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Home My WebLink About192-041 • • STATE OF ALASKA RECEIVED�� 203 • ALASKA OIL AND GAS CONSERVATION COMMI ON REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon El Repair Well❑ Plug Perforations ID Perforate El Other El Run Gas Lift Completion Performed: Alter Casing❑ Pull Tubing U Stimulate-Frac El Waiver❑ Time Extension El Change Approved Program❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WeII❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development O Exploratory❑ 192-041 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service❑ 6.API Number: Anchorage,Alaska 99504 50-733-20434-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018761 ' Granite Point 50 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Hemlock Undef Oil/Tyonek Undef Oil 11.Present Well Condition Summary: Total Depth measured 12,145 feet Plugs measured 11,020(cmt) feet true vertical 11,801 feet Junk measured 11,548 feet Effective Depth measured 11,020 feet Packer measured 8,723 feet true vertical 9,720 feet true vertical 7,754 feet Casing Length Size MD ND Burst Collapse Conductor 169' 24" 169' 169' Conductor 121' 26" 289' 289' Conductor 982' 18-5/8" 982' 982' Surface 3,820' 13-3/8" 3,820' 3,803' 3,450 psi 1,950 psi Production 10,063' 9-5/8" 10,063' 9,816' 6,870 psi 4,760 psi Liner 2,445' 7" 12,086' 11,746' 14,160 psi 11,720 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 8,783'(MD) 7,802'(ND) 8,723'(MD) 305'(MD) Packers and SSSV(type,measured and true vertical depth) DHL Hyd Set Pkr 7,754'(TVD) SSSV 305'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED : '3 ' ' Treatment descriptions including volumes used and final pressure: , ��! z 3, ;� 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 94 190 42 502 78 Subsequent to operation: 138 171 0 890 60 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ DevelopmentI - Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U . Gas ❑ WDSPL❑ 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: 313-398,313-478&313-516 Contact Dan Taylor Email dtavIor(C7hiIcoro.com, Printed Name Dan Taylor Title Operations Engineer I Signature Phone 907-777-8319 Date 11/7/2013 1 RBDMS NOV 19 C Form 10-404 Revised 10/2012 „to, Submit Original Only ./ " 6, H • • Granite Point Platform Well #: GP-50 SCHEMATIC Completion Date: 10/07/2013 Ilils•,un 1I.g.i.g.1.1.4. PTD: 192-041 API: 50-733-20434-00 CASING DETAIL RKB to TBG Head=43' Size WT Grade Conn Top Btm I1 24" 186.5# X-42 RL45 Surf 169' 4124„ 26" N/A N/A N/A 168' 289' 26" 18-5/8" 87.5# X-56 RL4C Surf 982' 13-3/8" 68# K-55 BUTT Surf 3,820' D 2 9-5/8" 47# N-80 BUTT Surf 7,550' 18-5/8" 9-5/8" 53.5# P-110 BUTT 7,550' 10,063' D 3 7"Liner 32# P-110 BUTT 9,641' 12,086' TUBING DETAIL D 4 2 7/8" 6.5# L-80 EUE Surf 8,783' 4 13-3/8° JEWELRY D 5 No Depth ID Item 1 305' 2.310 SCSSV D 6 2 2,338' 2.441 GLM 3 4,434' 2.441 GLM 4 6,143' 2.441 GLM 7 5 7,515' 2.441 GLM X 8 6 8,672' 2.441 GLM 9 7 8,723' 4.00 DHL Hydraulic Set Packer - C-5 8 8,775' 2.313 X Nipple 9 8,783' 2.500 WLEG C-6 10 11,020' Cement Retainer w/25 sx of class G cement above&75 below Liner Hanger IMF-- C-7 9,641' 9-5/8" , C-8 PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Status - C-9 C-5 8,823' 8,839' 8,642' 8,658' 16 Open C-6 8,931' 8,964' 8,745' 8,777' 33 Open C-7 9,178' 9,199' 8,981' 9,001' 21 Open C-7 9,219' 9,292' 9,020' 9,089' 73 Open C-10 C-7 9,327' 9,335' 9,122' 9,129' 8 Open C-8 9,645' 9,656' 9,422' 9,432' 11 Open C-9 9,722' 9,734' 9,494' 9,506' 12 Open = C-11 C-9 9,738' 9,742' 9,509' 9,513' 4 Open C-9 9,778' 9,813' 9,547' 9,580' 35 Open C-9 10,038' 10,048' 9,793' 9,802' 10 Open 10 C-9 10,149' 10,155' 9,899' 9,905' 6 Open Damaged casing C-9 10,185' 10,201' 9,933' 9,949' 16 Open 11,479'-11,485 . and C-9 10,253' 10,283' 9,999' 10,028' 30 Open 11,518-11,570- C-10 10,596' 10,614' 10,327' 10,345' 18 Open a 1- - Hemlock C-11 10,806' 10,827' 10,529' 10,549' 21 Open 11/21/12-Tag 0000000 11,455' 11,503' 11,152' 11,198' 48' isolated TOF/Fish @ 11,548' 0� = 11,511' 11,535' 11,206' 11,228' 24' Isolated ODCHemlock �O 11,562' 11,735' 11,254' 11,418' 173' Isolated 11,765' 11,888' 11,446' 11,561' 123' isolated PBTD=12,060' TD=12,145' Updated by JLL 11/07/13 • • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP-50 50-733-20434-00 192-041 8/22/13 10/7/13 Daily Operations: 08/22/13-Thursday Rigging up. 08/23/13- Friday Rigging up. 08/24/13-Saturday RU, circulated 720 Bbls of 6%to production. ND wellhead. NU riser. NU Flowcross/double gate BOP's. NU Annular preventer. Total of 720 Bbls Pumped down Annulus. 08/25/13-Sunday Continued with RU. Continued testing manifold valves and gas detection system. Set cat walk and beaver slide. Set trip tank. Set gas buster stand and gas buster, hooked manifold to gas buster and pits. Tested BOP's 250 psi low and 2500 psi high,tested annular with 750 psi on accumulator to 250 psi low and 1500 psi high. Witness of test waived by Jim Regg, AOGCC. Installed floor section of rig. Installed hard line to gas buster and manifold. 08/26/13- Monday MU 2 joints of 3" IBT. Landed in top of hanger. Backed out lock pins and line up pin. PU to 78k and hanger popped free, pulled up to 96K(24k over string weight). MIRU E-line Unit. RIH W/CCL/1-9/16"tbg puncher.Sat down @ 10,587 elm. PU to 10, 582' and perforated tbg from 10582'-10585'. POOH.When pulling out of hole, pulled into the SSV, kick rig pump on to work thru valve. MU 1-11/16" RCT tool/CCL on centralizer. RIH,tagged bottom @ 10,587'. PU up into position (10,571' elm), attempted to cut 2-7/8" 6.4# N-80 tbg, 3 times unsuccessfully. POOH, hung up in SSV. Tried to work free with rig pump and line, line parted, dropped tool string to bottom. Dropped hold open tool down tbg, chased down with 2.3 Blind Box and tapped into place. POOH. MU 1" Pulling tool, RIH to top of tool string @ 10574', sat down on tool string and PU, weight indicator show 150 psi change. POOH, recovered tool string. MU new 1-11/16" RCT tool/CCL/on centralizer. RBIH to top of fish @ 10,591' elm, PU to desired depth and made cut @ 10,571' elm. POOH, RDMO E-line Unit. 08/27/13-Tuesday Laid down 3" IBT landing joints, laid down tbg hanger, and 2-2 7/8" IBT pup joints. Continued TOH laying down 2 7/8" 6.4#N-80 IBT Production Tbg. Laid down total of 331 jts,total legnth of tbg/mandrels/pups, (10,526.50'). Installed flow nipple, hooked up flow lines to pits/trip tank. Installed flow paddle for PVT system. MU 5" overshot dressed with 2 7/8" Right handed wicker grapple on BHA and 3" PH-6 WS.Tripped in hole with total of 76 stands of 3 1/2 WS, 6 drill collars, bumper jar, eccelerator jar, and over shot. • 08/28/13-Wednesday Continued TIH W/3-1/2" WS and 5-3/4" overshot,tag top of fish @ 10,571'. PU and MU power swivel. Engage grapple, PU to 200k to lock grapple in, worked pipe back down. PU to 154k, 7 thousand over string weight and turned WS to the right 15 turns, let off on WS to 150K and put 13 more rounds to the right on tbg, seal assembly released. PU/LD power swivel and a single, weight was dragging up to 160K, SOOH W/ 167 stands of 3 1/2 PH-6 WS. L/D overshot and fish, continued laying down 2 7/8 IBT production tbg. L/D total of 21 jts and seal assembly, coil tbg was not inside of tbg. MU 5 3/4 overshot loaded with 1 1/2 grapple.TIH W/overshot, bumper jar, oil jar,4-drill collars, accelerator jars and 3 1/2 PH-6 WS,total of 91 stands in at 6am. 08/29/13-Thursday TIH W/5 3/4 overshot loaded with 1 1/2 grapple,TIH W/167 stands,tagged coil fish @ 10,600', worked over top of coil, continued picking up singles stripping over coil. PU 19 more singles before taking on weight. Sat down @ 11,180', PU and pulled up to 200k(40K over string weight) max pull with rig,coil would not move, worked coil up and down setting off jars several times before getting movement. Coil began to move up hole, dragging from 160-190, coil drug for 45 ft, before coming back down to string weight. TOH laying down 3 1/2 WS, laid down 336 joints and had top of fish looking up, started stripping coil out 3 1/2 WS, laid down 19 more jts in process, recovered approx 750'of coil and coil tools.Welbore continues to stay full of fluid, had to pull string wet. Last 180 ft of coil full of formation sand. 08/30/13- Friday Finished laying down coil tbg fish, recovered all coil tbg tools, recovered 728 ft of 1 1/2 coil.Clean rig floor and equipment. Racked and tallied 2 7/8 7.9# PH-6 WS. Started making up Burn shoe BHA.TIH WI 5 1/2 OD Burn shoe,4 3/4 Baker Inteq motor, 2 boot baskets, 2 inline magnets, bumper jar, oil jar, 6 Drill collars, and 2 7/8 PH-6 WS,TIH W/BHA and total of 310 jts of 2 7/8 PH-6 WS. 08/31/13-Saturday TIH W/2 7/8 PH-6 WS and motor/burn shoe, started taking weight at 11,155', MU power swivel and started washing down, washed down to 11,212'( 14 FT HIGH). Started attempting to mill, appeared to have made 1 ft over 5 hrs. Laid down power swivel„ SOOH W/2 7/8 PH-6 WS, laid down boot baskets/magnets, and baker motor, inspected burn shoe, burn shoe had no signs of wear, all indications say motor was not turning. Tools covered in parafin and asphalteens., MU same 5 1/2 Burn shoe on new 4 3/4 NOV mud motor, double boot baskets, double magnets, bumper jar, oil jar, 6 drill collars and 2 7/8 PH-6 WS,TIH to 11,155, MU Power swivel, 09/01/13-Sunday Started burning over_packer,_burned over packer in4 hrs_pumping at 5.5 Bbls/min @ 1575 psi on surface. Made 18" and lost 150 psi pump pressure and all torque at surface. Jarred down several times and started POOH, had 30K over pull, SOOH W/2 7/8 PH-6 WS,total of 178 Stands SB. Removed wear bushing from head, landed test joint and test plug. Installed TIW and Dart valve on test joint, landed test joint in top of test plug, hooked up test pump to test joint and performed pre-test on plug and pipe rams. Made ready for Bob Noble with AOGCC to witness BOP test on Monday 9/2/2013. • • 09/02/13- Monday Performed maintenance of rig and rig equipment while waiting on approval to move forward with BOP test. Loaded test joint and attempted to start BOP test, could not get first test. Pulled Test plug out of well head and found 0-ring cut, replaced 0-Ring and filled BOP's. Started BOP Test.AOGCC inspector arrived on platform.Tested BOP's to 250 psi low and 2500 psi high,tested annular 250 psi low and 2500 psi high, no failed tests,calibrated and tested gas detection system and tested PVT system.AOGCC inspector(Bob Noble)signed off on test. MU landing joint in test plug, pulled test plug, laid test plug down, made up wear bushing assembly and installed wear ring in wellhead, pulled out of hole landing assembly, laid down landing joint. MU 5 15/16 OD KHT Packer type burn shoe, 2-5' Boot Baskets, 2-5' magnets,4 3/4 bumper jar,4 3/4 oil jar, 6 drill collars on 2 7/8 PH-6 WS,TIH W/178 stands of 2 7/8 PH-6 WS. MU Power swivel and pump line.Top of packer @ 11,211', started pumping at 3.5 Bbls per min and started burning over packer. Burned through last set of slips- burn shoe and WS fell approx 2 ft. Circulated bottoms up to ensure hole clean. Laid down power swivel. 09/03/13-Tuesday SOOH W/2 7/8 WS, laid down burn shoe, magnets and boot baskets, recovered metal and rubber debris from packer. MU 5 3/4 short catch overshot loaded with 41/8 grapple, bumper jar, oil jar, 6 drill collars accelerator jar and 178 stands of 2 7/8 PH-6 WS. MU Power swivel and pump lines. PU 1 single joint of 2 7/8 WS,tagged top of fish @ 11,214', sat down caught fish, attempted to straight pull the packer, come up hole 20 ft and hung up. Pulled 155K, setting jars off on up stroke and beating back down. Continued to work pipe with jars for 50 ft, pipe freed up after laying down 3 singles, laid down power swivel and began SOOH.SOOH W/ 167 stands and drill collars, laid down overshot with packer assembly in grapple, laid down 4 single joints of 2 7/8 IBT Tbg, XN nipple, 10 ft pup with scoop head. Cleaned rig floor,tongs,etc. MU 5 3/4 Overshot W/2 7/8 right wicker grapple, on same BHA, started TBIH. TIH W/137 stands of 2 7/8 PH-6 WS. 09/04/13-Wednesday HSM.TIH with remaining 2-7/8" PH-6 WS,tagged top of fish @ 11,373 ft. MU Power swivel and pump lines, engaged fish with grapple, beat down several times to ensure grapple set. PU 10k over string weight, (108K string weight), put 15 rounds to the right in pipe with power swivel,worked pipe up and down to get torque to bottom, saw K-Latch release and back out of top of hanger. PU and laid down 2 single with power swivel. RD Power swivel and pump line. SOOH W/169 stands of 2-7/8" PH-6 WS. Laid down 13 ft of fish. Cut tbg and latch assembly. MU 5-15/16" packer type burning shoe, wp ext, top bushing, double pin sub, 2-boot baskets, double box sub, 2-string magnets, bumper jar, oil jar, 6-4-3/4" drill collars,xo = 245.83'. MU 5-5/16" packer type burning shoe, wp ext,top bushing, double pin sub, 2-boot baskets, double box sub, 2-string magnets, bumper jar, oil jar, 6-4-3/4" drill collars, xo= 244.97'. TIH t/tof @ 11,375'. P/U swivel burn over packer, pump 3 bpm @ 600 psi. 09/05/13-Thursday Continue burn over shoe, made approx 20" total. L/D swivel,SOOH t/look at burn shoe. L/D burn shoe approx 20% wear. P/U new burn shoe BHA#9 packer type burning shoe, wp ext,top bushing, double pin sub, 2-boot baskets, double box sub, 2-string magnets, bumper jar, oil jar, 6-4-3/4" drill collars, xo= 245.83'. TIH t/tof @ 11,376', up wt 93, dn wt 87, rot wt 88, pump 2 bpm 300 psi, rot 75 rpm 3-4k tq. P/U swivel, burn over packer, up wt 93, dn wt 87, rot wt 88, pump 2 bpm 300 psi, rot 75 rpm 3-4k tq. RIH down to 11,430'. Circ hole clean @ 11,430'. Swivel out L/D 2-jts. R/D power swivel. Continue POOH standing back 2.875" PH-6 workstring.T/BHA. • • 09/06/13-Friday LID Burn shoe BHA. Clean &clear floor. P/U BHA#10-Short catch overshot W/4-1/8" grapple, bumper jar, oil jar, 6 drill collar, accel jar,xo, = 219.99'.TIH t/ 11,400', up wt 103, dn wt 87. P/U swivel, CBU @ 3 BPM. Monitor well. Engage fish @ 11,430', pull 130k dropping t/114k. Pump pill. POOH and L/D 53' of fish. M/U fishing( BHA# 11), 6" bit 7" csg scraper, double box sub, bumper jars, oil jars, 6 4-3/4" D.C.s,X/O to 2-7/8" PH-6 workstring. RIH w/52 jts. M/U X/O's, 9- 5/8" scraper,X/O back to 2-7/8" workstring continue RIH w/workstring. 09/07/13-Saturday Continue TIH w/BHA#11-7" &9-5/8" scraper assembly,t/ 11,450', up wt, 106 dn wt 89.Work 11,450'-11,390' 6x, & 10,860'-10,920'. CBU @ 3 bpm 750 psi,0-G/L. Mix& pump pill. POOH L/D fishing BHA#11. M/U 7" RTTS Packer BHA#12, TIH w/362 Jts. of 2.875" PH-6 workstring packer setting depth @ 11,395', set packer, up wt 98, dn wt 72. Load csg adjust valves to pressure test csg.Valve on packer not holding. Reset packer and load casing.Valve still leaking. 09/08/13-Sunday Continue to test casing. Move RTTS up t/ 11,331', reset, P/T casing t/1500 psi hold for 20 min &chart good, bleed down, release RTTS. POOH L/D 2-7/8"work string&7" RTTS. Clean &clear floor. R/U & pull wear ring. Build test jt. Test BOP's w/3-1/2" test joint as per Hilcorp &AOGCC regulations, 250 psi low/2500 psi high, 5 min each, all tested good.Witness of test waived by Lou Grimaldi @ 11:48 on 9-7-13. Pull test plug, re-run wear ring, break down test jt. 09/09/13- Monday M/U &TIH W/( BHA#13), 5-3/4" wash pipe shoe, 12jts. 5-3/4" wash pipe,X/O 3 jts. of 5-1/2" wash pipe,Top Bushing, Bumper Jars, Oil Jars, 6-4-3/4" drill collars,X/O to 3.5" PH-6 workstring. EOT @ 9,860' String wt. @ TOL 120K up 109K down. Rig shut down for crane repair. 09/10/13-Tuesday TIH p/u 3-1/2" work string t/tag @11,428', up wt 175, dn wt 120. P/U swivel, break reverse circ.@ 3 bpm, 665 psi.Wash down f/ 11,428't/ 11,459', up wt 185, dn wt 116, 3 bpm 665 psi. Reverse CBU @ 3 bpm, 670 psi, getting 4920 units of gas back&traces of oil.Shut down after b/u gas. Continue t/break out and flow from tubing side. CBU again with same results.Shut tubing in &watch tubing psi for hour, initial SITP 25 psi,TP after hour 95 psi. Weight up fluid in pits to 9ppg. Circulate @ 3 bpm wt up fluid while circulating till 9 ppg around full system. Shut down & monitor well, static, make connection. Wash down f/ 11,459't/11,490'jt. 349 up wt 185K down wt.116K. P/U on string pull up to 220K work tbg. jar free max out on string wt. CBU bringing sand/oil mix gas units up to 3900. Wk string down to 11,482'.CBU get max gas units of 500. Break out jt.w/swivel tbg- light flow. Mix up dry pipe pill, pump 30 bbls. down tbg. Break out jt#349 and L/D. Start R/D swivel. 09/11/13 -Wednesday POOH w/3.5" PH-6 Workstring and wash over assy. Pulled shoe and found it had broken off leaving a 3' piece of shoe in hole. Wait on spear grapple. M/U ( BHA# 14) spear load w/5.013" grapple, stop sub, Bumper jars, Oil Jars, 6-4 3/4" Drill collars, accel Jars,X/O to 3.5" workstring.TIH w/3.5" workstring EOT @ 10,996'. 09/12/13-Thursday Service rig. P/U 3.5" PH6 wk string RIH f/10,966't/11,458'. P/u swivel, single & m/u, up wt 172, dn wt 118. Break circ. TIH t/ 11,485'tag TOF. Latched and pulled 205k, moving it up hole. L/D swivel. POOH & L/D fish, 2.9' 5-3/4" shoe. Waiting on wireline unit. Drain &clean pits.Service rig. • • 09/13/13-Friday R/U wireline. RIH w/2.25 DD bailer t/11,492' WLM,tag wk tool. POOH, bailer 3/4 full sand composition material. RIH w/5.5 LIB,t/11,492',tagged liner top and wk tool. POOH. Found no side deviation marks on LIB. R/D wireline. P/U BHA #15- 6" tapered mill, 6" string mill, bit sub, bumper jars,oil jars, X/O, 6-4.5" drill collars,accel.jars,X/o to 3.5" workstring.TIH w/3.5" PH-6 workstring to 11,465', check up down wts. 174Kup 124K down. R/U power swivel. M/U jt# 363, C/O from 11,479' reverse circulating, unable to make hole. Mix up Pipe Lube change over to Conventional, Circ down to 11,487',very sticky, pull up hole to 11,465'CBU. Continue C/O to 11,516' mixing 5 gal. of pipe lub. every 15min. Fluid wt. in 9.0#, Fluid wt. out 9.1#. G/L=0. 09/14/13-Saturday Cont. C/O f/11,516' t/11,552', up wt. 167, do wt 127, circ @ 4.5 bpm, 650 psi,tq 6-7k, CBU @ 4.5 bpm. Pump OOH t/ 11,440'. Circulate &condition fluid. Clean out circ. system & mix 18% KCL,circ @ 4.5 BPM, 660psi. L/D swivel. POOH w/3.5" PH-6 workstring and Milling assy. POOH w/string mill &found string mill parted just below bottom taper leaving 2' piece of string mill and tapered mill in hole.4.21'. 09/15/13-Sunday Service unit& equipment. M/U BHA#16, 5.75" over shot loaded w/4.25" grapple, bumper jars, oil jars, 6-4.75" drill collars,X/O to 3.5" work string.TIH w/BHA#16 to TOL @ 9,652'. Check string wts. P/U wt.126K S/O wt. 115K. Continue TIH to 11,458', 363 jts. R/U power swivel. (tight @ 11,484' rotate through). Break circ 4.5BPM, @ 480psi,good returns to pit.5/O without rotating 132K, start rotating 50RPM's 3000 ft/lbs, check string wt. 144K up, 140K down when rotating. Circ down past bad spot @ 11,484'. CIH to 11,550', latch onto fish, small psi spike in pump pressure indicating fish is latched. R/D power swivel prep to POOH. POOH w/3.5" workstring and BHA#16 with parted string mill and tapered mill. Break out fish from overshot. 09/16/13- Monday Clear tools from floor. M/U 3-1/2"tj, pull wear bushing,fill stack& manifolds with fluid. Test BOP's w/3-1/2" tj as per Hilcorp&AOGCC regulations,witness waived by Jim Regg @ 8:47am on 9-16-13. Test 250 psi low/2500 psi high 5 min ea. Had failure on annular, rest of the tests were good. Clear floor to access floor panels. Pull floor panels, rotary beams, drip pan &flow nipple. C/O annular element. Pressure test New annular 250psi low 2500psi high,tested good. Remove lock down pins. Remove test plug. Close and lock blind rams. Replace flow nipple, drip pan rotary beams, &floor panels. RIH w/test plug set wear bushing. 