87.17 25.5 93,30 2633,55 -151.41 -102.23 27.0 100.80 2690,19 -161,73 -118.21 28.7 108.65 27a7,al -172.38 -135.33 30.5 116.39 280~.06 482.90 -153.59 32.4 123.80 2863,0a -193.04 -172.87 34.4 I30.66 2921.23 -202.6a -192,95 36.5 137.35 2980.21 -212.55 -21a,91 38,8 ~43,85 3039.97 -29.:2.72 -238.73 al.2 I49.83 3099.93 ,232,40 -263,16 155.21 3159.77 -241.26 -287,5a 46.1 159.99 3219.40 -249.37 -311,61 44],7 164,53 3279.20 -257.35 -336.12 51.4 169,12 3339,75 -265,96 -362.16 54.2 173.77 3401,30 ,275,2a -390.27 57.1 177.62 ~462.81 -283.88 -a18,48 60,0 180,89 3524.53 -292.43 -447.25 63.1 lga,03 3586,93 -301.37 -477.38 66.3 187.55 36a9,69 -310.65 .508,08 69.5 191.91' 3712.50 -320,06 .538,57 72.6 197.36 3775.03 -32~.43 -568.19 75,8 179.02 0.75 0,13 I77.73 1.50 0,25 I76.99 Z9,3 0.38 I76Ad 3.0O 0..50 175.78 3,75 0.63 175.03 a,50 0.75 174.36 5,25 0.88 173,41 6.0O 1 172.25 6.75 1.12 170.79 7.50 1,25 169.15 8.25 1,~7 167,34 9.0O ] .50 165,16 9.75 1.62 162,63 10.50 1.75 159,91 11.25 1.87 156,95 12,00 2.00 153,71 12,75 2.12 150.0'2 13,50 2.25 1,~5.78 14,25 237 140.90 15,00 2.50 135.46 ! 5.75 2.62 129.68 16.50 2,75 123.66 17.25 2,87 117,49 18.00 3.00 111,15 18.75 3,12 104.44 19.50 3,25 97.28 20.9.5 3,37 89.47 21.00 3,50 80.96 21.75 3,62 71.83 22,50 3,75 62.19 23.25 :3.87 52,39 24.00 4.00 42.7] 24,75 4.12 33.73 25.50 4,25 26.40 26.25 4,37 il.Si 27.00 ~.$0 <~ 20,48 27,75 4.62 22.46 28,~0 a.75 ~ 25,60 29.~ 43'/~ 29.62 30,00 5.00 ~ 35.18 30.50 5,12 41.97 31.0O 5 49,70 31.50 5.37 58,07 32.OO 5.50 67,15 32.50 5.62 76.86 33,0O 5.75 87.50 33.50 5,87 99.42 34.OO 6.00 112.64 34.50 6.12 126,85 35.00 6.25 lal,82 35.50 6.37 15%08 36.00 6.50 173.33 36,50 6.62 190.63 37,00 6.75 208.57 37,50 6.87 226.68 38,00 %00 244.84- 38.50 7,12 264.35 39.00 7.25 285,28 39.50 7.37 3O6.29 40.0O %50 326.70 4O.5O 7,~2 34637 41.00 7.75 366,3d. 41,50 7.87 387.82 a2,00 8.00 411.37 a2,50 8,13 434.$0 43.0O 8.25 a57.90 43.50 8.38 482.(53 ~.00 8,50 508.26 44.50 8,63 534.17 45.00 8.75 559,78 45.50 8.88 DEC 88 'DS 03:80PM ALASKA HALLIBURTON DRILLING Halliburton Travelling Cy~der Re~ ~~ W~ C~eW~ No~ ~OWS~UT-~ ~ ~ NIS ~ PE I ~ ~ &N/S d-~ PE [ BPS~e~~ P.14/SB P~¢5 Da~;12C2/95 Tmn:l:OSpm 2969.07 ~600.00 1454,92 -588,28 52,1 2986.90 3650.00 1498.32 405,58 53,9 3003.70 3700.00 1542.08 -673.01 55,8 3019,47 3750.00 1586.17 -640.55 57,7 3034,28 3800.00 1630.56 -658.20 59,6 304&90 3850.00 16/5.01 -675.86 61,5 3063.52 3900.00 1719.45 -693,52 63,5 3078.14 3950.00 1763.90 -711.18 65A 3092.76 40~.00 1808.34 -728.8a 67,3 3107,38 4050.00 1852,98 2746.50 69.2 3121,99 aI00,OO 1897.23 -764..17 71.2 31:~6.6! 4150.00 19ai,67 -781,83 73.1 3151.23 4200.00 1986.12 -799,a9 75,0 3165,85 4250.00 2030.56 -817.15 76,9 3150.a7 a300,00 2075.01 -83431 ?8.9 3195.09 4350.00 2119A5 -852,47 80.8 3209.71 4400.00 2163,90 -870,13 82.7 322A.32 4450.00 9J~8,3,~ 48%80 84.6 39..38.94 4500.00 2252.79 -905,46 86.6 3253.56 4550.00 ~297.23 -9Z3,12 88.5 3268.18 4600.00 2~41.68 -940,78 90,4 3282,80 4650.00 2386.12 -958.4~ 92,3 3297.42 a700,00 2430,56 -976.10 94.3 3312.04 4750.00 2~75,01 -993,77 96.2 3326.65 4800.00 2519.,i5 *I011,4~5 98,1 3341.27 4850.00 2563.90-I029,09100,0 3:555,89 4900.00. 2608..'.'M -1046.75 102.0 3370.51 ~50,OO 2652,79 -1064.41 10~.9 3385.13 5000.00 2697.7.3-1082.07105,8 3399,75 5050.00 ' 2741.68 -1099.73107,7 3ala.37 5100,00 2786.12-1117.40109,7 202.93 3836.99 -338,03 .596,51 78.9 208.82 3898.57 -346,13 .623,83 82.0 215,63 3960.9..0 -354.20 -650,82 85,1 223,57 4022.16 -362.44 -677,96 88,2 231,80 4082.02 -372.11 -703,38 91,2 259.06 4138.02 -383.