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185-017
STATE OF ALASKA RECEIVED ALIIA OIL AND GAS CONSERVATION COIVSION OCT 3 1 2017 REPORT OF SUNDRY WELL OPERATIONS 1.0 Operations AbandonAOGCC p U Plug Perforations LJ Fracture Stimulate LJ Pull Tubing Li Operations shutdown LI Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program El Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Tubing Replacement 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: A'un CI LI) Name: Hilcorp Alaska LLC Development ❑., Exploratory ❑ 185-017 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-21280-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047437 MILNE PT UNIT B-10 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured 9,470 feet Plugs measured 9,104 feet true vertical 7,251 feet Junk measured 9,060 feet 8,768,8,867& Effective Depth measured 9,291 feet Packer measured 9,081 feet 6,708,6,782& true vertical 7,109 feet true vertical 6,945 feet Casing Length Size MD TVD Burst Collapse Surface 107' 13-3/8" 107' 107' 1,730psi 740psi Intermediate 5,789' 9-5/8" 5,789' 4,653' 3,520psi 2,020psi Production 9,438' 7" 9,438' 7,166' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feetED .!AN 112_013 SCANN True Vertical depth See Schematic feet 2-7/8" 6.5/L-80/EUE 8,859' 6,776' Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2/L-80/IBT 9,106' 6,965' PHL Hyd.Set, Packers and SSSV(type,measured and true vertical depth) Brown HB&HPT N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 143 950 902 1,140 182 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development❑i Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-332 Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola@hilcorp.com Authorized Signature: /1\--7)01--- 4. a' ttokL. Dab 10/31/2017 Contact Phone: 777-8412 ii-/4 . 11 RBDiviSForm 10-404 Revised 4/2017 r4,7 t/a / - 2 2017 Submit Original Only • • Milne Point Unit Well: MP B-10 SCHEMATIC Last Completed: 10/03/2017 fiilcoru Alaska,LLC PTD: 185-017 Orig KB Elev.:59.0'/Orig GL Elev.:24.0' TREE&WELLHEAD RKB Elev=31.3'(Nabors 27E) Tree 3-1/8"5M FMC w/3-1/2"Otis Quick Union Wellhead 11"5M FMC w/3-1/2"H BPV Profile OPEN HOLE/CEMENT DETAIL 133/8" 9-5/8" 762 bbls Arctic Set III,106 bbls Class'G'in a 12-1/4"Hole 7" 72 bbls Class'G'in a 8-1/2"Hole 1 CASING DETAIL 2 Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/PELP 12.715 Surface 107' 0.1571 11 3 9-5/8" Surface 36/NK-55/BTC 8.921" Surface 5,789' 0.0773 7" Production 26/L-80/BTC 6.276" Surface 9,438' 0.0383 4 TUBING DETAIL 5 2-7/8" Tubing 6.5/L-80/EUE 2.441" Surf 8,859' 0.0058 3-1/2" Tubing 9.2/L-80/IBT 2.992" 8,860' 9,106' 0.0087 9-5/8 IL 1 0 WELL INCLINATION DETAIL KOP @ 500' 1 7 Max Angle is 49 deg.@ 5,600' JEWELRY DETAIL 8 No Depth Item 1 9 GLM DETAIL:CAMCO 3.5"KBUG 1 2,246' GLM STA 12:2.875"SPMO-1.0M TK-2 coating BK-2 latch(12/64"1,148#)set 10/17/17 10 2 3,138' GLM STA 11:2.875"SPMO-1.0M TK-2 coating BK-2 latch(Dummy Set 10/03/17) 3 3,997' GLM STA 10:2.875"SPMO-1.OM TK-2 coating BK-2 latch(12/64"1,142#)set 10/17/17 4 4,827' GLM STA 9:2.875"SPMO-1.OM TK-2 coating BK-2 latch(Dummy Set 10/03/17) 11 5 5,472' GLM STA 8:2.875"SPMO-1.0M TK-2 coating BK-2 latch(12/64"1,1334)set 10/17/17 T 6 6,175' GLM STA 7:2.875"SPMO-1.0M TK-2 coating BK-2 latch(16/64"OGLV)set 10/17/17 12 7 6,756' GLM STA 6:2.875"SPMO-1.OM TK-2 coating BK-2 latch(Dummy Set 10/03/17) Fill@ 8, 8 7,491' GLM STA 5:2.875"SPMO-1.0M TK-2 coating BK-2 latch(Dummy Set 10/03/17) 10/03/17\ r 13 9 8,042' GLM STA 4:2.875"SPMO-1.0M TK-2 coating BK-2 latch(Dummy Set 10/03/17) y 14 10 8,592' GLM STA 3:2.875"SPMO-1.0M TK-2 coating BK-2 latch(Dummy Set 10/03/17) 11 8,768' 7"x2-7/8.HES PHL Hydraulic Set Retrievable Packer(36k Shear) 4411141 15 12 8.810' 2-7/8"X Nipple(Min ID=2.313") Min ID2.813" i sem: 13 8,845' 4-1/4"Seal Assembly,13.52'(5.05"No-Go,seals removed)Spaced Out 4'High __ _ @8,905 14 8,849' HPT Polished Bore Receptacle(14.6'Long;4.0"ID) 16 it 15 8,867' Brown HB Retrievable Hydraulic Packer(2.89"ID) _ 16 8,905' Camco Selective W-1 Nipple(Min ID=2.813") 17 17 8,938' GLM STA 2:MMG-2 1-1/2"Gutted Circ Valves w/RKP Latch 18 18 8,979' GLM STA 1:MMG-2 1-1/2"Gutted Circ Valves w/RKP Latch 19 8,989' Blast Joints(3 ea) IF 20 9,094' External Casing Packer 19 KupaukC1 21 9,081' Brown HPT 2-B Wireline Set Permanent Packer KupaukB7 22 9,104' Camco D Nipple(Min ID=2.75")CA-2 Plug Set 6/24/94 ECP@ 23 9,105' HPJShear Sub-Bottom @9,106' 9,094' 24 9,194' External Casing Packer Cal Cleanout 20 to 9,073'CT ' "I r I 21 SYS s PERFORATION DETAIL Min ID2.7. @9,104' Top Btm Top Btm zz Zone (MD) (MD) (TVD) (TVD) FT Date Status Size ECP@ Kuparuk C1/B7 9,008' 9,054' 6,918' 6,954' 46 3/01/85 Open 5"12SPF 9,194' 23 els KuparukA3 9,282' 9,290' 7,102' 7,108' 8 3/01/85 Open 5"12SPF i t 24 xiitKuparukA3 GENERAL WELL INFO Fish @9,29d Underreama----17* FII @9,291' API:50-029-21280-00-00 arm w/carbide 2:::.1.::::.12:01,*—,---ELM 7/2s/y3 Initial Completion by Nabors 27E -3/03/1985 7 Recompleted by ASR 1—10/03/2017 TD=9,470(MD)/TD=7,280'(TVD) PBTD=9,360'(MD)/PBTD=7,193'(TVD) Created By:STP 10/18/17 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-10 ASR#1 50-029-21280-00-00 185-017 9/22/17 10/3/17 Daily Operations: 9/20/2017-Wednesday No activity to report. 9/21/2017-Thursday No activity to report. 9/22/2017 - Friday ASR Crew Travel to Milne Point Safety Meeting Review B-10 Sundry with ASR Crew,Tool Pusher, Company Man, Mark O'Malley, Well Head Reps, Safety Well kill Operation with LRS, on B-10, Roads and Pads, Hauling ASR Rig and equipment To B-10. Pump 350bbIs of 10.5ppg brine, 150bbls away before seeing returns. 89bbls returned after pumping 350bbIs. Diesel still seen in fluid returns.TBG and IA on a vacuum when pump shut down. Utilize vac truck to pull 150bbls 10.5ppg brine from upright tank and continue circulation until clean brine seen on IA. Circulate 80bbls of 10.5ppg brine the long way. 14bbls needed to get returns to surface, 43bbls total returned after 80bbls away. 10.2ppg fluid seen in returns. Shut down and monitor TBG and IA.TBG on a vac, IA slightly blowing (U-tubing). Open IA to flowback tank and allow pressure to bleed off.Well Dead. R/D circulation manifold. Wellhead rep Mike Gilroy w/ FMC on location to set BPV. Bleed control line and hanger void, remove horse shoe scaffolding, spot mud boat into position, cover cellar area w/ herculite. Prep to remove tree and adapter. Set Doghouse and Company Rep trailer in position on location. Spot Tool Push trailer in position on location. Well support on location to set VR plug on IA. Roads and Pads on location w/Crane. N/D production tree and adapter. N/U BOPE w/riser and bell nipple. Spot well house and rig floor into position over B-10 well.Torque all bolts on BOPE. Back rig carrier into position on mud boat. Warm up hydraulic system, raise mast into working position. Spot mud pits into position on location. R/U fluid system lines. L/D herculite containment and set catwalk and pipe racks in position on containment. R/U hydraulic lines from accumulator system and function test rams. Call wellhead rep Mike Gilroy from FMC to pull BPV and set TWC. Update AOGCC rep Bob Noble of BOPE shell test between 6-7am. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-10 ASR#1 50-029-21280-00-00 185-017 9/22/17 10/3/17 Daily Operations 9/23/2017 -Saturday Service Rig Check Fluids Grease Well Head Rep Mike Gilroy on Location Remove BPV Pumped 10 bbl. 10.5 ppg. Install TWC Valve in Hanger Profile Install Cap String sheave in Derrick, Grease Chock manifold Valves and Manual and HCR Vales on Bop stack, Fill Bop stack, Electrician Brandon Rig up and Calibrated fire and gas Alarms in pits, Cellar, Rig Floor, Pump tested Alarms (AOGCC Bob Noble on Location Witness Bop test 9-23-17 at 0800hrs.) Rig up Test Equipment, Shell Test bop 250/ 2,500psi 5 min Each Chase low bleed off,TWC Valve Leaking, Made up landing joint screwed into Hanger closed pipe rams Bring pressure up to 2,700psi ( Good Solid Test on Rig Equipment and Hanger Seals) Break out lay down landing joint, Rig up on the IA Pump 10 bbl. down the Annuals, Well Support Larry, Rig up Lubricator Extension make up in Hanger Remove Leaking TWC Valve, Pumped 20 bbl. Down TBG,Tee Bar Installed new TWC Valve in Hanger Profile,Tighten LDS and Packing Gland Nuts on Well head Rig up Test Equipment Test bop as per sundry,Test with 2-7/8 and 3-1/2 Test Joints all Rams and Valves 250 low/2,500 high 5 min each,Test Annular with 2-7/8 test joint I-BOP and TIW Valves 250 low/2,500 high 5 Min Each, Record Accumulator Pre-Charge Pressures and Chart Test, (AOGCC Bob Noble on Location Witness Bop Test on 9-23- 17 at 730am) Make up Lubricator Extension up in Hanger,Well Support Larry Lubricate and Remove TWC Valve from hanger profile, Lay down Same M/U landing joint and 3.5" handing equipment. Wellhead Rep Mike Gilroy on location to BOLDS (4-3/4" LDS= Full Out). M/U 3.5" EUE pin x 2-7/8" EUE box to 2-7/8" EUE pin x 2-7/8" IF Box and M/U to landing joint. M/U crossovers and landing joint to TBG hanger(12.5 turns to M/U). M/U power swivel to landing joint.Attempt to pull 3.5" 9.3ppf L-80 TBG f/wellbore. Hanger unseated @ 70klbs, weight indicator continues to climb up to 140kIbs. No indication of seal bore assembly pulling free. Release tension from TBG and work overpull up to 160kIbs. Not able to pull pipe free.Work pipe between 100-160kIbs in an attempt to work pipe free. R/U to pump down TBG while working pipe to try and pressure assist the seal bore assembly to release. Pump @ 4BPM w/600psi while working pipe between 100- 160kIbs. Unable to free pipe. R/U to pump down IA and try to hydraulic pipe out of hole. Unable to effectively hydraulic pipe since pipe stretch @ 160klbs places TBG hanger at annular element on BOPE. Contact Ops Engineer and discuss plan forward. Decision to call out E-line and perform TBG cut as opposed to rigging up CSG jacks to pull pipe further. New 3.5" 9.3ppf TBG rated to 207kIbs, caliper shows TBG is in poor condition. Would rather cut pipe than part pipe by pulling. Contact Pollard E-line and SLB E-line. Neither have crews on slope, but Pollard could be at location by noon 9/24/17 w/ chem cutter BHA. Continue to work pipe f/ 100-160kIbs. Rig crews inventory BOPE from Knight Oil Tools, update rig inventory, and clean rig. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-10 ASR#1 50-029-21280-00-00 185-017 9/22/17 10/3/17 Daily Operations: 9/24/2017-Sunday Service Rig Check Fluids and Grease Continue to work pipe f/ 100-160k Rig crews inventory BOPE from Knight Oil Tools, update rig inventory,Continue Organizing and cleaning rig. Break out 40'. landing Joint, Make up 2-10'. Pups Joints make up into Hanger, Change out Bottle neck elevators to Slip type Elevators, Continue to work pipe f/ 100-160k Rig crews inventory BOPE from Knight Oil Tools, update rig inventory, Continue Organizing and cleaning rig. Pulled up on Hanger to 87k set Slips, Rig up Pollard E-Line Services, Make up BHA Weight Bars, CCL, Chemical Cutter( OD 2.625), RIH Correlate Chemical Cutter Depth Continue to log completion assembly in order to pick chem cutter firing depth. Set down with BHA @ 8,990'md P/U 20'md and repeat tag depth. No issues picking up from tag. Send logs to ops engineer and discuss cut location. Decide on cutting mid joint above PBR assembly @ 8,827'md. Set cutting BHA on depth and fire chem cutter. Pipe movement in the slips as well as movement in E-line unit giving good indication of cut. POOH w/ E-line chem cutter BHA f/ 8,827'md to surface. L/D E-line BHA and inspect for any indicators that would create an issue with the cut. Chem cutter appears to have gone off properly. L/D Eline sheave, latch up to 3-1/2" EUE landing pups, attempt to POOH w/completion. P/U to 160klbs, rig unable to pull any more. Notice two small pops as we initially pull tension into completion, but unable to identify any TBG movement beyond tubing stretch. Work pipe several time f/ 100k-160klbs with no pipe movement down hole. Line up and pump down IA w/TBG closed in. Hydraulic pipe 10klbs in addition to 160klbs. R/U and RIH w/ E-line CCL log BHA to log across cut depth and look for indications of pipe movement. Log interval and clearly see cut mark at 8827'md, but no sign of pipe movement when comparing spacing between jewelry.Able to easily drift through cut location w/2.125" CCL BHA, no indications of pipe separation. Contact Ops engineer and discuss plan forward. POOH w/CCL BHA. POOH w/CCL BHA, Pollard E-line redress chemical cutter. Latch up to landing pup joints and work pipe between 80-160klbs repeatedly until E-line BHA is ready to RIH. P/U to 87KIbs and set landing pups in slips to provide tension while cutting. M/U E-line Chem Cutter BHA as per Pollard E-line rep. RIH w/ E-line chem cutter BHA f/surface to 8,900'md. Perform tie in pass and verify no issues getting 2.65" OD cutter assembly through the cut section. No obstruction seen, after working through cut several times. Pull up to 8820'md with CCL which put chem cutter @ 8832'md and fire chem cutter. Good indication of cutter firing, (unit shake/pipe shake). Log up and down across 2nd cut. No issues passing through cut depth. POOH w/ Eline chem cutter#2 f/8,832'md. L/D E-line chem cutter BHA, latch up elevators to landing pups and attempt to pull TBG. Work weight up to 160klbs with no pipe movement. Pipe not stretching any further after 2nd cut than it did after the first cut when pulling 160klbs. Work pipe f/80-160klbs to attempt to free the stuck completion. Pollard headed back to Prudhoe to get free point tool and string shot. 1 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-10 ASR#1 50-029-21280-00-00 185-017 9/22/17 10/3/17 Daily Operations: 9/25/2017 - Monday Service Rig Check Fluids and Grease Break out landing Joint, Nipple down Spacer Spools,ASRC Crane Assisted in Hoisting Casing Jacks to Rig Floor Work Pipe from 150k to 185k Several Times with Casing Jacks, Contact Ops engineer and discuss plan forward, Re land Tubing Hanger, Rig up Pollard E-Line and Free Point Tight Spot, Drifted Goose Neck on Swivel (ID 2.375) Saver Sub ( ID 2' ) Pulled up on Tubing set in Slips at 75k Rigged up Pollard E-Line Make up BHA Weight Bars and Free Point Tool, ( Max OD 1.68) Springs ( OD 4-1/8) RIH to 5,000'. Pulled up on Tubing to 95k, Set Tubing Back down in slips to 75k,Correlate Tool (Tubing is Free) Continued RIH to 6,000'. Pulled up on Tubing to 95k Set Tubing Back down in slips to 75k Correlate Tool (Tubing is Free) Continued RIH to 6,500'. Pulled up on Tubing to 95k Set Tubing Back down in slips to 75k Correlate Tool (Tubing is Free) Continued RIH to 6,810'. Unable to get through ( Gas Lift Manual No' 7') Pulled up on Tubing to 95k Correlate Tools Through Gas Lift Manual, Set Tubing Back down in slips to 75k Continued RIH to 7,434'. ( Gas lift Manual No' 8') Unable to get Past Tight Spot with Tools, Work tubing f/ 105k to 75k Able to Pass through Tight Spot at 7,434'. Continued RIH to 7,850'. Pulled up on Tubing to 95k, Set Tubing Back down in slips to 75k Correlate Tool (Tubing is Free) Continued RIH to 7,875'. Unable to Pass through Wire Line Depth of 7,875', Pooh Changed out Wire Line BHA Added 451bs weight Bar, and Down sized Springs (OD 4') Continued RIH to 8,225'. Pulled up on Tubing to 95k, Set Tubing Back down in slips to 75k Correlate Tool (Tubing is Free) Continued RIH to 8,5,00'. Pulled up on Tubing to 95k, Set Tubing Back down in slips to 75k Correlate Tool (Tubing is Free ) Continue to work free point indicator tool down hole showing signs of pipe movement. Free point indicator showing signs of restricted pipe movement, but unable to hone in on the exact location of sticking point. Contact Ops Engineer and discuss plan forward. Decision made to verify deepest depth of unrestricted pipe w/free point tool. P/U to 7,850'md (previously seen free pipe location, prior to any signs of pipe restriction) perform free point stretch test by pulling pipe to—73klbs applying 20klbs overpull up to 93klbs and recording the deflection on the FPI gauge. Gauge showing full deflection indicating no pipe restriction. POOH w/ FPI tool and L/D at surface. Prior to POOH it was noted on the CCL log, when crossing chemical cut depth (8,827'md), that there were indications of 2' of pipe separation at the cut depth. E-line operator also had issues working logging tools across the cut zone, indicating tools were catching in potential cut area. Once OOH w/ E-line BHA, work pipe from 100kIbs to 185klbs utilizing casing jacks in an attempt to free pipe. Casing jacks not functioning in sequence with each other, adjust regulating valves until smooth actuation is created. Continue to work pipe f/ 100kIbs to 185klbs. (No success getting pipe to move up hole). M/U Pollard E-line hole punch BHA to punch holes in TBG prior to making RCT cut. RIH w/ E-line TBG punch BHA. Evaluate PDS caliper log f/06/17/17 and decide which joint would be most appropriate to cut around 7,850'md. Choose joint 248 @ 7,796'md due to it's low metal loss and reduced pitting in comparison to other completion pipe around that depth. Correlate E-line TBG punch depth by locating GLM #2 on CCL and pulling up to jnt#248. Punch holes roughly mid way through joint 248 (7,796'md) in order to leave 16' of fishable 3.5" TBG stump once RTC cut is performed. POOH w/ E- line TBG punch BHA. L/D E-line TBG punch BHA and M/U RCT BHA as per Pollard E-line. RIH w/ RCT f/surface to 7,796'md. Locate GLM #2 as a down hole marker,tie in E-line CCL log and P/U to cut depth. Pull landing pups to 80klbs to put string in tension at cut point. Fire RCT making cut @ 7796'md and verify pipe is cut by picking up with the elevators and watching for weight indicator to level off(Pipe is Free). P/U weight= 62klbs S/0 weight= 35klbs POOH w/ Pollard E-line RCT BHA and L/D. R/D Pollard E-line and prep to POOH w/3.5" 9.3ppf, IBT completion. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-10 ASR#1 50-029-21280-00-00 185-017 9/22/17 10/3/17 Daily Operations: 1 9/26/2017-Tuesday Service Rig Check Fluids and Grease Pull Hanger to the Rig Floor at 62k, Break and lay down Landing Joint, Layed down Tubing Hanger on a Full Joint, No pup Joints Installed under Tubing Hanger our GLM's during Original Completion, Changed out Control Line spooler unit Tooh lay down 3-1/2 IBT tubing, Spool up Control line f/Surface to 1,896'. 60 Joints to SSSV, Continued Tooh to 5,100'. Pipe is showing signs of Scale build up in Areas Between Joints 60 to 75 Depths 1,865'. to 2,333'. Sent in a Sample to Clyde with Baker for analyses Continue to POOH w/3.5" 9.3ppf, IBT completion pipe f/JNT 173 (-5100) to JNT 247 (7780'md). Recovered 1 SSSV, 8 GLM's, 247jnts, and 15.29' cut joint (3.5" OD, no flare) No sign of TBG punch holes on cut JNT. Load and strap Weatherford Fishing Overshot BHA(Series 150 overshot, bumper sub, oil jars, (6)4-3/4" collars, accelerator,x-over), load and strap additional 20jnts of 3.5" work string for a total of 192 joints on the pipe rack. M/U Weatherford Fishing BHA as per fishing rep. RIH w/Weatherford Fishing Overshot BHA# 1 on 3.5" NC-31 work string f/224.49'md to 5,000'md. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-10 ASR#1 50-029-21280-00-00 185-017 9/22/17 10/3/17 Daily Operations: 9/27/2017 -Wednesday Service Rig Check Fluids grease RIH w/Weatherford Fishing Overshot BHA# 1 on 3.5" NC-31 work string f/5,000"to 7,645' Work warm up Function Casing Jacks 20 Times, Continued RIH Tag TOF 6' in on Joint 190(DPM @ 7,796') Swallowed 5' of Fish to 7,801' Worked Jars in 10 k increments f/ 150k to 200k made 30' hole to 7,771' Layed down jt. 190 Pipe stop Moving up Stuck Solid Unable to Pull up.(Total Jar Hits 12) P/U=75K D/N=44K Make up Joint 190 Stacked weight on worked String Work pipe down to 7,801 Reciprocate and work Pipe up/Down 30'f/7,801 to 7,771' About 10 Times, Pulled up worked Fish Free Increase of Weight on Hook 15k Total weight 90k Pooh w/Weatherford Fishing Overshot BHA# 1 on 3.5" NC-31 work string f/7,801'to Surface Lay down Fishing BHA No 1' (6)4-3/4" Drill Collars Bumper sub and Jars Over Shot Pooh lay down 3-1/2" Old Completion Tubing From Cut Joint at 7,796'to 8,007' Continue to POOH w/completion Fish on Weatherford series 150 overshot BHA. Recover 32 full joints of 3.5" 9.3ppf IBT TBG, 2 GLM assemblies, and two cut joints, the upper cut joint which was engaged to the overshot= —13'md and the lower cut joint from the bottom of the fish = 9.69'. Discuss plan forward with Ops Engineer. Decision made to P/U fishing overshot as opposed to CSG scraper BHA. Contact Baker Fishing. Baker fishing assemble series 150 overshot w/ mill control, basket grapple, and add 9' of barrel above the grapple to allow us to swallow the 5' of cut TBG in the hole and engage the TBG stump for the seal assembly. Load and strap overshot, M/U BHA consisting of series 150 overshot w/9' extension, bumper sub, oil jar, (6) 4-3/4" drill collars, and accelerator RIH w/ Baker Fishing overshot BHA f/229'md to 3,600'md. Floor hands notice well is no longer on a vacuum and is starting to show returns with each joint ran in the hole. Shut down and monitor well bore. Fluid level in well bore rising slightly on its own. Stab the TIW, close our pipe rams, open HCR choke and monitor for flow back to pits. After "15mins slight drip seen coming out of choke manifold valve# 14. Shut choke valve# 10 and monitor pressure. Pressure slowly rising. Calculate bullhead volume to fill work string and IA w/ 10.5ppg KWF. Line up to bullhead down work sting. Pump 2.5bbls w/TBG pressure rising to 3,000psi. Shut down pump and monitor. No pressure bleed off after 5mins. Manually bleed off pressure from TBG and line up to bullhead KWF down the IA. Pump 1.5bbls and IA pressure increases to 2,000psi.Shut down and bleed off pressure from IA. Monitor IA pressure, rise to 15psi. Discuss plan to circulate KWF down TBG taking returns out the choke, through choke valve#12 and out to the flow back tank. Continue to monitor well bore pressure on the IA, pressure rose to 30psi. Wait on crews to change out before before beginning pumping operations. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-10 ASR#1 50-029-21280-00-00 185-017 9/22/17 10/3/17 Daily Operations: 9/28/2017 -Thursday Service Rig Check Fluids Grease Circulate KWF down Tubing, at 3,600'Take returns out the choke, through choke valve#12 and out to the flow back tank Circulated 60 bbl. out to the Take Fluid Cleaned up and Getting 10.5 ppg Brine Back, Changed Valves over to Pits Circulated total 150 bbl. Monitor Well bore ( No Flow Well is Dead) Open Pipe Rams Continued RIH w/ Baker Fishing overshot BHA f/3,600'to 8,798'Joint 214 Swivel up on Joint 215 Break Circulation P/R=3/340psi &4/640psi P/U/W=89K D/N/W=47K Set down (ASR DPM)TOF @ 8,828'. Swallowed 8' and stacked 25k on top of fish to 8,836' over pull 31k Pulled up to 140k set Jars off with Casing Jacks reset jars, Pulled up to 150k set jars off with casing jacks, Pulled up to 150k with Carrier, Pulled Free, (Total jar Hits=2) after laying down 1 jt. did not see any extra weight Tooh lay down 3- 1/2" work string 9.3ppf 1/8,838' to 1,734' Continue to POOH w/ Baker overshot BHA on 3.5" 9.3ppf work string to top of BHA at 229'md L/D BHA up to final drill collar. (BHA consists of Baker 150 series overshot, bumper sub, oil jars, 6 drill collars, accelerator, and crossover to 3.5" work string) Flow seen coming from annulus,followed by flow coming through the BHA. Closed annular element and stab TIW valve.Annular element began to leak due to spiral drill collar being across the annular element. P/U joint of 3.5" drill pipe, un-stab TIW and cross over, stab joint of drill pipe, strip joint of drill pipe down across the pipe rams and and close the pipe rams. Stab TIW and crossover onto joint of drill pipe. Monitor well for pressure. Pressure climbing f/ 10psi to 460psi. Bleed pressure off of the annulus back to the flow back tank. Circulate 15bbls down the TBG and up the IA out to the flowback tank, checking fluid returns weight. 