09/17/13-Tuesday Set wear bushing. POOH w/test jt. and plug break down test jt. M/U BHA#17, 5-3/4" overshot loaded w/3 21/32", basket grapple, dress off guide, 3.69" ID 4 3/4" pump out sub.w/3.5" IF box x pin, 3.5K Fike rupture disc, 4 3/4" bumper jars, oil jars, 6-4 3/4" drill collars,X/O to 3.5" workstring.TIH w/BHA#17 to 9,633'. 304 jts. in hole get string wts. P/U Wt. 126K S/O wt 114K. P/U jt#305, reverse circ. until clean @ 4.5BPM @ 175 psi, @ 210 bbls total circ. returns clean. Continue TIH to 11,461' (363jts). R/U power swivel. P/U jt.#364, check string wts. P/U 158K S/O 132K. CIH tag tight spot @ 11,484'.Work over shot thru tight spot. CIH to 11,552' latch onto fish. Start working pipe 155K to 220K,fish not moving start jarring on fish w/max hook load of 220K, continue jarring and working tbg.while circ. @ 4.5bpm. Slack off release grapple from fish, p/u 20'take weight up t/220, pump pressure up& pack off no returns.Slack off string watching weight indicator to 160k stop.Weight indicator kept bleeding off to 0, inspect& pancake had lost oil,troubleshooting& looking for alternative. 09/18/13-Wednesday Install weight indicator. Continue working and jarring stuck pipe @ 11,520', pull up t/line max 230k,wk down no movement. Change out drill line in order to be able to pull up t/275k. •• 09/19/13-Thursday Install deadman. Install weight indicator. Adjust brakes. P/U power swivel, work pipe. Pull up t/275k,dn t/60k, R/u e- line make free point run,found freepoint candidate @ 11,401'. RIH w/shot for backoff. R/U tongs, put 7.5 left hand wraps in pipe @ 4500 tq,work tq down every 2 turns,fire shot... string turned &weight fell. R/D e-line, pull 2 jts,CBU @ 4.5 bpm,600 psi. POOH w/3.5" PH-6 workstring. EOT @ 8,000'. 09/20/13 - Friday Cont. POOH f/8000' recover accelerator jars& 3 collars, leaving 3 collars,jars, bumper sub, pump out sub, &overshot 118.97' in hole tof @ 11,401'. P/U BHA# 18, 3.5" IF bumper sub, Big bore drilling jar w/3.5" IF connections,4-4 3/4" drill collars,Jar slinger X/O to 3.5" PH-6 workstring.TIH w/153 stds to 9,648'. Check string wts. up 128K 5/O wt.110K. Hook up to reverse circ @ 9,648' -4' above TOL @ 9,652'. Pump 110bbls. @ 3bpm @ 230psi, circ hole clean. Continue TIH to top of Fish @ 11,401' +/-, eot @ 11,383' up wt 156, dn wt 122. 09/21/13 -Saturday P/U power swivel & 3.5"jt. Circulate down t/tof, circulated 1-1/2 hole vol getting back some sand,gas units high, shut down monitor well, had no flow but gas breaking out, circulated another 100bbIs w/same results.Weight up system t/9.6+, weigh up fluid in pits, circulate @ 4.5 BPM 900psi, maintain a 9.6+going down hole. Monitor at pits till 9.6+back. TIH t/tof, up wt 156, dn wt 128, rot wt 140, screw into fish &tq. While working tq down to connection power swivel spun up guide line. Un-wind power swivel &cables, work on repair& r/u of power swivel. 09/22/13-Sunday Shorten tq arms for power swivel. Install tq cable to ods crown pad eye. Maintenance &clean rig. Install tq arms to swivel r/u t/second tq line. Continue r/u swivel lines&function test. Wk stuck pipe,jar down @ 40 60k less string weight, no go,jar up pulling to 245K no-go. R/D power swivel. R/U E-line RIH W/free point tools and string shot. 09/23/13- Monday Continue free point and back off operations. Back off Drill collars @ 11,406'. POOH w/E-line & R/D E-line. CBU at b/u had gas units of 4920, cont. circulation w/10#salt water circ 4.5BPM @ 900psi Circ until 10# back in returns.Shut down pump, monitor well,no flow,well static. C/o rig hydromatic cont. circulate while waiting for packer. POOH w/5jts. M/U packer assy. RIH 120' set packer 80' below surface 60' above fish.Test packer to 1000 psi held good. POOH w/2stds. R/u & pull wear bushing. M/U &set test plug,fill stack& manifolds. Test BOP's w/3-1/2" tj as per Hilcorp &AOGCC regulations.Witness waived by Jim Regg @ 8:48am on 9-23-13. Test 250/2500 psi 5 min ea. 09/24/13-Tuesday Test BOP's w/3-1/2"tj as per Hilcorp&AOGCC regulations. Witness waived by Jim Regg @ 8:48am on 9-23-13.Test 250/2500 psi 5 min ea. Good. Pull test plug, set wear bushing, l/d test jt. P/U running tool for RTTS. TIH t/120' m/u t/RTTS, & release. POOH &L/D. TIH t/TOF @ 11,414'. P/U swivel, Reverse CBU @ 4.2 bpm 760 psi. Screw into fish & work string between 60-235 Jar. R/U e-line, RIH w/string shot and collar locator. RIH w/same to 11,525' unable to pass down farther, slack wk wstring down t/60k&fire shot, no wt change. P/U wk string t/neutral wt 155. POOH w/e-line. Jar on work string between 60-235K. Movement on fish drag up hole 90' EOT @ pull up hole to 11,409' hook up to reverse circ.String wt 154K when pulling. Start pumping 4.5BPM @ 30psi. good returns to tank. • • 09/25/13-Wednesday Cont. reverse circ. Start POOH w/string pulling wet. Mix pill &try pumping but unable to circ. R/U e-line, punch holes in tubing jt above collars. Pump slug. R/D e-line. POOH w/3.5" PH6 workstring,X/O to drill collars. L/D Jar slinger,4-4 3/4" drill collars, Big Bore drilling jar, Bumper sub, 3-4 3/4" drill collars,Jars, Bumper sub, Pump out sub, and over shot. Prep to TIH w/3.5" PH-6 mule shoe. M/U BHA#19, 3.5" Mule shoe, RIH w/10 jts. of PH-6 workstring. M/U Jars, 2-4 3/4" drill collars, continue TIH w/workstring. EOT @ 10,893'. 09/26/13-Thursday Cont.TIH t/11,400'. P/U swivel, Wash down t/11,552' @ 4bpm, 650 psi. Getting high returns of fine sand @ 11,552', sand &small gravel, recovered 2 ss bands some 1" rock& 1/4 minus gravel. CBU with continued returns of fill. Continued circulating clean while pulling out laying down 5 jts to land end of Tubing @ 11,443 ft. Pumped mix of fluids from pits to Granite Point Tank Farm ( 137 Bbls). Continued to clean pits and pit system in preparation to run Down Hole camera. Loaded and weighted up to 9.9 with 132 bbls in pit system. MIRU E-Line Unit, hooked pump up to circulate clean fluids down tbg to ensure clean before running camera. Circulated 40 Bbls of 132 to Granite Point Tank Farm to clean tbg. 09/27/13- Friday Cleaned out pit system, mixed 140 bls of 9.9 Brine water,waited for E-Line tools to arrive. Started in hole with down hole camera on E-Line. Attempted to get data on casing issues, could not get data due to clarity of fluids down hole. Attempted to clean fluids by pumping 133 Bbls of clean 9.9 water down hole, did not clear up enough for camera. Attempted again to clean up hole by pumping 148 Bbls of filtered inlet water, still had clarity issues, could not take any accurate pics of casing down hole. Pulled up 5 to 500 ft from surface and pumped 90 Bbls of 9.9#fluid to equalize welbore, continued out of hole. Pulled camera and tools out, inspected tools, laid down 2 jts of 3-1/2" PH-6 WS, left EOT @ 10,481'. RBIH with camera. Water clarity fairly clear, started getting real time data of casing problems from 11,479'- 11,520'. Casin: is severel dama:ed from 11,479'-11,489' and then a:ain from 11 518'-11 520'. Pumped 50 Bbls of 9.9 down welbore to clean away from camera, continued recovering data on casing. POOH. RDMO E-Line and Equipment. 09/28/13 -Saturday Performed scheduled rig maintenance, cleaned rig floor and rig structure. RD Power swivel and back-up generator for deck space, made platform ready for cement job. Started TOH with 3-1/2" WS, laid down 11 joints. Continued SOOH W/ 3-1/2" PH-6 WS. SOOH W/total 178 stands, laid down drill collars,jars and mule shoe.TIH w/wash pipe from derrick, and TOH laying it down. MU cement retainer. TIH W/total of 97 stands of 3-1/2 PH-6 WS. 09/29/13-Sunday Continued TIH W/Cement Retainer,set retainer @ 11,020ft,tested retainer to 2500 psi, charted for 30 mins, good. Stung out of retainer. MIRU cementers and equipment, mixed 100 sacks of cement, pumped cement 5 Bbls short of end of cement retainer stinger, stung back into retainer and displaced 75 sacks(15 Bbls)of cement below retainer. Un-stung from retainer again. SOOH W/2 stands and a single, pumped remaining 25 sacks(5 Bbls)on top of cement retainer. Reverse circulated 3 bottoms up before shutting down. Flush all cement equipment and RD. Emptied rig pits to production, loaded pits with diesel, displaced welbore with diesel, sent 746 BBIs of 9.9#salt water to production/Granite Point Tank Farm. 09/30/13- Monday SOOH W/3-1/2" PH-6 WS,total of 178 stands. Laid down cement retainer stinger. MU Wear bushing and recovered wear ring. MU Test plug on test joint, land test plug in wellhead. Loaded BOP and equipment with non-potable water,void tested BOPs and test plug.Tested BOP's with AOGCC representative (John Crisp),Annual 250 low and 2500 High, all other equipment was test and charted to 250 low and 3300 High, test was witness and approved to continue working. Test nitrogen bottles and gas detection system as well. Unloaded TCP guns and E-Line Unit. RU E-Line. MU CCL/GR, RIH and Logged from 10,900' up to 5,000'. POOH, left unit rigged up to correlate TCP guns with. 10/01/13-Tuesday MU 86 TCP Guns(2,000'),TIH on 141 stands of 3 1/2 PH-6 WS, MIRU E-Line Unit. RIH W/GR/CCL, logged from 9,000' up to 8,500, log was showing guns to be 20 ft high. POOH W/GR/CCL, laid down 12 ft pup and PU 1 single of 3-1/2"WS. MU E-Line unit. RBIH W/GR/CCL, logged from 9,000' up to 8,500'. Correlated gun depths to be spot on. POOH W/GR/CCL. 10/02/13-Wednesday Correlated to get on depth. Dropped firing rod to detonate TCP Guns.TCP guns fired. Monitored well for 30 mins with no visual signs of change, started pumping diesel down the tbg out the casing,took 28 Bbls to break circulation, circulated 825 Bbls of diesel to rig pits, had influx of gas while circulating. Shut pumps down and monitor casing pressure and tbg pressure for 30 mins, well static. SOOH W/3-1/2" WS,total of 141 stands and laid down 1 single. Laid down TCP guns, confirmed all fired. Serviced rig and equipment. MU production jewelry. TIH W/WL Re-Entry guide, 1 joint of 2-7/8" 8 RD Tbg, X-Nipple, 12 ft pup,Tri-point packer, 1 joint of 2-7/8" 8Rd tbg and first GL mandrel. 10/03/13-Thursday Racked 2-7/8" 8 RD production Tbg. MU Production WL Re-entry guide, pup, x-nipple, 1 joint of 2-7/8" 8 RD, 9-5/8" Production Packer, and GL per design.TIH W/BHA and 147 joints of tbg. EOT @ 5,471'. Well tried to flow, shut well in and attempted to circulate gas out, down tbg and out annulus. Circulated 755 Bbls of diesel, had to pump slow due to packer and RHCP body in X-nipple. Pumped diesel in rig pits to production, loaded rig pits with filtered inlet water, pumped Fl water down the tbg and out annulus to attempt to kill well, repeated a second time. Pumped a total of 519 Bbls of diesel to production in past 24 hrs, recovered from wellbore. 10/04/13- Friday HSM. Continued circulating diesel out of wellbore and displacing with filtered inlet water, circulated 800 plus Bbls of diesel out of wellbore to production, circulated a total of 1702 Bbls. Emptied pits, pumped diesel to production from pits, clean out pits and loaded with filtered inlet water, mixed KCL and oilfield salt o make 10# kill fluid. • 10/05/13-Saturday HSM. Mixed 145 Bbls of 10.4#brine water, pumped 90 Bbls down the tbg taking returns to production, bled pressure off annulus to production. Rigged pump up on tbg and pumped 45 bbls down casing, balanced the well out, dropped RHCP plug prong and loaded tbg with 33 Bbls of filtered inlet water.TIH with remaining 2-7/8" 8 RD production tbg, last GL Mandrel and Sub surface safety valve. MU Tbg hanger on landing joint, landed tbg hanger. MU pump to landing joint, pressured up to 2800 psi for 5 mins, set 9-5/8" hydraulic set packer @ 8,722'. Rigged up test pump to annulus and tested packer to 2500 psi for 30 mins.Test good. Attempted to bleed off pressure on tbg, could not get TIW valve to operate. Tried to pressure up on top of valve to equalize pressure below and above valve,started at 300 psi up to 3800, no change, shut down operation to reassess. Emptied and cleaned rig pits for rig move. 10/06/13-Sunday HSM. Hooked up high pressure pump on top of TIW, pressured up to 3000 psi,TIW valve opened. Pumped through SCSSSV up to 6000 psi before SCSSSV valve opened. Installed pump in sub below new TIW in Landing joint.Test/charted to 1500 psi for 30 mins on 2-7/8" production tbg,test good. Bled pressure off tbg, hooked pump up to casing, pressured up to 1500 psi,tested &charted for 30 mins. Bled pressure off tbg&closed SCSSSV. Pulled landing joint. Installed BPV in tbg hanger, pulled false rotary table. ND flow nipple,flow line,Annular preventer off of top of double gate BOP, removed clamp below flow cross and hung BOP's under master skid. Removed clamp on wellhead & removed riser. Cleaned wellhead surfaces. Installed wellhead. Installed wellhead clamps, installed safety valve on tree, hooked up production flow lines, loaded and tested void,tested tree to 5000 psi, test good, started rigging up Slick line. 10/07/13- Monday HSM. RU Slick line Unit,tested lubricator to 4000 psi, left 1500 psi on lubricator, opened SCSSSV. Opened swab valve on top of tree,tbg pressured showed 2000 psi. RIH W/2.5 RB down to top of prong at 8,754', engaged and POOH with Prong. RIH to top of plug body @ 8,758', engaged plug body and POOH. RD Lubricator and slick line unit. Turned well over to production. Continued rigging down pit system, shaker etc. Continue to prepare for rig move. Installed skid jacks on rig. Installed pancake jacks on master skid to move. Cleaned shakers and cleaned pits, untorqued bolts on strong backs to move rig. • • \�� 7 's THE STATE Alaska 1 and as f 4 ALAsKA GOVERNOR SEAN PARNELL \Tip 333 West Seventh Avenue pF �. N MI a ��1� Anchorage, Alaska 99501-3572 ALAS U Main: 907.279.1433 Fax: 907.276.7542 Dan Taylor Operations Engineer I qa /4 `0` f Hilcorp Alaska, LLC ! 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Granite Point Field, Tyonek Undefined Oil Pool, Hemlock Undefined Oil Pool, Granite Point 50 Sundry Number: 313-516 Dear Mr. Taylor: 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, 1 / r � Cathy P. r oerster ,, .. Chair, C mmissioner DATED this / day of October, 2013. Encl. , L ?Js STATE OF ALASKA OTS /D1 )/43 ALASKA OIL AND GAS CONSERVATION COMMISSION A.,0 fA71 LA, ,`j APPLICATION FOR SUNDRY APPROVALS I ,3 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ ?::-..e./3 Perforate New Pod❑ Repair Well El [' Change Approved Program Suspend❑ Plug Perforations I/ Perforate❑ Pull Tubing IS lime Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Complete-Gas Litt 0 2.Operator Name: 4.Current Well Class: 5.Permit to DriII Number. Hilcorp Alaska,LLC Exploratory ❑ Development M. 192-041 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20434-00• 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 76.25 Will planned perforations require a spacing exception? Yes ❑ No 0 Granite Point 50 • 9.Property Designation(Lease Number): 10.Field/Pool(s): .°1b I ti I5 ADL0018761 • Granite Point Field/Tyonek Undefined Oil Pool, 14.640, U,Jf F• 04( 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 12,163. 11,801 l 11,548 11,241* 11,548 11,241 Casing Length Size MD TVD Burst Collapse Conductor 169' 24" 169' 169' Conductor 121' 26" 289' 289' Conductor 982' 18-5/8" 982' 982' Surface 3,820' 13-3/8" 3,820' 3,803' 3,450 psi 1,950 psi Production 10,063' 9-5/8" 10,063' 9,816' 6,870 psi 4,760 psi Liner 2,445' 7" 12,086' 11,746' 14,160 psi 11,720 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic f See Schematic 2-7/8" 6.4#/N-80 11,137' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): SB-3 Hydro Set&BOT-3H Perm.Packer/ Baker Model TE-5 SSSV • 11,266'(MD)10,932'(ND)&11,386'(MD)11,086'(ND)/383'(MD)383'(ND) 12.Attachments: Description Summary of Proposal 0 , 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El , Exploratory ❑ Stratigraphic El Development G • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9/28/2013 Oil El d Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: q•Lg./3 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: S-Jf.,..,t,,ft GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and cdrrect to the best of my knowledge. Contact Dan Taylor Email dtavlort hilcorp.com Printed Name Dan Ta low/ Title Operations Engineer Signature .11 -°.-. 1141W Phone (907)777-8319 Date 9/28/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3i3- 5/(o Plug Integrity ❑ BOP Test ild Mechanical Integrity Test ❑ Location Clearance ❑ 1 Other: S OCT 1 0 2013 330 �s.,. ��° �S RB�`�I Spacing Exception Required? Yes ❑ No TAV Subsequent Form Required: / b - fl O ti APPROVED MM BY /O _/— 3 Approved by: ` i:::) COMMISSIONER THE COMMISSION Date: ORIGINAL /°.(.,3 AzlqlAs Submit Form and Form 10-403(Revised 10/2012) Approved application is valid for 12 months from the date of approval.",X0,lG��chments in Duplicate • • • • Well Prognosis Well: GP-50 Hilcory Alaska,LL) Date:09/28/2013 Well Name: GP 50 API Number: 50-733-20434-00 Current Status: SI Leg: 3 Estimated Start Date: September 28, 2013 Rig: Moncla 301 Reg.Approval Req'd? Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 192-041 First Call Engineer: Dan Taylor (907) 777-8319 (0) (907) 947-8051 (M) Second Call Engineer: Reid Edwards (907) 777-8421 (0) AFE Number: 1322195 Current Bottom Hole Pressure: -4,229 psi @ mid perf 9,825' Est. assuming naturally pressured (9,591'ND) reservoir. Maximum Expected BHP: -4,229 psi @ mid perf 9,825' (9,591' TVD) Max. Anticipated Surface -3,270 psi Based on gas filled well to mid-pert Pressure: (9,591 ft TVD)with gradient= 0.1 psi/ft Brief Well Summary The GP 50 Workover was began under Sundry 313-398 to clean out and prepare the well for a Frac job. This involved running a kill string in the well and moving off until a second well was prepared so the two wells could be fracture stimulated with the same fracture stimulation equipment spread. A surface equipment problem involving a crane was encountered which would delay the ability to lift Frac equipment onto the platform. The workover plan was then modified with Sundry 313-478 to run a gas lift completion and produce GP-50 while waiting on the crane to be repaired. While executing Sundry 313-478 bad casing was encountered and verified with a camera at 11,479- 11-489' and again at 11,518- 11,520'. The nature and location of the casing damage limited the ability to repair this casing. Therefore a plan revision is necessary to set a plug above the Hemlock formation and recomplete up hole until a plan to sidetrack this well can be devised to return the Hemlock formation. This work plan includes the setting of a cement plug above the Hemlock, moving up hole and completing the Tyonek formation from 8823- 10,827' as detailed below: Procedure: 1. Pressure test BOP to 250 psi low/3,300 psi high ( notify AOGCC 24 hours before pending BOP test to give time to witness). 2. PU RIH with a cement retainer to 11,020' (+/-) and set. 3. RIH with 3-1/2"workstring to just above retainer to 11,000' (+/-). 4. RU Baker cementing unit and mix and spot 100 sxs class g cement to end of tubing. (5. Sting into retainer and pump 75 sxs. of cement through the retainer. '6. Sting out of retainer and spot 25 sx cement on top of retainer. PU 5 stands, reverse out, WOC. 7. Pressure test cement plug and casing to 2500 psi for 30 min. 8. POH w/workstring. 9. RU TCP perforating company. PU RIH with TCP Guns spaced out to perforate the Tyonek section According to the Final Perforating Data Sheet. Estimated intervals to be: C-5 8823-8839(16') • • Well Prognosis • Well: GP-50 Hilcorp Alaska,LL, Date:09/28/2013 C-6 8931-8964(33') C-7 9178-9199(21') 9219-9292 (73') 9327-9335 (8') C-8 9645-9656(11') C-9 9722-9734(12') 9738-9742 (4') 9778-9813 (35') 10038-10048(10') 10149-10155 (6') 10185-10201 (16') 10253-10283 (30') C-10 10596-10614(18') C-11 10806-10827 (21') 10. RU E-line and RIH w/GR—CCL and correlate TCP guns on depth. Fire Guns. 11. PU Guns above the top perforation. Circulate out pert gas and SD to monitor for 1 hr. Shooting Fluid level shots to determine fluid level. 