~1 -725,67 9L9 246.42 4194.14 -395.83 ,748,15 96.8 253.85 4250A3 .407.89 -770,98 99.6 261.49 4306.68 419.94 -795,62102,4 269,10 4362.95 -432.06 -816.3a 105,2 276.2a ~i19,35 .444.24 -839.59 108.1 28278 4475.8a. ,a56,38 -863.18111.0 28&77 453~34 468.~6 487,03113.9 29a,88 4589.10 -480.80 -911.37116,9 301.08 4646.16 -493.44 -936.30119.8 307.13 a703,53 -506,29 -961,89122.9 313.44 4761.10 -519,35, -987.76125.9 320.~7 4~18.79 -532,59 -1013,69128.9 327.68 4876.52 -5a5.97 -1039,48 131.8 335.33 49~4.30 -559,45 -1065.28 1~4.9 342.75 4-992.I7 -572.93 -1091,33 137.9 350,03 5049.88 -586.26 -ll17.1a I~0,9 357.26 5107,36 -599.38-1142.5214:~.8 364.57 516~.64 -612,33 -1167,45146.8 372.04 5221.76 -625.17 -1192.0I 149.7 379.75 5278.83 -6~8.01 -1216.34152,6 387,55 5335.96 -650,91 -12A0.77155,5 :59536 5393,09 -663,81 -1265.21 158.5 403.15 5450.04 -676.5a -1289,28 161.3 410.99 5506.90 -689.20'4313,1a164,2 a18.96 556:5.77 -'/01.88 -1336,9~ 167,1 3428.98 5150.00 2830.57 -1135.06111,6 I 427.46 5620.68 -714.66 -I360,59170,0 3443.60 5200.00 2875.01-1152.72113,5 ~58.22 5250.00 2919.46-1170.38115,a 3872.84 5300.OO 2963.90-1188.0~117,a 3a87A6 5350.00 3OO8.~4-1205.70119,3 3502,08 5400.00 3052.99-1223.36121.2 :5516,70 5450.00 3097.23-1241.03123.1 $531.3! 5.500.00 3141.68 .-1258.69 125.1 ~585,9~ 5550.00 3186.12-1276.35127.0 3560.55 5600,00 3230.57 -1294.01 128.9 3575.17 5650.00 3275.01 .1311,6'7130,8 3589.79 5700.00 3319.46-1329,35132,8 3604.41 5750.00 3363.90 -13,87,00 134,7 3619.03 5800.60 3408.35 -1368,66 136,6 3633.64 5850.00 3452.79-1382,32138,5 3648.26 5900.00 3497.24 -1399,98 la0,5 3662,88 5950.00 3541.68 -1417.641~2.a 3677,50 6000.00 3586.12-1435.30144.3 3692,12 6050,00 3630.57-I452.96146.2 T'/06,74 6100,00 3675.01-1470.63148.2 3721.36 6150,00 3719,46-1488.29150.1 3735.97 6200.00 3763.90-1505,95152,0 3750.59' 6250.00 3808.35 -1523.6l 153,9 3765,21 6na~,00 3852,79 -1541.~7 1~5.9 3779.83 6350,00 3897,24 -1558.95 157.8 3794.85 6WO0,O0 3941,65 -1576,60 159.7 ~$09.07 ' 6450,00 3986o13 -1594.26161.6 38~.69 6500.00 8030,57 -16!1,92 163,6 3838.30 6550.00 a075.02 -1629,58165,5 3862.92 6600.00 4119.46-1647.28167,a 3867.54 6650.00 4163.91-I 664.90169,3 3882.16 6700.00 4208.~5 -I682.561713 3896.78 6750.00 '4252.79 -1700.23 173.2 3911.40 6800.00 4297.24 -17t7.89 175.I 5926,02 6850,00 4341.68-1735.55177.1 3980.63 6900.00 4.386,13 -1753.21 179.0 3955.25 6950.00 a830,57 -1770.87 180.9 3969.87 7000.00 4475,02-1788,53182,8 3984.49 7050.00 4519,86-1806,20184,8 3999.11 7100.00 4563.91 -182~,86186,7 4013.73 7150.00 4608.35 -1841.52 188.6 4028,35 7200,00 4652.80-1859.18190.6 a082.96 7250,00 8697,24-1876,84192.$ 4057.58 7300.00 674L69-1898,50194.4 40?2.20 7350.00 4786.13-1912,16196A 4086.82 '/400.00 4~0.57 al01,,~ 7450,00 4875.02-1947.49200.2 4116.06 7500.00 6919A6-1965,15202,2 4130.68 9550.00 4963.91-198Z81204,1 4145.29 7600.00 5008.~5 -2000.47 206.1 4~59.91 7650.00 5052.80 -2018.I3 208,0 4174.$~ 77OO.OO $097.