10.3ppg fluid to start, followed by 10.4ppg fluid. Shut down and monitor well. IA pressure continues to rise f/10psi to 300psi. Bleed pressure off the IA back to flow back tank. Line up to bullhead down the IA to test for injectivity. Pump 4bbls away and pressure system up to 1,600psi. Drill pipe starting to hydraulic in the pipe rams. Shut down pump, bleed off pressure, and monitor well. Pressure continues to rise from 5psi to 30psi after bleeding off and shutting in again. Continue to monitor well and bleed pressure as necessary. Well showing signs of pressure bleeding off. No fluid flow seen on TBG or IA. Open pipe rams and TIW. L/D joint of drill pipe, the last drill collar, oil jars, bumper sub, overshot BHA^ 16' of fish including the seal assembly. Close blind rams and monitor well. R/U to test BOPE as per Sundry and AOGCC requirement. • • II Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-10 ASR#1 50-029-21280-00-00 185-017 9/22/17 10/3/17 Daily Operations: , 9/29/2017- Friday Service Rig Check Fluids and Grease Clear and Clean Rig Floor, Cellar Area, Nipple down Casing Jacks,ASRC Crane Assisted in Hoisting and Removing Casing Jacks, Hoisted Spacer Spools onto Rig Floor, Weighing up Pit Volume from a 10.3 ppg to 10.7 ppg Total of 160 bbl. Make up Mule shoe on 3-1/2" work string 9.3ppf Trip in the hole with 220 Joints Tagged Fill at 8,800' (ASR DPM) Wash down to 8,850' Circulate 10.7ppg fluid surface to surface through mud gas separator, taking returns to pits. Begin circulation pumping @ 4bpm w/ 1000psi. Gas cut fluids seen coming back from IA. Continue to circulate one full surface to surface volume of fluids from the pits (310bbls). Shut down pumps. Line up pumps to take fluid from upright tank, circulate the long way, taking returns to the flow back tank. Pump 360bbls from the upright tank down hole @ 4bpm = 1,100psi. 10.6ppg (heavy)fluid seen in returns from the IA. No losses seen during circulation. Shut down pumps and allow any remaining pressure on the well to bleed off.TBG and IA are stable, no pressure gain seen. R/U to test BOPE as per Sundry. Utilize test plug to hang work string off of prior to testing BOPE. M/U test plug to work string, cross over pipe handling equipment from 3.5"to 4.5". P/U and M/U 4.5" IBT landing joint and M/U to 4-1/2" IF crossover. Stab cross over in the top of test plug and M/U 4.5 turns. RIH w/test plug, utilizing the 5 foot stick to ensure we land the test plug @ ASR RKB 18.1'from rotary table. Land test plug, P/U/W=88K D/N/W=44K fill BOPE w/test fluid, and test BOPE as per Sundry to 250psi low f/5 charted min, 2,500psi high for 5 charted mins w/3.5" and 2-7/8" test joints. AOGCC Rep Jeff Jones waived witness to testing @ 4:05pm 9/28/17 9/30/2017-Saturday Service Rig Check Fluids and Grease Made up landing Joint RIH make up into Test Plug, Pulled up to 150k 20 Times Unable to pull free, Pressure up on the IA to 500psi 7' 26#Casing Pulled and worked 150k 20 Times, Engineer was Notified R/U Casing Jacks on Spacer Spools, Pulled 185k unset Test Plug Re landed and Unset Test Plug 3 Times, R/D Casing Jacks, Pull test Plug to rig Floor Break out lay down Landing Joint and Test Plug Make up Landing Joint RIH Make up into test Plug, Pull to Rig Floor Break and Lay Down Landing Joint and Test Plug Pooh Lay down 3-1/2" 9.3ppf Work String and Mule Shoe F/ 8,800'to Surface M/U acid job BHA consisting of seal assembly, pump out sub and 7" 26#CSG scraper. Notice pump out sub shear seat has been removed and there is no hard bottom in the sub to divert flow out of the ports. Contact Ops Engineer and make decision to L/D 3.5" NC-31 work string w/2" ID and P/U our old 3.5" RTS-8 work string w/2.92" ID along with a new pump out sub set to shear open at 2,300psi. Remove new work string from pipe rack and place in pipe tubs. SIMOPS, break down acid job BHA and remove sheared pump out sub. Move 7" CSG scraper below the pump out sub due to the 3.5" Reg connections having an ID less than 1.875" which is smaller than the pump out sub shear dart. Load RTS- 8 work string at Texaco Pad and deliver to B-10. Rig Crews clean rig and perform maintenance. M/U acid job BHA consisting of seal bore assembly, 7" 26#CSG scraper, and pump out sub and RIH on RTS-8 work string down to "2,400'md (JNT 82) • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number _ Well Permit Number Start Date End Date MP B-10 ASR#1 50-029-21280-00-00 185-017 9/22/17 10/3/17 Daily Operations. 10/1/2017-Sunday Service Rig Check Fluids and Grease Continue RIH on 3-1/2" 9.3ppf RTS-8 work string down to f/2,400' to 8,833' (joint 296)P/U/W= 76K D/N/W=34K P/U Joint 297 Tag 17' in Stack &set 25k down on No-Go (ASR DPM)@ 8,850' worked pipe 4 time Stacked out same spot Drop ball & Rod waited 15 min, Held Safety Meeting with Rig Crew, LRS,Schlumberger, NES Truck Driver, Pump and shear POS at .25 BPM, with 2,180psi Confirm Circulation to Pits(Good) Mix 40 bbl. flow-vis sweep with a Vis=46 Pill in pit 1' LRS P/T Lines to 3,000psi, Pumped 20 bbl. Flow-vis Sweep, Swap over to schlumberger Acid Truck Pump 30 bbl. 12%Acid, Chase with 20 bbl. Flow-vis Sweep, Displaced with 58 bbl. 10.7 Brine, P/R of 3.5 BPM @ 850psi, Shut down on Pumps let Acid Soak Letting Acid soak in the BTM of well bore Above the PBR f/8,850ft to 7,750'for 1/2 Hour Circulate Acid & Flow-Vis Sweeps with a P/R of 4 BPM @ 680psi Back to Surface,Total of 151 bbl. First sweep Arrived, Swap Valves to Flow back Tank Circulate with Clean Returns to Surface, un sting from the PBR Circulate Monitor well Bore checking for Losses our Gains well is Static Continue to circulate well bore until returns clean up. Circulate a total of 1,125bbls(-3.6x Bottoms Up) w/a 20bbl high visc sweep (60 funnel visc) @ 660bbls away taking high visc returns to the flow back tank once seen at surface. Shut down pumps and R/U to POOH w/Acid pumping BHA f/8850'md. Allow well to bleed off any remaining pressure. R/D kelly hose and chicksan on TBG stump. Fill hole until returns seen at shaker. 7lbbls to begin with prior to POOH. POOH w/Acid pumping BHA f/8,850'md to—3,000'md. Fill hole every 15 joints to verify fluid level and track metal displacement on trip sheet. Hole taking fill 1 for 1. No losses to report. 10/2/2017- Monday Service Rig Check Fluids and Grease Pooh w/Acid BHA f/3000'to Surface, Fill hole every 15 joints to verify fluid level and track metal displacement on trip sheet. Hole taking fill 1 for 1. No losses to report. Break and Lay down Acid BHA 7' 26# Casing Scraper and Seal Assembly POS Load and Tally 285 joints 2-7/8" 6.5# L-80 EUE Tubing, Strap BHA, Well Kill Ops on I- 15 RIH with 7' Halliburton PHL Completion PKR on 2-7/8 6.5# L-80 EUE Tubing,f/surface to jnt 275 (8,773'md). P/U = 47klbs, S/O= 27klbs. P/U jnts 276, 277, 278.Tag up 12' into jnt 278 (8,846.6'). Set down 15klbs to get 14' into jnt 278. L/D jnt 278 and P/U 2 -10' pups. RIH w/pups down to 8848.6' and w/ 15klbs set on completion. R/U to circulate down TBG taking returns to the pits via the flow line. P/U completion until neutral weight (47klbs) is seen, and then P/U an additional 12' and to ensure the seal bore is out of the PBR. Roll pumps @ 1BPM = 100psi, and slowly RIH to 8,846.6'md, pressure increase f/ 100psi to 125psi.S/D 15klbs pressure = 210psi P/U to neutral weight(47klbs) and then an additional 4'md for space out and begin rigging up Halliburton SL. R/U Halliburton SL and M/U BHA to retrieve RHC seat. RIH w/ Halliburton SL and retrieve RHC seat @ 8,809'SLMD (8,814' DP MD), M/U drift BHA(2.25" OD) and RIH.Tag up at 8,862'md SLMD. Beat down to 8,864'md prior to POOH. At surface bailer full of sand/scale/sludge. M/U BHA and RIH w/ RHC seat to be set back in X nipple @ 8,814'md, set and POOH. 10/3/2017-Tuesday • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-10 ASR#1 50-029-21280-00-00 185-017 9/22/17 10/3/17 Daily Operations: R/D Halliburton SL Services P/U 10 Pup Joint RIH Stack out on Seal Assembly No-Go Confirm Space Out L/D 2-10 Pups P/U Landing Joint make up on Tubing Hanger(ASR Rig RKB 18.10) P/U/W=45K D/N/W=27K RIH Land Hanger RILDS Break out Landing Joint L/D Drop ball & Rod Open IA Valve Pressure up Slowly on Tubing at 2,400psi Packer set Continued Pressure up to 4,000psi Hold for 30 charted Minutes Bleed Tubing down to 1,000psi Pressure up on IA to 2,000psi 30 charted Minutes, (Tested Good Both sides) Bleed Pressure off Both Sides to Pits Well Rep tee Bar Install BPV in Hanger( Release Rig at 10:00 hrs. on 10-3-17) (Nipple down Tree & Nipple up 11' Bop stack on 1-15) Blow down all Lines to Flow Back Tank, Circulate Fresh water Through out all the Service Lines and Bop Stack, Test Pump to the Flow Back Tank, Hoisted Hand up on Carrier to Crown Section Un spool both Tugger Lines to the Rig Floor Spooling back up on Reel Inspecting Both Tugger lines,for breaks Kinks, Frayed Line, (Notice one Tugger line is Frayed) Needs to be Replaced Remove pipe racks, disconnect Hydraulic lines from Accumulator to Bop Stack, Remove cat walk, Nipple down bop flanges to four Bolts, Rig down Floor, Remove Stairs, Blow down all Service lines and Disconnect, un pin Top Section and Lower Derrick onto Carrier, Hilcorp Electricians Disconnected Fire and Gas Alarms on Rig Floor, Cellar, Pits, Move Rig to 1-15 ASRC Crane hoisted mud Boat, Rig Floor, Well House on Trailer, Assisted in Nipple down Bop stack and Load on Trailer, Hoisted Tree in Place, Nipple up Tree, Test Hanger Void to 5,000psi, Fill Tree with Diesel Test new tree 5,000psi 15 Charted min with Well Support ASR Weekly Safety Meeting. Rib i6col70 Regg, James B (DOA) From: Cody Rymut - (C) <crymut@hilcorp.com> Sent: Friday, September 29, 2017 7:56 AM ���� l0I Z I i _j To: DOA AOGCC Prudhoe Bay Cc: Stan Porhola; Bo York; Craig Smith - (C) Subject: RE: B-10 Well Shut In Sequence Of Events# 2 Attachments: B-10 Well Shut In Sequence Of Events#2.docx Let's try this again. Attached is the B-10 sequence of events for our well shut in last night, prior to getting out of the hole with our fishing BHA. Please feel free to contact myself or Craig Smith with any questions. Craig is currently working days and I am working nights. Craig Smith: (0) 907-685-1266 Cody Rymut WSM, ASR#1 Hilcorp, Alaska C: 907-230-3594 ; F,r?, ;) ' crymutc hilcorp.com • 1 • • MPU B-10 Well Shut In Sequence of Events # 2 Date: 9/28/17 Time of BOPE Use: Annular Element was closed at 9:45pm and the 2-7/8" x 5" VBR was closed at 10:00pm. Well: B-10 Location: Milne Point Unit PTD Number: 185-017 / Rig Name: ASR # 1 Operator Contact: Craig Smith (6am-pm) (0) 907-685-1266 (C) 208-816-6803 Cody Rymut (6pm- am) (C) 907-230-3594 Operations Summary: ASR # 1 rig crew was pulling out of hole with an overshot fishing assembly after engaging a —20'md fish and jarring the fish free from a depth of—8850'md. At about 9:45pm the crew had made it out of the hole with the drill pipe and was in the process of laying down the BHA assembly when fluid was observed flowing out of the top of the annular element. The well was shut in utilizing the annular element and stabbing a TIW valve. A joint of drill pipe was then picked up, the TIW was removed, and the joint of drill_pipe was made up to the top of the drill collar and stripped in the hole through the annular element. When the joint of drill pipe made it to floor level the TIW was stabbed again, the 2-7/8" x 5" VBR's were shut, and the choke manifold was closed at valve 10 which is the first valve downstream of the choke. At this point it was about 10pm and the well had been completely secured. The thought process was that the kick was a result of trapped gas which was released when the fish was pulled free. Pressures were observed and bled off back to the flow back tank to verify the well was not underbalanced and flowing. After several bleeds and observing a diminishing trend, the wellbore pressure fell off and showed no further signs of flow. The well was opened up and the remaining BHA was removed from the hole. Note: BOPE was tested for well B-10 on 9/23/17 Ca? 17:00hrs. P7.I 165011 o Regg, James B (DOA) From: Cody Rymut - (C) <crymut@hilcorp.com> Sent: Thursday, September 28, 2017 7:18 AM o j To: DOA AOGCC Prudhoe Bay t� 1 ��Z t 7 Cc: Stan Porhola; Bo York; Craig Smith - (C) Subject: MPU B-10 BOPE Shut In Sequence Of Events Attachments: B-10 Well Shut In Sequence Of Events.docx Attached is the B-10 sequence of events for our well shut in this morning. Please feel free to contact myself or Craig Smith with any questions. Craig is currently working days and I am working nights. Craig Smith: (0) 907-685-1266 Cody Rymut WSM, ASR#1 Hilcorp, Alaska C: 907-230-3594 crymut@hilcorp.com 1 • • MPU B-10 Well Shut In Sequence of Events Date: 9/28/17 Time of BOPE Use: 2-7/8" x 5"VBR was closed at 3:30am,well was observed and finally shut in completely at 3:45am to monitor pressures. Well: B-10 ✓ Location: Milne Point Unit PTD Number: 185-017 / Rig Name: ASR# 1 Operator Contact: Craig Smith (6am-pm) (0) 907-685-1266 (C) 208-816-6803 Cody Rymut(6pm-am) (C) 907-230-3594 Operations Summary: On the morning of 9/28/17 at approximately 3:30am the ASR# 1 rig crew was tripping in hole with an overshot BHA on a 3.5" work string.The rig crew had just completed jarring out a —1030' piece of completion that was stuck in the hole @ 7796'md and was now heading back into the well to fish the remaining TBG section and seal assembly @ 8827'md with their overshot BHA.While tripping in hole the rig crew noticed the fluid level began to rise in the wellbore as they tripped in hole. This was a change for them because the wellbore had been on a vacuum since the well kill roughly 6 days prior.The rig crew shut down to monitor the well.They noticed a very small rise in fluid level once they stopped tripping pipe.The crew stabbed their TIW, closed their 2-7/8" x 5" VBR rams and opened their HCR choke to an open super choke back to the pits and observed for flow.After roughly 15mins a TP dr-Fp was seen in the pits, indicating the well was out of balance.The well was then shut in and the IA pressure was monitored.The well was completely shut in at roughly 3:45am. A bullhead kill was attempted by pumping down the TBG, but the wellbore pressured up to 3000psi after 2.5bbls away. Rig crew then lined up to attempt a kill down the IA and the well bore pressured up to 2000psi after 1.5bbls pumped.This indicated that the remaining TBG or perforations had become packed off during jarring operations when retrieving the prior fish.The plan forward is to circulate KWF surface to surface down the TBG taking returns out our choke to our flow back tank, until we see 10.5ppg fluid in our returns. We will then shut down and monitor the well. Note: BOPE was tested for well B-10 on 9/23/17 Ca) 17:00hrs. STATE OF ALASKA - AllikA OIL AND GAS CONSERVATION COAOSSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Plug Perforations U Fracture Stimulate LJ Pull Tubing LJ Operations shutdown Li Performed: Suspend El Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well El Other:Tubing Patch Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: At*,,....r-r: Name: Hilcorp Alaska LLC Development ❑., Exploratory ❑ 185-017 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-21280-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047437 MILNE PT UNIT B-10 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured 9,470 feet Plugs measured 9,104 RECEIVED true vertical 7,280 feet Junk measured 9,060 Effective Depth measured 9,291 feet Packer measured 8,867&9,081 feet O C!7 0 2 2017 true vertical 7,109 feet true vertical 6,782&6,945 feet,& AOGCC Casing Length Size MD TVD Burst Collapse Surface 107' 13-3/8" 107' 107' 1,730psi 740psi Intermediate 5,789' 9-5/8" 5,789' 4,653' 3,520psi 2,020psi Production 9,438' 7" 9,438' 7,166' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2/L-80/IBT 9,106' 6,965' 1,896'MD Packers and SSSV(type,measured and true vertical depth) Brown HB&HPT Camco TRPD-1A-SSA See Above 1,831'TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A pp pp,�� Treatment descriptions including volumes used and final pressure: N/A SCANNED DECDE1 4 2Q 17, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory El Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-394 Srfl Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: O7rperations Manager Contact Email: sporhola@hilcorp.com Authorized Signature: Dab 9/28/2017 - Contact Phone: 777-8412 7' 1c-„2y-/11 "A /07A4,1 RBDMS L' OCT 3 2017 Form 10-404 Revised 4/2017 Submit Original Only • Milne Point Unit 14 Well: MP B-10 SCHEMATIC Last Completed: 3/03/1985 flacon)Alaska,LLC PTD: 185-017 OrigKBElev.:59.0'/OrigGLElev.:24.0' TREE&WELLHEAD RKBElev=31.3' Nabors Tree 3-1/8"5M FMC w/3-1/2"Otis Quick Union d ,i,,% k Wellhead 11"5M FMC w/3-1/2"H BPV Profile i 1.. OPEN HOLE/CEMENT DETAIL 13-3/8" i:.•,,• ;• rt 9-5/8" 762 bbls Arctic Set III,106 bbls Class'G'in a 12-1/4"Hole Min ID2812' 7" 72 bbls Class'G'in a 8-1/2"Hole @ 1 ' 1 c` i,«' CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 2• 13-3/8" Conductor 48/H-40/PELP 12.715 Surface 107' 0.1571 11 9-5/8" Surface 36/NK-55/BTC 8.921" Surface 5,789' 0.0773 3 7" Production 26/L-80/BTC 6.276" Surface 9,438' 0.0383 TUBING DETAIL 4 3-1/2" Tubing 9.2/L-80/IBT 2.992" Surf 9,106' 0.0087 al WELL INCLINATION DETAIL i S KOP@500' 6 '.r Max Angle is 49 deg.@ 5,600' Iti Nr 9-5/8"Nu II k JEWELRY DETAIL 7 No Depth Item 1 1,896' CAMCO TRPD-1A-SSA SCSSV(Min ID=2.812") 8 GLM DETAIL:CAMCO 3.5" KBUG 2 3,192' GLM STA 12:3.5"35 Deg Dummy Valve BK Latch Set 7/09/17 9 3 3,103' GLM STA 11:3.5"43 Deg Dummy Valve BK Latch Set 8/02/09 Hole in Tubing ""1.-- G 4 3,946' GLM STA 10:3.5"46 Deg Dummy Valve BK Latch Set 7/09/17 @8,230' 10 / ` n 5 4,795' GLM STA 9:3.5"45 Deg Dummy Valve BK Latch Set 3/12/11 /© ,e 6 5,456' GLM STA 8:3.5"49 Deg Dummy Valve BK Latch Set 7/09/17 11 1i' 7 6,119' GLM STA 7:3.5"49 Deg Dummy Valve BK Latch Set 8/02/09 i._Ia'`y (4-44)- 8 6,806' GLM STA 6:3.5"47 Deg Dummy Valve BK Latch Set 7/09/17 T J 9 7,434' GLM STA 5:3.5"46 Deg Dummy Valve BK Latch Set 8/03/09 12 10 8,092' GLM STA 4:3.5"46 Deg Dummy Valve BK Latch Set 7/09/17 4. - 13 11 8,718' GLM STA 3:3.5"42 Deg Dummy Valve BK Latch Set 7/09/17 12 8.845' HPT Locator Seal Assembly(10.06'Long) i 13 8,849' HPT Polished Bore Receptacle(14.6'Long;4.0"ID) Min ID 2.813" iii ` 14 14 8,867 Brown HB Retrievable Hydraulic Packer(2.89"ID) @8,905' 15 8,905' Camco Selective W-1 Nipple(Min ID=2.813") l ;•Iq 15 ': 16 8,938' GLM STA 2:MMG-2 1-1/2"Gutted Circ Valves w/RKP Latch k` 4 17 8,979' GLM STA 1:MMG-2 1-1/2"Gutted Circ Valves w/RKP Latch gM 16 18 8,989' Blast Joints(3 ea) Ft ',.z 19 9,094' External Casing Packer Fill @ µ 1720 9,081' Brown HPT 2-B Wireline Set Permanent Packer 9,040'S11/14§ 21 9,104' Camco D Nipple(Min ID=2.75")CA-2 Plug Set 6/24/94 7/21/1218 ' Kuparuk Cl 22 9,105' HPJ Shear Sub-Bottom @ 9,106' 7 23 9,194' External Casing Packer Kupauk 67 ECP@ 0 1 PERFORATION DETAIL "94 ''''Ig ki 19 Top Btm Top Btm o, , i , Zone FT Date Status Size 20 (MD) (MD) (TVD) (TVD) Min ID2.75"4' ........2i ._ Kuparuk Cl/B7 9,008' 9,054' 6,918' 6,954' 46 3/01/85 Open 5"12SPF @9'10 �y 4 r" Kuparuk A3 9,282' 9,290' 7,102' 7,108' 8 3/01/85 Open 5"12SPF T-1..; i21 4 , ico. if RGENERAL WELL INFO ECP @ • API:50-029-21280-00-00 9,194' i' `� 23 Initial Completion by Nabors 27E -3/03/1985 Kuparuk A3 Fish @9,294 *1 LlnderrearerFill @ arm AIcabide i M1 9291'ELM 74Y 7/29/93 TD=9,470(MD)/TD=7,280'(TVD) PBTD=9,360'(MD)/PBTD=7,193'(TVD) Revised By:TDF 9/28/17 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-10 E-Line 50-029-21280-00-00 185-017 9/2/17 9/18/17 Daily Operations: 8/30/2017 -Wednesday No activity to report. 8/31/2017 -Thursday No activity to report. 9/1/2017- Friday No activity to report. 9/2/2017-Saturday MIRU E-line. Pressure test lubricator to 3,000 psi Hi/250 psi Low (good test). MU 3.5" Paragon Packer and setting tool. RIH and correlate log on depth. Set packer at 8,244'.Tag packer on depth. POOH. RD E-line. 9/3/2017-Sunday MIRU Slickline. Pressure test lubricator to 3,000 psi Hi/250 psi Low (good test). MU 3.5" Paragon Packer, spacer pipe, latch and setting tool. RIH and stab latch into lower packer. Set upper packer at 8,223'. POOH. RD Slickline.Turn well over to production. 9/4/2017- Monday No activity to report. 9/5/2017 -Tuesday No activity to report. • • +! Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-10 E-Line 50-029-21280-00-00 185-017 9/2/17 9/18/17 Daily Operations: 9/13/2017 -Wednesday No activity to report. 9/14/2017 -Thursday No activity to report. 9/15/2017 - Friday No activity to report. 9/16/2017-Saturday No activity to report. 9/17/2017-Sunday MIRU Slickline. Pressure test lubricator to 3,500 psi Hi/250 psi Low (good test). RIH w/ pulling tool and latch into 3.5" Paragon Packer, spacer pipe, and latch. POOH. Full recovery. RD Slickline. SDFN. 9/18/2017- Monday MIRU Slickline. Pressure test lubricator to 2,500 psi Hi/250 psi Low (good test). RIH w/pulling tool and latch into 3.5" Paragon Packer. POOH. Full recovery. RIH w/ 1.75" bailer. Tag 9,006' MD. POOH. Recovered hard sand. RIH to 9,000' MD and made static survey. POOH. RIH and pull dummy valve from Sta #3 at 8,731' MD. POOH. RD Slickline.Turn well over to production. 9/19/2017-Tuesday No activity to report. 276-(0 \2 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Hilrsirp Al.•toka_1,t,C RECEIVED Fax: 907 777-8510 E-mail: doudean@hilcorp.com SEP 21 2017 DATE 09/20/2017 AOGCC DATA LOGGED 9/25/2017 M.K.BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPB-10 scANNED FEB 2 7 2.018 Prints: CCL\Packer Setting Record CD's I HILCORP MPB-il_ PACKEn 02-SSE 17 rINAL 0's`2017 1:09 DV F e folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: • v °FT8 g*�\�\� /7/. THE STATE �� i� Alaska Oil and Gas y °f T e Conservation Commission Ll l Wiz__ r 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SCANNED AUG ? 1 Hilcorp Alaska, LLC 2 ~� 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU B-10 Permit to Drill Number: 185-017 Sundry Number: 317-394 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, A2CM Hollis S. French Chair 'r DATED this-Z- ' day of August, 2017. RBDMS (v AUG 2 3 2017 RECEIVED STATE OF ALASKA AUG 7 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate El Repair Well 21 Operations shutdown ElSus end ❑ Perforate El Other Stimulate ❑ Pull Tubing El Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing El Other: Tubing Patch 2 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ • 185-017. 3.Address: 3800 Centerpoint Dr,Suite 14006.API Number: Stratigraphic ElService ❑ Anchorage Alaska 99503 50-029-21280-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D• Will planned perforations require a spacing exception? Yes ❑ No El ✓ MILNE PT UNIT B-10. 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047437 . MILNE POINT/KUPARUK RIVER OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,470' . 7,280' . 9,291'. • 7,109' 2,904 9,104' Casing Length Size 9,060' MD TVD Burst Collapse Surface 107' 13-3/8" 107' 107' 1,730psi 740psi Intermediate 5,789' 9-5/8" 5,789' 4,653' p 3,520psi 2,020psi Production p 9,438' 7" 9,438' 7,166' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: TubingGrade: p Tubing MD(ft): See Schematic ( See Schematic 3-1/2" 9.2/L-80/IBT 9,106' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Brown HB Pkr/Brown HPT Pkr/Camco TRPD-1A-SSA • 8,867'MD/6,782'TVD;9,081'MD/6,945'TVD;1,896'MD/1,831'TVD 12.Attachments: Proposal Summary Q Wellbore schematic El 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: 8/30/2017 OIL El . WINJ El WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG El Commission Representative: GINJ ❑ Op Shutdown El Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name. Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola(C7hilcorp.com Contact Phone: 777-8412 Authorized Signature: Date: 8/17/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3k-7- 3y1-( Plug Integrity ❑ BOP Test El Mechanical Integrity Test ❑ Location Clearance El Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Wr Subsequent Form Required: ic) RBDMS 1,,L'AUu 1 3 2017 APPROVED BY p ✓� Approved by: COMMISSIONER THE COMMISSION Date: `� 7-3 1 i /14 sill$/ 7- , 0+-gs7 A ,,,,, s„ ,,, coc, ,z,3„ I Form 10-403 Revised 4/2017 ® RploG Itis valid for 12 months from the date of a Submit Form and ` approval. Attachments in Duplicate • • Well Prognosis Well: MPU B-10 Ililcarp Alaska,LL Date:8/16/2017 Well Name: MPU B-10 API Number: 50-029-21280-00 Current Status: SI Oil Well [Gaslift] Pad: B-Pad Estimated Start Date: August 31St, 2017 Rig: Wireline Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 185-017 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1752709 Job Te: r YP _ � _ � Tubir3g Patch Current Bottom Hole Pressure: 3,604 psi @ 7,000' TVD (SBHPS 7/25/2017/9.90 ppg EMW) Maximum Expected BHP: 3,604 psi @ 7,000' TVD (No new perfs being added) / MPSP: 2,904 psi (0.1 psi/ft gas gradient) Brief Well Summary: The Milne Point B-10 well was drilled as a Kuparuk development well with Nabors 27E in March 1985. The well was initially completed with 2 packers to isolate the lower Kuparuk A sands from the upper Kuparuk C and B sands. The well is a gaslifted oil well. The well was SI in 2002 due to high water cut.The Kuparuk A sands were isolated with a tubing plug and the well brought back online in 2009 producing only from the Kuparuk C and B. The tubing and IA pressure started to track in May 2017. Diagnostics included a combo MIT(Tubing and IA),confirming packer and casing integrity with a 2,000 psi test.A tubing caliper ran in July 2017 confirmed a hole in the tubing at 8,230' MD.The well remains SI waiting on repairing the tubing. , Notes Regarding Wellbore Condition Q • Casing tested to 2,000 psi down to 8,867' MD (Above HB Packer) on 7/11/2017. .0• cr'2'5 • Max angle 49.2° @ 5,700' in the 7" casing. • Deviation at PBR is 41.6°and dogleg of 1.0°/100 ft. • Min ID is 2.812" thru TRDP-1A-SSA SCSSV at 1,896' MD. • Min ID is 2.813"thru W-1 profile below the HB Packer at 8,904' MD. • Last Fill Depth: 9,040' MD slickline tag 7/21/2012. • CA-2 tubing plug set at 9,104' MD on 6/24/94. • Tubing caliper found hole at 8,230' MD ran on 7/17/17. • Stations#3 -#12 dummied off as of 7/10/17. Objective: The purpose of this work is to patch the tubing with 1 each wireline set/retrievable patch. Brief Procedure: Wireline Procedure: 1. MIRU Wireline and PCE (Press Control Equip) PT lubricator to 3,000 psi Hi 250 Low. 2. RIH w/tubing patch to cover hole at+/-8,230' MD with the following items: a. Paragon II Packer/Anchor Latch/1.42" ID Spacer Pipe/Paragon II Packer(Bottom to Top). 3. RD Wireline and PCE. 111 • 0 Well Prognosis Well: MPU B-10 Iiilcorp Alaska,LLI Date:8/16/2017 4. Turn well over to production. JA ( Attachments: -1--411)u ib 1. As-built Schematic 2. Proposed Schematic H . • MilnellPointMP UnitB-10 We : . SCHEMATIC Last Completed: 3/03/1985 PTD: 185-017 Ililcorp Alaska,LLC 44 Ong KB Elev.:59.0'/Ong GL Elev.:24.0' TREE&WELLHEAD RKB Elev=31.3'jNabors 27E) Tree 3-1/8"5M FMC w/3-1/2"Otis Quick Union f a Wellhead 11"5M FMC w/3-1/2"H BPV Profile }« OPEN HOLE/CEMENT DETAIL 133/8 ,.. 9-5/8" 762 bbls Arctic Set III,106 bbls Class'G'in a 12-1/4"Hole Min ID 2.812'0 a", 7" 72 bbls Class'G'in a 8-1/2"Hole @1 896 ;.; \.1.--'� 1 P. `` CASING DETAIL vt ' gas Size Type Wt/Grade/Conn ID Top Btm BPF s: 2! 13-3/8" Conductor 48/H-40/PELP 12.715 Surface 107' 0.1571 4, I9-5/8" Surface 36/NK-55/BTC 8.921" Surface 5,789' 0.0773 i'l 3, a 7" Production 26/L-80/BTC 6.276" Surface 9,438' 0.0383 i` TUBING DETAIL ', 4 3-1/2" Tubing 9.2/L-80/IBT 2.992" Surf 9,106' 0.0087 5, al ' WELL INCLINATION DETAIL 5 KOP @ 500' s ani Max Angle is 49 deg.@ 5,600' 9-5/8„ 4II g 7 JEWELRY DETAIL ali No Depth Item 8 1 1,896' CAMCO TRPD-1A-SSA SCSSV(Min ID=2.812") ali GLM DETAIL:CAMCO 3.5" KBUG 9 2 3,192' GLM STA 12:3.5"35 Deg Dummy Valve BK Latch Set 7/09/17 Hole in Tubing 11. 3 3,103' GLM STA 11:3.5"43 Deg Dummy Valve BK Latch Set 8/02/09 @8,230' 4 3,946' GLM STA 10:3.5"46 Deg Dummy Valve BK Latch Set 7/09/17 5 4,795' GLM STA 9:3.5"45 Deg Dummy Valve BK Latch Set 3/12/11 !.4 6 5,456' GLM STA 8:3.5"49 Deg Dummy Valve BK Latch Set 7/09/17 7 6,119' GLM STA 7:3.5"49 Deg Dummy Valve BK Latch Set 8/02/09 8 6,806' GLM STA 6:3.5"47 Deg Dummy Valve BK Latch Set 7/09/17 t 12 9 7,434' GLM STA 5:3.5"46 Deg Dummy Valve BK Latch Set 8/03/09 4, ", 13 10 8,092' GLM STA 4:3.5"46 Deg Dummy Valve BK Latch Set 7/09/17 11 8,718' GLM STA 3:3.5"42 Deg Dummy Valve BK Latch Set 7/09/17 1 Aiski "ko 12 8.845' HPT Locator Seal Assembly(10.06'Long) Mn ID2.813 ;, `. 14 13 8,849' HPT Polished Bore Receptacle(14.6'Long;4.0"ID) @8,905' III 1 14 8,867' Brown HB Retrievable Hydraulic Packer(2.89"ID) lir 15 ,. If 415 8,905' Camco Selective W-1 Nipple(Min ID=2.8131 �# 1 16 8,938' GLM STA 2:MMG-2 1-1/2"Gutted Circ Valves w/RKP Latch 16 4.7 17 8,979' GLM STA 1:MMG-2 1-1/2"Gutted Circ Valves w/RKP Latch i, fi 18 8,989' Blast Joints(3 ea) 17 19 9,094' External Casing Packer 9,040 SLM Fill 20 9,081' Brown HPT 2-B Wireline Set Permanent Packer 0' 7/21/12 18 L Kuparuk C1 21 9,104' Camco D Nipple(Min ID=2.75")CA-2 Plug Set 6/24/94 i - KuparukB7 22 9,105' HPJ Shear Sub-Bottom @ 9,106' 23 9,194' External Casing Packer 9,C94' ECP i„ ,::, . 0:414::: 014 19 ' It20 PERFORATION DETAIL MinID275" ' @9,104 +, if:14: ,1 '` Top Btm Top Btm FT Date Status Size 2 ;21 Zone , (MD) (MD) (TVD) (TVD) ECP @ 1 Kuparuk C1/B7 9,008' 9,054' 6,918' 6,954' 46 3/01/85 Open 5"12SPF 9,194' i � ' Kuparuk A3 9,282' 9,290' 7,102' 7,108' 8 3/01/85 Open 5"12SPF rte: ►±< 23 Y; - Kuparuk A3 GENERAL WELL INFO Fish @9,290' ) Underre ,`:r,'•:•&.•,. Fill @ API:50-029-21280-00-00 amivdcarbide i' 9,291'ELM Initial Completion by Nabors 27E 3/03/1985 "*i ��2 2' `A 7/29/93 TD=9,470(MD)/TD=7,280'(TVD) PBTD=9,360'(MD)/PBTD=7,193'(TVD) Created By:STP 7/19/17 - . Milnlle MP Point UB-10nit 14 II We : PROPOSED Last Completed: 3/03/1985 PTD: 185-017 Iiilcorp Alaska,LLC Orig KB Elev.:59.0'/Orig GL Elev.:24.0' TREE&WELLHEAD ARKB Elev=31.3',Nabors 27E) Tree 3-1/8"5M FMC w/3-1/2"Otis Quick Union 5 ,, 1"Wellhead 15M FMC w/3-1/2"H BPV Profile h4i li+ I OPEN HOLE/CEMENT DETAIL 13-3/S" 9-5/8" 762 bbls Arctic Set III,106 bbls Class'G'in a 12-1/4"Hole Min ID 2.812"e/ 7" 72 bbls Class'G'in a 8-1/2"Hole @1,896' ,; ti I 1 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 12 13-3/8" Conductor 48/H-40/PELP 12.715 Surface 107' 0.1571 ;:, 9-5/8" Surface 36/NK-55/BTC 8.921" Surface 5,789' 0.0773 .= 3 7" Production 26/L-80/BTC 6.276" Surface 9,438' 0.0383 I TUBING DETAIL 1 4 3-1/2" Tubing 9.2/L-80/IBT 2.992" Surf 9,106' 0.0087 . WELL INCLINATION DETAIL 5 KOP @ 500' Max Angle is 49 deg.@ 5,600' 9-5/8" 1 7 JEWELRY DETAIL No Depth Item 8 1 1,896' CAMCO TRPD-1A-SSA SCSSV(Min ID=2.8121 i; GLM DETAIL:CAMCO 3.5" KBUG ' 9 2 3,192' GLM STA 12:3.5"35 Deg Dummy Valve BK Latch Set 7/09/17 Tubing Patch p 1 ' 10 3 3,103' GLM STA 11:3.5"43 Deg Dummy Valve BK Latch Set 8/02/09 +x,230' --, 4 3,946' GLM STA 10:3.5"46 Deg Dummy Valve BK Latch Set 7/09/17 I I 5 4,795' GLM STA 9:3.5"45 Deg Dummy Valve BK Latch Set 3/12/11 � .i 11 , 6 5,456' GLM STA 8:3.5"49 Deg Dummy Valve BK Latch Set 7/09/17 7 6,119' GLM STA 7:3.5"49 Deg Dummy Valve BK Latch Set 8/02/09 8 6,806' GLM STA 6:3.5"47 Deg Dummy Valve BK Latch Set 7/09/17 (i' 12 9 7,434' GLM STA 5:3.5"46 Deg Dummy Valve BK Latch Set 8/03/09 13 10 8,092' GLM STA 4:3.5"46 Deg Dummy Valve BK Latch Set 7/09/17 II 11 8,718' GLM STA 3:3.5"42 Deg Dummy Valve BK Latch Set 7/09/17 ae 1 '1 I 14 12 8.845' HPT Locator Seal Assembly(10.06'Long) Min ID 2.813" a, . H 13 8,849' HPT Polished Bore Receptacle(14.6'Long;4.0"ID) @8,905' 14 8,867' Brown HB Retrievable Hydraulic Packer(2.89"ID) It t 1515 8,905' Camco Selective W-1 Nipple(Min ID=2.813") i4 hyo 16 8,938' GLM STA 2:MMG-2 1-1/2"Gutted Circ Valves w/RKP Latch 16 17 8,979' GLM STA 1:MMG-2 1-1/2"Gutted Circ Valves w/RKP Latch f t �� 17 18 8,989' Blast Joints(3 ea) 19 9,094' External Casing Packer Fill @en 0' 9,040'SLM 20 9,081' Brown HPT 2-B Wireline Set Permanent Packer a-i 7/21/12 18 KuparukC1 21 9,104' Camco D Nipple(Min ID=2.75")CA-2 Plug Set 6/24/94 Kupanak B7 22 9,105' HPJ Shear Sub-Bottom @ 9,106' ECP @ 23 9,194' External Casing Packer 9694 gi 19 I ' ' '' PERFORATION DETAIL Min ID 2.75 @9,1" i xTop Btm Top Btm 4. '121 Zone (MD) (MD) (TVD) (TVD) FT Date Status Size ECP@ ": Kuparuk Cl/B7 9,008' 9,054' 6,918' 6,954' 46 3/01/85 Open 5"125PF 9,194' ' 23 Kuparuk A3 9,282' 9,290' 7,102' 7,108' 8 3/01/85 Open 5"12SPF Kuparuk A3 GENERAL WELL INFO Fish @9,290' ' Underreamer-----^,—+ t' Fill @ API:50-029-21280-00-00 arm w/carbide .� �4`,--9291'� 7/29/93 ELM Initial Completion by Nabors 27E -3/03/1985 TD=9,470(MD)/TD=7,280'(TVD) PBTD=9,360'(MD)/PBTD=7,193'(1VD) Created By:TDF 8/16/17 • • kcsr. ads Seth Nolan Hilcorp Alaska, LLC 2%4.1 D 2 GeoTech 3800 Centerpoint Drive, Suite 100 RECEIVED Anchorage, AK 99503 Tele: 907 777-8308 Hilcarp Alueko,IiA: Fax: 907 777-8510 DATA LOGGED AUG 0 9 2017 E-mail: snolan@hilcorp.com i1r�GQ K BENDER DATE 08/09/17 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL SCANNED AUG 2 12 17, MPU B-10 Prints: Leakpoint Survey (UMT-CCL-PRES-TEMP-LP-LP) CD 1: ¶;MPB-10 Schematic.pdf 6/24/2013 1:09 PM PDF Document 87 KB Li MPU B-10_LeakPoint.Survey 24-June-2017.... 7/5/2017 1:59 PM LAS Hie 17,931 KB ro MPU B-10_LeakPointSurvey 24-Jure-2017.pdf 7/5/201712:17 PM PDF Document 36,283 KB MPU B40 LeakPaintSurvey24-June-2017.of 7/5/201712:28 PM TIF File 23,120 KB To MPU B-10 LeakPointSurvey24-June-2017_... 7/5/2017 12:05 PM PDF Document 6,918 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: 6Date: • d of T4 . h&\-\V/// s,b THE STAT Alaska Oil and Gas sem , of® TT A S KA Conservation Commission 333 West Seventh Avenue " `- GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "" Main: 907.279.1433 (4 ^hn":*Q, ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC ���® JUL ?� 1!. 3800 Centerpoint Dr.,Ste. 1400 $C Anchorage, AK 99503 Re: Milne Point Unit, Kuparuk River Oil Pool, MPU B-10 Permit to Drill Number: 185-017 Sundry Number: 317-332 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, WOCC — Hollis S. French Chair {-1 DATED this 2�qday of July, 2017. RBDMS LL- JUL 2 7 2017 • • RECEIVED STATE OF ALASKA 0 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 2 APPLICATION FOR SUNDRY APPROVALS 07 GCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate LI Pull Tubing Q • Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Tubing Replacement Q r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: GAS r Hilcorp Alaska LLC . Exploratory ❑ Development 2' 185-017 • 3.Address: 3800 Centerpoint Dr,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-21280-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D ' Will planned perforations require a spacing exception? Yes ❑ No ❑., ✓ MILNE PT UNIT B-10 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047437 MILNE POINT/KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total I pthVIR(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): ' Plugs(MD): Junk(MD): 9,470' 7, A 9,291' 7,109' 2,066 7,291' 7,291'(Fill) Casing Length Size MD TVD Burst Collapse Surface 107' 13-3/8" 107' 107' 1,730psi 740psi Intermediate 5,789' 9-5/8" 5,789' 4,653' 3,520psi 2,020psi Production 9,438' 7" 9,438' 7,166' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic ✓ See Schematic 3-1/2" 9.2/L-80/IBT 9,106' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Brown HB Pkr/Brown HPT Pkr/Cameo TRPD-1A-SSA - 8,867'MD/6,782'TVD;9,081'MD/6,945'TVD;1,896'MD/1,831'ND 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development E. Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 7/24/2017 Commencing Operations: OIL ❑., - WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola(Cr�.hilcorp.com "9r7Contact Phone: 777-8412 Authorized Signature: Date: Z 4 Zuw% %- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: v`t- 32 Plug Integrity ❑ BOP Test I.? Mechanical Integrity Test ❑ Location Clearance ❑ Other: 00 p$i: O :: (' Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS L `..JUL 2 7 2017 Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: /6 ._ ©c1 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: .4 12 l cl, UR1GtNAL �0(1� +�A i� Submit Form and 7- AX• " Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • i Well Prognosis Well: MPU B-10 Ililcorp Alaska,Lb Date:7/19/2017 Well Name: MPU B-10 API Number: 50-029-21280-00 Current Status: Oil Well [Gaslift] Pad: B-Pad Estimated Start Date: July 24th, 2017 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 185-017 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1 1722510 Job Type: Tubing Replacement Current Bottom Hole Pressure: 2,766 psi @ 7,000' TVD (SBHPS 7/21/2012 /7.60 ppg EMW) Maximum Expected BHP: 2,766 psi @ 7,000' TVD (No new perfs being added) ✓" MPSP: 2,066 psi V (0.1 psi/ft gas gradient) Brief Well Summary: The Milne Point B-10 well was drilled as a Kuparuk development well with Nabors 27E in March 1985. The well was initially completed with 2 packers to isolate the lower Kuparuk A sands from the upper Kuparuk C and B sands. The well is a gaslifted oil well. The well was SI in 2002 due to high water cut.The Kuparuk A sands were isolated with a tubing plug and the well brought back online in 2009 producing only from the Kuparuk C and B. The tubing and IA pressure started to track in May 2017. Diagnostics included a combo MIT (Tubing and IA),confirming packer and casing integrity with a 2,000 psi test.A tubing caliper ran in July 2017 confirmed a hole in the tubing at 8,230' MD.The well remains SI waiting on repairing the tubing. Notes Regarding Wellbore Condition • Casing tested to 2,000 psi down to 8,867' MD (Above HB Packer) on 7/11/2017. ✓ C-#` 1 • Max angle 49.2° @ 5,700' in the 7" casing. '�— • Deviation at PBR is 41.6° and dogleg of 1.0°/100 ft. • Min ID is 2.812" thru TRDP-1A-SSA SCSSV at 1,896' MD. • Min ID is 2.813"thru W-1 profile below the HB Packer at 8,904' MD. • Last Fill Depth: 9,040' MD slickline tag 7/21/2012. • WRP tubing plug set at 8,894' MD on 6/23/17. • MA-2 tubing plug set at 8,905' MD on 6/23/17. • CA-2 tubing plug set at 9,104' MD on 6/24/94. • Tubing caliper found hole at 8,230' MD ran on 7/17/17. ' 2111 • Stations#3-#12 dummied off as of 7/10/17. Objective: The purpose of this work is to pull tubing string and run new tubing and seal assembly. 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. • n 0 Well Prognosis Well: MPU B-10 � �pf7 Ililcorp Alaska,LLI Date:7/19/2017 1:1-" r� 5. Circulate at least one wellbore volume with 8.5 ppg seawater down tubing, taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD Crane. 9. NU BOPE house.Spot mud boat. Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg seawater prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2,500 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. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 3-1/2" test joint. g Z 1 e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. 1(/'. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg seawater as needed. Pump cleaning pill w/heated seawater to flush tubing of residual oil. 15. MU landing joint or spear and PU on the tubing hanger. 7a. x z'3 '//y v 114 C- a. The estimated PU weight is 100K(assuming some friction while pulling the seals). �n� b. If needed, circulate pill (forward or reverse) with cleaning surfactant prior to laying down the tubing hanger. 16. Recover the 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. • i • Well Prognosis Well: MPU B-10 Ililcorp Alaska,LL' Date: 7/19/2017 17. POOH and lay down the 3-1/2" tubing. Number and strap all joints. Lay down all tubing, gaslift mandrels,the SCSSV and control line and the seal assembly. a. Junk all joints of tubing and the gaslift mandrels. b. Note any sand or scale inside or on the outside of the tubing on the morning report. c. Original completion/packer fluid is 10.2 ppg NaCl-NaBr. 18. RIH with 7" 26#scraper assembly to ±8,849' MD (top of PBR) on 3-1/2" workstring. Circulate the well clean with 8.5 ppg seawater. 19. POOH and LD 3-1/2" workstring and scraper assembly. 20. PU completion and RIH on 2-7/8" tubing. a. Tubing is 2-7/8" 6.5# L-80 EUE (Range 2) b. Packer @ ±8,780' MD c. 2-7/8" XN (2.25" No-Go) @ ±8,820' MD [Pre-load RHC plug body] d. 2-7/8" WLEG @ ±8,860' MD 21. Tag up and space out above the PBR at±8,849' MD. Circ inhibited packer fluid and freeze protect fluid. 22. RIH to±8,860' MD. Land hanger. RILDS. 23. Set tubing tail 10' into the PBR at±8,860' MD. < 24. Drop ball and rod. Pressure up and set Packer(start 2,500 psi/final 4,000 psi). \ 25. Pressure test tubing to 4,000 psi for 30 min and chart. Bleed tubing to 500 psi. tfrk26. Test inner annulus to 2,000 psi for 30 min and chart. Monitor tubing for packer leaks. Bleed casing to 0 psi. Bleed tubing to 0 psi. 27. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 28. Set BPV. Rig down ASR. Post-Rig Procedure: 29. RD mud boat. RD BOPE house. Move to next well location. 30. RU crane. ND BOPE. 31. NU existing,3-1/8" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 32. RD crane. Move 500 bbl returns tank and rig mats to next well location. 33. Replace IA/OA gauge(s) if removed. 34. Turn well over to production. RU well house and flowlines. Wireline Procedure: 35. RU Slickline.Test lubricator to 250/3,000 psi. 36. RIH and pull ball/rod and RHC plug body from XN profile at±8,820' MD. POOH. 37. RIH and drift tubing and tag PBTD. POOH. 38. RD Slickline. Attachments: 1. As-built Schematic • Well Prognosis Well: MPU B-10 Hilcorp Alaska,LL1 Date: 7/19/2017 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO MOC Form •• Milne Point Unit II Well: MP B-10 SCHEMATIC Last Completed: 3/03/1985 Iiiileor„Alaska,LLC PTD: 185-017 OrigKBElev.:59.0'/OrigGLElev.:24.0' TREE&WELLHEAD RKB Elev=31.3' Nabors 27E) Tree 3-1/8"5M FMC w/3-1/2"Otis Quick Union Ag' , Wellhead 11"5M FMC w/3-1/2"H BPV Profile al 1w it OPEN HOLE/CEMENT DETAIL 13-3/8" a; P 9-5/8" 762 bbls Arctic Set III,106 bbls Class'G'in a 12-1/4"Hole Min ID 2.812V. ./, 7" 72 bbls Class'G'in a 8-1/2"Hole @1 896 ', !IL; e CASING DETAIL r ( �� Size Type Wt/Grade/Conn ID Top Btm BPF i", 2 i ,i 13-3/8" Conductor 48/H-40/PELP 12.715 Surface 107' 0.1571 J 9-5/8" Surface 36/NK-55/BTC 8.921" Surface 5,789' 0.0773 a i4 7" Production 26/L-80/BTC 6.276" Surface 9,438' 0.0383 4:4 3 r `t TUBING DETAIL 4 3-1/2" Tubing 9.2/L-80/IBT 2.992" Surf 9,106' 0.0087 , WELL INCLINATION DETAIL 5 fixKOP@500' . 'a Max Angle is 49 deg.@ 5,600' 4 6 9-5/8"i 7 JEWELRY DETAIL No Depth Item 8 1 1,896' CAMCO TRPD-1A-SSA SCSSV(Min ID=2.812") 9 GLM DETAIL:CAMCO 3.5" KBUG 2 3,192' GLM STA 12:3.5"35 Deg Dummy Valve BK Latch Set 7/09/17 Hole in Tubing 3 3,103' GLM STA 11:3.5"43 Deg Dummy Valve BK Latch Set 8/02/09 @8,230' 10 4 3,946' GLM STA 10:3.5"46 Deg Dummy Valve BK Latch Set 7/09/17 - 5 4,795' GLM STA 9:3.5"45 Deg Dummy Valve BK Latch Set 3/12/11 'A 11 '° 6 5,456' GLM STA 8:3.5"49 Deg Dummy Valve BK Latch Set 7/09/17 7 6,119' GLM STA 7:3.5"49 Deg Dummy Valve BK Latch Set 8/02/09 12 /n� 8 6,806' GLM STA 6:3.5"47 Deg Dummy Valve BK Latch Set 7/09/17 I �6P-- 9 7,434' GLM STA 5:3.5"46 Deg Dummy Valve BK Latch Set 8/03/09 ' � 13 10 8,092' GLM STA 4:3.5"46 Deg Dummy Valve BK Latch Set 7/09/17 11 8,718' GLM STA 3:3.5"42 Deg Dummy Valve BK Latch Set 7/09/17 )), r t r I - 14 12 8.845' HPT Locator Seal Assembly(10.06'Long) Min ID 2.813" -r = + 13 8,849' HPT Polished Bore Receptacle(14.6'Long;4.0"ID) @8,905 ? 111 I 14 8,867' Brown HB Retrievable Hydraulic Packer(2.89"ID) 15 I 15 8,905' Camco Selective W-1 Nipple(Min ID=2.813") 4 16 8,938' GLM STA 2:MMG-2 1-1/2"Gutted Circ Valves w/RKP Latch 16 s v 17 8,979' GLM STA 1:MMG-2 1-1/2"Gutted Circ Valves w/RKP Latch 17 18 8,989' Blast Joints(3 ea) Fill @ ` '1; 19 9,094' External Casing Packer 9,040'SLM 1 4 20 9,081' Brown HPT 2-B Wireline Set Permanent Packer 7/21/12 18 ,; KuparukCl 21 9,104' Camco D Nipple(Min ID=2.75")CA-2 Plug Set 6/24/94 • KupaukB7 22 9,105' HPJ Shear Sub-Bottom @ 9,106' ECP@ 4, 1 23 9,194' External Casing Packer 9,094' y 19 li I I ,: 20 Min ID2.75" `" PERFORATION DETAIL @9,10 Top Btm Top Btm i i 21 * Zone FT Date Status Size (MD) (MD) (TVD) (TVD) 7 Kuparuk Ci/B7 9,008' 9,054' 6,918' 6,954' 46 3/01/85 Open 5"12SPF ECP @ 9,194' x+ '° KuparukA3 9,282' 9,290' 7,102' 7,108' 8 3/01/85 Open 5"12SPF .423 V - KuparukA3 GENERAL WELL INFO Fish @9,29:Y '� " Underreamer - FII @ API:50-029-21280-00-00 armend catide—v ° 9,291'ELM Initial Completion by Nabors 27E -3/03/1985 7�6.4%,A-1,�, - 7/29/93 TD=9,470(MD)/TD=7,280'(TVD) PBTD=9,360'(MD)/PBTD=7,193'(TVD) Created By:STP 7/19/17 H . Proposed Milne Point Unit Well: MP B-10 Last Completed: Proposed Hiilean;Alaska,LLC PTD: 185-017 OrigKBElev.:59.0'/OrigGLElev.:24.0' TREE&WELLHEAD RKB Elev=31.3' Nabors 27E) Tree 3-1/8"5M FMC w/3-1/2"Otis Quick Union r 1 Wellhead 11"5M FMC w/3-1/2"H BPV Profile 1 OPEN HOLE/CEMENT DETAIL 13-3/8" ,� ,i 9-5/8" 762 bbls Arctic Set III,106 bbls Class'G'in a 12-1/4"Hole ° 7" 72 bbls Class'G'in a 8-1/2"Hole 1 4. CASING DETAIL ... 2 Size Type Wt/Grade/Conn ID Top Btm BPF I ' 13-3/8" Conductor 48/H-40/PELP 12.715 Surface 107' 0.1571 3 '' 9-5/8" Surface 36/NK-55/BTC 8.921" Surface 5,789' 0.0773 a :h1 7" Production 26/L-80/BTC 6.276" Surface 9,438' 0.0383 TUBING DETAIL E " 5 2-7/8" Tubing 6.5/L-80/EUE 2.441" Surf 8,860' 0.0058 ' 7/�y 9-5/8" 3-1/2" Tubing 9.2/L-80/IBT 2.992" 8,860' 9,106' 0.0087 ,.# r 2 6� �� WELL INCLINATION DETAIL 11 KOP @ 500' 7 Max Angle is 49 deg.@ 5,600' I JEWELRY DETAIL 8 No Depth Item 9 GLM DETAIL:CAMCO 3.5" KBUG 1 3,192' GLM STA 12:2.875"35 Deg Dummy Valve BK Latch 2 3,103' GLM STA 11:2.875"43 Deg Dummy Valve BK Latch ',i 10 3 3,946' GLM STA 10:2.875"46 Deg Dummy Valve BK Latch " • 4 4,795' GLM STA 9:2.875"45 Deg Dummy Valve BK Latch +: r r 1-t� 5 5,456' GLM STA 8:2.875"49 Deg Dummy Valve BK Latch Min ID 2.25" ,� 11 P - @8,820' .4,,, it y 6 6,119' GLM STA 7:2.875"49 Deg Dummy Valve BK Latch '; ig 12 " -5 7 6,806' GLM STA 6:2.875"47 Deg Dummy Valve BK Latch y � AA 8 7,434' GLM STA 5:2.875"46 Deg Dummy Valve BK Latch 13 9 8,092' GLM STA 4:2.875"46 Deg Dummy Valve BK Latch ',� :-.114 et"' 10 8,718' GLM STA 3:2.875"42 Deg Dummy Valve BK Latch .t+ 11 8,780' 7"x 2-7/8"Hydraulic Set Retrievable Packer '', ra lr ir1 15 12 8.820' 2-7/8"XN Nipple(Min ID=2.25") Min 1D2.813" 4! m = 4, 13 8,860' 2-7/8"WLEG @8,905' , 14 8,849' HPT Polished Bore Receptacle(14.6'Long;4.0"ID) `a 16 ' 15 8,867' Brown HB Retrievable Hydraulic Packer(2.89"ID) to 16 8,905' Camco Selective W-1 Nipple(Min ID=2.813") 17 », 17 8,938' GLM STA 2:MMG-2 1-1/2"Gutted Circ Valves w/RKP Latch `' 18 8,979' GLM STA 1:MMG-2 1-1/2"Gutted Circ Valves w/RKP Latch 18 x' '' 19 8,989' Blast Joints(3 ea) Fill @ p a, 9,040'SLM 20 9,094' External Casing Packer 7/21/12 19* Kuparuk C1 21 9,081' Brown HPT 2-B Wireline Set Permanent Packer Kuparuk B7 22 9,104' Camco D Nipple(Min ID=2.75")CA-2 Plug Set 6/24/94 ECP@ b* t' 23 9,105' HPJ Shear Sub-Bottom @ 9,106' 9,094' I1 20 24 9,194' External Casing Packer t 1 r? 121 Min ID 2.75' `#A PERFORATION DETAIL @9,1ckv w, r: ,' Top Btm Top Btm FT Date Status Size $ .4 *,i Zone (MD) (MD) (TVD) (TVD) 11Vi ECP@ �4 1Kuparuk C1/B7 9,008' 9,054' 6,918' 6,954' 46 3/01/85 Open 5"12SPF 9,194' 0 23 Kuparuk A3 9,282' 9,290' 7,102' 7,108' 8 3/01/85 Open 5"12SPF Soil 24 Fish @9,290 ' 44-KuparukA3 GENERAL WELL INFO Undenrearner.----1".-+ Fill @ API:50-029-21280-00-00 arm vA carbide ` 9,291'ELM 7'4Wili17..49iii 7/29/93 Initial Completion by Nabors 27E -3/03/1985 TD=9,470(MD)/TD=7,280'(TVD) PBTD=9,360'(MD)/PBTD=7,193'(TVD) Created By:STP 7/19/17 • • II Milne Point ASR Rig 1 BOPE 110.4.1. \I-L,.1I.t_ 11" BOPE , Stripping Head r 1' 1 3.98' - Shaffe z 11"- 5000 Iii lit (Ift 111141 rs- r. '-. CI ► -U ! I—` 4.54' H H VBR or Pipe Rams i ' c P� H 11"-5000 H Blind crop 4I i; e; C \ /.