12. Once convinced the well is static, POOH with TCP guns. 13. PU RIH with gas lift completion of tail pipe, packer, GLMs, SCSSV on 2-7/8"tubing string. Space out, set plug and pressure up on tubing to set packer. 14. Pressure test back side to 1,500 psi and chart for 30 min. to insure packer set. 15. Hang off in tubing hanger. 16. Set BPV, ND BOP, NU wellhead and test. Pull BPV. 17. Turn Well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Schematic II • • Granite Point Platform Well #: GP-50 SCHEMATIC Completion Date: 7/19/92 II l'o't, 1,I4-l.;i,114 PTD: 192-041 API: 50-733-20434-00 RKB to TBG Head=43' CASING DETAIL - 1 - Size WT Grade Conn Top Btm 24" 186.5# X-42 RL4S Surf 172' z 26" N/A N/A N/A 168' 289' 26' 18-5/8" 87.5# X-56 RL4C Surf 982' 2 13-3/8" 68# K-55 BUTT Surf 3,820' 9-5/8" 47# N-80 BUTT Surf 7,550' 18-5/8" 9-5/8" 53.5# P-110 BUTT 7,550' 10,063' 7"Liner 32# P-110 BUTT 9,641' 12,086' 1 TUBING DETAIL 2-7/8" 6.4# N-80 BUTT Surf 11,439' 4. 13-3/8" JEWELRY No Depth ID OD Item D 1 43' 2.92" Tubing Hanger MB-107 13-5/8"x 3-1/2"BTC-T+B3 2 383' 2.310" 4.630" Baker Model TE-5 SSSV D 2-7/8"GLM SFO-1 R-1 valves,BK-2 Latches(4.75" 3 (Various) 2.347" OD)(11 mandrels @ 11,114';10,690'; 10,232'; 3 9,713'; 9,012'; 8,219'; 7,369'; 6,322'; 5,079'; D 3,648'; 2,122') 4 11,226' 3.250" 5.680" SB-3 Hydro Set Packer D 5 11,207' 2.210" 3.625" BOT XN Nipple Liner Hanger 6 11,379' 3.000" 5.750" Scoop head guide 9,641' 4F D 7 11,386' 3.250" 5.812" BOT 3H Permanent Packer 9-5/8" D 8 11,397' 2.313" 3.500" X-Profile Nipple 1-1/z"coil 9 11,439' 2.125" 3.380" Tubing Tail I1SallI tubing& 10 11,548' 4.625" 368'Van TCP Guns 4,> inflatable packer in hole from 11,087'to PERFORATIONS 10,498' 1 ■1 11■11 4 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Status 5 11,455' 11,503' 11,152' 11,198' 48' Open 6 �, 10. 7 11,511' 11,535' 11,206' 11,228' 24' Open I II Hemlock 11,562' 11,735' 11,254' 11,418' 173' Covered P 8 11,765' 11,888' 11,446' 11,561' 123' Covered 11/21/12-Tag 9 TOF/Fish @ - 11,548' 414,-00000 00000 Hemlock o - o° i 7"../ .. PBTD=12,060' TD=12,145' Updated by JLL 01-24-13 • • Granite Point Platform • Well #: GP-50 PROPOSED Completion Date: Future tIil.nril th-La.I.1 r PTD: 192-041 API: 50-733-20434-00 RKB to TBG Head=43' CASING DETAIL - Size WT Grade Conn Top Btm I 1 [116 24" 186.5# X-42 RL4S Surf 169' J24 26" N/A N/A N/A 168' 289' 26" 18-5/8" 87.5# X-56 RL4C Surf 982' 13-3/8" 68# K-55 BUTT Surf 3,820' D 2 9-5/8" 47# N-80 BUTT Surf 7,550' 18-5/8" 9-5/8" 53.5# P-110 BUTT 7,550' 10,063' D 3 7"Liner 32# P-110 BUTT 9,641' 12,086' TUBING DETAIL D 4 2 7/8" 6.4# L-80 EUE Surf ±8,773' 13-3/8" D 5 JEWELRY No Depth ID Item 1 ±300' SCSSV D 6 2 ±2,350' GLM 3 ±4,441' GLM 4 ±6,137' GLM 7 5 ±7,532' GLM X 8 6 ±8,674' GLM 9 7 ±8,730' Hydraulic Retrievable Packer - C-5 8 ±8,766' X Nipple 9 ±8,773' WLEG = C-6 Cement Retainer w/25 sx of class G cement above&75 10 ±11,020' below Liner Hanger 26„ - C-7 9,641' 9-5/8" 1 C-8 PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Status C-9 C-5 ±8,823' ±8,839' ±8,642' ±8,658' 16 Future C-6 ±8,931' ±8,964' ±8,745' ±8,777' 33 Future C-7 ±9,178' ±9,199' ±8,981' ±9,001' 21 Future C-7 ±9,219' ±9,292' ±9,020' ±9,089' 73 Future C-10 apt C-7 ±9,327' ±9,335' ±9,122' ±9,129' 8 Future r- } C-8 ±9,645' ±9,656' ±9,422' ±9,432' 11 Future C-9 ±9,722' ±9,734' ±9,494' ±9,506' 12 Future = C-11 C-9 ±9,738' ±9,742' ±9,509' ±9,513' 4 Future S3+ C-9 ±9,778' ±9,813' ±9,547' ±9,580' 35 Future ' Z C-9 ±10,038' ±10,048' ±9,793' ±9,802' 10 Future ...r 10 C-9 ±10,149' ±10,155' ±9,899' ±9,905' 6 Future 11/21/12-Tag - . ?5.--5X. C-9 ±10,185' ±10,201' ±9,933' ±9,949' 16 Future TOF/Fish @ /. ±10,283' ±9,999' ±10,02$' 30 Futu re 11,548' C-9 ±10,253' C-10 ±10,596' ±10,614' ±10,327' ±10,345' 18 Future -1 1- = Hemlock C-11 ±10,806' ±10,827' ±10,529' ±10,549' 21 Future 11,455' 11,503' 11,152' 11,198' 48' isolated 0"CT'0 Hemlock 11,511' 11,535' 11,206' 11,228' 24' Isolated O O 11,562' 11,735' 11,254' 11,418' 173' Isolated 7 G Iii 11,765' 11,888' 11,446' 11,561' 123' isolated PBTD=12,060' TD=12,145' Updated by JLL 09/30/13 • • • Granite Point Platform GP-50 Current 07/24/2013 Hilrnrp:\larku.ILIA. Granite Point Tubing hanger,Vetco, GP-50 MB-107,13 5/8 X 3 t4 IBT lift 24 X 185/8 X 133/8 X 95/8 andsusp,w/3"typeHBPV X 2 7/8 profile,w/Flex neck and'A control line nipple BHTA,Bowen,3 1/8 5M FE X 3"Bowen union I III a in milmit nr—` ��,, Valve,Swab,WKM-M, ,O�1 3 1/8 SM FE,HWO,OD trim -' ®®® Sis 1st Valve,wing,SSV,WKM-M, 3 1/8 5M FE,w/1305 open L i\\ - O I Valve,Master,WKM-M, 0 3 1/8 5M FE,HWO,DD trim ri.•0. o ©00 ur�uI '' - Adapter,SS-137 Grayloc X 3 1/8 5M stdd top,prepped lilf�! 0 for Flex neck hanger and S Multibowl,MB-107, 1 control line exit X20-GR192 Grayloc bottom X SS 137(13 5/8 5M)Grayloc .isEli ry II. top w/ _�� , 4-2 1/16 5M 550 #r'1111%.-.ill I drat _ 4 SF, a141 _ 1■f• i ME IM1 =INS keel_∎_C, it �" _ ._•F∎•�u1�, i=.11 1∎1110. - All wellhead valves -,;AM r �I �V 2 1/16 5M VG-100 Casing head,CWC-LT,18 S/8 - p• SOW bottom x X20-GR192 �- `— Grayloc top,arranged for wi Regan starting head, —•- �� 2-2' LPO _ - IP z' '<f[ lMf__ .,..."1- __IU."1`y�,-l. 1 ' Starting Head,Regan,24" LT� . `�J housing for 18 5/8 casing (- hanger 1 111 II 18 5/8" 13 3/8" 9 5/8" 2 7/8" • Granite Point Platform Rental BOP 03/11/2013 turnip.thiska.*JA. Granite Point Platform 2013 Workovers BOP Drawing(Moncla) III ii iii iii'.i i 4.54' Hydril iii 111111 $ii1i I I III ID yyyy y�///111 III I I 4.67 — '4. C OD_ 2 7/8-5 variables _ ,v t All 13 5 8 5000 — Blind [Ii IW O iii IMO n11I1'I 'I I1 s Fl i� c C 0 2 1/16 5M Choke and Kill 2.00' ( �'�rith valves 11111. III ill 2.00 21.7' Drill deck 19.75 Riser 13 5/8 5M FE X 13 5/8 5M #13 API hub Top of wellhead @ 19.75'below deck • • Schwartz, Guy L (DOA) From: Ted Kramer <tkramer @hilcorp.com> Sent: Saturday, September 28, 2013 6:56 PM To: Schwartz, Guy L(DOA) Cc: Bettis, Patricia K(DOA); Dan Marlowe;Juanita Lovett; Daniel Taylor Subject: Re: GP-50 uphole pecomplete proposed perf depths(PTD 192-041) 113/3-576, — - Thanks Guy. Ted Kramer Sent from my iPhone On Sep 28, 2013, at 5:00 PM, "Schwartz, Guy L(DOA)" <guy.Schwartz@ alaska.gov<mailto:guy.schwartz@alaska.goy» wrote: Ted, Verbal approval granted to complete well in Tyonek zone as proposed and cement off existing Hemlock perforations . Guy Schwartz AOGCC C4„ S an-&? 3/3- 3� Sent from my iPhone On Sep 28, 2013, at 12:23 PM, "Ted Kramer" <tkramer@ hilcorp.com<mailto:tkramer@hilcorp.com>>wrote: Guy, Here is the draft of the Sundry. The official will be sent over first thing Monday morning. Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 From: Schwartz, Guy L(DOA) [ = ilto: uy.schwartz @alaska. , ] Sent: Friday,September 27, 2013 10:25 PM To:Ted Kramer Cc: Bettis, Patricia K(DOA) Subject: Re: GP-50 uphole pecomplete proposed perf depths (PTD 192-041) Ted, No spacing exception needed . Get me a draft of the sundry by email and I can get a verbal approved for the whole well completion . 1 • • • Guy Sent from my iPhone On Sep 27,2013,at 4:19 PM, "Schwartz,Guy L(DOA)" <guy.Schwartz(talaska.gov<mailto:guy,schwartz( ?alaska.gov» wrote: Ted, No problem with setting retainer and squeezing off Hemlock perfs. We will need a new sundry(change approved program/plug perforations)to approve the new perf intervals,capture the cement retainer and plugging off perforations. We will do our best to approve the perforations in a timely manner. You have verbal approval to squeeze off Hemlock and run TCP guns with understanding that you may have to wait for a spacing exemption if needed before actually perforating the zones. Keep me posted on what you find with the video. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From:Ted Kramer [mailto:tkramer a hilcorp.com] Sent: Friday,September 27,2013 3:47 PM To:Schwartz,Guy L(DOA) Subject:GP-50 uphole pecomplete proposed perf depths Guy, Currently we have the workstring setting above the damaged area with a camera inside of it. We will pump filtered inlet water to get it to clean up so we can get a look at the damage. Will know more tomorrow. If it comes to this,we would set a cement retainer above the damaged casing,squeeze cement through and above to isolate the hemlock. Then move up hole to the Tyonek section below. Here are the proposed up hole perf intervals in GP 50. The production packer will be 50 feet above the top pert. We believe no spacing exception is necessary as covered by Conservation Order number 76.25. The proposed perf depths are as follows(314'total): C-5 8823-8839(16') C-6 8931-8964(33') C-7 9178-9199(21') 9219-9292 (73') 9327-9335(8') 2 • • • C-8 9645-9656(11') C-9 9722-9734(12') 9738-9742(4') 9778-9813(35') 10038-10048(10') 10149-10155(6') 10185-10201(16') 10253-10283(30') C-10 10596-10614(18') C-11 10806-10827(21') Let me know what you require to do this and I will work on it this weekend. Ted Kramer <Tyonelk Re-compl.pdf> 3 • OF Tit, w' s� THE STATE Alaska Oil and Gas -�'�� ' °f � sKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue ALAS- Anchorage, Alaska 99501-3572 Main: 90 92079.3433 Fax: 907.276.7542 Dan Taylor 4v 11 l' Operations Engineer // �� t Hilcorp Alaska, LLC j 9 a-0 `T 0 / 3800 Centerpoint Drive, Suite 100 ,Anchorage, AK 99503 Re: Granite Point Field, Hemlock Undefined Oil Pool, Granite Point 50 Sundry Number: 313-478 Dear Mr. Taylor: 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, Daniel T. Seamount, Jr. Commissioner DATED this `t day of September, 2013. Encl. • • ok ,� RECEIVED STATE OF ALASKA a��\ ,EP 0 4 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAG 25.280 / 1.Type of Request: Abandon Cl Plug for Redrill❑ Perforate New Pod CI Repair Well CI Change Approved Program al./ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing p. Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Complete -pi --. �,..,Li;f 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drift Number. Hilcorp Alaska,LLC Exploratory ❑ Development El , 192-041 - PIA- 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. cc.,p•r 3 Anchorage,AK 99503 50-733-20434-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? NIA Will planned perforations require a spacing exception? Yes ❑ No ❑ Granite Point 50 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018761 - Granite Point Field/Hemlock Undefined Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12,163 • 11,801 . '11,548 • 11,241 11,548 11,241 Casing Length Size MD ND Burst Collapse Conductor 169' 24" 169' 169' Conductor 121' 26" 289' 289' Conductor 982' 18-5/8" 982' 982' Surface 3,820' 13-3/8" 3,820' 3,803' 3,450 psi 1,950 psi Production 10,063' 9-5/8" 10,063' 9,816' 6,870 psi 4,760 psi Liner 2,445' 7" 12,086' 11,746' 14,160 psi 11,720 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic • See Schematic 2-7/8" 6.4#/N-80 11,137' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): , SB-3 Hydro Set&BOT-3H Perm.Packer/ Baker Model TE-5 SSSV 11,266'(MD)10,932'(TVD)&11,386'(MD)11,086'(ND)/383'(MD)383'(ND) 12.Attachments: Description Summary of Proposal p • 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 6 • Exploratory ❑ Stratigraphic❑ Development 0` Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/8/2013 Commencing Operations: Oil GI " Gas Cl WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtaylor @hilcorp.com Printed Name yyDan Taylor /� � �Title Operations Engineer Signature V/A.. �/r D Phone (907)219 Date 9/3/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Ltd" Mechanical Integrity Test ❑ Location Clearance ❑ Other: t4�s��f5G Ed C /c5 (---- RBL ` OCT 1 0 2 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /6 —LiOct APPROVED BY �+ Approved by: 'V COMMISSIONER THE COMMISSION Date: ` ti - / fro /3 Ae- T'0 ' �� D G 44 Suborn Form and � Form 10-403(Revised 70/2012) Approved ,"•f6"�C,• 1 v 1 o the fr:m the date of approval. Attachments in Duplicate :�� • • Well Prognosis Well: GP-50 }Blear')Alaska,LL Date:09/03/13 Well Name: GP 50 API Number: 50-733-20434-00 Current Status: SI Leg: 3 Estimated Start Date: September 8, 2013 Rig: N/A Reg.Approval Req'd? Moncla Rig 301 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 192-041 First Call Engineer: Dan Taylor (907) 777-8319 (0) (907)947-8051 (M) Second Call Engineer: Reid Edwards (907) 777-8421 (0) AFE Number: 1322195 Current Bottom Hole Pressure: -5,290 psi @ 10,180' ND Based on pressure build up data (2010). Maximum Expected BHP: -5,290 psi @ 10,180' ND Max.Allowable Surface - 1,136 psi Based on gas filled well to mid-pert Pressure: (11,357 ft)with gradient= 0.1 psi/ft Brief Well Summary GP-50 was drilled and completed as a gas lifted horizontal oil well in the Hemlock sand in July 1992. The well was SI in December 2012 after a CT packer failed to release and the fish was left in hole choking off production. This work includes the running of a tail pipe, packer, gas lift completion, and SCSSV directly following the completion of Sundry 313-398. Prior to this work beginning GP-50 will have an unobstructed well bore with open perfs. Procedure: 1. Load pits with filtered inlet water. 2. Pressure test BOP to 250 psi low/2,500 psi high (Notify AOGCC 24 hrs. before pending BOPE test). 1. Pick up and make up production string, seal assembly, anchor latch, gas lift mandrels, SCSSV, and capillary string. a. Run in hole spacing out 2. Land new hangar. a. Pressure test to verify seals 1,500psi for 10min and chag. 3. Set back pressure valve. �-�- -72:5 /CO 0/a SI-7/ 3 6 ■. 4. Nipple down BOP and install tree. 5. Remove back pressure valve. 6. Turn well over to platform production. 4./0-a Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Schematic . fit • • Granite Point Platform Well #: GP-50 SCHEMATIC Completion Date: 7/19/92 IliIvory, 1h„{,a.I.I.c PTD: 192-041 API: 50-733-20434-00 RKB to TBG Head=43' CASING DETAIL Size WT Grade Conn Top BM 24" 186.5# X-42 RL4S Surf 172' 24 26" N N/A ' ' 26" 18-5/8" 87.5/A# X-56 N/A RL4C Su168rf 982289' - 2 13-3/8" 68# K-55 BUTT Surf 3,820' i 9-5/8" 47# N-80 BUTT Surf 7,550' 18-5/8" 9-5/8" 53.5# P-110 BUTT 7,550' 10,063' 7"Liner 32# P-110 BUTT 9,641' 12,086' TUBING DETAIL L 2-7/8" 6.4# N-80 BUTT Surf 11,439' 13-3/8" D JEWELRY No Depth ID OD Item D 1 43' 2.92" Tubing Hanger MB-107 13-5/8"x 3-1/2"BTC-T+B3 2 383' 2.310" 4.630" Baker Model TE-5 SSSV D 2-7/8"GLM SFO-1 R-1 valves,BK-2 Latches(4.75" 3 (Various) 2.347" OD)(11 mandrels @ 11,114';10,690'; 10,232'; aD }3 9,713'; 9,012'; 8,219'; 7,369'; 6,322'; 5,079'; 3,648'; 2,122') 4 11,226' 3.250" 5.680" SB-3 Hydro Set Packer D 5 11,207' 2.210" 3.625" BOT XN Nipple Liner Hanger 6 11,379' 3.000" 5.750" Scoop head guide 9,641' S D ,.; 9-5/8° 7 11,386' 3.250" 5.812" BOT-3H Permanent Packer 1 8 11,397' 2.313" 3.500" X-Profile Nipple 1-1/2"Coil 9 11,439' 2.125" 3.380" Tubing Tail /'1 tubing& y inflatable packer in hole from I 11,087'to PERFORATIONS 10,498' .:"" 4 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Status 5 11,455' 11,503' 11,152' 11,198' 48' Open 6 7 11,511' 11,535' 11,206' 11,228' 24' Open I =I II Hemlock 11,562' 11,735' 11,254' 11,418' 173' Covered 8 11,765' 11,888' 11,446' 11,561' 123' Covered 11/21/12-Tag 9 TOF/Fish @ 11,548' y'°'£,a-?. ' F 1 1,i ^+ Hemlock - iE.I.:: 1 1,s, 7„ PBTD=12,060' TD=12,145' Updated by JLL 01-24-13 ` • • Granite Point Platform Well #: GP-50 PROPOSED Completion Date: 7/19/92 1Iil,,urII ‘111.1,:4,1 I( PTD: 192-041 IL API: 50-733-20434-00 RKB to TBG Head=43' CASING DETAIL Size WT Grade Conn Top Btm 24" 186.5# X-42 RL4S Surf 169' 1 26" N/A N/A N/A 168' 289' 26)24"1 18 5/8" 87.5# X-56 RL4C Surf 982' 13 3/8" 68# K-55 BUTT Surf 3,820' D-1423'2 9-5/8" 47# N-80 BUTT Surf 7,550' 18-5/8" 9-5/8" 53.5# P-110 BUTT 7,550' 10,063' I D 3 7"Liner 32# P-110 BUTT 9,641' 12,086' D 4 TUBING DETAIL 3 1/2" 9.3# L-80 RTS-8 Surf ±10,933' 4 1 13-3/8" D 5 JEWELRY D 6 No Depth ID Item 1 ±300' SCSSV 2 ±2,300' GLM D 7 3 ±4,132' GLM 4 ±5,570' GLM D 8 5 ±6,603' GLM 6 ±7,429' GLM 7 ±8,050' GLM D 9 8 ±8,569' GLM 9 ±9,094' GLM D 10 10 ±9,676' GLM Liner 11 ±10,255' GLM 9,641' g 12 ±10,829' GLM L D 11 ,� 13 ±10,877' Sliding Sleeve 9-5/8" 14 ±10,895' Chemical Injection Mandrel D 12 15 ±10,890' Hydraulic Retrievable Packer 16 ±10,926' X Nipple ODD 13 17 ±10,933' WLEG \fl r 14 S 15 PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Status X I 16 11,455' 11,503' 11,152' 11,198' 48' Open -_A 17 11,511' 11,535' 11,206' 11,228' 24' Open Hemlock 11,562' 11,735' 11,254' 11,418' 173' Open 11,765' 11,888' 11,446' 11,561' 123' Open Hemlock 7" -..600 \NINI. PBTD=12,060' TD=12,145' Updated by JLL 07/22/13 • III • • il Granite Point Platform GP-50 Current 07/24/2013 Hilrnrp Almkn.1.1.(. Granite Point Tubing hanger,Vetco, GP-50 MB-107,13 5/8 X 334 IBT lift 24 X 185/8 X 133/8 X 95/8 and susp,w/3'type HBPV X 2 7/8 profile,w/Flex neck and'A control line nipple BHTA,Bowen,3 1/8 5M FE X 3"Bowen union I 1111 all 1111 NMI" i nt�l1 Valve,Swab,WKM-M, 0 3 1/8 5M FE,HWO,DD trim =^0'0\.. 0' O ) x Valve,wing,SSV,WKM-M, 3 1/8 5M FE,w/1305 oper li ,. L Valve,Master,WKM-M, ® F. 3 1/8 5M FE,HWO,DD trim _ -/ it ui n1 Adapter,SS-137 Grayloc X m-0 3 1/8 SM stdd top,prepped • �, for Flex neck hanger and e Multibowl,MB-107, 3 � • control line exit X20-GR192 Grayloc bottom X SS 137(13 5/8 5M)Grayloc •a I IL.Lii*,_.. top / �� FF �` 4-2 1/16 SM SSO 9 � ille� �=l�t- p - ' gal 1 ' 1" '•� �1�h �` _ ii 1. t ��. 7 IA All wellhead valves v.i�.mop� _mik.e∎opts =moo. - ' �' 2 1/16 5M VG-100 is t� ,■L tx 111-(x) .--. ' Casing head,CWC-IT,18 5/8 0 r.�� SOW bottom x X20-GR192 0 ,= _ • Grayloc top,arranged for Regan starting head, - �- 2-2' LPO _ ' f . .. „= i, oi ., phi«, C � IONS v it Starting Head,Regan,24" LT - E J housing for 18 5/8 casing hanger v`'J 1 1118 5/8" 13 3/8" 9 5/8" 2 7/8" • • Granite Point Platform Rental BOP 03/11/2013 Ilihvirp ala4.i.1.1.t, Granite Point Platform 2013 Workovers BOP Drawing(Moncla) 4.54' Hydril It! '.11 4.67' — 2 7/8-5 variables — 1111 13!58-5000 — Blind it fil ullhtli !I li! 200 r Q ;l 1 2 1/16 5M Choke and Kill + , I valves nP iit I ul • MIME III lilt I 2.00 21. Drill deck UOi 18 19.75' Riser 13 5/8 5M FE X 13 5/8 5M #13 API hub Top of wellhead @ 19.75'below deck . • • Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Friday, September 06,2013 12:51 PM To: 'Daniel Taylor' Subject: RE:GP-50, PTD:192-041, Sundry:313-398 Dan, mentioned in our phone call you have You have verbal approve to change completion to a Gas lift design. As you e p Y pp g p g Y already submitted a sundry for this change in the approved sundry (313-398) Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Daniel Taylor[rnailta_dtaylor hilcorp,comj Sent: Friday, September 06, 2013 12:01 PM To: Schwartz, Guy L(DOA) Subject: RE: GP-50, PTD: 192-041, Sundry: 313-398 Guy, I would like approval to run a gas lift completion in GP-50 instead of a kill string. Please see the attached proposed completion diagram.Thank you. Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Daniel Taylor Sent: Friday, September 06, 2013 11:35 AM To: guy_,schwartr aleaska,gov Subject: GP-50, PTD: 192-041, Sundry: 313-398 Guy, The Link Belt crane on the west side of Granite Point Platform is down and the turnaround time on the repairs is upwards of 10 weeks. For this reason we would like to change the completion plan on GP-50. I have submitted a request for Sundry approval to run a gas lift completion without performing any fracture stimulation as was initially planned. I do not currently have any need to run an expandable liner or kill string in GP-50 as was initially proposed in Sundry: 313-398 as this was for the fracture program. Please let me know what else you may need in order for us to move forward. Thank you. 1 • • Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8319 C: 907-947-8051 2 0 , .. 