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Home My WebLink About202-103 OF E AL (A OIL AND G STCONSE VAT ON COM SION RECEIVED REPORT OF SUNDRY WELL OPERATIONS DEC 2 8 2016 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U ,p�9Ka nh own Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ "8..,,J ,..�I asing ❑✓ Plug for Redrill ❑ srforate New Pool ❑ Repair Well Q Re-enter Susp Well❑ Other: Install Jet Pump 2 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory ❑ 202-103 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-23089-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380109 MILNE PT UNIT SB S-25 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 10,250 feet Plugs measured N/A feet true vertical 4,073 feet Junk measured N/A feet 5,894,5,935& Effective Depth measured 10,250 feet Packer measured 6,266 feet 4,048,4,062& true vertical 4,073 feet true vertical 4,146 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' N/A N/A Surface 6,366' 7-5/8" 6,366' 4,160' 6,890psi 4,790psi Production 5,935' 5-1/2" 5,935' 4,062' 7,740psi 6,390psi Liner"OA" 4,066' 4-1/2" 10,125' 4,084' 8,430psi 7,500psi Liner"OB" 3,992' 4-1/2" 10,250' 4,073' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic I„ True Vertical depth See Attached SchematicNNE !` Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.4#/L-80/SMAX 5,891' 4,047' 2-7/8 x 5.5"Paragon 7-5/8 x 4.8"Bore Packers and SSSV(type,measured and true vertical depth) Bkr ZXP LTP 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 0 200 0 Subsequent to operation: 457 115 1,797 50 238 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory Development 2 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-529 e Contact Ted Kramer r — Email tkramer(C�hilcorp.com Printed Name Bo York Title Operations Manager Signature Phone 777-8345 Date 12/27/2016 Form 10-404 Revised 5/2015 R I G I N A L Submit Original Only RBDMS i, DED 2 9 201 /z-3a,-./b /70 • • Milne Point Unit 11 Well: MPU S-25 SCHEMATIC Last Completed: 12/4/2016 Ililearn Alaska,LL( PTD: 202-103 TREE/WELLHEAD Tree 4-1/6"5M FMC Wellhead 11"x 4-1/2"5M Gen 6 w 4.5"TC-II T&B Tubing Orig.DF Elev X6.5'/Orig GL Elev.39'Doyon 141 Hanger CIW"H"BPV profile ii OPEN HOLE/CEMENT DETAIL 20" a 20" 260 sx of Arcticset in 42"Hole 7-5/8" 1380 sx PF'L',293 sx Class"G"in 9-7/8"Hole 4-1/2"x 2 Un-cemented Slotted Liners in a 6-1/2"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 215/A-53/Welded 17.938 Surface 80' /114, ' 7-5/8" Surface 29.7/L-80/BTC-M 6.875 Surface 6,366' 5 ry 5-1/2" Production 17#/L-80/Flushmax 4.892 Surface 5,935' Scc� LINER DETAIL i 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 6,059' 6,106' ery 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.958 6,106' 10,082' 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 10,082' 10,125' 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.958 6,258' 6,406' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.958 6,406' 10,250' TUBING DETAIL TOO @±3,103' 2-7/8 Tubing 6.4/L-80/SMAX 2.441 Surf 5,891' WELL INCLINATION DETAIL d" t` KOP @ 600'MD `'f ` Hole Angle Passes 55 to 68 Deg.@ 2,500'to 5,800 yl / �/� Max Angle in Tubing=68 Deg.@ 5,800' /� V" 65 Deg.at sliding sleeve G e JEWELRY DETAIL a I. No Depth Item ,kiq1J(��, -` �,_c/ �i 1 5,853' 2-7/8"Accelerated Jet Pump Cavity "1 5 a .-7/3 2 5,860' 2-7/8"SLB Saphire Gauge Mandrel w/Gauge(Intake) 3 5,870' Locator Seal Assembly 4 5,872' Seal Bore Receptacle,21.55'Long .t' il5 5,894' 2-7/8"X 5-1/2"Paragon Packer `5/ , m 6 5,914' WLEG-Bottom at 5,915' i. 7 5,935' Packer 7-5/8"X 4.80"Bore 8 6,058' Baker 6'Tie-back Sleeve-ID=5.75" ' ' 4 9 6,068' Baker Hook Wall Hanger Inside 7-5/8"Casing i 4, * 10 6,093' Baker Hook Wall Hanger Outside(Hook Point) 2 1 11 6,258' Baker 7'Tie-back Sleeve ' 3 12 6,266' Baker ZXP Liner Top Packer 4 13 6,271' Baker 7-5/8"x 5"HMC Liner Hanger S ;. OA LATERAL WINDOW DETAIL I = Window in 7-5/8"Casing @ 10,516'to 10,528'(MD)/4,199'to 4,2011ND) �' )E Well Angle @ Window=74 Deg. a. ,...„.. 6t ti 4VGENERAL WELL INFO API:50-029-23089-00-00 1 Drilled and Completed by Doyon 141-6/21/2002 "" 8 Re-complete to repair casing leak by Doyon 14-12/4/2016 r "04 Lateral 53'Rat Hole 12m 13 7-5/8" "OB"Late al ,0'Rat Hole li TD=10,250'(MD)/TD=4,073'(TVD) Revised By:TDF 12/6/2016 Hilcorp Alaska, LLC Weekly ['HempAI., k:L,LLC Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-25 Doyon 14 50-029-23089-00-00 202-103 11/8/16 12/4/2016 1,017-91;:,P4 y-y - '� �l� -:*'�r., qp fl,_a.r s4v .a o ,�I�II�r '.' ....a,.� ��. .�� t `"r.d,,,,„„Fl� .>... a� .. .� ,fir 11/16/16-Wednesday , Mill overshot @ 80 RPM, 5-15 WOB,4-7K TQ on,0-3 BPM, No returns, Mill F/5801'T/5801.5. UP/DN/ROT 110/93/100. Monitor Well, Good. POOH F/5801'T/BHA,Stand back Collars,Clean out boot baskets full, Inspect 6.75 Mill.Good. Pull Wear ring, Install Test Plug, M/U 2-7/8" test joint. Fill_stack&perform Body test on annular 250/2,500.Good. Matt Herrera with AOGCC on sight to witness the test.Start test @ 13:30.Test bops as per AOGCC 250/2,500psi.Test with 2-7/8",4&5.5 Test joint.Test Annular with 2-7/8". Monitor annulus filing the hole with 10 BPH.Test 14 Choke valves,with one manual&one hydraulic bleed off test.Test Top drive Manuel & hydraulic valves. Bump Test gas alarms.Test Pit level indicators, Flow paddle&Gain loss as per Matt Herrera. Perform accumulator draw down test.Test upper 3-1/2"x 6 VBR using 5.5 test jt,test 3-1/2",4 FOSVs,4 dart valve, 2-7/8" dart valve, mud cross valves, blind rams to 250psi/2500psi 5 min ea.Chart all tests. Close annulus valve. R/D test equipment. Blow down lines. Install 9 ID wear ring. Monitor annulus filling @ 10 bph. No failures. M/U 6- 3/4"x 2-3/4" packer mill, (2)4-3/4" boot bskts, bit sub, bumper sub,jar,XO,(9)4-3/4" DCs=313.51'. RIH with 58 stds 4 DP from 313'to 5,775'. Pump 35 bbl 200 vis, 10.4+ppg,80 ppb baracarb pill,chase w/8.6 ppg,42 vis mud w/6 ppb background LCM,spot pill f/5,775'to 4,623', blow down top drive. PJSM,cut and slip 59.5'drlg line. Reset and test crown saver. Note: Let pill soak 30 min then fill backside w/8.6 ppg,42 vis mud,see returns at 70 bbls pumped,shut down pump and monitor well.Static loss rate 100 bph. M/U stand#59,Tag TOF @ 5801.5'. Mill overshot @ 100 RPM, 12-16 WOB,4-7K TQ on,0-3 BPM, No returns, Mill F/5,801.5'T/5804.2'. UP/DN/ROT 110/93/100. Monitor Well,Good. 11/17/16-Thursday ,`' ' � Mill Packers 100 RPM 12-16 WOB,4-7K TQ on,0-3 BPM, No returns, Note:pumped 2-35 bbl LCM pills,got returns on 1st pill,went away, no returns on 2nd pill. Mill F/5,804.2'T/5,809.5', Not making any progress,decision made to POH. UP/DN/ROT 110/95/100. Monitor Well, Good.Obtain SPRs, blow down top drive. POH f/5,809'to 313'. Rack back DCs,jars, L/D boot baskets and 6-3/4" packer mill, Boot baskets full of metal shavings. Mill 1/8 under gauge,otherwise in good condition. Note: use double displacement on trip out. M/U new 6-3/4" packer mill,2 boot baskets, bit sub, bumper sub,jar,XO,3 stds 4-3/4" DCs=314.43'. RIH with 4 DP from derrick f/314'to 5,775'. M/U std#59, pump 1 bpm,tag TOF on depth @ 5,809.5'. UP/DN/ROT 120/95/100. Mill Packer @ 100 RPM, 10-20 WOB,4-7K TQ on,0-3 BPM, No returns, Mill F/5,809.5' using several different parameters, pump hi vis sweep making no progress,decision made to POH to inspect mill and boot bskts. P/DN/ROT 120/95/100. Monitor Well,Good. Blow down top drive, POH f/5,809'to 313'. Note: use double displacement on trip out. Rack back DCs,jars, L/D and inspect boot baskets and 6-3/4" packer mill, Boot baskets empty, mill worn on outer face with no wear on inner 5 inches of face. Decision made to run 6-3/4" burn shoe. Note: use 20 bph hole fill while working BHA. M/U 6-3/4" burn shoe, 1 jt wash pipe, drive sub,triple connect, 2 boot baskets, bit sub, bumper sub,jar,XO,3 stds 4-3/4" DCs=333.06'. RIH with 4 DP from derrick f/333'to 5,795'. M/U std#59,tag TOF on depth @ 5,809.5'. Mill Packer @ 80 RPM,5-15 WOB,4-8K TQ on, Mill F/5,809.5'for 15 minutes, packer free,fill w/30 bbls down annulus, hole full, monitor well,fluid continues to fall slow,push packer down hole tagging @ 6,001.5'. UP/DN/ROT 120/95/100. • tit Hilcorp Alaska, LLC Weekly HitempAlaska,I,I.0 Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-25 Doyon 14 50-029-23089-00-00 202-103 11/8/16 12/4/2016 11/18/16-Friday r ; . '''Sb L With packer chased to 6,001',set down 15k 3 times, pump 20 bbl sweep, POH to 5,987' L/D single DP. BD top drive. Monitor well-fluid falling. POH f/5,987'to 333', Fill hole using double pipe displacement w/no returns. POH f/333'to surface, L/D BHA 13,6-3/4" burn shoe and boot baskets.Small amount of metal, burn shoe had no wear. Monitor well,fill @ 20 bph. no returns. M/U BHA 14, 3-3/4"shoulder type itco spear w/2.938 grapple,XO, bumper sub, hyd jar,XO,9-4-3/4" DCs=304.91'. RIH w/4 DP f/304'to 5,959', P/U singles f/shed RIH to 6,058'tag up w/10k. P/U w/no over pull,set down 25k 3 times, P/U and observing no over pull while pumping 1.5 bpm 650psi. PU/SO 120/75. L/D single jt, BD TD. POH f/6022'to 304', Rack DCs in derrick. Use double displacement POH with no returns. Pull BHA to surface, L/D BHA 14, inspect spear assy. No fish engaged. Monitor well. M/U BHA 15,Spear w/3.947 grapple,XO, bumper sub, Hyd jar,XO,(9)-4- 3/4" DCs=302.25'. RIH w/4 DP f/302'to 6,047', M/U single and Top drive. Pump 4 bpm,460psi,engage fish,tag TOF @ 6,056',set down 15k, P/U then set down 25k 4 times, observe 5k over pull,set down 25k @ same depth, P/U-packer drag 10-25k off bttm. PU/SO 125/85. L/D single, BD TD. POH slow f/6,047'to 302'. Pulling up to 25k over @ casing collars every 40',working back down and then pulling with less drag, not seeing much casing collar drag past 5,500'. Monitor for swabbing while POH, use double displacement filling back side. Rack DCs and 'ars J in derrick, Pull fish out ofhole, rrecovered. . vereall of f fish, L/D same-packer(3.13'),X0,3-1/2" pup jt,3-1/2"jt of tbg w/IBP previously installed,XN nipple,3-1/2" pup jt,WL entry guide,total length of fish=50.96'. Monitor well, mobilize tool off rig floor. M/U BHA 16,TBR polish assy w/5.67 polish mill, (6.5 no go and 5.5'of swallow),double pin sub, 2-4-3/4" boot baskets,7 5/8 casing scraper, bit sub, 2-string magnets, bumper sub, hyd jar,XO,9-4-3/4" DCs=350.09'. Monitor well. Make cleanout run, RIH w/60 stds 4 DP f/350'to 6,004', M/U std 61 and top drive. Monitor well. Pump 8 bpm,830psi,wash down to 6,065' @ top of tieback sleeve, rot 40 rpm and cleanup tieback sleeve tagging no go @ 6,069', putting scraper depth @ 6044', pump 20 bbl hi vis sweep out of DP. No returns, rack 1 std back, BD TD. PU/SO/ROT 125/85/100. POH from 6,004'to 4,589', use double displacement POH. Continue POH from 4,589'to 350', Fill hole with double displacement, no returns. L/D 4-3/4"" DC's. L/D BHA,Clean magnets and Boot Baskets with 40 lbs metals on Magnets.Very little in boot baskets. Large metals on magnets.Some pieces of slip dies. Decision made to Re run C/O assy.TIH from Derrick to 5,821'.Single in hole to 6,011'.Wash down from 6,011'and no--go @ 6,070'w/5K WOB. P/U 10'off No-Go. Work string with 8 bpm/810psi. PUW 117K/SOW 85K/Rot 110K.Work through TOL with no pump/Rotation,tag with no indication of debris. Lay down 2 jts 4" DP. POOH from 6,011'to Surface.Clean magnets and Boot Baskets with 25 lbs metals on Magnets.Very little in boot baskets. Recovered large piece of casing 6"tall x 8" long, Large metals on magnets but smaller than previous run. Decision made to make 3rd run with Magnets. Note:use double pipe displacement POH, no returns.TBIH with 3rd C/O assy. M/U C/O BHA, RIH f/72'to 6,011', o PU/SO/ROT 115/85/100.Circ 8.8 bpm,880psi,Wash down from 6,011'to 6,065',Work through TOL with no pump/Rotation,tag with no -) indication of debris. Lay down 2 jts 4" DP. POOH from 6011'to Surface.Clean magnets and check Boot Baskets, 6 lbs small metal shavings on magnets, boot baskets empty, L/D cleanout BHA,clear rig floor. Note: use double pipe displacement POH, no returns. Note:Total metal pieces and shavings recovered during milling packer and cleanout trips=117 lbs. PJSM, R/U to run 5.5 flush max lower PKR/tubing tail tie L back assy. Monitor well, use 20 bph hole fill. M/U 6'5.5 Flush max 17#mule shoe w/4.90 WEG w/WSRP installed 3.13'down f/box end, 1- 5.5 FM 17#pup it. 1 it FM liner RIH to 56.70',fill with 50'of sand-13 sx. M/U liner jt#2,XO pup,5.5 Flex lock liner hanger w/3-1/4!.1-20 shear screws set @ 1,243psi.5.5 X 7.6HRD-E ZXPN liner top packer assy w/5-7/16 shear screws w/setting force 44,100 ft/lbs,. Hyd setting tool f/ top packer set,shear pressure 7-7/16"screws @ 1,974psi, neutral pressure(12)7/16"screws @ 3,252psi,3-1/2" IF pup jt=142.49' Per Baker rep. Note:TO Flush max liner to 5,100 ft/lbs. R/U 4 handling equip. RIH w/5.5 flush max lower PKR/tubing tail tie back assy conveyed on 4 stds DP f/142'to 5,985'(62 stds) no faster than 100 fpm,easy in and out of slips. M/U std 63, Note: Fill first 10 stds w/8.5 ppg seawater per Baker rep. M/U top drive. RIH tag @ 6,068.52 in tie back sleeve, P/U and work down 2-times tagging again @ 6,068.52', P/U 2' to 6,066.5',fill pipe in stages, bleeding off air thru standpipe. PU/SO 115/86.Stage pump in 200psi increments to 1,500psi,sheared @ 1,580psi, hanger set,S/O 40k on hanger, P/U to 80K,walk pressure up to 2,650psi,shear and set packer,increase pressure to 3,500psi, bleed off pressure to Opsi. P/U 8'dogs released,S/O tag LT with dog sub,sheared @ 35k, P/U 50' @ 6,010'. Pump 4 bpm to confirm circulation.Top of packer set @ 5,935.57'. V � • fi Hilcorp Alaska, LLC Weekly ---' ------- Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-25 Doyon 14 50-029-23089-00-00 202-103 11/8/16 12/4/2016 PUH off of PKR verify running tool released. Lay down 2 jts 4" DP. Blow down Top Drive.Slip and cut 60' Drill line, calibrate block height, service Top Drive, inspect brake linkage. POOH laying down 4" DP from 6,011'to 42'.Service break and L/D Liner PKR running tool.Clean up rig floor. Pull Wear Bushing. Pump 100 bbls with no returns to surface. R/U to run 5.5^ 17#, L-80 Flush Max casing. P/U 5.5" Bullet Seal assembly. M/U and thread lock Orifice Float Collar with Shut off baffle installed on top of Float Collar.Stage CMT Head and equipment on rig floor. Run 5.5" Flush Max Scab Liner as per tally to 1,451', Bakerloc and M/U ESC with FM x BTC XOs,verify pinned f/3,300psi shear, Continue R|Hw/liner f/1,464'to5,936' (l3Zjts). PU]t133.Tag TOL with No-Go Sub @5,94O'w/5KDn. Mule shoe depth @ 5,949' (Tagged /� TOL w/NoGo1U'inon]t#133�TOL S'deep w/[sXTaUyvsDPTaUy)� Lay down]tl33' M/U 9.83'and Z.O2' pups� WUHES F|ushmax pin x " Butt Box X0. R/U CMT Head and lines. Land seal bore on No-GO, PUH to 125K string wt. Pressure up 5.5"casing to 500psi to ensure seal rit engagement. PUH until pressure dumped,exposing the ports on seal assembly to the IA. Establish circulation staging up to 4 bpm with l2Opsi. PJSM for CMT iob. Perform cmt job as follows: Pump 5 bbls FW, Pressure test lines to 4,500psi, Pump 20 bbls of FW spacer @ 5 BPM. Mix and pump 140 sxs(28.8 bbls)ofType 1,class 2 Tail Cement at 15.8 ppg. Drop Shut off Plug. Displace cmt w/20 bbls FW f/Cmt Unit,turn over to rig, Pump 118 bbls,8.5 ppg Sea Water.Total Displacement @ 118 bbls.Calculated @ 117.5 bbls. Bump plug with 400psi over final circulating pressure. Bleed off pressure, leaving bleeder open,slack off and land seal assembly on depth in the up stroke.CIP @ 03:30. Load Closing Plug. Using rig pump,stage pressure ESCernenter Fill back side w/19 bbls to fill.Stage pumps up to 4 bpm and CBU with partial returns. Had returns the entire bottoms up. Lost 75 bbls on bottoms up,with no spacer or CMT to surface.Shut down pump and monitor well for losses while WOC and prepping for 2nd stage. Loss rate @ 60 bph static @ 06:00. 11/21/16-MondayU U -; Wait on cement to reach compressive strength, perform rig maintenance. Fill hole and monitoring well.Static loss rate 60 bph.Continue to � perform rig maintenance, cleaning. Due to losses decision made to pump Super flush 101 LCM treatment and load 100%excess cmt 1, /" ..,before pumping 2nd stage cement job.Continue filling hole and monitoring well.Static loss rate 30 bph.Wait on Haliburton to prep and ' load Super flush 101 LCM treatment for 2nd stage in Dead horse,continue to perform rig maintenance,cleaning.Continue filling hole and monitoring well.Static loss rate 30 bph+-. LCM treatment slurry on location @ 00:40,spot same. PJSM for pumping LCM slurry and pumping 2nd stAEe cement job. Pump LCM slurry as follows-10 bbls water, pump-10 bbls Ca2,7 bbls water, 10 bbls super flush 101,7 bbls water @ 2bpm.With rig pump,displace w/8.5 ppg seawater 2 bpm,see returns @ 35 bbls away,close annular, pump 3 bpm, displace w/105 bbls total w/psi increase to 100poi Shut down pump, bleed off pressure, open annular,stage pump up to 7 bpm,33Opsi with 20%returns,CBU, Note: @ BU lost 40 bbls during circulation.Top off pits w/seawater, establish loss rate @ 24 bph. Pump 2nd stage cement per plan, pump 2Obbls water with red dye 4b450 i 178.8bbkLl5.8ppgtype|/||ceme[t,,start4bpm2r displacement w/rig pump 84 bbls, FCP 2 bpm 700psi, plug bumped @ calculated-84 bbls,shift ESC tool closed @ 1720psi. Estimated 1385' cement coverage above ESC. Hold pressure for 5 min, bleed offpsi-2 bbls bled back, check tool is closed,CIP @ 05:46 hrs.(870 sx, 103.2 bbls mix water). Losses @ 193 bbls/111 bbls returned to surface. No spacer or cement returned. , ~ y}'r vy " « 411-'‘ " • • Hilcorp Alaska, LLC Weekly Hihorp Alaska.LLC Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-25 Doyon 14 50-029-23089-00-00 202-103 11/8/16 12/4/2016 11/22/16-Tuesday . R/D cement head, blow down lines, Break BOP flange bolts, P/U high enough so welder can rough cut casing. Prep 5-1/2"casing for emergency slips per Wellhead rep.Set slips with w/85k on slips. Rough cut 5-1/2"casing,cutoff 37.8'. Remove spacer spool, rack BOP back with adaptor flange.Welder make final cut and dress stub per wellhead rep. Install pack off and tubing spool,torque same.Test pack off to 5,000psi for 10 minutes per wellhead rep,good. N/U BOPE,install riser, mud cross and fill up lines, Record new RKB measurements. Mobilize test jt,test plug and wear ring to rig floor. M/U 2-7/8"test jt, R/U test equipment,fill stack and lines with water, perform BOP shell test to 2,500psi,good. PJSM, Perform weekly BOP Test,AOGCC rep Lou Grimaldi waived witness @ 07:32 AM on 11/22/2016.Test with 2-7/8"test jt,test lower 2-7/8"x 5 VBR, blind ram, mud cross valves, FOSV, Dart valve, mud cross valves, upper and lower IBOP,choke manifold valves and Annular to 250 low/2,500psi hi 5 min ea.charted. Perform hydraulic and manual choke bleed test. Perform accumulator drawdown test, Rig Electrician bump tested Rig gas alarms. No failures.Close I/A, R/D test equipment, Blow down lines,drain gas buster. Install 9" ID wear bushing. Install 30' mouse hole. R/U Power tongs, Breakout pup jts on 5.5 cutoff jt. R/U 2-7/8" handling equipment. PJSM, Load tools to rig floor, M/U Cleanout BHA#18,4-3/4" BIT,XO,3-1/8" Extreme motor, DBPV,XO, pump out sub,XO,(6)3-1/4"spiral DCs=196.70' Drift and single in the hole w/2-7/8" PAC work string f/196'to 4,409', M/U top drive, break circulation. Note:fill pipe @ 2,500'. �� Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-25 Doyon 14 50'029'23089'80'00 202'103 11/8/16 12/4/2016 Daily 0 lie ratio n s: 11/23/26/2016-Wednesday While washing down w/ 3'7/8" clean out string @4,4lU', cleanout string packing off @14SUpsi, attempt tofree blockage, working string and pressuring up to 2,500psi, continue working string pressuring up to 4,000psi and dumping pressure severa|timesw/nosuccess. Dnop7/8" stee| circsubbaU' Pressureupto3,OS0psiattennptingtosheardrrsubopen' nn circulation. L/D 3 singles f/4,41O' to 4,350', R/U test pump, pressure up to 5,000psi attempting to shear circ sub w/no success, bleed off pressure, R/D test pump. POH wet f/4,350'to 2,085' racking stds in derrick, observed trapped air inside 2'7/8''work string @2,08S' Line up and circulate 2.3 bpm 460psi, circulate string volume with no indication of any blockage, full returns. Blow down top drive, L/D jts 61 thru 63, cleaned out 2' column of scale, recovered 7/8" steel ball. Continue POHf/Z,08S'toBHA @l96', Flow check well, static. L/D (6) 3-1/4'' DCs, remove mud motor and XOs, Mill BHA 19, Re-run 4 3/4" bit, bit sub, pump out sub,XO, 6-3 1/4" DCs= 183.68'. RIH with 2'7/8''work string f/ 183'to 2'260' checking for debis in stds, L/D std 23 and remove scale, continu . �� PU/SO QO/6D. M/UTop Drive, obtain parameters @4.Sbpm/Z1S0psi/VVOB3'5K/SORPM 1-2KTq. Wash down to4,4l8' Drill hard CMT from 4,418'to 3'SKVVOB/SORPM/SBPM/2,S08psi. Pump 18bb|shivis sweep @4,468'. Note: sweep returned 3O0% increase ofcement @ shaker. Drill closing plug and ESC @4'489'tn4,491' back ream and pass thru easily with pumps off, pump 1Obbl hivis sweep 6bpm 2,y30psi@4'493', close annular,test 5-1/2" liner to 2,500psi for 5 mm to ensure integrity of ESC, good, bleed off pressure. Open annular. Drift and single inthe hole w/Z'7/Q'' work string fY 4,493' toS,6S9' tagging cement stringers. Wash and ream cleaning up cement stringers and contaminated cement f/ S'659'toS,82S', pumping 4bpm, 2'1O0psi3OUrpm, drill firm cement f/S'8ZS' toS,O79'' pump 18bbl hivis sweep, cleanup x� /^ wellbore. Blow down top drive. Pull 1 std, Park pipe @ 5,781', M/U headpin, close annular, pressure ___--__ -____-- ^+) 2,500psiliner toJ,500psi,found 1SOZconnection leaking, bleed off pressure,tighten same,test tofor38min good. RID ' ' test equip. Open annular. jz*' 11/24/2016-Thma1a��0��0':`,q`|||�k��U]��U�N��|�.�|�"��'��\�l0��g��U@��nU��/ Continue to drill cement and FEfrom S,879'to6,012'. Drill Brid P| d t 6,035'.Tag all Float equipment on depth as per tally. ESCMTR@4'480'/FC@S,y20'. Make dry tag ofsand @6'035' PUH 45' above sand plug. Pump hi vis sweep to surface @S.Sbpmo/3,61Opsi/60rpm/1'2KTqwith 10U96increase atshakers. Drop 7/8" ball and pump on seat. Shear circ sub @ 2,900psi. Blow down Top Drive. POOH from 5,942' Lay down 6' 3-1/4" DC's. Break out and L/D 4'3/4" Bit and bit sub. M/UBHA 2U, RC]8wf43/4'' head, X0, 6'31/4'' Spiral DCs~ 18O.46'' RIH w/27/8'' work string f/1O8'to6'U]6' tagging top ofsand. Drop 9/16'' ball @6810'. PU/SO/ROT1U0/7O/8S. ROT 38rpm, Reverse circulate 3.7bpm, Z,048psi' wash sand and junk f/6,U36' to6,0S1'w/final reverse pressure of2,160psi (1ZOpsiincrease). Note: 1stall @6,U48' while P/U, over pull 10k, stall @5k TQ, S/O to neutral wt and broke free, no other issues. Blow down top drive, POH f/6,038'to 188', L/D 4'3l/4'' DCs' L/D, empty and inspect reverse basket. Recovered 6 lbs junk consisting mostly of metal, brass and rubber with a few pieces of cement, Flow check well, static. Re-run cleanout BHA. Mill rev circ bskt, XO, 6- 3 1/4" DC= 188.46', RIH w/2 7/8" �nrkst string l8O�o 6,051'tagging topof sand. ROT 30 rpm, Reverse circulate 3.7 bpm, 2,040psi, wash sand and junk f/6,051'to 6,056' (leaving 5' of sand on top of RBP) w/final reverse pressure of 2,050psi. PU/SO/ROT 1UO/7U/85. Blow down top drive, POHf/6'8S0'to1QO', L/D BHA. Recovered a handfull of small metal pieces S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-25 Doyon 14 50-029-23089-00-00 202-103 11/8/16 12/4/2016 Daily Operations: ` a 11/25/2016- Friday PU RBP Retrieval Tool, (3)3-1/4" DC's.TIH from 194'. Set down and work past 5,951'. Continue TIH and tag sand @ 6,056' PUH 1' above sand. Pump 29 bbls Hi Vis sweep and follow with clean Sea water displacement @ 6 BPM/3,560psi. Recovered some plug rubber/sand no metals.With clean Sea Water to surface, pump additional bottoms up with trace sand no other debris. PUW 100K/SOW 70K. RIH and tag RBP @ 6,067'w/10K Dn to equalize RBP. Losses @ 100+ bph initially.Took 71 bbls to fill hole and losses diminished to 21 bph. POOH from 6,067' with 10-15K drag. Encounter and pump through tight spot from to 5,921'. RBIH and pull through on elevators with no issues through Float collar @ 5,929'. Park @ 5,921' Blow Down Top Drive. With RBP up into casing, losses increased to 96 bph. Continue POOH on elevators from 5,921' laying down 2 7/8' DP with continual hole fill through kill line choked back to 50 bph. Inspect and L/D RBP and retrieving tools. Note: Establish static loss rate @ 42 bph. PJSM, Install dutch riser, R/U Pollard E-line and lubricator, pump in sup, M/U 2 7/8"x 5 1/2" Paragon packer assy as follows, 4.53" X 2.81" WLEG, 5 1/2" PIIP w/7,200#shear to release and 4,8000#to shear/set, Baker 20 setting tool, CCL, RS= 16.3', OAL= 18'. Note: CCL to center element= 14.37'/ use continuous hole fill @ 42 bph. RIH w/Paragon packer assy on E-line tagging up @ 5,720', work down to 5,810' unable to get deeper, pump down 2 bpm,to 6,042' CCL.Attempt to POH to log, making several attempts up to 700 lbs overpull, unable to pull free or go down. Discussed with project engineer. Decision was made to set packer in place. Set packer @ 6,055' CCL, w/center element @ 6,070',TOP @ 6,066' ELM depth. POH with packer running tools f/6,066' to surface, R/D E-line and lubricator. Load out lubricator and tools. Note: Use continuous hole fill @ 42 bph. PJSM, Load lubricator and tools to rig floor. R/U Haliburton slick line and lubricator, M/U 3"JDC, and 5 1/2" paragon test tool= 36' OAL. pavitT- \ 12A / S • H lcorp A , LLC Weekly' O erationslaskaSummar p Y Well Name Rig API Number Well Permit Number Start Date End Date MP S-25 Doyon 14 50-029-23089-00-00 202-103 11/8/16 12/4/2016 Daily©' I �: rpt Ii' 11/26/2016-Saturday R/U Haliburton slick line and lubricator, M/U 3"JDC, and 5 1/2" paragon test tool= 36' OAL. RIH with test tool. Set tool in Paragon packer @ 6,078 SLM'. POOH and set slick line aside. Close Blind Rams and attempt to test PKR to 3,500psi. No test. RIH and retrieve test tool. POOH and rig down Slick Line unit. Note: Use continuous hole fill @ 42 bph. Lay Down Lubricator Riser. Rig up to run 2-7/8" tubing with 4.5" OD Flat coupling.TIH picking up 2 7/8 Supermax tubing to 4,075'. Note: Use continuous hole fill @ 42 bph Continue TIH picking up 2 7/8 Supermax tubing f/4,075'tagging top of packer @ 6,066', attempt to set wt on packer pushing packer down hole w/ 1-2k to 6080'taking wt, set 5k down, w/no movement working up to 10k w/no movement for 10 min. Note: Use continuous hole fill @ 42 bph POH standing tbg in derrick f/6,080'to surface. L/D flat coupling Note: Use continuous hole fill @ 42 bph M/U Paragon packer retrieving tool, 2 XOs, RIH w/stands 2 7/8"tbg to 6,005', PU/SO 70/60. Note: Use continuous hole fill @ 42 bph M/U last std tbg, RIH slow, tag packer @ 6,081', set down 5k latching onto packer, P/U slow w/ 15k overpull releasing packer, POH slow w/5k drag to 6,054', wait 10 min letting elements relax, continue to POH slow thru FC @ 5,929'seeing 3-4k drag thru FC. Continue POH slow f/5,929'to surface, recovered all of Paragon packer assembly, L/D same. Note: Use continuous hole fill @ 42 bph. 11/27/2016-Sunday M/U Coupling Mule shoe on 2-7/8" Super max Tbg and TIH with 35 stands to 3,280'. POOH laying down tbg from 3,280'. Pull Wear bushing. TIH with 30 stands (90 jts) 2-7/8", 6.5#, L-80 Super Max tubing tp 2,818'. MU Tubing Hanger, land - tubing @a 2,850'. 55K PUW/50K SOW. Blow down choke and kill lines. RILDS and lay down landing joint. Prep location for rig move. N/D BOP, N/U Tree.Test void to 5,000psi. Secure well leaving BPV in well. Continue prepping for rig move. Empty pits, R/D support equipment ect. Move rock washer, Blow down steam and water lines on rig floor. Retract beaver slide. Skid Rig floor into move position. R/D and move rock washer. Rig Released @ 18:00 hrs. Note: Sent in 24 hr notification to AOGCC @ 18:30 hrs for initial BOP test on E-20. PJSM, Notify DSO for pulling rig off well.Jack up rig, pull off well, stage rig in center of pad and set down same. Mobilize rig equipment to E-Pad. PJSM, install rear Boosters, install gooseneck for front Boosters, install front booster, Remove rig mats from around S-25, cleanup around well. Notify MP Security for rig move. Continue to Mobilize rig equipment to E-Pad. Mobilize rig to E-pad Move rig from S-Pad access, left traveling on MP Spine. 11/28/2016-Monday No activity to report. 11/29/2016-Tuesday No activity to report. t6-4/1) ft: 1' • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-25 Doyon 14 50-029-23089-00-00 202-103 11/8/16 12/4/2016 Daily,Op ratio s; _. 4 11/30/26/2016-Wednesday No activity to report. 12/1/2016-Thursday No activity to report. 