___, lIi 1111 Viii Ili ill 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves I.ilt'l iris 1!Il i 4 � e ii,' .1e :(0)41 �4eri 2.00 I ��°� } {�`° �} _ _ _ _ 1 �(° 1E i i i i 4 e ii 7 ■ i i ° i 111 iiileiildiW i l _ a' Manual Manual Manual HCR Updated 8/19/2015 • • • la EXISTING TREE/WELLHEAD MPU B-10 Wellhead/Tree Milne Point Unit Ilikorp Alaska,LLC 0 Tree Cap /,_ 00 PflTree Valve 3-1/8" 5M �(° 0 0�0 .,n—,1., Tree Cross 3-1/8" 5M i (o)®®i Tree Valve 3-1/8" 5M El SSV 3-1/8" 5M 0 minomil .I—RI 00 Tree Valve 3-1/8" 5M L/0 1' 0p0 Tubing Adapter = Tubing Head 1l Iii 11" 5M Top x 11" 5M Btm N. SII. _��mii ' '` �'® i� 1: $j I( " I.# Mt Casing Head ..ii iiit , ... 11" 5M Top x 11" 5M Btm • 0 § kCD # o :1-'cec DC 2 / ■ co c e > o / 7 Sa. § 2 / < �a E 0) o _c MI US \ { k 'E f E � a. $ § « m G2 a) 7 7 2 o.a k / � 7 n e o_ % •U) < m a a 3 \ o GI 0 § Ft k / % \ 5 0 /§ U \ ƒ § c ■ _ $\ co * 7G , \ / 0 2 / § 9 § CD E E § 2 e a k \ \ a _0 / '6 \ / CS) § _ 0 . as c _ # � Cl) \ / ta2 o 7?) 0 u)§ Et co 0 0_ /\ ° O ,-- 00 \ as� 0 Eo cc O _� a ° ® CV � _ .g o 15 / 2 o k & U) U) � § -, 0I-ii / � �us « E -1 E k t. E 0 a \ co 2 c 0 o $ Cl) \ / < a. , 1 ) (I 1.- , C (Yd S Memory Multi-Finger Caliper LogResults Summary y Company: Hilcorp Alaska, LLC. Well: B-10 Log Date: July 17, 2017 Field: Milne Point Log No.: 14276 State: Alaska Run No.: 1 API No. 50-029-21280 Pipe Description: 3.5 inch 9.2 lb. L-80 BTRS Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 8,889 Ft. (MD) Inspection Type : Corrosion Monitoring & Subsidence Inspection COMMENTS : This caliper data is tied into the top of the BOT`HB'Hydraulic Packer at 8,872 feet(Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage and to look for signs of subsurface subsidence. A 3-D log plot overlay of the centered and un-centered caliper recordings from surface to 1,000 feet is included in this report. No areas of tubing buckling are indicated over this interval. The caliper recordings indicate the 3.5 inch tubing logged appears to be in good to poor condition, with a probable hole recorded in joint 261 at 8,230 feet. Other recorded damage appears as apparent mill wear, deep isolated pitting and a deep line of pits. A 3-D log plot of the caliper recording illustrating the most significant damage, from 7,790 feet to 8,250 feet, is included in this report. No significant areas of cross- sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. MAXIMUM RECORDED WALL PENETRATIONS : Percent W< Probable Hole 99 261 8,230 Ft. (MD) Isolated Pitting /Apparent Wear 58 254 7,997 Ft. (MD) Isolated Pitting/Apparent Wear 57 251 7,914 Ft. (MD) Line of Pits/Apparent Wear 57 252 7,929 Ft. (MD) Line of Pits 57 256 8,053 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross-sectional wall loss(>9%)are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. C.Goerdt HY. Yang M. Linder Field ` Wltncss(uc) ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford,TX 77497 Phone: (281)431-7100 or(888) 565-9085 Fax: (281)431-7125 E-mail: PDSAnalysisamemorvloa.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ji4 .SPDS Report Cross Sections S Well: B-10 Survey Date: July 17,2017 Field: Milne Point Tool Type: UW MFC 24 No.214320 Company: Hilcorp Alaska,LLC. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.2 ppf L-80 BTRS Analyst: HY.Yang Cross Section for Joint 261 at depth 8,230.328 ft. Tool speed=53 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=91% Tool deviation=44° / 1 • Finger= 12 Penetration=0.251 in. Probable Hole! 0.25 in.=99%Wall Penetration HIGH SIDE=UP XHVZE Imat~Project Well History File e This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / ~- ~-'/7 Well History File Identifier RESCAN DIGITAL DATA [] Color items: ~iskettes, No~ [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other:. NOTES: ~ BY: BEVERLY BR~ SHERYL MARIA LOWEU~ OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other BY; ~REN VINCENT SHERYL MARIA LOWELl_ DATE; Scan'ningPreparation %x30=_~_~+ /4~-~=TOTALPAGES/~)(~_ BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: / L~ ,~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY; BEVERLY BREN VINCENT~ARIA LOWELL DATE///¢/O~,~--~~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDiVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (individual page [special attention] scanning completed) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd ~~~ -~w~~ Ti~'A/tf~l~fT~"~4L PeoAcTive Diwqnios~ic Seevic.~s, In~c. To: AOC~CC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907j 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / M1Tj The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittat letter to the foNowing : BP Exploration (Alaska), Inc. Petrotechnical Data Cer~ter Attn: Joe Lastuflca LR2-1 900 Benson Bhrd. Anchorage, Alaska 98508 and `~,~1'~~~ - ~ ~ ~:, _ .. •~~~~~w•t~ .'L' `_ 1~s-~1~- ProActive Diagnostic Senrices, lnc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907) 245,8952 ~ ~ 3~~ 1 J Gas Lift Survey 08-JuE09 MP&10 2) .~ ~ Signed : Print Name: BL/ E~ ,50-~~1280-00 [late _ PROACTIVE DIAGNOSTIC SERVICES, (NC., 130 W. INTERNATIONAI AIRPORT RD SUITE C, ANCHORAGE, AK 99548 PHONE: (907~245-8951 FAx: (907)245-88952 E-MAIL . , v. ~.~ „Y ~'' _..._~ _ WEBSITE _._ _ ._ . ______._. - _. C:~Documents and Settings\Ownec~Desk[op\Tiansmit_BP.docx . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount 0.7:) DATE: July 12, 2000 Commissioner' f I/o/bc,) THRU: Blair Wondzell, ~~ P. I. Supervisor . êf 1(óCJ FROM: ~t!1 Jeff Jones ,--' SUBJECT: Safety Valve Tests Petroleum'l sp c r Milne Point Unit B & C Pads JulV 9, 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. '3 MO... r.z..+Z-'":?i- 21 well houses were inspected, no failures. -'tf' Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc . . Alaska Oil ~1nd Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones SubInitted By: Date: FieldlUnitlPad: Kuparuk River/MPU/B-Pad Separator psi: LPS 140 HPS N/ A 7/9/00 .~. '" ...~.: '-".' I'd ,-', ;'...."'.1'-'~' ..... ._~.:' ';<. .. L -:';',-.¡ :~--~~-.'. ,.'" ' - . ~ \ :\...",:' .Well.Datà",: :. .'",' "", I' ~.' " " Pilots:' ~ ~1'~f~~J~é.~,1::.::.:,,:;:./ ',:\ ~~V':'; .~SSV'; : '_"':~::'-:'. '.:".' Well::TyPl!' ,- Well PerIn it Separ Set LIP Test Test Test NUl11ber Number PSI })81 Trip Code Code Code N W N B-02 B-03 B-04A B-06 B-07 B-09 B-10 B-13 B-15 B-16 B-19 B-20 B-21 B-22 B-23 Wells: 9. /7 I()O 1811420 1820560 1821000 1850130 1850620 1850340 1850170 1850930 1851210 1851490 1852300 1860050 1860230 1853020 1890160 140 ]40 140 140 140 140 140 140 ]40 9 Components: ]00 100 100 100 100 ]00 100 100 100 1 ] 5 95 90 95 95 100 p P P 95 90 p P Oil, WAG, GIN.J, GAS or CYClÆ P P p OIL OIL OIL 95 p p p OIL OIL P P P 18 Failures: p OIL p P 4 OIL OIL OIL Failure Rate: 5.50/0 090 Day Three well SV's recorded slow closing times; B-04A(3 :20), 8-03(3 :03),B-06(3 :30). S01ne of the wells on this pad do not have well signs on them. Larry Niles, the BP representative, said he would have these items corrected. Remarl{s: Page 1 of] Vv043m 1 t.xls SCHLUMBERGER WELL SERVICES · A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON, TEXAS 7725!-2! 75 AUG 0 4 M93 I .LE~SE .EPtY TO SCHLUMBERGER WELL SERVICES Pouch 340069 Prudhoe Bay, AK- 99734-0069 Conoco, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Linda Starr Gentlemen: Enclosed are 3 BLprintsofthe Company Conoco~ Inc. Well Milne Point Unit B-la Depth Determination 1, 7/29/93 on: Field. Hilne Point Additional prints are being sent to: 1 BL prints Conoco, Inc. County North Slope State Alaska 600 North Dairy Ashford Houston~ TX 77079 Attn: George Lamb, OF 2018 PT 1BL prints Conoco, Inc. 1000 South Pine Ponca City, OK 74603 Attn: Janet Webb, 1030 EB l~~prints , 1 RF Sepia~-~ //~laska 0il & Gas Conservatio~ // Commission 3001 Porcupine Drive Anchorage, AK 99501 ~: Larry Grant _ prints The film is returned to Conoco, Linda Start We appreciate the privilege of serving you. 1 BL prints , 1 RF Sepia Chevron U.S.A. 11111 South Wilcrest Houston, TX 77099 Attn: Larry__S.ydora 713/561-3674 1BL prints , I RF Sepia OXY U.S.A., Inr~ 6 Desta Drive, Suite 6002 Midland, TX 79705 Attn: John Carrol 915/685-5898 __prints prints Receivezd b.Y:-- · ?f6~e.~.?~ £~.~ Very truly yours, SCHLUMBERGER WELL SERVICES SwS- I 32? ~' OH/CH (11 BL/3RF) Raymond N. Dickes Oi S.T,I~ I C T bi A F~AG [ ~1 SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOL(X;Y CORPORATION HOUSTON. TEXAS 77251-2175 JUN 2 4 1~3 sc.~u~BE.G~R w~LL s~.v,cEs Pouch 340069 Prudhoe Bay, AK 99734-0069 Conoco, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Linda Starr Gentlemen: Enclosed are 3 BLprintsofthe Company Conoco, Inc. Well Milne Point Unit B-10 Run 2, 6/19/93 on' Field Milne Point Additional prints are being sent to: 1 BL prints Conoco, Inc. County North Slope State Alaska 600 North Dairy AShford Houston, TX 77079 Attn: George Lamb, OF 2018 PT 1BL prints Conoco, Inc. I000 South Pine Ponca City~ OK 74603 Attn: Janet Webb, 1030 EB 1BL~=~epia .~'~a Oil & Gas ConServation / Commission ~3001 Porcupine Drive ~nchorase, AK 99501 / A~: Larry Grant // prints 1 BL .prints , 1 RF Sepia Chevron U.S.A. 11111 South Wilcr¢$[ Houston, TX 77099 Attn: Larz~IS~ora 713/561-3674 1BL prints , 1RF Sepia OXY U.S.A., Inc f~iva, g.ito 6002 Midland, TX 79705 Attn: John Carrol 915/685-5898 .prints prints The film is returned to Conoco, Received/by: /,- ~ _ LindaStarr I ~ . r . L ~ , /~X ~ RECEIVED:..:- SwS- I 327 F OH/CH (11 BL/3RF) We appreciate the privilege Very truly yours, Alaska 011 & Gas Cons. Commissi{~HLUMSERGER WELL SERVICES Anchorage Ra~mond N. D~okes OIST~ICT Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 MR. MIKE MINDER STATE OF ALASKA OIL AND GAS COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 DEAR MR. MINDER, ATTACHED IS THE REQUEST FOR SUNDRY APPROVAL TO CONDUCT WORKOVER OPERATIONS ON THE B-lO WELL. THESE OPERATIONS WILL BE NECESSARY TO CONVERT THE PRODUCTION TECHNIQUE ON THE B-lO WELL FROM THE CURRENT GAS LIFT DESIGN TO ELECTRIC SUBMERSIBLE PUMP DESIGN. RESPECTFULLY, DRILLING FOREMAN R. ECEIVE . ,.,v~AY 2 i! ]97,'i ~ ~ ~nch0ra~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ APPLICATION FOR.SUNDRY APPROVALS N A 1. Type of Request: Abandon __ 2. Name of Operator CONOCO INC. Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing X.._ Variance __ Perforate __ Other PRUDHOE BAY. AK I 5. Type of Well: Development Exploratory Stratigraphic 99734 Service Sec 18, T13N, R11E, UM Address P.O. Rex 2,4OO45: Location of well at surface 232' FSL, 848' FWL, At top of productive interval N/A At effective depth N/A At total depth 1821' FSL, 4461' FEL, Sec 13, T13N, R10E, UN 6. Datum elevation (DF or KB) KB 59 feet 7. Unit or Property name MILNE POINT UNIT 8. Well number B-lO 9. Permit number 85-17 10. APl number 50- 02g-21280 11. Field/Pool Kuparuk River 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9438' feet Plugs (measured) 9348' N/A feet N/A feet Junk (measured) N/A N/A feet Casing Length Size Cemented Measured depth Structural Conductor Surface 13-3/8" 107' Intermediate 9-5/8" 5789' Production 7" 9438' Liner Perforation depth:measuredMK-l&2 9008'-9054', LK-1 9282'-9290' trueverticai~lKl&2 6g18'-Gg54', LK-1 7131'-7137' True vertical depth ,. 7,,~o~ e'lO, WlSo" Tubing(size. grade, and measured depth) 3-1/2", 9.2 #/FT, L-BO BUTTRESS 0 9105' Packers and SSSV (type and measured depthlBOT , HB' HYDRAUL I C PACKER $ 8866' PERM PACKER @ 9091'; SSSV CAMCO TRDP-1A SSA SCSSV ~ 1909' 13. Attachments Description summary of propose__ Detailed operations programL BOT 2-B BOP sketcl~__ 14. Estimated date for commencing operation .IlINI:' q_ I Clqll 16. I-f p~'o~o~a~ was verbally approved Name of approver Date approved 15. Status of well classification as: oilX__ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~,r/ ~"}.~e.r~ Title SENIOR PRODUCTION FOREMAN " FOR COMMISSION USE ONLY Date :~ /,~ ?/? v Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ ¢O ~' Mechanical Integrity Test __ Subsequent form required 10- [Approval No. 9~..' r-~"~),,~, ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commission Approved Copy Commissioner Returnod Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MILNE POINT UN 10 ACTUAL COMPLETION SKETCH COMPLETED ON '3-8-85 NOTES: FMC TUBING HANGER w/ $ I/1~' BPV PROFILE 1. All meeeuremenle are from KDB of Nabor5 27- E 2. KDB - SL 59' S. KDB - GL 35' 4. MaX. angle49° at 5600' MD 5. KOP o! 5.00' S. Slant type hole-Yes 7. Min. angle .~7.75 o at T D S. FMC 3 118' APl 5000e tree with 3 1/2' 8 rd. treetop connection. B. Min. reatriction ii 2.15" { D Nipple } 10. APl No. 50- 029 - 21280 11. Completion fluid 10.2 ppg Brine Cooing and cement Information euppUed on geeing end cement aketch. 3 I/2" 9.2#/fi L-80 BTRS 1909' CAMCO TRDP- IA-SSA SCSSV (2.812" ID) 2206 3116' . 3960 · 4808 5469' CAMCO 3 I/2"KSUG GLM 6132' 6819' 7447' 8106' 8731', PERFORAT IONS IZ SPF or 120° phasln§ 9008' - 9054' (6918'- 6954') MK-I & -2 9282' - 9290' (7151'- 7157') LK-I (Based on OIL dated 2-26-85} ACID TREATMENT ( II - 24 - 85 ) Total Yolume = 2400 9aS 15°~o 3000 gal 12-3 Mud ~:id 410 ga! Acetic Acid - B840' BOT PBR, Seal Assembly {3.0' ID) 8866' BOT 'HB' Hydraulic Pecker (2.89" ID) S916' CAMCO W - I Sale;live Nipple ( 2.BI3" ID ) 8949 "~ CAMCO MMG-2 GLM 11/2" 8~0 'J -- 3 I/2' Blast Joint, SOT Sial Sore RIClpIOCll · 091' BaT 2-B Permonenl Packer 9104' CAMCO D Nipple~.2.~"~'~?'lO~;~ · ~: .Cg ~ Gas Cons, 9438' 7" Z6~/fl. L-CO BTRS {6.ZT6"ID, 6.1~1" MPU KUPARUK RESERVOIR PROCEDURE FOR CONVERSION OF GAS LIFT WELLS TO ELECTRIC SUBNERSIBLE PUMP 1. STABILIZED WELL TESTS WERE OBTAINED FOR EACH WELL. 2. PRESSURE GAUGES WERE RUN ON WIRELINE AND FLOWING BOTTOM HOLE PRESSURES WERE MEASURED FOR EACH WELL. WELLS WERE THEN SHUT IN AT SURFACE AND 12 HOUR PRESSURE BUILDUP SURVEYS WERE PERFORMED TO DETERMINE RESERVOIR PRESSURES. 3. KILL FLUID DENSITIES WERE THEN DESIGNED BASED ON THIS PRESSURE DATA FOR EACH WELL TO PROVIDE FOR BALANCED CONDITIONS DURING THE WORKOVER OPERATIONS. FOLLOWING ARE THE RESULTING KILL FLUID DENSITIES: WELL DEPTH SBHP FBHP KILL FLUID (TVD-FT) (PSIG) (PSIG) (PPG) B-lO 7026 4370 1629 12.5 B-20 6985 3265 2349 9.5 B-23 6900 3500 2200 10.3 NOTE: KILL FLUIDS ARE A HALF POUND OVER-BALANCED TO THE SBHP. THE BRINES FOR THE B PAD WELLS SHOULD BE ABLE TO BE DELIVERED FROM TOWN SINCE THE KUPARUK RIVER BRIDGE SHOULD BE BACK IN BY THEN. IF THE RIG MOVES ON B PAD BEFORE THE BRIDGE IS BACK IN PLACE, B-lO SHOULD BE DRILLED FIRST SINCE IT WILL BE THE EASIEST AND MOST INEXPENSIVE BRINE TO BUILD ON LOCATION. ANY REMAINING BRINE CAN BE USED AS A BASE FOR THE B-23 WELL WHICH SHOULD PRECEED THE B-23 WELL FOR THE SAME REASON. 4. ALL KILL FLUIDS WILL BE FILTERED TO 2 MICRON AND STORED IN CLEAN TANKS. 5. SHUT IN OFFSET INJECTORS PRIOR TO RIGGING UP WORKOVER RIG ON WELL. BULLHEAD KILL FLUID DOWN TUBING TO KILL THE WELL. (SEE ATTACHED WELL BORE DIAGRAMS.) NIPPLE DOWN WELLHEAD AND NIPPLE UP BOPs. PRESSURE TEST BOPs TO 3000 PSIG. 6. P/U TUBING AND SHEAR THE PBR ASSEMBLY (SEE ATTACHED WELL BORE DIAGRAMS). CIRCULATE KILL FLUID AROUND AND MAINTAIN HOLE FULL OF KILL FLUID. POOH WITH TUBING AND LAY DOWN SBR. 7. M/U THE ELECTRIC SUBMERSIBLE PUMP ASSEMBLY AS ILLUSTRATED IN THE ATTACHED OTIS COMPLETION GUIDE. STRAP AND RECORD THE LENGTH OF EACH COMPONENT. RUN A STANDARD CENTRALIFT MOTOR CENTRALIZER FOR THE 562 SERIES MOTORS AND 7" 26# CASING ON THE BOTTOM OF THE MOTOR. MILNE POINT B-10 OPERATOR: CONOCO INC. SURFACE LOCATION: 232' FSL, 848' FWL, Section 18, T13N, RllE, U.M. BOTTOM HOLE LOCATION: 1821' FSL, 4461' FEL, NOTES: 1. Ail measurements from KDB of Nabors 27-E 2. KDB - SL ~ 59' 3. KDB - GL = 3'5' Section 13, T13N, R10E, U.M. 4. Max. angle = 49° at 5600' SPUD DATE: 02/17/85 5. KOP at 500' 6. Slant Type Hole - YES PBTD @ 9348' 13 3/8'" 48# H-40 Pelp at 107 ' 9 5/8" 36# K-55 Btrs. at 5789' TOC unknown ECP 9094.' ECP 9194' 7l! 26# L-80 Btrs. 9 5/8" Surface Casing 1. Pumped 40 Bbls of I1 ppg Sepiolite preflush. 2. Pumped 762 Bbls (2228 sx) of Cold Set III. 3. Pumped 106 Bbls (518 sx) of Class "G" cement w~th 1% CaC1 + .2% D-6. 4. Displaced with 441Bbls mud. NOTE: Full returns throughout Job. 50 Bbls cement to surface. Centralizers: 1 per 40' 5780' - 4836' 1 per 80' 4760' - Surface 7" Production Casing 1. Pumped 40 Bbls of 8.33 ppg Desco preflush. 2. Pumped 72 Bbls (352 sx) of Class "G" cement with .8% D-19 + .25% R-5 + .1% D-6. 3. Displaced with 358 Bbls of 10.2 ppg brine. NOTE: Lost circulation. Centralizers: 1 per 40' 9430' - 7597' 1 per 80' 3000' - Surface 7" x 9 5/8" Annulus (04/02/85) 1. Pumped 25 Bbls fresh water. 2. Pumped 30 Bbls (180 sx) Arctic Set I cement. 3. Displaced with 60 Bbls Arctic Pack. 8. RIH WITH THE ELECTRIC SUBMERSIBLE PUMP NO FASTER THAN 30' PER MINUTE. MAINTAIN SUFFICIENT HYDRAULIC PRESSURE WHILE RIH TO MAINTAIN VALVES IN THE OPEN POSITION. ATTACH 2 CABLE BANDS PER JOINT. ATTACH ADDITIONAL BANDS ABOVE AND BELOW EACH CABLE SPLICE. SET THE BOTTOM OF THE MOTOR AT DEPTHS SPECIFIED IN THE ATTACHED E.S.P. DATA TABLE. 9. LOCATE PACKER AND CONTROL VALVES NOT LESS THAN 500 FT MD. PIN PACKERS TO BEGIN SETTING AT APPROXIMATELY 1100 PSIG. (IMPORTANT NOTE: THE COMBINED MEASUREMENT OF THE DIAMETERS OF THE #2 ROUND CABLE DIAMETER AND THE SCSSV IS 6.0? INCHES -- THE DRIFT OF THE ?" CASING IS 6.059" (TOO LARGE TO FIT). IT WILL THEREFORE BE NECESSARY TO SPLICE APPROX. 20 FT OF #2 FLAT CABLE TO EXTEND ACROSS THE SCSSV.) 10. RIH WITH "X" PLUG ON WIRELINE AND SET IN THE "X" NIPPLE LOCATED BELOW THE PACKER AND PRESSURE UP TO 1000 PSIG. SET PACKER BY GRADUALLY PRESSURING UP THE TUBING FROM 1000 PSIG TO 2500 PSIG. 11. BLEED OFF THE CONTROL LINE PRESSURE TO CLOSE THE ANNULAR VENT VALVE AND TRSCSSV. PRESSURE THE ANNULUS TO 500 PSIG FOR 10 MINUTES TO TEST THE PACKER AND ANNULAR VENT VALVE. RETRIEVE THE X PLUG ON W/L. IF PRESSURE HOLDS, PROCEED TO STEP 12. IF PRESSURE DOES NOT HOLD, RETRIEVE THE PACKER/TRSCSSV SYSTEM, REPAIR OR REPLACE IT, RIH, RESET, AND RETEST IT. 12. NIPPLE DOWN BOPs, N/U AND TEST WELLHEAD TREE, RIG DOWN WORKOVER RIG, MOVE TO NEXT WELL. THIS PROCEDURE IS IN ACCORDANCE WITH AN EARLIER PROCEDURE WHICH WAS: PREPARED BY STEVE ROSSBERG, SENIOR PRODUCTION ENGINEER (3/23/90) REVIEWED BY MARC SHANNON, SUPV. PRODUCTION ENGINEER (3/27/90) APPROVED BY GARY FLOWERS FOR JACK COPELAND, PRODUCTION SUPT. (4/3/90) J.D. POLYA DRILLING FOREMAN Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. B No.10- CONFIDENTIAL (9,436'-Kuparuk River) AFE 10-61-1101 API No. 50-029-21280. Ak. Permit No. 85-17. Elevation: 54' KB. Location: 232' FSL, 848' FWL, Sec. 18, T13N, RllE, Umiat Meridian 02-17-85: Level location for pipe sheds & set same. Hook up heat ducts, electric lines & steam. Route steam throughout rig, slide braceway into position, thaw heaters. Install chute on conveyor, place heaters on hydraulic pumps, set Tioga. Start hydraulics, thaw suction lines from pits. Install Tankco speed head & diverter stack. Hook up fuel line from diesel tank. Hook up skate, begin NU diverter. Knife valves flanges in diverter line found to be warped. Remove flanges & attempt to repair. Thaw mixing hopper lines, hook-up diverter controls. Continuing diverter valve repairs. ACCEPT RIG 0800 hrs. 02-18: NU 10" lines on diverter system. Heat hydril rubber w/steam, install drain lines. Strap HWDP. Mix spud mud. PU BHA & strap same. Mix spud mud. Function test diverter, pressure test to 100 psi. Inspect knife valves, orient & chk. MWD. Drlg. from 107' to 250'. Pull up to make connection pipe stuck @ 220'. Work pipe free. Circ. & condition mud. Drlg. from 250' to 516'. Attempt to survey w/MWD. Electronics package malfunction POOH from 516' & repair same. TIH to 516'. Drlg. from 516' to 1100', survey every 90'. 02-19: Drlg from 1100' to 1348'. Survey, orient & jet every 3 jnts. POOH from 1458' for bit #3. PU new bit, re-orient MWD. RIH slow, break circ. & change saver sub. Drlg. from 1458' to 2588'. Perform wireline survey @ 2588'. Pump pill. POOH for BHA change, chg. jets in bit 3. Check MWD. TIH Brk. circ. 02-20: Drlg. from 2768' to 5305'. Pump slug. POOH from 5305'. PU bit, TIH to 5305'. Drlg. from 5305' to 5368'. 02-21: Drill & survey 5368' to 5552'. Lost pressure downhole. TOOH, Jars backed off, replaced jars. TIH to 2000'. Cut & slip drlg. line. TIH. Break circ. Drill & survey 5552' to 5813'. Short trip 5813' to 5350'. Circ. and cond. hole for logs. TOOH (SLM no corrections). RU Schlumberger. TIH w/DIL-SFL-CNL-LDT-GR. DIL failed at 3000', TOOH. 02-22: Replace DIL, TIH w/DIL-SFL-CNL-LDT-GR to 3890'. Tight spot, could not get tools down past 3890'. TOOH. RD Schlumberger. TIH w/BHA & D.P. to 3890'. Work through tight spot. TIH to 5813', PU Kelly. Circ. & cond. hole. Pump pill. TOOH. RU Schlumberger. TIH w/DIL-SFL-CNL-LDT-GR to 5812'. (Logger TD) Log 5812' to surface. RD Schlumberger. TIH w/BHA. TO©H & lay down BHA. RU to run csg. PU & TIH w/9 5/8" 36# K-55 buttress csg. 147 jts. PU fluted hanger. Landing jt., space out, float shoe at 5789'. Float collar at 5707'. RU cementing head. Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. B No.10- CONFIDENTIAL (9,436'-Kuparuk River) AFE 10-61-1101 API No. 50-029-21280. Ak. Permit No. 85-17. Elevation: 54' KB. Location: 232' FSL, 848' FWL, Sec. 18, T13N, RllE, Umiat Meridian 02-23: RD Weatherford. Circ. & Recip. csg. 15' strokes. RU B.J. Pump 40 bbls Sepiolite spacer; 762 bbls Arctic Set III, 12.2 ppg; 106 bbls Class G w/l% CaC1, & .2% D-6, 15.8 ppg.; 441 bbls displacement mud, 9.8 ppg. Bumped plug w/3000#, floats held, full circ. throughout job. 50 bbls of cement returns. RD BJ, drain diverter. ND diverter, cement at surface. Install speed head, orient valves. Install XO spool & BOP stack. NU choke line, flowline. Change upper rams. Install test plug, pressure test BOP stack, HCR valves, choke line, manifold, Kelly valves 5000 psi. Test hydril 3500 psi. Remove test plug. Install wear bushing. Strap & PU B.H.A. TIH to 5707'. Test csg. 1500 psi - 15 min. Drlg out float equip. 02-24: Drilled out float collar & float shoe & 35' of new hole to 5848'. Perform EMW test. Drill from 5848' to 5878'. Pump pill. TOOH from 5878'. Change bit. PU MWD & Navi-drill and orient MWD. TIH to 5850', wash to BTM, 5850' to 5878'. Drill & survey 5878' to 6726'. Pump pill, TOOH from 6726', unplug 2 jets and unbolt bit. TIH. 02-25: Continue trip in hole to 6726'. Drill & survey 6726' to 8681'. Run single shot survey on wireline. Drill & survey 8681' to 8750'. 02-26: Drill & survey, 8750' to 9412'. Survey & pump pill. Short trip, 9412' to 6700'. Circ. and cond. hole for logs. Pump pill. TOOH from 9412' to surface. Lay down MWD & Navi-drill (S.L.M. No correction) 02-27: RU Schlumberger. TIH w/DIL-SFL-GR-LDT-CNL. Log from 9402' to 5792' w/ DIL; 9376' - 8100' w/LDT; and 9355' to 8100' w/CNT. RD Schlumberger. TIH to csg shoe 5789'. Slip & cut drilling line. TIH to 9412'. Break circ. Drill from 9412' to 9470'. Circ. & cond. hole. TOOH from 9470'; lay down D.P. and B.H.A. Change top rams; RU Weatherford. PU and TIH w/7" 26# L-80 csg., continue to run pipe. 02-28: TIH w/7" 26# L-80 csg., break circ. at 5700' & 7500'. PU csg. hanger Land 7" csg , float collar at 9360' float shoe at 9438' · · ~ Top of ECP's at 9094' & 9194'. Rig down Weatherford, rig up BJ, pump 357 bbls 10.3 ppg mud, no circ. from beginning to end. Pump 40 bbls 8.33 ppg Desco mud sweep; 72 bbls 15.8 ppg Class G w/0.8% D-19, .25% R5; 358 bbls 10.2 ppg NaC1/NaBr. Pressure up to 3500 psi and set ECP's. RD BJ. Test hanger, packoff to 5000 psi. Change out rams to 3 1/2"; try pressure testing csg.; losing pressure. RU Dresser to run Gyro-GR-CCL. TIH to 9348'; Gyro survey 9348' to surface; GR failed and Gyro failed. Repair Gyro and GR. TIH w/Gyro-GR-CCL to 9348'. Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. B No.10- CONFIDENTIAL (9,436'-Kuparuk River) AFE 10-61-1101 API No. 50-029-21280. Ak. Permit No. 85-17. Elevation: 54' KB. Location: 232' FSL, 848' FWL, Sec. 18, T13N, RllE, Umiat Meridian 03-01: Log w/GR-CCL from 9348' to 8800' and run Gyro from 9348' to surface. Pressure test 7" csg. to 2000 psi; pressure loss 650 psi in 30 min. TIH w/wireline & Halliburton EZSV and set at 9346' WLM. Pressure test csg. to 2000 psi; 180 psi drop - 30 min. W.O.S. Make three perforating runs; perf MK-1 & MK-2 from 9008'-9054' & LK-1 from 9282'-9290' w/5" SEQ. Guns; 12 SPF total of 672 shots. TIH w/junk basket & 6.151" gauge on wireline to 9346'. TIH w/Brown "lB" wireline set packer; set top of packer at 9092' WLM. RD Dresser Atlas; RU to run production string. PU and RIH w/Brown "CL" locator, 1 jt. 3 1/2" tbg. and 3-4 1/4" blast & 2 "MMG-2" selective mandrel, continue to run remaining prod. string. 03-02: Continue running completion string. Stab into sealbore of 2-B permanent packer. Run isolation test down 7" annulus; 2 BPM 2200 psi, 14 bbls of 10.2 NaC1/NaBr. No returns up 3 1/2" tbg.; drop 1 3/4" setting ball. Pressure up 3 1/2" tbg. in 500 psi increments to 2500 psi. Set "HB" Packer at 8866'. Increase to 3400 psi. Sheared catcher sub; pull 145,000 shear PBR seal assembly. Space out. Install tbg. hanger. Pump 87 bbls. diesel down tbg. Backflow diesel down 7" annulus until 100 psi drop in tbg. pressure. Land tbg., test annulus to 1500 psi. Held O.K. Lay down landing joint. ND BOP stack, install tree. Final displacement pressure 1700 psi. 03-03: Pressure tested tree to 5000 psi, Set BPV. RIG RELEASED. Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 March 30, 1987 Ms. Fran Jones Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Ms. Jones: Enclosed please find the drilling "well histories" from Conoco's Milne Point Unit wells No. B-9, B-10, and C-7. If you require additional information concerning these well histories, please contact Don Girdler at 564-7637. Yours very truly, E. D. Wilson Sr. Administrative Coordinator DRG/vv B-9, B-10, C-7 RECEIVED vlkR 3 1 1987 Alaska 0il & I~as Cons. Commission Anchorage Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 March 5, 1987 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99510 Dear Mr. Chatterton: Production Profile Logs for Wells B-10; B-ii; C-9; C-13; C-14; C-i5; C-16 Included with this cover letter are the logs and related pressure data for production profile work completed at Milne Point prior to shutdown. This information is submitted to the State as per Rule 9 of the Kuparuk River Field Rules. If you should have any questions or comments, please contact Mr. Don Girdler at 564-7637. ~~T/. R. Painter Division Manager DRG/w Telecopy No. (907) 276-7542 January 14, 1987 Mr. T. R. Painter Division Manager Conoco Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Dear Mr. Painter.. The enclosed Administrative Approval (AA) No. 173.8 dated- December 30, 1986 is a corrected copy that should replace the Administrative Approval No. 173.1, also dated December 30, 1986, which was recently sent to you. Please destroy all copies of AA No. 173.1 of that date. Sorry for this inconvenience, and please call me at 279-1433 should you have any questions. ely, ~ Lonnie C. Smith Commissioner Enclosure LCS :job December 30, 1986 Telecopy No. (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 173.8 Re: Exemptions from Conservation Order No. 173, Rule 9(a), requiring production surveys. Mr. T, R. Painter Divis ion Manager Conoco Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Dear Mr. Painter: We have received your letter of December 12, 1986, in which you requested exemptions to the resuirements of Conservation Order No. 173, Rule 9(a), for Conoco s Milne Point Unit wells B-10, C-I, C-2 and C-7. Due to impending shutdown of production and injection operations at Milne Point Unit (MPU), the Commission agrees that production profiles at this point would not provide data essential for monitoring reservoir depletion. Therefore, the production surveys required by Rule 9(a) of Conservation Order No. 173 for MPU wells B-10, C-I, C-2 and C-7 are suspended. When production operations resume at MPU, then the production surveys for these wells will be required within twelve (12) months after regular production, begins. Sincerely, ~ Lonnie ¢. Smith ¢ ommi s s ioner BY ORDER OF THE COMMISSION jo/3.AA173.8 Tom Painter Division Manager Conoco inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Mitne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Milne Point Unit. There are 19 active and ~ inactive production wells at Mi!ne Point. K ~ ~_n, ~-4A, B-6, B-9, B-10 B-l! 5-13 B-15 5-16 C-l, C-2, C-3, C-4, C-5A, C-7, C-9, C-13, C-14, C-i6 STATIC: x-~ B_~ C-!7 ~ B-20, ~ ~i, ~: ,~-18 Ail active production. ~'ei!s will be freeze protected by displaaing the top 3000' of the tubing with a 1:3 diesel:oil mixture, ihe annular fluid levels will be monitored for !eakin~ gas lift valves, if necessary the production casing annulus will be displaced with a diesel:oil mixture to at !eas[ 3000'. Once the shut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs %~i!1 be installed and all $CSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze pronected with diesel across the permafrost. There are currently ten active and six inactive water injection wells in the Milne Point Unit. F~ E ~._ u i ~ ~ · ~ . ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-ii, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-i; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corresion an inhibiter will be displaced into the well. A 50:50 methanol:water mix will be used to carry the inhibitor° If you have any questions on the shutdo~ procedure please contact Don Girdler at 564-7637. Yours very truly, ~ ~'D~v?sion Manager STATE OF ALASKA ALASt,., OIL AND GAS CONSERVATION COMt, ..,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown _ Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of OPerator 5. Datum elevation (DF or KB) Conoco Inc. 54' KB feet 3' Add,~e2s(~l C Street, Ste. 200, Anchorage, Alaska 99503 6. Uni~,gr, Prol~,erty qaq-l,e .. ~to_±ne roznc unzt: 4. Location of well at surface 232' FSL, 848' FWL, Sec. 18, T13N, RilE, U.M. At top of productive interval 1757' FSL, 4216' FEL, Sec. 13, T13N, R10E, U.M. At effective depth N/A At t~t~IgP~sL, 4461' FEL, Sec. 13, T13N, R10E, U.M. 7. Well number B-10 8. Permit number 85-17 9. APl number 50-- 029-21280 10. Pool Kuparuk River 11. Present well condition summary Total depth: measured true vertical 9470 feet 7280 feet Plugs (measured) Effective depth: measured N/A true vertical feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 16" To Surface 5753' 9 5/8" 868 bbls 94-4' 7" 72 bbls measured true vertical 9008'-9054'; 9282'-9290' 6918'-6954'; 7131'-7137' Tubing (size, grade and measured depth) 3½", L-80, 9105' Measured depth True Vertical depth 115' 115' 5789' 4668' 9438' ~254' ~-~, t.~ ~ Y Oos Coils. ,, ,-;:,o'.... Anchorage Packers and SSSV (type and measured depthT'R' SCSSV @ 1909'; Perm. Pkr. @ 9091; Ret. Pkr @ 8866 12.Attachments Description summary of proposal,~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the f~c, going is true and correct to the best of my knowledge Signed Commission Use Only Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by ,~,. I--, .. i-/~ Commissioner IApproval No. / by order of /.~ 'F~ the commission Date } ,,-/' c~iJ . / Sub~it in triplicate Form 10-403 Rev 12-1-85 Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 12, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Conservation Order No. 173 Rule 9 Conoco requests exemption from Conservation Order No. 173 Rule 9 for Milne Point Unit wells B-10, C-l, C-2, and C-7. These wells are currently being supported by water injection but production and offset injection will be suspended in early 1987. Considering the circumstances, production profiles in these wells can not be justified. If you should have any questions please contact Don Girdler at 564-7637. Division Manager DRG/vv 500.~4 "' '., ' ~-" STATE OF ALASKA '~--" ALASK, ._ ,L AND GAS CONSERVATION C~_ .v'IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~ GAS [] SUSPENDED [] ABANDONED L~ SERVICE [] -2. Name of Operator 7. Permit Number Conoco Inc. 85-17 3. Address 8. APl Number 3201 C Street, Ste., 200, Anchorage, AK 99503 50-029-21280 4. Location of well at surface 9. Unit or Lease Name 232' FSL, 848' FWL, Sec. 18, T13N, RllE, U.M. Milne Point Unit At Top Producing Interval 10. Well Number 1757' FSL, 4216' FEL, Sec. 13, T13N, R10E, U.M. B-10 At Total Depth 11. Field and Pool 1821' FSL, 4461' FEL, Sec. 13, T13N, R10E, U.M. ... Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 59' KB ADL 47437 Kuparuk River . 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 2--17--85 2--26--85 Suspended 3--8--85I ~/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9470'MD(7280') 9360'MD (7193') YES ~ NO [] 1909 feetMD] 1800-+ 22. Type Electric or Other Logs Run D IL- SFL-CNL-LDT-GR/GR-CCL ' GYRO 23. CASING, LINER AND CEMENTING 'RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED q 5/8" 36¢~ K-55 O' .5789' 762 bbls Arctic Set TTI. 106 bbls Class .7" 26¢~ L-80 0' 9438' 72 bbls Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3½" 9091 ' Permanent 9008'-9054' (6918-6954') MK-1 and MK-2 9105' 9282'-9290' (7131-7137') LK-1 8863' Hydraulic 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5" Hollow Carrier 22 gram 12 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas rift, etc.) 11-15-85I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO I 1-14-8( 6 TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 190 1000 24-HOUR RATE I~ 656' 224 276 I 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ',,'~. E ~ iZ l '"..,,f 57 f "¢.-: '..,; ~.,J 0 Form 10-407 Rev. 7-1-80 Alaska 0il&~.~,,~ ~ d~as 00ns. 00[',~;T~,iSJf4b;mit in duplic~ CONTINUED ON REVERSE SIDE ^~,,kp.r,.ri^ -. ... . . : NAME · Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. - I- KA 4695 ' 3924' LA 4910' 4077 ' · 'MA 5034, 4164' NA 5334' '. 4368' 0A - 5532I' 4499' · Lower CretaceoU~ 8761' 6732' un~eonformity Midd'ie Kuparuk 9007' 6917' Lowe'r Kuparuk 9283' 7132' · . . 31. LIST OF ATTACHMENTS __ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in AlaSka.. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. It:em 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 cement- lng and the location of the cementing tool. : Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: if no cores taken, indicate "none". ' Form 10~407 STATE OF ALASKA " ALASKA Oil AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REP'ORT$ ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. u0noco 1nc. 85-17 3'Add~l C Street, Suite 200, Anchorage, Alaska 99503 4. Location of Well 232' FSL, 848' FWL, Sec. 18, T13N, RllE, U.H. 6. Lease Designation and Serial No. 47437 5. Elevation in feet (indicate KB, DF, etc.) 59' KB 8. APl Number 50-029-21280 9. Unit or Lease Name MilBe Point Unit 10. Well Number . B'IQ 11. Field and Pool Kuparuk River 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105,170). This well was brought on as an oil producing well on 11-12-85, and its suspended status should be removed. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. S i g n~"~~///--'2--~,,~ ~~- ~ Title The space ~//IzSw for Commission use Conditions~of Approval, if any: Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 October 24, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached is a Sundry Notice for the Milne Point B-10 well. intends to stimulate the above referenced well. If you have any questions, please call Don Girdler at 564-7637. R. J. ;r~ncis Manager-Engineering Conoco DRG/vv cc: MPU B-10 File STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. CONOCO, INC. 85-17 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, AK 99503 50- 029-21280 4. Location of Well 232 ' FSL, 848' FWL, Sec. 18, TI3N, RllE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point B-10 11. Field and Pool Kuparuk River 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Because of iow productivity (50± BOPD) well with a matrix acid treatment. 1985. Conoco proposes to stimulate the B-10 The job is scheduled for October 23, VERBAL APPROVAL WAS GIVEN BY'MR. CHATTERON 10-22-85. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sr. Production Signed Title The space below for Commission use Engineer Date 10-23-85 Conditions of Approval, if any: ORIG~NAL SIGNED BY iIAltItY W. KIIGLER Approved by COMMISSIONER Approved Copy ~,tuTned/ By Order of the Commission Date Form 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 October 11, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed please find the "Well Completion" forms #10-407 from Conoco's Milne Point Unit wells No..~CFP-1, CFP-2, B-5A, B-6, B-7, B-8, B-9, B-10, B-il, B-12, B-13, B-14, B-15, and B-16. If you require additional information concerning these completion forms, please contact Jim Hand at 564-7640. Very truly yours, ~hn R. Kemp /~anager of Alaska Operations lb RECEIVED Alaska 0il & Gas Cons, Commisslo~ Anchorage ~-- STATE OF ALASKA ALASK~ L AND GAS CONSERVATION CL MISSION 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 CONOCO, INC. 85-17 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 50-029-21280 4. Location of well at surface 9. Unit or Lease Name 232' FSi, 848' FWL, Section 18, T13N, RllE, U.M. Milne Point Unit At Top Producing Interval 10. Well Number 1757' FSi, 4216' FEL, Section 13, T13N, R10E, U.M. B No. lO At Total Depth 1 1. Field and Pool 1821' FSi, 4461' FEL, Section 13, T13N, R10E, U.M. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 59' KB ADL 47437 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 2/17/85 2/26/85 Suspended 3/8/85I N/A feet MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ l-VD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9470 ' ~D (7280') 9360' MD (7193 ' ) YES [] NO [] 1909 feet MD 1800+ 22. Type Electric or Other Logs Run DI L- SFL-CNL-LDT-GR/GR-CCL-GYRO 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE ITOP BOTTOM HOLE SIZE CEMENTING RECORD 'AMOUNT PULLED 9-5/8" 36# K-55 0' 5789' 762 bbls Arctic Set III, 106 bbls Class G 7" 26# L-80 0' 9438' 72 bbls Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9105 ' 9091 ' Permanent 9008'-9054' (6918-6954') MK1 and MK2 8863' Hydraulic 9282 ' -9290 ' (7131-7137 ' ) LK1 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. -' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 5" Hollow Carrier 22 gram 12 spf None 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED,1~ 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 Alaska 0il & Gas Cons. Commission Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE :· ':: ' ' --: 'GEOLOGIC' -:" ' MARKERS: .... .... ' : '"::-:'"' .... '" '~ ."i~ !-;~ -~i:. :'.::i.-'i .' :!': . ' . -.FORMA2FiON TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KA 4695 ' 3924 ' LA 4910 ' 4077 ' MA 5034 ' 4164 ' NA 5334 ' 4368' OA 5532 ' 4499 ' Lower Cret. 8761' 6732' Unconformity Middle Kuparuk 9007' 6917' Lower Kuparuk 9283 ' 7132 ' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.. Title Date INSTRUCTIONS General' This form is designed for submitting a cOmplete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). . Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". B.P. EXPLORATION B PAD, WELL NO. MPB-10 MILNE POINT FIELD, ALASKA Gyro Continuous Multishot Survey Inside 3.5"TUBING Survey date: 26- MAY, 2001 Job number · AK0501GCE508 CONTENTS JOB NUMBER: AK0501GCE508 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. INRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION , SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER' AK0501GCE508 Tool 968 was run in WELL# MPB-10 on SCHLUMBERGER 7/32" wireline inside 3.5" TUBING. The survey was completed without any problems. SURVEY CERTIFICATION SHEET JOB NUMBER' AK0501GCE508 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 :- WALTER KILEY OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: AK0501GCE508 CLIENT: B.P. EXPLORATION RIG: SCHLUMBERGER LOCATION: B PAD WELL: MPB-10 LATITUDE: 70.45 N LONGITUDE: 149.2 ~W SURVEY DATE: SURVEY TYPE : 26 - MAY, 2001 GYRO CONTINUOUS DEPTH REFERENCE: ROTARY TABLE ELEVATION 59.00' MAX. SURVEY DEPTH: 9000' SURVEY TIED ONTO: NA SURVEY INTERVAL: 0-9000' APl NUMBER: TARGET DIRECTION: 050-029-21280 287.50 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. INRUN SURVEY LISTING A Gyrodata Directional Survey for B.P. Exploration Well: MPB-10, 3.5" TBG Location: B PAD, MILNE POINT FIELD, ALASKA Job Number: AK0501GCE508 Run Date: 5/26/01 8:38:30 AM Surveyor: Tom Stoddard Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.450000 deg. N Sub-sea Correction from Vertical Reference: Azimuth Correction: Gyro: Bearings are Relative to True North 59.00 fi. Proposed Well Direction: 287.500 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference B.P. Exploration Well: MPB-10, 3.5" TBG Location: B PAD, MILNE POINT FIELD, ALASKA Job Number: AK0501GCE508 MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 0.0 0.00 0.00 0.00 100.0 0.41 308.82 0.41 200.0 0.24 323.83 0.19 300.0 0.51 312.13 0.27 400.0 0.81 308.23 0.30 500.0 2.65 285.60 1.93 600.0 4.57 282.36 1.93 700.0 6.45 281.28 1.88 800.0 8.05 280.23 1.60 900.0 9.46 280.51 1.41 1000.0 11.19 281.10 1.73 1100.0 12.55 280.27 1.37 1150.0 13.52 281.03 1.98 1200.0 15.36 281.12 3.69 1250.0 16.86 280.81 2.99 1300.0 18.10 280.20 2.52 1350.0 19.68 278.97 3.26 1400.0 20.64 278.18 1.99 1450.0 21.32 278.06 1.37 1500.0 22.12 278.94 1.73 1550.0 22.91 280.01 1.78 1600.0 23.99 280.74 2.22 1650.0 25.05 281.00 2.14 1700.0 26.11 281.19 2.12 1750.0 26.93 281.33 1.66 1800.0 27.39 281.31 0.92 A Gyrodata Directional Survey VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet CLOSURE DIST. AZIMUTH feet deg. 0.0 -59.0 0.0 ! 00.0 41.0 0.3 200.0 141.0 0.8 300.0 241.0 1.4 400.0 341.0 2.5 0.0 0.0 0.4 308.8 0.9 312.2 1.6 313.7 2.7 312.0 499.9 440.9 5.4 5.6 599.7 540.7 11.7 11.8 699.3 640.3 21.3 21.3 798.5 739.5 33.8 33.8 897.3 838.3 48.9 49.0 995,7 936.7 66.7 66.9 1093,5 1034.5 87.1 87.5 1142.3 1083.3 98.3 98.7 1190.7 1131.7 110.7 111.2 1238.7 1179.7 124.5 125.1 1286.4 1227.4 139.4 140.1 1333.7 1274.7 155.4 156.3 1380.6 1321.6 172.4 173.5 1427.3 1368.3 190.1 191.4 1473.8 1414.8 208.4 209.9 1520.0 1461.0 227.3 229.0 1565.8 1506.8 247.1 248.9 1611.3 1552.3 267.7 269.7 1656.4 1597.4 289.1 291.2 1701.2 1642.2 311.3 313.6 1745.6 1686.6 334.0 336.4 300.9 291.7 287.2 284.8 283.4 282.7 282.2 282.1 282.0 281.8 281.7 281.5 281.2 280.9 280.7 280.6 280.6 280.6 280.6 280.7 280.7 HORIZONTAL COORDINATES feet 0.00 N 0.22 N 0.62 N 1.08 N 1.82 N 2.87 N 4.35 N 6.30 N 8.64 N 11.38 N 14.75 N 18.55 N 20.64 N 23.04 N 25.67 N 28.41 N 31.10 N 33.66 N 36.19 N 38.93 N 42.09 N 45.67 N 49.58 N 53.74 N 58.10 N 62.58 N 0.00 E 0.28W 0.68W 1.13W 2.01W 4.80W 10.92W 20.32W 32.72W 47.68W 65.28W 85.49W 96.57W 108.80W 122.42W 137.19W 153.15W 170.19W 187.92W 206.22W 225.11W 244.68W 265.05W 286.24W 308.13W 330.52W B.P. Exploration Well: MPB-10, 3.5" TBG Location: B PAD, MILNE POINT FIELD, ALASKA Job Number: AK0501GCE508 MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 1850.0 27.73 281.28 0.67 1900.0 28.20 280.82 1.03 1950.0 29.08 279.18 2.37 2000.0 29.96 278.35 1.93 A Gyrodata Directional Survey VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet 1790.0 1731.0 357.0 1834.1 1775.1 380.3 1878.0 1819.0 404.1 1921.5 1862.5 428.4 2050.0 30.55 278.26 1.19 1964.7 1905.7 453.3 2100.0 31.49 278.27 1,87 2007.6 1948.6 478.7 2150.0 32.91 278.25 2.84 2049.9 1990.9 505.0 2200.0 34.06 278.40 2.30 2091.6 2032.6 532.3 2250.0 35.10 278.57 2.10 2132.7 2073.7 560.3 2300.0 36.32 278.59 2.43 2350.0 37.49 278.67 2.36 2400.0 38.87 279.11 2.80 2450.0 40.27 279.70 2.90 2500.0 41.38 280.02 2.26 2550.0 42.10 280.10 1.46 2600.0 42.47 280.74 1.12 2650.0 42.91 281.34 1.21 2700.0 43.46 281.75 1.22 2750.0 43.68 281.95 0.53 CLOSURE DIST. AZIMUTH feet deg. 359.5 280.8 383.0 280.8 406.9 280.7 431.6 280.6 456.7 482.5 509.1 536.7 565.0 2173.3 2114.3 589.1 594.2 2213.3 2154.3 618.8 624.2 2252.6 2193.6 649.3 655.1 2291.2 2232.2 680.9 687.0 2329.0 2270.0 713.3 719.6 2366.3 2307.3 746.3 752.9 2403.3 2344.3 779.7 786.6 2440.0 2381.0 813.3 820.5 2476.5 2417.5 847.4 854.7 2512.7 2453.7 881.7 889.1 2800.0 43.17 282.51 1.28 2549.0 2490.0 915.9 2850.0 42.97 283,17 0.98 2585.6 2526.6 949.9 2900.0 43.25 283.34 0.60 2622.1 2563.1 984.0 2950.0 43.43 283.37 0.36 2658.4 2599.4 1018.2 3000.0 43.20 283.45 0.47 2694.8 2635.8 1052.5 3050.0 42.83 283.67 0.80 3100.0 42.78 283.91 0.34 923.5 957.6 991.7 1026.0 1060.2 2731.4 2672.4 1086.5 1094.3 2768.1 2709.1 1120.4 1128.2 280.5 280.4 280.3 280.2 280.1 280.0 279.9 279.9 279.9 279.9 279.9 279.9 279.9 280.O 280.1 280.2 280.3 280.4 280.5 280.6 280.6 280.7 HORIZONTAL COORDINATES feet 67.11N 71.60 N 75.76 N 79.51N 83.15 N 86.85 N 90.68 N 94.68 N 98.86 N 103.22 N 107.72 N 112.50 N 117.71N 123.30 N 129.12 N 135.20N 141.70 N 148.55 N 155.62 N 162.90 N 170.49 N 178.33 N 186.25 N 194.21N 202.21N 210.31N 353.20W 376.21 W 399.81W 424.16W 449.09W 474.59W 500.95 W 528.25W 556.31 W 585.17W 614.85W 645.39W 676.80W 709.01 W 741.78W 774.87W 808.14W 841.67W 875.40W 908.99W 942.28W 975.54W 1008.93W 1042.30W 1075.46W 1108.46 W B.P. Exploration Well: MPB- I 0, 3.5" TBG Location: B PAD, MILNE POINT FIELD, ALASKA Job Number: AK0501GCE508 A Gyrodata Directional Survey MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE DEPTH SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet feet deg. 100 ft. 3150.0 42.34 284.12 0.92 3200.0 41.92 284.71 1.17 3250.0 41.47 285.52 1.39 HORIZONTAL COORDINATES feet 2804.9 2745.9 1154.1 1162.0 280.8 218.50 N 2842.0 2783.0 1187.6 1195.5 280.9 226.84 N 2879.3 2820.3 1220.9 1228.6 281.1 235.52 N 3300.0 41.35 286.05 0.74 2916.8 2857.8 1253.9 3350.0 41.68 286.33 0.75 2954.2 2895,2 1287.1 3400.0 42.12 286.41 0.89 2991.5 2932.5 1320.4 3450.0 42.14 286.70 0.39 3028.5 2969.5 1354.0 3500.0 42.42 287.26 0.93 3065.5 3006.5 1387.6 1261.6 281.2 1294.6 281.3 1327.9 281.4 1361.3 281.6 1394.8 281.7 3102.2 3043.2 1421.6 1428.5 3138.5 3079.5 1456.0 1462.7 3174.5 3115.5 1490.6 1497.1 3210.2 3151.2 1525.6 1531.9 3245.5 3186.5 1561.1 1567.1 3550.0 43.15 288.57 2.31 3600.0 43.77 289.11 1.44 3650.0 44.10 289.09 0.65 3700.0 44.82 289.05 1.45 3750.0 45.49 289.11 1.35 3800.0 45.49 289.34 0.33 3280.5 3221.5 1596.7 3850.0 46.03 289.43 1.08 3315.4 3256.4 1632.5 3900.0 46.31 289.57 0.59 3350.0 3291.0 1668.6 3950.0 46.22 289.67 0.23 3384.6 3325.6 1704.7 4000.0 46.05 289.46 0.46 3419.3 3360.3 1740.7 1602.5 1638.1 1673.9 1709.8 1745.6 4050.0 45.95 289.28 0.32 3454,0 3395.0 1776.6 4100.0 45.76 289.19 0.40 3488.8 3429.8 1812.5 4150.0 45.35 289.30 0.84 3523.8 3464.8 1848.2 4200.0 45.42 289.57 0.42 3558.9 3499.9 1883.7 4250.0 45.09 289.92 0.84 3594.1 3535.1 1919.2 1781.4 1817.1 1852.6 1888.0 1923.3 3629.5 3570.5 1954.6 1958.5 3664.9 3605.9 1989.8 1993.5 3700.5 3641.5 2024.9 2028.4 281.8 282.0 282.2 282.3 282.5 282.6 282.8 282.9 283.1 283.2 283.3 283.4 283.5 283.7 283.8 283.9 284.0 284.1 4300.0 44.94 290.05 0.35 4350.0 44.75 290.13 0.40 4400.0 44.45 290.18 0.60 244.51N 253.75 N 263.16 N 272.72 N 282.54 N 292.99 N 304.10 N 315.46 N 326.90 N 338.48 N 350.22 N 362.11N 374.15 N 386.28 N 398.35 N 410.28 N 422.10 N 433.87 N 445.71 N 457.71 N 469.79 N 481.90 N 494.00 N 1141.27W 1173.75W 1205.86W 1237.68W 1269.51W 1301.54W 1333.69W 1365.86W 1398.18W 1430.73W 1463.51W 1496.60W 1530.11W 1563.78W 1597.56W 1631.56W 1665.59W 1699.56W 1733.49W 1767.37W 1801.07W 1834.63W 1868.06W 1901.29W 1934.40W 1967.36W B.P. Exploration Well: MPB-10, 3.5" TBG Location: B PAD, MILNE POINT FIELD, ALASKA Job Number: AK0501GCE508 MEASURED I N C L AZIMUTtt DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 4450.0 44.20 290.39 0.58 4500.0 43.96 290.63 0.58 4550.0 43.86 290.79 0.31 4600.0 43.81 291.09 0.42 4650.0 43.84 291.45 0.50 4700.0 44.14 291.97 0.94 4750.0 44.45 292.38 0.85 4800.0 44.93 292.92 1.23 4850.0 45.59 293.54 1.58 4900.0 45.91 294.04 0.96 4950.0 46.14 294.47 0.77 5000.0 46.00 294.81 0.56 5050.0 46.64 294.96 1.31 5100.0 46.47 294.82 0.41 5150.0 46.76 295.19 0.80 5200.0 47.65 296.02 2.15 5250.0 47.85 297.20 1.79 5300.0 48.16 298.42 1.92 5350.0 48.52 299.45 1.70 5400.0 48.61 299.79 0.55 5450.0 48.88 299.89 0.55 5500.0 48.86 299.95 0.10 A Gyrodata Directional Survey VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 