11 • • Granite Point Platform $ Well #: GP-50 PROPOSED Completion Date: 7/19/92 Uut...0:%iu,ka.+.i.c PTD: 192-041 API: 50-733-20434-00 RKB to TBG Head=43' CASING DETAIL Size W3 Grade Conn Top Btm 24" 186.5# X-42 RL4S Surf 169' - 1 j24" 26" N/A N/A N/A 168' 289' z6" 18-5/8" 87.5# X-56 RL4C Surf 982' 13 3/8" 68# K-55 BUTT Surf 3,820' D 2 9 5/8" 47# N-80 BUTT Surf 7,550' 18-5/8" 9-5/8" 53.5# P-110 BUTT 7,550' 10,063' I D 3 7"Liner 32# P-110 BUTT 9,641' 12,086' TUBING DETA= D 4 3 1/2" 9.3# L-80 RTS-8 L ., 13-3/8" D 5 JEWELRY D 6 No Depth ID Item 1 ±300 SCSSV 2 ',300 GLM D 7 3 ±4,132 GLM 4 ±5,57( GLM D 8 5 ±6,603, GLM 6 ±7,429' GLM 7 -8,050' GLM D 9 8 __8,569 GLM 9 ±9,094 GLM 10 ±9,676' GLM D 10 Liner Hanger 11 ±10,255' GLM 9,641' 12 ±10,829' GLM Ati D 11 13 0,877' Sliding Sleeve 9-5/8" 14 ±10,895' Chemical Injection Mandrel D 12 15 ±10,890' Hydraulic Retrievable Packer D no 13 16 10,926' X Nipple 17 ±10,933' WLEG \E., ' 14 15 PERFORATIONS lone Top(MD) Btm(MD) Top(TVD) Btm(TVD) x 16 11,455' 11,503' 11,152' 11,198' 48' Open L._ N 17 11,511' 11,535' 11,206' 11,228' 24' Open Hemlock 11,562' 11,735' 11,254' 11,418' 173' Open 11,765' 11,888' 11,446' 11,561' 123' Open Hemlock PBTD=12,060' TD=12,145' Updated by JLL 07/22/13 RECEIVED STATE OF ALASKA . ALA OIL AND GAS CONSERVATION COMMON JAN 2 4 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other G Coil Tubing, Clean Out Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extension 0 Change Approved Program ❑ Operat. Shutdown0 Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development G Exploratory ❑ 192 -041 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 50-733-20434-00 7. Property Designation (Lease Number): 8. Well Name and Number: , — ADL0018761 Granite Point 50 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Granite Point Field / Hemlock Undef Oil 11. Present Well Condition Summary: Total Depth measured 12,145 feet Plugs measured 11,548 (fill) feet true vertical 11,801 feet Junk measured 11,241 feet Effective Depth measured 11,548 feet Packer measured 11,226 & 11,386 feet true vertical 11,241 feet true vertical 10,932 & 11,086 feet Casing Length Size MD TVD Burst Collapse Conductor 172' 24" 172' 172' Conductor 121' 26" 289' 289' Conductor 982' 18- 5/8" 982' 982' Surface 3,820' 13 -3/8" 3,820' 3,803' 3,450 psi 1,950 psi Production 10,063' 9 -5/8" 10,063' 9,816' 6,870 psi 4,760 psi Liner 2,445' 7" 12,086' 11,746' 14,160 psi 11,720 psi Perforation depth Measured depth See Attached Schematic WI fl R 1 8 a013, HED " t True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.4# / N -80 11,439' MD 11,137' TVD SB - 3 Hydro Set Packer 11,266' (MD) 10,932' (TVD) Packers and SSSV (type, measured and true vertical depth) BOT - 3H Perm Pkr; N/A 11,386' (MD) 11,086' (TVD) Baker Model T SSSV 383' (MD) 383' (TVD) 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: 20 100 100 200 80 Subsequent to operation: 40 150 100 800 80 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil — El Gas 0 WDSPL0 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 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: 312 -439 Contact Ted Kramer Email tkramer @hilcor•.com Printed Name �i Ted Kramer Title Operations Engineer Signature �. '> 4 " " ----..___ Phone 907 - 777 -8420 Date 1/24/2013 RSDMS JAN 28 2-0132 l- /3 Form 10 -404 Revised 10/2012 Submit Original Only • • Granite Point Platform Well #: GP -50 SCHEMATIC Completion Date: 7/19/92 sill-n '1hinka. PTD: 192 -041 API: 50- 733 - 20434 -00 RKB to TBG Head = 43' CASING DETAIL Size WT Grade Conn Top Btm 1 24" 186.5# X -42 R L4S Surf 172' 124'4 26" N/A N/A N/A 168' 289' 26- 18 5/8" 87.5# X -56 RL4C Surf 982' - 2 13 -3/8" 68# K -55 BUTT Surf 3,820' 9 -5/8" 47# N -80 BUTT Surf 7,550' 18 -5/8" 9 -5/8" 53.5# P -110 BUTT 7,550' 10,063' 7" Liner 32# P -110 BUTT 9,641' 12,086' TUBING DETAIL 2 -7/8" 6.4# N -80 BUTT Surf 11,439' L I 13 -3/8" D JEWELRY No Depth ID OD Item D 1 43' 2.92" Tubing Hanger MB -107 13 - 5/8" x 3 -1/2" BTC - T +B3 2 383' 2.310" 4.630" Baker Model TE -5 SSSV D 2 -7/8" GLM SFO -1 R -1 valves, BK -2 Latches (4.75" OD) (11 mandrels @ 11,114'; 10,690'; 10,232'; 3 3 (Various) 2.347" 9,713'; 9,012'; 8,219'; 7,369'; 6,322'; 5,079'; D 3,648'; 2,122') 4 11,226' 3.250" 5.680" SB -3 Hydro Set Packer D 5 11,207' 2.210" 3.625" BOTXN Nipple Liner Hanger ! v 6 11,379' 3.000" 5.750" Scoop head guide 9,641' - D 7 11,386' 3.250" 5.812" BOT- 3H Permanent Packer 9-5/8" 7 D 8 11,397' 2.313" 3.500" X- Profile Nipple 1 -1 /2" Coil 9 11,439' 2.125" 3.380" Tubing Tail ,. AA I tubing & l'''' inflatable packer in hole from 11,087'to PERFORATIONS W Wei- 4 10g9a Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Status 5 11,455' 11,503' 11,152' 11,198' 48' Open 6 =, �� 7 11,511' 11,535' 11,206' 11,228' 24' Open MI Hemlock 11,562' 11,735' 11,254' 11,418' 173' Covered 8 11,765' 11,888' 11,446' 11,561' 123' Covered 11/21/12 -Tag 9 T 0F /Fish @ 11,548' � � may 00000 _Hemlock O .0 _ 0 0 O O 7" PBTD = 12,060' TD = 12,145' Updated by JLL 01 -24 -13 • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP -50 50- 733 - 20434 -00 192 -041 11/21/12 12/4/12 Daily Operations: 11/21/2012 - Wednesday Performed AOGCC BOP test. (250 psi low - 4,500 psi high). Witness waived by Jim Regg, AOGCC. RIH to 7,000' got WT n n check. RI, tagged bridge of sand at 10,654 CTM. PU got WT check. RIH wash approx. 80' and bridge gone. Continued in hole to 10,900' CTM. Made wiper run up to 10,500' CTM (heavy sand returns). RIH to 10,800' CTM. Pumped 10 bbl gel sweep. Continue in hole to EOT @11,349'. PU and make wiper run to 10,500' CTM following gel sweep up hole. Returns cleaning up, only small amount of sand seen. RIH to 11,400' CTM and made short wiper back to EOT @11,349'. Ran back in hole 11,432' CTM. PU to EOT checking weight, no weight issues seen. ST N2 at 400 scfm, lowered fluid rate to .75 bpm. Continued in hole and tagged fish (TCP guns) at 11,548' CTM. PU 50'. RIH, re- tagged at same depth. Pumped final 10 bbl gel sweep, let it clear coil and POOH. SD fluid, continue to POOH pumping N2 to purge reel. Bumped up. SIW Winterized equipment for night. SD operations for night. Well secure. 11/22/2012 - Thursday CT ND injector, leaving BOP stack on well head secured. Move equipment around for slickline to MIRU. Standing by for slickline to complete work on GP 31 -13. RU slickline on CT BOP stack. RIH with 2.30" gauge ring. SL tagged #10 GLM at 10,630' SLM. PU RIH and cleared. Tagged XN nipple at 11,207' SLM. POOH. Bumped up, shut in well, bled lubricator. RD. Well Secure. 11/23/2012 - Friday Flow well until coil tubing operations start back up. Waiting on treatment fluids to AOL. 11/24/2012 - Saturday No activity to report. 11/25/2012 - Sunday NU BOP stack on wellhead. Install CT packer BHA. NU injector on BOP stack. AOGCC BOP test performed. Witness waived by Jim Regg, AOGCC. 250 psi low test/4,500 psi high test. OOW, RIH with CT packer BHA. Set packer at 11,187' CTM. Mix 330 gal. PA033 and 550 gal. PA072 in batch mixer. Finished filling tank with xylene. ST pumping treatment blend out of batch mixer. Able to establish a 1.0 bpm injection rate at 2,000 psi. Pressure decreased to 1,800 psi. Increased rate to 1.4 bpm at 3,000 psi. Pumped mix in batch mixer, 5,000 gal xylene, a 25 bbl diesel flush followed by H2O to flush reel. Completed treatment, tried to release packer and would not release. Rubber packer seals not correct for xylene mixture and will not retract. Tried multiple times to get packer to unseat with no success. Set down up to 10K numerous times and PU to max coil pull. Was able to slide packer up hole approx. 10'. Mixed a 10 bbl FR slug to attempt to slick up hole to aid in the packer sliding up hole. Still no success. During this time choke SI and up to 800 psi. Opened up and flowed well making gas and oil. Talked to town, decision made to disconnect and try possibly using jars and accelerator to break packer free. Weatherford tools did not have proper ball to disconnect with on location. Had circ. sub ball and dropped it thinking it was a disconnect ball. Saw pressure spike and fell off. Tried to POOH, still appeared stuck but started moving when max pull was used. Pulled packer 100' up hole and stopped. Traction on injector had to be set high to eliminate slippage of pipe and was marking pipe. Operation SD. Blew coil dry and winterized all support equipment. Schlumberger has man on night watch to ensure CT is secure in well. Chopper dispatched to bring thru tubing tools from Weatherford. Choke SI for night. • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP -50 50- 733 - 20434 -00 192 -041 11/21/12 12/4/12 Daily Operations: 11/26/2012 - Monday Chopper AOL with package from Weatherford (multiple size balls to operated tools) .75" (3/4 ") is suppose to be the proper disconnect ball per Weatherford management. Dropped ball at 11,087' CTM and seated. Pressured up to 5,900 psi but did not shear. Pressured on up to 6,700 psi, still no shear. Weatherford tool hand calls management to discuss problem and they break down motor head assembly at shop to confirm 3/4" ball is correct. We have spare on location that we break down and 3/4" ball is wrong. Takes a .625" ball. While inspecting we take a .75" ball and it does not make it to the disconnect seat but seals off in lower check valve neck causing coil tubing to pressure up and no way to circulate fluid. Called Weatherford back and they confirm that assembly we are using is not a heavy duty assembly like the one they broke apart. Talked to town and came up with plans. Ran a free point program on CT program and came up with a 7,572' measurement. Confirmed that surface safety valve was open. Cleaned injector blocks to help with slippage while trying to pull pipe. Chains are slipping while only pulling 23K (10K less than the amount we could pull if working properly). Covered reel and put heat on it. SD operations for night. Turned well over to production to flow for night to try to flow any obstructions restricting CT movement. Well secure and in control by production. 11/27/2012 - Tuesday RIH, PU to 23K chains still slipping. Standing by while well flowing to see if any obstructions can be flown from tubing. Yf Conference call with town and vendors on location to plan further actions. Tarped up injector assembly and put heat to it along with heat on reel. SD operations for night. Well secure and flowing to production. 11/28/2012 - Wednesday Pulled coil tubing to 23,100 lbs and chains slipped. Traction maxed out on unit. Schlumberger management AOL. Measured OD of pipe between stuffin box and bottom of chains. 1.47" big side of tubing and 1.39" on the small (pipe ovaled). This was measured with 12K pulled in tension. Increased tension to 23K and tubing measured 1.47" on big side and 1.25" on small. Noticed with traction set heavy the tubing gripper blocks are touching each other instead of gripping pipe. Called town. Decided gripper blocks need to be milled down to get sufficent grip on tubing. Game plan to have these sent to machine shop in town and milled, return them to platform and install on injector. Fill tubing with 9.5 lbs brine with Safe LUBE. Coil operations ended for day. Well secure and going to production. 11/29/2012 - Thursday Present plan was to send blocks to town, mill off 1/8" on each block, chopper them back to platform, install so we could pull 32K as agreed yesterday. Blocks AOL and installed. Mixed 14 lbs per bbl mix to FIW (2 %) to achieve 6% KCL. Added 52 lbs per bbl sodium chloride to wt water to 9.5 lbs. Max pull can only be 25K (58% min pipe yield) which is insufficent to POOH. WSS shut down operation. Called town, to discuss pipe and equipment problems on location. Decided to continue with plans per Schlumberger limits given. Pumped 7 bbls fluid in coil to fill. Pumped 50 bbls fluid (9.55 lbs) per micro motion meter. CT WT 13,324 lbs before pumping starts. Finished pumping weighted fluid. CT WT 15,500 Ibs (string 2,200 Ibd heavier with fluid in hole). RIH stacked down to -4,000 lbs PU to 27,400 lbs. Measured pipe OD under chains on injector. 3 measurement around various areas of pipe. (1.466 ", 1.301 ", 1.280" OD). RIH, pulled again to 24,600 lbs. Chains start to slip, tubing stops. (11,067' ctm). CT operations SD for day. Well secure with column of 9.5 lbs fluid in tubing and SI. Monitoring of WH by operator with WCCS certification. • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP-50 50- 733 - 20434 -00 192 -041 11/21/12 12/4/12 Daily Operations: 11/30/2012 - Friday Need to either increase the amount to pull tubing to a acceptable amount (amount used previously to move tubing 30K) or move on to the point of cutting tubing. Decision made to cut tubing. Well SI at choke. Operator with WCCS certification on duty for night. 12/01/2012 - Saturday RU treatment line to BS of well. PU coil to 18K Ibs closed slips, pipe rams held when slacked off. Set down to 10K continued to hold. Set manual locks on BOP's. Pressure tested all treatment lines. Low PSI test 250, High test 1500 PSI tested good. Open up 9 -5/8" casing valve, bled off gas head to production through 2 -7/8" tubing. Held 400 Ibs on tubing and started pumping down 9 -5/8 ". When tubing and casing reaches 1,000 Ibs, SD give gas time to swap out with fluid and bleed off casing to gas buster. Continued this process all evening and into the night. Pumped away 688 bbls, 9 -5/8" casing full. PSI 0. Tubing holding 20 -40 psi after bleeding gas head off. SD for night. Operator with WCCS on night shift, monitoring any pressure, and bleeding off any gas migration through the night. Well SI and secure. 12/02/2012 - Sunday Lubricate and bleed casing till no gas or pressure seen. Continue to bleed off any gas on tubing. Pumped down 9 -5/8" casing with 2 -7/8" tubing choke open to production until no gas seen. Released tension off of coil by releasing injector traction to be able to strip over coil to make cut under injector just above BOP's. When traction released, BOP slips fail, dropping the remaining tension on pipe down hole 15'. After failure of slips, changed procedure of cutting pipe to cutting above injector to ensure tubing is being held by injector chains. Also have a additional annulus barrier with injector pack off system. Put together external connector for coil with xo to 1,502 to be able to RU safety barrier on tubing and XO for a -line. Tested connector to 1,000 psi by pumping through pump n sub. Tested Good on second try. SD operations for night. Well secure SI and cut CT has two safety barriers (double flapper check on BHA and 2x1 valve at surface). 12/03/2012 - Monday Assemble E -line punch and cutter BHA's. RIH with 3/4" punch tool to 10,500' wlm. Pressured coil 300 PSI, fired punch, saw pressure decrease. POOH with cutter, BU, pumped 20 bbls 9.6 Brine down CT with 2 -7/8" tubing open to return tank. CT went on vacuum giving E -line a window to let Pollard be able to force cutter down tight spot at top of CT string. RIH, made cut at 10,498'. Saw weight jump on CT string. PU CT free. SD equipment and secured location. Well secure. 12/04/2012 - Tuesday Connect cut coil tubing with connector on reel. POOH, cut tubing. Tubing OOH, well SI, purged reel. RDMO CT unit and all support equipment. Well SI and secure. Secure well turned over to production. • • � I %%j s � THE STATE Alaska Oil and Gas 0, I I '14 °fA LASKA Conservation Commission , o GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF p. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 SCANNED JAN 2 3 2013 SCANNED JAN 3 2013 Fax: 907.276.7542 Chad Helgeson Operations Engineer �,. d U Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Granite Point Field, Hemlock Undefined Oil Pool, Granite Point 50 Sundry Number: 312 -439 Dear Mr. Helgeson: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, /7)-314-/'--7`.4^----- C e y Foerster Chair DATED this day of November, 2012. Encl. RECEIVED • • STATE OF ALASKA m\ v - NOV 2 4 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Aker Casing ❑ Other: Cal Tubing Clean Out_ Q • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number Hilcorp Alaska, LLC 192 -041 Exploratory ❑ Dev Q • 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 8. API Nn�rnber. Anchorage, Alaska 99503 50- 733 - 20434-00 0 7. If perforating: 8. Wel Name and Number: What Regulation or Conservation Order governs well spacing in this pool? WA Grande Point (GP) 50 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0018761 • Granite Point Field / Hemlock Undef Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12,145 11,801 12,060 11,722 12,060' 11,596' Casing Length Size MD TVD Burst Collapse Conductor 172' 24" 172' 172' Conductor 121' 26" 289' 289' Conductor 982' 18 -5/8" 982' 982' Surface 3,820' 13 -3/8" 3,820' 3,803' 3,450 psi 1,950 psi Production 10,063 9 -5/8" 10,063' 9,816' 6,870 psi 4,760 psi Liner 2,445' 7" 12,086' 11,746' 14,160 psi 11,720 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2 -7/8" 6.4# / N -80 11,439 Packers and SSSV Type: SB -3 Hydro Set Packer Packers and SSSV MD (ft) and TVD (ft): 11,226' MD - 10,932' TVD BOT - 3H Permanent Packer; N/A 11,386' MD - 11,086' TVD; N/A 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 11/20/12 Commencing Operations: Oil Q Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson Phone: 907 - 777 -8405 Email chelaeson(5 hilcoro.com Printed Name Chad Helgeson Title Operations Engineer Signature .��` /.