12/2/2016- Friday Continue rig move on access road to S-Pad location. Stage rig. Remove boosters and lay mats. Spot rig over S-25. Level and shim sub. Skid rig floor. Hook up service lines to rig floor. Pin beaver slide in place. Install exhaust stacks. Spot rockwasher and skid conveyor in place. P/U lubricator and make up to tree. Pull BPV(100 psi tbg, 30 psi on IA). R/U lines for kill operations. Pump down tubing taking returns through choke. Pump @ 3 BPM, 320psi. Saw returns @ 25 bbls into operations. Saw gas initially then crude for the next 30 bbls before cleaning up to saltwater. Increase to 4 BPM, 530psi. Pump 210 bbls with estimated 60% returns then shut choke and bullhead 100 bbls. Bullhead @ final rate of 5.5 BPM, 1110psi. Pump another 50 bbls for a total of 360 bbls 8.5 ppg seawater pumped.Shut down and monitor well. Well on vac. Rig down kill lines and dry rod BPV. Remove tree and N/U 13-5/8", 5K BOP equipment. Pull BPV and install TWC. R/U BOP test equipment. Shell test BOP equipment 300 psi and 2,500psi (ok).Test all BOP components to 250 low/2,500 high w/5 min hold on each. Chart and record same.Test w/2-7/8" test jt. Perform Koomey drawdown test-start psi 3,000, drawdown psi 1,700, 200psi increase @ 44 secs, full charge @ 191 secs, 2130 psi for 6 bottle avg. AOGCC rep (Bob Noble) waived witness. Blowdown test equipment and rig down same.Sym Ops- Load, drift, strap and tally 110 jts, 2-7/8", EUE 8rd, 6.5 ppf, L-80. • • Hilcorp Alaska, LLC Weekly Operations Summary Name Well e RigNumber Well Permit Number Start Date End Date API MP S-25 Doyon 14 50-029-23089-00-00 202-103 11/8/16 12/4/2016 Daily Operations: A 12/3/2016-Saturday Rig down BOP Test Equipment. Pull TWC, MU 2-7/8" Landing joint, BOLDS. Pull and unseat tubing hanger @ 60K, Pull hanger to floor with 55K. Lay down tubing hanger, Prep to POOH with 90 joints Kill String. POOH standing back 2-7/8" tubing from 2850 to surface. MU Paragon II packer assembly: WLEG/5-1/2" Paragon II Packer(7,200#Shear Release), Wire Line Adapter Kit, SWOS Baker Running Tool w/2-3/8" Eue box, XO 2-3/8" x 2-7/8" Eue pin x box, XO Pup 2-7/8" Eue pin x Super Max box Total BHA length = 21.87',TIH with Packer on 2-7/8" tubing from derrick to 2,828'. Continue TIH picking up 2- 7/8" Super Max tubing from pipe shed to 5,923',Cross over tubing string to Top Drive. Pump tubing volume @ 4 BPM/750psi. Catch returns 28 bbls pumped.. Break off Top Drive, drop 1" OD ball. MU Top drive. PUH and park with WLEG @ 5,900', Center of Elements @ 5,898',Top of Paragon Packer @ 5,894'. Chase ball on seat @ 1 bpm/50psi. Ball on seat @ 8 bbls pumped. Walk pressure up to 2,700psi and set packer with good indication. Wait 5 minutes. Set 15K Down on Packer. Break off and lay down circulating equipment. Blow down Top Drive.TOH standing back 2-7/8" tubing from 5,893' to surface. B/O and laydown packer running tool. Retrieve 1" ball from setting tool. R/D power tongs and stage on floor. PJSM, R/U slickline. Hang and secure sheaves. P/U riser Dutchman and install. P/U lubricator and dress .125" wire with 3" SB assy for Paragon test dart. Latch dart to running tool. M/U lubricator to stump. Zero WLM and RIH to tag depth of 5,888' WLM. Release dart on depth and pull out of hole. Secure wireline running tools in lubricator and shut blinds.Secure well for testing. R/U test equipment.Test 5.5", 17#, L-80 to 3,200psi w/30 min hold. Final psi 3,200psi. 2.1 bbls pumped, bled back 2 bbls. Chart and record. R/D test equipment and blowdown lines. RIH with wireline and retrieve test dart on depth. POH to surface. B/O lubricator. B/O test dart. Redress wireline with 3" ID seal bore receptacle (21.55'). M/U lubricator and zero WLM. RIH to 5,800' WLM. Obtain free up wt of 1,000 lbs line tension. S/0 and engage Paragon packer with seal bore receptacle. Pull test to 1,600 lbs to ensure properly anchored (ok). Release SBR and POH with wireline. B/O lubricator. Breakdown running tools and laydown same. Release wireline @ 03:30.Top of SBR @ 5,874' MD. Cut and slip 68' drilling line. Check COM, Inspect deadman, drawworks and saver sub. Service IBOP. Bring SLB completion tools to rig floor and stage. R/U WOT power tongs. Bring control line spool to rig floor and rig up same. Continuous hole fill via IA @ 30 BPH. • I Hilcorp Alaska, LLC WeeklyOperations Summary p Well Name Rig API Number Well Permit Number Start Date End Date MP S-25 Doyon 14 50-029-23089-00-00 202-103 11/8/16 12/4/2016 DailyrO erations: 12/4/2016-Sunday Rig up to run Seal stem/Jest pump cavity on 2-7/8" Super max Tubing. Spot SLB Control line spool on rig floor. PJSM on running completion. MU Completion assembly with WLEG, Seal Stem w/3.875" No-Go Locator, SLB Sapphire Gauge Mandrel,Jet pump Cavity, XO pup to 2-7/8" Supermax Tubing. RIH with 2-7/8" tubing from Derrick, installing every joint for 1st 10 joints then every other joint. Tag top of Seal Bore Receptacle @ 5,872' PUW 72K/SOW 60K. Work Seal Stem into SBR and No-Go w/15K set down @ 5,892'. Lay down tag joints. MU Space out pup,tubing hgr pup and tubing hanger, MU landing joint. Dress tubing hanger with SLB Sapphire Gauge Control line. RIH, working Seal Stem into top of SBR @ 5,872'. Had to make up top drive and rock pipe to pass through top of SBR. PUW 72K/SOW 60K. Clamp Count= 104 Cross Collar Clamps, 3 Single Clamps.Total Joints 186. RILDS, B/O and laydown landing joint. R/D Weatherford casing running equipment. Rig down I-line spool from rig floor. Clean and clear all other tools and equipment from rig floor. PJSM, Nipple down BOP equipment and rack back on pedestal. Remove and laydown mousehole. Clean and prep top of wellhead for tree installation. Remove Surface safety valve from production tree assy. Install production tree/adapter flange and tighten same.Terminate I-wire to penetrator w/gauge (temp/psi).Test hanger void 250 low/5,000 high w/ 10 min hold (ok). Remove BPV and install TWC.Test production tree 5,000psi (ok). Remove TWC. R/U test pump to production valve. Pump 15 bbls diesel down tubing @ 2 bpm. No notable pump psi while freeze protecting tubing. R/D pump equipment. Close all valves on tree, secure well for handover to production. Rig down service lines to rig floor. Prep for skid floor. Prep pipeshed and equipment for demob. Release rig @ 06:00 hrs 12/5/2016- Monday No activity to report. 12/6/2016-Tuesday No activity to report. • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, November 28,2016 11:25 AM To: Ted Kramer Cc: Tom Fouts; Bo York Subject: RE:S-25 - PTD 202-103, Sundry#316-529 Ted, As we discussed on the phone today you can keep the current sundry open. If the work gets delayed by more than 30 days contact me for further guidance. This is assuming Doyon 14 is used to complete the work also. If the Doyon is used to set the 2 7/8"x 5%" paragon packer update the MOC form for this...this change is pre-approved. Makes more sense given the deviation and fluid losses. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Monday, November 28, 2016 10:33 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Tom Fouts<tfouts@hilcorp.com>; Bo York<byork@hilcorp.com> Subject:S-25-PTD 202-103,Sundry#316-529 Guy, Our jet pump completion did not go as planned over the weekend. The paragon packer that we were setting inside of the 5-1/2"casing(Step 12) became hung up in the casing after e-line accidentally got it too deep in the well. At this point,we could not move it up or down. We ended up trying to set it deep(thinking we were in the tail pipe, but it would not hold pressure when we tested it. We then ran in to see if we could put 10,000 lbs of weight on it to get it to shear to recover the packer but it started moving down hole. We then pushed it to bottom on top of the lateral hanger to give us a bottom to stack weight on it. We then ran in with a retrieving tool and managed to latch onto the packer and get it out of the well. Since this is an odd sized packer,we did not have a redress kit for it or a back up. We therefore were forced to run a kill string and move off the well to E-20A to replace the ESP there. In the meantime,we will get a re-dress kit flown up for the paragon packer for S-25 and plan to move either Doyon 14 back to S-25 to finish up or move ASR#1 there after B-1 WSW. A question to sort out is the Sundry. If Doyon#14 moves back,can we suspend the operation and come back and continue under the current Sundry and finish the well,or do we need to close it out and re-submit a new Sundry? 1 • We have a preset number of days that we can use the Doyon#14. If the E-20A goes well,we have time under our contract with Doyon to use that rig. If we run out of days,we may need to use ASR#1. If it is the ASR#1 rig that is used to finish the 5-25, is the path the same? If you would like to discuss this further, please give me a call. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 2 1.0 OF T4ri, 6 THE STATE Alaska Oil and Gas 0f.ik LASKA Conservation Commission „WA#x 333 West Seventh Avenue *'h GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ® Main: 907.279.1433 ALAS- Fax: 907.276.7542 www.aogcc.alaska.gov December 13, 2016 Mr. Wyatt Rivard Well Integrity Engineer Hilcorp Alaska LLC P.O. Box 244027 Anchorage, AK 99524-4027 SCANNED Jt!C 2 7 2017 Re: Docket Number: OTH-16-034 Surface Safety Valve Variance Request Milne Point Unit S-25 (PTD 2021030) Dear Mr. Rivard: By correspondence received December 7, 2016 Hilcorp Alaska LLC (Hilcorp) requested a variance to the requirements of 20 AAC 25.265(c)(1)for Milne Point Unit S-25. Hilcorp's specific request for the alternate placement of the well's surface safety valve is approved. 20 AAC 25.265(c)(1) requires that a well's surface safety valve (SSV) be located within the vertical run of a well's production tree. A recent rig workover of Milne Point Unit S-25 reconfigured the well's completion to incorporate a downhole jet pump with power fluid pumped down the tubing and production fluids returning up the tubing-casing annulus. To provide the required shut-in capability for the well in the event of a low-pressure condition, the actuated surface safety valve will be relocated from the vertical run of the production tree to the tubing- casing annulus outlet. Also,an actuated valve will be installed to block power fluid delivery to the production tree in the event of an emergency condition. The non-actuated master valve remains in the vertical run of the tree. 20 AAC 25.265(o)(1) authorizes Alaska Oil and Gas Conservation Commission to approve a variance from a 20 AAC 25.265 requirement if the variance results in at least equally effective compliance. The Alaska Oil and Gas Conservation Commission finds that Hilcorp's request for the Milne Point Unit S-25 meets this regulatory standard. Sincerely, , Daniel T. Seamount, Jr. Commissioner S • Post Office Box 244027 Anchorage,AK 99524-4027 Hiltarp Alaska.LLC 3800 Centerpoint Drive Suite 100 4 20q, Anchorage,AK 99503 Phone: (907)777-8300 • s+ Fax: (907)777-8301 December 7, 2016 Mr.James Regg Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: MPS-25 (PTD# 2021030) - Request for variance to 20 AAC 25.265(c)(1) Dear Mr. Regg, Hilcorp Alaska, LLC (HAK) requests a variance to 20 AAC 25.265(c)(1) to operate a surface safety valve (SSV) that is not located in the vertical run of the tree on Milne Point Unit (MPU) well S-25 (PTD# 2021030). A rig workover (RWO) on MPS-25 was completed on 12/5/16 to repair a casing leak below 4,666'. The well was originally constructed as a "monobore" producer with a single 7-5/8" casing. As part of the RWO, a 5-1/2" liner was run and cemented in place then tested successfully to 3200 psi on 12/4/16. Following confirmation of casing integrity, the well was completed as a "normal flow"jet pump with high pressure power fluid pumped down the innermost 2-7/8" completion and lower pressure production fluids returning up the 2-7/8"x 5-1/2" liner annulus. Because production is around the innermost 2-7/8" completion, there is no way to utilize an SSV within the vertical run of the tree. Instead, HAK has horizontally mounted the SSV directly to the tree. The valve is a standard 2-1/16" 5M FE CIW valve that will be tied into the Safety Valve System (SVS) low pressure trip. Additionally, there is an actuated power fluid valve installed that will shut-in the high pressure power fluid in the event of a low pressure SVS trip. This configuration provides an equivalent level of protection to an SSV mounted in the vertical run of the tree. The well is currently shut-in as surface connections are being made and will remain shut-in until the alternate configuration is approved. Wellbore schematic, P&ID and the wellhead drawing are attached for reference. Should you have any questions, please contact me at 777-8547. Sincerely, r • Page 12 Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Guy Schwartz Or • • Milne Point Unit Well:' lit MPU 5-25 SCE M ATI C Last Completed: 12/4/2016 Hamra mak,,'if PTD: 202-103 TREE/WELLHEAD Tree 4-1/6"5M FMC Wellhead 11"x 4-1/2"5M Gen 6 w 4.5"TC-II T&B Tubing Orig DF Elev a6.5'/OrigGLElev.=39'Doyon 141 Hanger CIW"H"BPV profile Li- OPEN HOLE/CEMENT DETAIL 2O" 20" 260 sx of Arcticset in 42"Hole 7-5/8" 1380 sx PF'L',293 sx Class"G"in 9-7/8"Hole 4-1/2"x 2 Un-cemented Slotted Liners in a 6-1/2"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 215/A-53/Welded 17.938 Surface 80' 7-5/8" Surface 29.7/L-80/BTC-M 6.875 Surface 6,366' 5-1/2" Production 17#/L-80/Flushmax 4.892 Surface 5,935' LINER DETAIL 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 6,059' 6,106' 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.958 6,106' 10,082' 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 10,082' 10,125' 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.958 6,258' 6,406' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.958 6,406' 10,250' TUBING DETAIL TOC @±3,10.3 2-7/8 Tubing 6.4/L-80/SMAX 2.441 Surf 5,891' WELL INCLINATION DETAIL KOP @ 600'MD s Hole Angle Passes 55 to 68 Deg.@ 2,500'to 5,800 Max Angle in Tubing=68 Deg.@ 5,800' 65 Deg.at sliding sleeve JEWELRY DETAIL No Depth Item 1 5,853' 2-7/8"Accelerated Jet Pump Cavity 2 5,860' 2-7/8"SLB Saphire Gauge Mandrel w/Gauge(Intake) ' 3 5,870' Locator Seal Assembly 4 5,872' Seal Bore Receptacle,21.55'Long 5 5,894' 2-7/8"X 5-1/2"Paragon Packer 6 5,914' WLEG-Bottom at 5,915' 7 5,935' Packer 7-5/8"X 4.80"Bore 8 6,058' Baker 6'Tie-back Sleeve-ID=5.75" 9 6,068' Baker Hook Wall Hanger Inside 7-5/8"Casing 1 10 6,093' Baker Hook Wall Hanger Outside(Hook Point) X12 11 6,258' Baker 7'Tie-back Sleeve 3 12 6,266' Baker ZXP Liner Top Packer 4 13 6,271' Baker 7-5/8"x 5"HMC Liner Hanger OA LATERAL WINDOW DETAIL p ® i Window in7-5/8'Casing @ 10,516'to10,528'(MD)/4,199'to4,201'(TVD) `' Well Angle @ Window=74 Deg. 6 l' GENERAL WELL INFO t 7 API:50-029-23089-00-00 Drilled and Completed by Doyon 141-6/21/2002 8 Re-complete to repair casing leak by Doyon 14-12/4/2016 "OA'Lateral 53'Rat Hole 11 «-: 44 . 12 13 7-5/8" 4 ••OIT Latera 0'Rat Hole 111 TD=10,250'(MD)/TD=4,073(TVD) Revised By:TDF 12/6/2016 • • EXISTING TREE/WELLHEAD Wellheadifree LLC Milne Point Unit Hiker.Mask:. MPS-25 BHTA,Otis,3 1/8 5M 11"X31/8 FMC TG2 Threads T&B3" BW '•' 111M '"' profile ' PM Valve,Saab,CIW -�O O L�p, 31/80 y eJ , DDtrim l <3 .O0 ,b o/ 1-4 w!= E Valve,Master,OW 4)1 7" 3 1/8 5M FF HWO, DDO trim IC) J9, A. h��3 aaapte� 11 F-Se M: FL\Allt il ■ II15i- �a�,le, 0a 21/16/./w0 _ IP16�'0 E�� L, _ IPA (3 ) ..Arici,... . — _II t e:- 2 V26 H14/0s ��I'f'N .,_7 . pit-- IF al F %,.--- • • M.P A s-Z5� PM Zv ZtiD3 Regg, James B (DOA) From: Sloan Sunderland <ssunderland@hilcorp.com> Sent: Sunday, November 13, 2016 6:25 AM To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA) Cc: Ted Kramer; Paul Chan; Paul Mazzolini; Mike Leslie; Bo York Subject: Doyon 14 BOP Usage Attachments: Notice of BOP Usage MP S-25.docx This is a notification and detailed description for using the BOPs on Doyon 14 and operation leading up to using the BOPS. Sloan Sunderland 907-715-0591 % HEDJUNo 8 2.01 , • • • Notice of BOP Usage Date/Time of usage: 11/12/16 15:00 , WeII/Location/PTD: Milne Pt Unit SB S-25, Milne Point S pad, 202-103 Rig Name: Doyon 14 Operator Contact: Sloan Sunderland Operations Summary: On 11/7/2016 Doyon 14 rigged up over S-25 for workover operations. On 11/8 the well was killed by pumping 100 bbls of seawater down the tubing followed by 200 bbls down the annulus. No returns were observed during the operation. Initial BOP test was conducted on 11/9. Fluid was consistently added to the well at a rate of 10—40 bph or a minimum of double displacing during well work. On 11/12 forty-two feet of washover pipe was made up to wash over a tubing stub at 5761' MD to attempt to facilitate the recovery of the tubing down to the overshot above the Baker S-3 packer. While washing over the tubing at 3 bpm at a depth of 5794' returns were noted at the flowline. The pumps were shut down and drill string spaced out. The well was observed flowingwith 20%flow recorded on the flow meter. The upper pipe rams (3-1/2" x 6" VBR's) were shut around the drill pipe, 20 psi was observed on the annular and 0 psi on the drill pipe. The rig pumped down the drill string at 3 bpm against a closed choke without an increase in pressure on the annulus. The choke was opened and a slight flow was noted prior to becoming static. The rig pumped 20 bbls down the drill string with no returns. The rig then pumped through the kill line to get returned flow. A slight vacuum was noted on the annular and drill string. The upper pipe rams were opened and the fluid level was observed dropping. The well was monitored for 20 minutes while maintaining a full column of fluid on the annular side. Well work commenced, continuing to wash over the tubing stump at 3 bpm with partial returns. The returns were being consistently monitored. Gas was observed percolating out of the returns with approximately 20%of the fluid pumped returning. The pumps were shut down and drill string spaced out. Fluid level was observed as falling slightly with gas continuing to break out. The upper pipe rams were shut to pump through the choke to the mud gas separator. While pumping through the separator the returns were noted to be crude oil and gas with minimal returns. Pumping was ceased and the rig lined up and bullheaded 125%annular volume down to the S-3 packer to ensure a full column of good fluid. The annulus was noted to be on a vac, the well was opened up. Well work was commenced until 21:30 when the drill string was pulled out of the hole. BOPE components used during well control operations were tested once out of the hole on 11/13/16 at 02:30. BOPE Used: Upper pipe rams, Choke manifold valves 3, 6 and 5, HCR choke, HCR Kill, Hyd choke. • S Reason for BOPE Use:To control flow from well. Actions Taken/to be taken: 125%of annular volume down to the S-3 packer was bullheaded and the well was on a vacuum. BOPE components used during the operation were tested on 11/13/16 at 02:30; the first trip out of the hole. • S Schwartz, Guy L (DOA) 7 - (0 From: Schwartz,Guy L(DOA) Sent: Friday, November 11, 2016 8:54 PM To: Ted Kramer 3 2` Cc: Sloan Sunderland r} Subject Re: MPS-25 WO Procedure 10-10-2016 - Program Change 2 Ted, Verbal approval granted for changes as shown below. Please update MOC as required. Guy Schwartz AOGCC Sent from my iPhone SCANNED JUN 0 2017 i� On Nov 11,2016,at 7:54 PM,Ted Kramer<tkramer@hilcorp.com>wrote: Guy, Here is the updated procedure. The changes we discussed today on the phone are highlighted in blue. Please reply with your approval for these changes to document your verbal approval of earlier today. Sincerely, Ted Kramer Sr.Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 <MPS-25 WO Procedure 10-10-2016-Program Change 2.docx> 1 • • • 14 Well Prognosis Well: MPS-25 Hilcorp Alaska,LL Date: 11/11/2016 Well Name: MPS-25 API Number: 50-029-23089-00-00 Current Status: Oil Producer Pad: S Pad Estimated Start Date: November 12,2016 Rig: Doyon 14 Reg.Approval Req'd? Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-103 First Call Engineer: Ted Kramer (907)-777-8420(0) (985)-867-0665 (M) Second Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228 (M) AFE Number: Current Bottom Hole Pressure: 1,103 psi @ 3,861'ND (From Offset producer S-35 Gauge Maximum Expected BHP: 1,103psi @ 3,861'ND (No perforating or cleanout planned) Max.Allowable Surface Pressure: 716 psi (Assuming a .1 psi/ft. gas gradient) Brief Well Summary: The Milne Point S-25 well is a Shut In jet pump producer that was found to have a casing leak below 4,666'. Attempts to locate the leak were unsuccessful due to believed bad casing as determined in the ASR Workover attempt to replace the tubing from 9-19-16 to 9-24-16. A 3-1/2" kill string w/a non -sealing overshot was ran in the well. Coil then was RU on the well. CT RIH with a mechanical cutter and cut the mandrel of the Premier packer @ 5,725' in preparation for its removal. RWO Objective: This workover will involve removing the two packers at 5,725'and 5,807' respectively. A Baker ZXP packer will be installed above the tieback sleeve at 6,058'. A 5-1/2"flush joint liner will be ran and cemented in place. A concentric power string of 2-7/8"will be ran inside of the 5-1/2"with a pump cavity. The well will be placed on Jet pump with power fluid down the 2-7/8" and low pressure production fluid coming up the 2-7/8"X 5-1/2" annulus. WO Rig Procedure: 1. MIRU Doyon 14 Rig,ancillary equipment and lines to 500 bbl returns tank. 2. Check for pressure, kill well as needed,set BPV, ND wellhead, NU BOP. a. Test BOPE to 250psi Low/2,500psi High,annular to 250psi Low/2,000psi High (Notify AOGCC 24 hrs in advance of BOP test to give them the opportunity to witness). b. Test rams on 2-7/8" and 5-1/2"test joints. c. Send BOP test report in to AOGCC within 5 days. 3. RU POOH with 3-1/2"Tubing and non-sealing over shot(kill string). Lay down same and send for inspection. • • Well Prognosis Well: MPS-25 Hilcorn Alaska,Lb Date: 11/11/2016 4. PU Fishing tools on 4" drill pipe. RIH fishing/milling to remove the two packers at 5,725' and 5,807' as per fishing companies procedure. Lay down fishing tools. 5--'kJ RIH with 6.60" Gauge Ring on 4" dp to the top of the tic back sleeve at 6,058' (Drift for 7 5/8 29.71f is 6.750",tic back sleeve ID is 5.75"). POOH W/WS. {Note: If Gauge Ring does not make it to depth,then string mills will need to be ran to open up hole to 6.60".J Packer milling run should drift down to the top of Tie back Sleeve. RIH with 5.75 polish mill clean out assembly with no go and 7 5/8 scraper, boot baskets and magnets.Clean out tie back sleeve for W LEG. 6. PU RIH W/ZXP Packer assembly W/hanger and set same according to the vendors procedure. P/U W Leg with RBP already installed &2 joints of 5.5 flush max casing. Set in slips. Dump 50' sand on top. P/U baker ZXP packer assembly with hanger& M/U same. RIH Filling as per baker. Space out W Leg in 6"Tie back.Set packer hanger as per Baker. POOH L/D 4" DP &BHA. 7. Install RBP in the 5 1/2" casing joints below the ZXP packer and dump 50' of sand on top. (Note: The RBP may be set prior to running the packer in the well. ) 8. Pull WB, PU RIH with Seals,cementing tool,float collar,on 5-1/2" 17# Flushmax casing and stab into the ZXP packer. Space out as needed nd set cas'ne in cmcrccncv slips 9. Pressure up on 5-1/2" casing to 500 psi to verify Bullet Seals are landed in the ZXP packer. 10. RU Cementers. Pressure test lines to 4,500 psi. PU on casing to open cementing tool.Cement 5- 1/2" liner in place according to vendors cementing procedure. Bump plug,check that floats are holding. Clean up, RD cementers, and WOC. 11. Lift stack,Set emergency slips as per wellhead rep. Cut 5.5 casing. Rack back BOPs. 12. Install pack off. Install new tubing spool &test void. N/U BOPs&test as per sundry . 13. PU, RIH with 4-3/4" Bit on a 2-7/8"WS. Tag TOC and drill out cement, Float collar. Pressure Test casing to 2,500 psi on chart for 30 min. Continue to drill/wash down to the sand just above the RBP. Circ sand off top of RBP. POOH with Bit. 14. Make reverse circulating clean out run to the top of the RBP. 15. PU RIH with Retrieving Tool to RBP and pull same. POOH W/RBP. L/D 2 7/8 Pac DP. 16. RU E-line. PU RIH with 2-7/8"x 5-1/2" Paragon packer with plug inserted to 5,949 (+/-)'and Set same. RD E-line. 17. ''l pump truca Pressure test packer to 1,500 psi on chart for 30 minutes. Bleed off pressure. 18. PU RIH with the Jet pump cavity and seals. RIH on 2-7/8" Supermax tubing. Stab into seals. Space out same. 19. RU Slick line. RIH and Retrieve plug. Pressure test back side of packer to 1,500 psi. Bleed off pressure. RD Slickline. 20. Hang off well. Set BPV. ND BOP, NU wellhead and test same. 21. RDMO Doyon 14. 22. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Well Prognosis Well: MPS-25 Hilcora Alaska,LL Date: 11/11/2016 4. Choke Manifold Doyon 14 5. Current Wellhead Diagram 6. Proposed Well head diagram 7. Blank Procedure Change Form , •OF Tit, � S • y �� yyy�� THE STATE Alaska Oil and Gas ti�►" � f ® Conservation Commission o ALAsKA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0 Q. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager �� iviAR L Hilcorp Alaska, LLC s 017, 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB S-25 Permit to Drill Number: 202-103 Sundry Number: 316-529 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, de) Daniel T. Seamount, Jr. 7- Commissioner DATED this v day of November, 2016. RBDMS (,V NOV 1 0 2016 0 • RECEIVED . , STATE OF ALASKA `'C 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AO GCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well 0 , Install Casing Q Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q . Change Approved Program❑ Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing ❑ Other. Install Jet Pump Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Hilcorp Alaska LLC Exploratory ❑ Development Q. 202-103' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23089-00-00 . 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes 0 No Q / MILNE PT UNIT SB S-25 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380109 MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,250' ` 4,073' ` 10,250' - , 4,073' 716 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' N/A N/A Production 6,366' 7-5/8" 6,366' 4,160' 6,890ps1 4,790psi Liner"OA" 4,066' 4-1/2" 10,125' 4,084' 8,430psi 7,500psi Liner"OB" 3,992' 4-1/2" 10,250' 4,073' 8,430ps1 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 3-1/2" 9.3#/L-80/EUE 5,722' See Attached Schematic See Attached Schematic 3-1/2" 9.2#/L-80/TCII 5,859' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7-5/8 x 3.5"Bkr Premier,7-5/8 x 3.5"Bkr&Bkr ZXP LTP and N/A • 5,725MD/3,984TVD,5,807MD/4,017TVD&6,266MD/4,146TVD and N/A 12.Attachments: Proposal Summary Q Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch Q Exploratory 0 Stratigraphic 0 Development 0 * Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 11/12/2016 Commencing Operations: OIL Q , WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved �f/ herein will not be deviated from without prior written approval. Contact Ted Kramer ,I iL Email tkramer hilcoro.com Printed Name Bo York Title Operations Manager Si nature 9 Phone 777-8345 Date 10/13/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. .2 t t..4 6.2_9- Plug Integritypp❑ BOP Test Mechanical Integrity Test 0 Location Clearance 0 Other: 1)V> BCZ-rcSC:JA1Z->` 'T1�Sz -2-CCii) V-.. 1 Post Initial InjectionMIT Req'd? Yes 0 No 00 !?BONS w NOV 2016 Spacing Exce. '.n Required? Yes 0 No Subsequent Form Required: I .— 40 �� / APPROVED BY It / Approved�� COMMISSIONER THE COMMISSION Date: INS PM/ l Rice M-Sti 1l ort 1(6 Submit Form and Form 10-403 Revised 11/2015 0 1pNati�rr Lalid for`�17t7 from the date of app��oOval. Attachments in Duplicate • • Well Prognosis Well: MPS-25 Hilcora Alaska,LL' Date: 10/13/2016 Well Name: MPS-25 API Number: 50-029-23089-00-00 Current Status: Oil Producer Pad: S Pad Estimated Start Date: November 12, 2016 Rig: Doyon 14 Reg.Approval Req'd? Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-103 First Call Engineer: Ted Kramer (907)-777-8420 (0) (985)-867-0665 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 1,103 psi @ 3,861' TVD (From Offset producer S-35 Gauge Maximum Expected BHP: 1,103psi @ 3,861' TVD (No perforating or cleanout planned) Max. Allowable Surface Pressure: 716 psi .,1` (Assuming a .1 psi/ft. gas gradient) Brief Well Summary: The Milne Point S-25 well is a Shut In jet pump producer that was found to have a casing leak below 4,666'. Attempts to locate the leak were unsuccessful due to believed bad casing as determined in the ASR Workover attempt to replace the tubing from 9-19-16 to 9-24-16. A 3-1/2" kill string w/a non -sealing overshot was ran in the well. Coil then was RU on the well. CT RIH with a mechanical cutter and cut the mandrel of the Premier packer @ 5,725' in preparation for its removal. RWO Objective: This workover will involve removing the two packers at 5,725' and 5,807' respectively. A Baker ZXP packer will be installed above the tieback sleeve at 6,058'. A 5-1/2" flush joint liner will be ran and cemented in place. A concentric power string of 2-7/8" will be ran inside of the 5-1/2" with a pump cavity. The well will be placed on Jet pump with power fluid down the 2-7/8" and low pressure production fluid coming up the 2-7/8" X 5-1/2" annulus. WO Rig Procedure: 1. MIRU Doyon 14 Rig, ancillary equipment and lines to 500 bbl returns tank. 2. Check for pressure, kill well as needed, set BPV, ND wellhead, NU BOP. a. Test BOPE to 250psi Low/2,500psi High, annular to 250psi Low/2,000psi High (Notify AOGCC 24 hrs in advance of BOP test to give them the opportunity to witness). b. Test rams on 2-7/8" and 5-1/2"test joints. c. Send BOP test report in to AOGCC within 5 days. 3. RU POOH with 3-1/2" Tubing and non -sealing over shot (kill string). Lay down same and send for inspection. • Well Prognosis Well: MPS-25 Hiicorp Alaska,Li' Date:10/13/2016 4. PU Fishing tools on 4" drill pipe. RIH fishing/milling to remove the two packers at 5,725' and 5,807'as per fishing companies procedure. Lay down fishing tools. 