3736.3 3677.3 2059.8 2063.2 284.2 506.11 N 3772.2 3713.2 2094.5 2097.7 284.3 518.30 N 3808.2 3749.2 2129.1 2132.2 284.4 530.56 N 3844.3 3785.3 2163.7 2166.6 284.5 542.94 N 3880.4 3821.4 2198.2 2201.0 284.6 555.49 N 3916.4 3857.4 2232.9 2235.5 284.7 568.34 N 3952.1 3893.1 2267.7 2270.1 284.8 581.51N 3987.7 3928.7 2302.7 4022.9 3963.9 2338.0 4057.8 3998.8 2373.6 4092.5 4033.5 2409.3 4127.2 4068.2 2445.1 4161.7 4102.7 2480.9 4196.1 4137.1 2516.9 4230.4 4171.4 2553.0 4264.4 4205.4 2589.3 4298.0 4239.0 2625.8 4331.5 4272.5 2662.4 4364.7 4305.7 2699.0 4397.8 4338.8 2735.6 4430.8 4371.8 2772.4 4463.7 4404.7 2809.1 2304.9 285.0 2340.1 285.1 2375.5 285.2 2411.0 285.4 2446.6 285.5 2482.3 285.6 2518.1 285.8 2554.0 285.9 2590.1 286.0 2626.5 286.2 2662.9 286.3 2699.4 286.5 2735.9 286.7 2772.5 286.9 2809.2 287.0 2846.0 287.2 2882.7 287.4 2919.5 287.5 2956.3 287.7 5550.0 48.95 300.19 0.40 4496.5 4437.5 2845.9 5600.0 48.93 300.38 0.30 4529.4 4470.4 2882.7 5650.0 49.13 300.66 0.57 4562.2 4503.2 2919.5 5700.0 49.20 300.83 0.29 4594.9 4535.9 2956.3 595.06 N 609.07 N 623.51 N 638.29 N 653.30 N 668.52 N 683.80 N 699.16 N 715.02 N 731.59 N 748.93 N 767.00 N 785.53 N 804.23 N 823.02 N 841.90 N 860.91N 880.09 N 899.42 N 2000.13W 2032.71W 2065.15W 2097.49W 2129.75W 2162.01W 2194.35W 2226.80W 2259.44W 2292.21W 2325.01W 2357.74W 2390.54W 2423.47W 2456.40W 2489.49W 2522.58W 2555.45W 2588.14W 2620.73W 2653.33W 2685.97W 2718.58W 2751.14W 2783.66W 2816.17W B.P. Exploration Well: MPB-10, 3.5" TBG Location: B PAD, MILNE POINT FIELD, ALASKA Job Number: AK0501GCE508 A Gyrodata Directional Survey MEASURED I N C L AZIMUTIt DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE DEPTH SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet feet deg. 100 fl. 5750.0 49.00 300.89 0.41 5800.0 48.60 300.63 0.89 5850.0 48.60 300.34 0.44 5900.0 48.85 299.57 1.27 5950.0 49.06 297.98 2.43 6000.0 49.15 297.39 0.90 6050.0 49.06 296.67 1.10 6100.0 49.03 295.82 1.29 6150.0 49.08 295.76 0.14 6200.0 48.88 294.20 2.39 6250.0 49.06 292.72 2.25 6300.0 48.85 292.33 0.72 6350.0 48.41 291.15 i.98 6400.0 47.95 289.53 2.59 6450.0 47.70 289.25 0.65 6500.0 47.63 288.63 0.93 6550.0 47.07 286.90 2.79 6600.0 46.82 285.92 1.51 6650.0 46.90 285.64 0.45 6700.0 47.16 285.71 0.52 6750.0 47.27 285.65 0.25 6800.0 47.34 285.44 0.35 6850.0 47.20 285.30 0.35 6900.0 47.14 285.22 0.16 6950.0 47.17 285.23 0.07 7000.0 47.01 285.23 0.33 4627.6 4568.6 2993.1 2993.1 287.9 HORIZONTAL COORDINATES feet 918.81N 4660.5 4601.5 3029.7 3029.8 288.0 938.05 N 4693.6 4634.6 3066.2 3066.4 288.2 957.08 N 4726.6 4667.6 3102.9 3103.2 288.3 975.84 N 4759.4 4700.4 3139.9 3140.3 288.5 993.99N 4792.1 4733.1 3177.1 3177.6 288.6 1011.55 N 3215.0 288.7 3252.5 288.7 3290.0 288.8 3327.5 288.9 3365.1 289.0 4824.9 4765.9 3214.4 4857.7 4798.7 3251.7 4890.4 4831.4 3289.1 4923.2 4864.2 3326.5 4956.1 4897.1 3364.0 4988.9 4929.9 3401.5 3402.7 289.0 5021.9 4962.9 3439.0 3440.2 289.0 5055.3 4996.3 3476.2 3477.4 289.0 5088.9 5029.9 3513.2 3514.5 289.0 5122.5 5063.5 3550.2 3551.4 289.0 5156.4 5097.4 3586.9 5190.5 5131.5 3623.5 5224.7 5165.7 3659.9 5258.8 5199.8 3696.5 5292.8 5233.8 3733.2 3588.2 289.0 3624.7 289.0 3661.1 289.0 3697.7 288.9 3734.3 288.9 5326.7 5267.7 3769.9 3771.0 288.9 5360.6 5301.6 3806.6 3807.6 288.8 5394.6 5335.6 3843.2 3844.2 288.8 5428.6 5369.6 3879.9 3880.8 288.8 5462.6 5403.6 3916.5 3917.4 288.7 1028.73 N 1045.43 N 1061.86 N 1077.79 N 1092.80 N 1107.25 N 1121.15 N 1134.10 N 1146.40 N 1158.40 N 1169.62 N 1179.94 N 1189.86 N 1199.75 N 1209.67 N 1219.51N 1229.25 N 1238.90 N 1248.53 N 1258.15 N 2848.61W 2880.94W 2913.26W 2945.82W 2978.87W 3012.34W 3046.01W 3079.87W 3113.88W 3148.07W 3182.67W 3217.50W 3252.35W 3287.29W 3322.24W 3357.20W 3392.22W 3427.27W 3462.38W 3497.60W 3532.93W 3568.34W 3603.76W 3639.13W 3674.51W 3709.84W B.P. Exploration Well: MPB- 10, 3.5" TBG Location: B PAD, MILNE POINT FIELD, ALASKA Job Number: AK0501GCE508 A Gyrodata Directional Survey MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE DEPTH SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet feet deg. 100 fl. HORIZONTAL COORDINATES feet 7050.0 46.91 285.20 0.20 5496.8 5437.8 3953.0 7100.0 46.73 285.23 0.36 5531.0 5472.0 3989.4 7150.0 46.47 285.31 0.53 5565.3 5506.3 4025.7 7200.0 46.37 285.41 0.26 5599.8 5540.8 4061.9 7250.0 46.26 285.55 0.30 5634.3 5575.3 4098.0 7300.0 46.17 285.56 0.17 7350.0 46.07 285.53 0.21 7400.0 45.82 285.39 0.54 7450.0 45.69 284.98 0.65 7500.0 45.55 284.83 0.35 7550.0 45.55 284.85 0.03 7600.0 45.40 284.72 0.35 7650.0 45.19 284.67 0.42 7700.0 45.06 284.57 0.31 7750.0 45.42 284.15 0.95 3953.9 288.7 3990.2 288.7 4026.5 288.6 4062.7 288.6 4098.8 288.6 5668.9 5609.9 4134.1 4134.8 288.6 5703.6 5644.6 4170.1 4170.8 288.5 5738.3 5679.3 4206.1 4206.7 288.5 5773.2 5714.2 4241.8 4242.5 288.5 5808.2 5749.2 4277.5 4278.1 288.4 5843.2 5784.2 4313.2 5878.3 5819.3 4348.8 5913.5 5854.5 4384.3 5948.7 5889.7 4419.7 5983.9 5924.9 4455.1 7800.0 45.79 283.91 0.81 6018.9 5959.9 4490.8 7850.0 45.61 283.89 0.35 6053.8 5994.8 4526.5 7900.0 45.51 283.89 0.21 6088.9 6029.9 4562.1 7950.0 45.54 283.82 0.12 6123.9 6064.9 4597.7 8000.0 45.38 283.74 0.34 6159.0 6100.0 4633.3 8050.0 45.51 283.77 0.26 6194.0 6135.0 4668.9 8100.0 45.54 283.77 0.05 6229.1 6170.1 4704.5 8150.0 45.51 283.72 0.09 6264.1 6205.1 4740.1 8200.0 45.43 283.64 0.19 6299.2 6240.2 4775.6 8250.0 45.23 283.44 0.49 6334.3 6275.3 4811.1 4313.7 288.4 4349.3 288.4 4384.8 288.4 4420.1 288.3 4455.6 288.3 4491.2 288.3 4526.9 288.2 4562.5 288.2 4598.0 288.2 4633.6 288.1 4669.1 288.1 4704.7 288.1 4740.3 288.0 4775.8 288.0 4811.2 288.0 1267.74 N 1277.31N 1286.87 N 1296.47 N 1306.12 N 1315.80 N 1325.46 N 1335.03 N 1344.42 N 1353.61N 1362.75 N 1371.85 N 1380.86 N 1389.80 N 1398.61N 1407.27 N 1415.86 N 1424.43 N 1432.97 N 1441.46 N 1449.93 N 1458.42 N 1466.90 N 1475.33 N 1483.65 N 3745.10W 3780.29W 3815.33W 3850.26W 3885.10W 3919.88W 3954.60W 3989.24W 4023.80W 4058.34W 4092.84W 4127.30W 4161.68W 4195.96W 4230.35W 4265.01W 4299.75W 4334.40W 4369.04W 4403.66W 4438.27W 4472.92W 4507.57W 4542.21W 4576.78W A Gyrodata Directional Survey B.P. Exploration Well: MPB-10, 3,5" TBG l.ocatmn, lgPAl) MII.NI:I'()iN'I'FIIiI,I),AI.ASKA Job Number: AK0501GCE508 MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE I)EI'Tll SEVERITY DEPTii DEPTII SECTION DIST. AZIMIJTII feet deg. deg. deg./ feet feet feet feet deg. 100 ft. 8300.0 45.09 283.32 0.33 8350.0 44.87 283.20 0.47 8400.0 44.78 282.98 0.36 8450.0 44.55 283.02 0.44 8500.0 43.98 283.48 1.32 6369.6 6310.6 4846.5 4846.6 287.9 6404.9 6345.9 4881.7 4881.8 287.9 6440.4 6381.4 4916.8 4916.9 287.9 6476.0 6417.0 4951.9 4952.0 287.8 6511.8 6452.8 4986.7 4986.8 287.8 8550.0 43.40 283.73 1.22 8600.0 42.94 283.44 1.00 8650.0 42.67 282.97 0.83 8700.0 42.41 283.24 0.62 8750.0 42.03 283.50 0.85 6547.9 6488.9 5021.1 6584.4 6525.4 5055.3 6621.1 6562.1 5089.1 6657.9 6598.9 5122.9 6694.9 6635.9 5156.4 5021.2 287.8 5055.3 287.7 5089.2 287.7 5122.9 287.7 5156.4 287.6 8800.0 41.96 283.29 0.33 8850.0 41.58 283.19 0.77 8900.0 40.92 283.27 1.32 8950.0 40.27 283.36 1.31 9000.0 40.14 283.47 0.29 6732.1 6673.1 5189.7 6769.4 6710.4 5222.9 6807.0 6748.0 5255.8 6845.0 6786.0 5288.3 6883.1 6824.1 5320.5 5189.7 287.6 5223.0 287.6 5255.8 287.6 5288.3 287.5 5320.5 287.5 Final Station Closure: Distance: 5320.47 ft Az: 287.51 deg. HORIZONTAL COORDINATES feet 1491.86 N 1499.97 N 1507.95 N 1515.86 N 1523.85 N 1531.98 N 1540.01N 1547.77 N 1555.43 N 1563.20 N 1570.95 N 1578.58 N 1586.12 N 1593.62 N 1601.11N 4611.27W 4645.67W 4680.00W 4714.25W 4748.22W 4781.78W 4815.03 W 4848.11 W 4881.04 W 4913.72W 4946.27W 4978.69W 5010.78W 5042.44W 5073.84W A Gyrodata Directional Survey Job Number: AK0501GCE508SS Run Date: 5/26/01 8:38:30 AM Surveyor: Tom Stoddard Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.450000 deg. N Sub-sea Correction from Vertical Reference: Azimuth Correction: Gyro: Bearings are Relative to True North for B.P. Exploration Well: MPB~I0, 3.5" TBG Location: B PAD, MILNE POINT FIELD, ALASKA 59.00 fl. Proposed Well Direction: 287.500 deg Vertical Section Calculated from Well }lead Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference B.P. Exploration \Veil: MPP,-I(I..~, 5" TB(i Location: B PAD, MILNE POINT FIELD, ALASKA Job Number: AK0501GCES08SS S1 iBSi..A I N (' I. AZIMII'I'il DEPTH SEVERITY feet deg. deg. deB./ 100 ft. -59.0 0.00 0.00 0.00 41.0 0.41 308.82 0.41 141.0 0.24 323.83 0.19 241.0 0.51 312.13 0.27 341.0 0.81 308.23 0.30 440.9 2.65 285.60 1.93 540.7 4.57 282.36 1.93 640.3 6.45 281.28 1.88 739.5 8.05 280.23 1.60 838.3 9.46 280.51 1.41 936.7 11.19 281.10 1.73 1034.5 12.55 280.27 1.37 1083.3 13.52 281.03 1.98 1131.7 15.36 281.12 3.69 1179.7 16.86 280.81 2.99 1227.4 18.10 280.20 2.52 1274.7 19.68 278.97 3.26 1321.6 20.64 278.18 1.99 1368.3 21.32 278.06 1.37 1414.8 22.12 278.94 1.73 A Gyrodata Directional Survey VER'I'ICAIJ VERTICAl. CLOSURE DEPTIt SECTION DIST. AZIMUTH feet feet feet deg. 0.0 0.0 0.0 0.0 100.0 0.3 0.4 308.8 200.0 0.8 0.9 312.2 300.0 1.4 1.6 313.7 400.0 2.5 2.7 312.0 499.9 5.4 5.6 300.9 599.7 11.7 11.8 291.7 699.3 21.3 21.3 287.2 798.5 33.8 33.8 284.8 897.3 48.9 49.0 283.4 995.7 66.7 66.9 282.7 1093.5 87.1 87.5 282.2 1142.3 98.3 98.7 282.1 1190.7 110.7 111.2 282.0 1238.7 124.5 125.1 281.8 1286.4 139.4 140.1 281.7 1333.7 155.4 156.3 281.5 1380,6 172.4 173.5 281.2 1427.3 190.1 191.4 280.9 1473.8 208.4 209.9 280.7 1461.0 22.91 280.01 1.78 1520.0 227.3 229.0 280.6 1506.8 23.99 280.74 2.22 1565.8 247.1 248.9 280.6 1552.3 25.05 281.00 2.14 1611.3 267.7 269.7 280.6 1597.4 26.11 281.19 2.12 1656.4 289.1 291.2 280.6 1642.2 26.93 281.33 1.66 1701.2 311.3 313.6 280.7 1686.6 27.39 281.31 0.92 1745.6 334.0 336.4 280.7 HORIZONTAL COORDINATES feet 0.00 N 0.22 N 0.62 N 1.08 N 1.82 N 2.87 4.35 6.30 8.64 11.38 14.75 18.55 20.64 23.04 25.67 28.41 31.10 33.66 36.19 38.93 42.09 45.67 49.58 53.74 58.10 62.58 N N N N N N N N N N N N N N N N N N N N 0.00 E 0.28W 0.68W 1.13W 2.01W 4.80W 10.92W 20.32W 32.72W 47.68W 65.28W 85.49W 96.57W 108.80W 122.42W 137.19W 153.15W 170.19W 187.92W 206.22W 225.11W 244.68W 265.05W 286.24W 308.13W 330.52W B.P. Exploration Well: MPB- 10, 3.5" TBG Location: B PAD, MILNE POINT FIELD, ALASKA Job Number: AK0501GCE508SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 1731.0 27.73 281.28 0.67 1775.1 28.20 280.82 1.03 1819.0 29.08 279.18 2.37 1862.5 29.96 278.35 1.93 1905.7 30.55 278.26 i.19 1948.6 31.49 278.27 1.87 1990.9 32.91 278.25 2.84 2032.6 34.06 278.40 2.30 2073.7 35.10 278.57 2.10 2114.3 36.32 278.59 2.43 2154.3 37.49 278.67 2.36 2193.6 38.87 279.11 2.80 2232.2 40.27 279.70 2.90 2270.0 41.38 280.02 2.26 2307.3 42.10 280.10 1.46 2344.3 42.47 280.74 1.12 2381.0 42.91 281.34 1.21 2417.5 43.46 281.75 1.22 2453.7 43.68 281.95 0.53 2490.0 43.17 282.51 1.28 2526.6 42.97 283.17 0.98 2563.1 43.25 283.34 0.60 2599.4 43.43 283.37 0.36 2635.8 43.20 283.45 0.47 2672.4 42.83 283.67 0.80 2709.1 42.78 283.91 0.34 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 1790.0 357.0 359.5 280.8 1834.1 380.3 383.0 280.8 1878.0 404.1 406.9 280.7 1921.5 428.4 431.6 280.6 1964.7 453.3 456.7 280.5 2007.6 478.7 482.5 280.4 2049.9 505.0 509.1 280.3 2091.6 532.3 536.7 280.2 2132.7 560.3 565.0 280.1 2173.3 589.1 594.2 280.0 2213.3 618.8 624.2 279.9 2252.6 649.3 655.1 279.9 2291.2 680.9 687.0 279.9 2329.0 713.3 719.6 279.9 2366.3 746.3 752.9 279.9 2403.3 779.7 786.6 279.9 2440.0 813.3 820.5 279.9 2476.5 847.4 854.7 280.0 2512.7 881.7 889.1 280.1 2549.0 915.9 923.5 280.2 2585.6 949.9 957.6 280.3 2622.1 984.0 991.7 280.4 2658.4 1018.2 1026.0 280.5 2694.8 1052.5 1060.2 280.6 HORIZONTAL COORDINATES feet 67.11N 71.60 N 75.76 N 79.51N 83.15 N 86.85 N 90.68 N 94.68 N 98.86 N 103.22 N 107.72 N 112.50 N 117.71 N 123.30 N 129.12 N 135.20 N 141.70N 148.55 N 155.62 N 162.90N 170.49 N 178.33 N 186.25 N 194.21N 2731.4 1086.5 1094.3 280.6 202.21N 2768.1 1120.4 1128.2 280.7 210.31N 353.20W 376.21W 399.81W 424.16W 449.09W 474.59W 500.95W 528.25W 556.31W 585.17W 614.85W 645.39W 676.80W 709.01W 741.78 W 774.87 W 808.14W 841.67W 875.40W 908.99W 942.28W 975.54W 1008.93W 1042.30W 1075.46W 1108.46W B.P. Exploration Well: MPB-10, 3.5" TBG Location: B PAD, MILNE POINT FIELD, ALASKA Job Number: AK0501GCE508SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 2745.9 42.34 284.12 0.92 2804.9 1154.1 1162.0 280.8 2783.0 41.92 284.71 1.17 2842.0 1187.6 1195.5 280.9 2820.3 41.47 285.52 1.39 2879.3 1220.9 1228.6 281.1 2857.8 41.35 286.05 0.74 2895.2 41.68 286.33 0.75 2932.5 42.12 286.41 0.89 2969.5 42.14 286.70 0.39 3006.5 42.42 287.26 0.93 3043.2 43.15 288.57 2.31 3079.5 43.77 289.11 1.44 3115.5 44.10 289.09 0.65 3151.2 44.82 289.05 1.45 3186.5 45.49 289.11 1.35 3221.5 45.49 289.34 0.33 3256.4 46.03 289.43 1.08 3291.0 46.31 289.57 0.59 3325.6 46.22 289.67 0.23 3360.3 46.05 289.46 0.46 3395.0 45.95 289.28 0.32 3429.8 45.76 289.19 0.40 3464.8 45.35 289.30 0.84 3499.9 45.42 289.57 0.42 3535.1 45.09 289.92 0.84 2916.8 1253.9 1261.6 281.2 2954.2 1287.1 1294.6 281.3 2991.5 1320.4 1327.9 281.4 3028.5 1354.0 1361.3 281.6 3065.5 1387.6 1394.8 281.7 3102.2 1421.6 1428.5 281.8 3138.5 1456.0 1462.7 282.0 3174.5 1490.6 1497.1 282.2 3210.2 1525.6 1531.9 282.3 3245.5 1561.1 1567.1 282.5 3280.5 1596.7 1602.5 282.6 3315.4 1632.5 1638.1 282.8 3350.0 1668.6 1673.9 282.9 3384.6 1704.7 1709.8 283.1 3419.3 1740.7 1745.6 283.2 3454.0 1776.6 1781.4 283.3 3488.8 1812.5 1817.1 283.4 3523.8 1848.2 1852.6 283.5 3558.9 1883.7 1888.0 283.7 3594.1 1919.2 1923.3 283.8 3570.5 44.94 290.05 0.35 3629.5 1954.6 1958.5 283.9 3605.9 44.75 290.13 0.40 3664.9 1989.8 1993.5 284.0 3641.5 44.45 290.18 0.60 3700.5 2024.9 2028.4 284.1 HORIZONTAL COORDINATES feet 218.50 N 226.84 N 235.52 N 244.51N 253.75 N 263.16 N 272.72 N 282.54 N 292.99 N 304.10 N 315.46 N 326.90 N 338.48 N 350.22 N 362.11N 374.15N 386.28 N 398.35 N 410.28 N 422.10 N 433.87 N 445.71N 457.71N 469.79N 481.90 N 494.00 N 1141.27W 1173.75W 1205.86W 1237.68W 1269.51W 1301.54W 1333.69W 1365.86W 1398.18W 1430.73W 1463.51W 1496.60W 1530.11W 1563.78W 1597.56W 1631.56W 1665.59W 1699.56W 1733.49W 1767.37W 1801.07W 1834.63W 1868.06W 1901.29W 1934.40W 1967.36W B.P. Exploration Well: MPB-10, 3.5" TBG Location: B PAD, MILNE POINT FIELD, ALASKA Job Number: AK050 i GCE508SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 3677.3 44.20 290.39 0.58 3713.2 43.96 290.63 0.58 3749.2 43.86 290.79 0.31 3785.3 43.81 291.09 0.42 3821.4 43.84 291.45 0.50 3857.4 44.14 291.97 0.94 3893.1 44.45 292.38 0.85 3928.7 44.93 292.92 1.23 3963.9 45.59 293.54 1.58 3998.8 45.91 294.04 0.96 4033.5 46.14 294.47 0.77 4068.2 46.00 294.81 0.56 4102.7 46.64 294.96 1.31 4137.1 46.47 294.82 0.41 4171.4 46.76 295.19 0.80 4205.4 47.65 296.02 2.15 4239.0 47.85 297.20 1.79 4272.5 48.16 298.42 1.92 4305.7 48.52 299.45 1.70 4338.8 48.61 299.79 0.55 4371.8 48.88 299.89 0.55 4404.7 48.86 299.95 0.10 4437.5 48.95 300.19 0.40 4470.4 48.93 300.38 0.30 4503.2 49.13 300.66 0.57 4535.9 49.20 300.83 0.29 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 3736.3 2059.8 2063.2 284.2 3772.2 2094.5 2097.7 284.3 3808.2 2129.1 2132.2 284.4 3844.3 2163.7 2166.6 284.5 3880.4 2198.2 2201.0 284.6 3916.4 2232.9 2235.5 284.7 3952.1 2267.7 2270.1 284.8 3987.7 2302.7 2304.9 285.0 4022.9 2338.0 2340.1 285.1 4057.8 2373.6 2375.5 285.2 4092.5 2409.3 2411.0 285.4 4127.2 2445.1 2446.6 285.5 4161.7 2480.9 2482.3 285.6 4196.1 2516.9 2518.1 285.8 4230.4 2553.0 2554.0 285.9 4264.4 2589.3 2590.1 286.0 4298.0 2625.8 2626.5 286.2 4331.5 2662.4 2662.9 286.3 4364.7 2699.0 2699.4 286.5 4397.8 2735.6 2735.9 286.7 4430.8 2772.4 2772.5 286.9 4463.7 2809.1 2809.2 287.0 4496.5 2845.9 2846.0 287.2 4529.4 2882.7 2882.7 287.4 4562.2 2919.5 2919.5 287.5 4594.9 2956.3 2956.3 287.7 HORIZONTAL COORDINATES feet 506.11N 518.30 N 530.56 N 542.94 N 555.49 N 568.34 N 581.51N 595.06 N 609.07 N 623.51 N 638.29 N 653.3O N 668.52N 683.80 N 699.16N 715.02 N 731.59 N 748.93 N 767.00N 785.53N 804.23N 823.02 N 841.90 N 860.91N 880.09 N 899.42N 2000.13W 2032.71W 2065.15W 2097.49W 2129.75W 2162.01W 2194.35W 2226.80W 2259.44W 2292.21W 2325.01W 2357.74W 2390.54W 2423.47W 2456.40W 2489.49W 2522.58W 2555.45W 2588.14W 2620.73W 2653.33W 2685.97W 2718.58W 2751.14W 2783.66W 2816.17W B.P. Exploration Well: MPB- I 0, 3.5" TBG Location: B PAD, MILNE POINT FIELD, ALASKA Job Number: AK0501GCE508SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 fl. 4568.6 49.00 300.89 0.41 4601.5 48.60 300.63 0.89 4634.6 48.60 300.34 0.44 4667.6 48.85 299.57 1.27 4700.4 49.06 297.98 2.43 4733.1 49.15 297.39 0.90 4765.9 49.06 296.67 1.10 4798.7 49.03 295.82 1.29 4831.4 49.08 295.76 0.14 4864.2 48.88 294.20 2.39 4897.1 49.06 292.72 2.25 4929.9 48.85 292.33 0.72 4962.9 48.41 291.15 1.98 4996.3 47.95 289.53 2.59 5029.9 47.70 289.25 0.65 5063.5 47.63 288.63 0.93 5097.4 47.07 286.90 2.79 5131.5 46.82 285.92 1.51 5165.7 46.90 285.64 0.45 5199.8 47.16 285.71 0.52 5233.8 47.27 285.65 0.25 5267.7 47.34 285.44 0.35 5301.6 47.20 285.30 0.35 5335.6 47.14 285.22 0.16 5369.6 47.17 285.23 0.07 5403.6 47.01 285.23 0.33 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 4627.6 2993.1 2993.1 287.9 4660.5 3029.7 3029.8 288.0 4693.6 3066.2 3066.4 288.2 4726.6 3102.9 3103.2 288.3 4759.4 3139.9 3140.3 288.5 4792.1 3177.1 3177.6 288.6 4824.9 3214.4 3215.0 288.7 4857.7 3251.7 3252.5 288.7 4890.4 3289.1 3290.0 288.8 4923.2 3326.5 3327.5 288.9 4956.1 3364.0 3365.1 289.0 4988.9 3401.5 3402.7 289.0 5021.9 3439.0 3440.2 289.0 5055.3 3476.2 3477.4 289.0 5088.9 3513.2 3514.5 289.0 5122.5 3550.2 3551.4 289.0 5156.4 3586.9 3588.2 289.0 5190.5 3623.5 3624.7 289.0 5224.7 3659.9 3661.1 289.0 5258.8 3696.5 3697.7 288.9 5292.8 3733.2 3734,3 288,9 5326.7 3769.9 3771.0 288.9 5360.6 3806.6 3807.6 288.8 5394.6 3843.2 3844,2 288.8 5428.6 3879.9 3880.8 288.8 5462.6 3916.5 3917.4 288.7 HORIZONTAL COORDINATES feet 918.81N 938.05 N 957.08 N 975.84N 993.99 N 1011.55 N 1028.73 N 1045.43 N 1061.86 N 1077.79 N 1092.80 N 1107.25N 1121.15 N 1134.10N 1146.40 N 1158.40 N 1169.62 N 1179.94 N 1189.86 N 1199.75 N 1209,67 N 1219.51N 1229,25 N 1238,90 N 1248.53N 1258.15 N 2848.61W 2880.94W 2913.26W 2945.82W 2978.87W 3012.34W 3046.01W 3079.87W 3113.88W 3148.07W 3182.67W 3217.50W 3252.35W 3287.29W 3322.24W 3357.20W 3392.22W 3427,27W 3462.38W 3497.60W 3532,93W 3568.34W 3603.76W 3639.13W 3674.51W 3709.84W B.P. Exploration Well: MPB-10, 3.5" TBG Location: B PAD, MILNE POINT FIELD, ALASKA Job Number: AK0501GCE508SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 5437.8 46.91 285.20 0.20 5472.0 46.73 285.23 0.36 5506.3 46.47 285.31 0.53 5540.8 46.37 285.41 0.26 5575.3 46.26 285.55 0.30 5609.9 46.17 285.56 0.17 5644.6 46.07 285.53 0.21 5679.3 45.82 285.39 0.54 5714.2 45.69 284.98 0.65 5749.2 45.55 284.83 0.35 5784.2 45.55 284.85 0.03 5819.3 45.40 284.72 0.35 5854.5 45.19 284.67 0.42 5889.7 45.06 284.57 0.31 5924.9 45.42 284.15 0.95 5959.9 45.79 283.91 0.81 5994.8 45.61 283.89 0.35 6029.9 45.51 283.89 0.21 6064.9 45.54 283.82 0.12 6100.0 45.38 283.74 0.34 6135.0 45.51 283.77 0.26 6170.1 45.54 283.77 0.05 6205.1 45.51 283.72 0.09 6240.2 45.43 283.64 0.19 6275.3 45.23 283.44 0.49 5496.8 3953.0 3953.9 288.7 5531.0 3989.4 3990.2 288.7 5565.3 4025.7 4026.5 288.6 5599.8 4061.9 4062.7 288.6 5634.3 4098.0 4098.8 288.6 5668.9 4134.1 4134.8 288.6 5703.6 4170.1 4170.8 288.5 5738.3 4206.1 4206.7 288.5 5773.2 4241.8 4242.5 288.5 5808.2 4277.5 4278.1 288.4 5843.2 4313.2 4313.7 288.4 5878.3 4348.8 4349.3 288.4 5913.5 4384.3 4384.8 288.4 5948.7 4419.7 4420.1 288.3 5983.9 4455.1 4455.6 288.3 6018.9 4490.8 4491.2 288.3 6053.8 4526.5 4526.9 288.2 6088.9 4562.1 4562.5 288.2 6123.9 4597.7 4598.0 288.2 6159.0 4633.3 4633.6 288.1 6194.0 4668.9 4669.1 288.1 6229.1 4704.5 4704.7 288.1 6264.1 4740.1 4740.3 288.0 6299.2 4775.6 4775.8 288.0 6334.3 4811.1 4811.2 288.0 1267.74N 1277.31N 1286.87N 1296.47 N 1306.12N 1315.80N 1325.46 N 1335.03 N 1344.42 N 1353.61N 1362.75 N 1371.85 N 1380.86 N 1389.80N 1398.61N 1407.27 N 1415.86 N 1424.43 N 1432.97 N 1441.46 N 1449.93N 1458.42 N 1466.90N 1475.33N 1483.65N 3745.10W 3780.29W 3815.33W 3850.26W 3885.10W 3919.88W 3954.60W 3989.24W 4023.80W 4058.34W 4092.84W 4127.30W 4161.68W 4195.96W 4230.35W 4265.01W 4299.75W 4334.40W 4369.04W 4403.66W 4438.27W 4472.92W 4507.57W 4542.21W 4576.78W A Gyrodata Directional Survey B.P. Exploration Well: MPB-10, 3.5" TBG Location: B PAD, MILNE POINT FIELD, ALASKA Job Number: AK0501GCE508SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 6310.6 45.09 283.32 0.33 6345.9 44.87 283.20 0.47 6381.4 44.78 282.98 0.36 6417.0 44.55 283.02 0.44 6452.8 43.98 283.48 1.32 6369.6 4846.5 4846.6 287.9 6404.9 4881.7 4881.8 287.9 6440.4 4916.8 4916.9 287.9 6476.0 4951.9 4952.0 287.8 6511.8 4986.7 4986.8 287.8 6488.9 43.40 283.73 1.22 6525.4 42.94 283.44 1.00 6562.1 42.67 282.97 0.83 6598.9 42.41 283.24 0.62 6635.9 42.03 283.50 0.85 6547.9 5021.1 5021.2 287.8 6584.4 5055.3 5055.3 287.7 6621.1 5089.1 5089.2 287.7 6657.9 5122.9 5122.9 287.7 6694.9 5156.4 5156.4 287.6 6673.1 41.96 283.29 0.33 6710.4 41.58 283.19 0.77 6748.0 40.92 283.27 1.32 6786.0 40.27 283.36 1.31 6824.1 40.14 283.47 0.29 6732.1 5189.7 5189.7 287.6 6769.4 5222.9 5223.0 287.6 6807.0 5255.8 5255.8 287.6 6845.0 5288.3 5288.3 287.5 6883.1 5320.5 5320.5 287.5 Final Station Closure: Distance: 5320.47 fi Az: 287.51 deg. HORIZONTAL COORDINATES feet 1491.86 N 1499.97 N 1507.95 N 1515.86 N 1523.85 N 1531.98 N 1540.01N 1547.77 N 1555.43 N 1563.20 N 1570.95 N 1578.58 N 1586.12 N 1593.62 N 1601.11N 4611.27W 4645.67W 4680.00W 4714.25W 4748.22W 4781.78W 4815.03W 4848.11W 4881.04W 4913.72W 4946.27W 4978.69W 5010.78W 5042.44W 5073.84W 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: AK0501GCE508 TOOL NUMBER: 968 MAXIMUM GYRO TEMPERATURE: 81.00 C MAXIMUM AMBIENT TEMPERATURE: 77.01 C MAXIMUM INCLINATION: 49.20 AVERAGE AZIMUTH: WIRELINE REZERO VALUE: REZERO ERROR/K: 287.51 ADD 10' N/A CALIBRATION USED FOR FIELD SURVEY: CALIBRATION USED FOR FINAL SURVEY: 3637 3637 PRE JOB MASS BALANCE OFFSET CHECK: .45 POST JOB MASS BALANCE OFFSET CHECKf: .56 USED .55 CONTINUOUS CONDITION OF SHOCK WATCHES UPON ARRIVAL AT RIG: UPON COMPLETION OF SURVEY: OK OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING 1981 GYRO 9000 39.75 283.00 6911.97 1524.37 -5059.91 FINAL SURVEY 9000 40.14 283.47 6883.1 1601.1 -5073.8 * Change from field survey results. FUNCTION TEST JOB NUMBER: AK0501GCE508 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. ft 1 2 3 4 5 1100 12.73 12.73 12.73 12.73 12.73 AZIMUTH M.D. ft 1 2 3 4 5 1100 280.77 280.96 280.88 281.01 280.77 5. EQUIPMENT AND CHRONOLOGICAL REPORT DOWNHOLE ELECTRONICS EQUIPMENT REPORT JOB NUMBER: AK0501GCE508 SURFACE ELECTRONICS PRIMARY TOOL No. 968 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 789 GYRO SECTION DATA SECTION POWER SECTION A0167 C0159 C0197 A0084 C0207 C0211 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0527 A0107 A0079 A0166 A0693 A0085 A0029 A0165 WIRELINE COMPANY: SCHLUMBERGER CABLE SIZE: 7/32" RUNNING GEAR 2.25" HOUSING W/WEIGHT BARS AND ECCENTRIC BAR TOTAL LENGTH OF TOOL: 30' MAXIMUM O.D.: 2.25" INCHES TOTAL WEIGHT OF TOOL: 250 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: AK0501GCE508 FRIDAY, 05/25/01 12:30 TO SLOPE 14:00 ~E SLOPE 21:00 CHECK TOOLS, LOAD EQUIPMENT FOR JOB IN A.M. SATURDAY, 05/26/01 07:45 09:00 10:30 11:00 11:30 14:00 14:15 16:30 18:00 20:30 23:00 TO LOCATION ARRIVE LOCATION MU TOOL/RU SCHLUMBERGER PU TOOL/LD TOOL CO SWIVEL/PU TOOL PRESSURE TEST LUBRICATOR, NO TEST CO FLANGE, TEST LUBRICATOR O.K. SURVEY IN TO 9000' SURVEY OUT/ LD TOOL. LEAVE LOCATION PROCESS SURVEY SUNDAY, 05/27/01 09:00 CHECK TOOLS 10:00 RESULTS TO MILNE POINT 13:30 TO ANCHORAGE : ::.. -~ ~.....?? ~.' ,..... ~ .': ~.:.' ::~. -. I .~-~.J~',~,'"... ! ;.~ ::,,"i~.~i ~':';;: ~'_.'- I . '-_.~: ~ ...~o.-"~-.;:.:"---,. - -~' ~-:'~ :;i- I z~,-k~.~'~-~::l~"'~-' , '~ I ~'E'?';,;~.~'i:"~: !:%.?' ':~'~,,',.I -~ :~-._.~. ~f~-i~';: :.'..'~'.::.... ,. ~-.: ! :--~'::~-:.;.,~:..~.-:... ~..:. :. : ,. ?;[.~ ~' , .- ,.~ . . -. ~: ~ :.',. ' -;'i:!';'f~:'~:. ' :- · ~' '~.'K'-:'. ~;.'.'. " '- - ~'~. ~". :.: . ... . . : -. :-,.