�j o Phone 907-777-8405 Date / 1 /.;,, t ; 1:,r c• • , `a- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n 21 n Plug Integrity ❑ BOP Test 4A Mechanical Integrity Test ❑ Location Clearance Other: IcO ps4 Boo T Spacing Exception Required? Yes ❑ No (( Subsequent Form Required: 1 d' — 0 �•,,� � �//_ APPROVED BY Approved by: '�`t'�� COMMISSIONER THE COMMISSION , i Date: it - 2,0 -- / Z ^ e a �(z proved ap v 1 0 R I ( k) p is vd fo e d e of approval. Attacb m entn Duplice R At �1 / ��v� RECEIVE D Hilcorp Alaska, LLC Post Office Box 244027 NOV 2 ®202 Anchorage, AK 99524 -4027 AOGCC 3800 Centerpoint Drive U (V= Suite 100 Anchorage, AK 99503 Phone: 907 /777 -8405 November 20, 2012 Fax: 907/777 8510 Ms. Victoria Ferguson Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 West 7 I Avenue, Suite 100 Anchorage, Alaska 99501 Re: Granite Point Platform Coiled Tubing Work November 2012 Dear Ms. Ferguson: Please find enclosed a 10 -403 request to perform a coil tubing cleanout on the Granite Point 50 well (PTD# 192 -041). This is the first of several coiled tubing projects we plan to complete this November/December on the Granite Point Platform. The work will be performed with the Schlumberger Coiled Tubing Unit (CTU). The plan for this well and the other 4 wells do not specifically require a 10 -403, but per our requirement to notify you of starting coiled tubing work in the field we are requesting approval to commence the work described below. The following gives a brief summary of the work planned for the coiled tubing unit while on the Granite Point Platform. GP -50, (PTD# 192 -041) will be the first project completed on the Platform. Attached is the proposed work plan for this well. In summary it will be tubing cleanout with coil tubing removing the sand from the tubing. GP 31 -13 (PTD# 166 -055) will be the second well the Schlumberger CTU will be used on the GPP. A patch will be removed from the tubing and coil will be used to circulate and mill scale, sand and fish junk from the well. Once the well is cleaned the, slickline will be used to shift some sleeves to optimize production and re- install the patch on the tubing. GP 42 -23 (PTD# 168 -042) will be the third well the Schlumberger CTU will work on. This well has fill covering several hundred feet of perfs in a horizontal section. Coil will circulate the sand from the horizontal section of the wellbore. GP 44 -11 (PTD# 167 -070) is a water disposal well. CTU will be used to clean out fill covering perfs and perform an injection test. It is possible an acid/xylene treatment will be performed on the formation to improve well injection performance. If the formation is stimulated, a 10 -404 will be completed. GP 11 -13 (PTD# 167 -033) is a low performer that may be treated with an HC1/Xylene mixture, to increase productivity. • • Ms. Victoria Ferguson November 20, 2012 Page 2 of 2 GP 32 -13RD (PTD# 192 -020) is a recently repaired well with parted tubing. Slickline could not get down through corkscrewed tubing. The plan is to re -enter the well and lift deeper to help unload the well. There is also 500t of fill in the casing covering perfs and it may be attempted to cleanout the casing and flow to surface if possible. Hilcorp Alaska, LLC requests the approval to move the Schlumberger CTU to the Granite Point Platform and complete this work; 24hr notice will be provided for BOP testing. Equipment has been mobilized to the Granite Point Platform. If you have any questions regarding this work, please contact me via email (chelgeson @hilcorp.com) or via phone (777 -8405 office, 229 -4824 cell). Sincerely, HILCORP ALASKA, LLC % /1 7 ,1 Chad A. Helgeson Operations Engineer Attachments: 10 -403 for GP -50 Procedure for work on Granite Point 50 Well diagrams: • GP 50 • GP 31 -13 • GP 42 -23 • GP 44 -11 • GP 11 -13 • GP 32 -13RD cc: Well File • • Well Prognosis Well: GPP G -50 Hilcorp Alaska, LLC Date: 11/16/2012 Well Name: G -50 API Number: 50- 733 - 20434 -00 Current Status: SI Leg: #3 Estimated Start Date: November 20, 2012 Rig: SLB Coiled Tubing Reg. Approval Req'd? NA Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 192 -041 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Reid Edwards (907) 777 -8421 (0) (907) 250 -5081 (M) AFE Number: 1223422 Current Bottom Hole Pressure: — 5,290 psi @ 11,100'TVD (Pressure buildup data from 2010) Maximum Expected BHP: — 5,530 psi @ 11,200' TVD Max. Allowable Surface Pressure: — 1,000 psi ./ (Based on fluid column with 1000ft of oil floating on water) Brief Well Summary Well is currently SI. When on production it was making water and little to no oil. Has a fish in bottom of well consisting of a 4 5/8" TCP Vann gun (total length of 487') Top of TCP gun is at 11596' SLM, 11573' ELM. On 8- 22 -2012 slickline ran 1 % OD sample bailer to 10525' SLM and recovered 2 cups of sand. On 9 -3 -2012 slickline ran another 1 % OD sample bailer to 10518' SLM and recovered %2 cup of sand. Bottom hole pressure is approx. 5300 PSI. Notes Regarding Wellbore Condition • Bottom hole pressure is approximately 5300 PSI Brief Procedure: 1. Safety Meeting 2. MIRU Coil equipment ensuring all equipment is RU to operational safety standards with proper warning signs and barrier tape in danger areas. 3. NU BOP stack on WH, function test BOP's 4. Stab pipe into injector head and install 1 %2 BHA internal RO connector with smooth wash nozzle BHA assembly. Install injector on BOP stack and secure properly 5. Line out pump to flow cross ensuring all valve alignment is correct for BOP test. 6. Test BOP stack, swab valves and choke manifold per AOGCC (250 -300 psi low test and 4500 psi high test) Notify 24hrs in advance of testing. 7. Fill coil and perform Shell Test on all treatment lines and equipment with FIW. (500 psi low test and 4500 psi high test) 8. Open well ( Count and record number of valve turns on treatment report) 9. Line out valves and choke for returns to FB tank, start pumping till returns are seen. 10. RIH 50 -60 FPM performing weight checks every 2500' (record RI and PU weights) 11. Once fill is tagged, (Approx.10518') perform WT check, increase fluid rate to 1.25 bpm and begin washing. Monitor returns to ensure bbl in bbl out is achieved. Use N2 as needed to achieve this. 12. Pump gel sweep every 100 ft or 20 min. whichever comes first. • • Well Prognosis Well: GPP G -50 Hilcorp Alaska, LLC Date: 11/16/2012 13. Continue to tag point, record depth pump final gel sweep, wait for sweep to clear coil 14. Pump 10 bbl spacer and POOH while pumping 1.25 bpm 15. SD fluid, start to purge reel with N2 before coming out of the hole and leave a N2 cap on the well. Ensure CT is OOH 16. SIW (count number of turns) 17. RD CT unit and all support equipment. 18. Turn well over to operations. 19. Operations bleed well off to wellclean tank to remove the N2 from the well. 20. Start gas lift to well and flow well to production. 21. Once the well is on line, RU slickline and run a PT survey to evaluate gas lift and adjust valves as necessary. Attachments: 1. As -built Schematic 0 r Granite Point Platform Well #: GP -50 SCHEMATIC Completion Date: 7/19/92 l l,l.•„r,, ' L, -I,:,. l I 1 PTD: 192 -041 API: 50- 733 - 20434 -00 RKB to TBG Head = 43' CASING DETAIL 1 Size WT Grade Conn Top Btm 24" 186.5# X -42 RL4S Surf 172' 24 , 26" N/A N/A N/A 168' 289' z6" 18 -5/8" 87.5# X -56 RL4C Surf 982' 2 13 -3/8" 68# K 55 BUTT Surf 3,820' 9 -5 /8" 47# N -80 BUTT Surf 7,550' 18 -5/8" 9 - 5/8" 53.5# P -110 BUTT 7,550' 10,063' 7" Liner 32# P -110 BUTT 9,641' 12,086' TUBING DETAIL 2 -7/8" 6.4# N -80 BUTT Surf 11,439' I 13 -3/8" JEWELRY No Depth ID OD Item D 1 43' 2.92" Tubing Hanger MB -107 13 -5/8" x 3 -1/2" BTC - T +B3 2 383' 2.310" 4.630" Baker Model TE-5 SSSV 2 -7/8" GLM SFO -1 R -1 valves, BK -2 Latches (4.75" D 3 (Various) 2.347" OD) (11 mandrels @ 11,114'; 10,690'; 10,232'; 9,713'; 9,012'; 8,219'; 7,369'; 6,322'; 5,079'; 3 3,648'; 2,122') D 4 11,226' 3.250" 5.680" SB -3 Hydro Set Packer 5 11,273' 2.210" 3.625" BOT XN Nipple 6 11,379' 3.000" 5.750" Scoop head guide Liner Hanger 9,641' 4 ►�. 7 11,386' 3.250" 5.812" BOT- 3H Permanent Packer 9 -5/8" I , 8 11,397' 2.313" 3.500" X- Profile Nipple I D 9 11,439' 2.125" 3.380" Tubing Tail 10 11,596' 4 -5/8" TCP Vann Gun/ Length =487', Top = 11,596' D SLM & 11,573' ELM I ► -� ►.t jira 5 6/18/10: Could not work a 1.75" Bailer deeper than ��, � 7 8,992'. Retrieved mud -like substance. 1 PERFORATIONS D < 8 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt 9 _ 11,455' 11,503' 11,152' 11,198' 48' 11,511' 11,535' 11,206' 11,228' 24' l Hemlock 0 °O °0 = Hemlock 11,562' 11,735' 11,254' 11,418' 173' °0 10 _ 11,765' 11,888' 11,446' 11,561' 123' o°0 o 0 PBTD = 12,060' TD = 12,145' Revised by: TDF 11/16/12 • • Chevron boosts Granite Point production Company reports improved platform performance following volcano- induced shut -in; Cook Inlet operators provide unit updates to state Wesley Loy DEL 3 0 21W For Petroleum News Chevron is reporting improved performance from its Granite Point platform in Alaska's Cook Inlet following an unusual shut -in during 2009. Oil production "actually increased throughout the year" in 2010, rising from 530 barrels per day in January to 662 barrels in October, Chevron recently told the state in an update on the South Granite Point unit. The increase was the result of two major factors, Chevron said. First, the Granite Point wells continued to show improvement after being shut -in for over four months due to volcanic eruptions at nearby Mount Redoubt, on the west side of Cook Inlet, in 2009. Second, a more efficient use of gas lift helped improve well performance, Chevron said. "The Granite Point gas lift compressor was designed to lift much more fluid than the field is currently producing," Chevron told the state. "As wells have failed and production has declined over time, the compressor's output of gas lift gas has exceeded well demand. This has resulted in wells being overlifted which results in reduced fluid production." Attempts to reduce gas lift output in the past resulted in unstable compressor performance, Chevron said. The company overcame the problem by recycling excess gas through the gas lift valves in a pair of wells including GP 31 -13, which had been shut -in since 1990. "The ability to recycle as much as 4 mmcfpd of excess gas thru wells GP 31 -13 anfLeit 50 allowed the gas lift gas volumes to be reduced in the remaining producers," Chevron said. "Well GP 42 -23RD showed the greatest benefit from reduced gas lift. The gas lift volume was reduced by 50% in this well which resulted in an increase in oil production of 70 bopd or a 46% increase over production at the higher gas lift rates. In September the owners agreed to a permanent restage of the compressor to reduce overall output and eliminate the need for cycling excess gas. This project will likely take place in the second quarter of 2011." r • • Unocal, a Chevron subsidiary, operates the South Granite Point unit, in which ExxonMobil owns a share. First production from the unit was in 1967. Chevron's unit update also said the Hemlock oil reservoir is "a potential target for future development." Chevron operates most of Cook Inlet's offshore platforms. The company announced in mid - October, however, that it plans to sell its Cook Inlet assets as a package. Cook Inlet unit highlights Operators of several other Cook Inlet units recently provided updates to the state. Here are some highlights: • Pioneer Natural Resources reported completing well workover, diagnostic and testing operations at its Hansen 1A -L1 well in the Cosmopolitan unit during the period November 2009 through September 2010. The well was suspended. "Results of this work enhanced Pioneer's understanding of the reservoir and will be incorporated into future plans," Pioneer said. The Cosmopolitan unit takes in eight state leases and two federal leases in Cook Inlet offshore the west bank of the Kenai Peninsula. Pioneer has talked of a development that could peak at 8,000 barrels a day of oil production. • Marathon, in its 53rd plan of development and operations submitted Dec. 16, said it has no plans to drill new wells in its Kenai gas unit, but is contemplating other work. "Several existing wells in the field continue to be evaluated for non -rig remedial activities including the installation of velocity strings, foamer capillary strings and other de- liquefaction methods to assist with water removal, and improve gas production," Marathon said. • Chevron reported "on -going efforts to farm -out the Red prospect" in the Nikolaevsk unit on the Kenai Peninsula. • Marathon said it's working to "resolve ownership issues" related to the Spurr platform and its associated wells. "Marathon hopes that a resolution to this situation can be reached in time to facilitate the abandonment of Spurr wells in the 2012/2013 timeframe," the company said. The Spurr platform hasn't produced oil since 1992 and is slated for decommissioning. The question of who will pay the decommissioning costs has been the subject of a court fight. ') ) ~ FRANK H. MURKOWSKI, GOVERNOR AI,ASKA OIL AND GAS CONSERVATION COMMISSION 333 W. ? AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 1,2004 Dwight Johnson Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 RE: Corrected No-Flow Verifications Well GP-50, PTD 192-041 Well GP-51, PTD 192-072 Dear Mr. Johnson: On May 12, 2004, the Alaska Oil and Gas Conservation Commission ("AOGCC") approved the removal of subsurface safety valves from service in Granite Point Platform Wells GP-50 and GP-51. No flow tests witnessed by a Commission inspector demonstrated that there was no flow of gas or liquid to surface during the tests, and serve as the basis for these approvals. The Commission's May 12 letter incorrectly references Granite Point State 18742 Wells 50 and 51 (Anna Platform wells). Please replace that authorization with this corrected letter. You should retain a copy of this letter on the Granite Point platform. Sincerely, s~ 'B 1< f4? James B. Regg l Petroleum Inspection Supervisor cc: Bob Fleckenstein SCANNED NO\! n 2 2004 ) ') MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~i H-\ -04" DATE: May 3,2004 P. I. Supervisor I t Corrected 11-1-04 FROM: Chuck Scheve, Petroleum Inspector SUBJECT: No Flow Granite Point Platform 50 192-041 51 192-072 Monday, May 3, 2004: I traveled to Unocal's Granite Point Platform and witnessed no- flow tests on wells 50 and 51 . I arrived on location and found all both wells opened to atmosphere with no flow of gas or fluid evident. Both wells were shut in and observed for several hours with a minimal pressure build up,<30 psi, observed. I recommend Wells 50 and 51 on the Granite Point Platform be approved no flow status for the purpose of removing the Sub Surface Safety Valve. SUMMARY: Wells 50 and 51 on the Granite Point Platform meet the AOGCC requirements for no flow status. Attachments: SCANNED DEC 142004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of request Abandon ['-'] Suspend ~] Ops Shutdown E~] Perforate [--] variance [-'-] Ann. Disposal r--[ Alter Casing [~ Repair Well [--] Plug Perforations [--] Stimulate E~ Time Extension r-'] Other [] Change Approved Program [~ Pull Tubing [--] Perforate New Pool ['--] Re-enter Suspended Well 2. Operator Name: 4. Current Well Class 5. Permit to Drill Number: Union Oil Company of California 92-41 3. Address: Development [] Exploratory r'-] 6. APl Number: PO Box 196247, Anchorage, AK 99519 Statigraphic r-'] Service [--] 50-73320434 7. KB Elevation (ft): 9. Well Name and Number 109 RKB GPP-50 8. Property Designation: Granite Point Platform 10. Field/Pool(s): Granite Point/Middle Kenai 11. Present well condition summary Total depth: measured 12,145 Feet Plugs (measured) 12,060' true vertical 11,801 Feet Effective depth: measured 12,060 Feet Junk (measured) 11,596 true vertical 11,722 Feet Casing Length Size MD TVD Burst Collapse Structural 126' 24" 169 168 I Conductor 939' 18-5/8" 982 981 Surface 3,777' 13-3/8 3820 3803 1,069 psi 1,950 psi Intermediate 7,507' 9-5/8" 7550 7418 1,086 psi 4,760 psi Production 2,513 9-5/8" 10063 9816 1,710 psi 7,930 psi Liner 2,445' 7" 12086 11746 1,025 psi 10,760 psi I Perforation depth: measured 11,455-11,503'; 11,511-11,535'; 11,562-11,735'; 11,765-11,888' true vertical 11,511-11,197'; 11,205~11,228'; 11,254-11,417~; 11,445-11,560' Tubing (size, grade, and measured depth) 2-7/8", 6.4#, L-80 @ 11,439' Packers and SSSV (type and measured depth) SB-3 permanent packer @ 11,226'; Baker 3H permanet packer @ 11,356' 12. Stimulation or cement squeeze summary ~,' ,.:' "~ i'. ....... ;i "~ .~,','~' Intervals treated (measured) n/a i ~ ii~'~ ~,\,~z~ i.~"~ t '~ '~ ...... Treatment description including volumes used and final pressure ii~0V ~/[~ 6 13 Representative Daily Average Production or Injection Data~:!~::;"',?!~;~, "'~"" c .... -,,~ ¢ ........... F:;':i~':.:' , .. .... .,.. ~.~ t~, ~i~ i~,~ ~:~ L,,, '~::'.~ ;~.-. '~. OiI-BBL Gas-Mcf Water-Bbl Casing Pre~{~,r.,~,?;;~i~ubing Pressure Prior to well operation 50 181 12 657 93 Subsequent to operation 57 299 19 635 88 14. Attachments: 15. Well Class after proposed work: Daily Report of Well Operations E~ Exploratory r'~ Development [~ervice 16. Well Status after proposed work: Oil ~ Gas WAG ['-] GINJ E~ WINJ r'-] WDSLP 17. I hearby certify that the foregoing is true to the best of my knowledge. Sundry Number: Contact: Printed Name: Steve Tyler Title: Engineering Technician Signature: . Phone: 263-7649 Date: 11/04/03 Form 10-404 Revised 3~0'03 0R G NAL Submit in duplicate uNOCAL ) Granite Point Field Well # GP-50 Actual 12/8/02 289' 982' RKB to TBG Head = 43.0' 1 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 186.4 X-42 RL-4S 22.5' 43' 169' 84.5 X-56 17.755" 43' 982' 68 K-55 BTC 12.415" 43' 3820' 47 N-80 BTC 8.681" 43' 7550' 53.5 P-110 BTC 8.535" 7550' 10,063' 32 P-110 BTC-TKC 6.094" 9641' 12,086' 24" 18-5/8" 13-3/8" 9-5/8' 9-5/8" 7" Liner 3,820' Tubing: 2-7/8" 6.4 L-80 IBTC 2.441 43 11,439' (S.C.C.) (E.O.T.) 9641' 10,063' NO. 4. 9, 10. 11. 12. ,IEWELRY DETAIL Depth 'Il) Item 43 2.92 383' 2.310" (various) 2.347" 11,226' 2.441" 11,356' 2.441" 11,367' 2.312" 11,379' 2.441" 11,273' 2.21" 11.359' 2.441" 11,408' 2.441" 11,542' Vetco Grey 13.5" 5m tbg hanger 3 V2" IBTC (top/boO 2-7/8" TE-5 TRSV (flapper) (4.625" OD) 2-7/8" GLM SFO-1 R-1 valves, BK-2 Latches (4.75" OD) (11 mandrels ~ 11,114'; 10,690'; 10,232', 9713'; 9012'; 8219'; 7369'; 6322'; 5079'; 3648'; 2122') SB-3 permanent packer (threaded - no seals) Baker 3H (orig.) permanent packer w/5' mill out ext. "X" nipple (original equipment) Scoop head guide (non-sealing overshot over orig. tbg stub) Dropped 4 5/8" TCP Vann gun (total length = 487') (top of TCP gun at 11,596' SLM, 11,573' ELM) Baker 'XN' nipple E-22 Anchor Seal Assembly (original) Mechanical release (B shift tool - apparently shifted, no record) CTCO fill on 5/26/03 PBTD = 12,060' Hemlock TIE)= 12,145' Zone Hemlock Hemlock Hemlock Hemlock PERFORATION DATA Top Btm Amount 11,455 11,503 48 Open 11,511 11,535 24 Open 11,562' 11,735' 173 Open 11,765' 11,888' 123 Open Condition GP-50Schematicl 10403 revised by DED 5~20~2003 PJSM with Schlumberger Production and Drilling. Move/spot CT equipment, storage tanks and pump. NU riser, pump-in sub and BOPE onto well. MU surface lines manifold storage tanks. RU iron f/pump-in sub t/DS choke manifold t/MicroMotion Meter t/Production Header. Cut coil and thread into injector head. RU FIW line from production. Install nite cap on BOPE. Make room for N2 Tank. SDFN 5/21/2003 PJSM and SIMOPS Meeting Respot N2 tank. Fill CT w/FIW. MU Roll-on CTC. Pull test to 10k. OK. MU BHA onto CTC as follows: DCV, GLM By-pass Tool and Rotating Jet Nozzle. Remove Nite Cap. Funtion test BOPE's SI gaslift on well. Left flowline open to allow well to bleed off. Pressure test BOPE's. Stab injector head, w/additional 10' lube stick, onto BOPE Stack. Pressure test Choke Manifold, Surf Iron and BOPE Shell to 3k. OK. Pressure test surf iron between Choke and production header to 500 psi. OK. Break for lunch. Displace FIW from CT with diesel to production. Calibrate MicroMotion Meter. RIH w/CT, "dry" w/flowline open to production. Wt checks @ 1000' - 2k, @ 2000' - 4k, @ 6000' = 11.5k, @ 8600' - 22.5k and at 11,000' = 34k Up wt at 11,000' abnormally high. Close flowline open production header to rout returns through choke manifold and MicroMotion. Start pumping diesel down CT @ 1.5 bpm. PU to 10,144'. Pumped 80 bbls down CT. no returns to surface. CT and CT x Tbg annulus displace volume is 68 bbls. SD pump. Noted casing annulus pressure was gradually increasing from 398 psi shut-in pressure to 416 psi and slowly trending up. Close Return line. Pumped/inject 8 bbls to catch up to fluid in CT. Pumped another 32 bbls. No indication of well ~ressuring up or fluid at surface. Casing pressure still trending up, gradually. Total Volume pumped into well 120 bbls. POOH w/CT. BO and stand back injector head. Put nite cap on well. Secure well and CT equipment. -STf2T2-0--0-3 PJSM Move/Spot Slickline unit. Test wire. Spool-off 3000'. Test wire. OK. RU Pollard Wireline unit and lubricator on DS BOPE Stack. Pressure test to 1500 psi. OK. MU Quick Temp/Pressure gauges onto tool string. RIH w/Quick temp/pressure tool at 60 fpm to 11,450'. 