5. PU RIH with 6.60" Gauge Ring on 4" dp to the top of the tie back sleeve at 6,058' (Drift for 7-5/8 29.7#is 6.750",tie back sleeve ID is 5.75"). POOH W/WS. (Note: If Gauge Ring does not make it to depth,then string mills will need to be ran to open up hole to 6.60".) 6. PU RIH WI ZXP Packer assembly W/hanger and set same according to the vendors procedure. 7. Install RBP in the 5-1/2" casing joints below the ZXP packer and dump 50' of sand on top. (Note: The RBP may be set prior to running the packer in the well. ) 8. PU RIH with Seals, cementing tool,float collar, on 5-1/2" 17# Flushmax casing and stab into the ZXP packer.Space out and set casing in emergency slips. 9. RU Cementers. Pressure test lines to 4,500 psi. PU on casing to open cementing tool. Cement 5- , \ °'Z] 1/2 liner in place according to vendors cementing procedure. Bump plug, check that floats are -\D i>er holding. Clean up, RD cementers, and WOC. 10. PU, RIH with 4-3/4" Bit on a 2-7/8"WS. Tag TOC and drill out cement, Float collar, and Sand to ur" „p.N.''' just above the RBP. Circ sand off top of RBP. POOH with Bit. 11. PU RIH with Retrieving Tool to RBP and pull same. POOH W/RBP. FN" e 12. RU E-line. PU RIH with 2-7/8"x 5-1/2" Paragon packer with plug inserted to 5,949 (+/-)' and Set ,`i") same. RD E-line. x�\ti 13. RU pump truck. Pressure test packer to 1,500 psi on chart for 30 minutes. Bleed off pressure. c^' 14. PU RIH with the Jet pump cavity and seals. RIH on 2-7/8" Supermax tubing. Stab into seals. Space out same. 15. RU Slick line. RIH and Retrieve plug. Pressure test back side of packer to 1,500 psi. Bleed off pressure. RD Slickline. 16. Hang off well. Set BPV. ND BOP, NU wellhead and test same. 17. RDMO Doyon 14. 18. Turn well over to production. 4. viz, \-)i6A, CAA. ' eSS..:tt;21 Attachments: Fi.u�a �s�`� a P.up-aPED DOL °=' A-1.1/42g-it--"C7 1. As-built Schematic 11- C .-(^� � ` PCP- 2. Proposed Schematic 3. BOP Schematic 4. Choke Manifold Doyon 14 x1/442.1 (16 5. Current Wellhead Diagram 6. Proposed Well head diagram 7. Blank Procedure Change Form • H • • Milne Point Unit Well: MPU S-25 SCHEMATIC Last Completed:9/3/2003 PTD: 202-103 ililcorp Alaska,LLC TREE/WELLHEAD Tree 4-1/6"5M FMC Wellhead 11"x 4-1/2"5M Gen 6 w 4.5"TC-II T&B Tubing Orig DF Elev=66.5'/Orig GL Elev.=39'Doyon 141 Hanger OW"H"BPV profile OPEN HOLE/CEMENT DETAIL ,i 20 L 20" 260 sx of Arcticset in 42"Hole 7-5/8" 1380 sx PF'L',293 sx Class"G"in 9-7/8"Hole 4-1/2"x 2 Un-cemented Slotted Liners in a 6-1/2"Hole WELL INCLINATION DETAIL KOP@600'MD Hole Angle Passes 55 to 68 Deg.@ 2,500'to 5,800 Max Angle in Tubing=68 Deg.@ 5,800' 65 Deg.at sliding sleeve CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 215/A-53/Welded 17.938 Surface 80' 7-5/8" Surface 29.7/L-80/BTC-M 6.875 Surface 6,366' LINER DETAIL 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 6,059' 6,106' k x 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.958 6,106' 10,082' 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 10,082' 10,125' 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.958 6,258' 6,406' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.958 6,406' 10,250' TUBING DETAIL 3-1/2" Tubing 9.3/L-80/EUE 2.992 Surf 5,722' 3-1/2" Tubing 92/L80/TC-II 2.992 5,703' 5,859' JEWELRY DETAIL No Depth Item 1 5,709' X0 Pup 3.5"EUE Box x 4.5"IBT Pin 2 5,715' Crossover-4-1/2"IBT x 5"LTC 8rd w 5"LTC 8rd Pup 3 5,719' 4.5"ID Tubing Stub Overshot 4 5,714' 3.5"HES X-Nipple:ID=2.813" 5 5,725' 7-5/8"x 4.5"Baker Premier Packer:ID=3.870" 6 5,754' 3.5"HES XN-Nipple:ID=2.750"No Go 7 5, 8' Baw/Seals-3-1/2"Tubing Stub Stop @ 5,799' 3.5'Jet Tubing Cut 1 8 5,80797 7 -5/8ker"x35 Overshot"Baker S-3 Packer @5,710.5-9151 la 2 9 5,854' 3.5"HES XN-Nipple:ID=2.750"No Go 3 10 5,857' WLEG-Bottom @ 5,859' 4 5 11 6,058' Baker 6'Tie-back Sleeve Tubing Leak 12 6,068' Baker Hook Wall Hanger Inside 7-5/8"Casing 0' e @5.73 ..i•: 6 13 6,093' Baker Hook Wall Hanger Outside(Hook Point) Casing L_ 14 6,258' Baker 7'Tie-back Sleeve 05,755 �' 7 . 15 6,266' Baker ZXP Liner Top Packer 4. 6 16 6,271' Baker 7-5/8"x 5"HMC Liner Hanger , 3 9 3 e 17 5,714' 3.5"HES X-Nipple:ID=2.813" ka 10 .. 18 6,271' Baker 7-5/8"x 5"HMC Liner Hanger ." OA LATERAL WINDOW DETAIL 8 r Window in 7-5/8"Casing @ 10,516'to 10,528'(MD)/4,199'to 4,201'(TVD) 1,11 Well Angle @ Window=74 Deg. y '12GENERAL WELL INFO 4 13. S at Hole API:50-029-23089-00-00 TA"Lateral Drilled and Completed by Doyon 141-6/21/2002 15?f - 16 14' x, .> Re-complete to repair casing leak by Doyon 141 16 7-5/8" Jet Tubing Cut by Slick Line-9/15/2016 'OB'Lateral 0'Rat Hole TD=10,250'(MD)/TD=4,073'(TVD) Revised By:TDF 9/26/2016 4 • S S Milne Point Unit Well: MPU S-25 PROPOSED Last Completed: 9/3/2003 PTD: 202-103 Hamm Alaska,LLC TREE/WELLHEAD Tree 4-1/6"5M FMC Wellhead 11"x 4-1/2"5M Gen 6 w 4.5"TC-IIT&B Tubing Orig.OF Hey=66.5'/Orig GL Elev.-39'Doyon 141 Hanger CIW"H"BPV profile OPEN HOLE/CEMENT DETAIL 20.,' 20" 260 sx of Arcticset in 42"Hole 7-5/8" 1380 sx PF'L',293 sx Class"G"in 9-7/8"Hole 4-1/2"x 2 Un-cemented Slotted Liners in a 6-1/2"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 215/A-53/Welded 17.938 Surface 80' 7-5/8" Surface 29.7/L-80/BTC-M 6.875 Surface 6,366' 5-1/2" Production 17#/L-80/Flushmax 4.892 Surface ±6,058' LINER DETAIL 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 6,059' 6,106' 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.958 6,106' 10,082' 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 10,082' 10,125' 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.958 6,258' 6,406' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.958 6,406' 10,250' TUBING DETAIL 2-7/8 Tubing I 6.4/L-80/SMAX I 2.441 Surf I ±6,000' WELL INCLINATION DETAIL KOP@600'MD Hole Angle Passes 55 to 68 Deg.@ 2,500'to 5,800 Casing Leak Max Angle in Tubing=68 Deg.@ 5,800' @5,755 65 Deg.at sliding sleeve JEWELRY DETAIL No Depth Item 1 1 ±5,919 2-7/8"Accelerated Jet Pump Cavity 2 2 ±5,923 2-7/8"SLB Saphire Gauge Mandrel w/Gauge(Intake) J 3 3 ±5,927 Locator Seal Assembly ilin1114._ q&5 4 ±5,929 Seal Bore,19.5'Long 6 5 ±5,934 Seal Units x 4 on 15'Seal Extension tri 6 ±5,949 2-7/8"X 5-1/2"Paragon Packer 7 ±5,950 WLEG 8 ±5,954 Seals 7 9 ±5,971 Packer 7-5/8"X 4.80"Bore 10 6,058' Baker 6'Tie-back Sleeve-ID=5.75" 11 6,068' Baker Hook Wall Hanger Inside 7-5/8"Casing 12 6,093' Baker Hook Wall Hanger Outside(Hook Point) 13 6,258' Baker 7'Tie-back Sleeve 14 6,266' Baker ZXP Liner Top Packer 15 6,271' Baker 7-5/8"x 5"HMC Liner Hanger OA LATERAL WINDOW DETAIL Window in 7-5/8"Casing @ 10,516'to 10,528'(MD)/4,199'to 4,201'(TVD) Well Angle @ Window=74 Deg. GENERAL WELL INFO API:50-029-23089-00-00 11 Drilled and Completed by Doyon 141-6/21/2002 ;,*!t „, 12 Re-complete to repair casing leak by Doyon 141 *Mew 4 "OA"Weal 53'Rat Hole 13 14_x: 15 7-5/8" Lateral 0'Rat Hole TD=10,250'(MD)/TD=4,073'(TVD) Revised By:TDF 10/13/2016 • • 1l 6 Hydril GK z Annular BOP 13-5/8"x \\\ 5M pall if ..n I ��13-5/8" x 5M a Doi -:.i 0000 0 © as 00 I a."f O/f 3"x 5M HCR YY YYY // 'I i Ifr T y°]Ili t.. ' AID11 ' --Choke Line Kill Line nn 2111111 ''''''....-''"---3''''''''....-''"---3''x 5M Manual Gate Valve Cr.. "i" � € € 13-5/8"x 5M r�'r__I l r_�€ YY YYY an nnn `-"^--11"x 5M 9-5/8"DBL 0 Seal ( ' i'111ri• 2-1/16"x 5M 11�iI_1i► rift 16-3/4'x 3M Casing Hanger _ 1 SMB-22 V III ,lli,, 0'11 ,, 1 16-3/4"NOM A ILI 9-5/8"BTC Btm x 2-1/16"x5M 14.5"-4 SA Pin Top W/Primary Sea. 20"Casing 9-5/8"Casing • . 10- 111 - 9 . \ n 6';- ------ 0 '11 —f ct , ,- •ik •••,, ,,. S:14 0 Cl) 0 . olb 0 ., 41111. IP a) •,--. 0 4—. ca, ;•-•4 .,.,-. a) 0 0 . , .., w., CO 4111 Chi a) •,—. 0-1 Cli; 4 CD '4.(7.1 mll ink ,• CI 0 • mai......... U. - z Tr ti (o) (A4 ai tr; > Cll I ...-- 4,-.4 _ M 0 L- 0 > II) _c (" o_ 0 a: NI= a) TD 4-, CCS 77:1 Ce . ft IL' a) • ('' 7 v) a) > 0 0 -0 a) a) > Ln m -15 ,-9- Lo >: c kJ (1) U a) ca -1 ' i ••-• c ..-• ce Ln Z _ Co I 0 0 7 rt 7 .4- 4-, E IE — Z >LE 'c5 Tv L6 r`i rn v rn ,:i rl aiocd ,,, 1- . . .LL1 6 •••-(n .,L) ,..,47 0 Lu > Z cc Z 05— o — ,n > (9 AI, Ali 6 E9 MI a >. Z f LI"' 2 iRi rCi '-zi- S M . . WELL MPS-25 DATE 5-23-16 11 Hilcorp Alaska, LLC M I .—... 0 ,L, Swab valve CIW Model FL,4 I W '' 1 ' 1/16" 5K, FE,DD L-U O Via. ,SWing valve CIW Model FL,4 o°o 0 1/16" 5K, FE,DD L-U o iii o 0 0 000.0 °@.0 SSV valve Cameron FL;4 1/ 7I in 16" 5K reverse actuating Cut______"1-') valve, EE.PSL2,PR2 w/ * r Otis actuator -4) rMaster valve CIW Model FL, 4 1/16" 5K, FE,DD L-U ' ' ! :„..,.. „ ,4i.,:w : _ ___ , 2 , ,,... , . .. . 11 x 11 5M FMC Wellhead E 1---:'11.2'"I I I I IH.7T*' ,,,. -fil:7 6112 elU1=4:0:"::*1): [IF l'-'1' ii .. " • • 0 I I] O , A e O iri LI ‘:z110 0 QO jO a 900° o 00®3 A IM m II 111Ili 7111 I. t..30°0 11 I I 1.1 New Tbg spool PN P102110-0002 .-.1—I--. t 11" 5K mg la 11 x 5 %" slip[ hanger with seal ; '- - Current Tbg spool PN 13-301-629 asst F_ ISI I., II 11 I ' . oI ) iy . (I" N • . . � � 3 a) S. J2 aj / �CD ot, � \ % « <a E £ • G o 7 '00 $ % > d = b f �� E j " .- = o o Kra CS \\ Ia)� cu e or co % : a) ■ \ A k 0 \/ E Co 0 £ 4 — o T 0 2 o_ ogo 7 g a) co g9 c /f ) o \ Q \ Ts0 -a CO � 0 0 E« 2 O E § 0. o• c 2 oa O -o E5) k s. II e§ c.§ c■ c w t o � � co0 o_ i a ■ / kQ / k 0. � � � > c 0 2 ) § Q cu 4) w e co 0 � C.) / / $ 12) ° c � 00 / � 2 iZ u E t. / Q � e E � � ft § % _ E . . . Vkk k . . . � . I . . . . . . • • • Quick, Michael J (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Thursday, October 27, 2016 10:43 AM To: Quick, Michael.' (DOA); Bo York Cc: Schwartz, Guy L(DOA) Subject: RE: MPU SB S-25 (PTD 202-103) Sundry application for workover Mike, Thanks for the e-mail. Please see the answers to your questions below in Green. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Quick, Michael J (DOA) [mailto:michael.quick@alaska.gov] Sent: Wednesday, October 26, 2016 3:03 PM To: Ted Kramer; Bo York Cc: Schwartz, Guy L (DOA) Subject: MPU SB S-25 (PTD 202-103) Sundry application for workover Ted— We are reviewing your Sundry application for MPU SB S-25, and request more detail on the following: 1) Step 9 in your procedure discusses cementing the 5-1/2" liner. We require the detailed cementing plan for this operation, including cement type, weight, planned volume, and estimate top of cement. The cement vendor for this job will be Halliburton. The plan for the well will be to pump the calculated volume ( 107.7 bbls) of the of the annular space plus 10 bbls excess to bring cement to surface. Halliburton is the vendor and the cement to be pumped is Halcem 15.8#/gal cement. 2) Step 13 and 15 call out pressure testing values of 1500 psi for the tubing and tubing x casing annulus. What is the planned pumping/circulating pressure of the power fluid for this jet pump? The pressure test value must exceed the planned operating pressure value. This will be a conventional concentric jet pump installation with 2-7/8"tubing inside of the 5-1/2" liner. The high pressure fluid will be pumped down the inside of the 2-7/8"tubing,through the jet pump and and low pressure up the 2-7/8" X 5-1/2" annulus. Return pressure at the surface will be less than 300 psi. Therefore I believe the 1,500 psi test pressure is appropriate(annulus will not see the 3,000 psi ). • 1 Give me a call to discuss as needed. Michael Quick Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1231(phone) (907)276-7542(fax) mike.quick@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Mike Quick at 907-793-1231 or mike.quick@alaska.gov. 2 STATE OF ALASKA ALL OIL AND GAS CONSERVATION COMIISION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program El Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Complete ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: (( s-i--i- Hilcorp Alaska LLC Development Q Exploratory ❑ 202-103 Cr 3.Address: Stratigraphic Service ❑ 6.API Number: IOC"- 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-23089-00-00 IOC2 7.Property Designation(Lease Number): 8.Well Name and Number: 1..�' 0451 ' :,t ADL0380109 MILNE PT UNIT SB S-25 RECEIVE fr._,e--- 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL OCT 0 6 201 11.Present Well Condition Summary: Total Depth measured 10,250 feet Plugs measured N/A feC /L-)1 -ft true vertical 4,073 feet Junk measured N/A feet 5,725,5,807& Effective Depth measured 10,250 feet Packer measured 6,266 feet 3,984,4,017& true vertical 4,073 feet true vertical 4,146 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' N/A N/A Production 6,366' 7-5/8" 6,366' 4,160' 6,890psi 4,790psi Liner"OA" 4,066' 4-1/2" 10,125' 4,084' 8,430psi 7,500psi Liner"OB" 3,992' 4-1/2" 10,250' 4,073' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 3-1/2" 9.3#/L-80/EUE 5,722' 3983 Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80/TCII 5,859' 4,035' 7-5/8 x 3.5"Bkr Premier ,�"_ ".......^..•_.'°,°..�^.,,,. _ 7-5/8 x 3.5"Bkr Packers and SSSV(type,measured and true vertical depth) Bkr ZXP LTP N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A i r SCAMED ED 2 3 Lail, 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: 235 51 587 2,872 230 Subsequent to operation: 0 0 0 60 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❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-404 Contact Ted Kramer Email tkrameric'�i hilcorp.com Printed Name Bo York Title Operations Engineer Signature Phone 777-8345 Date 10/6/2016 Form 10-404 Revised 5/2015Submit Original Only -�04%0 2%-- /e //—1 RBDMS C L_ OCT 1 0 2016 • . Milne Point Unit Well: MPU S-25 SCHEMATIC Last Completed: 9/3/2003 Hamlin Alaska,I1.0 PTD: 202-103 TREE/WELLHEAD Tree 4-1/6"5M FMC Wellhead 11"x 4-1/2"5M Gen 6 w 4.5"TC-Il T&B Tubing Orig.DF Elev=66.5'/Orig GL Elev.=39'Doyon 141 Hanger CIW"H"BPV profile OPEN HOLE/CEMENT DETAIL 20' 20" 260 sx of Arcticset in 42"Hole 7-5/8" 1380 sx PF'L',293 sx Class"G"in 9-7/8"Hole 4-1/2"x 2 Un-cemented Slotted Liners in a 6-1/2"Hole WELL INCLINATION DETAIL KOP@600'MD Hole Angle Passes 55 to 68 Deg.@ 2,500'to 5,800 Max Angle in Tubing=68 Deg.@ 5,800' 65 Deg.at sliding sleeve CASING DETAIL Size Type WV Grade/Conn ID Top Btm 20" Conductor 215/A-53/Welded 17.938 Surface 80' 7-5/8" Surface 29.7/L-80/BTC-M 6.875 Surface 6,366' LINER DETAIL 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 6,059' 6,106' 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.958 6,106' 10,082' 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 10,082' 10,125' 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.958 6,258' 6,406' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.958 6,406' 10,250' TUBING DETAIL 3-1/2" Tubing 9.3/L-80/EUE 2.992 Surf 5,722' ( 34/2" Tubing 9.2/L-80/TC-II 2.992 5,703' 5,859' JEWELRY DETAIL No Depth Item 1 5,709' XO Pup 3.5"EUE Box x 4.5"IBT Pin 2 5,715' Crossover—4-1/2"IBT x 5"LTC 8rd w 5"LTC 8rd Pup 3 5,719' 4.5"ID Tubing Stub Overshot 4 5,714' 3.5"HES X-Nipple:ID=2.813" 5 5,725' 7-5/8"x 4.5"Baker Premier Packer:ID=3.870" 6 5,754' 3.5"HES XN-Nipple:ID=2.750"No Go !.,44 7 5,798' Baker Overshot w/Seals—3-1/2"Tubing Stub Stop @ 5,799' 3.5'Jet Tubing Cut +r3 1 8 5,807' 7-5/8"x 3.5"Baker S-3 Packer @5,710.5-0/15h165^ is 2 9 5,854' 3.5"HES XN-Nipple:ID=2.750"No Go 3 10 5,857' WLEG—Bottom @ 5,859' 4 11 6,058' Baker 6'Tie-back Sleeve Tubing Leak 5 @5 rr 12 6,068' Baker Hook Wall Hanger Inside 7-5/8"Casing Leak = 6 13 6,093' Baker Hook Wall Hanger Outside(Hook Point) Casing@5755 • 9` 7 14 6,258' Baker 7 Tie-back Sleeve 15 6,266' Baker ZXP Liner Top Packer 8 16 6,271' Baker 7-5/8"x 5"HMC Liner Hanger 17 5,714' 3.5"HES X-Nipple:ID=2.813" 0 10 18 6,271' Baker 7-5/8"x 5"HMC Liner Hanger OA LATERAL WINDOW DETAIL Window in 7-5/8"Casing @ 10,516'to10,528'(MD)/4,199'to4,201'(TVD) 11 Well Angle @ Window=74 Deg. 12 13 GENERAL WELL INFO A API:50-029-23089-00-00 "Q4 Lateral 53'Rat Hole Drilled and Completed by Doyon 141-6/21/2002 14 t"-..i.n.'41.*" 15 t7` '�,6 Re-complete to repair casing leak by Doyon 141 7_5/g. Jet Tubing Cut by Slick Line—9/15/2016 "OB Lateral 0'Rat Hole TD=10,250'(MD)/TD=4,073'(TVD) Revised By:TDF 9/26/2016 . • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig _ API Number Well Permit Number Start Date End Date MP S-25 ASR 50-029-23089-00-00 202-103 9/18/16 10/2/16 Daily Ofperattons: 9/14/2016-Wednesday No activity to report. 9/15/2016-Thursday No activity to report. 9/16/2016- Friday No activity to report. 9/17/2016 Saturday No activity to report. 9/18/2016-Sunday Continue to move rig and equipment f/ MP 1-03 to MP S-25. Spot Mud Boat. ND Production Tree per Wellhead Rep. NU BOPE. Install "VR" plug in OA. Remove valve and install flange w/ needle valve on wellhead. Set Well Cover over MP S-25. Set Rig Floor. Release Crane. Move Rig onto Mud Boat. Raise Derrick& pin same. Install Derrick Anchors to Rig. Spot pit trailer into position.Take on 265 bbls of 140 degree 2% KCL to pits at 13:00 hrs.;Continue to R/U ASR unit and prep f/BOPE test. Spot crew trailer and company rep trailer, tie in hydraulic and fluid lines. Electrician on location to R/U gas detection and alarms. Wellhead Rep on location to pull BPV. Pressure noted under BPV, decision to pump 150bbls through BPV to clear pressure f/TBG. IA pressure =Opsi. No pressure under BPV or on the IA, post 150bbls pumped. Wellhead Rep retrieve BPV and set TWC. N/U riser on BOP stack,fill stack w/test fluid and perform shell test on BOPE. (Good Test). Perform BOP test as per BOP testing procedureutilizing 3-1/2" and 4-1/2" test joints.Test to 250psi low f/5 charted mins and 2,500psi high f/5 charted mins on all ram preventers.Test annular element to 250psi low f/5 charted mins and 2,000psi high f/5 charted mins. AOGCC Rep Jeff Jones waived witness of test on 09/18/2016 @ 11:38am. R/D BOP test equipment and blow down fluid lines.Wellhead Rep, check for pressure under TWC, well bleeding off slight pressure. IA pressure=0 psi. Well continuing to bleed off pressure through TWC. Decision to utilize lubricator to pull BPV and bleed any remaining pressure out to the flow back tank. Call Well Support and gather crossovers to R/U lubricator to riser. R/U lubricator, line up flow path through choke, and out to flow back tank. Pull TWC and bleed any pressure off TBG to flow back tank. Less than lbbl flow back, 25psi pressure on open choke to flowback tank. Pressure bled off within a few seconds to zero. Monitor well and prep to P/U landing joint. • • • Hilcorp Alaska, LLC pV" Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-25 ASR 50-029-23089-00-00 202-103 9/18/16 10/2/16 Daily Operations: .M n 9/19/2016- Monday PU 4 1/2" Landing jt. Engage hanger. BOLDS. Pull hanger free 1/wellhead. Pull 120k on pipe. Not free. Work pipe down and PU to 130k. Work pipe down, PU and pipe pulled free w/138k up wt. Pull hanger to rig floor and break out same. PUW 61k. LD hanger and U. Break hanger out of U and send with Wellhead Rep for redress. Pull first joint and RU spooling unit for"I" wire. POH LD 4-1/2" tubing. Recovered 140 joints&jewelry. Cut 3-1/2" pup joint= 5.40'w/a 3-5/8" OD flare at cut. All joints appear to be junk. Pipe was pitted badly with the worst beginning at joint#65 out. Clean and clear rig floor, change out rig floor equipment in prep to RIH w/cut lip guide dress off BHA#1 on 3-1/2" RTS-8 work string. Fill pipe racks with first layer of work string, strap first layer, then add second layer and strap. M/U Baker fishing cut lip guide dress off BHA# 1 and RIH to 18.82'md. Crossover to 3-1/2" RTS-8 work string and RIH to 317'md. Having difficulty making up RTS-8 connection. Decision to center the BOP riser slightly so work string is centered when in the slips to prevent from stabbing pipe crooked. Continue to RIH w/ BHA#1 on 3-1/2" RTS-8 work string to jnt 30 (910'md) line up and fill pipe to get an estimate of fluid level in the well. Pressure seen after 4.7bbls away down 3.5"TBG, estimated fluid top at"'540'md. Continue to RIH w/BHA #1 on 3-1/2" RTS-8 work string f/910'md to 5,300'md. 9/20/2016-Tuesday Continue RIH w/6" X 3-1/2" dress-off BHA on 3-1/2"RTS-8 workstring and tag top of tubing cut at 5,710'. RU wash/rotating head and standpipe hose. MU swivel. Engage pumps w/3 bpm, 45 psi. Observed returns w/70 bbls away. Take returns to flowback tank and circulate to clean wellbore w/3-1/2 bpm, 290 psi. Slow rate to 1 1/2 bpm while waiting on vac truck to arrive w/additional fluid. Load pits and continue pumping. Unable to get returns at 2 bpm. Increase rate to 3 1/2 bpm and observed returns. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number _ Well Permit Number Start Date End Date MP S-25 ASR 50-029-23089-00-00 202-103 9/18/16 10/3/16 Daily Operations: 0 9/21/2016-Wednesday Continue RIH w/6" X 3-1/2" dressoff BHA on 3 1/2" RTS-8 workstring and tag top of tubing cut at 571.01,,RU wash/rotating head and standpipe hose. MU swivel. Engage pumps w/3 bpm,45 psi. Observed returns w/70 bbls away.Take returns to flowback tank and circulate to clean wellbore w/3-1/2 bpm, 290 psi. Work over 3-1/2" stub w/shoe rotating 25 rpm.Tag up on X-Nipple at 5,714'. Continue to rotate to verify on X-Nipple (weight not drilling off,torque increase). PU and work back down over stub w/no rotary. Appears clean. Slow rate to 1-1/2 bpm while waiting on vac truck to arrive w/additional fluid. Load pits and continue pumping. Unable to get returns at 2 bpm. Increase rate to 3-1/2 bpm and observed returns. Continue to circulate to clean wellbore. RU and reverse circulate 300 bbls of 120° source water to get back 1 tubing volume (45 bbls) at 4 bpm. RD wash/ rotating head and standpipe hose. POH LD 3-1/2" workstring & Dressoff BHA. Issues getting power tongs to bite on drill string. Change out dyes on tongs to get an effective bite on the pipe. Rust on pipe balling up M/U dyes on power tongs, brush clean after breaking each connection. Several joints took extra torque to break out due to debris in tool joint. L/D 6" X 3-1/2" dressoff BHA, clean and clear rig floor. M/U Halliburton RTTS test packer on 3-1/2" work string and RIH to 39.74'md. Halliburton hand check function of tool and discuss functionality w/rig crew in order to establish running parameters.;RIH w/ Halliburton RTTS test packer on 3-1/2" work string f/39.72'md to 2,982.56'md. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 5-25 ASR 50-029-23089-00-00 202-103 9/18/16 10/3/16 Daily Operations: = x��' 4 9/22/2016-Thursday Continue to RIH w/7-5/8" RTTS test packer on 3-1/2" PH6 workstring to 5,680' PUW 43k-SOW 23k. Set packer per HES Rep w/2 RH turns. Set down 20k to verify. Fill annulus w/8.5 seawater(23 bbls to fill). Close pipe rams. Pressure up to 3,500psi. Bleeding off quickly. Check surface equipment. Attempt to retest w/no success. Call Anchorage Engineer. Decision made to unseat packer& move up 10'to verify packer is operating properly. Install 2 RH turns to open bypass valve on packer. PU 7k over. Packer not released. Repeat process. No success. Pump down tubing attempting to equalize pressure. No success. Install 2 more RH turns and PU to 14k over. Packer released. PU to 5,670'. Set packer&fill annulus (27 bbls).Pressure up on 7-5/8" casing w/ 1/2 bpm to 3,500 psi.Still bleeding off.Allow to bleed off f/20 min. Bled off f/ 3,500psi to 500psi in 10 min. Bled off f/500psi to 300psi in next 10 min. Pressure began to stabilize at 300psi. Bleed off to 100psi. Begin pumping with 1/4 bpm watching for formation breakdown. Broke over at 930psi. Pump for 3 min to achieve tktnts tlit injection rate. 1/4 bpm, 930psi. POH LD 34 joints to Jnt 157 (4,666'md.) Set RTTS packer per HES Rep. Fill annulus w/8.5 „ �`y ppg seawater(28 bbls).Test 7-5/8" casing to 3,000psi f/5 min. Good test. Bleed off pressure. Release packer. RIH w/ 10 jnts to 4,985'md, set RTTS,fill annulus w/8.5ppg seawater(26bbls). Close pipe rams and test 7-5/8" CSG to 3,400psi. Pressure bled off 500psi over 2mins. Walk down all lines and verify no leaks. Bump pressure back up to 3,400psi and see consistent bleed off. Release RTTS, allow wellbore fluid to U-tube, bleeding returns back to the pits. L/D 5 jnts to 4,831'md. Repeat testing steps. Test pressure bled off with the same trend as earlier, 500psi over 2mins.Verify no leaks in the system and retry.Test continues to bleed off. Call operations engineer and discuss plan forward. Decision made to retest at 4,666'md, chart 1/30mins and POOH w/ HES RTTS packer. L/D 5 more joints to 4,666'md. Set RTTS packer and repeat testing steps.Test CSG to 3,400psi f/30 charted mins. (Good Test). Release RTTS, blow down lines and begin POOH on 3- 1/2" work string. Continue to POOH w/ HES RTTS packer f/4,666'md to 3,328'md. (NPT) Driller noticed small leak coming from hydraulic line on elevators. Isolate pressure to the elevators, remove hyraulic line, retrieve new line from A pad storage and replace. Continue to POOH w/HES RTTS packer f/3,328'md to surface. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-25 ASR 50-029-23089-00-00 202-103 9/18/16 10/3/16 DailyOperations ' l 9/23/2016- Friday LD RTTS. Clean/clear rig floor. Load completion jewelry on catwalk. Load 30 jts of 3-1/2" 9.3# EUE tubing on pipe rack. Strap same. Prep to PU completion.Suspend completions operations per Anchorage Engineer. Contact Wireline companies to get a unit for Caliper Log. Conference call with Anchorage and Milne Point team to discuss a path forward. Decision made to run a Caliper Log, run a kill stringwith Poorboy Oversh_otengag_e 3 2" tubin cut at 5710' land hanger,ND BOPE, NU tree, suspend well and RDMO. ND riser from top of Annular. NU 7" x 11" shooting flange while waiting on Schlumberger slickline to arrive w/ Memory Caliper Log. Schlumberger unit arrived location. Discuss plan forward with Operator and PDS Rep. RU slickline w/S.L. BOPE and 5k psi Stripping Head. Fill hole. Close blinds and test to 500 psi. Schlumberger RIH w/ PDS caliper,tag tubing stump @ 5,703' wireline and and begin logging up w/40 finger caliper to surface. R/D wireline, remove wireline BOPE. SIMOPS: Load and strap 3-1/2" 8rd EUE kill string tubulars . Remove XN nipple f/overshot assembly and remove X nipple profile f/3.5" x 4.5" crossover. Prep rig floor f/ RIH w/ Poorboy Tubing Stub Overshot on 3-1/2" 8rd EUE kill string. Swap crossover on TIW f/ RTS-8 to 8rd EUE. RIH w/ Poorboy Tubing Stub Overshot on 3-1/2" 8rd EUE kill string f/surface to 975'md. Issue w/rig floor anti-collision system not allowing carrier/bales and elevators to lower to tubing stump on rig floor in order to latch up. (NPT) Clean all electrical connections on power tongs. Found parted electrical ground within connection head on transducer cable. Remove cable,take to VMS shop and solder ground back in connection head.Verify line conductivity(Good Test). Return to rig and install.Anti-collision system back up and running. Continue to RIH w/ Poorboy Tubing Stub Overshot on 3-1/2" 8rd EUE kill string f/975'md to 1,400'md.Anti- collision system occasionally mis-reading power tong position, slowing the running speed of the carrier/power swivel. (NPT) Call Prostar and assess the problem. Prostar performed diagnostics and adjusted sensor parameters to allow proper function of anti-collision system. SIMOPS: Driller noticed small hydraulic fluid drip coming from elevators. Swap or fitting on hydraulic line. Continue to RIH w/ Poorboy Tubing Stub Overshot on 3-1/2" 8rd EUE kill string f/1400'md to 5,682' 9/24/2016-Saturday Continue to RIH w/3-1/2" 9.3# L-80 EUE kill string to 5,682' (178 jts). PU joint# 179-180. Lower Poorboy overshot over cut tubing w/no issues.Tag shear screws in O.S. and observe shear w/15k down weight. PU to neutral.Take space out measurements. LD 2 joints. Change handling equipment to 4-1/2". PU 4-1/2" x 3-1/2" XO and 1-4-1/2" Supermax pup joint (4.10'). PU 4-1/2" x 11" FMC Gen 6 hanger w/ pup. Land hanger in wellhead. RILDS. Install BPV. Bottom of O.S. = 5721'. N/D riser, and BOPE. R/D all support lines in the mast, blow down all fluid lines on the rig and set rig floor equipment into move position. Lower mast and remove carrier/truck from mud boat and stage on the side of pad until ready to move. Remove pipe racks, catwalk, and load on NES truck for rig move. Fold up all herculite containment in prep for re-use on MPF-34. Remove 110bbls of fluids from pit trailer and send trailer to MPF-34 to be utilized in well kill. Clean pit# 1 in pit trailer in prep f/welding in new shakers in the pits. Clean and clear location in prep f/move to MPF-34. NOTE: AOGCC was notified of upcoming BOP test on MP F-34 via website at 13:16 hrs on 9/24/16. Inspector Chuck Scheve waived witness of test at 13:49 hrs on 9/24/16. 9/25/2016-Sunday No activity to report. 9/26/2016- Monday No activity to report. 9/27/2016-Tuesday . • IIHilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-25 ASR 50-029-23089-00-00 202-103 9/18/16 10/3/16 04( eratrons ,,,� � , � � p�ioM�i � - 1,iu��d L: eI F.. Jt !