~ -2035.79 209.9 4159,15 7750.OO $14~.69 ,0,053.46211.9 ~a0~,7't 78OO,OO $1a~,Ia -2071.12~13.g 4218.39 7850.00 52~0.5~ -2088,78 215,7 4253,01 7900.00 5275.02 -2106.44217.7 4287,63 7950,00 5319.47.2124.i0219.6 4262.24 8000,00 5363,9I.214136221.5 4276.86 8050.00 5805,35-2159,83223,5 8291A8 8100.00 $452.80 -2177.09225.4 4306.10 8150.00 5aw/.2a-2198,75227,3 436.41 5677.57 -727.44-1385,98172.8 445.25 5734.14 -739.96 -1406,78 175,6 853.95 5790.78 ' -752.58 -1429.75 178,5 862,51 5847.78 -765.46-1453.57181,3 871,I0 5904.72 -7'/8.28 -1477.2611~,2 879,71 5961.49 -790.95 -1500.58187.0 ~88,12 6018,13 -803.47 -1523.71189.9 896,35 6078,7~ -815.99 -1546.87192.7 504.49 6131A6 ..828,55,1570.30 195.6 512.69 6188.25 -841.20 -1593,8~ 198,5 521.01 6245.15 454.02 -1617,58 201.4 529.37 6302,41 -867.13 -1642.01 208.3 537.77 6359.90 -880.44 -1666,90 207,2 546.11 6417.47 -89'3.86-1692,01210.2 553,62 6475.21 -907.29 -1717.78 213,3 560,21 6533.09 -920.70-1744.18216.4 566,32 6591,10 -934,12-1771.00219.5 57239 6689,16 ,947,56 -1797.93 222.5 578.75 6707,23 -961,06 -1824.77 225.6 555.24 6765.31 -978,58-1851.57228.7 591.79 6823.23 -987.94 -1878,07 251.7 598,30 6880.7I -1000.95 -1903.71 234.8 605.04 6938,19 -1014.03 -1929.28 257.8 612.0I 6995.85 -1027,27 -1955.11240.8 618.45 7053.31 -1040,26 -1980,74243.8 624.76 7110.59 -1053,03 ,2006,06 246.8 6~L44 7167.77 -I065.81 -2031,03 249.8 638.57 '/225.07 -1078.79 -2056,08 252,7 646,03 7282.54 -1091.95 -2081.35 255,7 653,11 7339.82 -1104.88 -2106.40 255.7 659,8a 7396.88-1117.52-2131.12261.6 666,80 7853,70 -i129.95 -2155.45 264.6 672,79 7510,36 -1142.20 -2179.47 267.5 678.95 7566,98 -1154,40 -2203.51 270.5 684.93 7673.59 -! 166,56 -2227,61 273.4 690.74 7680.2I -1178.71 -2251,78 276A 696.61 '/737.12 -1191.17 -2276,51 279A 700..59 7794.45 -1204.00 -2~02`05 287.A 708.48 7852.11 -1217.09 -2328.27285.5 71&28 7909,8~ -1230.18 -2354.67 288.5 719.87 7967.32 -128~,03 -2380.65 291.6 725.43 8024.42 -1255.50 -2405,87 294.6 730.96 8081.16 -1267.69 -2430.39 29'7,5 736,46 8137.81-1279.78-2454.72300.5 742,17 8194,46 -1291.92 -9.A78.97 303.4 748.33 8251.20 .130a,25 -250~,27 30~5.4 754.56 8308.07 -1316.68 -2527.79 309.3 760,81 8365.02 -1329.19 -2552.47 312.3 767,52 8422.00 -I341.80 -2577.05 315.2 774,47 8478,96 -I354.40 -2601.47 318.2 781,28 8535,79 -1366,88 -2625.?0 321.1 788j8 &~92,69 -1379,49 4649.95 ~24.0 '/95.g0 8649.67 -1392.21 -2674,25 327,0 803.16 8706.56 -1404.81 -2698.36329.9 810.61 8763,35 ,.1417,34 -2722.23 332.8 818.27 8820.07 -la29,85 -2745J~8 335,7 825.95 8876.77 -14~2.35 -2769A8 ~38,5 833.62 8933.4-2 -1454.78 -2792.98 2al.a 8&1.~6 8989,119 ,la67.05 -2816.00344.2 8492M 9046.20 -I479.2! -2~38.68 3a7J , 584.06 a6,00 9.00 6O7.46 a6,50 9.13 630.~ 47.0O 9,25 654.74 47.50 9,38 678.07 48.00 9.50 699.58 48.50 9.63 72I.~ ag,00 9.75 743.46 49.50 9,88 765.51 50.00 lO,O0 787,58 50.50 I0,13 809,98 51.00 10.~5 W3za5 51,50 lO J8 854.95 52.00 10,50 878.00 52.50 10,63 901,66 53.00 10.75 92,5,92 53.50 10.88 950.59 54,00 I1.00 975.54 5a,50 11.13 1000.60 55,00 11.25 1025.76 55,50 11.~8 1051.07 56.00 11,50 1076.08 56.50 11.63 1100,66 57.00 11.75 1124.80 5%50 11.88 1148.66 58.00 12.00 1172.40 58.50 12.13 1196.25 59.00 12.25 I220, Ia 59,50 12.~8 124~.63 60.00 12,50 1266.94 60.25 12,63 1290.27 60.50 12.75 1313.66 60.75 12.88 1336.98 61.00 ] 3,00 1359.67 61.25 13.13 1382.46 61.50 13.25 1406.04 61.75 I3.38 1429,51 62.00 13.50 la52.62 62.25 13.63 1475.44 62.50 13.75 I898,25 62,75 13.88 1521.24 63,00 14.00 1544.40 63.25 14,13 1567.80 63.50 la,25 1591.90 63.75 14.38 1616.47 64.00 14,.50 164I .23 64.25 18,63 1666.26 64.50 14.7:5 1691,58 64.75 14.88 1717,03 65,00 I5.00 1742.62 65,25 15.13 1768.25 65,50 15.25 1793.90 65,75 15,38 1819.27 66.00 15.50 1843,78 66.25 15.63 ] 868.32 66,50 15.75 1893.20 66,75 15,88 1917.67 67,00 I6.00 1941.77 67,25 16.12 1965.69 67.50 16,25 1989.89 67.75 16.37 2014,43 68.00 16.50 2038,58 68.25 16.62 2062,26 68,50 16.75 2085,48 68,75 16.87 210831 69,00 17.00 2131.08 69,25 17.12 2153.82 69.50 17,25 2176.56 69.75 1737 2199.90 70.00 17.50 2224.07 ?0.25 17.62 22a8.89 70.50 17.75 2273.