30 min stop. POOH at 60 fpm making 2 min stops below and above each mandrel. POOH. Secure well. Download gauges. Send data in to be analyzed. SDFN. 512312003 Pollard Crew Up. PJSM. RU slickline. MU GLM 2-1/2" OK-6 KOT. RIH to 11,114'. Latch #11 GL Orifice. Slipped off. Worked tools. Sheared PT. POOH. No recovery. Found 1-1/4" Daniels PT sheared. Change out to 1-1/4" JDC PT. RIH w/GLM KOT. Latch GL Orifice. Jarred twice. Slipped off. Worked tools. No progress. POOH. No recovery. Had metal shavings from latch on dogs. Change out to 1-1/4" Daniels PT. RIH w/GLM KOT. Latch GL Orifice. Jarred on valve for 45 min. came loose. POOH. Recovered Valve. Break orifice valve apart. Found check valve completely wash out. MU Running tool onto OK-6 KOT w/new 1" office valve. RIH w/same. Set valve in GLM #11 @ 11,114'. POOH. RD Slickline. Send slickline crew to beach Perform MIT on Tbg RU 1/2" High pressure hose from 1170 psi gas header to GPP 50. tie-in to DS lubricator. Pressure test to 1100 psi. OK. Tbg pressure @ 600 psi. Csg Pressure @ 600 psi. Start gas into tbg. Pressure tbg to 1100 psi. Monitor pressures. Tbg @ 1100 psi. Csg @ 600 psi. Start bleeding csg to production through 1/2" line. Tbg pressure trending up due to fluid rising in wellbore. Attempting to achieve a 1000 psi differential between tbg and csg. $/24/2003 Continue bleeding csg pressure through 1/2" line. Tbg pressure @ 1350 psi csg pressure @ 450 psi. SI csg and monitor well. Tbg pressure @ 1460 psi csg pressure @ 450 psi. Continue monitoring well. Tbg pressure @ 1505 psi csg pressure @ 450 psi. MIT of Tbg good. Bleed tbg to production header pressure. Drilling Foreman left platform @ 12:00 Noon. Fluid to surface. Well flowing to production. Csg pressure @ 450 psi. 5/25/2003 Travel to Granite Point Platform, Orientation for Dowell hands Crane operator inspects both cranes, Dowell fired up equipment and prepared to pressure test equipment Simops and safety meeting with Production and Dowell crews, reviewed Simops checklist, Did walk-a-round with Production Foreman. Reviewed Pep - 2 chemical MSDS with Production, Dowell and Baker Petrolite hands Test BOP and surface equipment 250 Iow and 3000 psi high. Make up BHA Stab injector head on, fill coil with Diesel ( 20 bbls ) Body test injector head to 4000 psi Rih to 11,000' checking pick up wts every 1000' to 2000'. Pick up wt. at 11000' spiking at 42K. Displace tubing x CT anuulus with Diesel, calculated volume 31 barrels, Diesel returns at 33 bbls pumped, pumped 35 bbls total, Returns to Production well clean tank. Pull up hole to 9500' checking excess drag treng, top off Diesel tanks. Run in hole to 11410' pumping down coil at 1.4 BPM 4000 psi picking up every 200' to check drag. Up weight at 11000 after washing through area 30K pumping 34K without pumping. Up wt at 11410' 36K. Shut down pump, RIH tag fill at 11505'. Attempt to pull back up into tubing tail at 11400'. Attempt to pull back into tubing tail without success, no problems going down. Attempted with and without pumps pulled up to maximum allowed pull of 44K many times PJSM: Fill one Dowell tank with 16 bbls Pep-2, pump 10 barrels down hole at 1 BPM, slow pump to .3 BPM as chemical is exiting coil, continually working pipe between 11400' and 11450'. Stop pump and work pipe trying to get into tail on every up stroke with max pull. Start pumping at .8 BPM pulled into tail at a fast speed coming up, pulled 44K and popped into tail. Pump 12 bbls at 1.3 BPM POH pumping at 1BPM until calculated bottoms up slow pump to .3 BPM until out of hole. Break off injector head and inspect BHA, upset on coil connector shows some signs of being pulled into something Some Asphaltine film present on CT, break off BHA, cut off 100' of coil, set down injector head install night cap. Fill up Diesel tanks. NOTE: while using crane, ladder on walk-a-round entangled fuel hose from Crane pedestal to Diesel tank on the deck, causing a fitting to break and Diesel to leak, see incident report to follow. Clean up Diesel, scrub decks. Note pumped a total of 270 bbls diesel, counting coil fill up. Will carry diesel cost on tomorrws report when price per gallon information is known ~-f2-6-f2-O-O-~ Clean up diesel and scrub decks Fuel equipment and fill diesel tanks Simops meeting with Production and Pre-tour safety and day plan meeting with Dowell crew. Start up equipment, continue to fill diesel tanks New coil connector and disconnect arrives on helicopter, bevel coil connector. Make up coil connector and BHA Stab on injector head, shell test head and surface equipment to 4000 psi Open well 750 psi on tubing, bleed to well clean tank, RIH with 1.85" wash nozzle to 11400' checking up weights every 1500 after 8500'. Up weight at tail 32K. Pumping at .4 BPM Work through tail multiple times to ensure access, Wash down to 11500' and pull back into tubing tail, no problems, Wash down to 11520' and pull back into tail with no problems, repeat process at 11540' wih no problem, went back down and tagged at 11542' picked up, gained 5K additional up weight. Pull up into tail. All above work was done pumping at 1.2BPM 3300 PSI. Went back down pumping at same rate and attempted to wash through fill at 11542' without any success, took 43K pull to get free. Gained a additional 2K in up weight. Pull up into tubing tail Fill Dowell tank with another tote of PEP-2 chemical, pump down coil tubing and chase with diesel, work the coil string towards bottom as pill is exiting pipe, unable to pick up at 11535' with maximum pull, continue to spot spill When pill was clear of Coil shut down pump and shut in CT x tubing annulus trapping 300 psi, pull to maximum pull 43K, and leave in overpull, 15 minutes after pill was in place pipe pulled free, pull into tubing tail slowly without pumping. Continue to pull up hole slowly letting pill work on the bottom of hole. Pulled up hole to 10650' RIH to tubing tail at 11400' pumping at 1.3 BPM 3500 psi, pump bottoms up Attempt to inject into formation. Pump 2.5 bbls at .4 bbls a minute to 3000 psi, no breakover, pressure bled off to 2450 psi in 5 minutes, Repeat test attempting a slower pump rate, hard to keep pump running at slower rate, pumped 2.5 bbls between .2 and .5 BPM to 3000 psi. Same bleed of rate as above test. Bleed off pressure, shut in well, POH POH, set off injector head, install night cap. Clean up decks. Suspend operations $/27/2003 Arrive on platform: Simops and pre-job safety and operations meeting. Simops walk-a-round with Production foreman Pump through lines to well clean tank, test lines to 5200 psi and bleed off to well clean tank, pressure up above swab valve to 1200 psi, open swab 465 psi on tubing, annulus pressure 1120 psi, Pump down tubing at .4 to .6 BPM..5 barrels away 786 psi, 1 bbl away 1395 psi, 1.5 bbl away 1860 psi, 2 bbls away 2270 psi, 2.5 bbls away 2610 psi, 3 bbls away 2917 psi, 3.2 bbls away 3100 psi, 3.5 bbls away 3130 psi, 3.7 barrels away 3160 psi, started counting 4.5 barrel injection at this point..5 barrels away 3250 psi, 1 barrel away 3350 psi, 1.5 barrels away 3402 psi, 2 bbls away 3440 psi, 2.5 bbls away 3492 psi, 3 bbls away 3546 psi 3.5 bbls away 3572 psi, 4 bbls away 3590 psi, 4.5 bbls away 3604 psi. Shut in well. All pumping at .4 bpm after 3000 psi. Monitor well, tubing pressure bled off to 1025 psi in 2 hrs. Bleed well down to 465 psi in 3 minutes, .4 bbls back. Blow down coil with nitrogen and rig down coil equipment, transfer PEP chemical from Dowell tank to chemical tote. 572-872003- Rig down coil equipment Unload Production freight from boat and load 3 tanks on boat for transfer to Bruce Continue rig down, scrub decks Load Boat, wash deck Leave Platform 51291200;3 - Facility Orientation / PJSM - Complete SIMOPS, Flammable fluids Checklist, Review MSDS's & PPE, Review procedure Begin Rig-up & PEP2 transfer into treatment tank Continue rig-up to wellhead Tailgate safety meeting Shut of lift gas and allow well to Die Shut In Master valve, open swab and displace treating lines w 3 bbls FIW Close Swab valve and preform stepped pressure test to 5,000 psi Open Swab valve and displace treating lines w/3 bbls Diesel Close Production wing valve and open Master valve, Tubing at 556 psi, Casing at 790 psig Begin pumping Baker Petrolite PEP2 Tubing 575 psi, 0.5 bpm, 0.2 BBLS, Tubing 508 psi, 1.5 bpm, 2.5 BBLS Tubing 447 psi, 2.0 bpm, 4.2 BBLS, Tubing 179 psi, 2.0 bpm, 10.3 BBLS Tubing 22 psi, 3.7 bpm, 26.5 BBLS. Switch to Diesel Tubing 11 psi, 2.3 bpm, 0.4 BBLS, Tubing 9 psi, 3.6 bpm, 1.1 BBLS Tubing 35 psi, 5.0 bpm, 5.4 BBLS, Tubing 185 psi, 3.5 bpm, 15.1 BBLS Tubing 841 psi, 3.4 bpm, 18.5 BBLS, Tubing 2017 psi, 3.2 bpm, 21.9 BBLS Tubing 2971 psi, 2.5 bpm, 24.5 BBLS, Tubing3153 psi, 1.5 bpm, 29.1 BBLS Tubing 3437 psi, 1.2 bpm, 40.6 BBLS, Tubing 3470 psi, 1.0 bpm, 42.9 BBLS Tubing 3588 psi, 0.9 bpm, 66.5 BBLS, Tubing 3701 psi, 0.8 bpm, 68.1 BBLS Tubing 3696 psi, 0.7 bpm, 69.6 BBLS Shut Down - Tubing 3715 psi, 0.0 bpm, 73.5 BBLS, Casing 790 Total Fluids 100 bbls, 26.5 Baker Petrolite PEP2, 73.5 bbls Diesel Tubing 2531 psi Shutin Master valve, open production wing valve, flush lines w/3 bbls FIW Shut-in production wing valve & swab valve, Bleed off treatment iron. Rig Down (began over injecting well 07/15/03 at 15:40 to "dry out" tubing WELL TO REMAIN SHUT IN FOR 48 HOUR SOAK - RTP 07118/03 @ 16:00 HOURS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 ACC 25.280 1. Type of request Abandon [] Suspend [] Operation Shutdown [] Perforate [] Variance Q Annular Disposal [] Alter Casing [] Repair Well [] Plug Perforations r~ Stimulate [] Time Extension [] Other X Change Approved Program [] Pull Tubing X Perforate New Pool El Re-enter Suspended Well [] 2. Operator Name: 4. Current Well Class 5. Permit to Drill Number: Union Oil Company of California/Unocal 92-41 3. Address: Development X Exploratory [] 6. APl Number: PO Box 19-0247, Anchorage, AK 99519 Statigraphic [] Service [] 50-733-20434 7. KB Elevation (ft): 9. Well Name and Number 109 RKB Granite Point, GP-50 8. Property Designation: Steelhead Platform, Cook Inlet 10. Field/Pool(s): Trading Bay/Grayling Gas Sands Pool 11. Present well condition summary ,~ Totaldepth: measured 12,145' Feet Plugs(measured) RE,CE '/ED true vertical 11,801' Feet JUN'~,. ..~ 2003 Effective depth: measured 12,060 Feet Junk (measured) true vertical 11,723 Feet Alaska 0il. & ,"., ~ ~...~,.~,~ Co~s,, Commission Casing Length Size MD TVD Burst Collapse Structural 169' 24" 169' 168' Conductor 982' 18-5/8" 982' 981' Surface 3,820 13-3/8" 3,820 3,803' 3,980 psi 1,130 pSi Intermediate 10,063' 9-5/8" 10,063' 9,816' 7,930 psi 6,620 psi Production Liner 12,086' 7" 12,086' 11,746' 11,640 psi 10,760 psi Perforation depth: measured 11,455-11,503'; 11,511-11,535'; 11-562-11,735'; 11,765-11,888' true vertical 11,151-11,197'; 11,205-11228'; 11,254-11,417'; 11,445-11,560' RECEIVED Tubing (size, grade, and measured depth) 2-7/8" 6.4# 1-80 @ 11,439' JUN ! I 2003 Packers and SSSV (type and measured depth) SB-3 Permanent Packer; Baker 3H Permanent Packer; Alaska 0il & Gas Cons, Commissi0 12. Stimulation or cement squeeze summary Anchorage Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut in prior to operations Subsequent to operation 41 1,700 I 31 I 510 I 97 Daily Report of Well Operations: X 16. Well Status after proposed work: Oil X Gas Copies of Logs and Surveys Run WAG [] GINJ [] WlNJ [] WDSLP [] 17. I hearby certify that the foregoing is true to the best of my knowledge. Sundry Number: Contact: Printed Name: Jerry Bowen Title: Consulting Drilling Engineer Signature: ., ,~..~~ /(~'3'"z,,v",~ ,~ ~; .~ .~____~,~ Phone: 907-263-7640 Date:6/6/03 Form 10-404 Revised 2~2003 SCANNED JUN 1 ~ 2003 JUN oRiGiNAL Submit in duplicate 11/14/02: MI/RU. 11/15/02: Continue RU. RU Pump. Circ lines to tank. Install check valve. Test pump to 4,000 psi. 11/16/02: Continued series of pressure tests. Secure lines. 11/17/02: Continued pressure testing. 11/18/02: Continued pressure testing 11/19/02: Continued pressure testing. 11/20/02: NU BOPE. Bled well. Flushed production line. ND tree, clean seal, reinstall. PT to 3,000 psi. PT well to 40 psi. 11/21/02: RU choke. RU fill line. Circulate well. Bled well. Well pressure ~ 85 psi. 11/22/02: Lubricate and bled well. RU accumulator lines, circulate. Bled off well. 11/23/02: Pressure up well. 11/24/03: Continued to prep platform for Cudd Pressure Control Rig. Monitored well annulus pressure. 11/25/02: Bled off well. Continued to monitor annulus pressure. Continue to prep for Cudd Pressure Control Rig.. Set BPV. Installed riser.. Close blind rams and shut annulus. 11/26/02: Work on hold due to weather. 11/27/02; RU Cudd and function test. Bled off well. Set BPV. Continue to monitor well for annulus pressure. Continue BOP testing. 11/28/02 Continue BOP testing. Change rams in dble gate from VBR To 3 1/2", test to 250/4000 psi. Check annulus pressure. Back out lock downs & pull hanger loose. Lay down hanger + XO + PUP & Collar off the first full joint below hanger. RIH, fishing. Tag top of fish at 71' RKB. Swallow & latch fish. POOH. RD hose & swivel. RU pollard pump in sub + wire line BOPS & Lubricator on Full tubing ID Valve. RIH w/pulling tool to 108'. Pressured down tbg and annulus. RU Lubricator. & make planed slick line ruI1s. 11/29/02: Bled off well and continued to monitor annulus pressure. Fishing. Continued measuring annulus pressure. Circulate. Continued fishing. 11/30/02: Continued fishing. RD Pollard wire line unit and RU APRS Unit. RIH Logging gas lift valves. Circulate. Arm chemical cutter make up same and stab up lubricator. RIH w/2 1/8" chemical cutter count GLM'S on way in. Drop down and Cut pipe mid joint ~ 6411'. POOH Lay down Lubricator, pull on Tbg. RD APRS & RU to circulate bottoms up. 12/01/02 Continue circulating. RIH. Pull tbg. 12/02/02: PU BHA # 2. Continue circulating. Continue fishing. Circulate tubing and casing volume to production with fresh mixed 3% KCL. Pump total volume to production from Cudd tank & coil tank. Continue monitoring pressure, continue circulate. Isolate well from production bleed off annulus, open annular. Continue fishing. Reverse circulate. Reverse circulate at 3 bbl per min 600 psi. 12/03/02: Finished reverse circulating well. POOH lay down 3-1/2" drill pipe. Removed fish. RD Hawk Jaw, RU Cudd's tong pole and tubing tongs. Changed slip dies to 2-7/8". Laying down 2-7/8" tubing and Gas Lift Mandrels. POOH. RU slickline unit. 12/04/02 Finished RU slickline unit and lubricator. RIH with gauge ring to 9639' (WLM) tagged top of 7" liner. Fishing. POOH with slickline and RD Pollard Wireline. Pulled tbg. 12/05/02: Continued RIH with 2-7/8" tubing and gas lift completion. Circulate well. RU slickline and lubricator. RU Cudd's pump to pressure up on casing. PU on tubing to 3500 psi with BOP test pump and set Baker 7" 32# SB-3 Hydro Set Packer at 11226.16'. Continued to monitor pressure. 12/06/02: POOH w/slickline. LD lubricator. Set BPV. RD wireline, Cudd. ND BOP. NU tree, test void and hangar seal from top down to 3K. NU Manumatic valve and production flowline. Pull BPV, install two-way check and test tree to 4700 psi, and hold for 15 minutes (OK) 12/07/02: RD/MO 12/08/02: RD/MO UNOCAL ) Granite Point Field Well/4 GP-50 Actual 12/8/02 289' 982' RKB to TBG Head = 43.0' 1 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 186.4 X-42 RL-4S 22.5" 43' 169' 84.5 X-56 17.755" 43' 982' 68 K-55 BTC 12.415" 43' 3820' 47 N-80 BTC 8.681" 43' 7550' 53.5 P-110 BTC 8.535" 7550' 10,063' 32 P-110 BTC-TKC 6.094" 9641' 12,086' 24" 18-5/8" 13-3/8" 9-5/8" 9-5/8" 7" Liner 3,820' Tubing: 2-7/8" 6.4 L-80 IBTC 2.441 43 11,439' (S.C.C.) (E.O.q'.) 9641' 10,063' N'O. Depth JEWELRY DETAIL ID Item 4. 9. I0. 11. 43 383' (various) 11,226' 11,356' 11,367' 11,379' 11,273' 11.359' 11,408' 2.92 2.310" 2.347" 2.441" 2.441" 2.312" 2.441" 2.21" 2.441" 2.441" Vetco Grey 13.5" 5m tbg hanger 3 W' IBTC (top/boO 2-7/8" TE-5 TRSV (flapper) (4.625" OD) 2-7/8" GLM SFO-1 R-1 valves, BK-2 Latches (4.75" OD) (11 mandrels @ 11,114'; 10,690'; 10,232', 9713'; 9012'; 8219'; 7369'; 6322'; 5079'; 3648'; 2122') SB-3 permanent packer (threaded- no seals) Baker 3H (orig.) permanent packer w/5' mill out ext. "X' nipple (original equipment) Scoop head guide (non-sealing overshot over orig. tbg stub) Dropped 4 5/8" TCP Vann gun (total length = 487') (top of TCP gun at 11,596' SLM, 11,573' ELM) Baker 'XN' nipple E-22 Anchor Seal Assembly (original) Mechanical release (B shift tool- apparently shifted, no record) PBTD = 12,060' TIE)= 12,J45' Zone Hemlock Hemlock Hemlock Hemlock PERFORATION DATA Top Btm Amount 11,455 11,503 48 Open 11,511 11,535 24 Open 11,562' 11,735' 173 Open 11,765' 11,888' 123 Open Condition GP-50 Schematic 12-8-02 Created: 12/11/02 ---- STATE OF ALASKA -: ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: .... Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved Program: Pull tubing: X Variance: Perforate: Other: Replace Parted Tubing 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 109 RKB feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247, Anchorage, AK 99507 Stratigraphic: Service: UNOCAL-MOBIL STATE #1 4. Location of well at surface Granite Point Platform Leg #3 Conductor #11 8. Well number 2386' FNL & 1372' FWL F/NW Corner Section 13/T10N,~ R12W,, S.M. GP-50 At top of productive interval~/ ~' ~/ 9. Permit number 11455' MD 3039' FNL & 479' FWL F/NW Corner Section 13 T10N, R12W, S.M. 92-41 At effective depth 10. APl number .~/,' 50- 733-20434 At total depth 11. Field/Pool 12163' MD 3143' FNL & 695' FWL F/NW Corner Section 13 T10N, R12W, S.M. Granite Point Middle Kenai 12. Present well condition summary Total depth: measured 12145' feet Plugs (measured) None true vertical 11801' feet Effective depth: measured 12,060' feet Junk (measured) Dropped 487' TCP gun from 11,573' ELM to PBTD. true vertical 11,723' feet Casing Length Size Cemented Measured depth True vertical depth Structural 169' 24" 169' 169' Conductor 982' 18-5/8" 1250 sxs 982' 982' Surface 3820' 13-3/8" 2648 sxs 3820' 3806' Intermediate 10063' 9-5/8" 1465 sxs 10063' 9819' Production Liner 12086' 7" 650 sxs 12086' 11745' Perforation depth: measured 11455'-11503' MD 11152'-11198' TVD true vertical 11511'-11535' MD 11205'-11228' TVD 11562'-11735' MD 11254'-11418 TVD Tubing (size, grade, and measured depth) 11765'-11888' MD 11446'-11561' TVD 2-7/8" 6.4#, 11408' (Note: Tubinbg apparently parted 7' below tubing hanger, purpose of workover is to replace tubing) Packers and SSSV (type and measured depth) Packer: Baker 7" 3H permanent packer w/5' mill out ext. @ 11356' TRSV: Baker FV-6E (not functional - control line parted with tubing) 13. Attachements Description summary of proposal: Detailed operations program: X BOP sketch: X Choke Manifold sketch_~_X Current & Proposed Wellbore SchematicS__~_X 14. Estimated date for commencing operation 15. Status of well classification as: 11/26/2002' 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver N/A Date approved Service: 17. I hereby certify t"~e foregoing i,¢ltrue and correct to the best of my knowledge. / / ' FOR COMMISSION USE ON~LY ~'~"~ ' Date: /"~ /0 Conditions of appfoval: Notify Commission so repre§,~ntative may witness ~{~ (~_~ ~,~ ~'a-mb ~ "~%~--, Approval No. Plug integrity__ BOP Test_~,~_. Location clearance~ . . Mechanical Integrity Test Subsequent form required 10- L-~(~) SCANNE [. EC 0 ¢ 2.002. NOV 1 5 2002 lj Oil &.6 . ns.O°mmlsslm Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Granite Point GP-50 HWOU Workover to Replace Parted Tubing Unocal Alaska requests Sundry Approval to perform workover operations on Granite Point Well GP-50 with the following exceptions to surface equipment requirements: 1.) 2.) ~GANN[D BEC 0 To employ use of 2" dual manual choke manifold, as per attached diagram, downstream from 4" 5m HCR valve on choke line (outer of two valves will be an HCR valve). From HCR, system will be stepped down to 2" 5M flanged hose to 2" 5M manifold with dual 2" 10m chokes. No chicksans or .