� i�oi�i � ui,iy,i,�,��,, eq� om No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-25 CTU 50-029-23089-00-00 202-103 9/18/16 10/3/16 Daily Operations: LO 9/28/2016-Wednesday No activity to report. 9/29/2016-Thursday No activity to report. 9/30/2016- Friday No activity to report. 10/1/2016 -Saturday No activity to report. 10/2/2016-Sunday No activity to report. 10/3/2016- Monday MIRU Halliburton AMU-01 CTU with 18,325' of tapered 1.75" CT. CV= 35.2 bbls. PJSM. Spot up to well. Raise mast. PU injector, 10' of lubricator, and BOP stack. On Well, NU BOPE. BOPE TEST. MU Baker BHA. Pull test CTC to 25k. PT tools to 3,500psi. MU motor and Underreamer. Measurement from No-Go sub to cutter blades was 177" (14.75'). On Well. PT via backside to 300/3,500psi. Open Well, RIH with underreamer. Choke closed. Set down high initially at 5712' ctmd. PU/ RBIH and tag 2nd time at 5,729'. Set down 5k at 5,732'.This puts the No-Go sub at 5,714' (3-1/2" X-Nipple)+ 14.65'to blades = 5,728.65' CUT DEPTH. Start underreaming at 1.2 - 1.3 bpm/3,700psi CTP/248psi WHP. 24 minutes later see erratic CTP spikes. SD pumping. Baker rep thinks cut is made.Attempt to POOH. Overpull 2-3 times, pull free, POOH. Tag up at surface. L/D tools. Wear marks on underreamer blades indicate good cut. RDMO. Secure Well. 10/4/2016-Tuesday No activity to report. • • Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Tuesday, September 27,2016 4:33 PM To: 'Ted Kramer' Cc: Tom Fouts; Bo York Subject: RE: MPU S-25 - PTD 202-103, Sundry#316-404 Ted, You have approval to run the tubing w/overshot and then cut packer mandrel with CT as proposed below. Update the MOC and close out sundry by submitting the 10-404 report(include the CT packer cut work). Additional wellwork to S- 25 will require another sundry. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From:Ted Kramer[mailto:tkramer@hilcorp.com] Sent:Tuesday, September 27, 2016 3:47 PM To: Schwartz, Guy L(DOA) Cc:Tom Fouts; Bo York Subject: RE: MPU S-25 - PTD 202-103, Sundry # 316-404 Guy, Attached is a schematic of how we are leaving S-25 until we can get a larger rig to mill out the packers and run a liner. We are considering the Doyon 14 for this operation. In preparation for this workover, Hilcorp would like to RIH with Coil tubing and cut the mandrel of the Premier Packer @ 5,725'. This will help the workover operation on this well allowing us to pull that top packer leaving only one packer to burn over. Would the AOGCC have an issue with Hilcorp performing this work under this Sundry while we have a coil tubing unit in the field? This would possibly happen this weekend. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 1 • • 0 907-777-8420 C 985-867-0665 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, September 23, 2016 3:07 PM To: Ted Kramer Cc: Tom Fouts; Bo York Subject: RE: MPU S-25 - PTD 202-103, Sundry# 316-404 Ted, You plan as outlined below is approved. Update the MOC as needed and if things change over the weekend feel free to text or call my cell phone. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Friday, September 23, 2016 2:14 PM To: Schwartz, Guy L(DOA) Cc: Tom Fouts; Bo York Subject: RE: MPU S-25 - PTD 202-103, Sundry # 316-404 Guy, We had a conference call this morning concerning the plan forward for this well. We could not locate an E-line unit but did locate a Slickline unit and crew. We plan to run a caliper on slickline and have it processed. I wanted to get this plan forward to you since we are going into the weekend. While waiting on the processing, we plan to run a 3-1/2" kill string with an overshot on the bottom and overshot the 3- 1/2"tubing stub looking up at 5,710" (+/-). We then plan to rig down the ASR off the well and bring in Slickline to set a plug in the X-nipple at 5,714'. This will isolate the well from the perforations. From there we will analyze the caliper data and develop a new plan forward for this well and decide on which rig is appropriate to perform the work. I hope this will meet with the AOGCC's approval. Sincerely, 2 • • Ted Kramer Senior Operations Engineer Hilcorp Alaska LLC 907-777-8420(Office) 985-867-0665 (cell) From:Ted Kramer Sent: Friday, September 23, 2016 8:36 AM To: Schwartz, Guy L(DOA) (auy.schwartz@alaska.gov) Cc: Tom Fouts; Bo York Subject: MPU S-25 - PTD 202-103, Sundry # 316-404 Guy, Please be advised that while conducting the casing pressure test on the above well, we have found a small casing leak. A PIR was established at X bpm @ 930 psi. We then pulled our test packer up to 4,666'and got a good test to 3,000 psi. In order to establish a plan forward,we will be bringing in E-line and running a caliper log to narrow down where this leak may be and to determine the overall condition of the casing from 5,700'to 4,666'and above. Once we have that information,we will devise a new plan forward and let you know what we plan to do. FYI,we have checked the top oil bearing sand in this well and determined that it is located at 4,750'in this well. I am working from home today so please call me on my cell if you would like to discuss further. Sincerely, Ted Kramer Senior Operations Engineer Hilcorp Alaska LLC 907-777-8420(Office) 985-867-0665 (cell) 3 ,4 OF zo �w\�., vi s� THE STATE Alaska Oil and Gas '��—��Iii of LAsKAL Conservation Commission al' t--1-:_=7..4i. 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF *+`'� S Main: 907.279.1433 ALAFax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SCANNEQ JAN / 2:1 Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB S-25 Permit to Drill Number: 202-103 Sundry Number: 316-404 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, /a169i-e...‹,)5L— Chair Cathy P. oerster DATED this of August,2016. RBDMS (,u.,./tiPA 1 (1 ?U16 • e RECEIVED STATE OF ALASKA AUG 0 4 2016 Q ALASKA OIL AND GAS CONSERVATION COMMISSION TS 8 g APPLICATION FOR SUNDRY APPROVALS AOGCtC/� 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing DLJ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: C—.onetp/Fl.. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. w/- PSP Hilcorp Alaska LLC • Exploratory ❑ Development ❑✓ • 202-103 " 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23089-00-00 • 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 • Will planned perforations require a spacing exception? Yes ❑ No Q / MILNE PT UNIT SB S-25 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380109 , MILNE POINT/SCHRADER BLUFF OIL „ 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,250' ' 4,073' ' 10,250' • 4,073' • N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' N/A N/A Production 6,366' 7-5/8" 6,366' 4,160' 6,890psi 4,790psi Liner"OA" 4,066' 4-1/2" 10,125' 4,084' 8,430psi 7,500psi Liner"OB" 3,992' 4-1/2" 10,250' 4,073' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4-1/2" 12.6#i L-80/I BT 5,703' See Attached Schematic , See Attached Schematic 3-1/2" 9.2#/L-80/TCII 5,859' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): • 7-5/8 x 3.5"Bkr Premier,7-5/8 x 3.5"Bkr&Bkr ZXP LTP and N/A - 5,725MD/3,984TVD,5,807MD/4,017TVD&6,266MD/4,146TVD and N/A 12.Attachments: Proposal SummaryEil Wellbore schematic r 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development❑✓ r Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/1/2016 Commencing Operations: OIL Q • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG El 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. Contact Ted Kramer Email tkramer( hilcorp.com Printed Name Bo Bo York Title Operations Manager Signature`/ Phone 777-8345 Date 8/2/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3 1ce 11 O Plug Integrity ❑ BOP Test El Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4 Z )OO los.v /SOP t G�si 4?-51- 43`ro� psi iCk ` ey Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: / p 4104 APPROVED BY Approved by:4.64.4dCOMMISSIONER) 1THE COMMISSION Date: 0-�-/(I �� T RrileaR4tAtlid g `'��" 1 �/ �f7Submit Foorrm and Form 10-403 Revised 11/2015 ® for �[months from the date of approval. Attachments in Duplicate RBDMS bk- AK 1 1 2016 • • Well Prognosis Well: MPS-25 Hilcorp Alaska,LL Date:7/31/2016 Well Name: MPS-25 API Number: 50-029-23089-00-00 Current Status: Oil Producer Pad: S Pad Estimated Start Date: September 1, 2016 Rig: ASR# 1 V Reg.Approval Req'd? Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-103 First Call Engineer: Ted Kramer (907)-777-8420 (0) (985)-867-0665 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 1,103 psi @ 3,861' TVD (From Offset producer S-35 Gauge Maximum Expected BHP: 1,103psi @ 3,861'TVD (No perforating or cleanout planned)/ Max. Allowable Surface Pressure: 716 psi ,/ (Assuming a .1 psi/ft. gas gradient) Brief Well Summary: The Milne Point S-25 well is a jet pump producer that is believed to have developed a tubing leak between 3,000 and 4,500'. RWO Objective: This workover will involve cutting and pulling the 4-1/2" tubing above the packer. A new packer with an over shot to cover the tubing stub looking up will then be installed, and the well returned to production. 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 and 500bbl returns tank with choke manifold. 4. Pressure test lines to 3,000psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing,taking returns up casing to 500bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services. 8. Set BPV. RU crane. ND Tree. NU 11" BOPE. RD Crane. 9. NU BOPE house.Spot mud boat. WO Rig Procedure: 10. MIRU ASR#1 Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if Opsi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5ppg seawater prior to pulling BPV. Set TWC. a. Test BOPE to 250psi Low/2,500psi High. annular to 250psi Low/2,000psi High (hold each �+ ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. 30 \, b. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. 0 . 11 i 0 Well Prognosis Well: MPS-25 Hilcorp Alaska,LU Date:7/31/2016 c. Notify AOGCC 24 hrs in advance of BOP test. d. Test rams on 4-1/2" and 3-1/2"test joints. e. Send BOP test report in to AOGCC within 5 days. 12. 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. tc''Y b. With stack out of the test path, test choke manifold per standard procedure P"V" 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 constantpressure on the equipment and monitor the fluid um rate into the fluid/pump 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. 13. Bleed any pressure off casing to 500bbl returns tank. Pull TWC. Kill well w/8.5 ppg seawater as needed. 14. If able to circulate well, mix and pump caustic soda pill (^'5 lb/bbl) ahead of Baraklean pill (-4 gal/bbl) to clean oil of tubulars. Displace with 8.5 ppg seawater. 15. PU landing joint and BOLDS. 16. Pull over string weight on tubing hanger to confirm free . LD tubing hanger. 17. RU E-line, RIH with CCL and Jet cutter. Locate and cut tubing just below the coupling in the top ' l pup joint below the 4-1/2"X 3-1/2" X/0. ti c Toe 'r--c' X l 2_G i'/,,�f a. Contingency: This step may be performed in'a vance of the rig arriving on location unless (,)19 1u the Rig is needed to pull tension into the tubing string. r 0 00 Ib> 18. RU POOH with 4-1/2"Tubing,Sliding sleeve, and gauges. Note: Look for damage and or hole in the production tubing and Jewelry on way out of the well. Leak__ ction log showed hole between 3,000—4,500'. Document same and notify operations engineer of findings. 19. PU, RIH with 7-5/8" C/O assembly and dress off assembly to top of the 3-1/2"to ing stub. Dress off same. Circ hole clean. POOH with C/O Assembly. 20. PU RIH with 7-5/8"Test Packer to 5,680' and set. Pressure test casing to 3,400 psi. on chart for 30 r min. Bleed pressure and POOH with Test Packer. G, 21. RU SLB I-wire, PU Over shot, Packer, and Gauges on 4-1/2" Production Tubing. RIH and install over shot over the 3-1/2" tubing stub @ (+/-)5,704'. 22. PU Tubing hanger, Space out and land same. RILDS. 23. Drop Ball and rod, lay down landing joint, close blinds. 24. Pressure up on tubing and set packer according to vendor packer setting procedure. Bleed down pressure, recover ball and rod. l 25. Pressure test back side of packer to 3,400 psi. `3"`4' • S Well Prognosis Well: MPS-25 xa`orp Alaska,LL Date:7/31/2016 26. ND Bop, NU well head and test same. 27. Turn well over to production. Attachments: 1. As-built Schematic 2. BOP Schematic 3. Fluid Flow diagram—Forward 4. Fluid Flow Diagram—Reverse 5. Fluid Flow Diagram—Bleed to Pits 6. Blank Procedure Change Form , , 0 Milne Point Unit Well: MPU 5-25 ` SCHEMATIC Last Completed: 9/3/2003 Ilikora Alaska,LLCPTD: 202-103 TREE/WELLHEAD Tree 4-1/6"SM FMC Wellhead 11"x 4-1/2"5M Gen 6 w 4.5"TC-II T&B Tubing Orig.DF Elev=66.5'/Orig GL Elev.=39'Doyon 141 Hanger CIW"H"BPV profile OPEN HOLE/CEMENT DETAIL 20 20" 260 sx of Arcticset in 42"Hole [ M 7-5/8" 1380 sx PF'L',293 sx Class"G"in 9-7/8"Hole 4-1/2"x 2 Un-cemented Slotted Liners in a 6-1/2"Hole 11 1 WELL INCLINATION DETAIL KOP@600'MD ',' Hole Angle Passes 55 to 68 Deg.@ 2,500'to 5,800 Max Angle in Tubing=68 Deg.@ 5,800' 65 Deg.at sliding sleeve 10-3/4"=A • CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 215/A-53/Welded 17.938 Surface 80' 7-5/8" Surface 29.7/L-80/BTC-M 6.875 Surface 6,366' , Li /f / 1 LINER DETAIL '� ,f1D 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 6,059' 6,106' ` t.t 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.958 6,10C2 10,082' �� 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 10,082' 10,125' 3 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.958 6,258' 6,406' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.958 6,406' 10,250' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT 3.958 Surf 5,703' 3-1/2" Tubing 9.2/L-80/TC-II 2.992 5,703' 5,859' JEWELRY DETAIL No Depth Item 1 2,115' GLM#1:CAMCO 4.5"x 1"w/BK Latch Side-pocket KGB-2 GLM 2 5,672' Phoenix Discharge Gauge:ID=3.850" 3 5,679' 4.5"HES"XD"Dura Sliding Sleeve:ID=3.813" 4 5,698' Phoenix Jet Pump Gauge Sensor:ID=2.840"(3,973'TVD) 2 5 5,703' 4.5"x 3.5"X-Over 111 6 5,714' 3.5"HES X-Nipple:ID=2.813" IT1 3 --, 7 5,725' 7-5/8"x 4.5"Baker Premier Packer:ID=3.870" a 8 5,754' 3.5"HES XN-Nipple:ID=2.750"No Go 4b� C) 9 5,798' Baker Overshot w/Sels—3-1/2"Tubing Stub Stop @ 5,799' e (•w icy 10 5,807 7-5/8"x 3.5"Baker S-3 Packer ! 6II 11 5,854' 3.5"HES XN-Nipple:ID=2.750"No Go Tubing Leak 7 12 5,857 WLEG—Bottom @ 5,859' @5,730' t s, 8 13 6,058' Baker 6'Tie-back Sleeve Casing Le.. .:), 14 6,068' Baker Hook Wall Hanger Inside 7-5/8"Casing @5,755 9 1, 15 6,093' Baker Hook Wall Hanger Outside(Hook Point) - 10 11 16 6,258' Baker 7'Tie-back Sleeve 17 6,266' Baker ZXP Liner Top Packer 12 18 6,271' Baker 7-5/8"x 5"HMC Liner Hanger OA LATERAL WINDOW DETAIL Window in 7-5/8"Casing @ 10,516'to 10,528'(MD)/4,199'to 4,201'(TVD) 13 Well Angle @ Window=74 Deg. a 15 GENERAL WELL INFO AI API:50-029-23089-00-00 "Qq"Lateral 53'Rat Hole Drilled and Completed by Doyon 141-6/21/2002 16 `, � 17 4 Re-complete to repair casing leak by Doyon 141 ' 18 7-5/8" J "OB"Lateral 0'Rat Hole 11 TD=10,250'(MD)/TD=4,073'(TVD) Revised By:TDF 7/28/2016 • • Milne Point Unit II Well: MPU S-25 PROPOSED Last Completed: 9/3/2003 Nilcorp Alaska,r.i,c PTD: 202-103 TREE/WELLHEAD OPEN HOLE/CEMENT DETAIL Tree 4-1/6"5M FMC 20" 260 sx of Arcticset in 42"Hole 11"x 4-1/2"5M Gen 6 w 4.5"TC-II T&B Tubing 7-5/8" 1380 sx PF'L',293 sx Class"G"in 9-7/8"Hole Orig.DF Elev X6.5'/OrigGL Elev.=39 Doyon 141 Wellhead Hanger CIW"H"BPV profile 4-1/2"x 2 Un-cemented Slotted Liners in a 6-1/2"Hole WELL INCLINATION DETAIL 20" KOP@600'MD Hole Angle Passes 55 to 68 Deg.@ 2,500'to 5,800 Max Angle in Tubing=68 Deg.@ 5,800' c;. 1 65 Deg.at sliding sleeve CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 215/A-53/Welded 17.938 Surface 80' 7-5/8" Surface 29.7/L-80/BTC-M 6.875 Surface 6,366' LINER DETAIL 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 6,059' 6,106' 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.958 6,106' 10,082' 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 10,082' 10,125' 4-1/2" OB Solid Liner 12.6/L80/IBT 3.958 6,258' 6,406' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.958 6,406' 10,250' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT 3.958 Surf 5,703' 3-1/2" Tubing 9.2/L-80/TC-II 2.992 5,703' 5,859' JEWELRY DETAIL No Depth Item 1 ±2,115' GLM#1:CAMCO 4.5"x 1"w/BK Latch Side-pocket KGB-2 GLM I 2 ±5,636' SLB Saphire Gauge Mandrel w/Gauge(Discharge) 3 ±5,646' 4-1/2"HES Dura Sliding Sleeve:ID=3.813" 4 ±5,650' SLB Saphire Gauge Mandrel w/Gauge(Intake) 1 5 ±5,656' 4.5"x 3.5"X-Over t 6 ±5,676' 3.5"HES X-Nipple:ID=2.870" 2 7 ±5,686' Packer 8 ±5,700' 3.5"XN-Nipple:ID=2.750"No Go 9 ±5,710' 3-1/2"Overshot(No Seals) mo 4 10 5,714' 3.5"HES X-Nipple:ID=2.813" is 5 yr 11 5,725' 7-5/8"x 4.5"Baker Premier Packer:ID=3.870" 6 +r 12 5,754' 3.5"HES XN-Nipple:ID=2.750"No Go A 8 rt—rpt- 13 5,798' Baker Overshot w/Seals–3-1/2"Tubing Stub Stop @ 5,799' 14 5,807' 7-5/8"x 3.5"Baker S-3 Packer Nes ) 15 5,854' 3.5"HES XN-Nipple:ID=2.750"No Go 9 16 5,857' WLEG–Bottom @ 5,859' :10} 17 6,058' Baker 6'Tie-back Sleeve Tubing Leak .,;.. =�,11 @5,730 �: I 18 6,068' Baker Hook Wall Hanger Inside 7-5/8"Casing Casing Leak 12 19 6,093' Baker Hook Wall Hanger Outside(Hook Point) @5,755'—100 013 20 6,258' Baker 7'Tie-back Sleeve 21 6,266' Baker ZXP Liner Top Packer 15 22 6,271' Baker 7-5/8"x 5"HMC Liner Hanger 3 16 OA LATERAL WINDOW DETAIL Window in 7-5/8"Casing @ 10,516'to 10,528'(MD)/4,199'to 4,201'(TVD) 17 Well Angle @ Window=74 Deg. 1819 GENERAL WELL INFO API:50-029-23089-00-00 QA"Lateral 53'Rat Hole Drilled and Completed by Doyon 141-6/21/2002 20 21 t Re-complete to repair casing leak by Doyon 141 , 5/gVs...4s, J "OB"Lateral 0'Rat Hole il TD=10,25Y(MD)/TD=4,073'(1VD) Revised By:TDF 8/1/2016 • • Milne Point ASR Rig 1 BOPE flskntp.Ata.ka.Ell: 11" BOPE Alit- Stripping Head 3.98' MI6. MEliv ° haffer ° 1"- 500 rairal -r 1ituillati i ( r `' gag CI / -U amp 4.54' °m� � IM �° VBR or Pipe Rams � I 11"-5000 r_� :i.—= Blind aim * l ift rain itt 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves 2.00 1 J': f_ ju a i ill Manual Manual Manual HCR Updated 8/19/2015 . • • 44 en 0 a- = (I) 3U N o > > U u;'a • 3 ? 4 is o 5 `rri fir. e w > co .a z m b '''' O y § § El ;::1 Cal tril N OI3 9TJ a '8 U g ~ z J 3_ M Z7 v,♦ 63 TID D7 b s V l' l7 0Tr f Cs QQ ti CO a V m m 0 o m ul V N C N G 'C a� o A a w V _ _ �_ (�-��, ,if, @ O a 1:1 _ to , uIv din 9 ' _O Y N @ d,- Y Z H G 7 V C CO m Y O 01 'P A -floc Q< H I H co 0 m O Y$ Y Q x-1 F– Z -�Q y 2 H 9N Y -oa--Daa— ♦ „ -I F- Y . Y a VIF E m a HI F cc a N D Q c 2 1 -1— H I- -N— H F— a/�(��'fl04- .<I .<I u. j V � O a V 0 • • • - Eu a ® $ $ � aR- a 4 V E o L b 7'dO N Q O V a. U itl C R (y Gi. °e' ,, u > . m „ § § x ND 9T3 a C V in w pu in _1 z ap p �o T is P. 6 i V acu' LTJ 'O 7 G>i p ti Q Z V. C7 2 a 2 ...ppQ 'SO4 o'p w > 7 7 Q ` Z w Z7 in: 61 TTS VID V • M (o ro Y U s E V V m O m m O m N 0G8'Ln N V 41 C N u •� N O a 0 L Au O K > W U 1 ry N a ^ A_ S o > A l V I v — L� 2uignl Q _ _°, a a -0 'lS N 0 Z 9 ie vi 1- F Y, o Lil l7 F 7 V Wm j m O al 401 ii at -II H H 1- K 7 O mN m y2 =-1 H O y a7 0 A Z --004 2 y� 9N Y 11 - 1.' 11 H r tn I-9 a 7 r oc a cc a �L < O 1� Q 7 2 .L a 7 1 0 � LL .2 m L:7) LA • 0 • E.Es i 1,0 co § § CI on9ID > 0 7 0) ,.,•• E Q) '''. > U (D , .S ..-! 0 w z ,c,• o ',35 w .6 d) z < 2:01 < 2 co -I Z ZD tn: 0 HD VD LA co 0 Q 2 _1 F- u co co _1 co 0 o co Ln o 8D o < Lel N g U .a.) c M co C 0.. QJ D I" o _c U 1" L.. u (• . ,---4 _, •,., 1 ___=-- _ _ a, —1XX31 iiict ni 1 0 1 E. t _ . .., ,... LIL El t E NJ -,,-- -0 ivi 1– D U -i MI CC1 0 al cc H H M 2 l'§ < .-. 0 - -01 z 1414 0•411 -I H H 1 • • : • • • • • 2 i i-- 1– ..e, 2 H F– ee on : v;i: —{RI- -N— —I I- .. (---- a c pc; • ili t2 .i, U U . . 0 . • • .... • ,,, � . o a)S. S.• J 2 0 ai73c o w O2 .E \ 2 o.2 § o « E £ • 0 0 . -C3 CO \ § ltd = % f �� \ .E O. � . m \ o \ 2 22 > 2 % 2 / / I a)0.- CO e Ca % .� ■ ■ \ o) k k o E c• 0 k L. ± � ƒ CD / m O \ C a) & 0 ol k/ .c OD = � k U \ -00 -0 k � 0 co §� @ CD 2 E a) § a. o ° 0 2 /' \ i 2 / o D S \ / / § .� \ c / . co $ 0 a I t a) > o § 2 > o k ik CO «k k ' n o o ■ / R % � E O Q ~ § \ Ct m ._ o / o / m $ / CI. $ 2 S o # / co 2 .. _ . • • 5 oU cu E © 0 \ k •— a c >O a E \ RI $ 2 \ / < E ) ) XHVZE Image Project Well History File Cover Page 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. ~O:J - L Q 3 Well History File Identifier 0 Other::, / Date: e I j () '+ 151 IMP '. ~ . II 11111111111111 . . 9 ~ Date: g, 1/. óLt 151 ¡1 VVfP : ~ 3 + c¡ = TOTJ\.L PAGES wf ir ~ Date: g II, 6'1 151 r11PZ Production Scanning J '. lIll, 111111 11111 Page Count from Scanned File: Î D ~ ~ ~ Page Count Matches Number in Scanning Preparation: ~ YES Date: q ~ Lt, [) if 151 Vl1 P Organizing (done) 0 Two-sided 1111111111111111111 RESCAN ~olor Items: 0 Greyscale Items: DIGITAL DATA øOiskettes, No.l} 0 Other, No/Type: 0 Poor Quality Originals: 0 Other: NOTES: BY: Helen ~ Project Proofing BY: Helen ~ Scanning Preparation BY: Helen ~\ ~ x 30 = &D Stage 1 BY: Helen ~ If NO in stage 1, page(s) discrepancies were found: Stage 1 BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: ~scan Needed OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) 0 Logs of various kinds: NO YES NO Date: 151 I - 1111111111111111111 Date: 151 Quality Checked 1111111111111111111 R/Q/?OO4 WI"ll Hic:tory Fill" c;ovpr Panp rlnr • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 L AD FEB 2, 4 2.01Z Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 1 3 Anchorage, Alaska 99501 aJ� cS Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, r.,, Mehreen Vazir BPXA, Well Integrity Coordinator . 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPS -Pad 10/11/2011 Corrosion • Vol of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPS-01A 2070340 50029231410100 0.25 NA 0.25 NA 5.1 9/6/2011 MPS -02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/30/2011 I MPS-03 2021460 50029231050000 Open Flutes - Treated MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/3/2009 MPS-08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/302011 MPS-09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS -10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -11 2021130 50029230920000 1 NA 1 NA 10.2 7/29/2011 MPS -12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7292011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS -14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 7292011 MPS -15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS -16 2030650 50029231510000 1.2 NA 1.2 NA 10.2 7/29/2011 MPS -17 2021730 50029231150000 Open Flutes - Treated MPS -18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7/29/2011 MPS-20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 72912011 MPS -21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS -22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 7282011 MPS -23 2021320 50029230980000 Open Flutes - Treated MPS -24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 7/28/2011 ' MPS-25 2021030 50029230890000 Open Flutes - Treated MPS -26 2030610 50029231500000 1 NA 1 NA 8.5 7/28/2011 MPS-27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7/28/2011 MPS -28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7282011 MPS -29 2021950 50029231190000 Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 1.2 NA 11.9 7282011 MPS -31 2020140 50029230660000 Open Flutes - Treated MPS-32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7282011 MPS-33A 2061720 50029231230100 1 NA 1 NA 6.8 7282011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7282011 MPS-35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-37 2070520 50029233550000 13.9 Need top job NA MPS -39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS -41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS-43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/112011 MPS-90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB-04 500299990799 0.6 NA 0.6 NA 3.4 7/30/2011 . . ···~"r . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill 2021030 nJ;l~ÀJÙ'{ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2004 Well Name/No. MILNE PT UNIT SB S-25 Operator BP EXPLORATION (ALASKA) INC - -------------------~- 10250 --- TVD 4073 /' Completion Date 6/18/2002 ~ Completion Status 1-01L Current Status 1-01L MD --- --- _.~------~------------- REQUIRED INFORMATION ----- -------- - --~------ ----- DATA INFORMATION Mud Log No Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Fnnt Number Name r----~-~-- - ( ED 0 Directional Survey .....;...-/ cYÐ C H391 See Notes ~ Rpt ; €fr()~ ~ 0 LIS Verification Directional Survey Directional Survey 9-ð981 LlSVerification ~// ~D (D Las r12252 v~.' ED J~' 0 Las .) 12252 I ED/ D Las l12252 ~,þÓ , Lps xI1> ~252 !E~ 117 iE~~ ~~~ Directional SurVey Spinner Temperature Casing collar I()c~t()r Well Cores/Samples Information: Name w V~ --\ ~~.\ \ Interval Start Stop )P6L¿ ;<) M') ~;¿ API No. 50-029-23089-00-00 UIC N Samples No /---..... Directional Survey Ges.--J ------- (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No 1 Interval OH / Start Stop CH Received Comments 0 10250 Open 7/17/2002 110 1 0250 Open 12/13/2002 60 10196 Open 8/23/2002 0 10250 Open 7/17/2002 0 1 0250 Open 7/17/2002 60 10196 Open 8/23/2002 0 10250 Open 7/17/2002 0 5829 10/6/2003 0 5829 10/6/2003 0 5829 10/6/2003 0 5829 10/6/2003 ~ ~ 7991 10895 ~08~5ß ?¿Ó2'7~:t~' . Sent Sample Set Number Comments Received -" Digital Well Logging Data / Rate of Penetration, Dual Gamma Ray, Electromagnetic wave Resistivity MWD MWD DATA SUBMITTAL COMPLIANCE REPORT 7/6/2004 Permit to Drill 2021030 Well Name/No. MILNE PT UNIT 5B S-25 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23089-00-00 MD 10250 TVD 4073 Completion Date 6/18/2002 Completion Status 1-01L Current Status 1-01L UIC N ADDITIONAL INFORMATION Well Cored? Y /~ Daily History Received? ŒJN (!yN Chips Received? -Y / N ~ Formation Tops Analysis Received? -Y..L1*--- ~- -- ---- -- -- -------- ---- --- ---- ---~-~- Comments: ~ - ------- --------- ----- -- -------~- ~ Date: ") ~\ 2Æ-o ( J Compliance Reviewed By: ---. Jds.. ) WELL LOG TRANSMITTAL \ &02- \Q3 ProActive Diagnostic Services, 'nc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE: Distribution - Final Print[s] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration(Alaska), Inc. Petro-Technical Data Center LR2-1 900 East Benson Blvd. Anchorage, Alaska 99508 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MVLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUELINE Open Hole 1 Res. Eva!. CH 1 1 1 &25 7 -26-03 Mech. CH 1 J M'7r9.- Caliper Survey r,~.J._'\ -' ~~~:.'" ~¡ ~-.: L) Signed: ~ ' '" -, ~\ ~- !~, ~L(¿~" 0/~ Date .. r\ ("' --I' 0 /). ~; 1''1 t. :,)~ \ - J "r' ,"- ,) ,¡ . Print Name: ""\ .' ~.~:~: ~.tl~;1i2~~~~O¡~ PRoAcTivE DiAGNOSTic SERVicES, INC., PO Box 1 ~69 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ..~ '---- c..- J ~<.. '" ~\ \ \-.----- -. STATE OF ALASKA , ALASKJ )L AND GAS CONSERVATION CC ~ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 66.50' 0 Suspend 181 Repair Well 181 Pull Tubing 0 Operation Shutdown 0 Perforate 0 Plug Perforations 0 Stimulate 0 Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: II Development 0 Exploratory 0 Stratigraphic 0 Service 0 Variance 181 Othel 0 Time Extension Repair Casing Leak 0 Annular Disposal 5. Permit To Drill Number 202-103 6. API Number: 50-029-23089-00-00 Effective depth: measured true vertical 10250 4073 10250 4073 9. Well Name and Number: MPS-25 10. Field I Pool(s): Milne Point Unit I Schrader Bluff feet feet Plugs (measured) NIA feet Junk (measured) NIA feet Size MD TVD Burst Collapse 20" 112' 112' 7-5/8" 6366' 4161' 6890 4790 4-1/2" 6258' - 10250' 4145' - 4073' 7500 8440 8. Property Designation: ADL 380109 11. Present well condition summary Total depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length 112' 6338' 3992' Perforation Depth MD (ft): Slotted Liner - 6406' - 10248' Perforation Depth TVD (ft): Slotted Liner - 4164' - 4074' Tubing Size (size, grade, and measured depth): 4-1/2" x 3-1/2", 12.6# x 9.2# L-80 5857' 5725' & 5807' Packers and SSSV (type and measured depth): S-3 Baker 7-5/8" x 3-1/2" 12. Stimulation or cement squeeze summary: Intervals treated (measured): ...- .,~. ,~.... ,""'.'\ ""'~ ,I. ",'. t "',' ~I .- .~-. ~~ ~~ ';.' ..... .... ~, Treatment description including volumes used and final pressure: r"\è"\~ 0, f ' ~ ."", l.' '.... ~ () ...., , .. Oil-Bbl Representative Daily Average Production or InJectiònData'¡ " ..",: '¡ Gas-Met Water-Bbl CasinQ Pressúre" "'1"ubinQ Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: 0 Exploratory II Development 0 Service 16. Well Status after proposed work: II Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Matt Green, 564-5581 0 Copies of Logs and Surveys run II Daily Report of Well Operations Printed Name Sondra Stewman Si~~~ Form 10-404 Revised 2/2003 Title Technical Assistant Phone 564-4750 OklGINAL . q. 2 Prepared By Name/Number: Date (.J # )O-o~~ondra Stewman, 564-4750 !