$3 70,75 17.87 2298.30 71.00 18,00 2321.98 71.25 18,12 2344,96 71.50 18.25 2367,73 71.75 18.37 2390,52 72,00 18.50 2413.55 72.25 i 8.62 2836,82 72.50 18.75 2860,27 72.75 18.87 2483,81 73,00 I9.00 2507,28 73,25 19.12 :2530.50 73,50 19.25 qECE V D 2553.88 73.75]9,37 ~aska Oil & Gas Cons. Commission 2577.43 74-.00 19.50 Anchorage 2600.76 74.25 19.62 2623.90 74.50 19.75 2646.90 74.75 19,87 266936 ?5.00 20.00 2692,73 75.25 20.12 Z7i5.15 75.50 20.25 2737,31 75.75 20.37 DEC 02 '95 03:21PM ALASKS~' Rcrcrcnc~ Well /%,'D MD N/S ~ PB I 4-TVD HALLIBURTON DRILLIM~ IL~li, 'burton TraveJHng Cylinder Report Com~a~eWell No~al FLOW MD d-N/$ ~B/W l:'E I ~P $~f~ P. 15/23 ."agc 6 Da~e: 1~2J~5 Tim~: 1:05 pm 4320.79, 8200.00 5541.69 -2212, a1229,3 4335,34 8250.00' 5586.13 -9-230.072~I.2 ,~349,96 8~0,00 5630.58 -2247.73235.2 4364.57 8350.00 5675,02 ,2265.39235.1 4379.19 8400.00 5719.47 -2283.06237.0 4393.8:I 8450.00 5763.91 -2300.72239,0 4408.43 8500.00 580836 -2318,38 2a0,9 4423,05 8550.00 5852.80 a~37,67 8600.00 5897.25 ~2353.7024~,.8 4~52.29 8650.00 5941,69 -23'/1.36 246.7 4466.90 8700.00 5986,13 ,2389.02248.6 4481.52 8750.00 6030,58-2406.69250.6 4496.14, 8800.00 6075.02-2424.35252.5 4510.76 8850.00 6119.a7 -2442,011154.5 4525.38 8900.00 6163,91 -24,59.67256.4 4540.00' 8950.00 6208,36 -2477,;53 258.3 4554.69, 9000.00 6252.80 -2494.99260,3 4569.23 9010.00 t5297.25 -2512,66 262,2 4583,85 9100.00 6341.69 -2550.32264, I 4598,47 9150.00 6386.14 -2547.98266,l 4613,09 9200,0O 6430.58 -2565.64265.0 4627,71 9250,O0 6475.03 -2563.309..69.9 464.2.:53 9300.00 6519,47 -2600.96:271.9 4656.95 9350.00 6563.92 -2618,62273.$ 4671.56 9400.00 6608.:56 -26;56,29275,$ 4686.18 9450.00 6652.80-2653,95277.7 4700.80 9500.00 6697.25 -2671,61279,6 4715.42 9550.00 6741.69.-2689.27281,6 4730,04 9600,00 6786.14 -2706.93283.5 4744.66 9650.00 6830,58 -2724.59285.4 4759.~ 9700.00 6875.03 ,2742,25287,4 4773.89 9750.00 6919.47 -2759,92289,;5 4788,51 9800.00 6963.92 -2777.58 291,3 4795.82 9825.00 6986.I4 -2786.41292.2 857.07 910Z43-1491.25-2861,24349.9 86L60 9158.53-1503.16-2883.62352,7 871,96 9214,57 -1515.02 -2965.95 355.5 879.27 9270,79 -1527,01 -2928.66 358.4 886.51 9327.15 -I539,14 -2951.71361.3 893.62 9383.60 -1551.:53 -2975,03 364.2 900.62 9440.07-1563,52-2998,44367.0 907.61 9496.51 -1575.~ -3021.77 369.9 91,%98 9552.79 -1587.69 -3044.61 372,7 922,48 9608,94 -1599.63 -3067.11 375,6 929.79- 966~,97 -1611,43 -3089.45 378.4 F36.88 9721.0a -1623.27 -3111.91381.2 944.05 9777,19 ,1635.19 -3134.55 384.0 951.36 9833,36 .1647.14 -3157.18 386.9 958.79 9889,54 -1659,11 -3179.79389.7 966.21 9945.7:5 -1671,09 -3202.39 392.5 973.75 10O01.92 -1683,08 .3224.96 395.4 981.42 10058.13 -1695.10 -3247A9 398.2 989,02 10114.35 ,1707.11:-3270.95 401.0 99638 10170.58 -1719.20 -5292.75 403,9 1004,27 10227.04 -1731.49 -~315,82 406,7 1011.99 10283.70 -1743.96 -3339.30 409,6 1019.69 10340.52 -1756.60 -3365.15 412.5 1027.48 10397.49 -1769,:56.3387.25 415.4 10352,4 10454.46 -1782, l 0 .