~wivels will be utilized. To take returns to the production low pressure separator and/or a poor-boy de-gasser as required. GP-5~ 13 ~8" ~ HWOU BOP S~ack up Choke Line - two flanged Top of Unihead {tbg spool) Bypass 2" 1502 Hook up to Production separator or poor-boy gas buster (if needed Drain w/1502 Bull plug 2" Dual Manual Choke Manifold 2" HP Hose w/4 1/16" 5M Flange From Drillin,cI Spool ~ SCANNED UNOCAL GP-50 HWOU Pr6 edure Workover to Repair Parted Tubing Version 2 11/13/02 Objective: Recover parted 2 718" completion & run new 2 7/8" gas lift completion. History: The subject well was drilled and completed in the Hemlock in 1992. The well initially produced oil at a rate of +1000 BOPD, and production had declined in stages to a flat +110 BOPD from 1998 to 2001. The unusual production decline trend was attributed to an inefficient gas lift design and/or to leaks in an SPM at 6234'. A significant amount of slickline work occurred between 1999 and 2001. Dummy valves in the lower portion of the tubing string were replaced with live valves and an orifice valve. The leaking SPM at 6243' was blanked off with a slickline patch in January 2001. Efforts to optimize the gas lift design were apparently successful, and the production rate spiked at an average 290 BOPD in June and July 2001. In April 2002, during routine gas lift operations, the 2 7/8" production tubing parted approximately 7' below the tubing hanger. The 2 718" tubing fell some undetermined distance downhole, and parted the TRSV control line in the process. There is no information in the wellfile concerning when the TCP gun was dropped, but S-line runs in 1999 and 2000 tend to prove that the gun was dropped at some point. The deepest recorded slickline tag at 11,596' SLM occurred on 9/23100. This is between the second and third set of perfs. Well Status: The SlWHP (tubing and casing are the same) has ranged from 640 to 980 psi since the tubing failed. The well has been flowed briefly several times since the tubing parted. It reportedly unloaded 105 BO in 4 1/2 hours the first time the well was flowed, however the FWHP declined and the production rate decreased to a relatively Iow rate (not measured) before the well was shut-in. The well has never passed a NO-FLOW test and should be regarded as having significant flow potential. The produced oil and solution gas reportedly have 0 ppm H2S. The well reportedly has a tendency to build up asphaltenes in the tubing. However, virtually all slickline runs over the past ten years made it to bottom without significant difficulty, so the problem is not considered to be severe. Wellhead Status: GP-50 has a Vetco Grey multibowl (unihead) wellhead system. The complete system is a 24" x 18 518" x 13 3/8" x 9 518" x 3 1/2", 5M MSP, MB-107, multibowl assembly (refer to attached diagram). The 3 118" 5m WKM MIM tree has two masters, a swab, and a wing SSV. The 13 518" tubing hanger will require using a full opening 13 5~8" BOP. The top connection on the multibowl is a Graylock SS137. A Graylock SS137 x APl 13 518" 5M flange adapter spool will be required. It should be noted that the maximum test pressure for the 9 5~8" packoff is 3000 psi. On 5128/02 an inspection along with communications testing was performed. Tubing pressure 1110 PSI 13 3~8" pressure 130 PSI 9 5/8" pressure 1110 PSI 18 5/8'" pressure 50 PSI Tested tubing hanger void to 500 PSI Iow pressure test, and to 5000 PSI for a high pressure test. All tested good for 15 minutes each. Void area had some gas in it that bled to zero. Installed a gauge on the SSSV control line port, it reported the same pre.~(~~,t,l~pgR ~r~14:l(f~uction casing 1110 PSI. All gas. GP-50 HWOU Procedure.doc 1 11/13/2002 UNOCAL ) GP-50 HWOU Pr6 edure Workover to Repair Parted Tubing Version 2 11/13/02 The hanger top/bottom threads are reportedly 3 1/2" IBTC. A short 3 1/2" IBTC x 2 7/8" IBTC X-over exists immediately below the hanger. Some damage to one of the tubing hanger LDSs has occurred as a result of an accident on an offset well. Steve Lawrence will service the tree and hanger during the workover, and has ordered a replacement LDS. Also, during the initial tubing hanger installation, 4 allen head bolts that hold the seal assembly on the hanger sheared twice during installation, and remain broken at this time. This same problem occurred in the next well completed, GP 51. Vetco Grey is investigating this problem and it might be necessary to send the hanger to shore for quick repairs during the workover. Pre-HWOU Bullhead Kill (wi short crew): . Off-load & spot Swaco pump & CTU mixing tank. Spot CTU tank according to HWOU layout diagram. 2. Stir OBM in beam tank while spotting & R/U pumping equipment. 3. Bleed off any trapped gas pressure to Production prior to starting. . ND production flowlines from X-mas tree. Install second valve on casing outlet. Blind flange flowlines per UNOCAL lock out tag out procedure. R/U high pressure piping and/or hose to tree wing valve. Pressure test piping and/or hose to 3000 psi. 6. Mix +/-300 bbls of 3% KCI-FIW in CTU tank & confirm density is approximately 8.6 ppg. Note: Estimated reservoir pressure gradient = 0.41 psi/ft. . Bullhead kill well with 80 to 100 bbls 3% KCI-FIW (8.6 ppg). Maximum pump pressure should not exceed 3000 psi. Discuss with Superintendent if 3000 psi is insufficient. Stop pumping if/when fluid hits perfs & pump pressure increases. Observe trapped pressure leak off after pumping & bleed back if necessary. Observe well 30 minutes to verify dead & determine loss rate. Discuss with Superintendent & be prepared to bullhead more 3% KCL-FIW, or to increase density to 6% KCI-FIW (8.9 ppg) if required to kill well. Have Star-Carb CaCO3 materials on board in case needed (same LCM pill as ESP workover pill). Note: It is predicted that the reservoir will not break down with only 3000 psi. Therefore, the initial matrix pump rate with <3000 psi might be Iow. As more KWF is pumped the pressure should decrease due to increased hydrostatic head and the rate might can be increased for a more efficient displacement of hydrocarbon into the perfs. Note: The 80 - 100 bbl figure assumes that bullheaded fluid will travel down the inside of the parted tubing through packer and into the 7" liner. If the tubing is also parted, or severely damaged, above the packer, bullheaded fluid might travel down the tbg-csg annulus, possibly through SPMs, thus, more than 100 bbls might be required to kill well. Note: The 9 5~8" 47 ppf N-80 casing has a new burst rating of 6820 psi. However, this casing is 10 years old and some unknown amount of drilling wear has occurred. Therefore, the maximum recommended pump pressure should not exceed 3000 psi. The reason for killing the well in advance of the HWOU arrival is to verify that the well can be GP-50 HWOU Procedure.doc $C/4NNE¢ HE[} 0 ~ 2002 11/13/2002 UNOCAL ) killed off the critical path. to top kill the well. GP-50 HWOU Pr6Cedure Workover to Repair Parted Tubing Version 2 11/13/02 If necessary, CTU can be mobilized & RIH alongside ethe fish Capacities: Calculated Volumes: 9 518" 47 ppf csg capacity = 0.0732 bbl/ft 9 5/8" 53.5 ppf csg capacity = 0.0707 bbl/ft 7" 32 ppf liner capacity -' 0.0360 bbl/ft 2 718" 6.5 ppf capacity = 0.00579 bbl/ft Full Vol. to bottom perf (no tbg) = Vol. to top perf (no tbg) = Tbg volume (as if not parted) = Tubing displacement -- Full Well Volume - Tbg DispI. -- Liner Capacity (pkr to bottom perf) = ((0.0732'(7550-43))+(0.0707'(9641-7550))+(0.036'(11888-9641))) ((0.0732'(7550-43))+(0.0707'(9641-7550))+(0.036'(11465-9641))) (.00579'11356) (11356/10.6235~42) (778.2-25.5) ((11888-11356)*.036) = 778.2 bbls = 763.0 bbls = 65.8 bbls = 25.5 bbls = 752.7 bbls = 19.2 bbls Rig Up HWOU (wi short crew, 12 hour days): . Position surface equipment per attached lay out plan. Start mixing 3% KCL-FIW (KWF) in 300 bbl CTU mixing plant. Note: Mixing of fluid can be carried out off of the HWOU's critical path. . Hold safety meeting with crews prior to RU. Discuss all pertinent safety issues & review SIMOP & HWOU MOC Checklist. 10. RU circulating system per attached diagram. Secure all lines with chains. Pressure test entire circulating system to choke to 3,000 psi with KWF. 11. If well is not dead, attempt to bleed off any trapped gas pressure. If necessary, bullhead kill well with 3% KCI-FIW. Pump as little as is required to kill well. Maximum pump pressure should not exceed 1500 psi. Discuss with Superintendent if 1500 psi is insufficient. Bleed back trapped pump pressure & observe well 30 minutes to verify dead. Determine loss rate before proceeding. 12. Set 3" Cameron Type "H" BPV. 13. ND 3 1/16" 5m X-mas tree. Lock down pins should remain fully engaged until BOPE is fully tested. Scribe hanger out of wellhead as required to ensure X-mas tree orientation is maintained after workover to avoid flowline modifications. Note: Have wellhead rep ensure that all pressure has been bled from all lines and all voids associated with the tree, seal flange, tubing hanger and 9 518" casing hanger immediately prior to removal. Verify Tubing Hanger lift thread is 3 1.2" IBTC, thread condition is acceptable & ensure that any ports in the hanger are properly plugged. 14. NU & function test 13 5/8" 5m BOP's in a 5m triple ram configuration as per attached diagram (i.e. drilling spool, double ram preventer & annular preventer). BOP's should be dressed with 2 7/8" x 5" VBR in top preventer, blinds in the middle, and 2 7/8" pipe rams in the bottom preventer, preferably off of the HWOU's critical path. GP-50 HWOU Procedure.doc 11/13/2002 UNOCAL GP-50 HWOU PrOCedure Workover to Repair Parted Tubing Version 2 11/13/02 Note: Contact AOGCC 24 hours prior to testing BOPE (279-1433). The MASP is estimated to be 1100 psi, assuming a full column of oil with a minor gas cap, based on previous experience with this well. Full evacuation with gas, which is highly unlikely in this well, could theoretically result in up to 3000 psi surface pressure. The BOPs will be tested to 4000 psi since high bullhead pressures theoretically could be required, even though the maximum pressure on the 9 5/8" casing is limited to 3000 psi for safety. 15. NU work window & basket. Continue RU HWO unit and associated equipment. Ensure all safeguards are met for a safe operation with adequate fall protection and spill prevention. Conduct "Pre-Spud" Inspection and fax results to Drilling Superintendent, Note: Check stack bolts once per tour and ensure bolts remain properly torqued. 16. Check casing for pressure. Replace BPV w/TWCV. Pressure test blind rams & all choke/kill line components to 250/4000 psi as per AOGCC regulations. Note: Monitor casing pressure while testing BOPE. 17. Check casing for pressure & pull TWCV. 18. Engage hanger with 3 %" landing joint. Pressure test VBR & pipe rams to 250/4000 psi. Test annular to 250/3000 psi. Complete Unocal Alaska BOPE Checklist and Contract Toolpushers Checklist and fax to Drilling Superintendent. Workover Procedure (wi full crew, 24 hour operations): 19. Hold Pre-well safety meeting. Brief crews on safety and environmental concerns. Verify full compliance with SIMOP & MOC-HWOU Checklist. Note: Use trip tank to keep hole full and monitor loss rate at all times. 20. Check casing for pressure, back out hanger hold down screws, un-land hanger, pull to work window & LID same. Inspect upper piece of parted 2 7/8" tubing. Hot-shot hanger to Vetco Grey for urgent repair/re-dress. 21. Note: It is assumed that a connection failure occurred at the lower end of a pup joint +7' below the hanger. Verify whether or not the overshot is likely to slip freely over the fish or if some amount of 'dressing' will be required. Verify whether overshot will be sized for regular 2 718" coupling (3.668") or for 2 7/8" tube. MU & RIH slowly w/Baker sealing overshot fishing BHA #1 (refer to attached Baker procedure) on 3 %" DP to tag and engage parted 2 7/8" tubing. Overshot will be sized to catch & seal on tubing coupling or on 2 7/8" tube, depending on what is recovered from the well with the tubing hanger. Run bumper sub w/full open (3.0") ID to be able to disengage overshot, if required. Note: Top of fish is likely to have slipped downhole some distance due to possible buckling in the 7" liner and above the liner top in the 9 518" casing. Utilize overshot with pack-off to allow circulating out oil after tubing cut. 22. If possible, pull top of fish up to original point of failure, but do not exceed estimated original string weight (in case tubing is jammed or stuck downhole, etc.). It tubing can be pulled up approximately to it's original position without excessive weight, proceed with step #16. If not, discuss next step with Drilling Superintendent. 2 7/8" 6.5ppf N-80 IBTC Tube Body & connection strength - 144,000 ibs (if new) GP-50 HWOU Procedure.doc , ANNED DEl; © 201 2 11/13/2002 UNOCAL ) GP-50 HWOU PrOCedure Workover to Repair Parted Tubing Version 2 11/13/02 Maximum Recommended Pull = 115,00 lbs (80% Yield) Approximate hook load when landed = 60,000 lbs on hanger Note: Annular can be closed at this point, if desired, to minimize risk of gas release while making S-line runs. 23. RU S-line unit. Pressure test lubricator with KWF 250/3000 psi on all S-line runs. RIH w/2 7/8" FV6E "lock Open Tool" & lock open Baker FV-6E TRSV. POH w/running tool. RIH w/Pulling Tool Probe Assembly & recover outer portion of Lock Open Tool. Note: Two runs are required to lock open the TRSV. The safety valve will have a minimum 2.313" ID once locked open. It is recommended that a Pollard skid mounted slickline unit with a 0.125" line be mobilized to do this work in order to save time and improve efficiency (as opposed to using the smaller on-board unit with 0.108" line). 24. Make three trips with 2 %" GS pulling tool to recover; (1) the 'G' Stop Anchor, (2) the top pack- off & upper 10' of spacer pipe, and (3) the lower 10' of spacer pipe & bottom pack-off. Make one trip with the 2" JDC pulling tool to recover the 'A' Tubing Stop. Note: Only four hours was required to make four runs and set these tools on 1/26/01. Recovery of the assembly is expected to take approximately 4-5 hours assuming four successful runs. 25. RIH w/2.125" GR/JB to the end of tubing at the mechanical gun release @ 11,408'. RD S-line unit. Note: The GR/JB might set down above the packer if the tubing was damaged when it parted. An additional run with a smaller tool (perhaps a 1.5" LIB or ) might be required to verify the damage and/or to try to get through any ID restriction or asphaltene deposit that might exist. 26. RU APRS E-line unit. RIH w/2.125" jet cutter & cut 2 7/8" tubing in middle of first full joint above packer @ +/- 11,343'. POH & RD E-line unit. Note: Slightly smaller OD jet cutter should work better in tubing with asphaltene deposits, plus cut cut tbg stub will serve as wireline entry guide (looking up) inside of production overshot. Close annular & be prepared for U-tube when cuttinq tubing. 27. Circulate oil out of tbg-csg annulus and verify well dead. 28. POH & LID 2 7/8" completion. Note: The pipe should be checked for NORM while POH. Norm pipe to be properly marked and handled in accordance with UNOCAL's NORM pipe handling procedures. Run New Completion: 29. RU S-line unit. RIH w/5.795" GR/JB for 7" 32 ppf casing to planned packer setting depth @ +11,275' (+ 81' above original packer). RD S-line unit. 30. Pick up & RIH w/the following completion. GP-50 HWOU Procedure.doc 11/13/2002 UNOCAL GP-50 HWOU Prb' edure Workover to Repair Parted Tubing Version 2 11/13/02 Completion Details: - 5.75" OD x 10' overshot (non-sealing) - X-over - I jt. 2-7/8" 6.4 ppf L-80 IBTC SCC tubing - Baker 2 7/8" 'XN' nipple 2.25" minimum ID - 1 jt. 2-7/8" 6.4 ppf L-80 IBTC SCC tubing Baker 7" SB-3 Hydro-Set Retainer Production Packer w/mill-out ext. 2-7/8" 6.4#, L-80, Buttress SC Tubing to 400' w/eleven (11 ) live 2 7/8" SFO-1 SPM gas lift valves (refer to attached gas lift design for setting depths) Baker TE-5 TRSV @ 400' 2-7/8" 6.4#, L-80, Buttress SC Tubing to surface X-over 2 7/8" IBTC pin x 3 W' IBTC box - 3-1/2" 9.2 ppf L-80 IBTC pup joint - Repaired & re-dressed Vetco Grey MB-107 13 5/8" x 3 %" IBTC top/bottom tbg hanger w/3" type 'H' BPV profile 31. RIH with assembly torquing connections to make up marks on buttress connections. Note: Drift all 2 7/8" tubing & all other components (except nipples) to 2.347". Maintain 3500 psi pressure on TRSV while RIH w/control line. Verify minimum ID of nipple & TRSV. 32. RIH & work overshot over jet cut tubing the full 10'. 33. RU S-line unit. RIH w/2.25" GR & verify passage through stub & original packer to top of TCP gun. RD S-line unit. 34. Pick up 2', mark pipe & measure for space out. 35. Space out/land completion. Engage lock down screws. Note: Maintain 5000 psi control line pressure on TRSV while RIH, spacing out & landing completion. 36. RU S-line unit. RIH w/2 7/8" 'N' test tool to 'XN' nipple @ _+11,305'. Land 'N' test tool in 'XN' nipple. Pressure up to 3500 psi (official required pressure is 3000 psi) to set packer. Pressure test packer to 1500 psi while maintaining 3500 psi tubing pressure. Bleed off tubing (and casing) pressure slowly. POH, RD & release S-line unit. Note: Monitor slickine tension while pressuring up to set packer. RD & Release HWOU: 37. Set BPV. RD HWOU. ND BOP's. 38. NU original 3 1/8" 5M ClW tree w/original orientation to match flowline. Pull BPV & set TWCV. Pressure test tree to 5,000 psi. Recover TWCV. 39. NU original flowline & gas lift line. 40. Turn well over to production. 41. Release HWOU. GP-50 HWOU Procedure.doc 6 11/13/2002 I~: L.,31""-OU OUllLlly /"~tJI,.~lUVC~l Subject: Re: GP-50 Sundry Approval Date: Tue, 19 Nov 2002 14:32:59 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Bowen, Jerry -Alaska" <jbowen@unocal.com> Jerry, This confirms our discussion with regard to the HWO NU on GP-50. In your sundry application you indicate that the choke manifold will employ 2 manual chokes. The operations you are conducting are covered by 20 AAC 25.285 (workover operations with the tree removed). 25.285 10 A requires two or more adjustable chokes, one of which must be hydraulic and remotely controlled from near the driller's station if the operation requires a BOP stack equal to or greater than APl 5K. As indicated in your application, the present SI surface pressure is about 1100 psi. Using your highest anticipated fluid weight of 8.9, the MASP with a gas column would be about 4000 psi. The well has shown that the likely anticipated pressure is the 1100 psi experienced. Based on the information in you application and the reading of the regulation at 25.285 A, your proposal to use 2 manual chokes is acceptable. Tom Maunder, PE AOGCC "Bowen, Jerry -Alaska" wrote: Tom, I know you're busy, but is there any chance we can get the GP-50 Sundry approval today? If so, we would like to nipple up BOPE prior to the arrival of the HWOU. The unit will not be winterized and ready to send offshore until +/-Tuesday, but we would like to nipple up starting tomorrow, if you have no objections. Please call if I can be of assistance. Thanks. Jerry F. Bowen, P.E. Sr. Advising Drilling Engineer Office: 907-263-7640 Cell: 907-360-2490 Home: 907-688-2278 Fax: 907-263-7884 . Tom Maunder<tom maunder@adm~n.state.ak, us> :.1 Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 11/19/2002 2:33 PM MEMORANDUM TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. i. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission FROM: John Crisp, SUBJECT: Petroleum Inspector DATE: May 10, 2001 Safety Valve Tests Granite Point Platform Granite Point Field May 10, ...2.00!.; I traveled to UNOCAL's Granite Point Platform and witnessed the semi annual safety valve system testing. I found a very clean platform with sign's of regular maintenance and much fresh paint in evidence. The Safety Valve Systems were tested. 