~, "I ì.nCS~) ~ \1 '-'V'W~'i,j (ô)r)ì 0) ~'I' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-25~ l-\ MPS-25 WORKOVER DOYON DOYON 141 Date From ~ To Hours Task Code NPT Phase 9/1/2003 15:00 - 15:30 0.50 MOB P PRE 15:30 - 17:30 2.00 MOB P PRE 17:30 - 18:30 1.00 MOB P PRE 18:30 - 19:30 1.00 WHSUR P COMP 19:30 - 21 :30 2.00 WHSUR P COMP 21 :30 - 22:00 0.50 WHSUR P COMP 22:00 - 23:00 1.00 WHSUR P CaMP 23:00 - 00:00 1.00 WHSUR P COMP 9/2/2003 00:00 - 01 :00 1.00 WHSUR P COMP 01 :00 - 02:00 1.00 WHSUR P COMP 02:00 - 02:30 0.50 WHSUR P COMP 02:30 - 03:00 0.50 WHSUR P CaMP 03:00 - 04:30 1.50 WHSUR P COMP 04:30 - 08:00 3.50 WHSUR P COMP 08:00 - 09:00 1.00 WHSUR P COMP 09:00 - 10:30 1.50 WHSUR P COMP 10:30 - 11 :00 0.50 WHSUR P COMP 11:00-12:00 1.00 WHSUR P COMP 11 :30 - 12:00 0.50 PULL P COMP 12:00 - 20:30 8.50 PULL P COMP 20:30 - 21 :30 CaMP 1.00 BOPSURP ) Start: 9/1/2003 Rig Release: 9/4/2003 Rig Number: 141 Spud Date: 5/23/2002 End: 9/4/2003 Description ofOperatiÖns Skid rig floor Move rig to MPS-25 Rig up on MPS-25 Rig up circ. line, install landing on tree, Rig Accept @ 18:30 hrs. 9/1/2003 Nipple up Lubricator, pull BPV, rig down same Rig up tubing Annulus to choke manifold, had 1, 160psi on it, tubing 0 psi. Rig up and pumped down tubing 2-3 bbls min 150 psi, Bleeding gas off annulus, pumped 87 bbls sea water down tubing, had water,diesel,crude to surface with 67 bbls pumped, 15 bbls returned. shut down 0 psi on tubing, 180 psi on annulus Reverse lines, bull head down annulus 4 bbls min 430 psi tubing 0 psi bull head down annulus 4 bbls min 450 psi tubing 0 psi total pump 150 bbls sea water Monitor well after one hr. well on vac. 0 psi on tubing and annulus Install TWC in tubing and test from top to 1000 psi, rig down circ. equipment Nipple down tree. Nipple up BOPS Test BOPS and Manifold 250-3,500 psi, Annular 250-2,500, 5 min. per test, performed accumulator test The right to witness test was wavied by Chuck Scheve AOGCC. Was unable to test bottom set of rams due to crossover. Will test bottom rams after laying down tubing. Rigged up lubricator to pull TWC through 13-5/8" BOP stack. Screwed into TWC and pulled with lubricator. Well was on strong vacuum on tubing and annulus has 75 psi. Rigged down lubricator with extensions. Bled off 75 psi from the annulus through the rig gas buster. Gas continued to bleed off annulus. Shot fluid level on annulus-700'. Bullheaded 150 bbls of seawater down annulus at 4 bpm. At 38 bbls away pressure increased from 280 psi to 420 psi. Shut down pump and well was on vacuum. Made up crossover and jt of drill pipe into tubing hanger. Backed out lock down screws. Pick up string with 11 OK weight. No overpulls. Laid down tubing hanger ( no damage observed on impengement area under hanger). Rigged up spooling unit for I-wire. Pulled out of hole laying down tubing. Pumping in displacement fluid every 10 jts at 125% over calculated and 20 bbls every hour. Shot fluid level down tubing after laying down 1000' -330'. Continued pulling and laying down tubing. Shot fluid level at 2500' down tubing- 250'. Finished pulling out of hole laying down tubing. - Recovered 4.25' of fish - Stump looking up 5.62' - Excellent cut on tubing - 00 3.5" with no jagged edges or burrs - (total fluid pumped on trip out laying down tubing 206 bbls) - (79 clamps - 158 pins - 1 ss band - all clamps, pins, bands accounted for) Pump 30 bbls fluid - Install test plug - Rig up test equipment - Test lower rams to 250 low - 3500 psi high for 5 mins each test Printed: 9/8/2003 8:46:50 AM ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPS-25 MPS-25 WORKOVER DOYON DOYON 141 9/2/2003 From~To Hours Task Code NPT Phase 20:30 - 21 :30 1.00 BOPSUR P CaMP 21 :30 - 22:00 0.50 CLEAN P CaMP 22:00 - 23:30 1.50 MOB P COMP 23:30 - 00:00 0.50 CLEAN P COMP 00:00 - 01 :00 1.00 CLEAN P CaMP 01 :00 - 02:30 1.50 CLEAN P CaMP 02:30 - 03:00 0.50 CLEAN P COMP 9/3/2003 03:00 - 03:30 0.50 CLEAN P CaMP 03:30 - 05:30 2.00 CLEAN P CaMP 05:30 - 06:30 1.00 CLEAN P CaMP 06:30 - 08:30 2.00 EVAL P COMP 08:30 - 11 :30 3.00 EVAL P COMP 11 :30 - 12:30 1.00 EVAL P COMP 12:30 - 14:00 1.50 EVAL P COMP 14:00 - 15:00 1.00 EVAL P COMP 15:00 - 15:30 0.50 EVAL P CaMP 15:30 - 16:00 0.50 EVAL P CaMP 16:00 - 17:30 1.50 EVAL P COMP 17:30 - 19:00 1.50 EVAL N WAIT CaMP 19:00 - 21 :30 2.50 RUNCOM' COMP 21 :30 - 00:00 2.50 RUNCOM' COMP 9/4/2003 00:00 - 02:00 2.00 RUNCOM' COMP 02:00 - 03:00 1.00 RUNCOM' COMP Start: 9/1/2003 Rig Release: 9/4/2003 Rig Number: 141 Spud Date: 5/23/2002 End: 9/4/2003 Descriþtionof Operations -Rig down test equipment - Pull test plug - Install wear ring Clear rig floor - mobilize milling assembly on floor - Pump 25 bbls fluid in well - (Pump 25 bbls fluid in well every hour) PJSM - Make up polish milling assembly - Pick up 6 4 3/4" dc's RIH With BHA # 1 - Picking up 4" dp from pipe shed - (Total fluid pumped into well from 0000 hrs to 00:00 hrs 610 bbls) RIH with polish mill BHA - Picking up 66 jts of 4" dp from pipe shed - Filling hole with 25 bbls fluid every hour RIH with 4" dp from derrick - SLM - to 5790' Wash from 5790' to 5798' spm 50 - PP 540 - Pump pressure increased to 640 psi with no additional loss of weight seen on indicator @ 5798' then pressure fell back to 540 psi - Tag top of stump 5799.5' - polish off stump from 5799.5 to 5805' - crude oil back after pumping 60 bbls of fluid - 50 spm 540 psi flow 14% - 35 spm 240 psi flow 4% - 25 bbs crude back - Shut down pump - No flow - Annulus fluid falling Pull up 30' up hole - monitor well - RIH tag up 5805' without pump - Pump 12.5 bbls fluid POH with polish mill assembly - filling hole every 5 stands 3.5 bbls - filling every hour 25 bbls Stood back drill collars and laid down polish mill assembly. Recovered small amount of sand, small pieces of metal and scale in junk baskets. Cleared floor. Made up Halliburton RTTS with bypass and ran in hole to 5781'. Set RTTS at 5781' and filled the annulus with 12.5 bbls of seawater. Hole would not stay full. Closed annular perventor and pressured up on backside and began pumping into hole in casing 3 bpm at 420 psi. Released pressure and opened bypass on RTTS. Pulled RTTS loose and pulled up hole to 5740'. Set RTTS and filled backside with 8 bbls of seawater. Hole standing full. Close top rams and pressured up to 4500 psi. Held pressure for 30 minutes. Good Test. Released pressure and opened bypass and pulled RTTS free. Well went on vacuum. Pulled out of hole with 4" drill pipe standing 40 stands in derrick. Drill pipe overflowed - Possible gas bubble - break circ 1 drill pipe volume = 20 bbls - monitor well - still adding 25 bbls per hour while monitoring well Laying down 4" dp - 4 3/4" dcs - filling hole with 3.5 bbls each 15 joints down and 25 bbls per hour Lay down dc's - Howco RTTS packer Pull wear ring - clear floor PJSM - Rig up tubing running equipment - I-Wire spool Waiting on completions assemblies - Packer - pup joints PJSM - Make up - tail pipe assembly and I-wire connections to pump and gauge sensors Running 4.5" 12.6# L-80 IBT tubing - 90 jts ran @ 3800' filling hole with fluid every hour 25 bbls Con't running 4.5" L-80 12.6# tubing from 3800' to 5750' Space out - Broke I-Wire while picking up to space out Printed: 9/8/2003 8:46:50 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-25 MPS-25 WORKOVER DOYON DOYON 141 Start: 9/1/2003 Rig Release: 9/4/2003 Rig Number: 141 Spud Date: 5/23/2002 End: 9/4/2003 Date From '-To Hours Task Code NPT Phase. . Description of Operations 9/4/2003 03:00 - 04:30 1.50 RUNCOWN HMAN COMP Splice I-Wire - Test 04:30 - 06:00 1.50 RUNCOrvP COMP Make up hanger to landing joint - Run I-Wire through penatrator make up to hanger - Test same - Make up space out pups - Land tubing - RILDS - Lay down landing joint 06:00 - 07:00 1.00 RUNCOrvP COMP Rig up lubricator - Rig up to pump below hanger and down tubing - Rig up Howco slick line 07:00 - 10:00 3.00 RUNCOrvP COMP RIH with 2.7" tapered swedge to 5850' - POH - RIH with 2.813 XN plug - Set in XN nipple @ 5745' - Verify plug set by pressure up to 1000 psi on tubing - POH - Rig down Howco slick line - lubricator and lines for pumping down well 10:00 - 10:30 0.50 RUNCOrvP COMP Set TWC - Test on top to 1000 psi 10:30-11:00 0.50 RUNCOrvP COMP Clear rig floor of all completion tools 11 :00 - 12:00 1.00 RUNCOrvP COMP Nipple down BOP's - Set back on stump 12:00 - 13:30 1.50 RUNCOrvP COMP NU tree - test adapter - I-Wire port - Tree to 5000 psi 13:30 - 14:30 1.00 RUNCOrvP COMP Rig up lubricator - Pull TWC - Rig down lubricator 14:30 - 15:00 0.50 RUNCOrvP COMP Rig up lines and testing equipment 15:00 - 17:30 2.50 RUNCOrvP COMP Set packer @ 2600 psi - Test tubing to 4200 psi for 30 mins - Bleed tubing pressure down to 2500 psi - Test annulus to 4500 psi for 30 mins - Bleed tubing and shear out DCK-2 valve - Bleed off pressure to zero on both sides 17:30 - 18:30 1.00 RUNCOrvP COMP Pump 83 bbls diesel down annulus taking returns from tubing into pits 18:30 - 19:30 1.00 RUNCOrvP COMP U-tube annulus and tubing for freeze protection - clean pits - change out choke spool 19:30 - 20:30 1.00 RUNCOrvP COMP Set BPV - test to 1000 psi from below 20:30 - 21 :00 0.50 RUNCOrvP COMP Secure well - Clean cellar - Release rig @ 21 :00 hrs 9/4/2003 Printed: 9/8/2003 8:46:50 AM ) 1 d,ð¿)-/O 3 I J 39 I WELL LOG TRANSM.ITTAL To: State of Alaska Alaska Oil and Gas Conservation Corum. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 11, 2002 RE: MWD FOffilation Evaluation Logs: MPS-25, AK-MW-22082 MPS-25: Digital Log Images: 50-029-23089-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO mE ATTENTION OF: Spen-y-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Si~ Ú-~~ RECEtVE,D DEC 1 3 L002 teJaska Œ¡ & Gas Gons. C()mmiss~n ÞJlchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised 09/06/02, Start Production ) ) ~- 1. , '" 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3284' NSL, 281' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 4387' NSL, 3821' WEL, SEC. 12, T12N, R10E, UM At total depth 632' NSL, 41091 WEL, SEC. 12, T12N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 66.5' ADL 380109 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 5/23/2002 6/11/2002 6/18/2002 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 10250 4073 FT 10250 4073 FT 0 Yes 181 No 22. Type Electric or Other Logs Run MWD, GR, RES, ABI/IFR / CASANDRA Classification of Service Well 7. Permit Number 202-1 03 8. API Number 50- 029-23089-00 9. Unit or Lease Name Milne Point Unit 10. Well Number MPS.25 11. Field and Pool Milne Point Unit / Schrader Bluff 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost N/A MD 1800' (Approx.) 23. CASING SIZE 20" 7-5/8" , 4-1/2" WT. PER FT. 92# 29.7# 12.6# GRADE H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 112' 42" 28' 6366' 9-7/8" 6258' 10250' 6-1/8" CEMENTING RECORD 260 sx Arctic Set (Approx.) 1380 sx Class PF 'LI, 293 sx Class 'G' Uncemented Slotted Liner AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Liner 6406' -102481 4164' - 4074' 26. TUBING RECORD SIZE DEPTH SET (MD) 4-1/2", 12.6#, L-80 5790' 3-1/2", 9.2#, L-80 57901 - 5855' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 33 Bbls of Diesel PACKER SET (MD) 5803' 25. MD TVD MD TVD 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) September 2, 2002 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL 9/4/2002 12 TEST PERIOD 1875 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF 896 GAs-McF WATER-BBL 3056 WATER-BBL CHOKE SIZE 176 OIL GRAVITY-API (CORR) GAS-OIL RATIO 478 28. CORE DATA ~EÐ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. fiDC~Of! flY;. SEP 2 5 2002 Alaska 01& Gas Cons. eommtssion Anchorage OCT 2 I 20D2 No core samples were taken. f)90MS 8Ft (:/~ Form 10-407 Rev. 07-01-80 Submit In Duplicate ... . ) 29. Geologic Markers Marker Name Measured True Vertical Depth Depth SBF2-NA 5696' 3973' SBF1-NB 5748' 3993' SBE4-NC 5826' 4023' SBE2-NE 5865' 4037' SBE1-NF 5988' 4080' TSBD-OA 6078' 4109' TSBC 6178' 4132' TSBB-OB 6303' 4152' SBA5 6490' 4169' TSBB-OB 10181' 4081' 31. List of Attachments: ) 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RI€ElVED SEP 2 5 2002 AlasRa 01& Gas Gons. CommisSion Anchorage 32. I hereby certify that the for ,poing is true and ?orrect to the best of my knowledge Signed ondra Stewman '. ,r I I ~'-, Title Technical Assistant .. -- ~ ll), P- M PS-25 202-103 Well Number Permit No. I Approval No. INSTRUCTIONS Date ()q - '2 C){) 7--- Prepared By Name/Number: Sandra Stewman, 564-4750 Drilling Engineer: Steve Campbell, 564-4401 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 (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 .. I ) aO~-I03 IO~~1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 21, 2002 RE: MWD Formation Evaluation Logs MPS-25, AK-MW-22082 1 LIS formatted Disc with verification listing. llPI#: 50-029-23089-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETT~R TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Sign~~/£.Qç"r'-.-J RECEIVED AUG 2 J 2002 AIa8ka Oil & Gas Cons. CommiSsion Anctøage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ') 1. Status of Well 1m Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at sUrface. J '¿o-.~I;rL..ÊÌ:¡ÕÑ'11. 3284' NSL, 281' WEL, SEC. 12, T12N, R10E, UM . DATE At top of productive interval "_C' /Ý{>Z 4387' NSL, 3821' WEL, SEC. 12, T12N, R10E, UM i 'If WED .. 6~,t~~~~~~9' WEL, SEC. 12, T12N, R10E, UM t4;,,~~,J 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. KBE = 66.5' ADL 380109 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 5/23/2002 6/11/2002 6/18/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10250 4073 FT 10250 4073 FT Ia Yes 0 No 22. Type Electric or Other Logs Run MWD, GR , RES, ABIIIFR I CASANDRA 23. CASING SIZE 20" 7-5/8" 4-1/2" Classification of Service Well 7. Permit Number 202-1 03 8. API Number 50- 029-23089-00 9. Unit or Lease Name Milne Point Unit 10. Well Number MPS-25 11. Field and Pool Milne Point Unit I Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1800' (Approx.) WT. PER FT. 92# 29.7# 12.6# GRADE H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 112' 42" 28' 6366' 9-7/8" 6258' 10250' 6-1/8" CEMENTING RECORD 260 sx Arctic Set (Approx.) 1380 sx Class PF IL', 293 sx Class IG' Uncemented Slotted Liner AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Liner 25. TUBING RECORD SIZE DEPTH SET (MD) 4-1/2", 12.6#, L-80 5790' 3-1/2",9.2#, L-80 5790' - 5855' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 33 Bbls of Diesel PACKER SET (MD) 5803' MD TVD MD TVD 6406' - 10248' 4164' - 4074' 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR OIL -BBL TEST PERIOD GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) ?8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. :.:,,'.~:;<:i,(~¡ ~ Form 10-407 Rev. 07-01-80 ~. N B D M 5 B F l AUG 2 7 2~mit In Duplicate ') ") 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. SBF2-NA 56961 3973' SBF1-NB 5748' 3993' SBE4-NC 5826' 40231 SBE2-NE 5865' 4037' SBE1-NF 5988' 4080' TSBD-OA 6078' 4109' TSBC 6178' 4132' TSBB-OB 6303' 4152' SBA5 6490' 4169' TSBB-OB 10181' 4081' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak-Off Test Summary 32. I hereby certify that the fore oing is true and correct to the best of my knowledge , . ...-' Signed Sondra ~man Title Technical Assistant Date œ""éX'3--ù Z- MPS-25 Well Number 202-103 Permit No. I Approval No. Prepared By Name/Number: Sondra Stewman, 564-4750 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 (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ) ) BP E)(.PLORATION Operations.SlImmaryReport Page 1 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-25 MPS-25 DRILL +COMPLETE DOYON DOYON 141 Start: 5/23/2002 Rig Release: 6/18/2002 Rig Number: 141 Spud Date: 5/23/2002 End: 6/18/2002 Date From-To HoUrs Task Code NPT Phase Description. of Operations 5/22f2002 09:00 - 09:30 0.50 MOB P PRE MOVE RIG MODULES OUT OF THE WAY OF MPS-25 09:30 - 11 :30 2.00 MOB P PRE FILL IN HOLES AND LEVEL PAD AROUND MPS-25 11 :30 - 12:30 1.00 MOB P PRE MOVE PIPE SHED AND SUB MODULE FROM MPS-27 12:30 - 14:00 1.50 MOB P PRE REPARE PAD AROUND CELLAR ON MPS-25 WITH DIRT WORK FOR 141 FOOT PRINT 14:00 - 15:30 1.50 MOB P PRE LAY MATTS FOR SUB - NIPPLE UP DIVERTOR SYSTEM 15:30 - 17:30 2.00 MOB P PRE LAY MATTS - SPOT / LEVEL SUB MODULE - OVER MPS-25 17:30 - 19:30 2.00 MOB P PRE LAY MATTS - SPOT UTILITY MODULES 19:30 - 20:30 1.00 MOB P PRE SPOT ROCK WASHER - START WITH SERVICE HOOK UP - ELECTRICAL LUG HOOK UP'S 20:30 - 21 :30 1.00 MOB P PRE SET MATTS - SPOT PIPE SHEDS 21 :30 - 23:00 1.50 MOB P PRE FINISH SERVICE HOOK UPS - COMPLETE BERMS - COMPLETE RIG ACCEPT LIST 23:00 - 00:00 1.00 RIGU P PRE LOAD PIPE SHED WITH 4" DP - NIPPLE UP RISER AND FLOW LINE - 5/23f2002 00:00 - 03:30 3.50 RIGU P PRE NIPPLE UP RISER / FLOWLINE - CLEAR CELLAR - MIX SPUD MUD 03:30 - 06:00 2.50 RIGU P PRE LOAD 4" DRILL PIPE AND STRAP IN PIPE SHED - RIG UP HANDLING TOOLS TO PICK UP DRILL PIPE 06:00 - 15:00 9.00 DRILL P INT1 PICK UP AND RACK BACK 4" DRILL PIPE - TOTAL 110 STANDS IN DERRICK 15:00 - 16:00 1.00 DRILL P INT1 CHANGE 4" HANDLING TOOLS TO 5" - PICK UP 17 JOINTS 5" HWDP - JARS - STAND BACK IN DERRICK 16:00 - 16:30 0.50 RIGU P PRE FUNCTION TEST DIVERTOR SYSTEM -ACCUMULATOR TEST - GAS DETECTION SYSTEM - WITNESS OF TEST WAIVED BY CHUCK SHEVE WITH AOGCC 16:30 - 19:00 2.50 DRILL P INT1 MAKE UP BHA#1 - RE-CONFIGURE MTR - ORIENT MOTOR 19:00 - 19:30 0.50 DRILL P INT1 PRE-SPUD MEETING HELD WITH ALL PERSONNEL FOR DRILLING OF MPS-25 - BP, DOYON, PEAK, SPERRY SUN, 19:30 - 20:00 0.50 DRILL P INT1 FILL CONDUCTOR - CIRC THROUGH SYSTEM CHECKING FOR LEAKS - RIH TAG UP @ 104' - DRLG ICE FROM 104' TO 112' 20:00 - 22:00 2.00 DRILL P INT1 SPUD WELL - DRLG 97/8" SURFACE HOLE FROM 112' TO 262' - WOB 0 TO 2k - RPM 50 - TQ 0 - PP 465 - GPM 450 - PU47K-S047K-ROT47K 22:00 - 23:00 1.00 DRILL P INT1 POH - PU 6.5" FLEX DC'S - STABLlZERS - RE-PROGRAM PRESSURE DROP ON MWD FROM 375 TO 275 - COULD NOT GET SURVEY - SYSTEM SET TO HIGH FOR TOOL TO COME ON 23:00 - 00:00 1.00 DRILL N RREP INT1 TROUBLE SHOOT HYDRALlC SYSTEM ON TOP DRIVE - BREAKER TRIPPING ON ON HYDRALlC PUMP - PULLING TOO MUCH AMPERAGE - PULLING 14.5 AMPS 5/24/2002 00:00 - 09:30 9.50 DRILL P INT1 DIRECTIONAL DRILL FROM 262' TO 1193'. WOB 5-20 K, RPM 80, TORQUE 1-3K, PUMP PRESSURE 1600 PSI AT 450 GPM, PU 65K, SO 65K, ROT 65K. SUSPEND OPERATIONS FOR RIG MODS. 6/4/2002 00:00 - 13:00 13.00 DRILL P INT1 DIRECTIONAL DRILL 1193 TO 3031 WITH 80 RPMS 10/15 BIT WT 450 GALS MIN 2000 PSI AST 4.25 ART 3.5 13:00 - 14:00 1.00 DRILL P INT1 CIRC. 14:00 - 18:00 4.00 DRILL P INT1 SHORT TRIP@ 3031, TO BHA, 720' PUMPING OUT( NO PROBLEMS) TRIP BACK TO BOTTOM NO FILL 18:00 - 00:00 6.00 DRILL P INT1 DIRECTIONAL DRILL 3031 TO 3997 WITH 80 RPMS 20/30 BIT WT 500 GALS MIN 2800 PSI AST .75 ART 3.5 Printed: 6/24/2002 1 :20:32 PM ) ) BP EXPLORATION . . . Opèratiol1sSummary Report Page 2 of6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-25 MPS-25 DRILL +COMPLETE DOYON DOYON 141 Start: 5/23/2002 Rig Release: 6/18/2002 Rig Number: 141 Spud Date: 5/23/2002 End: 6/18/2002 Date From - To HOurs Task Code NPT Phase Description of Operations 6/4/2002 18:00 - 00:00 6.00 DRILL P INT1 TO 6000 6/5/2002 00:00 - 21 :00 21.00 DRILL P INT1 DIRECTIONAL DRILL 3997 TO 5706 WITH 80 RPMS 20/30 BIT WT 500 GALS MIN 2800 PSI AST 9.5 ART 3.25 TO 6000 OFF BOTTOM, TO ON BOTTOM 9,000 BIT OUIT ROP DOWN TO 8-10 FT PER HR. WITH 35/TO 40,000 BIT WT. 21 :00 - 23:30 2.50 DRILL P INT1 CIRC, THREE BOTTOM UP, STANDING BACK ONE STAND PER BOTTOMS UP WITH 500 GALS MIN, 2800 PSI, 100 RPMS 23:30 - 00:00 0.50 DRILL P INT1 PUMPING OUT WITH 500 GALS MIN 2800 PSI 6/6/2002 00:00 - 06:00 6.00 DRILL P INT1 PUMPING OUT TO HWP WITH DRILLING RATE 06:00 - 07:30 1.50 DRILL P INT1 TRIPPING OUT WITH BHA. 07:30 - 10:45 3.25 DRILL P INT1 TRIP IN WITH BHA, DOWN LOAD MWD AND UP LOAD MWD 10:45 - 12:00 1.25 DRILL P INT1 TRIP IN TO 1745, HIT BRIDGE WASH AND REAM FROM 1745 TO 1845 12:00 - 15:00 3.00 DRILL P INT1 TRIP IN TO 5590 ,( TIGHT FROM 1845 TO 3050, BACK REAM EVERY 3 STAND TO CLEAN HOLE) LOTS OF SAND COMING ACROSS SHAKERS, INCREASE VIS FROM 80 VIS TO 140 VIS 15:00 - 18:00 3.00 DRILL P INT1 REAMING OUT OF GAUGE HOLE FROM 5590 TO 5706 WITH 500 GALS MIN., 3300 PSI, 10,000 BITWT, LOST 2.5 DEGREES ANGLE 4 DEGREES OF TURN 18:00 - 00:00 6.00 DRILL P INT1 DIRECTIONAL DRILL 5706 TO 6093 WITH 80 RPMS 30/35 BIT WT 500 GALS MIN 3400 PSI AST 3.5 ART .25, ECD 9.9 TO 6000 OFF BOTTOM, TO ON BOTTOM 9,000 6/7/2002 00:00 - 03:30 3.50 DRILL P INT1 DIRECTIONAL DRILL 6093 TO 6378 WITH 80 RPMS 30/35 BIT WT 500 GALS MIN 3400 PSI AST 1.75 ART 1, ECD 9.9 TO 6000 OFF BOTTOM, TO ON BOTTOM 9,000 03:30 - 06:00 2.50 DRILL P INT1 CIRC, THREE BOTTOMS UP, WITH 500 GALS MIN. 3400 PSI 100 RPMS, STANDING BACK 1 STAND EVERY BOTTOMS 06:00 - 07:30 1.50 DRILL P INT1 TRIP OUT TO 5,000, PUMPING AT FULL DRILLING RATE 07:30 - 10:30 3.00 DRILL P INT1 TRIPPING OUT TO HWP 10:30 - 13:00 2.50 DRILL P INT1 TRIPPING OUT WITH BHA, DOWN LOAD MWD,LAYING DOWN MOTOR AND MWD 13:00 - 14:00 1.00 DRILL P INT1 PICKING UP BHA # 4, HOLE OPENER, BIT SUB,2 FLEX COLLARS, STAB, FLEX COLLAR, STAB. 12 HWP,JARS, 5 HWP 14:00 - 14:30 0.50 DRILL P INT1 SERVICE RIG 14:30 - 15:00 0.50 DRILL P INT1 TRIPPING IN TO 1496 15:00 - 18:30 3.50 DRILL P INT1 WASH AND REAM WITH HOLE OPENER FROM 1496 TO 3085, WITH 550 GALS MIN. 2700 PSI 150 RPMS 18:30 - 19:00 0.50 DRILL P INT1 TRIPPING IN FROM 3085 TO 4393 19:00 - 23:00 4.00 DRILL P INT1 WASH AND REAM FROM 4393 TO 6378, WITH 550 GALS MIN. 2700 PSI 150 RPMS 23:00 - 00:00 1.00 CASE P INT1 CIRC, THREE BOTTOMS UP, WITH 550 GALS MIN. 2700 PSI 150 RPMS, 6/8/2002 00:00 - 01 :30 1.50 CASE INT1 CIRC. FOR CSG JOB WITH 150 RPMS 550 GALS MIN 2700 PSI 01 :30 - 04:00 2.50 CASE INT1 TRIPPING OUT TO HWDP, TWO OVERPULLS @ 675 AND 400 FT WIPED CLEAN 04:00 - 07:00 3.00 CASE INT1 LAYING DOWN BHA Printed: 6/24/2002 1 :20: 32 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ') BP EXPLORATION . . OperatIons Summary Report Page 30f6 MPS-25 MPS-25 DRILL +COMPLETE DOYON DOYON 141 Start: 5/23/2002 Rig Release: 6/18/2002 Rig Number: 141 Spud Date: 5/23/2002 End: 6/18/2002 Date From - To Hours Task Gode NPT Phase Descri ption of Operations 6/8/2002 07:00 - 08:30 1.50 CASE INT1 RIG UP CSG TOOLS AND FRANKS TOOL, PJSM 08:30 - 15:00 6.50 CASE INT1 RUNNING 153 JTS 7 5/8 29# L-80 CSG TO 6,366, BRIDGE @ 1750 WORKED TRU, LANDED WITH 80,000 ON HANGER SHOE @ 6366, FLOAT @ 6279, CSG COLLAR 10 FT ABOVE OA SAND 15:00 - 15:30 0.50 CASE INT1 LAY DOWN FRANKS TOOL AND RIG UP CEMENT HEAD 15:30 - 18:00 2.50 CASE INT1 CIRC CSG, WITH 69 PSM, 240 GALS MIN. 600 PSI, REDUCE VIS TO 50 PJSM 18:00 - 22:45 4.75 CASE INT1 CEMENT CSG, PUMP 10 BBLS WATER, TEST LINE TO 3500, PUMP 40 WATER,50 BBLS ALPHA SPACER 10.2, 1020 BBLS LEAD MIX @ 10.7 ,60 BBLS TAIL MIX @ 15.8 DISPLACE WITH 30 BBLS WATER 257 BBLS MUD, BUMP PLUG WITH 2300 PSI, FLOATS HELD, 357 BBLS OF GOOD CEMENT TO SURFACE, FULL RETURN TRU OUT JOB, CEMENT IN PLACE @ 2245 22:45 - 00:00 1.25 CASE INT1 RIG DOWN HEAD AND FLUSH RISER 6/9/2002 00:00 - 03:00 3.00 BOPSUR P INT1 NIPPLE DOWN 20" DIVERTER 03:00 - 07:30 4.50 BOPSUR P INT1 NIPPLE UP GEN 6 WELL HEAD AND TEST TO 1000# FOR TEN MIN., NIPPLE UP BOPS 07:30 - 13:30 6.00 BOPSUR P INT1 TEST BOPS TO 4000# HIGH 250 LOW, HYDRILL 2500 TO 250 TEST WAS WITNESS BY JOHN SPAULDING AOOGC INSTALL WEAR RING 13:30 - 15:00 1.50 CASE P INT1 PICK UP BHA #5 6.125 SEC. 2643 W/3-12, 4 3/4 1.5 BEND MOTOR, FLOAT SUB,RES/GAMMA,DM/PWD,HANG OFF SUB,3-FLEX DC,JARS, WENT TO UPLOAD MWD, NO COMMUNICATION WITH TOOLS 15:00 - 20:30 5.50 CASE N DFAL INT1 TROUBLE SHOOT MWD TOOLS, OUTLINE ON WHAT WE DONE TO TOOLS HAS BEEN FAX IN. 20:30 - 21 :00 0.50 CASE P INT1 FINISH PICKING UP BHA AND PULSE TEST MWD 21 :00 - 22:00 1.00 CASE P INT1 TRIPPING IN TO 2613 22:00 - 23:30 1.50 CASE P INT1 CUT DRILLING LINE AND SERVICE RIG 23:30 - 00:00 0.50 CASE P INT1 TRIPPING IN TO 4205 6/10/2002 00:00 - 01 :30 1.50 CASE P INT1 TRIPPING IN TO 6262, CEMENT STRINGERS @ 6262 01 :30 - 02:30 1.00 CASE P INT1 PRESSURE TEST CSG TO 4,000# FOR 30 MIN. 02:30 - 03:30 1.00 CASE P INT1 DRILL CEMENT AND FLOAT EQ. AND DRILL 30' NEW HOLE TO 6408 03:30 - 04:30 1.00 CASE P INT1 FIT TEST TO 11.3 HELD ON CHART FOR 10 MIN. 9.0 MUD WT. 500 PSI 4160 TVD = 11.3 04:30 - 06:00 1.50 CASE P INT1 DISPLACE HOLE WITH 40 BBLS HIGH VIS PILL AND NEW 9.1 FLOW-PRO MUD 06:00 - 00:00 18.00 DRILL P PROD1 DRILL DIRECTIONAL FROM 6408 TO 8173 WITH 2/5000 BIT WT.,80 RPM,245 GALS MIN. 2150 PSI, TQ 4,000 TO 5500 (ADDING HUBERCARB S-200 AT THE RATE OF 300 LB. HR. AS A BRIDGING AGENT) 6/11/2002 00:00 - 23:00 23.00 DRILL P PROD1 DIRECTIONAL DRILL FROM 8173' TO 10250' T.D. OB LATERAL - WOB 2K TO 4K - RPM 80 TORQUE ON BTM 8K OFF 7K - GPM 245 - PP ON 2000 OFF 11800 - ECD 11.1 - PU 106K SO 35K ROT 80K - TOP OF OB LATERAL 10,181' 23:00 - 00:00 1.00 CASE P COMP CIRCULATE - CONDITION HOLE - GPM 280 - PP 2200 - RPM 90 - TQ 4K 6/12/2002 00:00 - 03:00 3.00 CASE P COMP CIRCULATE 4 BOTTOMS UP - CONDITION MUD / HOLE- 280 GPM - PP 2200 - RPM 90 - TQ 4K Printed: 6/24/2002 1 :20:32 PM ) ') BP EXPLORATION Operations Summary Report Page 4 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-25 MPS-25 DRILL +COMPLETE DOYON DOYON 141 Start: 5/23/2002 Rig Release: 6/18/2002 Rig Number: 141 Spud Date: 5/23/2002 End: 6/18/2002 Date From '- To Hours Task Code NPT Phase Description.of Operations 6/12/2002 03:00 - 06:30 3.50 CASE P COMP PUMP OUT TO SHOE @ 6300' - HOLE IN EXCELLENT SHAPE - NO PROBLEMS 06:30 - 08:30 2.00 CASE P COMP MONITOR WELL - WELL STABLE - PUMP DRY JOB - POH TO BHA 08:30 - 09:30 1.00 CASE P COMP DOWN LOAD MWD - STAND BACK 09:30 - 10:00 0.50 CASE P COMP LD MOTOR - BIT - JARS - CLEAR FLOOR 10:00 - 14:00 4.00 CASE P COMP RIG UP LINER RUNNING TOOLS - PJSM - PU 101 JTS OF 4.5" LINER - LINER HANGER 14:00 - 16:00 2.00 CASE P COMP RUN IN HOLE WITH 4.5" LINER ON 4" DRILL PIPE TO 10250' - NO PROBLEMS - HOLE EXCELLENT SHAPE 16:00 -16:30 0.50 CASE P COMP DROP BALL - CIRC WITH 5 BPM FOR 500 STKS - SLOW TO 2 BPM FOR 575 STKS - BALL ON SEAT - PSI UP TO 1800 SET HANGER - PSI UP TO 3200 BLOW BALL SEAT - RELEASE FROM HANGER - 16:30 - 19:00 2.50 CASE P COMP PUMP DRY JOB - POH WITH LINER RUNNING TOOL - LD RUNNING TOOL 19:00 - 22:00 3.00 STWHIP P PROD2 PU WHIPSTOCK ASSEMBLY - ORIENT MWD - PROGRAM MWD - NO COMMUNICATION ON TOOL 22:00 - 22:30 0.50 STWHIP N SFAL PROD2 TROUBLE SHOOT COMMUNICATION PROBLEM WITH MWD - LAY DOWN TOOL IN PIPE SHED - REPROGRAM TOOL - TOOL FUNCTIONING OK - PICK UP MWD 22:30 - 00:00 1.50 STWHIP P PROD2 MAKE UP MWD - PULSE TEST - PU BUMPER JARS - 4.75" DC'S - 3.5" HWDP - RIH WITH WHIPSTOCK 6/13/2002 00:00 - 03:00 3.00 STWHIP P PROD2 CON'T MAKE UP WHIPSTOCK MILLING ASSEMBLY RIH WITH WHIPSTOCK TO 6030' - ORIENT TOOL - RIH TO 6081' 03:00 - 03:30 0.50 STWHIP P PROD2 SET WHIPSTOCK 3 DEGREE TO LEFT OF HIGH SIDE - TOP OF WINDOW 6081' 03:30 - 10:00 6.50 STWHIP P PROD2 MILL WINDOW FROM 6081' TOP OF WINDOW TO 6093' BOTTOM OF WINDOW - RPM 105 - TO 6K ON BTM - 5K OFF BTM - GPM 250 - PP 1150 - PU 105K - SO 80K ROT 90K 10:00 - 10:30 0.50 STWHIP P PROD2 CLEAN UP WINDOW - WASH AND REAM WINDOW 10:30 - 12:00 1.50 STWHIP P PROD2 CIRCULATE AND CONDITION HOLE 12:00 - 14:00 2.00 STWHIP P PROD2 OSBERVE WELL - WELL STATIC - PUMP DRY JOB - POH TO MILLING ASSEMBLY 14:00 - 16:00 2.00 STWHIP P PROD2 STAND BACK HWDP - DC'S - LD BUMPER SUB - DOWN LOAD MWD - CHANGE OUT MWD PROBE - LD MWD - LD MILL'S AND MILLING TOOLS - CLEAR FLOOR 16:00 - 16:30 0.50 STWHIP P PROD2 PU STACK WASHER - FLUSH OUT BOP'S - LD STACK WASHER 16:30 - 19:00 2.50 STWHIP P PROD2 PU MOTOR - MAKE UP BIT - ADJUST MOTOR - MAKE UP MWD - PROGRAM MWD - ORIENT - RIH WITH NMDC'S - JARS - 2 JTS OF DRILL PIPE - PULSE TEST MWD 19:00 - 21 :00 2.00 STWHIP P PROD2 RIH WITH DRILLING ASSEMBLY TO 6050' - FILLING PIPE EVERY 25 STANDS - ORIENT - CON'T RIH THROUGH WINDOW TO 6111' - NO PROBLEMS 21 :00 - 00:00 3.00 DRILL P PROD2 DIRECTIONAL DRILLING FROM 6111' TO 6346' - WOB 2K TO 4K - RPM 80 - TO ON BTM 5K - OFF BTM 4K - GPM 245 - PP ON BTM 1760 - OFF BTM 1470 - ECD 10.5 - PU 95 - SO 70 - ROT 85 6/14/2002 00:00 - 00:00 24.00 DRILL P PROD2 DIRECTIONAL DRILL FROM 6346' TO 9013' - WOB 2K TO 5K - RPM 80 - TQ ON BTM 6K - OFF BTM 5K - GPM 245 - PP ON BTM 1900 - PP OFF BTM 1700 - ECD 11.2 - PU 100 - SO 54 - ROT 81 Printed: 6/24/2002 1 :20:32 PM ) ') BP EXPLORATION Operations Summary Report . Page 5 of6 Legal Well Name: MPS-25 Common Well Name: MPS-25 Spud Date: 5/23/2002 Event Name: DRILL +COMPLETE Start: 5/23/2002 End: 6/18/2002 Contractor Name: DOYON Rig Release: 6/18/2002 Rig Name: DOYON 141 Rig Number: 141 Date Desctiptionof Operations 6/15/2002 00:00 - 11 :00 11.00 DRILL P PROD2 DIRECTIONAL DRILL FROM 9013' TO 10178' - T.D. OA LATERAL - WOB 2K TO 6K - RPM 80 - TO 8K ON 6K OFF - GPM 245 - PP ON BTM 2050 - PP OFF BTM 1900 - ECD 11.5 -PU103-S040-ROT80 11 :00 - 15:00 4.00 CASE P COMP CIRCULATE / CONDITION HOLE 4 X BOTTOMS - GPM 280- PP 2550 - RPM 90 - TO 7K 15:00 - 18:00 3.00 CASE P COMP FLOW CHECK WELL - WELL STABLE - PUMP OUT TO 6162' - STOP PUMP PULL THROUGH WINDOW TO 6069' - HOLE IN EXCELLENT SHAPE - NO PROBLEMS 18:00 - 20:00 2.00 CASE P COMP MONITOR WELL - WELL STABLE - PUMP DRY JOB - POH TO BHA 20:00 - 21 :00 1.00 CASE P COMP LAY DOWN 2 JTS DP - JARS - XO - 3 FLEX COLLAR'S - BREAK BIT - ADJUST MOTOR - LD MOTOR 21 :00 - 23:30 2.50 CASE P COMP MAKE UP BAKER WHIPSTOCK RETRIEVING TOOL - MWD- ORIENT - DOWN LOAD / UP LOAD MWD - PULSE TEST MWD - RIH WITH - BUMPER SUB - OIL JARS - DC'S - HWDP 23:30 - 00:00 0.50 CASE P COMP