$al 1.38 418.4 1042.77 10511~,4. -1794,6:5 -3435.18 421.3 1050.9,0 10567.98 -1807. Ia -3458,98 424.2 1057.61 10624.84 -1819.80 1065,13 10682,11 -1832.81 -3507.85 430,1 1072.63 10739,6I -1845.98 -3533.15 433.1 1079.93 10796.99 -I859,06 -3558,31436.0 1087.23 10854.44 -1872.18 -3583,57439,0 1094,62 10911.91 -1885.30 -3608.67 1098,27 10940,56 -1891.80 -3621.37 aa$.5 2759.2,4 76.00 20,50 2780.93 76.25 20,62 2802,49 '76.50 20.75 2,g24,40 76.75 20.~7 2846.62 77,O0 21.00 2869.06 77,25 21.12 2891.54. 77,50 21.25 2913.95 77,75 21.37 2936.04 78.00 2I ,50 2957,81 78.25 21.62 2979,33 78.50 21.75 ~00o.94 78,75 21.87 3022,74 79.OO 22.0O 3044,55 79.25 22.19- 3066,~ 79.50 9~25 3058,~0 79,75 22.37 3110.11~ 80,00 22.50 :5132.07 80,25 22.62 3153.95 80,50 22,75 3175.96 80.75 22,$7 3198.40 81.00 23,00 3221.25 81.25 9-3.12 32~A8 81.50 23.25 3267.96 .81,75 23.3'/ 3291.50 82,00 23.50 ~314.59 ~2,25 23.62 3337.64 82.50 23,75 3360.95 82.75 23,87 3385,05 83.00 24.00 ~39,61 83.25 24.12 3433.97 8350 24.25 3458.44 83.75 24,37 3482.95 64.0o 2,L50 ~95,06 84.12 24.56 Halliburton Travelling Cylinder Report Coraput~d u,rtag ~42v. CADD$ RE$2.1.8 Pag~ 1 Date: 12,~J9 5 Time: 1./)3 pm Normal Plane Method BPX,$ha.md Sn-vice~ Drilling State Plane:. Zone4 ~-~ ~-B~lt ~-22 ~ wP~ ~D~~~m~~~ h~ S~ ~ ~0.~ ~) ~0.~ To ~.~ ~) D~ ~ BP ~ M~ ~ ~.D~. Wcll Safe:y ~ Clear Spread M'PF-37 Spe 144.9 MFF-78 G+M ~99,3 MIrP-77 Mwd 4264 MPF-?0 O~ ~8,2 ~2 ~ ~9~ ~F~I ~-I ~15.1 ~-53 ~ ~9.8 No P~m N ~1 G-I I78.0 1:54.9 406.8 429,5 290,1 361,8 2a6.? 317.0 257.9 259.1 lS,9 200,1 107.2 40.9 107.I 119,8 151.8 Close Approach Status Flo~ng ShuMn Safety Ssi'ay Dis~ Dist gO0 799 I2.0 2,0 6OO 600 9,0 1,5 250 250 3.7 0,6 1750 1708 26.3 a,a I000 997 15.0 2.5 la00 1386 21.0 ~.5 150 I50 2.2 0.4 650 6~0 9,8 1.6 650 650 9.8 1.6 lSS0 1797 27,~ 4,6 ~0 849 12,8 2,1 · 650 ~0 9.8 1.6 1050 ]Oa7 15.8 2.6 4OO 400 6,0 1,0 300 300 4.5 0.8 3(1) 300 4.5 0,8 OK OK OK OK OK OK OK OK OK OK OK OK OX OK WELL PERMIT CHECKLIST UNIT~ PROGRAM: exp [] de~redrll [] aery ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval~ . 13. Can permit be approved before 15-day wait ....... ENGINEERING REMARKS 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y ~ 18. CMT will cover all known productive horizons ..... ~~ 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved.~~ 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ 28. Work will occur without operation shutdown ....... O N 29. Is presence of H2S gas probable ............ O N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures 31. Data presented on potential overpressure zones ..... 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ......... 34. Contact name/phone for weekly progress reports .... [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: TAB ~'~- Comments/Instructions: HOW/ljb - A:~FORMS~heklist rev 11/95 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. .~e Subfile 2 is .type:, LI~ TAPE HEADER MILNE POINT I/NIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 6648.00 M. WORDEN J. GAFFANEY MPF-22 500292263200 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 17-APR-96 MWD RUN 2 M, HANIK J. GAFFANEY MWD RUN 3 M. HANIK J. GAFFANEY MWD RUN 4 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: M. HANIK J. GAFFANEY WELL CASING RECORD 6 13N 2802 Date ~_~~~~~ 45.85 12.