~ - ~>,..: ;: :. '. . · ~-- ':.: '...i':i '. : ~. CONOCO, INC. COMPANY ' ' ':' '-' ~ "'~"¢, "~ ''- ":~ '-~' ':' :'~';~'%-~':~-"' ~ JOB NUMBER A0285G0173 Pad B, Well Number: .LU WELL NAME . .... - .... Milne Point;TM'North Slope, Alaska LOCATION -~ - - - .~ _ _ ~ · ·."" DATE TYPE OF SURVEY R E C-E'[V ED 28-FEB-85 · .Gyro Multi-Shot -. ' ---':.,. ,. '..'-: - .:? . .. , . · . Alaska 0ii & (~as COns. Commission Anchorage SURVEY BY B JAHN OFFICE Anchorage, Alaska _ Eastm. Wh Date: April 23, '1985 Conoco, Inc. 3201 C. Street '---Suite-, 200 Anchorage, Alask~ ...... 995'03 (907) 349-4617 P. O. Box 4-1970/Anchorage, Alaska 99509-1970 Well Number: Pad B, Well No: 10 Location: Milne Pt., North Slope, Alaska 'Type of Survey: Gyro Multi-Shot Date: 28-FEB-85 Method of Computation: Radius of Curvature Surveyor: B JAHN ~ ~'. --' Job Number: A0285G0173 Atten: Mr. Dan Robertson Dear Mr. Robertson: We are enclosing the original and one copy of the Gyro Multi- Shot survey run on the above mentioned well. - To date, the following distribution has been accomplished: A. 1 copy delivered to drilling for in-house distribution. B. 9 copies noted for oil company representatives. C. 3 copies for E/W permanent well files. We wish to take this .opportuoity .to..than~._you_ fo_r_._Dsing Eastman Whipstock and look forward to being of service in the future. /~i~re~y~_.~_.~ ................ _:::~--i-~::~::' ': ........................ TOM J~S - - ......... ' ".; .................... '--' District Technical Coordinator cc/file cc: L.A. Dinges - Offshore Exploration Conoco ' O.G. Kiel- P.E.S. Reservoir Section Conoco H~E. Gilliland- P.R.D. Reservoir Section Conoco William Van Alen- Alaska Oil and Gas Conservation Commission J.L~ Weaver - Chevron U.S.A., Inc. Dave Engstrom - Chevron U.S.A., Inc. Concord Office Dale Bossert -Champiin Petroleum Co. C.E. Seery, Jr. - Reading and Bates Petroleum Co. Nell Buttram - Cities Service Oil and Gas Corp. Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide .. C:FIN ,"il-: I_-I, I N C:. PAD B, WELL NO. 10 EM.:. JOB NO A¢~28~A0173 MILNE PT., NORTH SLOPE, ALASKA GI'I'.--~, ¢~-'F.~:35:--: MD, SURVEYOR: B dAHN, DATE RUN: 28-FEB-85 GYRJ3 NO: 271-628, CAMERA NO: 179, ':}0 DEI]4 A/I_I NO: 153/_-. VERTICAl. .=,E_.TIF~N CALCLILATEf'~ IN PLANE AF F'Rr]F'r'~:=:AL DIREr':TI~"~N: N 74 DEG. :34. 1',lIN· 1,4 REL. E RD OF SLIRVEY RADIUS OF C1JRVATLIRE METHOD Eastman Whipstock A PE."TROLANE OOMI=i~IY r-:oIqOC:O, INC. .. ...'.'...' '. ' COMPU'rATION PAGE NO. PAD B, WELL NO: 10 GMS dOB NL] ." A () ...- ,:, ._, U O'-' ~' =-' ' 173' ' ' T I ME DATE MILNE F"f., NORTH SLOF'E, AL ASKA " 11: '-":' · 42 ~'-"-'.:,-AF"R'-,=,'-'~._, TRUE MEASURED DR I FT DR I FT COURSE VERT I CALVERT I CAI_ ~'1 ~ ¢- o_B.=,EA R E C T A N G U L A R C L 0 S LI R E DOG LI DEPTH ANOLE D IRECTII]N LENGTH DEPTH 'SECTION TVD C 0 0 R D I N A T E S DISTANCE D IREI]:TION SEVER FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/1 5C)0. 2 45 N 72 0 W 100. 499.96 2.40 44.0.96 0.74 N 600. 4 3o N 77 0 W 100. 5';?'.T~.76 8·72 540.76 2.43 N 700 ........... 6 30 N :--.', 0 o W 10 A 1-,'-.? 9 2"::) 1 :::; .."-' 8 /=, 40. ":'~'=.Y 4. . :34 N :=:00. 8 0 N 82 0 W 100. 798.4':.-~ :30.8:2 7:3'.:). 4? 6. :-'~2 N '~00. 9 30 N 81 0 W 100. , 897.32 : 45.92 838.32 8.56 N 2.28 W 8.37 W 17.76 W 30.23 W 45.27 W '='.'.40 N 72 0 W ( .7~ :3.72 N 73 4'.~ W i. 7:i 18.29 N 76 1/=, W 2.CK 30.88 N 7:9 12 W 1.5': 46.07 N 79 17 W 1.5: 1000. 11:30 N 80 30 W 1100. 12 30 N 81 0 W 1200· 15 45 N 81 0 W 1:300. 1,_, ¢' 0 N,_._c:'-.' 0 W 1400· 20 30 N 83 0 W 1500. 22 0 N 83 0 W 1600. 24 0 N 81 0 W 1700. 26 0 N 80 30 W 1800. 27 15 N 81 0 W 1700. 27 45 N :3~ 0 W 2000. 29 30 hi 8:3 30 W 2100. :31 0 N :B4 0 W 2200. 3:3 45 N :-:4 0 W 230(]. 36 (:) hi :]:4. 0 W 24.00. 28 45 N 83 0 W 100. 995.64 100. '109:3.4/=, 100. 1190, 42, 100. 12:-]:/-,. 11 100. 1:380.51 100. 14.73.71 100. 1565.75 100. 1/.,5 L-,. 38 100. 1745· 77 100. 1834.47 64.03 736.64 84.70 10:=:4.46 10::: "' -'= ... Y.:, 1 1 :=: 1 4"' 13'7.76 1 227. 11 170· 42 1321.51 206.27 1414.71 24!5.01 1506.75 2:.]:7.02 15'.-} 7.38 :.3 :=: 1. !--;:~ 1/=,:=: 6.77 :]:77.4/=, 1775.4.7 424. ?3 1863.25 474./=,6 1949.63 527.48 20:34.08 5:..-'::=:. 88 211/=.. 11 64:"4.84 2195.57 31./.-,6 N 205.24. W 37.10 N 243.73 W 4.3. :.]:9 N 285.64 W 51.10 N' 327.87 W '"'-' "-'"' "='7"~ 48 W 64'.78 N .422.94 W 70.26, N 473.02 W 75.86 N ".'526.27 W , 81.84 N 583.13 W 88.71 N 643.43 W 64.29 N 79 42 W 85.08 N 77 58 W 109.48 N 80 11 W · ::,::. 50 N :::(') 2 :--': W 171.45 N 80 51 W 207./=,7 N 81 14 W 246.74 N 8i 21 W 288.99 N 81 16 W 333.81 N 81 12 W 379.'.--.~8 N 81 10 W 427· 88 N 81 18 bi 478.21 hi 81 23 W 531.71 N 81, 48 W 58:=:.84 hi 82' 1 W 64'2. 5'..=.'N 82 '2 W 2. O( 1.0: :=:. 2500. 41 0 N 82 30 W 2600. 4-1 45 N :_='2 0 W 270,0. 4:3 15 hi 80 0 W 2800. 42 4.5 N 79 0 W 2'F~00. 42 45 N 7:3 30 W 100, 2331.31 1 O0. 2406.35 100. 2480.08 1 O0. 25!5:3.21 100. 2/=,26.6,5 707.2'.-'., 2272.31 772.80 2347.35 839.93 2421.08 ':.-' 0 7. '='"" ,::.,,:, 2494.21 ":¢7~'] =;':'";'.=;/-,7 /=,5 c:..,/., .~,(' · .... :,.) N 707 03 W ") l-- mm mm -- lt.:, 71 N 772 52 W 1 16. '"'-' -",:, N o ~,:, --,= ,.,._, ::.- · ..' ._1 W ,128.71 N 906.:31 W 141 9?] N ?72 ~"-' . · - . ,Fi,,'", W . 713· 62 N 82 12 W 779.72 hi 82 12 W F:47.2/., N 82 7 W 915.4.0 N 81 55 W 9. :::. :::.. 1,_,° Iq :-:1 42 W 0.82 2.0=. C). "" '"':' 0. :34 CONOCO, INC. . . ,~ r'. ¢) ,,.-,~ . " PAD B, WELL NO: 10 EM.:, dOB NO: A.2o~.,G0173 TIME DATE M I LNE PT , NnRTH '._::LOF'E, ALASKA ' 11 ' '.~.'=:: 42 o..-._^o=, .-~=. TRUE MEASI )RED Y-IR I F1 13R I FT COURSE VERT I F:AL VERT I CAL - .-,_IBoEA R E C T. A N O U L A R C L 0 o U R E DnGLI DEPI'H ANGLE DIRECTION LENGTH DEEPTH F-;ECTION TVD C A 0 R D I N A T E S DISTANF:E lqIREF:TION SEVER' FEET ]] M 13 M FEET FEET FEET' FEET FEET . FEET D P'I Di-~/1(-)i 3000. 43 O.iq 78 0 N :B100· 42 3o Iq 78 o W :3 :.2o0. 4:L :3o N 77 0 W 3400. 42 0 N 7!]i :_::0 W 100. 2699...°:3 1043.48 2640.9:3 1¢)0. 2773.36 1111.24 2714.36 100. 2:E:47. /=,8 i 17~::. 06 278:E:. /=,:_-: 100. S.".-}'=..' :_-..:. 00 1243. 7 ::: 2864. 00 100. 2998. 04 130'P. :36 29~2:?~. 04 · - .... (0. 41 4.5 N 74 30 W :'=: ,"-, ~') {') . 4.:3 1 ._, "= N 7::3 0 W :::700. 4-4 45 N 72 0 W :2::::00. 4. 5 0 N 72 o W :E:900. 4/=, 0 N 71 30 W 100. 3072.50 1376.61 3013.50 100. 3146.2:'-: 1444.16 30:::7. 2:_'-: 100 -=:,=, o _. . ,. ,. 1 .... 16 1513.57 :31 .=;'=/. 16 100 · ::32:=:'~. 02 15:34.06 :=:2:30.02 100 '-"-' ~'- 11 1/=, 55. ~. Y .... · .:,.z,._, .=~.· '-"- 3 ::: (') ¢) 11 4000. 4-6 0 N 71 30 W 4100.. 4.5 15 N 71 30 W 4200. 4.=_; 0 N 72 0 W 4::3¢)0. 44 30 N 72 0 W 4400· 44 ::0 N 71 0 W 4500. 43 45 N 71 0 W 4600. ,4:3 30 N 70 0 W ,.~7007:~: 4:3 45 N 70 0 W 4:--:0c). 44 :=:0 hi 69 0 W 4900. 45 3¢) N 67 0 W 155· 81 N 1039.50 W 1051.1'1 N 81' 2t-~ W O. 4': 169..92 N 1105,90 W 1118.87 N 81 1/=, W 0.5c 184.40 N. 1171,22 W 1185.65 N :E:l' 3 W 1·2( 1 '.:.)'3). 48 N 1235,24. W 1251.24 N :::0 .50 W , ('). 8] 21 .~ 47 N 12'-79. :37 W 1317 1 '-:' N ::: 0 "" ='-- ~ ........ -'.._, W .? 1.4' 23:2.74 N 1363 '-'= ~-'E'~-' .=, ( ' · o._, W 1.-, .._,...7 N :=:0 19 W .7 251.65 N 1428.71 W 1450.70 N 80 :1 W i.::3] 272.53 N 14'.'-.'~4.95 W 151'F.~.59 N 7'? 40 W 1. 294.34 N. 1562,06 W 1589.55 N 79 20 W 0.2.~ 316.67 N 1/=,2S~, 7S/ W 1660, 27 N · :,}¢.}0. 46 0 N 67 0 W 51o0. 46 15 N 6/=, 0 W 5200. ~47 :_--:0 N /=,6 0 W 5300. '"4.:=: 0 N 6::3 0 W 5400. 4:E: 45 N 61 0 W 100. 34:28 .._5o,., 1727 .1 ~.'.'.' oo6? . 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W :374-:3 .71 N 72 1'='._, W 100. ~ '~' '" "; ~' : '-' "'""? .... ,:,,:, · .,4.14-.14 :381:2:.1.5 ._,." ..... ,.14 11._,,:,.--, N .. .:,/:,.:,6. 02 W '-"-'16.c) 6 N 72 20 W ,, · . 4,_ .:,. 1 <' ~ ~ ' ' ~: 7 ¢')~. 6:'P W 4. 0 N 72 ""'-" 100. ~ "]'-' '-' ''~ ''"': '-' '~'''''' · :, .: ..... =,..,..-4 424 13 1177 .94 'N :' · -~ · · ..], ,_-i ,", ,"i · ,,~., -.' W · ., 4 ."Y.:, · ~.,., I 19/:, 94 N .:,,=, W 396 c). =-''-' '-' 1C)0 55=.-' :":' '=:'-?~7 77 =~ ,-.-, o,:, ~-'77F, ""'¢' . ._,.=, N 72 W · . ..' ._l · · .--' ----., · 1 ()0. .'9-, '-,- ' ~ , .., 1 '7' l '''=' :36 N o,=, 4 ~. 7'2 gl 4 c):.9:2 4/-, Iq 72 2'7 N . ../:,.<:. 1.7.. 402'2.71 ~=;_ :9./,.,. 2 . ~ = ._,. ""'-' . _ -- · · -- 100 .~ 6'=Y ! 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E 1'. 00 0.7:'"'; O..'.'-:2 0./_-,0 Cf"fNFICCI, INC. ., '.: ' ' CnMF'LITATION F'~GE biff. · PAI"~ f.'~ WELL NO: 10 LM.=, ,_lOB NCi: AO285GOt73 TIME DATE M I LNE F'T. , NORTH '.=:LOF'E_, ALASKA 11: ~,'='~-' '. 4='=' ,."*"._--A F-"R'-.=,'-'=._, · TRUE MEASIJRED DRIFT DRIFT p. nlIRSE VERTICAL VERTICAL ,:,_IB.:,EA R E C: T A N G U L A R C: L Fi :=; i_1 R E Dor'_:;L[ DEPTH ANGLE DIRECTION LENGTH DEPTH '.E;ECTION TVD C iD 0 R D I N A T E :E-, DI'-'.:,TANF'_.E- DIREE:TIFIN_ '.-:;EVER FEET D M I) M FEET FEET FEET FEET FEET FEET D M DG/10( 100. 6911.97 52:"::3.11 6852.9'7 1524.37 N 5059.91 W 5284.54 N 7:_.' 14 W 1.4] 100. 6988.9'F.~ 5:34/=,. 85 6929.9'F¢ 15:=:9.26 N 5121.92 W 5:"::4.8.21 N 73 16 W 0.6:! 100. 7066 ....... 70 ~4o'...-~. 7'7 7¢~07 70 1==,..,4. 75 N 51'~'-',.... 92. W '-]._4t 1 . o9.. N 7:7:: 1:=: W 1 . O.~. 100. 714.5.37 :54.71.50 70:::6.2:7 1570.73 N 5242.55 W 5472. :::(") N 7:3 1 ? W , ,::). 97 58. 717,' 1.23 :=;507.01 71:32.2:3 15:$:0.22 i',1 5276.77 W 550:3.30 N 7:3 20 W ;., 0.0( F:' R O.J E C T E D T 0 'r ri 94.70. :7::7 4...5 N 74:30 W 0.0( FINAL CLO::;URE - DIRECTION: Ti I .:, FAN _.E. N 7:3 DEGS '.-'¢) M IN:=: 36 ':':'F'=' ....... ,_ .... :, W 5576 o.=; . ,_,._ FEE]' Eastman L} Whipstock l A F~'I'ROLANE OOMPANY CONOCO, INC. PAD B, WELL NO: 10 GMS dOB NO: AO285G0173 MILNE PT., NORTH SLOPE, ALASKA GH'.:;, 0-':.-J:2:5F: MD, SIJRVEYOR: B .JAHN, DATE RUN: 28-FEB-85 , F · 90 DEG A / U NO: 15:'-':6 GYRO NO: 271-628 C:AMERA NJ. 17':.--*, RECORD OF INTERPOLATED ~:,JRVEY ,': ~ ,'... :., L ~ Whipstock2 ' ' - ~"' ': J A Pb'TROLANE (20MPANY CONOCFi, INC, PAD B, WELL NO: 10 GMS MILNE F'T. , NOR'I'H '.--;LOF'E, ALASI<A dOB NO: AO285G0173 TRUE SUBSEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEF'TH FEET FEET FEET 600.24 600.00 541.00 700.71 700.00 641.00 801.5:3 800.00 741.00 902.72 '?00.00 841.00 1004.45 1000.00 94,1.00 106.75 1100.00 104.1. O0 210.01 1200.00 114.1.00 314.. 72 1300.00 1241.00 4-20.91 1400.00 1341.00 528.56 1500.00 1441.00 1637.79 1600.00 174:3.79 1700. O0 1861.13 1800.00 1974.65 1900.00 2(:J90.01 2000.00 2208.44 2100.00 2:3:2:1. :2:2 2200.00 24.59.20 23o0. O0 · .'..~, .".~ 1,54 240i'~. 00 2727.24 2500,. O0 1541. O0 1641.00 1741.00 1841.00 1741.00 RECTANGULAR C 0 0 R D I N A T E S FEET COMPUTAT I ON T I ME 1lATE 11:'-'~:56 '~'~ -' ' '-~' · " .-' ."._',-Al'- R-o._, C: L 0 :--; LI R E D I STANC:E D I RECT I ON F E E T 1] M F'AGE NO. 0.00 0. O0 0.00 0.00 O. 00 O. 00 0.00 0.00 0.74 N 2.28 W 2.44 N 8.40 W 4.36 N 17.85 W 6. :2:!5 N 30.46 W 8.64 N 45.76 W 11.64 N 64.17 W O. O0 0 0 0.00 0 0 0.00 0 0 0.00 0 0 2.40 N 72 0 W 8.74 N 7:2: 4,':.-~ W 18'.:38 N 76 17 W :2:1.11 N 7::::: 12 W 46.57 N 79 18 W 6.5 ""-' 79 · .,' ." N 4 3 W 15.0'.~ N 85.40 W 19.0F': N 110.75 W 23.58 iq 14.1.39 W 28.17' N ,~176.7'F.¢ W 3.3.22 N 216.2:.~ W 86.7:2: N 79 59 W 112.._,':-"::',_, I',1 :::0_. 1:3 W 143.35 N 80 2:2 W 17'F~.02 N 80 57 W '~'18 :'"'::2: N :::": 1 16 W · ' . 2041.00 2141.00 224,1. O0 2341.00 2441.00 39.67 N 259.69 W 47.41 N 307.22 W 55.51 N :2:57.7!5 W 63. I4 N ,4.10.91 W 69.72 N 4. 68.02 W 262.70 N 8:[ 19 W 310.86 N 81 14, W 3.62.04- N c,,_,.i. 11 W 415.74 N 81 16 W 47:2:.18 N 81:2:2 W 2863.71 - 260o.00 2541.00 :2: (')00.10 2700.00 2641.00 :2:1._,._':' .~. ':',_,..~ 2800, 00 274.1 ,0 ("J 32/:,?. 46 2'.-.-~00, 00 284.1.00 :2: 4. 0 2.6:3 :2:0 0 0.0 0 2'P 41.0 0 76.36 N 531.06 W 8:3.99 hi 602.02 W 93.50 N 681.08 W 104.76 N 766.98 W 11':}.66 N 857.51 W '=""I ~":' 4':~ · :,.:, '",. Iq :2:1 W 607.:2:5 hi 8:2 3 W 687.47 N 82 11 W , 774..12 N 82 12 W 865.82 N 8:2 :2: W 17:5.11 hi 11'''-'~.~...~ ,_"Al W l'F~4. :2:7 N 1'21~ /-,9 W 21 '"- ':~ '~' .., .... ~ N 1:301.07 W 1:2:7.14 N 948 72 W ~'='-' · . ~.._,,:,.._,~.~ N 81 46 W 1..,:,.,:,~ N lO3'~.5/, W lO~1.18 N 81 29 W 114.:2.81 N 81 11 W ~..,1.21 N 80 54 W 13 ~ 8.87 N :=:_ o. ._,...'="~ W .. ~ '.. ' ' ,.,,: :, Eastman/ ' '"'. A ~,'rF~)I. ANE ~r~Y CONOCO, INC. PAD B, WELL NO: 10 GMS MILNE PT., NORTH SLOPE, ALASKA MEA:::LIRED DEPTH FEET TRUE VERTICAL DEPTH FEET 35:::7.30 :2:/_-.74.75 :}815.66 :2:95 :::. ::: 6 4102. 10 3100. O0 3200.00 · ~,.-,(. 0.00 34. 00.00 · .:.."~ (. ~ ). 0 0 4243.55 43:34. O0 4.~2:::_ _. ~:~'""., 4661.36 4.800.35 3/:, 00.00 3700. O0 3800.00 3'P00. O0 4000.00 4942. :33 · 50:s:/~.. 22 52:32, 86 5382.59 · _,._,.:,.:,. :37 4100. O0 4. 20 C). 0 C) 4:300. O0 4400.00 45(.')0. O0 6292.45 4/_-,00.00 4700· 00 4800.00 4900.00 5000.00 644.2.4:3 .%,, 6 58'P .... .. 6734.4.2 C.,,879.51 7024. :39 5100.00 5200.00 M ::: (') ('). C) 0 54.00..00 55(:)(:). C)C) 7168 · 69 7312.5'-.? 7455.41 7596.81 7737.41 5600.00 5700.00 5 :--': 00.00 5?00.00 6 C) C)C). C) 0 SUBSEA VERTICAL DEPTH FEET · ' JOB NO: AO285GO173 -.- · ,. RECTANGULAR COORD I NATES~ FEET .. , ...'.:. COMPUTATION .. . . T I ME DATE 11:25:56 23-APR-85 ,. C L 0 S U R E D I STANCE D I RECT I ON FEET D M PAGE NO.., · 3041.00 3141.0 C) 3241. O0 3:]{:41.00 3441.00 · -', Q'~ . · '-,._41 C)0 :::64-1. :3741.00 3841. :3'.-}'~ 1.00 4041. O0 4141.00 4241. O0 4. F.: 41.00 444.1.00 4541.00 4641.00 4.741,00 4841. O0 494.1.00 5041. O0 5141,00 5241. O0 ~;'-'Z . . ._.:, ~1 (')C) 54.41. C)0 239.7'.~ N 1388.04 W 267.26 N 147:E:.23 W 297.8:3 N 1572./:,6 W :2:30. i i N 16/_-,':7~.S/4 W 362.64 N 1767.21 W 393.84 N 1862.24 W 4.24·80 N 1955.87 W 456.38 N 2047·43 W 4.88.54 N 2137.16 W 522.13 N 2227.65 W 560.38 N 2320.8'B W' /_-,01.30 N 24.15.'P1 W ,. 64P]. 42 N 251:2:. 65 W 6 ::)..,. 7'P bi ~ c. 1:2:. 00W 751.20 N 2712.08 W 1408.60 N 80 12 W 1502.2C) N 7'P 4!5 W 1600.62 N 79 17 W 17(.')2.25 N 78 4'.o W 1804.03 N 7::: 24 W 1~03.4-4 N 78 4, W 2001· 47 N 77 4.5 W 2C)97./_-,8 N 77 26 W 21'P2.28 N 77 7 W 2288.02 N 76 4.'-.) W 2387.58 N 76 26 W 2489.62 N 76 1 W 25'.-.?5.18 N 75:3/-, W 27()4.05 N 75 5 W 2814.1':.? N 74 31 W 808.80 N 2811.14 W 866.93 N 2?08,54 W. 'P22..'F'.~8 N 3007.11: W .:" :' , : , ~ 7..,. 4-8 i%1 :'-': 1 (')..9. ~1':' W '" 1023.35 N 3212.8'F~ W . 1062.'P5 N 3:317.37 W 1096.0'.-'.) bi 341'.;~. 71 W 1125.23 N 3520.71 W 1154.20 N 3621.77 W 11:32.57 N :2:722.69 W 2925.18 N 7:2:57 W' 3(}34.99 N 73 24 W' '"'~"':'" :37 N 72 · .:, .L "t .-'. ..[ ["~ W 3258./:,4 N 7>2:35 W 3371.9:2: N 72 2(1) W 3483.51 N 72 14 W 3591.07 N 72 14. W 36~6.15 N 72 17 W , 3801.23 N 72:19 W 3~06.01 N 72 23 W 5541. C)C) 5641. O0 5741 · 00 5:341. O0 5'P 41. C)0 1209.'.T~4 ,N '3823,06 W 4.00S.~.S.~5 N 72 26 W 1237.:::.:7 Iq 3922.68 W 4113.37 N 72 29 W 12/:,5.81 N 4020.74 W 4215.2'.-.? N 72':'-:2 W 12'P:3.24 N 4.116,88 W 4315.22 N 72 34 W 1,.,":'19..74. N 421.';.'.C)9.. W 4414..C)C) N 72 36 W , '. ..... ':)..' ,.': Eastman' L__ L Whipstock 1 ?) ~"· . ' ; APE ~'ROLANE COMPANY CONOCO, INC. F'AB B, WELL NFl: 1() GMS MILNE F'T., NORTH SLOPE, ALA:=;KA MEASLIRED DEPTH FEET TRUE VERT I C:AL DEF'TH FEET 7878.7:3 802 ('~. 4. 7 ':' 1/., 2.2 CD :z: :30:3.6':T' :3444. 1 ':2 6100. O0 /., 200.00 /-,300. O0 6400.00 6500.00 :E:582.68 8718.61 :-'.':6:52.40 :::'.~' ::: 4.29 7114.17 6600.00 /.,700. O0 6800.00 6900.00 7000.00 7100.00 7200.00 JOB NO: AO.-'c,~,L'0173 SUBSEA VERT I CAL DEPTH FEET 6041. O0 614-1.00 6:2.4.1.00 /-,341.00 6441.00 6541.00 6641. O0 /.,741.00 6:34. I. O0 6?41.00 7041. O0 7141.00 RECTANGULAR C n 0 R D I N A T E ..E; FEET 1345.5:3 N 4308.54 W 1371.52 N 4405.57 W 1397.09 N 4502.69 W 1422.55 N 4.59'~,.4'~.' W . 1446.16 N 4/.,'~.)5.20 W 1466.77 N 4788.86 W 1485.8/_-, N 4.:37:3.92 W 1503:. 'Fy6 N 4'.-7,65. ':}4 W 1522· 1'7 N 504'.-.?. 97 W 1541 4. F'; N .~1:--:0 56 W 't ... CF~PIF'UTAT InN 'T Z ME DATE ii:.-,=:56 .-,-~, -,, ,-,= ~ .-, ." .:,- A I- R -,=, ._, C L 0 ::; I.'l R E STANCE D I RECT I ON FEET D FI 451':' 77 N 72 :::'P W 4614.12 N 72 42 W 4714.46 N 72 46 W 4814·4.5 N 72 4'.:.) W 4912.:37 N 72:5:3 W 500:::.45 hi 72 5:=: W 5100.16 N 7:3 4 W 51,:,,r..'.._,,../_,.,'..7¢ N 7'2: 9. W 5274.. :3';-* N 7:2:14 W 5:357.12 N 73 17 W ,_4..:.7 2]1 N -/:3 19 W 5,...5. ,.~ ... =' , 0 S~ N 7 :':: :2:0 14 PAGE NC,. ,Eastman / · -I" ~. E^STM~^iyl~I~T~S~'. T~l"' i'""~' ~: ' ,~ , , : ~ ~,~, .. .. i .; .... 0:: ' i.. ~. ~.:.,~?~:.~.-,..~ ~'? i"' .~';I ' ~ , ~'~i'l,i'~ ~ ~ .... : ~ ~ '~'"t '! ' I '' i 598.54 WEST 5342.84 ~ i. 5 N 7~ 20 36 W 'l ',i ~ ~ i':l- " i . i,. ~.. DEPTH I ND I CATOR, ~.. TVD..i.. D^I'A Suggested form to be inserted ~,n each "Active" well folder to check for timely complian,-e with our regulations. OPERATOR, WELL NAME AND NUhBER ' .~ Reports and Materials to be received by: . ¢--~~~ Date Required Date Received ~:ompletion RePOrt /~ --~ ~ ~'~'' Mud Log . Core Chips Core Descr~ptSon Inclination Survey . Digitized Data yes .., . ~ I A I I- L)h ALASKA ALASKA ',AND GAS CONSERVATION C(' '.tllSSION ~, ~. MONTHLY REPORT DRILLING AND WOR"WOVER OPERATIONS J 2. Name of operator 7. Permit No. Conoco Inc. 85-17 3. Address 3201 C Street, 4. Location of Well at su r{a~e 232' FSL, 848' Suite 200, Anchorage, AK 99503 FWL, Section 18, T13N, RllE, U.M. 5. Elevation in feet (ind/cate KB, DF, etc.) 59' KB 6. Lease Designation and Serial No. ADL 47438 8. APl Number 50-029-21280 9. Unit or Lease Name Milne Point Unit 10. Well No. B No. 10 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of May ,19 85 12. Depth at e~d of monzh, foot-~e drilled, fishing jobs, directional drilling problems, spud date, remarks None. 13. CasJ~J o~ ~ine~ run and quantities of cement, ~esults of pressurs tests None. 14. Corin~j resa~e ampi brief descfii)tion None. 15. Logs_ run a~d de~h where run None. 16. DST data. perforating data, shows of H2S, miscellaneous data None. Well suspended. Completion report to follow. ~ ~ ,ora~,~ c~n~4qis.e/on 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-~-80 Conoco~ Inc. 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 A~ention:~an Rob~rtson' SCHLUMBERGER OFFSHORE SERVICES a Division of Schlumberger Limited HOUSTON, TEXAS 77001 PLIrASE: RIrlB'LY TO 3 June 85 ,¢,.uM,,,o,, o,,,,o,,,,,v,c,, .. 500 W. International Airport Rd. Anchorage, Alaska 99502 ATTN' Holly Burgan Gentlemen: Enclosed are 2 B[prints of the 2"&5"DIZ.;LDT/CN1.- Comlmany Conoco Inc. , Well B-!0 Field Kuparuk , County North Slope Stat~ Alaska on: Additional prints are being sent to: 1 BL prints EX 1 RFolded Sepia Conoco~ Inc. Offshore Exploration-E.W.A. Div. P.O. Box 4444 Houston ~ TX 77252 ATTN' L.A. Dinges C/O Randy Altobelli I BL ~rints & 1 RFolded Sepia Conodo, Inc. P.E.S. Reservoir Sec. Offshore Building P.O. Box 2197 Houston, TX 77252 ATTN' O.G. Kiel 1BL prints Conoco, Inc. P.R.D. Reservoir Sec. P.O. Box 1267 Ponca City, OK 74603 ATTN' H.E. Gilliland - 6356 RW 1 BL nrints EX 1 RFolded Sepia Chevron U.S.A.~ Inc. P.O. Box 8200 Concord, CA 94524 ATTN: Dave Engstrom C/O Louis Klonsky 1 BL-rints Ex 1 RFolded Sepia Champ~fin Petroleum Co. P.O. Box 1257 Engiewood, CO ATTN' Dale Bossert .- 1BL prints EX 1 RFolded Sepia Reading & Bates Petroleum Co. 3200 Mid Continent Tower Tulsa, OK 74103 ATTN' C. E. Seery, Jr. 1 BL "rints & 2 RFolded Sepia Chev~gn U.S.A. , Inc. P.O. Box 107.839 Anchorage, AK 99510 ATTN' J.L. Weaver 1BL tints EX 1RFolded Sepia p Cities Service Oil & Gas Corp. P.O. Box 93q Bakersfield, CA 93302 ATTN' Neil Buttram C/O Jim Quinn The film is returned to Conoco Anchorage Office We appreciate the privilege of serving you. Received by' Date' Very truly yours, SCHLUMBERGER OFFSHORE SERVICES Art HUffman OI STIqlCT Id ANAG ~'l~ SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited · ' HOUSTON. TEXAS 77001 PLEASE REPLY TO 3 June 85 CONOCO ~ INC. 3201 "C" Street,Suite 200 Anchorage, Alaska 99503 Attention: Dan Robertson 500 W.INTERNATIONAL AIRPORT RD. ANCHORAGE,ALASKA 99502 ATTN:Holly Burgan Page 2 of 2 ~prihts.~r,e being ~ & ZRF . L & GAS-_ / ANCtiORAGE, ALASKA 99501 Gentlemen' Enclosed are prints of the ?"&5" T~_TT_.~I.T~T/CNT!_. Company CONOCO, INC. , Well B-10 Field KUPARUK ~ , County NORTH SLOPE prints prints on: State ALASKA prints ~.prints prints prints The film is returned to Conoco Anchorage Office We oppreciate the privilege of serving you. SO~--1565-A .- Very truly yours, SCHLUMBERGER OFFSHORE SERVICES Art Huffman DISTRICT MANAGER - '- STATE OF ALASKA ALASKA.~ ,_AND GAS CONSERVATION C( ,MISSION ~f'~ MONTHLY REPORT DRILLING AND woR'KOVER OPERATIONS, 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. CONOCO INC. 85-17 3. Address 3201 "C" Street, Ste 200, Anchorage, AK 99503 4. Location of Well atsurface 232' FSL, 848' FWL, Section 18, T13N, RilE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 59 ' KB ADT.-47438 8. APl Number 50-029-21280 9. Unit or Lease Name Milne Point Unit 10. Well No. B No. 10 11. Field and Pool - Kuparuk River Field Kuparuk River For the Month of February ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 9470' TD Spud date 2-17-85 13. Casing or liner run and quantities of cement, results of pressure tests Size Wt. Grade From To' -' 9 5/8" 36# K-55 0:"S 57-~9' 7" 26# L-80 0' 9438' 762 bbts'' ArctiC. Set III, 106. bbls. Class Gw/ 1% CaCi'. Cement'at surface. 72 bbls. Class G, 358 bbls. 10.2 ppg NaC1/NaBr 14. Coring resume and brief description None 15. Logs run and depth where run Logs Dual Induction Run #1 Dual Induction Run #2 Litho Density Neutron Run #1 Litho Density Neutron Run #2 From To 111' 5-~12' 5792! 9412' 4350' 5766' 5100' 9376' 6. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED Alaska 0il & "*" ~'""° P. nmmiSSJ0" Anchorage DATE NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate COMPANY LOCATION ATTENTION' WELL NAME SERVICES SCHLUMBERGER OFFSHORE SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99502 · v~:'~//?/-//- /z/~ u~-COMPUTING CENTER · f~//'~ f/j/-?~."/-~/~ ....... PRIN~ CENTER ..... · /--- gg// WELL NAME -' SERVICES · NO. OF BOXES' ~-' NO. OF BOXES' ', ~'~'I JOB NO' ' ~O/y? JOB NO' ' / ADD'L T~ES : ~-,"~ ~ ADD'L TAPES · "'-,, WELL NAME :~~:~ --& WELL N~E ~ SErViCeS · 1"'01/~ s~v~c~s - NO. OF BOXES· NO. OF BOXES' 30B NO. · ~f)Z~Pg JOB NO. ' ADD'L TAPES · '}' /(-~//~ ADD'L TAPES · /~ i l/,,,~ 7~, C - Y~ ~ ~ ~ 3 ~ ~ ~ 5 -ope,. _ WELL NAME · WELL NAME · SERVICES · SERVICES ' NO. OF BOXES' NO. OF BOXES' JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER DATE DELIVERED / / · 1~.--' ,/ /./' RECEIVED BY'" ...... ."~ "M EMORAI OU'M Stat of Alaska ALASKA OIL AND GAS CONSERVATION COM~ISSION TO: C. ~.~j~terton THRU: Lonnie C. Smith //,,' :'~' '( Commi s s ioner FROM: Bobby Fost-JT-'%'erl '~'' Petroleum Inspector DATE: February 26, 1985 FILE NO: D. BDF. 16 TELEPHONE NO: SUBJECT: Witness BOPE Test on Conoco ' s B- 10, Sec. 18, T13N,RllE,UM, Permit No. 85-17. Friday, February 22, 1985: The BOPE test began at 9:15 pm and was Concluded'at 11:45 p~.' ~s the attached BOPE test report shows, there were no failures. In summary, I witnessed the BOPE test on Conoco's B-10. Attachment 02-O01AfRev. 10/79) ,: ' " ' .- . . '".:.. '~.":,---.i~:'---'STATE 'OF/ALASKA- :':.'-.!-"" -' ' :'----!-:~->:'' "- -'"'- "': AiASKA-OIL' '& GAS CONSERVATION-COMMISSION -' , · B.O.P.E. Inspection Report · p rator J~f9~,~ Well Location: Sec/~ ' ~/R//~/J M. d - ~~Casing Set'@ 5 ? ~ ft. Drillin~ Cont~ctor~--~~_ Ri ~~ RePresentative /~/// ~/'/;~/~ / Location, General ~.~ Well SignZ~P~ . General Housekeepi~g~._Rig ~~ Reserve Pit ~~ Visual Audio Mud Systems Trip Tank Pit Gauge Flow Monitor G~s Detectors BOPE Stack Annular Preventer Pipe Rams . Blind Rams Choke Line Valves H.C.R. Valve ~ Kill Line Valves Test Pressure Check Valve ACCUMULATOR SYSTEM .. Full Charge Pressure ~~--gP psig '" Pressure After ClOsure. /~P psig Pump incr. clos. pres. 200 psig -- mind'sec. Full Charge Pressure Attained:' ~.~ min O sec. N2 ~~2/~ ~ ~-~-~ psig Controls:'Master Remote~~Blinds switch cover~~ / Kel.ly and Floor Safety Valves Upper Kelly / Test Pressure Lower Kelly / Test Pressure Ball Type / Test Pressure Inside BOP, ./ Test Pressure Choke Manifold~-~Test Pressure No. Valves / ~ No. flanges Adjustable Chokes Test Results: Failures Hydrauically ope.rated choke Test Time ~ ~.z hrs. Repair or Replacement of failed equipment to be made within ~ days and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operato? cc - Supervisor · .o N SEC. SEC. 19 O.Z.Z,,o85 iii SI SON LAGooN MILNE F~'. UNIT SCALE ix [~,t. Es CO N OCO MILNE POINT UNIT EXISTING DEVELOPMENT NOTES: I. STATE PLANE CO-ORDINATES ARE ZONE 4. ALL GEODETIC POSITIONS ARE BASED ON N. A.D. 1927. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. LOCATION IN SECTION FROM S. LIN4 FROM W. UNE NORTHINGS EASTINGS 212' .if- 978' 6,022,911.70 572 ,058.98 rc~ Z' 910' 6,023,121.76 5TI,geg. 7T 'S 49' · ll29' 6,023 ,077.00 572,209.10 165'~ 1158' S, 022,960.7G 572 . 239.11 Px 88' II I0' 6 t 023. 193.21 572 , 179.11 STATE PLANE CO-ORDS. GEODETIC POSITION LATITUDE LONG IT UDE 70°28' 22.367" N. 149° 24'41.176' W. 70°28' 24.439' N. 1490 24' 4:~.151' W. 70028' 23.978" N. 149°24' 3G.714' W. 70"Zn'Z2.812'N. 14,9°24. :~5. BS§"W. 70028. 2.5. 124" N: 14g~24' 37. 56:~' W. 7o'-z~'-Z~.$SS"~: fa9;7_.,4;,~4, i~ ,o DATE 3 - 6 -82 L.K. 3-6- 82 L.K. '4 -22-82 L. K[- 4-22-82 L. K~ 7-24-82 L K. CHECKED FIELD BOOK 09-82 09 -82 09 '82 09 -82 16 - 82 ~ ' ~,. oz3. 354.3G $71,924.97 , II- 3- 84 J.w. ~ G97' 731' ~ OZ3,~18. gO 571. 803.95 7~-25-31. 3~'u 149t24'.~.4~6-~ II-A- &4 '3. H. CERTIFICATE OF SURVEYOR ' .__~'~'~,~, . ~~[ OBI PAD I H[REB~ ~ERTIFY ]HA]I AM PROPERL~ z **~e~ ~ AS-BUIlT WELL *'tO THAT THIS PLAT REPRESENTS A f~ ~" / ~ /-, ~ Ill MUll'; ~; I G U ~ U ' ~, .~I'~-- ~ ~ - t.~ ' ~ ,,,-.,o. ~.~.~ ..~ .. ~ ~. u.~. ,: ~...... .............. ~.=~.:~ III ~ ~~E !. - . ~*~ (~ ~ . Dern~rd Tcnu,ch · SCALE SHEET .,,~ ~,.~, ~,.,~, ..~ ~o..~.. '~S;2...'.~- ? ~...:~ III ~...'.,, /"' ~o~. I ' ~?4;;::.-:::'tt~ ill - ~ ..... l . ~t~_...~s:0,,~. ~.~ I!1~..~ ~.~o~ Io,.~.s,o. ~.~,~ ~.~'.. ' ' ~~ III ............... I~c~ ,~, .~ ~.~.s ~.o~ s.u.~ February l, 1985 Mr. Daniel J. Robertson Supervising Production Engineer Conoco !nc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 Re: Milne Point Unit No. B-10 Conoco Inc. Permit No. 85-17 Sur. Loc. 232'FSL, 848'FWL, Sec. 18, T13~, RILE. UM. Btmho!e Loc. 3546'FNL, 4598'FEL, Sec. 13, T~13N, R10E, UM. Dear Mr. Robertson: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a-brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Daniel J. Robe~'tson Milne Point TJnit B-10 -2- February !, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. !~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co~_~nission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Vec¥ truly yours, C. V. Chatterton Chairman of Alaska 0±1 and Gas Conservation BY ORDER OF nE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o eric!. Department of Environmental Conservation w/o eric!. Mr. Doug L. Lowery Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 January 25, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Permit to Drill applica- tion for Milne Point B-10. A $100 check is being submitted with the permit application to fulfill the permitting fee requirement. If you have any questions, please call Dan Robertson at 279-0611. ~ >uly~ours, Manager of Alaskan Operations DRG/kr cc: MP B-10 Correspondence File STATE OF ALASKA ALASKA't=-rL AND GAS CONSERVATION CO~,,,'MISSION PERMIT TO DRILL 20 AAC 25.005 ,~/% ' ;TR AT I G R AP'I~'~...I lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] la. Type of work. DRILL REDRILL DEEPEN SERVICE [] S SINGLE ZO N E~6~_ MULTIPLE ZONE 2. Name of operator Conoco Inc. 3. Address 2525 C Street, Suite 100, Anchorage, AK 99503 4. Location of well at surface 232' FSL, 848' FWL, Sec. 18, T13N, RilE) At top of proposed producing interval 3600' FNL, 4400' FEL, Sec. 13, T13N, R10E. At total depth 3546' FNL, 4598' FEL, Sec. 13, T13N, R10Ei 5. Elevation in feet (indicate KB, DF etc.) RKB 59' Pad 24' I 6 . Lease designation and serial no. ADL 47437 9. Unit or lease name Milne Point Unit 10. Well number BNo. 10 11. Field and pool Kuparuk River ' 12. Bond information (see 20 AAC 25.025 Type Blanket Surety and/or number 8086-15-54 Amount $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 33 mi. NW of Deadhorse miles 3546' @ TD feet well B-2 240' feet 16. Proposed depth (MO & TVD) 17. Number of acres in lease 18. Approximate spud date 7429' (TVD) 9856 ! (MD) fe,t 2560 02-15-85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 600 feet. MAXIMUM HOLE ANGLE 46 Ol(see2OAAC25.035(c) (2) 3000 psig@ .Surface 3800 psig@ 7A29ft, TO (TVD) 21 i Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole Casing 17½" 13 3/8' 12¼" 9 5/8' 8~" 7" Weight 48 36 26 CASING AND LINER Grade Coupling PELP K-55 22. Describe proposed program: Length M D TOP TV D 80 35' I 35' 5771 35' I 35' I 9821 i 35' I ~ 35' MD BOTTOM TVD 115'~I 115' 5806' I 4600' 9856' I 7429' (include stage data) +100 cf 900 sks. Permf. "E" 950 sks. Cl. "G" 700 sks. Cl. "G" Conoco Inc. proposes drilling the subject well as a delineation well in the Kuparuk River field. Mud system will be non-dispersed, low solids with a minimum mud weight in surface ~ole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T.D. will be 10.2 ppg. A 20" 2000 psig diverter will be installed on the 13 3/8" conductor for drilling the surface hole. A 13 3/8" 5000 psig RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per state regulations. Maximum anticipated surface pressure was based on a fluid column at T.D. of 80% gas and 20% oil. Casing will be tested to 1500 psig. B No. 10 is no closer than 120' from another wellbore. The closest wellbore will be the proposed B No. 6 which will parallel this wellbore at a distance of 120' to the B-6 kickoff point at 500'. B-t0 will kick-off at 600'. It will then progress away from Bo6 as it is drilled in a northwest direction. The closest existing wellbore, is B-2 which is 240' away. Arctic pack will be placed in the 7" x 9 5/8" annulus after disposing of test oil and excess drilling fluid. The well will be perforated and completed before releasing the drilling rig. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge i SIGNEB D~I.,~ t:~' /%~-"~ TITLE Supervising Prod. Eng. DATE 01-25-85 The space below for Commission use CONDITIONS OF APPROVAL Samples required []YES [~NO Permit number~. 85-17 Form 10401 Rev. 7-1-80 Approval Mud log required Directional Survey required APl r~rzrd~r []YES [~NO i~YES []NO 50- 029-21280 SEE COVER LETTER FOR OTHER REQUIREMENTS - February 1, 1985 ,COMMISSIONER DATE by order of the Commission Submit in triplicate CEMENTING PROGRAM SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Milne Point No. ~ Conoco Inc. 2525 "C" Street, Suite 100 Anchorage, Alaska 99503 A, The 13-3/8" conductor will be set at 80' below the surface (115' K.B.), then cemented to the surface with permafrost cement. B. The 9-5/8" surface casing will be cemented with 900± sacks of Permafrost "E" cement followed by 950± sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. C, The 7" production casing will be cemented in two stages. The primary cementing job will consist of 700± sacks of Class "G" cement pumped around the casing shoe (estimated 2000~ of annular cement, assuming an AHS=ll"). The secondary cement job will consist of 200± sacks of permafrost type "G" cement followed by 60± barrels of Arctic Pack, pumped down the 7" x 9-5/8" annulus. II. ANTICIPATED GEOLOGY 0' - 4500' Surface conglomerates, clay, silt and sand sequences. Estimated base of permafrost at 1700'±o 4500' - TD Predominately shale until the Kuparuk Sands - expected at 6600'± subsea TVD. III. FORMATION EVALUATION A. Sidewall cores to be taken as determined by onsight geologist. B~ Wireline logs for the 8~" hole from T.D. to ±1000' above the Kuparuk interval will include: Dual Induction Laterolog; Sypherically Focused Log; Formation Compensated Density with CNL and GR-caliper. IV. DRILLING FLUIDS A high viscosity gel-fresh water (non-dispersed) mud system Low solids non-dispersed gel/water mud system O' - 1000' 1000' - T.D. V. DIRECTIONAL PROGRAM The well will be drilled to a proposed KOP of 600', then angle will be built in a north 75° west direction. The closest that' the B-10 will come to another wellbore is from surface to KOP where the proposed B-10 will be 120' northwest of the B-6 well. An M~ too]. is to be run while drilling for surveying purposes. Final hole angle will be 46°. The existing B-2 well is 240' from the proposed B-10 well. · . 5000 2000 _ 1000 _ ..... . . CONOCO, INC,. PAD El, WELL NOt 10 PROPOSED MILNE PT., NORTH SLOPE, ALASKA .. EASTMAN WHIPSTOCK, INC. ?000 5000 I 6000 · .~ · !.. 1 TAROET TVD-6880 TMD-gO?O DEP-~4,~4 NORTH 14.48 tIEST,~, 5248 :HORIZONTAL PROJECTION;,.I SCALE 1 IN. = 1000 FEET. 4000 -i WEST-EAST :~000 I TARGET LOCATIONt 3600' FNL. 4400' FEL SEC. 13. RIOE N 7'4 DEG 35 MIN I,/ 5444~ (TO TARGET) 1 . ~1000 0 ;URFACE SURFACE LOCATIONt 232' FSL; 848' FWL SEC. 18. Tt3N. Rile · , 15~i~ B, W~LC-NO, ~o, PROPOSED..:_~ HILNE PT.. NORTH '.OPE, ALASKA: EASTHAN WHIPSTOCK, [NC. 0 _ SURFACE .. 1 000 _ 2000 _ . KOP TVD=600 TMD=600 DEP=O- $ !0 BU!LD 2 1/2 DEe I$ PER I00 FT . 25 BASE PERHAFROST TVD=I?O0 THD=1747 'DEP=281 30 ~.$ EOB TVD=2240 T~D=2428 DEP=691 4000 _ m 5000 _ 6ooO _ 7000 _ 80O0 . ' · -. : ; ....' ~ "\ ' - , i . : : ...................... , .............. ..--: IIA SNDS-~: TVD=4025 T,D=4983 DEP=2519 ' ;--:'- ' ~ : : ~ '-:' ~ OB SNDS TVB 4450 T'D=SS9, 0EP=2955 .TD TVD=7080 T~D=9356 DEP=5'649 .~ ~ ..... . . . . AlaSka Oil ::Anchorage ~. -, _ 1 000 2000 3000 4000 5000 VERTICAL SECTION ' .... 400 ,. ~ : 3OO · . . 200__ · : . . · 1.00 .._ · . · . , : · · . 100~ , · . . . 200 .... . CONOCO. INC.' · 200. ' .......... PAD B. WELL NOt 6 ' PROPOSED MILNE PT.. 'NORTH SLOPE.' ALASKA , : - EASTMAN - WHI PSTOCK.--I NC. - rote,: .... HELL P^THs..ExTEND'-- - _,BE.YOND.__m.I,s.V_IEWZNO ........ ZNDOW--- ' i .... i :- i '. ':' I J ! J ':-- ! ~ :' i - , , · I :. : ~ [ I . - , i · I ~'~ . ~ :- .i .... i . - : - ' , · ~ - , i-.- ~-.. · i ''! ' ' ': ! · , ; · _ . · . . : 300.- 1 ?32 : 1815 400 .............. ~ ~797 1 974 5O0 ~00 .......................... -, 30.0 .; 3729 ......... : · · 334,8 o ~ 3510 : . 324., RE_C._EIV:ED _' ".. i I JAN 2049 Alaska Oil & Gas' Cons. Commission . . ......... , .~n,,.oraye .... ~ N $1MPCON LAGOON ' jl MILN£ PT' UNIT BOLINDARY ""~ ...... .~ ~, :c~ . , ................ ~ ~ ' - ' I~ ~"~ ................................................ ..- ' SC~L~ m ~S CONOCO EXISTING DEVELOPMENT ' ' 'Z ~ ~ SEC. 19 I. STATE PLANE CO-ORDINATES ARE Z. ALL GEODETIC POSITIONS ARE BASED ON . N.A.D. 1927. ~. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. j i I i i ~CATION ~ SECTION SILTS PLANE CO~RDS. 6EODEIIC POSITION ' WELL ¢aO~ S. k~ ~ W. UNE NOnTH~NGS LATITUDE LONGITUDE {FIELD B-I I 212' ~ 978' 6,02Z,911.70 572 ,058.98 70028'22.567"N. 149024'41.176" W. S-6 -82 L.K. 09- - .. B-2 ~ 2' 910' 6,02~,121.76 571,989. Z~ 7002B' 24.4~9' N. 149024'45.151" W. ~-G-82 L.K. 09-82 B-~~ 49' ~ 1129' 6,02~,0~.~ 572,209.10 70028" 25.978"N. 149024'56.714' W. '4-22-82 L. B-4 ~ 165'~ 1158' 6~0~960.76 572,2~9.11 ~°28'22.8~2"N. 149024' 55.865"W, 4-22-82 L.K. 09-82 B-5 88' II10' 6 ~02~, 19~.2t 572 ~ 179.11 70028'~.124'~N~ 14~24'~.565"W. 7-24-82 L K. 16 -82 . ~ - e.lo ~3~' g4~' ¢,oz3.55~.3b 571,0~4.97 ~5~g'-ZG ~ u' t4~24'-~.99o~ 11-3-~ J.u. ,, '.b G97' 731' &,oz3. glb. BO 571. 803. ~.5 7~-2g'-31. g~', 149tZ4'-~g.4~,J !1-[-84 . . . , · - Il ' I I I I lB 11 Il I I n I I I I CERTIFICATE OF SURVEYOR : ' ' I~l P A D Surveye~ for AND THAT THIS PL~, REPRESENTS A UUII/ LOCATION SURVEY MADE BY ME OR UNDER 'A~~ scaLE : ' MY SUPERVISION. ~D THAT ALL DIMENSIONS ~ ~ ~ I' n 400' AND OTHER ~TAIL~ ARE CORRECT. -. AlasKa Oil & Gas ConS, C0mmi~ a.EN~NEERSAND COMMENTS z Anchorage LAND ~RVEYO~ DIMENSION THUS'~ FR~ ' N. LINE ' * SECT. 19, ALL ~HERS FROM S. LINE SECT. . . I I I I I I I I I .. Fill-up Line~. ~Flow [ Preventer Line CONOCO INC. MILNE POINT UNIT BoP STACK (1) B.O P-, stack-size rating meets API RP 53 & spec 6A for class 5M with clamp & hub COnnectors all hydraulically operated ...... (2) BOPE to be oPerated on each trip & pressure tested weekly. (3) Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 gallon acdumulat0r and reserVoir unit and auxiliary energy source for system activation. (4) Ram type BOP to include a minimum of one set of blind rams and'two sets of appropriate pipe rams. (5) Choke and kill manifolds shown seperately to meet API RP 53 class 5M requirements. 2" - 5000 Side Outlets 3" - 5000 Side Outlets 5/8"- 5000 13 5/8" - 5000 3" - 5000 Side Outlets 1-3 5/8"- 5000 _ . . 11'"- 5'000 " RECE VED ~laska 0ii &.Gas Cons, CommJssio~ Anchorage CONOCO INC. MILNE POINT UNIT 20" DIVERTERSTACK Fill-up Line~-------- ! Annular [_Preventer HCR ~_ '., HCR - Valve ] Drilling~ Valve "~ ) Spool 1 20" x 20" i ] 2000 psi i Flow Line 6" I ~ 6" Relief Valve Relief Line ( ~ ~ ~ Diverter Quick I~ Connect Assembly '''i%'f~[I ~ Saver Sub ~ ::~;~ ~~' Assembly ~.; I / Casing c~:,n 1. Relief lines .from the drilling spool will be routed for do,wind diversion. 2. Hydraulic control system will be in accordance with ~I specifications and AOGCC regulations. 3. Both HCR valves will open when the preventer closes, then either one may be closed. Depending on rig contracted, the two 6" lines may be replaced by a single 10" line with a do--stream tee. DRG 7-17-84 · .~_~, ~ FROM MUD PU~.._~' KILL 'MANIFOLD- : ~ . FROM REMOTE HIGH ~---ITi~ m--~ ~ ~ RENOTE PRESSURE GAGE SENSOR · PRESSURE PUMP --" L----UJ ~ NOTE: ' ' '~ HYDRAULIC CONTROLLED REMOTE OPERATED I. HYDRAULIC CONTROL SYSTEM FOR BOP STACK 8 CHOKE ,Z~ MANIFOLD TO INCLUDE (5) STATION CONTROL MANIFOLD LOCATED REUOTFIy WITH 3COO PSI ACCUMULATOR 8 \/ 160 GAL. RESERVOIR P, AUX. ENERGY SOURCE. {51 STA. CONTROL UANIFOLO PLUS VARIABLE CHOKE CONTROL TO BE LOCATED ON RIG FLOOR. ~ DRILLING 2.KILL 8 CHOKE MANIFOLDS TO MEET APl RP53 CL.(~ SPOOL 5111 STDS. 3. KILL MANIFOLD SIZE-RATING 2"-5000 it `/ 4. CHOKE ~ANIFOLD SIZE - RATING 3"- 5000 ..... . ~ HYDRAULIC CONTROLLED ·y.~ REMOTE OPERATED - . E PRESSURE GAGE SENSOR .- · , ~ CHOKE ADJUSTABLE [-~t.cr~ ~ ~ ',,u.p,- ~ ADJUSTABLE MANIFOLD VARIABLE ( h C.OKE ~OTEI I ~ ~ ~ ---- TO SHALE SHAKER BLEED LINE TO ATMOSPHERIC TO PIT MUD/GAS SEPARATOR ' RECEIVED JAN 2 8 1985 - Alaska Oil & Gas Cons· CommJss n['- .... CHOKE 8 KILL MANIFOLDS FOR c1~/8'~ & 7" OD CASING BOP STACK '~-~ BOP MANIFOLD LAYOUT - CONOCO, INC. ; i ! i (4) C, as~; (13 thru ~1)-- 16. 1!. 12. 13. 1,4. 15. 16. 17. 18. 1'9. 20. 21. (22 thrd26) 22. 23. 24. 25, 26. 27. ...,i;:~,~, :.: ~i...: .. ~k:: ,. ~ ' ...... "'i'~ Lt./' ' ', ".~:. ::" ..~ . . , .,: 'pe'm~t.t:' .' ....... ' ..... . ,, ~. ' .. ,. /"" ' ' Is wetl located'proper distance from other wells .......... Is sufficient Undedicated acreage available in this pool.. Is well to'be deviated and is wellbore plat-included ................ Is operator the only affected party ...... ' .................... . ....... Can permit be approved before ten-day wait ........................... · · .. Does operator have a bond in force ................................... · · conservation order'needed '' Is administrative approval needed Is thc. lease.number appropriate ....... , .................... ~ ........ · , . Is conductor string provided ...................... , ......... ..... Is enough cement..used to c±rculate On Conductor and surface.' .... WilI cement tie 'in surface and intermediate or prodUction strings Will surface casing Protect'fresh water zonesWill cement cover all known productive horizons ............... ' r ' ' .... Will all casing give ~dequate safety in collapse, tension Is thi.s well to b.e kicked off from an existing wellbore .............. Is old/wellbore abandonment procedur.e, included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a di, verter system required ....................................... Are necessary diagrams, of diverter and BOP equipment.attached . Does the choke manifold comply w/API RP-53 (Feb.78)..: ...... , ....... Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks.: _ Geology: , ~En~i~ee7in~: ,.cs rev: 10/29/84 6. CKLT ~.. POOL INITIAL CLASS STATUS GEO. I UNIT AREA NO. ON/OFF SHORE 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. ~ .... SCHLUMBERGER ...... ~ LIS T~PE VERIFICATION LISTING .VP OIOoHOZ V~RIFiCATION LISTING PA.~E 1 :* REEL 'HEADER ;ERVICE NAME : iEDiT )ATE : )RIG.iN : :EEL NAME : ;O.NT INOATiON ~ 'R~EV IOUS REEL : ',OMMENT S : :* TAPE HEADER ;ERVICE NAME :~DIT ~A'TE :85~'05/.I7 tRIGIN : 'APE NAME :0[49 :ONTiNUATI~N ~ 'REVIOUS T~P~ : ~OMMENTS ~ :* FIL'E HEADER ~* :ILE NAM~ :~DIT ;ERVICE NAME : 'ERSION m : ~ATE : ~AXIMUM LENGTH : 102~ :ILE TYPE : 'R~VIOUS FZL~ :* INFDRM~TION RECOROS ~* ~NEM CONTENTS NOCO I0 LNE E ~LASKA POINT SLOPE ~SKA NT~.NTS ~R:S.~ = ~- C~MMENTS ~* 'UN .I T TYPE CA'TE SiZE 000 000 013 000 000 004 065 000 GO0 011 0~5 000 000 003 000 000 003 065 gO0 000 OD£ 065 000 000 007 0°5 000 000 006 065 OOO 000 003 ONIT TYPE CATE .SIZE COD~. 000 000 OSl O55 LVP O.I~.MOZ VERIFICATI.gN LISTING SCHLUMS.ER~E~ : A~ASK~ DIVi.SION COMPUTING CEN'TER CQMPAN¥ = CONDCD ALaSkA ~ELL : ~-.1~ FIELD .: MiLNE POINT ~G~NTY .= N.SLOPE STA'T~ = ACASK SECTION = ~ [OWNSHIP = RANGE = lie T~PE DENSITY = 800 ~PI J.O~ ~ ?O:L2. B ~3AS.E L2G: DIL , RUN ~ '~ DATE :LQSSEO 21 .FE5 85 80'TTDM LDG INTERVAL : 5785 TOP LO~ INTERVAL : 111 FT. ~ASING-L2G~ER = i3.375 IN. ~ 111 FT. 8I'T SIZE = 12.5.00 IN. TYPE HOL~ FLUID = LIGHTLY DISPERSED .VP OlOoH02 'VE'RIFICATICN LISTING FA~E .3 DENSITY = 9. gO VI£COS[T¥ = 35.00 PH = 8.50 FLUIO LOSS = 7.00 RM ~ MEAS. TEMP. : 3.260 ~ RM'F @ MEAS. TEMP. : .3.100 ~ RMC ~ MEAS. TEMP. = 3.4B.0 ~ RM ~ BHT = Z.~9'7 ~ MATRIX = SANDSTONE 65 F ~5,5 F ~5 F 8'7'7 F LOP: T HAL$'TEA.D SCHLUMBERGER : ALASKA ~IVISI~N COMPUTING :C~NTER : COMPANY = C~NDC3 ALASKA WELL = FIE'LO = MiLN[ POINT ~OUN'TY = N.SLOPE STATE = ALA3K SECTION = TOWNSHIP = 13N RANG~ LVP OIO.HOZ VERIFICATION LISTING PAGE TAPE O~NSITY : 800 ,~PI JO~ ~ 70i49 SASE LOG: :OiL , RUN ~ 2 DATE LOGGED Z6 FEB 85 30TTOM LOG IN'T,~RVAL = TOP LOG INTERVAL CASING,-L 3G.GER ~IT TYPE HOLE FLUID D~ NS IT ~ VISCOSITY PH FLUID LOSS ~M:~ ;~ MEAS. TEMP. RMC ~ MEAS. TEMP. RM ~ ~HT M~TRiX 9402 :FT. 579Z FT,. '~.,625 IN. @ 5'792 FT. 8. 500 ~.h. DISPERSED lO.tO 38,.00 9.50 2.180 @ 67 F 1.?ZO @ 67 F 2..300 ~, ,6,7 F 1.0,27 @ 1,!50 F SANDSTONE LOP: T ~ACS'TEAD DATA FORMAT R6C3RO ~, ==~ LVP OIO.HOZ VERIFICATION LISTING PAGE .=NTR¥ 'BLOC KS )A'TU M SPiEC.IFICATION 4NEM S~RV.ICE SERVICE ID ORDER ~ )E PT S~FLb OiL [LO OIL ELM OIL SP OIL SR OIL ~R LD'T :ALI LOT ~HO,8 LOT ]RHC LOT ~RAT LOT ~NRA LOT ~ P ~ I L D T =EF LDT ~CNL LOT = C N L L D T TYPE 2 4 8 9 .16 SiZE 1 1 1 1 2EPT SP ~IPHI 3EPT SP ~PHI DEPT SP RHOB NPHI OEPT SP NPHI OEPT SP RHOB REPR CODE 6'5 73 6 5 6 & 66 ~LOCKS UNIT API APZ AP[ LOG TYPE CL4SS FT O0 OOO 00 OHMM OD 220 Oi O.HMM O0 120 46, OHM~ O0 120 44 MV O0 010 ~API O0 310 GAPI 0"0 310 G/C3 O0 3~6 O0 ~20 O0 OOD PO OD 8'90 O0 O0 358 O1 CPS 00 330 31 CPS O0 330 .30 9398. 0000 SFLU -28.7500 GR ~.,3398 ORHO 28.41~80 P:-: 9300.0000 SFLU -26.7969 GR 2.3145 DRHG 29.5387 PEF 9200.0000 SFLU -7,.6~55 GR 2.4121 ORHO 29.3457 PEF 9100.0000 SFLU -26.1875 GR 32.4219 PEF -Z 0'7. 0. Z. . ! 2~. O. 9000.0000 SFLU -33.1875 GR 2.3857 OReO MOD NO. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .S I 67 97 5000 0024 0918 4375 3125 0029 8389 6250 0039 6289 3906 5625 0063 2383 6055 3750 06~9 IL D NRAT NC~L ~,R NRAT NC ILO SR NRAT NCNL ILO GR NR~T NCNL NRAT -207. Z. -6100. 7. 86.. 3110. 2. 7~ 96. 2. 3. ENTRY 1 50' .lin 0 ,;'.E SPL REPR CODE i 68 1 68 I 68 -4 I 68 .l 5 8 1 68 1 68 i 68 4 1 58 1 68 1 68 4 i 58 59.38 50O0 6367 0000 5078 3125 7266 0000 35'98 5250 7266 0000 t797 5625 9375 0000 4395 8750 1992 ILM CALl RNRA FCN'L iLM CALl RNRA F,CNL CALI RNRA FCNL .IL M CAL:~ RNRA FCNL CA~.i RNRA P R 0 :C :.6 S S COCTAL) 000 O00000000OO' 0000000000000~ 0 O0 O000'000000,'0 0000.0000000000 00000000000000 00000000000000 OOO00:O.O:O000 000 00.000000000000 00,000000000000 00000000000.000 OOO00000000000 80000000000000 '0000000000000'0 O000'O00000000g 00000000000000 4,.4.414 Z..7734 7.74,22 $°5406 7.2539 3.0781 858.~000 2.~258 '9.390~ 3.2090 LVP O,IO.MOZ VERIFICATION LIS'TING PASE 6 ~PHI ]EPT ~P ~PHI )EPT ~P ;~PHI )EPT ~P qPHi )EPT ~P 2HgB 'JPHI )EPT ~H~B 4PrtI }EPT ~P '~PHI )EPT ~P ~PHI 2EPT SP RHDB NPHI 3EPT SP RHOB NPHI OEPT SP ~HOB NPHI DEPT SP 36,3281 PEF 2.6348 ~900.0000 SFLU -37.0000 GR 2,.~180 ORHO 34-~2,38 PEF 2.59'73 12'7.6250 0.0762 3.0195 8800.0000 SFLO -30.5875 GR 1.3535 DRHg %3.~570 PEF 141. 2. 0918 OOZO 87'70 8?00°0000 SFLU -4~.o0020 GR 2.,3~38 DRHO 41.1621 PE~ 199. O. 3. 5250 0005 0137 8500.0000 SFL.U -4Z.1875 ,'GR Z.~727 DRHO 29.?852 . 177. O. 7285 52,50 0088 8500.0000 SFLU -32. Z187 &R 2.3867 ORHO 3Z GZI9 168. O. 76.66 5000 ,B477 B~O0.O000 SFcO -39.2187 GR 2.39.65 DRHO 33.5449 PEF 7461 ~375 0083 5156 8300.0000 SFLU -65.i875 ~R 2.%551 DRHO 34.7168 PEF 110. Z. 0000 06t5 0.239 9180 8ZO0.OOOO SFLU -70.0000 GR 2.~453 ORHO 31.5195 PEF 3.,5~84 116.6250 0.0034 2.9258 8100.0000 SFLU -6~.5000 5R 2.~180 ORHO 33-5938 PEF . 107. O. 2. 3164 3125 00'73 7813 8000.0000 SFLU -i3.0156 GR -999.2500 ORHC -99'9.2500 PEF 91. -999. -999.. 5801 2500 2500 2500 7'~00.0000 SFCU -19.Z969 GR i.9219 93.0000 NCNL iLO GR NRAT NCNL ILO NRAT NC~WL ILO GR NR AT NCNL .IL 0, GR NRAT NCNL ILD r-' ',.,R NRAT NCNL ILg GR NRAT NCNL I L D GR NRAT NC NL I L D GR NRAT NCNL !~RAT NCNL IL3 GR NR&T NCNL iLO 19Z~.O000 F:CNL 2.5191 ILM 1£7.62:50 CALI 3.11.33 RNRA 2125.0000 FCNL I'Zr949 ,ILM 3'60,55 RNRA IZ'O~''O000 F:CNL lo1641 IiLM igg.~ZSO CALl 3.~5'~0 RNRA 1831.0000 FCNL 2.~8~4 iLM 17'?.6250 CALI 2.77'73 RNRA lZ6k. O000 FCNL 2.29i0 i68.5000 CALl Z.'9.33.6 RNRA 2680.0000 F:CNL 2.1191. iLM i19o63'75 ,CALl 3.0~69 RNRA 2205.0000 FCNL 2.0313 ILM i10.0625 CALI 3.1406 RNRA Z23~.0000 FCNL 3.8281 iLM ~16.6250 CALI 2.9961 RNRA 23~6o0000 FCNL 3.5035 ILM 107.3125 CALi 3.0~88 RNRA Z~&.O000 FCNL 2 7ZZ7 =LM -999.2500 CALI -999.Z500 RNRA -999.1500 FCNL 2.98~4 iLM -999.2500 CALl 1.8760 9-5016 4.i5,23 410.0000 9.33S9 ,5.5059 52Z.0000 2.501o 9', 1406 2,,8301 99.0000 2.33,20 3.0313 9~9.5000 3.148:4 ?00.5000 1-1016 9.,765b 3.27?3 581.5000 3.8379 9.5625 3.1504 '74~o5000 3.5855 9.3906 3.3955 720.0000 -999.2500 -999.!500 3.0005 -999.2500 LVP OlO.H02 VERIFICATION LISTING PAS.E 7' RH~B -'999.Z500 ORHO ~PHI -'999. iSO0 'PEF ]EPT 7800.0000 SF~-U SP -23.0513 SR RH~B -999.25;00 DRH~3 ~iPHI -999.25,00 !PEF )EPT 7'700.0'000 SFLU SP -31.5625 GR RHOB -999.2500 DRHO 3EPT 7,500.0000 SFLU SP -21.2969 'GR RHOB -999.2500 DRH~ NPHI -999. Z500 PEF DEPT 7500.0000 SFLU SP -26.0781 '~R RH~B -999.2500 DR.HO NPHI -999.2500 PEF OEPT 7~00..0000 SFLU SP -22.o0~69 GR RHOB '-999.,2500 ~RHO NPHI -999. Z500 PEF OEPT 7500.0000 SFLU SP -Z7.$~06 .SR RH'26 --999.£500 gRHO NPHI -999.ZSDO PEF DEPT 7ZO0.~OOO SFLU SP -30.2969 GR RHDB -99'9.2500 ORHG NPHi -999.2500 PEF DEPT 7100.0000 SFLU SP -Z8.6~06 GR RHgB -999.Z500 2RHC NPHI -999.2500 ?E~ DEP'T 7000.0000 SFLb SP -13.0938 &R RH~B -999.2500 DRHO NPHI -999.2500 PEF DEPT 6]00.0000 SFLO SP -2~.5938 GR RHO8 -999.Z500 ORHO NPHi -99'9.2500 PEF OEPT 5300.0000 SFLU -999.2500 NR.~T -999.2500 NCNL 2.8926 iL~ 91,.1375 GR -999.Z500 NRAT -999.250,0 NCNL ,Z,.7539 IL~ I0~.93'75 GR -999.2500 NRAT .-999.2500 NCNL 2.5117 ILO 9~.3125 SR -999.Z500 NRAT -999=2500 NCNL Z. 9629 ILO 99°3750 GR -999,.2500 N,RAT -999. ZSO0 NC ',~L .2.898~ ILD ~0'?.'9375 GR -999.250'0 NR~T -999.2500 NCNL ,2.$191 99.5000 ~R -999.2500 NRAT -999.2500 NCNL 2.8828 ILD i05.8125 GR -999.2500 NRAT -99'9.2500 NCNL 2.63Z8 ILO 94.5000 GR -999.2500 NR~T -999.2500 NCNL 2.8437 ILO 77.5000 GR -999.2500 NRAT -99'9.2500 NCNL 2.6895 iLD 88.~375 SR -999.2500 NRAT .-999.2500 NCNL Z.7090 IL2 -99~o2500. -999.2500 3.00lO -999.2500 -999.2500 -999.Z500 -999 ,o .25 O 0 -999.2.5.'00 -999.,2500 3.00ZO -999.2500 -999.2500. -99'9.2500 2.9902 -999.2500 -999.Z$00 -999.2,500 -999.2500 -999.2500 -999.2500 ,Z. 703'0 -'~99,.Z500 -999.2500 · - ~9'go 2500 ~.5973 -999.2500 -999.2500 2.8086 -99'9.Z500 -999.2500 -999.Z500 2.4316 -999.2500 -999.2500 -999.2500 2. ~33.6 RN:RA FCNL ILM CA,LI' R NRA MCNL, C AL,I RNRA FCNL C~'LI RNRA FCNL I'LM CALI RNRA FCNL ILM C ALi RNRA ZLM CALi RNRA FCNL ILM RNRA FCNL CALi RNRA FCNL ILM CALl RNRA FCNL CALi RNRA FCNL -999 .ZSO0 -'99:9 . 25 ~'0 ,3.08~i -999.2500 -999°2500 -999.Z500 -99'9.'Z500 -999.250-0 -999.2500 Z.539i -99~.Z50,0 -999.2500 5=.0~62 -999.2500 - ~9'99. 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