CON'T RIH WITH WHIPSTOCK RETRIEVING ASSEMBLY ON 4" DP 6/16/2002 00:00 - 01 :00 1.00 CASE P COMP RIH WITH RETREIVING TOOL TO 6085' 01 :00 - 01 :30 0.50 CASE P COMP ORIENT TOOL TO 3 DEGREE TO LEFT OF HIGH SIDE - LATCH ON TO WHIPSTOCK 01 :30 - 04:00 2.50 CASE P COMP OBSERVE WELL - WELL STATIC - PUMP DRY JOB - POOH WITH WHIPSTOCK 04:00 - 06:00 2.00 CASE P COMP LAY DOWN HWDP - DC'S - MWD - (DOWN LOAD MWD) - RETRIEVING TOOL ASSEMBLY - WHIPSTOCK 06:00 - 07:00 1.00 CASE P COMP CLEAR FLOOR - RIG UP 4.5" LINER RUNNING TOOL'S 07:00 - 10:30 3.50 CASE P COMP PICK UP 4.5" LINER, RUN 130 JTS WITH 129 JTS BEING SLOTTED, TWO 5 3/4" CENTRALIZER PER JT. - MAKE UP HOOK WALL HANGER ASSEMBLY TO LINER' 10:30 - 11 :00 0.50 CASE P COMP RIH WITH LINER TO 6087' 11 :00 - 11 :30 0.50 CASE P COMP ORIENT / ACCESS LINER OUT WINDOW - EXIT WINDOW ON THIRD ATTEMPT 11 :30 - 13:00 1.50 CASE P COMP CON'T RIH WITH LINER TO 10125' 13:00 - 13:30 0.50 CASE P COMP HOOK LINER ON BOTTOM OF WINDOW 6093' - TOP OF LINER AT 6059' 13:30 - 14:30 1.00 CASE P COMP DROP BALL - BALL ON SEAT - PRESSURE UP TO 2500 PSI AND RELEASE FROM HANGER - PRESSURE UP TO 3600 PSI & SHEAR OUT BALL SEAT 14:30 - 15:30 1.00 CASE P COMP CUT DRLG LINE 15:30 - 16:30 1.00 CASE P COMP OBSERVE WELL - PUMP DRY JOB - POH TO 4205' 16:30 - 20:00 3.50 CASE P COMP LAY DOWN EXCESS 4" DRILL PIPE - LINER RUNNING TOOLS - CLEAR FLOOR 20:00 - 20:30 0.50 BOPSUR P COMP PULL WEAR RING - INSTALL TEST PLUG 20:30 - 00:00 3.50 BOPSUR P COMP TEST BOP'S - LOW PRESSURE TEST 5 MINS - HIGH PRESSURE TEST 5 MINS - ANNULAR 250 /2500 - TOP PIPE RAMS 250/4000 - CHOKE MANIFOLD 250 /4000 - HYD KILL / HYD CHOKE 250 /4000 - MANUAL KILL / MANUAL CHOKE 250/4000 - UPPER / LOWER IBOP 250/ 4000 - FLOOR SAFETY VALVES 250 /4000 6/17/2002 00:00 - 01 :30 1.50 BOPSUJ P COMP CON'T BOP TEST - LOWER PIPE RAMS 250/4000 - BLINDS 250 / 4000 - ACCUMLA TOR TEST - ALL TEST GOOD 01 :30 - 02:00 0.50 BOPSU P COMP PULL TEST PLUG -INSTALL WEAR RING 02:00 - 04:00 2.00 RUNCOrvP COMP MAKE UP MULE SHOE - RIH WITH 4" DRILL PIPE TO 6045' Printed: 6/24/2002 1 :20:32 PM ) ') BP EXPLORATION Operations Summary Report Page 6 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-25 MPS-25 DRILL +COMPLETE DOYON DOYON 141 Start: 5/23/2002 Rig Release: 6/18/2002 Rig Number: 141 Spud Date: 5/23/2002 End: 6/18/2002 Date From- To Hours Task Code NPT Phase Descri pHon of. Operations 6/17/2002 04:00 - 07:00 3.00 RUNCOMP COMP CIRCULATE - DISPLACE WELL WITH 500 BBLS OF 8.8 NACL FOLLOWED BY 9.2 NACL WITH CORRISION INHIBITOR 07:00 - 11 :00 4.00 RUNCOMP COMP POH LAYING DOWN 4" DRILL PIPE 11 :00 - 11 :30 0.50 BOPSUR P COMP PULL WEAR RING 11 :30 - 12:00 0.50 RUNCOMP COMP RIG UP 4.5" COMPLETION TOOL'S - PJSM ON RUNNING COMPLETION 12:00 - 20:00 8.00 RUNCOMP COMP RUN 142 JTS 4.5" TUBING WITH COMPLETION ASSEMBLIES - (RAN 72 CLAMPS AND ONE STAINLESS STEEL BAND) - PU 80K - SO 62K - BLOCK WEIGHT 35K 20:00 - 21 :30 1.50 RUNCOMP COMP INSTALL HANGER WITH TWC IN HANGER - TIE IN I WIRE - TEST - LAND TUBING @ 21 :30 HRS 21 :30 - 22:00 0.50 RIGD P COMP LAY DOWN LANDING JOINT - CLEAR FLOOR - TEST TWC / HANGER SEALS TO 1000 PSI - OK 22:00 - 23:30 1.50 RIGD P COMP NIPPLE DOWN BOP'S 23:30 - 00:00 0.50 RIGD P COMP NIPPLE UP ADAPTER FLANGE /41/16" CAMRON TREE 6/18/2002 00:00 - 01 :00 1.00 RIGD P COMP CON'T NU TREE 01 :00 - 02:00 1.00 RIGD P COMP TEST ADAPTER FLANGE AND TREE TO 5000 PSI - OK 02:00 - 02:30 0.50 RIGD P COMP PULL TWC WITH DRY ROD 02:30 - 07:30 5.00 RIGD P COMP RIG UP HB&R - TEST LINES TO 4700 PSI ON ANNULUS - 4300 PSI ON WING VALVE - CIRCULATE WELL COMPLETION FLUID TO 100 DEGREE'S 07:30 - 08:30 1.00 RIGD P COMP DROP BALL - SET PACKER - TEST TUBING TO 4000 PSI FOR 30 MINS - RECORD ON CHART 08:30 - 09:00 0.50 RIGD P COMP TEST ANNULUS TO 4500 PSI FOR 30 MINS - RECORD ON CHART 09:00 - 09:30 0.50 RIGD P COMP SHEAR OUT RP VALVE FOR FREEZE PROTECT 09:30 - 11 :00 1.50 RIGD P COMP PUMP 33 BBLS OF DIESEL FOR FREEZE PROTECTION - 750 FEET 11 :00 - 11 :30 0.50 RIGD P COMP SET BPV 11 :30 - 12:00 0.50 RIGD P COMP SECURE WELL - CLEAN CELLAR - RELEASE RIG @ 12:00 HRS Printed: 6/24/2002 1 :20:32 PM Legal Name: MPS-25 Common Name: MPS-25 Test Date 6/10/2002 Test Type FIT Test Depth (TMD) 6,408.0 (ft) BPEXPLORATION Leak-Off. TestSul11mary Test Depth (TVD) 4,160.0 (ft) AMW 9.00 (ppg) StirfacePressure 500 (psi) li~àkOffPr~s$Ure (ßHP) 2,445 (psi) EMW 11.31 (ppg) ---' --- Printed: 6/24/2002 1 :20:24 PM l BP Exploration (Alaska) Inc. Petrotechnical Data Center, L 900 E. Benson Blvd. Anchorage, AK 99508 Re: Distribution of Survey Data for Well MPS-25 MWD Dear Sir I Madam: ') 1 ~Od-/03 12-Jul-02 Enclosed are 3 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: Window I Kickoff Survey Projected Survey: 0.00' MD 'MD (if applicable) 10,250.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED IJ ~f "-; 7 ¡DO? """""""'''-0 I I ...... ... Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORA T/OR(A:LASKA) INC. Milne,./IJ . .,~- .yUrtlt s".-- Milne Point MPS, Slot MPS-25 MPS--25-'lfWD Job No. AKMW220B2, Surveyed: 11 June, 2002 ~ SURVEY _PORT 10 July, JØJJ2 Your Ref: API 5lJØ2J230B900 Surface Coordinates: 5999951.95 N, 565729.35 E (70.24' 37.1260" N, 149027' 53.2236" W) Kelly Bushing: 66.500 above Mean Sea Level --' -.þl!ti :'1. .V.:-rq II! DRILLING Sh-RVIC&S A Halliburton Company Survey Ref: 5vy10142 Sperry-Sun Drillil/lg Services . Survey Report for MI'$-25 MWD Your Ref: API 5OtJ~92308900 Job No. AKMW22082, Surveyed: 11 June, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -66.50 0.00 O.OON O.DOE 5999951.95 N 565729.35 E 0.00 MWD Magnetic 121.29 0.270 159.550 54.79 121.29 0.275 0.10 E 5999951.68 N 565729.45 E 0.223 0.07 207.29 0.580 189.880 140.79 207.29 0.895 0.10 E 5999951.06 N 565729.45 E 0.433 0.43 297.60 0.220 270.440 231.10 297.60 1.34 5 0.16W 5999950.61 N 565729.21 E 0.648 0.89 387.79 1.670 322.820 321.27 387.77 0.29S 1.12W 5999951.65 N 565728.23 E 1.714 1.09 483.58 2.620 338.530 416.99 483.49 2.86N 2.77W 5999954.79 N 565726.56 E 1.157 0.65 572.52 4.450 339.790 505.76 572.26 7.99 N 4.70W 5999959.90 N 565724.58 E 2.059 -0.68 670.16 7.280 343.030 602.88 669.38 17.47 N 7.82W 5999969.35 N 565721.38 E 2.917 -3.50 751.93 9.120 341.720 683.81 750.31 28.58 N 11.36 W 5999980.42 N 565717.73 E 2.262 -6.91 845.64 11.410 333.170 776.02 842.52 43.90 N 17.88 W 5999995.69 N 565711.09 E 2.929 -10.27 937.66 14.020 329.630 865.78 932.28 61.64 N 27.62 W 6000013.35 N 565701.18 E 2.959 -12.35 1032.23 17 .750 326.730 956.72 1023.22 83.59 N 41.33 W 6000035.17 N 565687.29 E 4.031 -13.56 1125.35 19.890 320.080 1044.87 1111.37 107.61 N 59.28 W 6000059.04 N 565669.12 E 3.251 -12.46 1220.01 20.880 314.180 1133.61 1200.11 131.72 N 81.72 W 6000082.95 N 565646.48 E 2.409 -7.72 1313.82 24.040 312.630 1220.29 1286.79 156.32 N 107.77 W 6000107.31 N 565620.21 E 3.427 -0.28 1408.25 27.230 312.460 1305.42 1371.92 183.94 N 137.87 W 6000134.67 N 565589.87 E 3.379 8.76 1500.34 30.240 309.260 1386.16 1452.66 212.84 N 171.38'W 6000163.28 N 565556.10 E 3.670 19.87 1593.54 30.490 308.460 1466.58 1533.08 242.40 N 208.06 W 6000192.51 N 565519.16 E 0.510 33.23 1686.29 31 .740 307.980 1545.98 1612.48 272.05 N 245.72 W 6000221.83 N 565481.24 E 1.374 47.34 1779.14 32.450 308.920 1624.64 1691.14 302.73 N 284.35 W 6000252.17 N 565442.34 E 0.935 61.66 ~ 1873.70 34.350 307.860 1703.58 1770.08 335.04 N 325.16 W 6000284.12 N 565401.26 E 2.102 76.83 1966.61 37.960 304.800 1778.59 1845.09 367.45 N 369.33 W 6000316.14 N 565356.80 E 4.343 94.73 2061.14 40.980 303.470 1851.56 1918.06 401.15 N 419.08 W 6000349.39 N 565306.76 E 3.317 116.4 7 2154.47 44.890 304.240 1919.88 1986.38 436.57 N 471.85 W 6000384.35 N 565253.68 E 4.227 139.73 2247.18 47.990 304.040 1983.76 2050.26 474.27 N 527.45 W 6000421.56 N 565197.75 E 3.347 164.01 2341.36 50.290 305.800 2045.37 2111.87 515.05 N 585.84 W 6000461.82 N 565139.00 E 2.821 188.83 2435.16 52.790 305.450 2103.70 2170.20 557.83 N 645.54 W 6000504.07 N 565078.93 E 2.681 213.60 2528.10 55.230 305.620 2158.32 2224.82 601.53 N 706.73 W 6000547.24 N 565017.36 E 2.630 239.06 2622.11 55.550 305.370 2211.71 2278.21 646.46 N 769.72 W 6000591.61 N 564953.97 E 0.405 265.32 2714.72 56.210 305.830 2263.66 2330.16 691.09 N 832.06 W 6000635.69 N 564891.24 E 0.823 291.20 ----- ---. 10 July, 2002 - 10:38 Page 20f8 DrillQuest 2.00.08.005 Sperry-SunDn -~8srvices . Survey Report for MWD Your Ref: API Job No. AKMW220B2, SUlYèyed: 11 June, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) eft) (ft) (ft) (°/1 OOft) 2807.97 57.300 305.060 2314.78 2381.28 736.31 N 895.59 W 6000680.35 N 564827.31 E 1.358 317.73 2901.90 57.390 305.100 2365.46 2431.96 781.76 N 960.31 W 6000725.23 N 564762.20 E 0.102 345.10 ~..I 2993.83 55.760 304.270 2416.10 2482.60 825.42 N 1023.40 W 6000768.34 N 564698.73 E 1.927 372.14 3088.22 54.720 304.120 2469.92 2536.42 869.01 N 1087.54 W 6000811.35 N 564634.21 E 1.110 400.10 3181.58 54.810 304.260 2523.78 2590.28 911.86 N 1150.61 W 6000853.65 N 564570.76 E 0.156 427.60 3274.83 49.810 304.940 2580.77 264 7.27 953.73 N 1211.34 W 6000894.99 N 564509.66 E 5.393 453.73 3368.17 50.380 304.470 2640.65 2707.15 994.50 N 1270.21 W 6000935.23 N 564450.44 E 0.723 478.95 3461.79 50.820 303.470 2700.08 2766.58 1034.92 N 1330.20 W 6000975.12 N 564390.09 E 0.950 505.30 3555.12 52.040 304.020 2758.26 2824.76 1075.45 N 1390.87 W 6001015.12 N 564329.07 E 1.386 532.14 3649.50 52.920 303.400 2815.74 2882.24 1117.00 N 1453.14 W 6001056.11 N 564266.43 E 1.068 559.72 3742.27 53.920 305.120 2871.03 2937.53 1158.94 N 1514.71 W 6001097.51 N 564204.50 E 1.838 586.50 3836.32 54.780 304.430 2925.85 2992.35 1202.52 N 1577.48 W 6001140.54 N 564141.35 E 1.092 613.33 3929.14 54.820 304.100 2979.35 3045.85 1245.23 N 1640.16 W 6001182.69 N 564078.29 E 0.294 640.59 4023.27 52.670 303.650 3035.02 3101.52 1287.54 N 1703.18 W 6001224.45 N 564014.91 E 2.316 668.35 4116.44 53.110 304.730 3091.23 3157.73 1329.29 N 1764.64 W 6001265.66 N 563953.08 E 1.038 695.15 4210.47 53.540 303.140 3147.39 3213.89 1371.38 N 1827.20 W 6001307.20 N 563890.15 E 1 .431 722.66 4302.63 54.070 303.580 3201.82 3268.32 1412.28 N 1889.32 W 6001347.55 N 563827.67 E 0.692 750.48 4397.83 54 .220 297.310 3257.62 3324.12 1451.34 N 1955.79 W 6001386.03 N 563760.86 E 5.339 782.93 4491.11 53.970 292.760 3312.34 3378.84 1483.31 N 2024.22 W 6001417.39 N 563692.16 E 3.960 821.02 4584.75 54.230 287.980 3367.27 3433.77 1509.69 N 2095.29 W 6001443.14 N 563620.85 E 4.144 864.4 7 4677.65 55.690 283.710 3420.62 3487.12 1530.43 N 2168.44 W 6001463.23 N 563547.53 E 4.078 912.83 4771.52 56.820 281.410 3472.77 3539.27 1547.39 N 2244.62 W 6001479.53 N 563471.20 E 2.366 965.84 4864.03 58.810 278.760 3522.05 3588.55 1561.08 N 2321.69 W 6001492.53 N 563394.01 E 3.241 1021.44 4958.00 60.080 272.620 3569.85 3636.35 1569.07 N 2402.16 W 6001499.81 N 563313.48 E 5.786 1083.07 5051.17 60.570 268.060 3616.00 3682.50 1569.54 N 2483.07 W 6001499.57 N 563232.56 E 4.284 1149.36 5144.70 61.160 264.490 3661.55 3728.05 1564.22 N 2564.58 W 6001493.54 N 563151.11 E 3.393 1219.41 5238.28 62.040 259.820 3706.07 3772.57 1552.98 N 2646.09 W 6001481.58 N 563069.70 E 4.489 1292.84 5331.41 62.430 253.710 3749.49 3815.99 1534.12 N 2726.25 W 6001462.02 N 562989.70 E 5.820 1369.50 5424.72 62.990 249.590 3792.29 3858.79 1508.01 N 2804.93 W 6001435.22 N 562911.25 E 3.969 1449.06 5~)16.75 64 .200 248.310 3833.21 3899.71 1478.40 N 2881.86 W 6001404.93 N 562834.60 E 1.811 1529.17 ._---~--- --.------- -" -- - - 10 July, 2002 - 10:38 Page 3 ofB DrillQuest 2.00.08.005 Sperry-Sun lJriIJIlJfJServices . SurveyReportfØtf-,-2S1tfWD Your Ref: API _fS2301í9OO Job No. AKMW22D82, Surveyed: 11 June, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5611.18 67.510 244.410 3871.85 3938.35 1443.83 N 2960.75 W 6001369.67 N 562756.01 E 5.146 1613.72 5700.62 64.740 248.650 3908.06 3974.56 1411.24 N 3035.72 W 6001336.42 N 562681.32 E 5.327 1693.93 ~~ 5793.61 68.060 247.270 3945.28 4011.78 1379.26 N 3114.69 W 6001303.74 N 562602.64 E 3.820 1777.06 5886.88 69.910 242.540 3978.75 4045.25 1342.32 N 3193.50 W 6001266.12 N 562524.16 E 5.132 1862.89 5930.39 69.620 238.820 3993.80 4060.30 1322.34 N 3229.09 W 6001245.82 N 562488.75 E 8.050 1903.52 5980.20 69.520 237.840 4011.19 4077.69 1297.83 N 3268.81 W 6001220.96 N 562449.24 E 1.855 1950.14 6023.72 70.680 237.680 4026.00 4092.50 1276.00 N 3303.42 W 6001198.83 N 562414.83 E 2.688 1991.02 6074.03 73.420 236.260 4041.50 4108.00 1249.91 N 3343.54 W 6001172.39 N 562374.94 E 6.072 2038.86 6119.94 76.040 237.410 4053.59 4120.09 1225.69 N 3380.61 W 6001147.84 N 562338.08 E 6.197 2083.13 6167.47 78.560 237.900 4064.04 4130.54 1200.89 N 3419.78 W 6001122.69 N 562299.13 E 5.396 2129.45 6211.72 81.710 237.990 4071.62 4138.12 1177.75 N 3456.73 W 6001099.23 N 562262.39 E 7.121 2173.00 6261.02 81.630 238.260 4078.77 4145.27 1151.99 N 3498.15 W 6001073.11 N 562221.20 E 0.566 2221.72 6309.75 80.670 238.120 4086.26 4152.76 1126.61 N 3539.01 W 6001047.37 N 562180.50 E 1.990 2269.81 6423.57 85.440 238.200 4100.02 4166.52 1067.02 N 3635.02 W 6000986.94 N 562085.08 E 4.191 2382.62 6467.92 88.830 239.480 4102.24 4168.74 1044.11 N 3672.92 W 6000963.70 N 562047.38 E 8.169 2426.83 6516.73 91.600 237.790 4102.05 4168.55 1018.71 N 3714.59 W 6000937.93 N 562005.93 E 6.648 2475.55 6561.97 94.130 231 .130 4099.79 4166.29 992.46 N 3751.34 W 6000911.36 N 561969.42 E 15.730 2520.70 6609.95 94.380 227.370 4096.23 4162.73 961.24 N 3787.58 W 6000879.82 N 561933.46 E 7.832 2568.27 6654.44 93.510 219.220 4093.16 4159.66 928.96 N 3817.99 W 6000847.27 N 561903.33 E 18.379 2611.64 6702.72 91.660 214.320 4090.98 4157.48 890.34 N 3846.85 W 6000808.40 N 561874.81 E 10.838 2657.34 -~.-'" 6748.22 91.910 209.450 4089.57 4156.07 851.73 N 3870.86 W 6000769.58 N 561851.14 E 10.712 2699.05 6796.83 91.170 204.060 4088.26 4154.76 808.36 N 3892.73 W 6000726.02 N 561829.66 E 11 .188 2741 .71 6841.63 92.710 198.130 4086.74 4153.24 766.60 N 3908.84 W 6000684.13 N . 561813.92 E 13.668 2778.71 6890.60 95.050 191.910 4083.42 4149.92 719.44 N 3921.50 W 6000636.85 N 561801.67 E 13.543 2815.95 6935.37 92.340 187.560 4080.54 4147.04 675.42 N 3929.05 W 6000592.77 N 561794.51 E 11.430 2847.20 6983.28 93.820 182.080 4077.96 4144.46 627.77 N 3933.07 W 6000545.09 N 561790.91 E 11.832 2877.61 7028.70 93.820 180.680 4074.94 4141.44 582.47 N 3934.16 W 6000499.77 N 561790.22 E 3.075 2904.28 7076.94 93.140 180.350 4072.01 4138.51 534.32 N 3934.59 W 6000451.62 N 561790.21 E 1.566 2932.03 7121.96 92.770 179.310 4069.69 4136.19 489.36 N 3934.46 W 6000406.67 N 561790.74 E 2.449 2957.49 7170.46 93.020 179.570 4067.24 4133.74 440.92 N 3933.98 W 6000358.24 N 561791.64 E 0.743 2984.65 --- - ---------~-- ----~----- --- ~ 10 July, 2002 - 10:38 Page 40f8 DrmQflest 2.00.08.005 Sperry-Sun DriI(llfServices . SurveyRepott - 151fWD Your Ref: API oli9Ðo Job No. AKMwJ20B2, - Stl~: 11 June, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 7215.40 92.590 179.060 4065.04 4131.54 396.04 N 3933.45 W 6000313.36 N 561792.57 E 1 .483 3009.74 7264.03 91.910 178.620 4063.13 4129.63 347.46 N 3932.46 W 6000264.79 N 561793.98 E 1.665 3036.57 -- 7308.87 91.540 177.400 4061.78 4128.28 302.67 N 3930.91 W 6000220.01 N 561795.93 E 2.842 3060.77 7363.60 91.600 176.720 4060.28 4126.78 248.03 N 3928.10 W 6000165.40 N 561799.22 E 1.247 3089.54 7402.53 91.540 177.710 4059.21 4125.71 209.16 N 3926.21 W 6000126.55 N 561801.45 E 2.547 3110.10 7450.49 90.550 181.570 4058.34 4124.84 161.22 N 3925.91 W 6000078.61 N 561802.17 E 8.307 3137.12 7495.65 91.290 181.840 4057.61 4124.11 116.09 N 3927.25 W 6000033.47 N 561801.23 E 1.744 3163.90 7546.85 91.480 181.240 4056.38 4122.88 64.92 N 3928.63 W 5999982.29 N 561800.30 E 1.229 3194.14 7589.07 91.850 181.340 4055.15 4121.65 22.73 N 3929.58 W 5999940.10 N 561799.72 E 0.908 3218.92 7637.56 91 .350 180.960 4053.79 4120.29 25.73 S 3930.55 W 5999891.63 N 561799.18 E 1.295 3247.29 7683.06 91.350 180.230 4052.72 4119.22 71.22 S 3931.02 W 5999846.14 N 561799.11 E 1.604 3273.55 7730.53 90.920 179.780 4051.78 4118.28 118.68 S 3931.03 W 5999798.68 N 561799.52 E 1.311 3300.55 7776.15 90.740 179.720 4051.12 4117.62 164.29 S 3930.83 W 5999753.07 N 561800.12 E 0.416 3326.34 7824.56 90.250 180.380 4050.70 4117.20 212.70 S 3930.87 W 5999704.66 N 561800.50 E 1.698 3353.91 7869.97 91.910 182.020 4049.85 4116.35 258.09 S 3931.82 W 5999659.27 N 561799.95 E 5.138 3380.51 7918.63 90.120 180.340 4048.99 4115.49 306.73 S 3932.82 W 5999610.62 N 561799.38 E 5.045 3409.00 7963.36 91.850 180.780 4048.22 4114.72 351.45 S 3933.26 W 5999565.90 N 561799.33 E 3.991 3434.80 8007.83 92.400 180.890 4046.57 4113.07 395.88 S 3933.91 W 5999521.46 N 561799.08 E 1.261 3460.61 8054.77 91.850 181.150 4044.83 4111.33 442.78 S 3934.74 W 5999474.56 N 561798.66 E 1.296 3487.97 8102.90 86.860 179.840 4045.37 4111.87 490.89 S 3935.16 W 5999426.45 N 561798.66 E 10.719 3515.68 8149.68 86.490 179.690 4048.08 4114.58 537.59 S 3934.97 W 5999379.75 N 561799.27 E 0.853 3542.09 8197.20 88.950 179.950 4049.97 4116.47 585.07 S 3934.82 W 5999332.28 N 561799.83 E 5.206 3568.98 8243.30 90.740 181 . 160 4050.10 4116.60 631.16 S 3935.26 W 5999286.18 N 561799.79 E 4.687 3595.56 8293.91 89.690 180.540 4049.91 4116.41 681.77 S 3936.02 W 5999235.57 N 561799.49 E 2.409 3624.97 8336.64 88.710 180.300 4050.50 4117.00 724.49 S 3936.33 W 5999192.84 N 561799.55 E 2.361 3649.53 8388.03 90.550 180.990 4050.84 4117.34 775.87 S 3936.91 W 5999141.46 N 561799.42 E 3.824 3679.23 8430.32 90.310 180.750 4050.52 4117.02 818.16 S 3937.55 W 5999099.17 N 561799.15 E 0.803 3703.81 8480.75 90.310 180.490 4050.25 4116.75 868.58 S 3938.09 W 5999048.74 N 561799.05 E 0.516 3732.95 8523.92 91.230 181.230 4049.67 4116.17 911.75 S 3938.74 W 5999005.58 N 561798.78 E 2.735 3758.03 8575.62 91.110 180.860 4048.61 4115.11 963.43 S 3939.69 W 5998953.89 N 561798.30 E 0.752 3788.21 __n__- 10 July, 2002 - 10:38 Page 50fB DrillQuest 2.00.08.005 Sperry-Sun Drilling S.ervices . Survey Report for...25o,MWD Your Ref: APlSØflB23oøOO Job No. AKMW220B2. Sur:tiêYéd: 11 June. 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOff) 8616.96 90.060 180.200 4048.19 4114.69 1004.76 S 3940.07 W 5998912.55 N 561798.28 E 3.000 3812.03 8667.41 86.670 179.010 4049.63 4116.13 1055.18 S 3939.72 W 5998862.14 N 561799.07 E 7.121 3840.43 8711.05 86.300 179.090 4052.30 4118.80 1098.73 S 3939.00 W 5998818.59 N 561800.17 E 0.867 3864.61 - 8758.59 87.350 180.230 4054.94 4121.44 1146.20 S 3938.72 W 5998771.13 N 561800.87 E 3.257 3891.38 8804.77 89.020 180.480 4056.40 4122.90 1192.35 S 3939.00 W 5998724.98 N 561800.99 E 3.657 3917.87 8851.71 90.180 180.290 4056.73 4123.23 1239.29 S 3939.32 W 5998678.04 N 561801.09 E 2.504 3944.83 8898.25 90.120 179.940 4056.60 4123.10 1285.83 S 3939.41 W 5998631.50 N 561801.41 E 0.763 3971.38 8949.50 90.060 179.380 4056.52 4123.02 1337.08 S 3939.11 W 5998580.26 N 561802.16 E 1.099 4000.28 8991.35 90.120 179.220 4056.46 4122.96 1378.92 S 3938.60 W 5998538.42 N 561803.04 E 0.408 4023.67 9038.15 91.600 179.370 4055.76 4122.26 1425.71 S 3938.02 W 5998491.63 N 561804.03 E 3.179 4049.81 9084.82 91.600 179.070 4054.45 4120.95 1472.36 S 3937.39 W 5998444.99 N 561805.07 E 0.643 4075.82 9132.45 91.290 178.090 4053.25 4119.75 1519.96 S 3936.21 W 5998397.41 N 561806.67 E 2.157 4101.93 9177.66 91.110 177.600 4052.30 4118.80 1565.13 S 3934.51 W 5998352.26 N 561808.77 E 1.154 4126.23 9228.04 91.050 177.460 4051.35 4117.85 1615.45 S 3932.34 W 5998301.95 N 561811.38 E 0.302 4153.07 9271.51 91.420 177.040 4050.42 4116.92 1658.86 S 3930.25 W 5998258.56 N 561813.85 E 1.287 4176.05 9320.56 91.480 177.100 4049.18 4115.68 1707.83 S 3927.74 W 5998209.62 N 561816.79 E 0.173 4201.84 9365.43 92.150 176.160 4047.76 4114.26 1752.60 S 3925.11 W 5998164.87 N 561819.82 E 2.572 4225.14 9412.86 92.280 176.480 4045.92 4112.42 1799.90 S 3922.07 W 5998117.60 N 561823.28 E 0.728 4249.54 9458.45 91.850 175.500 4044.28 4110.78 1845.35 S 3918.88 W 5998072.19 N 561826.86 E 2.346 4272.77 9508.01 91.480 175.630 4042.84 4109.34 1894.74 S 3915.05 W 5998022.83 N 561831.13 E 0.791 4297.72 '- 9551.75 90.860 174.710 4041.95 4108.45 1938.31 S 3911.37 W 5997979.29 N 561835.19 E 2.536 4319.48 9601.59 92.220 174.510 4040.61 4107.11 1987.91 S 3906.69 W 5997929.73 N 561840.31 E 2.758 4343.85 9645.43 94.190 175.680 4038.16 4104.66 2031.52 S 3902.94 W 5997886.16 N 561844.44 E 5.224 4365.57 9693.38 92.400 175.420 4035.40 4101.90 2079.25 S 3899.23 W 5997838.47 N 561848.57 E 3.772 4389.67 9738.75 92.400 175.120 4033.50 4100.00 2124.42 S 3895.49 W 5997793.33 N 561852.71 E 0.661 4412.29 9787.43 92.220 174.700 4031.54 4098.04 2172.87 S 3891.18 W 5997744.92 N 561857.45 E 0.938 4436.30 9832.14 91.850 173.980 4029.95 4096.45 2217.33 S 3886.77 W 5997700.50 N 561862.24 E 1.810 4457.97 9881.69 92.090 173.780 4028.25 4094.75 2266.57 S 3881.49 W 5997651.31 N 561867.96 E 0.630 4481.64 9925.86 92.160 173.750 4026.61 4093.11 2310.45 S 3876.70 W 5997607.47 N 561873.14 E 0.172 4502.66 9973.17 92.150 173.780 4024.83 4091.33 2357.45 S 3871.56 W 5997560.52 N 561878.68 E 0.067 4525.17 - --- ------- ----- 10 July, 2002 - 10:38 Page 6 of8 DrillQlIest 2.00.08.005 Sperry-Sun DrltI@sServices Survey Reportfor..'f;MWD Your Ref: API 5OðfíflôBIoo Job No. AKMW22082, Surveyêd: 11 June, 2002 . . t BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates' Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eatlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10019.64 92.340 174.160 4023.01 4089.51 2403.62 S 3866.68 W 5997514.39 N 561883.97 E 0.914 4547.42 10067.58 92.830 174.600 4020.85 4087.35 2451.29 S 3861.99 W 5997466.77 N 561889.08 E 1.373 4570.68 ~/ 10113.25 92.770 174.100 4018.62 4085.12 2496.68 S 3857.50 W 5997421.42 N 561893.97 E 1.101 4592.81 10159.65 93.450 173.890 . 4016.10 4082.60 2542.76 S 3852.66 W 5997375.39 N 561899.22 E 1.534 4615.03 10181.58 96.230 172.850 4014.25 4080.75 2564.46 S 3850.13 W 5997353.71 N 561901.93 E 13.529 4625.30 10250.00 96.230 172.850 4006.82 4073.32 2631.95 S 3841.67 W 5997286.30 N 561910.99 E 0.000 4656.73 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Structure. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 235.330° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10250.000., The Bottom Hole Displacement is 4656.78ft., in the Direction of 235.585° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10250.00 4073.32 2631.95 S 3841.67 W Projected Survey ------._------- -~----~- 10 July, 2002 - 10:38 Page 70'8 DrillQlIest 2.00.08.005 BP EXPLORATION (ALASKA) INC. Milne Point Unit Survey tool program for MPS-25 MWD '---...-- From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 10250.00 4073.32 MWD Magnetic 10 July, 2002 - 10:38 Sperry-Sun DrilliftgServices Survey Report for MPS-2SMWD Your Ref: API 500292308900 Job No. AKMW220821 Surveyed: 11 Junel 2002 . BPXA Milne Point MPS Survey Tool Description -' ~/ - ----- ---- ------ -- Page 8 of8 DrillQuest 2.00.08.005 l c51~-JO~ 11-Jul-02 BP Exploration (Alaska) Inc. Petrotechnical Data Center, L 900 E. Benson Blvd. Anchorage, AK 99508 DEFINITIVE Re: Distribution of Survey Data for Well MPS-25 Dear Sir / Madam: Enclosed are 3 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , MD (if applicable) 10,250.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JUL 1 7 2002 Alaska Oil & Gas Cons. Comm_A Anchorage I IIU NWlUn BP EXPLORA1.3'~~bSKA) INC. DEF"l\ITIVE Milne 1'0;.' Unit lIP. Milne Point MPS,.SlotMPS-25 MPS.. Job No. AKZZ22082, Surveyed: 11 June, 2002 ~. SURVE'Y.PORT 10 July, 2002 Your Ref: API 5011.308900 Surface Coordinates: 5999951~95 N, 565729.35 E (TO° 24' 37.1260" N, 149027' 53.2236" W) Kelly Bushing: 66. 50ft above Mean Sea Level --- - -1" 'I!!i''''''\ 'Y-BLJr1 DRILL.ING S."'VtCeS A Halliburton Company Survey Ref: 5vy10121 Sperry-Sun Dr.It.-Services . Survey ReportfJ!t~&-25 Your Ref: API5.l.~30B900 Job No. AKZZ22082, Suweýêd: 11 June, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -66.50 0.00 O.DON O.OOE 5999951.95 N 565729.35 E 0.00 AK-6 BP _IFR-AK 121.29 0.270 159.550 54.79 121.29 0.27 S 0.10E 5999951.68 N 565729.45 E 0.223 0.07 -- 207.29 0.580 215.610 140.79 207.29 0.81 S 0.08W 5999951.14 N 565729.27 E 0.563 0.53 297.60 0.220 270.310 231.1 0 297.60 1.18 S 0.52W 5999950.76 N 565728.84 E 0.539 1.10 387.79 1.670 322.820 321.27 387.77 0.13 S 1.49W 5999951.80 N 565727.86 E 1.714 1.30 483.58 2.620 338.050 416.99 483.49 3.01 N 3.15W 5999954.93 N 565726.17 E 1.148 0.88 572.52 4.450 339.320 505.76 572.26 8.12 N 5.13W 5999960.03 N 565724.15 E 2.059 -0.40 670.16 7.280 342.630 602.88 669.38 17.57 N 8.32W 5999969.45 N 565720.88 E 2.918 -3.16 751.93 9.120 341.280 683.81 750.31 28.66 N 11.94 W 5999980.50 N 565717.16 E 2.262 -6.48 845.64 11.410 332.810 776.02 842.52 43.94 N 18.56 W 5999995.72 N 565710.40 E 2.921 -9.73 937.66 14.020 329.390 865.78 932.28 61.63 N 28.40 W 6000013.33 N 565700.41 E 2.951 -11.70 1032.23 17.750 326.530 956.72 1023.22 83.52 N 42.19 W 6000035.10 N 565686.43 E 4.029 -12.81 1125.35 19.890 319.830 1044.87 1111.37 107.47 N 60.24 W 6000058.89 N 565668.17 E 3.263 -11.59 1220.01 20.880 313.000 1133.61 1200.11 131.29 N 82.97 W 6000082.50 N 565645.23 E 2.720 -6.45 1313.82 24.040 311.630 1220.29 1286.79 155.39 N 109.48 W 6000106.37 N 565618.51 E 3.414 1.65 1408.25 27.230 311.520 1305.42 1371.92 182.49 N 140.04 W 6000133.20 N 565587.71 E 3.379 11.37 1500.34 30.240 308.320 1386.16 1452.66 210.85 N 174.02W 6000161.26 N 565553.48 E 3.670 23.18 1593.54 30.490 307.860 1466.58 1533.08 239.91 N 211.10 W 6000189.99 N 565516.15 E 0.366 37.15 1686.29 31 .740 307.770 1545.98 1612.48 269.29 N 248.96 W 6000219.04 N 565478.03 E 1.349 51.57 1779.14 32.450 308.630 1624.64 1691.14 299.80 N 287.73 W 6000249.21 N 565438.99 E 0.909 66.10 1873.70 34.350 307.630 1703.58 1770.08 331.93 N 328.68 W 6000280.98 N 565397.76 E 2.092 81.50 1966.61 37.960 305.080 1778.59 1845.09 364.37 N 372.84 W 6000313.03 N 565353.32 E 4.209 99.37 2061.14 40.980 303.280 1851.56 1918.06 398.10 N 422.56 W 6000346.31 N 565303.31 E 3.416 121.07 2154.47 44.890 303.700 1919.88 1986.38 433.18 N 475.56 W 6000380.93 N 565250.00 E 4.201 144.71 2247.18 47.990 304.740 1983.76 2050.26 470.97 N 531.10 W 6000418.22 N 565194.13 E 3.441 168.89 2341.36 50.290 305.100 2045.37 2111.87 511.74N 589.49 W 6000458.48 N 565135.37 E 2.459 193.72 2435.16 52.790 305.500 2103.70 2170.20 554.18 N 649.43 W 6000500.40 N 565075.07 E 2.686 218.87 2528.10 55.230 304.610 2158.32 2224.82 597.36 N 710.99 W 6000543.03 N 565013.13 E 2.737 244.94 2622.11 55.550 304.940 2211.71 2278.21 641.50 N 774.54 W 6000586.60 N 564949.19 E 0.446 272.10 2714.72 56.210 305.220 2263.66 2330.16 685.56 N 837.28 W 6000630.11 N 564886.06 E 0.755 298.64 - ----_.~ 10 July, 2002 - 9:48 Page 20fB DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Reportloí1"'~~5 Your Ref: AP'_.B900 Job No. AKZZ22Ø82, SUìWjted: 11 June, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs fastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 2807.97 57.300 305.190 2314.78 2381.28 730.52 N 901.01 W 6000674.51 N 564821.95 E 1.169 325.4 7 2901.90 57.390 304.690 2365.46 2431.96 775.81 N 965.84 W 6000719.23 N 564756.72 E 0.458 353.02 ~~ 2993.83 55.760 304.340 2416.10 2482.60 819.28 N 1029.05 W 6000762.15 N 564693.13 E 1.801 380.29 3088.22 54.720 303.640 2469.92 2536.42 862.64 N 1093.34 W 6000804.93 N 564628.46 E 1.259 408.50 3181.58 54.810 303.540 2523.78 2590.28 904.83 N 1156.87 W 6000846.56 N 564564.56 E 0.130 436.75 3274.83 49.810 304.450 2580.77 2647.27 946.05 N 1218.04 W 6000887.25 N 564503.03 E 5.417 463.60 3368.17 50.380 304.250 2640.65 2707.15 986.46 N 1211.15 W 6000921.13 N 564443.57 E 0.632 489.24 3461.79 50.820 303.930 2700.07 2766.57 1021.00 N 1331.06 W 6000961.15 N 564383.30 E 0.539 515.45 3555.12 52.040 303.830 2758.26 2824.76 1067.68 N 1397.64 W 6001001.29 N 564322.36 E 1.310 542.13 3649.50 52.920 303.4 70 2815.74 2882.24 1109.16 N 1459.96 W 6001048.22 N 564259.69 E 0.980 569.79 3742.27 53.920 303.610 2871.03 2937.53 1150.32 N 1522.05 W 6001088.83 N 564197.24 E 1.085 597.44 3836.32 54.780 303.420 2925.84 2992.34 1192.51 N 1585.17 W 6001130.46 N 564133.15 E 0.929 625.84 3929.14 54.820 303.290 2979.35 3045.85 1234.22 N 1649.12 W 6001171.61 N 564069.43 E 0.122 654.22 4023.27 52.670 302.590 3035.01 3101.51 1275.49 N 1712.82 W 6001212.32 N 564005.38 E 2.361 683.13 4116.44 53.110 302.390 3091.22 3157.72 1315.40 N 1715.49 W 6001251.68 N 563942.36 E 0.502 711.97 4210.47 53.540 302.590 3147.39 3213.89 1355.91 N 1839.10W 6001291.63 N 563878.39 E 0.488 741.24 4302.63 54.070 302.520 3201.81 3268.31 1395.94 N 1901.19 W 6001331.09 N 563815.35 E 0.578 770.03 4397.83 54.220 297.300 3257.60 3324.10 1434.39 N 1968.63 W 6001368.95 N 563748.17 E 4.446 803.14 4491.11 53.970 293.600 3312.31 3378.81 1466.85 N 2036.83 W 6001400.82 N 563679.69 E 3.224 840.76 4584.75 54.230 288.900 3367.24 3433.74 1494.32 N 2107.50 W 6001427.67 N 563608.78 E 4.075 883.25 - 4677.65 55.690 284.730 3420.59 3487.09 1516.29 N 2180.29 W 6001449.00 N 563535.80 E 3.997 930.62 4771.52 56.820 280.680 3472.75 3539.25 1533.44 N 2256.41 W 6001465.47 N 563459.54 E 3.784 983.4 7 4864.03 58.810 277.610 3522.03 3588.53 1545.85 N 2333.69 W 6001411.21 N 563382.14 E 3.537 1039.97 4958.00 60.080 272.560 3569.83 3636.33 1553.00 N 2414.26 W 6001483.64 N 563301.52 E 4.821 1102.16 5051.17 60.570 267.540 3615.98 3682.48 1553.06 N 2495.17 W 6001482.99 N 563220.61 E 4.710 1168.67 5144.70 61 .160 263.860 3661.53 3728.03 1546.93 N 2576.61 W 6001476.14 N 563139.22 E 3.494 1239.14 5238.28 62.040 259.140 3706.05 3772.55 1534.75 N 2651.99 W 6001463.25 N 563057.96 E 4.535 1313.00 5331.41 62.430 253.260 3749.47 3815.97 1515.10 N 2737.96 W 6001442.90 N 562978.16 E 5.602 1389.95 5424.72 62.990 248.980 3792.26 3858.76 1488.27 N 2816.40 W 6001415.38 N 562899.96 E 4.120 1469.72 5516.75 64.200 247.540 3833.19 3899.69 1457.73 N 2892.96 W 6001384.17 N 562823.67 E 1.922 1550.06 ----~-- 10 July, 2002 - 9:48 Page 30f8 DrillQuest 2.00.08.005 Sperry-Sun lJ;-_.