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 20.000 112.0 3RD STRING 12.250 9.625 8841.0 PRODUCTION STRING 8.500 16070.0 REMARKS: MWD - DGR/EWR4/CNP/SLD. ALL DEPTHS ARE MEASURED BIT DEPTHS. MWD RUNS 1 & 2 WERE DIRECTIONAL WITH GAMMA RAY (DGR/ SGRC), & ELECTROMAGNETIC WAVE 4-PHASE RESISTIVITY (EWR4). MWD RUNS 3 & 4 WERE DIRECTIONAL WITH GAMMA RAY (DGR/ SGRC), ELECTROMAGNETIC WAVE 4-PHASE RESISTIVITY (EWR4), COMPENSATED NEUTRON POROSITY (CNP/SPSF), & STABILIZED LITHO-DENSITY (SLD/SBDC). ALL GAMMA RAY (DGR/SGRC) DATA WAS ACQUIRED WITH DUAL GAMMA RAY, GEIGER MUELLER TYPE DETECTORS. ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR LOGGING: HOLE SIZE: 8.5" MI/D FILTRATE SAL: 500 - 700 ppm MUD WEIGHT: 8.5 - 10.0 ppg FORM. WATE~ SAL: FLUID DENSITY: 14545 ppm 1.0 g/cc FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP NPHI RHOB $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 117.0 16025.0 110.0 16000.0 8816.0 16007.0 8870.0 16015.0 (WALS, 12-FEB-96) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 110.0 86.0 15064.5 15040.5 15135.0 15115.5 15296.0 15273.0 15519.0 15494.5 15607.0 15590.5 15889.0 15865.0 15894.5 15872.5 15904.0 15882.5 16014.0 16007.5 16076.5 16070.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 1 141.0 MWD 2 6234.0 MWD 3 8870.0 MWD 4 15707.0 $ REMARKS: MERGED MAIN PASS. ALL MWD CURVES WERE SHIFTED WITH GR. MERGE BASE 6234.0 8870.0 15707.0 16070.0 CN WN FN COUN STAT /??SHIFT. OUT $ : BP EXPLORATION (ALASKA) : MPF-22 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: FILE HEADER FILE NLIMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP NPHI RHOB $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH 117.0 110.0 8816.0 8870.0 BASELINE DEPTH GR 110.0 86.0 15064.5 15040.5 15135.0 15115.5 15296.0 15273.0 15519.0 15494.5 15607.0 15590.5 15889.0 15865.0 15894.5 15872.5 15904.0 15882.5 16014.0 16007.5 16076.5 16070.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: all bit runs merged. STOP DEPTH 16025.0 16000.0 16007.0 16015.0 (WALS, 12-FEB-96) EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 141.0 6234.0 2 6234.0 8870.0 3 8870.0 15707.0 4 15707.0 16070.0 MERGED MAIN PASS. ALL MWD CURVES WERE SHIFTED WITH GR. /? ?SHIFT. OUT $ CN : BP EXPLORATION WN : MPF-22 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: (ALASKA) Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 RHOB MWD 68 1 G/C3 4 8 DRHO MWD 68 1 G/C3 4 9 PEF MWD 68 1 BN/E 4 10 ROP MWD 68 1 FPHR 4 11 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 810 01 1 4 90 180 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 1523 Tape File Start Depth = 16077.000000 Tape File End Depth = 86.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 383797 datums Tape Subfile: 2 1636 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 93.0 EWR4 86.0 $ 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 6185.0 6179.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : 27-DEC-95 ISC 2.11 / MPDS 1.22 3.94 MEMORY 6234.0 141.0 6234.0 0 .1 75.2 TOOL NUMBER P0459CGR8 P0459CGR8 12.250 112.0 SPUD 9.20 60.0 8.5 300 10.5 3.200 2.001 3.200 4.500 60.0 99.0 60.0 60.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 1. $ : BP EXPLORATION (ALASKA) : MPF-22 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE~ 0) 998 BYTES * Total Data Records: 398 Tape File Start Depth = 6240.000000 Tape File End Depth = 86.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 98473 datums Tape Subfile: 3 463 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SEIMMARY VENDOR TOOL CODE START DEPTH GR 6187.0 EWR4 6179.0 $ 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 8820.0 8814.