~>,-< Services . Survey Report~1fIIØ.I5 Your ReI: API 5OIJftì3OØOO Job No. AKZZ22082, SutvèVêd: -11 June, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azlm. Depth Depth Northing. Eastin". Northing. Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5611.18 67.510 243.420 3871.83 3938.33 1421.95 N 2971.31 W 6001347.70 N 562745.64 E 5.304 1634.85 5700.62 64.740 248.110 3908.04 3974.54 1388.36 N 3045.84 W 6001313.46 N 562671.41 E 5.707 1715.25 ~~. 5793.61 68.060 246.620 3945.27 4011.77 1355.56 N 3124.47 W 6001279.96 N 562593.08 E 3.860 1798.58 5886.88 69.910 241.830 3978.73 4045.23 1317.70 N 3202.83 W 6001241.41 N 562515.05 E 5.188 1884.57 5930.39 69.620 238.110 3993.78 4060.28 1297.27 N 3238.16 W 6001220.67 N 562479.89 E 8.050 1925.25 5980.20 69.520 237.320 4011.17 4077.67 1272.34 N 3277.62 W 6001195.40 N 562440.65 E 1.500 1971.89 6023.72 70.680 237.310 4025.98 4092.48 1250.24 N 3312.07 W 6001173.00 N 562406.41 E 2.666 2012.78 6074.03 73.420 235.950 4041.49 4107.99 1223.92 N 3352.03 W 6001146.32 N 562366.68 E 6.023 2060.63 6119.94 76.040 237.110 4053.58 4120.08 1199.50 N 3388.97 W 6001121.57 N 562329.95 E 6.205 2104.90 6167.47 78.560 237.570 4064.03 4130.53 1174.48 N 3428.00 W 6001096.21 N 562291.14 E 5.385 2151.24 6211.72 81.710 237.450 4071.61 4138.11 1151.06 N 3464.77 W 6001072.48 N 562254.58 E 7.124 2194.79 6261.02 81.630 237.990 4078.75 4145.25 1125.01 N 3506.01 W 6001046.06 N 562213.57 E 1.096 2243.53 6309.75 80.670 237.720 4086.25 4152.75 1099.39 N 3546.78 W 6001020.09 N 562173.03 E 2.045 2291.63 6423.57 85.440 239.420 4100.01 4166.51 1040.50 N 3643.16 W 6000960.35 N 562077.17 E 4.445 2404.40 6467.92 88.830 240.980 4102.22 4168.72 1018.49 N 3681.59 W 6000938.00 N 562038.94 E 8.412 2448.53 6516.73 91.600 238.410 4102.04 4168.54 993.87 N 3723.73 W 6000913.01 N 561997.02 E 7.741 2497.19 6561.97 94.130 232.140 4099.78 4166.28 968.15 N 3760.84 W 6000886.96 N 561960.13 E 14.928 2542.34 6609.95 94.380 227.830 4096.21 4162.71 937.39 N 3797.48 W 6000855~88 N 561923.77 E 8.973 2589.97 6654.44 93.510 221.290 4093.15 4159.65 905.78 N 3828.60 W 6000824.00 N 561892.92 E 14.795 2633.55 6702.72 91.660 216.020 4090.97 4157.47 868.13 N 3858.72 W 6000786.09 N 561863.14 E 11.558 2679.73 6748.22 91.910 209.860 4089.55 4156.05 829.98 N 3883.43 W 6000747.72 N 561838.76 E 13.543 2721.76 6796.83 91.170 205.040 4088.25 4154.75 786.87 N 3905.83 W 6000704.42 N 561816.75 E 10.028 2764.70 6841.63 92.710 198.520 4086.73 4153.23 745.32 N 3922.43 W 6000662.72 N 561800.51 E 14.945 2802.00 6890.60 95.050 192.530 4083.41 4149.91 698.27 N 3935.50 W 6000615.56 N 561787.85 E 13.105 2839.51 6935.37 92.340 187.050 4080.52 4147.02 654.26 N 3943.09 W 6000571.49 N 561780.65 E 13.631 2870.79 6983.28 93.820 181.670 4077.95 4144.45 606.58 N 3946.73 W 6000523.77 N 561777.43 E 11.631 2900.90 7028.70 93.820 180.630 4074.92 4141.42 561.27 N 3947.64 W 6000478.46 N 561776.92 E 2.285 2927.43 7076.94 93.140 180.160 4071.99 4138.49 513.12 N 3947.97 W 6000430.31 N 561777.01 E 1.713 2955.09 7121.96 92.770 179.140 4069.67 4136.17 468.16 N 3947.70 W 6000385.35 N 561777.68 E 2.407 2980.44 7170.46 93.020 179.490 4067.22 4133.72 419.73 N 3947.12 W 6000336.93 N 561778.69 E 0.886 3007.51 --------_..----~-----------~-~ 10 July, 2002 - 9:48 Page 40fS DriflQuest 2.00.08.005 Sperry-Sun Drillil1gServices . Survey Reporflc:Jl:"",S-25 Your Ref: API_IlU'Ø900 Job No. AKZZ22082,. .Su~:..11 June, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) "- 7215.40 92.590 179.150 4065.02 4131.52 374.85 N 3946.59W 6000292.05 N 561779.62 E 1.219 3032.61 7264.03 91.910 178.510 4063.11 4129.61 326.27 N 3945.59 W 6000243.48 N 561781.04 E 1.920 3059.43 7308.87 91.540 177.410 4061.76 4128.26 281.47 N 3944.00 W 6000198.70 N 561783.03 E 2.587 3083.59 7363.60 91.600 176.530 4060.26 4126.76 226.84 N 3941.11 W 6000144.10 N 561786.40 E 1.611 3112.29 7402.53 91.540 177 .420 4059.20 4125.70 187.98 N 3939.05 W 6000105.26 N 561788.80 E 2.290 3132.71 7450.49 90.550 181.170 4058.32 4124.82 140.04 N 3938.46 W 6000057.33 N 561789.81 E 8.086 3159.49 7495.65 91.290 181.580 4057.60 4124.10 94.90 N 3939.55 W 6000012.18 N 561789.12 E 1.873 3186.06 7546.85 91.480 181.310 4056.36 4122.86 43.73 N 3940.84 W 5999961.00 N 561788.28 E 0.645 3216.23 7589.07 91.850 181.310 4055.13 4121.63 1.54 N 3941.80 W 5999918.80 N 561787.69 E 0.876 3241.03 7637.56 91.350 180.740 4053.78 4120.28 46.92 S 3942.67 W 5999870.33 N 561787.25 E 1.563 3269.31 7683.06 91.350 180.120 4052.71 4119.21 92.41 S 3943.01 W 5999824.85 N 561787.31 E 1.362 3295.46 7730.53 90.920 179.560 4051.77 4118.27 139.87 S 3942.88 W 5999777.39 N 561787.86 E 1.487 3322.35 7776.15 90.740 179.230 4051.11 4117.61 185.48 S 3942.40 W 5999731.78 N 561788.74 E 0.824 3347.90 7824.56 90.250 180.020 4050.69 4117.19 233.89 S 3942.08 W 5999683.38 N 561789.48 E 1.920 3375.18 7869.97 91.910 181.430 4049.83 4116.33 279.28 S 3942.65 W 5999637.98 N 561789.31 E 4.796 3401.4 7 7918.63 90.120 179.750 4048.97 4115.47 327.93 S 3943.15 W 5999589.33 N 561789.23 E 5.045 3429.56 7963.36 91.850 180.130 4048.20 4114.70 372.65 S 3943.11 W 5999544.61 N 561789.67 E 3.960 3454.96 8007.83 92.400 180.350 4046.55 4113.05 417.09 S 3943.29 W 5999500.17 N 561789.88 E 1.332 3480.39 8054.77 91.850 180.650 4044.81 4111.31 463.99 S 3943.70 W 5999453.27 N 561789.88 E 1.334 3507.41 8102.90 86.860 178.680 4045.35 4111.85 512.10 S 3943.42 W 5999405.16 N 561790.59 E 11 .146 3534.55 8149.68 86.490 178.090 4048.07 4114.57 558.79 S 3942.11 W 5999358.49 N 561792.31 E 1 .487 3560.02 8197.20 88.950 178.860 4049.96 4116.46 606.25 S 3940.84 W 5999311.05 N 561793.99 E 5.424 3585.98 8243.30 90.740 180.030 4050.08 4116.58 652.34 S 3940.40 W 5999264.96 N 561794.85 E 4.639 3611.83 8293.91 89.690 179.410 4049.89 4116.39 702.95 S 3940.15 W 5999214.35 N 561795.54 E 2.409 3640.42 8336.64 88.710 178.770 4050.49 4116.99 745.67 S 3939.47 W 5999171.64 N 561796.59 E 2.739 3664.16 8388.03 90.550 179.500 4050.82 4117.32 797.05 S 3938.69 W 5999120.27 N 561797.82 E 3.852 3692.75 8430.32 90.310 179.670 4050.50 4117.00 839.34 S 3938.39 W 5999077.98 N 561798.50 E 0.695 3716.55 8480.75 90.310 180.040 4050.23 4116.73 889.77 S 3938.26 W 5999027.56 N 561799.07 E 0.734 3745.13 8523.92 91.230 180.420 4049.65 4116.15 932.93 S 3938.43 W 5998984.39 N 561799.28 E 2.306 3769.83 8575.62 91.110 180.120 4048.59 4115.09 984.62 S 3938.68 W 5998932.71 N 561799.49 E 0.625 3799.43 ~_.- ----- --~-- ------- 10 July, 2002 - 9:48 Page 50f8 DrilfQuest 2.00.08.005 Sperry-Sun DrilfiWlServices . Survey Report,IotIfÞS-25 Your Ref: API 5f1Ø8230S900 Job No. AKZZ220B2, SUl'VeYÞd: 11 June, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8616.96 90.060 179.130 4048.17 4114.67 1025.96 5 3938.41 W 5998891.37 N 561800.12 E 3.491 3822.73 8667.41 86.670 178.040 4049.61 4116.11 1076.36 5 3937.16 W 5998840.98 N 561801.81 E 7.058 3850.38 ~' 8711.05 86.300 178.310 4052.29 4118.79 1119.905 3935.78 W 5998797.46 N 561803.58 E 1.049 3874.00 8758.59 87.350 179.320 4054.92 4121.42 1167.355 3934.79 W 5998750.01 N 561804.98 E 3.062 3900.19 8804.77 89.020 179.840 4056.38 4122.88 1213.51 5 3934.46 W 5998703.86 N 561805.73 E 3.787 3926.16 8851.71 90.180 179.830 4056.71 4123.21 1260.455 3934.32 W 5998656.93 N 561806.27 E 2.471 3952.75 8898.25 90.120 179.830 4056.59 4123.09 1306.995 3934.18 W 5998610.39 N 561806.82 E 0.129 3979.11 8949.50 90.060 178.950 4056.51 4123.01 1358.23 S 3933.64 W 5998559.15 N 561807.82 E 1.721 4007.82 8991.35 90.120 179.210 4056.44 4122.94 1400.08 S 3932.96 W 5998517.32 N 561808.86 E 0.638 4031.07 9038.15 91.600 178.750 4055.74 4122.24 1446.86 5 3932.13 W 5998470.54 N 561810.10 E 3.312 4057.00 9084.82 91.600 178.490 4054.44 4120.94 1493.50 5 3931.01 W 5998423.91 N 561811.64 E 0.557 4082.60 9132.45 91.290 177.970 4053.24 4119.74 1541.095 3929.54 W 5998376.34 N 561813.53 E 1.271 4108.47 9177.66 91.110 177.560 4052.29 4118.79 1586.26 5 3927.77 W 5998331.19 N 561815.69 E 0.990 4132.71 9228.04 91.050 177.060 4051.34 4117.84 1636.57 5 3925.41 W 5998280.89 N 561818.49 E 0.999 4159.39 9271.51 91.420 176.460 4050.40 4116.90 1679.96 S 3922.95 W 5998237.53 N 561821.33 E 1.621 4182.05 9320.56 91.480 176.350 4049.16 4115.66 1728.90 5 3919.88 W 5998188.62 N 561824.84 E 0.255 4207.36 9365.43 92.150 175.770 4047.74 4114.24 1773.64 5 3916.80 W 5998143.91 N 561828.31 E 1.975 4230.27 9412.86 92.280 175.890 4045.91 4112.41 1820.91 S 3913.35 W 5998096.67 N 561832.17 E 0.373 4254.33 9458.45 91.850 174.720 4044.26 4110.76 1866.32 S 3909.62 W 5998051.30 N 561836.30 E 2.733 4277.09 9508.01 91.480 174.820 4042.82 4109.32 1915.655 3905.11 W 5998002.01 N 561841.25 E 0.773 4301.44 9551.75 90.860 174.070 4041.93 4108.43 1959.185 3900.87 W 5997958.52 N 561845.87 E 2.224 4322.72 9601.59 92.220 174.120 4040.59 4107.09 2008.73 5 3895.75 W 5997909.01 N 561851.43 E 2.731 4346.69 9645.43 94.190 174.820 4038. 14 4104.64 2052.30 5 3891.53 W 5997865.48 N 561856.03 E 4.768 4368.01 9693.38 92.400 174.890 4035.39 4101.89 2099.97 5 3887.24 W 5997817.85 N 561860.74 E 3.736 4391.60 9738.75 92.400 174.550 4033.49 4099.99 2145.11 5 3883.07 W 5997772.75 N 561865.31 E 0.749 4413.84 9787.43 92.220 174.120 4031.52 4098.02 2193.51 5 3878.27 W 5997724.39 N 561870.54 E 0.957 4437.43 9832.14 91.850 173.920 4029.94 4096.44 2237.95 5 3873.61 W 5997679.99 N 561875.59 E 0.941 4458.88 9881.69 92.090 173.690 4028.23 4094.73 2287.185 3868.27 W 5997630.81 N 561881.36 E 0.671 4482.49 9925.86 92.160 173.520 4026.59 4093.09 2331.05 5 3863.35 W 5997586.99 N 561886.66 E 0.416 4503.40 9973.17 92.150 173.600 4024.82 4091 .32 2378.03 S 3858.05 W 5997540.06 N 561892.38 E 0.170 4525.76 ---------- 10 July, 2002 - 9:48 Page 60f8 Dri/lQflest 2.00.08.005 Sperry-Sun Dr_gServices Survey Repo~.S-25 Your Ref: AÞI ~~~ Job No. AKZZ220B2¡S~:11 June, 2002 . BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) f)/1 OOft) 10019.64 92.340 173.680 4023.00 4089.50 2424.18 S 3852.90 W 5997493.96 N 561897.93 E 0.444 4547.78 10067.58 92.830 174.120 4020.83 4087.33 2471.80 S 3847.81 W 5997446.39 N 561903.44 E 1.373 4570.68 10113.25 92.770 173.790 4018.60 4085.10 2517.16 S 3843.01 W 5997401.07 N 561908.64 E 0.734 4592.54 10159.65 93.450 173.520 4016.08 4082.58 2563.20 S 3837.89 W 5997355.07 N 561914.17 E 1.576 4614.52 10181.58 96.230 172.600 4014.23 4080.73 2584.89 S 3835.25 W 5997333.40 N 561917.00 E 13.348 4624.69 10250.00 96.230 172.600 4006.81 4073.31 2652.34 S 3826.49 W 5997266.03 N 561926.35 E 0.000 4655.85 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Structure. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 235.330° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10250.00ft.. The Bottom Hole Displacement is 4655.85f1., in the Direction of 235.272° (True). Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastings (ft) (ft) (ft) Comment 10250.00 4073.31 2652.34 S 3826.49 W Projected Survey - ---_._-_n___- -.- ---~- - --- - 10 July, 2002 - 9:48 Page 70fB DrillQuest 2.00.08.005 BP EXPLORATION (ALASKA) INC. Milne Point Unit Survey tool program for MPS-25 .'-... From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Sperry-Sun Dri"",gServices Survey Report ,~tlPS-25 Your Ref: API 5OØIIR30B900 Job No. AKZZ22082, Surveyed: 11 June, 2002 . BPXA Milne Point MPS Survey Tool Description 0.00 0.00 10250.00 4073.31 AK-6 BP _IFR-AK 10 July, 2002 - 9:48 -.---..- --- ---------- - Page 80fB DrillQuest 2.00.08.005 :) ) l ~u~r~ (ID~ ~~~~æffi\ A.I/A.~1iA. OIL AND GAS CONSERVATION COMMISSION / / / / TONY KNOWLES, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Milne Point Unit MPS-25 BP Exploration (Alaska), Inc. Permit No: 202-103 Sur Loc: 3284' NSL, 281' WEL, Sec. 12, TI2N, RI0E, UM Btmhole Loc. 615' NSL, 4139' WEL, Sec. 12, TI2N, RI0E, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~~y=: Chair BY ORDER OF THE COMMISSION DATED thisNday of May, 2002 jjc/Enclosures cc: Department of Fish & Game, Habitat Section wlo encl. Department of Envirçmmental Conservation wlo encl. Hole 42" 9-7/8" 6-1/8" STATE OF ALASKA, ALASKA C- )AND GAS CONSERVATION COMMk )ON PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test III Development Oil 0 Service 0 Development Gas 0 Single Zone III Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 68' 6. Property Designation ADL 380109 7. Unit or Property Name Milne Point Unit 8. Well Number / MPS.25 9. Approximate spud dat~ 05/29/02 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10197' MD I 4150' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 91 0 Maximum surface 1451 -Psig, At total depth (TVD) 4152' /1867 psig Setting Depth Top Bottom MD TVD MD TVD Surface Surface 113' 113' Surface Surface 6303' 4164' 6252' 4152' 10197' 4150' \lJ6A- sf î7/~ 1- Ji+- 517 1 a. Type of work III Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3284' NSL, 281' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 4366' NSL, 3772' WEL, SEC. 12, T12N, R10E, UM At total depth 615' NSL, 4139' WEL, SEC. 12, T12N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 025637,615' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 320' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couplina 20" 92# H-40 Welded 7-5/8" 29.7# L-80 BTC 4-1/2" 12.6# L-80 IBT-M 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Lenath 80' 63031 3945' Quantitv of Cement (include staae data) 260 sx Arctic Set (Approx.) 665 sx Class ILl, 270 sx Class 'G' Uncemented Slotted Liner ,./ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RE(:EI\/ED tv!þ\" 0 6 2002 Perforation depth: measured Alasl<a on & Gas Cons. ¡,;omrmsSiOn, - AnchorafJ6 true vertical 20. Attachments III Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch III Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Campbell, 564-4401 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Pat Archey f ~ (i ~7' Title Senior Drilling Engineer Commission Use Only Permit Number API Number Appr9v.aJ Dat~ '- --- See cover letter Z ð .2... - -10 .3 50- 0 Z:9 -2- 3 ð ~? ç-) \~ \ \ (~'! ,~.Jor other reauirements Conditions of Approval: Samples Required 0 Yes 12JNo Mud Log ReqJired 0 Yes.!! No Hydrogen Sulfide Measures 0 Yes;g( No Directional Survey Required ':B Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: Di" €Æu- r-eÖM ~ d . 0ng~tneW~ {; f () "; SOD k'J~, "~ by order o.f . rApproved By r,::1mmy OAd1§li T~yln¡: 0 R' Cf~ls~1e,^ L the commiSSion Form 10-401 Rev. 12-01-85 , \ U \ \! 1-\ Prepared By Name/Number: Sandra Stewman, 564-4750 Date S / 5/{)~ ¿.. ~ ,- \ Date ) ~~\ C~~~ Subllit In Tr'plicate Milne Poin' . r8-25 Well Permit ') rwell Name: I MPt>-2b Drill and Complete Plan Summary 1.1 ype of Well (service / producer / injector): I Multi Lateral producer "UA" & "UI:f' ~urface Location: 1994' t-NL, (3284 t-~L), 281' t-i:.L, (4991 t-WL), ~i:.c.;. 12, 112N, k 1 Oi:. X=565,729.08 Y=5,999,951.78 832' t-NL, (444f' t-~L), 3632' t-i:.L, (164/' t-WL), ~i:.c.;. 12, 112N,K10i:. X=562,368.19 Y=6,001 ,085.41 Z=4099' TVD/RKB 4663' t-NL, (61b' t-~L), 4139' t-i::L, (1140' t-WL), ~i:.c.;. 12, I 12N,k10i:. X=561 ,895.00 Y=5,997,250.00 Z=4100'TVD/RKB 913' t-NL, (4366' t-~L), 3If2' t-i:.L, (1 bOI' t-WL) , ~i:.c.;. 12, 112N,k10i:. X=562,229.12 Y=6,001 ,003.47 Z=4152' TVD/RKB 4663' t-NL, (61b' t-~L), 4139' t-i:.L, (1140' t-WL) , ~I::c.;. 12, I 12N,k101:: X=561 ,895.00 Y=5,997,250.00 Z=4150'TVD/RKB 4663' t-NL, (61b' t-~L), 4139' t-i:.L, (1140' t-WL) , ~i:.c.;. 12, I 12N,k101:: X=561 ,895.00 Y=5,997,250.00 Z=4150'TVD/RKB I At-I:: Number: I.II::SU I Kig: I Uoyon 141 I Il::stimated ~tart uate: I May 29, 2002 I I uperating days to complete: 123 I I MU: 11019/1 IIVu: 141bO I I Max Inc: 190 I I Kul-': 1320 I I KtSl::: 1681 I Well uesign (conventional, slim hole, etc.): I Gonventional Grass Roots Producer I I Ubjective: I ~chrader "UA" & "UI::S" I Mud Program: .. arget Location: TOP "OA" .. arget Location: Bottom "OA" .. arget Location: TOP"OB .. arget Location: Bottom "OB .. otal uepth 9-'¡ /8" ~uñace Hole Mud I-'roperties: Uensity (ppg) I-unnel visc Vp 8.6 - 9.20 H.. HI-' ~pud - L~NU I-reshwater Mud pH AI-'l I-iltrate LG Solids < 6.b Ib - 1bO 2b - 60 9.0-9.b <8 N/A KGL-GaGU3 I-Iow Pro pH AI-'l I- iltrate LG Solids < 12 6-1/8" I-'roduction Hole Mud I-'roperties: Uensity (ppg) I-unnel visc VI-' H I HI-' 8.6 - 9.20 40 - bb 22 - 21 <10 8.0 - 8.b 4 - 6 LCM Restrictions: No Organic LCM products in the Schrader HlutI=ormation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU lR. 1 '~ Cement Program: Casing Size 1'/-5/8" 29:/ lb/ft L-80 BTC Surface casing Hasis 2500/0 excess over gauge hole in permafrost interval, 400/0 excess over gauge hole below permafrost Milne Poin"'fS-25 Well Permit / Wash 50 bbl of Newtonian Wash weighted to 8.32 ppg Spacer 50 bbl of Viscosified Spacer (Alpha Design) weighted to 10.50 ppg Lead 665 sxs 10:/ lblgal Class L - 4.15 cuft/sx (cement to surface) Tail 2'/6 sxs 15.8lb/gal Prem G - 1.15 cuft/sx (top of tail at 5246' MD) Temp I BHST '~800 t' from SOR, HHCT 85° F estimated by Halliburton Evaluation Program: '.'otal Cement Volume: 9 '{ 18" Hole ~ection: Upen Hole: Cased Hole: 6-1/8" Hole section: Upen Hole: MWu/{:;K/KI::~ n-K/(;A~ANuKA N/a MWu/{:;KIKt:~ AI:$I/I"'K/(;A~ANuKA Formation Markers: Formation Tops M Drkb (ft) TVDrkb Pore Pressure ~stimated ~MW (ft) *(Psi) (ppg) Base Permafrost 1924 1822 819 8.65 SVl N/A ,!'op Ugnu 345'/ 1554 8.65 Top UgnuM N/A NA 396"1 1'/84 8.65 NB 39~r/ 1"193 8.65 NC 4012 1804 8.65 NE 402' / 1811 8.65 Nt' 406'/ 1829 8.65 Top OA 4099 1843 8.65 Base OA Top OB 4152 186'/ 8.65 I'D 4152 186'/ 8.65 . tsased on I VL depths CasinglTubing Program: Hole ~ize {;sg I Wtll-t l;rade {;onn Tbg O.D. 20" * 92# H-40 Welded '/-5/8" 29:/# L-80 BTC Length 'lOp tsottom MD I TVDrkb MD I TVDrkb 42" 9 '118" 80' 6303 ' 0' 0' 113'/113' 6303 14164 2 ') Milne Poin" . .'fS-25 Well Permit ! 6-1/8" 4-1/2" OA lateral Slotted 12.6# L-80 IBT-M 4085' 6,083'/4099' 10,168'/4,100' Liner 6-1/8" 4-112" OB lateral Sl<?tted 12.6# L-80 IBT-M 3894' 6,303'/4152' 10,197'/4,150' Lmer ~.I he 20" casing is insulated Recommended Bit Program: i:SHA Hole uepth (Mu) tsit .. ype Size 9 j 18?' 6 1/8?' 1 2 0' - 6303' 6303' - TV' Well Control: Nozzle/l-Iow rate 3-13 & 1-10 T13U Smith ""Twist" Hycalog US-III . 20-1/4" 2M diverter in the surface hole and 13-5/8" 5M BOP stack in the production hole. Suñace Interval: . Maximum anticipated BHP: . Maximum surface pressure: Planned BOP test pressure: . Kick tolerance: . Planned completion fluid: 1867 psi @ 4152TVDrkb - Top of "OB" 1451 psi @ surface (Based on BHP and a full column of gas from TD @ 0.1 psi/ft) 20-1/4" annular function tested. Test BOP Rams to 250 psi low and 3500 psi high, Annular to 250 low and 2500 psi high N/A 9.1 ppg KCL / 6.8 ppg Diesel Drilling Hazards & Contingencies: Hydrates . Hydrates have not been seen on S pad, but has been encountered in the surface holes on other pads, especially nearby H-Pad. Hydrates generally occur just below the Permafrost (+/- 1800 ss) but may be present in shallower SV sands and also as deep as 3000 ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates. Pretreat mud with DrilTreat; Increase mud wt; Maintain cool mud « 60 deg F); Limit ROP and Reduce pump rate while drilling hydrates; Circulate connections thoroughly. See Well Program and Recommended Practices for specific information. . Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne pt wells have experienced stuck pipe from this situation. Lost Circulation . We do not expect losses while drilling this well. . Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Below is a list of the wells and the lost circulating problems associated with them. H-06 (1995): Lost 100 bbls running 9-5/8" casing, good returns during cementing except no returns for last 20 bbls, contaminated cement to surface, cement 12 ft down, no top job. 3 Milne POirr-,PS-25 Well Permit ) . Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures ') . It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be (8.65 Ib/gal EMW). In this well, the Schrader Bluff formation will be drilled with 9.1 ppg mud. Offset injectors that have above normal shut-in pressures will be shut-in prior to drilling this well. Some of the wells on H-pad have experienced sever gas cut mud well below the permafrost. Pad Data Sheet . Please Read the S-Pad Data Sheet thoroughly. Breathing . N/A Hydrocarbons . Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Faults . NA Hydrogen Sulfide . MPS Pad is not designated as an H2S Pad. Anti-collision Issues . MPS-25 has no anti-collision issues. 4 ') DRILL & COMPLETION PROCEDURE Milne Poi..," '}PS-25 Well Permit Pre-Rig Operations 1. The 20" conductor has been pre installed Procedure 1. MIRV, NV 20-1/4" 2 M diverter and lines and function test, PV 4" drill pipe 2. Drill 9-7/8" surface hole as per directional plan. Maximum angle 77° 3. Condition mud with lubes and spot casing running lube pill prior to 7-5/8" casing run. POOH laying down DP 4. Run and cement 7-5/8" casing from TD to surface 5. ND diverter. 6. Install FMC 11" 5m horizontal wellhead 7. N/U and test 13 %" 5m BOP to Rams to 250 low and 3500 psi high, Annular to 250 low and 2500 psi high 8. RIH with 6-1/8" bit and BHA. Test casing to 3500 psi. 9. Drill out float equipment and 25' of new hole and perform FIT to 11.0 ppg 10. Drill 6-1/8" OB horizontal production hole as per directional plan. 11. Run 4-1/2" slotted liner and hang off 100' inside 7-5/8" casing. 12. Make up Baker Window Master milling assembly with bottom trip anchor and MWD. a. RIH. Orient and set whipstock to place window at top of the OA interval. b. Shear off and mill window thru 7-5/8" casing. 13. Drill 6-1/8" OA lateral geosteering and short tripping as required. Maintain FloPro mud properties and POOH. 14. MV whipstock retrieving tool and pull whipstock 15. Run 4 12" slotted liner with Baker Hook Hanger and hang off in 7-5/8" casing 16. Displace out drilling mud with 9.1 ppg KCL 17. POOH 18. Run in hole with 4-1/2" jet pump completion as per schematic 19. Land tubing hanger and test 20. Set BPV 21. ND BOP 22. Install and test tree 23. Pull BPV 24. Freeze protect 25. Drop ball and set production packer 26. Test 7-5/8" x 4-1/2" annulus and packer to 3500 psi 27. Install BPV and secure the well 28. RD/MO 5 . , Field: Milne Point Well: S-25 ML DIRECTIONAL LWD OPEN HOLE LOGGING NONE NONE Dir/GR/RES NONE FORMATION Top of Lead Cement Base of Permafrost Top of Tail Cement Top of N sand ) BP EXPLORATION Milne Point Unit 8-25 & 8-25 L 1 Section 112, T12N, R10E Actual Surface Location: 3284 FSL 281' FEL DEPTH MD I TVD TOC 113' 113' Surf Surf 1,924' 1,822' 5,246' 5,746' 3,985' --ði~/Res. .-..-.. -..-.. -..-..-.. -..-. .----- ABI/GR NONE OA sand 6,083' 4,099' - - . . - . . - . . - . . - . . - . . - . . - . . - .. .1.0.: ~6~ .4.: 1.29~. - 7-5/8" Surface casing 6,303' 4,164' ~.I. ") ENG: Steve Campbell RIG: Doyon 141 MSL 35' RKB: 72' HOLE CASING MUD INFO TOC SIZE SPECS PIT INFO INFORMATION Wellhead LV ;:¡ I,vtr, 40 FMC Gen 6 20" x 11" 5M InsulatedWelde N/A 42" d -1 , .... , '-- --Õi~/Res.._.. -.. -..- ..-..-..-.. -.. - ..----- ABI/GR NONE OB sand 6,252' 4,152' - -.. -.. -.. -.. -.. -.. -.. -.. -.. ..1.°~ ~9~ .4~ ~'.. -.. -.. 4/30/2002 KOP @ 1847' MD EOB @ 2969' MD .. 6-1/8" Hole - 4-1/2", 12.6#, L-80 Slotted Liner 9-7/8" Surface Casing 7-5/8" 29.7# L-80 BTC MW = 9.2 6-1/8" Hole - 4-1/2", 12.6#, L-80 Slotted Liner MPS-25ML WBD.xls TREE: CameronI4-1/16" 5M WELLHEAD: FMC Gen 6 11 ", 5M tbg. head 11" x 4-1/2", FMC tbg. hanger P'-\QP 1\,.. ~ 1101 20" 92 Ib/tt, H-40 Welded Insulated Jet Pump Installed in Sliding Sleeve 7-5/8", 29.7#, L-80, BTC-M Casing Drift: 6.750 Casing I D: 6.875 Coupling 00:8.5" Burst: 6,890 psi Collapse: 4,790 psi Window in 7-5/811 casing @ 6,0831 I Well Inclination @ Window = 70 deg Multi-Lateral Packer 7-5/8" Casing Shoe @ 6,3031 Well Inclination @ Shoe = 77 Degrees PBTD TO DATE COMMENTS REV. BY 05/01/02 SKC level 3 Multi-lateral, 4-1/2" Jet Pump Completion BP Exploration (Alaska) ~ - !:,":' Q " II') ~ ~ ','"",.' LEt~} Q) ~ 0. y II' ,',I I::,:!:t I ":, I ¡¡S.,:" ,¡t~-:,' 1':;1' " :[8":' "~:::: I ,,'II:¡,::::::Jil" 1~1 ') KB. ELEV =67.' Cellar Box ELEV = 39.1' ... 42" Hole 4-1/2",12.6 Ibltt, L-80, BTC-M Coupling 00: 5.2" Orift/lO: 3.833" 7 - 5/8"/6.750" Baker TEC Wire '1,','1 I Ii 4-1/2"x1" Gas Lift Mandrel Selective X Nipple II I D I 1 III Baker CMU Sliding Sleeve with ID Selective X Profile ", Baker Sentry Pressure Gauge (Internal Pressure) .:i,"'::- Baker Packer I 1 "::):"'1:.,:,1"",.,:.,.".,'",',i,.:i,.":,.,:,,,,:,,' ~ No Go XN Nipple "ID Wireline Entry Guide Multi-Lateral Junction 6-118" OA Lateral TD 6-1/8" OB Lateral TD 6,0831 10,168' 10,197' / \~ ....... """"'- - - - - - - - OA Horizontal r-- -- - - - - - - -- 4-1/211 Slotted Liner WIHookwall hanger 2 ~ ~' . ~ 9-718" Hole \ . - - - - "- "- OB Horizontal ------ --- - - - - 4-1/2" Slotted Liner & Hanger / Milne Point Unit WF. . : ~-,?5 M. API NO: , 6083' MD 4099 %'TVD . .1 Start Dir 121100 : D. 10'/100'". 6249 67' MD, 4128.7S'TVD. l I ~ Start Ir .. I ~ 3900 lEd Dc , "64.31' MO, 'm.73' T . ..M 0;, l,o<' . ''''' 41' un. '''', """0 <=> " ! 1J-LÎd~-D' 6/10)"""089.,::¿,::t.93 VD" I / In. 773L4"""40162TVJ 1'\ - -- . .. - -- ''"'' . -.:": ~- I . Emt."., . .w, I . ! :-_:.-~--- :--~=: . ~ J I ~OOO ¡ý .~ {:! 0 ~ / ~ 7000 / ~ / I Ii ~-/ z..-. ~, -L-,-. - / - StattDir.4/IOO':8198.95,~,~.I~ /!I ~ - - -D,L - - -~--- / I E'ld Die : 8239.23' MD, 40S4.09 TVD 2 ¡ , 69S 74' \.1D 41l7jTVD I . I ¡.-. 4200 i Start Jir4.t00 : . .' 7239:8:3'MD 4 III 49'TVD - - -----------t----- -- ElIl Du . . 1 J - - -----1 u.--- - - I I I -------' I I - ---r-- r I-I --.----. i I i ! I I I I I ö COMPANY DETAilS REFERENCE INFORMATION SURVEY PROGRAM Plan: MPS.25L I wp02 (Plan MPS.25/Plan MPS.25L I) ur An",".,:o Co-oo:Jjnat< (HE) R.rer=: W.U C"""", Plan MPS-25. Tru< Nonh Venkal aVD) R.rer=: S.Pad 0.,. 72.00 SoclioD (VS) R<r<reoc.: Slot. (O.ooN.O.ooE) M<3SUrW Depth R.rereoœ: S-Pad D<v 72.00 Cakulation Method: MiIIimum Cu""lure D<pth Fro lkpth To SUJ\"<'y,plau 6083.00 10168.13 PIanœd: Mps.25L1 \\p02 VI Tool Crealed By: Ken Allen Checked: - Dale: Date: 4/l1/2002 MWIr-lFR.MS Caku!.1lion MCIOOd: Mmimum C"">lure ~': ~¡;::,~: ~~~~¿n!<r N.>!Ih Error SurflKç: EIlip6.;a1 . Casing Waminx MetOOd: Rules n_t Reviewed: Date: WELL DETAILS Name "Ni.S Northing Easting Latitude Longitude Slot 565129.08 10"24"J1.124N 149"21'53232W NlA 'EI.W Plan MPS-25 .20.15 ~16.\9 5999951.78 TARGET DETAILS Name TVD -;-Nf-S ~fJ.W NorthiDg Easting Sbape MPS-25LI 13 4094.00 .131.61 -4001.05 5999185.00 56 1735.00 Point MPS--25LI T5 4100.00 .2668.19 .3858.08 5997250.00 561895.00 Point MPS.250APoIy 4102.00 1479.61 .355153 6001400.00 562165.00 Polyg"" MPS.25LI T2 4102.00 .221.68 .399t56 5999695.00 561740.00 Point MPS-25LI T 4 4102.00 .1526.76 -4003.05 5998390.00 561140.00 Point MPS.25L1 TI 4111.00 532.65 .3904.92 600MSO.OO 561820.00 Point SECTION DETAILS See MD Inc Azi TVD +N/-S +FJ-W DLeg TFace VSec Target I 6083.00 70.00 240.00 4099.96 1163.27 -3351.10 0.00 0.00 2094.50 2 6249.67 90.00 240.00 4128.75 1081.62 -3492.53 12.00 """"'---0.00 2257.27 3 6364.38 91.02 228.57 4127.73 1014.78 -3585.51 10.00 -84.86 2371.76 4 6408.92 91.02 228.57 4126.93 985.31 -3618.90 0.00 0.00 2415.99 5 6951.74 91.02 196.00 4117.00 532.65 -3904.92 6.00 -89.70 2908.70 MPS-25L1 Tl 6 7239.83 91.17 184.47 4111.49 249.68 -3956.02 4.00 -89.17 3111.69 7 7650.47 91.17 184.47 4103.13 -159.62 .3988.05 0.00 0.00 3370.85 MPS-25L1 T2 . ~ 8 7712.64 90.92 182.00 4102.00 -221.68 -3991.56 4.00 -95.65 3409.04 9 7736.40 90.92 181.05 4101.62 -245.43 -3992.20 4.00 -89.99 3423.07 10 8198.95 90.92 181.05 4094.19 -707.84 -4000.67 0.00 0.00 3693.06 I I 8222.78 90.00 180.80 4094.00 -731.67 -4001.05 4.00 -164.82 3706.93 MPS-25L1 T3 12 8239.23 89.36 180.65 4094.09 -748.12 -4001.26 4.00 -166.50 3716.46 13 8876.05 89.36 180.65 4101.21 -1384.86 -4008.44 0.00 0.00 4084.55 14 9018.11 90.00 175.00 4102.00 -1526.76 -4003.05 4.00 -83.55 4160.82 MPS-25L1 T4 15 9075.56 90.10 172.70 4101.95 -1583.88 -3996.90 4.00 -87.45 4188.25 16 10168.73 90.10 172.70 4100.00 -2668.19 -3858.08 0.00 0.00 4690.84 MPS-25L1 T5 '\tb -.I'~ ..,.~ " ~ '-..../ "' " ~~ CASING DETAILS No. TVD MD Name Size 4.500 4100.00 10168.72 41/2" 3600- FORMATION TOP DETAILS All TVD depths are ssTVD plus 72'for RKBE. No. TVDPath MDPath Formation 4112.00 6122.81 OA "'- 00- "" i I I 4J. 100001 I 10168.73 MD,4100'TVJ I I ì 1 Start [ ir4/' 00' :~876 os' lD, 410U 1'T ¡ / En:IDir : 9O"S.56 MD,41O .9S' ~ I Jooo 00 co Total ~pth : 2100 2400 2700 3000 3300 3600 Vertical Section at 235.330 [300ft/in] 3900 4200 4500 4800 bp 0 c ~ 0 0 1:::. + J5 t: 0 ~ J5 :; 0 en -1400 -2100 -2800 ("OMI'ANY )ElAII S REFERENCE INFORMATION np Am\~o Co-ordiD3~ (N-E) Reference: Well Centre: PI.m MPS-25, True North VenicaIITVD) Rer"""",,: S.Pa<! 0.,' 72.00 s<':'ion (VS) Rerere"",: SIot- (O.ooN.O.ooE) Measured Depth Rerer"""e: S-Pa<! 