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 29-DEC-95 ISC 2.11 / MPDS 1.22 3.94 MEMORY 8870.0 6234.0 887O.0 0 71.1 74.0 TOOL NUMBER P0459CGR8 P0459CGR8 12.250 112.0 SPUD 9.60 54.0 9.0 1000 7.8 2.200 1.260 2.200 3.500 64.0 117.0 64.0 64.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 2. $ : BP EXPLORATION (ALASKA) : MPF-22 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 175 Tape File Start Depth = 8880.000000 Tape File End Depth = 6170.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 427166 datums Tape Subfile: 4 240 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8811.0 15645.0 EWR4 8782.0 15618.0 CNP 8792.0 15626.0 SLD 8846.0 15635.0 $ 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD LITHO-DENSITY DGR DUAL GAMMARAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 06-JAN-96 ISC 2.11 / MPDS 1.22 3.94 MEMORY 15707.0 8870.0 15707.0 0 31.6 74.0 TOOL NUMBER P0468CRNSLDG6 P0468CRNSLDG6 P0468CRNSLDG6 P0468CRNSLDG6 8.500 8841.0 LSND 9.20 43.0 9.0 400 7.0 1.600 .815 1.800 1,600 72.0 148.0 72.0 70.0 SANDSTONE 2.65 HOLE CORRECTION '(IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 3. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-22 : MILNE POINT : NORTH SLOPE : ALASKA 8.500 .0 0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 FCNT MWD 68 1 CPS 4 8 NCNT MWD 68 1 CPS 4 9 RHOB MWD 68 1 G/C3 4 10 DRHO MWD 68 1 G/C3 4 11 PEF MWD 68 1 BN/E 4 12 ROP MWD~ 68 1 FPHR 4 13 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 334 31 1 4 90 334 30 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 810 01 1 4 90 180 01 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 771 Tape File Start Depth = 15710.000000 Tape File End Depth = 8775.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 292668 datums Tape Subfile: 5 840 records... minimum record length:' Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 15639.0 EWR4 15612.0 CNP 15620.0 SLD 15629.0 $ 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 16019.0 15992.0 15999.0 16008.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD LITHO-DENSITY DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 09-JAN-96 ISC 2.11 / MPDS 1.22 3.94 MEMORY 16070.0 15707.0 16070.0 0 30.6 33.8 TOOL NUMBER P0468CRNSLDG6 P0468CRNSLDG6 P0468CRNSLDG6 P0468CRNSLDG6 8.500 8841.0 LSND 9.90 45.0 9.5 400 4.4 1.800 .780 2.300 2.000 65.0 158.0 65.0 68.0 SANDSTONE 2.65 HOLE CORRECTION ('IN) : 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 4. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-22 : MILNE POINT : NORTH SLOPE : ALASKA .0 0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 FCNT MWD 68 1 CPS 4 8 NCNT MWD 68 1 CPS 4 9 RHOB MWD 68 1 G/C3 4 10 DRHO MWD 68 1 G/C3 4 11 PEF MWD 68 1 BN/E 4 12 ROP MWD 68 1 FPHR 4 13 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 334 31 1 4 90 334 30 1 4 90 350 01 1 4 90 356 99 1 A 90 358 01 1 4 90 810 01 1 4 90 180 01 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 54 Tape File Start Depth = 16080.000000 Tape File End Depth = 15600.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 440621 datums Tape Subfile: 6 123 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 7 is type: LIS 96/ 4/ 7 01 **** REEL TRAILER **** 96/ 4/18 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 18 APR 96 1:25p Elapsed execution time = 10.66 seconds. SYSTEM RETURN CODE = 0 ! ' MPF 22 ~'~°~~ -~~/ PRUDHOE BAY ~' i MAR 33 1996 i¢ i ;r f ¢_' 1'2-- '... -~"; / ---;:'--.:-~-~ ........... ' ..... =- .." "q -' -./ ' ' I-' .:~:" '. i ~ ~ ~" · ' -- ~%-. ~ ' ~x:":' ':;" ::,;~ -~-'~- :.