0., 72.00 Calculation Method: MiIrimum Cun"3lUre C.1kulalioo MI,.'tJ)r..~: Mmimwn Cur\'.1lUn: t~: ~(~~:r ~~\~~IDd:r Nooh Error SurCx~: Hlirh¡;a1 ' Casing WamiOl Metl.oo: Rule. 11"...,\ 1400- 700 0 ----.- ---- - _._-~---- -- - - - -. --C.- '-LEndIM--;..-72J-9083' MD, 4111.49' TVD 4110; - ---.~ - - -"'"':' D.,..' ,765047' MD, 410313"TVD -- - -. . ~ - ~-.z5b1-'lJ----C-- - - -=-=-=--End-Dir : 77:'6.4' MD, 4101.62' TVD -~ ~L - - -- --- -- -- -- - ~- ----S1 art--..Jif-4í.l~ 98.95' MD, 4094. 19'TVD ~ MPS25L11 . -=-===- Enc--Ði! --:-æ-39;-2-3' MD, 4094.09' TVD -700 - -~ -- - - - --- - -- --.-0-- - -- - --- --~- - 4100-~ - ~ - S~rt ""}ir 4/l()()' : 8876.05' MD, 410 1.21 'TVD ~ ' -------- ""P~h-1--"F4- ~nd Dir : 9075.56' MD, 4101.95' TVD ~~: 4 If¡"~Ii~-t-,u T5 IvPS.25LI wp02 TctalJeph :0168.73' MD, 4100' TVD -------- ----- ---0--- -4200 I -3500 -2800 West(-)lEast(+) [700ft/in] I -2100 SURVEY PROGRAM Depth Fm Depth To Sun~y¡PIan 6083.00 10168.73 PIanœd: MPS-25Ll "1'02 VI Tool MWIHFR-MS Name Plan MPS-25 Name -w.S .20.75 -616.19 5999951.78 Plan: MPS.25L1 "'P02 (Plan MPS.25/Plan MPS.25L1) Created By: Ken AUen Checked: Date: 4/12/2002 Date: Reviewed: Date: WElL DETAILS -Fl.W Northing Loogitude Slot Easting Latitude 565729.œ 70"24'37.124N 149'27'53232W N"A TARGET DETAILS 1VD ~EJ4W Easting Shape 561735.00 Point 561895.00 Point 562165.00 Pol)-goo 561740.00 Point 561740.00 Point 561820.00 Point Northing 5999185.00 5997250.00 6001400.00 5999695.00 5998390.00 6000450.00 ~Nt-S Mps.25L1 13 4094.00 -731.67 -4001.05 Mps.25L1 15 4100.00 .2668.19 .3858.œ MPS.250APoIy 4102.00 1479.67 .355153 MPS-25L1 12 4102.00 .221.68 .399156 MPS-25Ll 14 4102.00 .1526.76 -4003.05 Mps.25L1 n 4117.00 532.65 .3904.92 SECTION DETAILS See MD Ine Azi TVD +N/-S +EI-W DLeg TFaee VSee Target I 6083.00 70.00 240.00 4099.96 1163.27 -3351.10 0.00 0.00 2094.50 2 6249.67 90.00 240.00 4128.75 1081.62 -3492.53 12.00 0.00 2257.27 3 6364.38 91.02 228.57 4127.73 1014.78 -3585.51 10.00 -84.86 2371.76 4 6408.92 91.02 228.57 4126.93 985.31 -3618.90 0.00 0.00 2415.99 5 6951.74 91.02 196.00 4117.00 532.65 -3904.92 6.00 -89.70 2908.70 MPS-25L1 TI 6 7239.83 91.17 184.47 4111.49 249.68 -3956.02 4.00 -89.17 3111.69 .~ 7 7650.47 91.17 184.47 4103.13 -159.62 -3988.05 0.00 0.00 3370.85 8 7712.64 90.92 182.00 4102.00 -221.68 -3991.56 4.00 -95.65 3409.04 MPS-25L1 T2 9 7736.40 90.92 181.05 4101.62 -245.43 -3992.20 4.00 -89.99 3423.07 10 8198.95 90.92 181.05 4094.19 -707.84 -4000.67 0.00 0.00 3693.06 11 8222.78 90.00 180.80 4094.00 -731.67 -4001.05 4.00 -164.82 3706.93 MPS-25L1 T3 12 8239.23 89.36 180.65 4094.09 -748.12 -4001.26 4.00 -166.50 3716.46 13 8876.05 89.36 180.65 4101.21 -1384.86 -4008.44 0.00 0.00 4084.55 14 9018.11 90.00 175.00 4102.00 -1526.76 -4003.05 4.00 -83.55 4160.82 MPS-25L1 T4 15 9075.56 90.10 172.70 4101.95 -1583.88 -3996.90 4.00 -87.45 4188.25 16 10168.73 90.10 172.70 4100.00 -2668.19 -3858.08 0.00 0.00 4690.84 MPS-25L1 T5 FORMATION TOP DETAILS No. TVDPath MDPath Formation 4112.00 6122.81 OA CASING DETAILS ~ y~ '/4b " ~""'-...../, ."" No. TVD Size MD Name 4100.00 10168.72 41/2" 4.500 "----- ~~ All TVD depths are ssTVD plus 72'lor RKBE. ) BP My Planning Report ) Company: Field: Site: Well: Wen path: Field: BP Arnoco MilnePpint MPìSPad Plan. MPS-25 PlaI1MPS-25L 1 Milne Point North Slope UNITED STATES Map System:US Sta.te Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Ä>åt~:'1/12/2()Of ..Thne:Ol:22:27' ... ,.",',..., Page: Co"ordi,a,te(NE)Rêf~~e..ce:, . W~n;,Rlqn MPS,.25; Irue North Yert~cal(:rYQl~~fe..~~ce: $~~aciDev72;O, ..' , , '~ection(YS)'~e(e~nc~:... .., ,. 'vven(~:()ON,O.90~.235,33Azi) ~uryeyC~lc,ulatiC)n,l\1;etb()~: Mil"liniumCul'Vat~re ,:qb: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Wen Centre BGGM2001 Site: M pt S Pad Site Position: Northing: 5999978.00 ft Latitude: 70 24 37.329 N From: Map Easting: 566345.00 ft Longitude: 149 27 35.171 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.51 deg Well: Plan MPS-25 Slot Name: Well Position: +N/-S -20.75 ft Northing: 5999951.78 ft Latitude: 70 24 37.124 N +E/-W -616.19 ft Easting: 565729.08 ft Longitude: 149 27 53.232 W Position Uncertainty: 0.00 ft Wellpath: Plan MPS-25L 1 Drilled From: Plan MPS-25 Tie-on Depth: 6083.00 ft Current Datum: S-Pad Dev Height 72.00 ft Above System Datum: Mean Sea Level Magnetic Data: 4/1/2002 Declination: 26.02 deg Field Strength: 57471 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 235.33 Plan: MPS-25L 1 wp02 Date Composed: 4/10/2002 Version: 1 Principal: Yes Tied-to: From: Definitive Path Casing Points MD TVD Diameter Hole Size ft ft in in ' 10168.72 4100.00 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 NA 0.00 0.00 0.00 NB 0.00 0.00 0.00 NC 0.00 0.00 0.00 NE 0.00 0.00 0.00 NF 0.00 0.00 6122.81 4112.00 OA 0.00 0.00 0.00 TSSC 0.00 0.00 0.00 OS 0.00 0.00 Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/10OO deg/100ft deg/100ft deg 6083.00 70.00 240.00 4099.96 1163.27 -3351.10 0.00 0.00 0.00 0.00 6249.67 90.00 240.00 4128.75 1081.62 -3492.53 12.00 12.00 0.00 0.00 6364.38 91.02 228.57 4127.73 1014.78 -3585.51 10.00 0.89 -9.96 -84.86 6408.92 91.02 228.57 4126.93 985.31 -3618.90 0.00 0.00 0.00 0.00 6951.74 91.02 196.00 4117.00 532.65 -3904.92 6.00 0.00 -6.00 -89.70 MPS-25L 1 T1 7239.83 91.17 184.47 4111.49 249.68 -3956.02 4.00 0.05 -4.00 -89.17 7650.47 91.17 184.47 4103.13 -159.62 -3988.05 0.00 0.00 0.00 0.00 7712.64 90.92 182.00 4102.00 -221.68 -3991.56 4.00 -0.40 -3.98 -95.65 MPS-25L 1 T2 7736.40 90.92 181.05 4101.62 -245.43 -3992.20 4.00 0.00 -4.00 -89.99 8198.95 90.92 181.05 4094.19 -707.84 -4000.67 0.00 0.00 0.00 0.00 Compa~y: BP Amoco Field; Milne point Site: M PtSPad Well: Plan MPS-25 Wellpath: Plan MPS-25L1 Plan Section Information MD ft 8222.78 8239.23 8876.05 9018.11 9075.56 10168.73 Incl deg 90.00 89.36 89.36 90.00 90.10 90.10 Targets Name MPS-25L 1 T3 MPS-25L 1 T5 MPS-25 OAPoly -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 -Polygon 10 MPS-25L 1 T2 MPS-25L 1 T4 MPS-25L 1 T1 ) BP My Planning Report ) Date:. ....4112(2002 Time:.. 07:22:27 Page: Ç()~~~i~~te~)'~f~ren~e: . ,^,øn:~lanMPS..25iTrue North. . YerticalØ'VD) I{efel'e~ce: S.,PadOev72.0 ' S~tion(VS)Referenee:.' W~U(0.OON,ŒOOE,235.3:3AZi) Su.,-ey (Jalculation Metho4: :. ~inimumCllI'vature Db: Oracle Azim TVD +N/,;S +E/-W DLSBuild 'turn.. TFO 'J:'~rget dag ft ft ft " deg/100ft degl100ftdeg/1qQft d~g 180.80 4094.00 -731.67 -4001.05 4.00 -3.86 -1.05 -164.82 MPS-25L 1 T3 180.65 4094.09 -748.12 -4001.26 4.00 -3.89 -0.93 -166.50 180.65 4101.21 -1384.86 -4008.44 0.00 0.00 0.00 0.00 175.00 4102.00 -1526.76 -4003.05 4.00 0.45 -3.97 -83.55 MPS-25L 1 T 4 172.70 4101.95 -1583.88 -3996.90 4.00 0.18 -4.00 -87.45 172.70 4100.00 -2668.19 -3858.08 0.00 0.00 0.00 0.00 MPS-25L 1 T5 fE/-W ~!lê ...' M~p '~~~Lfttituae~ ~..~Ø~g~~ude--> +N/-S ' No~thing , ., Easting ,:Óeg.Mi#S.~... DegMhfySeC' , ft ft' . .ft ,ft 4094.00 -731.67 -4001.05 5999185.00 561735.00 70 24 29.918 N 149 29 50.493 W 4100.00 -2668.19 -3858.08 5997250.00 561895.00 70 24 10.873 N 149 29 46.273 W 4102.00 1479.67 -3551.53 6001400.00 562165.00 70 24 51.668 N 149 29 37.350 W 4102.00 1479.67 -3551.53 6001400.00 562165.00 70 24 51.668 N 149 29 37.350 W 4102.00 1111.52 -3199.72 6001035.00 562520.00 70 24 48.049 N 149 29 27.031 W 4102.00 879.68 -3561.81 6000800.00 562160.00 70 24 45.767 N 149 29 37.643 W 4102.00 -243.09 -3831.73 5999675.00 561900.00 70 24 34.724 N 149 29 45.538 W 4102.00 -1519.49 -3692.94 5998400.00 562050.00 70 24 22.171 N 149 2941.452 W 4102.00 -2721.31 -3503.49 5997200.00 562250.00 70 24 10.353 N 149 29 35.883 W 4102.00 -2695.86 -4123.35 5997220.00 561630.00 70 24 10.600 N 149 29 54.046 W 4102.00 -1365.17 -4181.65 5998550.00 561560.00 70 24 23.687 N 149 29 55.776 W 4102.00 -114.83 -4200.65 5999800.00 561530.00 70 24 35.983 N 149 29 56.353 W 4102.00 984.61 -4120.96 6000900.00 561600.00 70 24 46.797 N 149 29 54.035 W 4102.00 -221.68 -3991.56 5999695.00 561740.00 70 24 34.934 N 149 29 50.223 W 4102.00 -1526.76 -4003.05 5998390.00 561740.00 70 24 22.098 N 149 29 50.539 W 4117.00 532.65 -3904.92 6000450.00 561820.00 70 24 42.353 N 149 29 47.695 W Survey MD Inel Azim TVD Sys TVD MapN MapE VS DLS Tool/Comment ft deg deg ft ft ft ft ft dag/tOOft 6083.00 70.00 240.00 4099.96 4027.96 6001085.41 562368.19 2094.50 0.00 Start Dir 12/100' : 6083' MD, 6089.07 70.73 240.00 4102.00 4030.00 6001082.50 562363.26 2100.21 12.00 MPS-25 OAPoly 6100.00 72.04 240.00 4105.49 4033.49 6001077.25 562354.34 2110.53 12.00 MWD+IFR+MS 6122.81 74.78 240.00 4112.00 4040.00 6001066.15 562335.51 2132.31 12.00 OA 6125.00 75.04 240.00 4112.57 4040.57 6001065.08 562333.69 2134.42 12.00 MWD+IFR+MS 6150.00 78.04 240.00 4118.39 4046.39 6001052.74 562312.74 2158.65 12.00 MWD+IFR+MS 6175.00 81.04 240.00 4122.93 4050.93 6001040.26 562291.57 2183.15 12.00 MWD+IFR+MS 6200.00 84.04 240.00 4126.17 4054.17 6001027.68 562270.21 2207.85 12.00 MWD+IFR+MS 6225.00 87.04 240.00 4128.12 4056.12 6001015.04 562248.74 2232.69 12.00 MWD+IFR+MS 6249.67 90.00 240.00 4128.75 4056.75 6001002.52 562227.50 2257.27 12.00 Start Dir 10/100' : 6249.67' M 6300.00 90.45 234.99 4128.56 4056.56 6000975.11 562185.31 2307.55 10.00 MWD+IFR+MS 6350.00 90.89 230.01 4127.97 4055.97 6000944.34 562145.93 2357.47 10.00 MWD+IFR+MS 6364.38 91.02 228.57 4127.73 4055.73 6000934.87 562135.12 2371.76 10.00 End Dir : 6364.38' MD, 4127.7 6408.92 91.02 228.57 4126.93 4054.93 6000905.11 562101.99 2415.99 0.00 Start Dir 6/100' : 6408.92' MD 6450.00 91.03 226.11 4126.20 4054.20 6000877.02 562072.04 2456.66 6.00 MWD+IFR+MS 6500.00 91.04 223.11 4125.29 4053.29 6000841.13 562037.25 2505.77 6.00 MWD+IFR+MS 6550.00 91.05 220.11 4124.38 4052.38 6000803.47 562004.39 2554.33 6.00 MWD+IFR+MS 6600.00 91.06 217.11 4123.46 4051.46 6000764.14 561973.55 2602.20 6.00 MWD+IFR+MS 6650.00 91.06 214.11 4122.53 4050.53 6000723.25 561944.81 2649.25 6.00 MWD+IFR+MS 6700.00 91.06 211.11 4121.60 4049.60 6000680.91 561918.25 2695.36 6.00 MWD+IFR+MS 6750.00 91.06 208.11 4120.68 4048.68 6000637.24 561893.94 2740.39 6.00 MWD+IFR+MS ) ) BP My Planning Report Company: BP Amoco J)a~:~112/2002,' ThneLQ7:2~:27, . "'.' . Page: FicHd: Milne Peint Co+o..di~ate(~)Ref..,rence: W$II:Rlanfv1pg~2S; True Nørth . Site: MPt gPad Yert;ca~(TVD)~efer~nce:' $:-P;:¡dDev72.0, Wèll: Plan. MP$25 Section(VS)Ref!rence:... VVell.(O.OON,O:OOE;235.33AZi) Wellp~th: Plan MPS~25L1 SurveyCalculation,Meth()d:" , . Minimum' CurVature" })IJ: Qracle Survey MD Inel Azim TVD SysJ'~ ,Map~ M:åpE VS DLS Tool/Coßunent ft deg deg ft tt' ft,' ft .' , ft (jeg/t06ft 6800.00 91.05 205.11 4119.75 4047.75 6000592.35 561871.95 2784.22 6.00 MWD+IFR+MS 6850.00 91.05 202.11 4118.84 4046.84 6000546.38 561852.34 2826.74 6.00 MWD+IFR+MS 6900.00 91.03 199.10 4117.93 4045.93 6000499.44 561835.16 2867.82 6.00 MWD+IFR+MS 6951.74 91.02 196.00 4117.00 4045.00 6000450.00 561820.00 2908.70 6.00 MPS-25L 1 T1 7000.00 91.05 194.07 4116.13 4044.13 6000403.29 561807.89 2945.50 4.00 MWD+IFR+MS 7100.00 91.10 190.07 4114.25 4042.25 6000305.37 561787.86 3018.30 4.00 MWD+IFR+MS 7200.00 91.15 186.07 4112.29 4040.29 6000206.29 561774.70 3086.13 4.00 MWD+IFR+MS 7239.83 91.17 184.47 4111.49 4039.49 6000166.61 561771.39 3111.69 4.00 End Dir : 7239.83' MD, 4111.4 7300.00 91.17 184.4 7 4110.26 4038.26 6000106.60 561767.22 3149.67 0.00 MWD+IFR+MS 7400.00 91.17 184.47 4108.23 4036.23 6000006.87 561760.30 3212.78 0.00 MWD+IFR+MS 7500.00 91.17 184.47 4106.19 4034.19 5999907.14 561753.38 3275.89 0.00 MWD+IFR+MS 7600.00 91.17 184.47 4104.16 4032.16 5999807.41 561746.46 3339.00 0.00 MWD+IFR+MS 7650.47 91.17 184.4 7 4103.13 4031.13 5999757.08 561742.96 3370.85 0.00 Start Dir 4/100' : 7650.47' MD 7700.00 90.97 182.50 4102.21 4030.21 5999707.63 561740.39 3401.45 4.00 MWD+IFR+MS 7712.64 90.92 182.00 4102.00 4030.00 5999695.00 561740.00 3409.04 4.00 MPS-25L 1 T2 7736.40 90.92 181.05 4101.62 4029.62 5999671.25 561739.58 3423.07 4.00 End Dir : 7736.4' MD, 4101.62 7800.00 90.92 181.05 4100.60 4028.60 5999607.67 561738.97 3460.19 0.00 MWD+IFR+MS 7900.00 90.92 181.05 4098.99 4026.99 5999507.69 561738.02 3518.56 0.00 MWD+IFR+MS 8000.00 90.92 181.05 4097.39 4025.39 5999407.72 561737.07 3576.93 0.00 MWD+IFR+MS 8100.00 90.92 181.05 4095.78 4023.78 5999307.75 561736.12 3635.30 0.00 MWD+IFR+MS 8198.95 90.92 181.05 4094.19 4022.19 5999208.83 561735.17 3693.06 0.00 Start Dir 4/100' : 8198.95' MD 8200.00 90.88 181.04 4094.17 4022.17 5999207.77 561735.16 3693.67 4.00 MWD+IFR+MS 8222.78 90.00 180.80 4094.00 4022.00 5999185.00 561735.00 3706.93 4.00 MPS-25L 1 T3 8239.23 89.36 180.65 4094.09 4022.09 5999168.55 561734.94 3716.46 4.00 End Dir : 8239.23' MD, 4094.0 8300.00 89.36 180.65 4094.77 4022.77 5999107.79 561734.79 3751.58 0.00 MWD+IFR+MS 8400.00 89.36 180.65 4095.89 4023.89 5999007.81 561734.54 3809.38 0.00 MWD+IFR+MS 8500.00 89.36 180.65 4097.00 4025.00 . 5998907.82 561734.29 3867.18 0.00 MWD+IFR+MS 8600.00 89.36 180.65 4098.12 4026.12 5998807.84 561734.04 3924.99 0.00 MWD+IFR+MS 8700.00 89.36 180.65 4099.24 4027.24 5998707.85 561733.79 3982.79 0.00 MWD+IFR+MS 8800.00 89.36 180.65 4100.36 4028.36 5998607.87 561733.55 4040.59 0.00 MWD+IFR+MS 8876.05 89.36 180.65 4101.21 4029.21 5998531.83 561733.36 4084.55 0.00 Start Dir 4/100' : 8876.05' MD 8900.00 89.47 179.69 4101.45 4029.45 5998507.89 561733.50 4098.23 4.00 MWD+IFR+MS 9000.00 89.92 175.72 4101.99 4029.99 5998408.04 561738.38 4151.76 4.00 MWD+IFR+MS 9018.11 90.00 175.00 4102.00 4030.00 5998390.00 561740.00 4160.82 4.00 MPS-25L 1 T 4 9075.56 90.10 172.70 4101.95 4029.95 5998332.94 561746.65 4188.25 4.00 End Dir : 9075.56' MD, 4101.9 9100.00 90.10 172.70 4101.91 4029.91 5998308.74 561749.97 4199.49 0.00 MWD+IFR+MS 9200.00 90.10 172.70 4101.73 4029.73 5998209.67 561763.54 4245.46 0.00 MWD+IFR+MS 9300.00 90.10 172.70 4101.55 4029.55 5998110.61 561777.11 4291.44 0.00 MWD+IFR+MS 9400.00 90.10 172.70 4101.37 4029.37 5998011.54 561790.68 4337.41 0.00 MWD+IFR+MS 9500.00 90.10 172.70 4101.19 4029.19 5997912.48 561804.25 4383.39 0.00 MWD+IFR+MS 9600.00 90.10 172.70 4101.01 4029.01 5997813.41 561817.82 4429.36 0.00 MWD+IFR+MS 9700.00 90.10 172.70 4100.84 4028.84 5997714.35 561831.39 4475.34 0.00 MWD+IFR+MS 9800.00 90.10 172.70 4100.66 4028.66 5997615.28 561844.96 4521.31 0.00 MWD+IFR+MS 9900.00 90.10 172.70 4100.48 4028.48 5997516.22 561858.53 4567.29 0.00 MWD+IFR+MS 10000.00 90.10 172.70 4100.30 4028.30 5997417.15 561872.10 4613.27 0.00 MWD+IFR+MS 10100.00 90.10 172.70 4100.12 4028.12 5997318.08 561885.67 4659.24 0.00 MWD+IFR+MS 10168.71 90.10 172.70 4100.00 4028.00 5997250.02 561895.00 4690.83 0.00 41/2" 10168.73 90.10 172.70 4100.00 4028.00 5997250.00 561895.00 4690.84 0.00 MPS-25L 1 T5 MPS-25 Diverter Waiver Denial ) ) Subject: MPS-25 Diverter Waiver Denial Date: Thu, 09 May 2002 11 :03 :39 -0800 From: Winton Aubert <Winton_Aubert@admin.state.akus> Organization: AOGCC ...<"fL-- To: campbels@bp.com ~ j't% cc: Jack Hartz <jack_hartz@admin.state.akus>, ~ Robert P Crandall <bob_crandall@admin.state.ak.us>, Daniel Seamount <dan_seamount@admin.state.akus> Steve, AOGCC hereby denies your verbal diverter waiver request for well MPS-25. In making this decision, Commission staff reviewed information previously submitted in support of your MPS-27 diverter waiver request, which the Commission also denied. Please contact me at your convenience regarding modification of your proposed MPS-25 drilling procedure, currently under Commission review. Sincerely, Winton Aubert AOGCC 793-1231 1 of 1 5/912002 3 :31 PM H 206701 DATE INVOICE I CREDIT MEMO DESCRIPTION 040902 CK040902C PYMT COMMENTS: HANDL:NG INST: PERMIT TO DRILL FEE S/H - TERRIE HUBBLE I í) r:~ ~ ';- ~'...- Yr(~Ó-J. '5 DATE 04íi1/02 CHECK NO. 0020670i GROSS VENDOR DISCOUNT ÁLÁSKAOILA NET iOO. 00 iOO.OO X4Ó28 : ~ ~ - - ',- ~. ...- ", ; , . ;~;ld~~:;;H:¡r MaS¡Ci Q¡ ¿~: ,s\¡~¡C¡'¡Ur-::~!(; , THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ / BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY To The ORDER Of 100.00 iOO. 00 FIRST NATIONAL BANK OF ASHLAND AN AFFlUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 206701 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00206701 ONE HUNDRED & 00/100************************************* US DOLLAR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AVo. 99501 DATE 04/11/02 AMOUNT $100.00 NOT VALID AFTER 120 DAYS ç¿ ð--jh~ - r .-J"j ~ .{ J." / ;./i ,¡ - " . {J., , 4.f ¡.' '..¡,- .r'.:-,4, .. ~~..""........c~.- ~. .r -- 118 2 0 b ? 0 ¡. 118 I: 0 L. ¡. 2 0 :18 9 5 I: 0 0 8 L. L. ¡. 9 118 00 H -' ~ ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BEINCLUDEDINTRANSNDTTALLETTER WELL NAME /1;þt#, n CHECK 1 ST ANDARD LEITER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL v (If api number last two (2) digits are between 60-(9) DEVELOPMENT RED RILL PILOT HOLE (PH) EXPLORA TION ANNULA:R ~OSAL <jLJNO INJECTION WELL ANNULAR DISPOSAL <--J YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL. I?flt.Ç -2-5 "CLUE" The permit is for a new wellbore segment of existing weD ~ Permit No, . API No. . " Production should continue to be reported as a function of the original API number stated above. ' In accordance with 2,0 AAC 25.005(t), aU r~ords, data and logs acquired for the pilot bole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for wel~ (n~me on permit). . Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated... . ANNULUS L-J YES + SPACING EXCEPTION Template5 are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved ,sùbJec:t to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY If P)¿ WELL NAME 11'-( - ~ ~ FIELD & POOL 6"::J. S ) Lf C) INIT CLASS I),p-v /-ð~. / ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 'Y\ N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . y' N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N ~PR ~~!~ 12. Permit ca~ be issued without administrativ~ approval.. . . . . ~ N t'ft:... S/,/,/b;;;>... 13. Can permIt be approved before 15-day walt.. . . . . . . . . . Y N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . N 15. Surface casing protects all known USDWs. . . . . . . . . . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . N 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . .Y-N- ¡ú /It- ¡ 18. CMT will cover all known productive horizons. . . . . . . . . . -¥-N ~/o tf-e d. 19. Casing designs adequate for C, T, B & permafrost. . . . . . . tfi!. N 0 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . ét N /)..vj th---. ''-I' 21. If a re-drill, has a 10-403 for abandonment been approved. . .¥-N- N. / It 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . N 24. Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N 26. BOPE press rating appropriate; testto 5~oo psig. N /IIl<; r (c./S ( (1~, 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ 30. Permit can be issued w/o hydrogen sulfide measures. . . . . &5>N 31. Data presented on potential overpressure zones. . . . . . . XN /) 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y /1 ~ /Y APPR DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N Ijt~ .$7~7 34. Contact namelphone for weekly progress reports [exploratory 0 1 Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal' (0) will not damage producing formation or impair recovery from pool; and (E) will not circumvent 20 MC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP~ SFD- PROGRAM: Exp - Dev K Redrll - Serv - Wellbore seg - Ann. disposal para req - GEOL AREA ~7 ~--> UNIT# // :1..2.... ? ON/OFF SHORE a ~ :If ~~-//) J~¡. .~'-.t _.~~: ¿ APPR DATE W6¡\-' '5//7/ () 1. GEOLOGY APPR DATE ~ ~~l- Æ/~/t , ~ WGA WG1!r .:$ COT ,h DTS 0 J"j ¿Or~ L JMH _'S"...----I.~~ /2. - r "'7/.''..,..1 w/ /V$. --- ,..(;:'0::: ( Comments/Instructions: ') ) Well History File APPENDIX Information of detailed nature that is not particularly gennane 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. ') ') aoa-/Q3 } 09¡ ~) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Aug 21 09:40:44 2002 Reel Header Service name............ .LISTPE Date.................... .02/08/21 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments... ............. .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02/08/21 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.... ........... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-25 500292308900 BP Exploration (Alaska), Inc Sperry-Sun Drilling Systems 21-AUG-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22082 B. HENNINGSE E. VAUGHN MWDRUN 2 AK-MW-22082 B. HENNINGSE E. VAUGHN MWDRUN 3 AK-MW-22082 J. STRAHAN C. DIXON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW-22082 J. STRAHAN C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 1994 281 MSL 0) 66.50 39.00 ) ) # WELL CASING RECORD 1ST STRING 2ND STRING 3 RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 20.000 110.0 6.125 7.625 6366.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1, 2, 3, AND 4 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4)¡ AND PRESSURE WHILE DRILLING (PWD). RUN 4 ALSO INCLUDED AT-BIT-INCLINATION (ABI). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 7/08/02. MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1, 2, 3, AND 4 REPRESENT WELL MPS-25 WITH API#: 50-029- 23089-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10250'MD/4073'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .02/08/21 Maximum Physical Record..65535 File Type............... .LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # 1 clipped curves¡ all bit runs merged. .5000 FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ ) ) START DEPTH 60.0 69.5 69.5 69.5 69.5 69.5 110.5 STOP DEPTH 10196.0 10203.0 10203.0 10203.0 10203.0 10203.0 10250.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO 1 2 3 4 MERGE TOP 60.0 1193.0 5705.5 6378.0 MERGE BASE 1193.0 5705.5 6378.0 10250.0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ... . Undefined Absent value. ............... .... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 60 10250 5155 20381 60 10250 ROP MWD FT/H 1.64 1411.12 254.058 20280 110.5 10250 GR MWD API 7.36 126.78 69.0843 20273 60 10196 RPX MWD OHMM 0.1 2000 139.342 20268 69.5 10203 RPS MWD OHMM 0.1 2000 177.743 20268 69.5 10203 RPM MWD OHMM 0.08 2000 144.103 20268 69.5 10203 RPD MWD OHMM 0.05 2000 199.084 20268 69.5 10203 FET MWD HOUR 0.04 255.42 1.94413 20268 69.5 10203 First Reading For Entire File........ ..60 J Last Reading For Entire File....... ... .10250 File Trailer Service name........... ..STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..02/08/21 Maximum Physical Record..65535 File Type.............. ..LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/08/21 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Previous File Name.. .... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 60.0 69.5 69.5 69.5 69.5 69.5 110.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 1141.5 1151.5 1151.5 1151.5 1151.5 1151.5 1193.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA 24-MAY-02 Insite 66.37 Memory 1193.0 60.0 1193.0 .3 19.9 TOOL NUMBER PBOO160HWGR6 PBOO160HWGR6 ) OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.... ......... ....Down Optical log depth units.... ..... ..Feet Data Reference Point............. . Undefined Frame Spacing................ .... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 ) 9.875 110.0 Spud Mud 8.70 175.0 7.5 900 13.8 .000 .0 .000 59.0 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD010 FT/H GR MWD010 API RPX MWD010 OHMM RPS MWD010 OHMM RPM MWD010 OHMM RPD MWD010 OHMM FET MWD010 HOUR Min 60 10.68 18.14 2.22 3.06 3.68 5.86 0.05 Max 1193 353.75 100.87 2000 2000 2000 2000 3.08 First Reading For Entire File......... .60 Last Reading For Entire File.... ...... .1193 Mean 626.5 176.276 53.5205 867.329 1097.69 803.547 1252.46 0.491691 Nsam 2267 2166 2164 2165 2165 2165 2165 2165 First Reading 60 110.5 60 69.5 69.5 69.5 69.5 69.5 Last Reading 1193 1193 1141.5 1151.5 1151.5 1151.5 1151.5 1151.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .02/08/21 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/08/21 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS FET RPD RPX RPM ROP $ 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 1142.0 1152.0 1152.0 1152.0 1152.0 1152.0 1193.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 5654.5 5664.5 5664.5 5664.5 5664.5 5664.5 5705.5 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 05-JUN-02 Insite 66.37 Memory 5706.0 1193.0 5706.0 20.9 67.5 TOOL NUMBER PBOO160HWGR6 PBOO160HWGR6 9.875 DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. .................0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value.. ................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 110.0 Spud Mud 9.10 98.0 7.8 300 5.4 4.300 3.160 7.000 4.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR Min 1142 3.66 7.36 0.1 0.1 0.08 0.05 0.04 Max 5705.5 1411.12 126.78 2000 2000 2000 2000 255.42 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 First Reading For Entire File..... .... .1142 Last Reading For Entire File.......... .5705.5 Mean 3423.75 342.414 67.1751 80.5115 102.366 92.8964 110.7 2.82988 Nsam 9128 9025 9026 9026 9026 9026 9026 9026 ) 68.0 95.0 68.0 68.0 First Reading 1142 1193.5 1142 1152 1152 1152 1152 1152 Last Reading 5705.5 5705.5 5654.5 5664.5 5664.5 5664.5 5664.5 5664.5 File Trailer Service name. ..... ...... .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..02/08/21 Maximum Physical Record. .65535 File Type. .......... .... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name. ........... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/08/21 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPX RPS RPD RPM ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 5655.0 5665.0 5665.0 5665.0 5665.0 5665.0 5706.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 6327.0 6337.0 6337.0 6337.0 6337.0 6337.0 6378.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 07-JUN-02 Insite 66.37 Memory 6378.0 5706.0 6378.0 64.7 81.7 TOOL NUMBER PBOO160HWGR6 PBOO160HWGR6 9.875 110.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction.. ....... ....... . Down Optical log depth units.......... .Feet Data Reference Point..... ........ . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. .................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Spud Mud 9.20 135.0 8.0 300 5.2 2.800 2.090 6.000 2.600 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR Min 5655 11.7 32.16 4.85 5.44 5.71 5.58 0.21 Max 6378 827.55 114.54 137.32 237.19 233.34 166.5 22.64 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 First Reading For Entire File......... .5655 Last Reading For Entire File.......... .6378 Mean 6016.5 159.459 78.9354 17.3153 19.6262 22.121 21.1156 1.9017 Nsam 1447 1345 1345 1345 1345 1345 1345 1345 ) 72.0 98.6 72.0 72.0 First Reading 5655 5706 5655 5665 5665 5665 5665 5665 Last Reading 6378 6378 6327 6337 6337 6337 6337 6337 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation... ... .02/08/21 Maximum Physical Record. .65535 F i 1 e Type...... . . . . . . . . . . LO Next File Name..... ..... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/08/21 Maximum Physical Record. .65535 File Type. .............. .LO Previous File Name.. .... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 5 ) header data for each bit run in separate files. 4 .5000 START DEPTH 6327.5 6337.5 6337.5 6337.5 6337.5 6337.5 6378.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 10196.0 10203.0 10203.0 10203.0 10203.0 10203.0 10250.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # 11-JUN-02 Insite 66.37 Memory 10250.0 6378.0 10250.0 85.4 96.2 TOOL NUMBER PB00193HAGR4 PB00193HAGR4 6.125 6366.0 ) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... ... ......0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units..... ... ...Feet Data Reference Point......... .... . Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absen t value. . . . . . . . . . . . . . . . . . . . . . - 9 9 9 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) Flo-Pro 9.20 51.0 7.5 37000 4.2 .080 .060 .100 .120 72.0 92.0 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6327.5 10250 8288.75 7846 6327.5 10250 ROP MWD040 FT/H 1.64 684.3 189.271 7744 6378.5 10250 GR MWD040 API 33.07 123.76 73.9516 7738 6327.5 10196 RPX MWD040 OHMM 0.22 1768.43 25.4046 7732 6337.5 10203 RPS MWD040 OHMM 0.24 2000 35.6491 7732 6337.5 10203 RPM MWD040 OHMM 0.24 2000 40.4502 7732 6337.5 10203 RPD MWD040 OHMM 0.08 1957.34 38.2668 7732 6337.5 10203 FET MWD040 HOUR 0.21 74.76 1.32422 7732 6337.5 10203 First Reading For Entire File......... .6327.5 Last Reading For Entire File.......... .10250 File Trailer ) ) Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/08/21 Maximum Physical Record. .65535 File Type... ............ .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02 / 08 / 21 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name...... ......... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments... ............. .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02 / 08 / 21 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name... ............ . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments..... ........... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File