-:-: --;~' '*." ' :'--' ~ ' ' " "' ' : " " · "- '-;"' i . / ._ ..... .. , .... ...,, ._ .........-;-. .... ; ....... , ~X, . ~. , _ _ I, /. :,--., --....,. x M--.: :~-::::;--.-.:-_: .... . ...... - -.- - ,. , ~ 1-_ ~, i ] / ~ - .: . ,_--'_' : ~ ~-;,--:::).~:::u>c-:~.~*-;W:.r:;;::~-u?::.:'' ~'? '~ " :~: ','':'~' '.' . ~..~ .... .~- - ~:'1 Run !: ~, ..fy - 1998 MARKED Ln~ ~ Cased Hole 16004' i /~JI I i WESTERN i i ,:,,,t,, I I.~/a./ ATLAS Logging Services .~e Subfile 2 is type: IS TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPF-22 500292263200 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 28-FEB-96 6595.00 K. BRUNNER D. ROBERTSON 6 13N 10E 1897 2802 45.85 12.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9.625 8842.0 40.00 PRODUCTION STRING 7.000 16054.0 26.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ REMARKS: GR/CCL. GR GRCH 2 1 12-FEB-96 WALS ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH TIED INTO MARKS ON MARKED LINE. TOOK 3 PRESSURE READINGS TO DETERMINE FLUID GRADIENTS OFF BOTTOM. *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 WAS NOT DEPTH SHIFTED SINCE PASS 1 IS THE DEPTH REFERENCE FOR THIS WELL. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 14990.0 16000.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH $ ......... EQUIVALENT UNSHIFTED DEPTH ......... MAIN PASS. NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPF - 22 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F i Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod i GRCH GR 68 1 GAPI 4 4 30 995 99 1 * DATA RECORD (TYPE~ 0) 1022 BYTES * Total Data Records: 16 Tape File Start Depth = 14990.000000 Tape File End Depth = 16000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE ~RAIL~R **** LIS representation code decoding summary: Rep Code: 68 4043 datums Tape Subfile: 2 110 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes .. Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 14987.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ROL ROLLERS SBAR ROL PCM GR P/T CENT $ STOP DEPTH 16019.0 12-FEB-96 FSYS REV. J001 VER. 1.1 1901 12-FEB-96 16010.0 16008.0 15000.0 16004.0 2400.0 YES SINKER BAR ROLLERS PULSE CODE MODULATOR GAMMA RAY PRESSURE/TEMPERATURE CENTROLLER TOOL NUMBER 8250EA/8248EA 8220XA 8255XA 8257LA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 16054.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): WATER/DIESEL 0.00 0.0 -- 175.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: MAIN PASS. $ CN : BP EXPLORATION WN : MPF - 22 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE~ 64 ) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units 1 GR GR 68 1 2 CCL GR 68 1 3 SPD GR 68 1 4 TEN GR 68 1 GAPI API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 310 01 1 4 4 30 150 01 1 4 4 30 636 99 1 4 4 30 635 99 1 16 * DATA RECORD (TYPES 0) Total Data Records: 83 1006 BYTES * Tape File Start Depth = 14990.000000 Tape File End Depth = 16015.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20506 datums Tape Subfile: 3 160 records... Minimum record length: 26 bytes ~ximum record length: 1006 bytes £ape Subfile~4 ,is type: LIS 96/ 2/28 O1 **** REEL TRAILER **** 96/ 2/28 O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 28 FEB 96 4:54a Elapsed execution time = 10.98 seconds. SYSTEM RETURN CODE = 0