9 wells and 26 components were tested with two failures. Ted Medley lead operator conducted the testing today, he demonstrated good test procedure and was a pleasure to work with. The SSSV on GP-50 failed to close. This is a repeat of the previous tests failure; I expressed the AOGCC's concern for the repair & retest of the failures. The AOGCC test report is attached for reference. SUmma.r't; I witnessed the semi annual Safety Valve System testing at UNOCAL's Granite Point Platform in the Granite Point Field. Granite Point Platform, 9 Wells, 26 components 2 failures. 7.7% failure rate. A..tt. achment: SVS Granite Point Pit. 05-10-0 ljc NON-CONFIDENTIAL SVS Granite Point Pit. 05-10-0 ljc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep: Ted ~ed!ey AOGCC Rep: John Crisp Submitted By: John Crisp~ __ Date: Field/Unit~ad: Granite Point Field &Plt. ..... Separator psi: LPS 60 HPS 5/10/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip, ,Code, ,,Code Code .... Pas, sed GAS or CYCLE i i-13RD 191 i33'0 .... 60 '40 33 P '.~ ~ 4 P 0'IL i3-i3 1670210 60 40 ...... 40 'P "P ......P .............. 0iL! '5i'i3' '1660550 .................................... 31-14RD2 1002660 3'1-23 ' ' ' 16708~0 '60 40 ..... 40' J P ..... p ...... OIL 32-13RD 19202i30 ...... 60 40 " 40 P ..... e P ' " 0IL 42-23RD 195'1450 " 60 '~0 34 'P e "P ........... OiL 44-14 1670620 60 40 36 P e P OIL '50 "i/32'04i'0 '6'0 ..... 40'' ' 33 .... P P '" 8 ........... 0IL "5'1 ..... 1920720 60''~ 40 "35 ..... P .... e "P .................. O'I'L '54 1960130 " ~0 '" 40 34. 'P .... P ' P ..... OIL Wells: 9 Components: 26 Failures: 2 Failure Rate: 7.69% F190 var Remarks: .SSV on well 11-13 failed to ,h01d D,p.,,, ,Th_is gate valve,,~ ~ ~,rvi,ce, d,,&,re.-te.sted; SS~ on well GP-50 failed to close. Ted, M.edley will co,,ntact..,,U .n~cal. Sul~,,, .r~. r.s' ,a..bout. AOGCC's conCern for the repair & re-test of GPS0's SSSV. RJF 1/16/01 Page 1 ofl SVS Granite Point Pit. 5-10-01jo MEMORANDUM TO- Julie Heusser, Commissioner THRU' Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 7, 2000 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Granite Point Platform Granite Point Field December 7, 2000; I traveled to UNOCAL's Granite Point Platform and witnessed the semi annual safety valve system testing. I found a very clean platform with sign's of regular maintenance and much fresh paint in evidence. The Safety Valve Systems were tested. 9 wells and 26 components were tested with two failures. 'Ted Medley lead operator conducted the testing today, he demonstrated good test procedure and was a pleasure to work with. The AOGCC test report is attaChed for reference. Summary; I witnessed the semi annual Safety Valve System testing at UNOCAL's Granite Point Platform in the Granite Point Field. Granite Point Platform, 9 Wells, 26 components 2 failures. 7.7% failure rate. Attachment: SVS Granite Point Pit. 12-07-00jc NON-CONFIDENTIAL SVS Granite Point Pit. 12-07-00jc.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: nocal Operator Rep: Ted Medley AOGCC Rep: John Crisp . Submitted By: John Crisp ,,, Date: Field/Unit/Pad: Granite POint Field & Pit. Separator psi: LPS 60 HPS 12/7/00 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLe, 11-13RD 1911330 60 40 33 P P P OIL 13-13 1670210 60 40 37 P (5~ P 12/8/00 OI[ 31-13 1660550 ,, 31-14RD2 1002660 31-23 1670840 60 40 35 P P OIL 32-13RD 1920200 60 40 35 P P P OIL 42-23RD 1951450 60 40 40 P P P OIL 44-14 1670620 60 40 35 P P P OIL 50 1'92041'0 . 60 40 '35 P P OIL 51 1920720 60 40 35 'P P P OIL 54 , 1960130 60 40 36 P P P OIL Wells: 9 Components: 26 Failures: 2 Failure Rate: 7.7% Eloo var Remarks: Well 31023 is a no flow. 12/13/00 Page 1 of 1 SVS Granite Point Pit. 12-07-00jc.xls PERMIT DATA ~' · AOGCC Individual Well ~-=~ological Materials Inventory T DATA_PLUS Page: 1 Date: 01/18/95 RUN DATE_RECVD 92-041 5362 92-041 5363 92-041 92-041 92-041 DRY DITCH 407 DAILY WELL OP 92-041 SURVEY 92-041 ASL 92-041 ASL 92-041 CBT 92-041 92-041 T 640-12152, OH-EDIT T 0-12145, GCT S 290-12163, SS#854 R COMP DATE: 07/19/92 R 05/18/92-08/03/92 R 0-12145, GCT L 981-12094 L 981-12094 L 7280-12034 CHROMATOGRAPHY : L 292-12163 DDL L 292-12163 L 1500-12104 L 1500-10052 92-041 DNL (PORO) 92-041 FMI 92-041 GCT L 0-12022 92-041 LDT L 1500-12104 92-041 ML L 1500-12104 92-041 MUD L 292-12163 92-041 PDI L 981-12094 92-041 PDI L 981-12094 92-041 RFT L 8420-9332 1-3 09/01/1992 i 09/01/1992 07/29/1992 09/10/1992 09/10/1992 09/01/1992 1-3 09/01/1992 1-3 09/01/1992 1 09/01/1992 09/01/1992 09/01/1992 2-3 09/01/1992 1-2 01/05/1995 1 09/01/1992 2-3 09/01/1992 2-3 09/01/1992 09/01/1992 1-3 09/01/1992 1-3 09/01/1992 1 01/05/1995 Are dry ditch samples required? yes no And received? yes no Was the well cored? yes no Analysis & description received? Are well tests required? yes no Received? yes no Well is in compliance Initial COMMENTS yes no Unocal Energy Resoun )ivision ~ West ~h, P.O. BOX ,~5247 Anchorage, AK ~519-6247 Telephone (~)9) 276-7600 Fax (907) 263-7828 UNOCAL ) Debra Childers Clerk Janua~ 4,1995 DATA TRANSMITTAL # 1. To: From: Larry Grant Debm Childers 3001 Porcupine 909 W. 9th Avenue Anchorage,,AK 99501 Alaska Oil & Gas Anchorage, AK 99519-6247 Unocal GRANITE POINT 50 BLUELINE / SEPIA RFT, FMI IVAN RIVER 13-31 SEPIA SBT/GR 6400 - 9990, 1000-11410 IVAN RIVER 13-31 BLUELINE / SEPIA BHC/AC/GR 3458-11558 I IVAN RIVER 13-31 BLACKLINE CALIPER IVAN RIVER 13-31 SURVEY Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. I Received by: ]Date: PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page: 1 Date: 06/13/94 RUN DATE_RECVD 92-041 92-041 92-041 92-041 92-041 92-041 92-041 92-041 92-041 92-041 92-041 ASL L 981-12094 ASL L 981-12094 CBT L 7280-12034 CHROMATOGRAPHY : L 292-12163 DDL L 292-12163 DNL (PORe) L 1500-12104 GCT L 0-12022 LDT L 1500-12104 ML L 1500-12104 MUD L 292-12163 PDI L 981-12094 92-041 PDI 92-041 407 92-041 DAILY WELL OP 92-041 SURVEY 92-041 DRY DITCH 92-041 5362 92-041 5363 L 981-12094 R COMP DATE: 07/19/92 m 05/18/92-08/03/92 R 0-12145, GCT S 290-12163, SS#854 T 640-12152, OH-EDIT T 0-12145, GCT 1-3 09/01/92 1-3 09/01/92 1 09/01/92 09/01/92 09/01/92 2-3 09/01/92 1 09/01/92 2-3 09/01/92 2-3 09/01/92 09/01/92 1-3 09/01/92 1-3 09/01/92 09/10/92 09/10/92 09/01/92 07/29/92 1-3 09/01/92 1 09/01/92 Are dry ditch samples required? yes ~ And received? ~no Was the well cored? yes ~ Analysis & description received? Are well tests requi~l~ yos_~~ Received? yes ~ Well is in compiianc~ ~ ~Initial yes Unocal North Americr'-'~,il & Gas Division Unocal Corporation 909 West 9th Avenue, F.. 3ox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 R. C. Warthen Regional Manager Development Geology & Geophysics Alaska Region UNOCAL ) DOCUMENT TRANSMI'ITAL July 28, 1992 HAND DELIVERED TO: Larry Grant 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION FROM: Dick Stewart P O Box 196247 Anchorage AK 99519-6247 ALASKA REGION Transmitting as Follows: Unocal, Granite Point Field GP-50 well 14 boxes of dry samples-'~ Unocal, Granite Point Field GP 32-13RD well 9 boxes of dry samples PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATED: O. A ASKA 0 il I G I ALA$?'"':OIL AND GAS CONSERVATION CO~' ~'-SSION WELL COMPLET;'~,N OR RECOMPLETION r,,--PORT AND LOG '~ i 1. Status of Well Classification of Service Well 2. Name of Operator ?['.~AI'K)N~; 7. Permit Number (UNOCAL) UNION OIL COMPANY OF CALIFORNIA ¥1~1F~ 92--41 3. Address ~-~_ ~_.~L 8. APl Number P.O. BOX 196247, ANCHORAGE, AK 99519 ~. .. ,~-'*'1^ 50-733-20434 4. Location of well at surface GRANITE POINT PLATFORM LEG #3 CONDUCTOF/~~-- -----"'---- 9. Unit or Lease Name 23~6'At TopFNL & 1372'Producing IntervaIFWL F/NW CORNER SECTION 13 TI ON, R12W, S.M. 15~~..~~tz.,,._._.....~l;E~,~~E ~'~_ 10. UNOCAL-MOBIL STATE #1Well Number 11455' MD ;~)39' FNL & 479' FWL F/NW CORNER SECTION 13 TION, R12W. S.M., ..~-~,_., , I...~_ V~_~.~/F,~'~"'~! GP #50 2A:6T;t;DD~Plth43 ~ 11. Field and Pool I ' FNL &695' FWL F/NW CORNER SECTION 13 T10N, R12W, S.M. GRANITE POINT 5. 1Elevation09 RKB in feet (indicate KB, DF, etc.) 6. LeaseADL_lDesignation8761 and Serial No. MIDDLE KENAI 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 05 - 20- 92 07 - 10 - 92 07 -- 19- 92I 75 Feet M S L S I NG LE 17. Tota112163,MDDepth/(MD +TVD)i 1818'TVD 18. 12060'MDPlUg Back/Depth11722'TvD(MD +TVD) YES19' Directional[~ Surv~NO I I 20.328Depth where SSSVfeet MDSet 21. NAThickness of Permafrost 22. Type Electric or Other Logs Run D IL/SDT/M L/G R/SP/LDT/C N L/EPT/G R/FM I/RFT/AM S/C ET/C BT/GCT 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER GRADE TOP ~ BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 18-5/8' 87.5# X-56 0' 982' 24' 1250 SXS 13-3/8' 68# K-55 0' 3820' 17-1/2' 2648 SXS 9-5/8' 47# N-80 0' 7550' 12--1/4' 1465 SXS 9-5/8' 53.5# P110 7550' 10063' 12--1/4' 7' 32# P110 9641' 12086' 8--1/2' 650 SXS 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE I DEPTH SET (MD) I PACKER SET (MD) 2--7/8' 11356' 11356' 11455'--11503' MD 11152'--11198q'VD 11511'--11535' MD 11205'--11228'1'VD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11562'-11735' MD 11254'--11418q'VD DEPTH INTERVAL IMD) I AMOUNT & KIND OF MATERIAL USED 11765'-11888' MD 11446'-11561q-VD NA 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 08--05-92 LLOWING Date of Test Hours Tested PRODUCTION FOFt OIL-BBL GAS-MCF WATER--BBL CHOKE SIZE I GAS-OILRATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY--APl (corr) Press. 24--HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. R CEIV :'D A/asRa 0it & {'~as ,rjons~ goro. r~issior~ Anchorag,~ Form 10-407 rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 31. LIST OF-A'I-rACHMENTS FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 32, I hereby ce,rtify that'the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supple mental records for this well should show the details of any mu Itipl e stage ce ment- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. - TUBING DETAIL: RKB 109' _ 1 I 2-7/8", 6.4#, N-80, BU-FI- I-- 2 ALL TUBING DEPTHS ARE TBG DETAIL TOPS 26" @ 289' I-- 1) DOT "FV6E" TBG. RET. SSSV @ 328' 18-5/8" @ 982' I 84.5# X-56 i-- i 1) 1457' 2) 2353' 3) 3085' 4) 3745' -- 5) 4375' 6) 4849' 7) 5298' 8) 5770' -- I -- 13) 8116' 14) 85~' 15) 9055' 16) 9513' I _-' ~q **,,¢~. 17) 9987' 18) 10462' 19) 10928' ~ ' 3) eOT "CMU" ~E~E e 11316' ~" ~ i I ,i ~ 4) DOT "3H" ~D. PERM PACKER ~ 11356' 5) DOT "X" NIPPLE ~ 11367' : = ' u,s 13-3/8" ~ 3820' 4-5/8" x 8 SPF DEEP PEN. 6~ K-55 i ~ W~L PRODUCING THRU PORT SUB AT 11405' ~ 3 ~ TCP MECH. TUBING REL~SE AT 11408' 9-5/8" ~ 10063' 47~, N80 A 53.5~ Pl10 ~ ~ 4 : 5 HEMLOCK INTERVALS (568') T C 6 11455'- 11505' MD DIL 115 11'- 11535' MD DIL P , 11562'- 11735' MD DIL ~ 11765'- 11888' MD DIL 7" L F/9 ~ 1'- 12086' 52~, Pl10 ~ ~ ~D 12060', C~ WELL GP 50 DRAWN' CLL ACTUAL COMPLETION SC~E: N/A UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DATE: 7-51-92 ORIGINAL WELL HISTORY GRANITE POINT 50 Day 1 (5/18/92) COMMENCED OPERATIONS AT 1200 HRS. SKIDDED RIG. FASTLINE SHEAVE ON THE BLOCKS. REPAIRING SCR. REPAIRED DAY 2 (5/19/92) CONT'D REPAIRING BLOCKS. REROUTED SCR POWER DISTRIBUTION. RIH W/23" MILL TO CLEAN OUT CONDUCTOR. TAGGED AT 242'. DAY 3 (5/20/92) CENTERED RIG OVER CONDUCTOR. CLEANED OUT CONDUCTOR TO 291', WITH A 23" MILL. RAN MULTI SHOT GYRO TO 234'. RIH W/ A 17.5" BIT AND 26" TAPERED MILL. DRESSED THE TOP OF THE 26' CASING AT 168'. RIH WITH AN IMPRESSION BLOCK TO 168'. RIH WITH A 26" X 24" TAPERED TIE-BACK ON 24" CASING. ENGAGED TIE-BACK. BEGAN CUTTING 24" CASING. DAY 4 (5/20/92) CONT'D CUTTING 24" CASING. RIH TO 170' WITH A 1-1/4" STINGER BETWEEN THE 24" AND THE 33" CASING. MIXED AND PUMPED 450 SXS OF CEMENT DOWN THE 1-1/4" STINGER. TOC 3' FROM THE TOP OF THE 33". INSTALLED REGANHEAD ON THE 24" CASING. REMOVING DRILL FLOOR AND ROTARY TABLE BEAMS FOR INSTALLATION OF THE DIVERTER. DAY 5-8 (5/22-25/92) CONT'D TO REMOVE ROTARY BEAMS. INSTALLED 30" RISER. INSTALLED 29-1/2"ANNULAR. COMPLETED INSTALLATION OF DIVERTER LINES. INSTALLED ROTARY BEAMS AND DECKING. FUNCTION TESTED ANNULAR PREVENTER AND DIVERTER LINE VALVES. DRILLED 17-1/2" HOLE F/292'-1010'. POOH. UNDERREAMED 26" HOLE FROM 289'- 996'. CIRCULATED. POOH. RAN 18-5/8" CASING TO 982'. RIH WITH A SEAL ASSEMBLY AND 5" D.P. STABBED INTO FLOAT COLLAR AT 906'. CIRCULATED. RECEIVED S E P 1 4 !092 Alaska 0JJ & (:~as 6o~'~s, Commissio['~ Anchorag~ DAY 9 (5/26/92) PUMPED 1250 SACKS OF CEMENT, CEMENT RETURNS TO SURFACE. UNSTABBED FROM FLOAT COLLAR. CIRCULATED. POOH. REMOVED 30" RISER AND DIVERTER. REMOVE 30" BOPE. INSTALL 18-5/8" X 24" PACK OFF AND TEST. INSTALLED 20" BOPE. DAY 10 (5/27/92) FINISH INSTALLATION OF 20" BOPE & TEST. RIH-DRILL CEMENT FROM 882' TO 905'. TEST CASING. DRILL CMT & FLOAT EQUIP FROM 882' TO 960'. TEST CASING. DRILL CMT FROM 960' TO 1010'. DRILL FORMATION FROM 1010' TO 1020'. PERFORM L.O.T. DRILL 17-1/2" HOLE FROM 1020' TO 1523'. DAY 11 (5/28/92) DRILL 17-1/2" FROM 1523' TO 1893' CIRC. TRIP FOR BIT. WASHED OUT NOZZLES. RIH. DRILL 17-1/2" HOLE FROM 1893' TO 2435'. DAY 12-14 (5/29,30,31/92) DRILL 17-1/2" FROM 2435' TO 2554' POOH FOR BHA. PIH AND DRILL FROM 2554' TO 2795'. DRILL 17-1/2" HOLE FROM 2795' TO 3280' CBU. POOH FOR BIT. RIH AND DRILL 17-1/2" HOLE FROM 3280' TO 3652'. DAY 15 (6/1/92) DRILL 17-1/2" HOLE FROM F/3652'-3830'. CCM. POOH. RU SCHLUM. RIH W/DIL/ARRAY SONIC/GR TO 3830' WLM. DIL TOOL FAILED TO BTM. POOH. CHANGED OUT DIL/AMS TOOL. RIH AND LOGGED F/3830'-3580'. DIL TOOL FAILED AGAIN. POOH. CHG OUT TCC/ARRAY SONIC TOOL. RIH & LOGGED F/3830'-982'. RIG DN SWS. PULLED WEAR BUSHING. DAY 16 (6/2/92) RUN 13-3/8", 68# K-55 CSG TO 3820'. M&P 2648 SXS CMT. CIP 1700 HRS 6-2-92. INSTALL CSG PACKOFF & TEST. REM 20" BOP STUCK & RISER. DaY 17 (6/3/92) ~COMPT REMOVAL OF 20 STACK. INSTALL TBG HEAD & TESTED ~INSTALL CSG VALVES, 13-5/8" RISER, AND BOP STACK. CLEAN ~ACTIVE PITS & BUILD MUD VOL. TEST BOP. DaY 18 (6/4/92) COMPT BOP TEST. MU BHA & RIH 3732'. PRESS TEST CSG 2700 PSI, OK. C/OUT CMT & SHOE & DRILL T/3841'. PERFORM L.O.T. .85 PSI/FT. CHG OVER TO PHPA POLY MUD. DRILL & SURVEY 12-1/4" HOLE T/4243'. DAY 19-21 (6/5-7/92) (3 DAYS) DRILL & SURVEY 12-1/4" HOLE F/4243-5175'. SHORT TRIP F/5175- 3817'. DRILL & SURVEY 12-1/4" HOLD F/5175-5429'. CBU TRIP F/BIT & BHA. DRILL & SURVEY 12-1/4" F/5429-6300 W/STEERABLE MUD MOTOR. CBU. DAY 22 (6/8/92) DRILL & SURVEY 12-1/4" HOLE F/6300 ' -6852 ' . T/6200'. DRILL 12-1/4" HOLE T/6863'. SHORT TRIP DAY 23 (6/9/92) DRILL & SURVEY 12-1/4" HOLE F/6863'-7512'. DAY 24 (6/10/92) CBU. POOH F/BHA CHG. TEST BOPE. MU BHA & RIH. DRILL 12- 1/4" HOLE F/7512'-7696'. DAY 25 (6/11/92) DRILL 12-1/4'" HOLE F/7696'-8106'. CBU. DAY 26-28 (6/12-14/92) POOH. CHG BIT MU BHA & RIH. DRILLED 12-1/4" HOLE F/8106'- 8460'. POOH F/BIT. RIH AND DRILLED 12-1/4" HOLE F/8460'- 8488', MUD MOTOR FAILED. POOH. REPLACE MOTOR IN BHA & RIH. DRILLED 12-1/4" HOLE F/8488'-8579'. DAY 29 (6/15/92) DRILLED F/8579'-8729'. POOH F/BIT CHG. RIH AND DRILLED 12- 1/4" HOLE F/8729'-8745'. DAY 30 (6/16/92) 9007'/262' 18-5/8" @ 982' 13 3/8" @ 3820 483 PSI DRILLED F/8745'-9007'. DAY 31 (6/17/92) 9109'/102' 18-5/8" @ 982' 13 3/8" @ 3820 483 PSI DRILLED F/9007'-9048'. POOH. TEST BOPE. RIH AND DRILLED 12-1/4" HOLE F/9048'-9109'. DAY 32 (6/18/92) 9323 '/214 ' 18-5/8" @ 982' 13 3/8" @ 3820 483 PSI DRILLED F/9190'-9323'. POOH. DAY 33-35 (6/19-21/92) 9816'/493' 18-5/8" @ 982' 13 3/8" @ 3820 483 PSI DRILLED F/9323 '-9588' . LOST CIRC PUMPED LCM REGAIN CIRC. POOH TO SHOE BUILD VOL. DR~~~OLE TAKING FLUID. DAY 36 (6/22/92) 9932'/116' 18-5/8" @ 982' 13 3/8" @ 3820 483 PSI DRILLED F/9816'-9932' WITH TRIP FOR BHA @ 9891'. PILL @ 9588' ON TRIP SLOWED LOSSES TO 1-1/2" BPH. SPOTTED LCM DAY 37 (6/23/92) 10081'/149 ' 18-5/8" @ 982' 13 3/8" @ 3820 483 PSI DRILLED F/9932'-10081' (T.D. 12-1/4" SECTION). FLUID LOSSES TO HOLE 3 BPH. R/U SOS. RIH WITH SUPER COMBO TOOL DIL-SDT- LDT-CNL-ML-AMS-GR. LOGGING OUT @ 2400 HRS. DAY 38 (6/24/92) 10081'/0' 18-5/8" @ 982' 13 3/8" @ 3820 488 PSI CONT'D LOGGING WITH S.O.S. SUPER COMBO (DIL-SDT-LDT-CNL-ML- AMS-GR). RAN FMS-IMAGING DIP METER LOGGED INTERVAL F/10055'- 7500'. RIH W/C.O. ASSY CBU @ 2400. RECEIVED SEP 14 1992 Alaska 0il & Gas Cons, Commission Anchorage DAY 39 (6/25/92) 10081'/0' 18-5/8" @ 982' 13 3/8" @ 3820 488 PSI POH W/C.O. ASSY. RU & RUN SOS RFT-GR-AMS. MADE 32 SETS. SOS. RU & RUN 9-5/8" CSG 2400 HRS RUNNING 9-5/8" CSG. DAY 40-42 (6/26-28/92) 10363 '/282 ' 18-5/8" @ 982' 13 3/8" @ 3820 9-5/8" @ 10063' 551 PSI RAN & CMT 9-5/8" CSG TO 10063'. CIP 1300 HRS 6-26-92. INSTALL CSG PACKOFF & TEST. TEST BOPE. MU DRLG BHA & RIH. TAG CMT AT 9332' (HIGH). C/OUT CMT F/9332'-9980'. PRESS TEST CSG TO 5000 PSI F/30 MIN, OK. C/OUT CMT TO 10081'. DRILL 8- 1/2" HOLE TO 10086'. PERFORM FORMATION INTEGRITY TEST TO 17.9 PPG EMW. CHG OVER WELLBORE MUD TO CLEAN MUD SYSTEM. DRILL 8- 1/2" HOLE F/10086'-10363'. DAY 43 (6/29/92) 10524'/161' 26" CONDUCTOR @ 289' 18-5/8" @ 982' 13 3/8" @ 3820 9-5/8" @ 10063' 551 PSI POOH. CHG BIT & RIH. SLIP & CUT DRLG LINE. CONT RIH. DRILL 8-1/2" HOLE F/10363'-10524'. DAY 44 (6/30/92) 10752'/228' 26" CONDUCTOR @ 289' 18-5/8" @ 982' 13 3/8" @ 3820 9-5/8" @ 10063' 624 PSI DRILLED 8-1/2" HOLE F/10524'-10752'. INCR MW TO 12 PPG. CBU. POOH F/BIT. SHUT DN F/RIG REPAIR. ~- A~,aska~ Oil & Gas Cons. Commission A~¢hom~ DAY 45 (7/01/92) 10874 '/122 ' 26" CONDUCTOR @ 289' 18-5/8" @ 982' 13 3/8" @ 3820 9-5/8" @ 10063' 624 PSI CONT RIG REPAIR. CONT TO POOH. CHG BIT & RIH, REAM 10698'- 10752'. DRILL 8-1/2" HOLE F/10752'-10874'. DAY 46-49 (7/02-05/92) 11552'/678' 26" CONDUCTOR @ 289' 18-5/8" @ 982' 13 3/8" @ 3820 9-5/8" @ 10063' 671 PSI DRILL 8-1/2" HOLE F/10874'-11241'. TEST BOPE. MU BIT & BHA, RIH AND DRILLED 8-1/2" HOLE F/11241'-11552'. TOP OF HEMLOCK AT 11473' (~ 173' LOW). DAY 50 (7/06/92) 11707'/155' 26" CONDUCTOR @ 289' 18-5/8" @ 982' 13 3/8" @ 3820 9-5/8" @ 10063' 671 PSI DRILL 8-1/2" HOLE F/11552'-11707'. CHG BHA & BIT. RIH. DAY 51 (7/07/92) 11943'/236' 26" CONDUCTOR @ 289' 18-5/8" @ 982' 13 3/8" @ 3820 9-5/8" @ 10063' 671 PSI RIH. REAM F/11517'-11707'. DRILL 8-1/2" HOLE F/11707'- 11914'. FLUID LOSS 5-7 BPH. SPOT 40 BBL LCM PILL. SHORT TRIP TO CSG SHOE & MONITOR WELL, ZERO FLUID LOSS. RIH & DRILL TO 11943'. RECEIVED SEP I 4 1992 Alaska Oil & Gas Cons. Commission Anchorage DAY 52 (7/08/92) 12021'/78' 26" CONDUCTOR @ 289' 18-5/8" @ 982' 13 3/8" @ 3820 9-5/8" @ 10063' 671 PSI DRILL TO 11960'. POOH TO CSG SHOE & MONITOR WELL. FLUID LOSS 1-2 BPH. POOH. RIH AND REAM F/11788'-11960'. DRILL 8- 1/2" HOLE F/11960'-12021'. DAY 53 (7/09/92) 12142'/121' 26" CONDUCTOR @ 289' 18-5/8" @ 982' 13 3/8" @ 3820 9-5/8" @ 10063' 692 PSI DRILL 8-1/2" HOLE F/12021'-12098'. REAM TIGHT HOLE F/12075'- 12098', ST TO 11328'. RIH & REAM F/11887'-12098' HOLE UNSTABLE F/12060'-12070'. DRILL 8-1/2" HOLE F/12098'-12142' (ROP = 4.4 FPH) . DAY 54-56 (7/10-12/92) 26" CONDUCTOR @ 289' 18-5/8" @ 982' 13 3/8" @ 3820 9-5/8" @ 10063' 692 PSI DRILL 8-1/2" HOLE F/12142'-12163'TD. ST TO CSG SHOE. RIH TO 12153', LOST 10' OF HOLE. POOR HOLE CONDITIONS BELOW 12000'. POOH. RU SCHLUM. RAN LOG RUN #1 (DITE-SDT-SGT-AMS-SP) F/12100'-10052'. RAN LOG RUN #2 (LDT-CNL-MLT-SGT-AMS) F/12100'-10048'. TIGHT HOLE F/RUN #2. MU BHA & RIH TO 11977'. CIRC DN TO 12143'. CBU, LOST HOLE TO 12116'. REAM TO 12143' UNABLE TO KEEP HOLE OPEN BELOW 12116'. POOH. RU SCHLUM. RAN LOG RUN #3 (FMI-SGT). STUCK TOOL AT 10215'. UNABLE TO PULL TOOL LOOSE. MU FISHING BHA & RIH STRIPPING OVER E-LINE. ENGAGE TOF AT 10170'. PULL FISH & E-LINE TO 9988'. PULL E-LINE OUT OF WEAK PT. POOH W/E-LINE. DAY 57 (7/13/92) 12163'TD/12111'ETD 26" CONDUCTOR @ 289' 18-5/8" @ 982' 13 3/8" @ 3820 9-5/8" @ 10063' 692 PSI R£C VF..D SEP 1 4 1992 Alaska 0il & Gas Cons. Commissior~ Anchorage POOH, 100% RECOVERY OF LOGGING TOOL. TEST BOPE. MU C/OUT BHA. RIH TO 11944', WASH DN TO 12045'. C/OUT FILL F/12045'- 12111'. UNABLE TO C/OUT DEEPER. CCM. POOH. LAY DN HWDP. DAY 58 (7/14/92) 12163 'TD/12111'ETD 26" CONDUCTOR @ 289' 18-5/8" @ 982' 13 3/8" @ 3820 9-5/8" @ 10063' 7" L F/9641'-12086' 692 PSI POOH. CHG RAMS TO 7" & TEST. RU & RUN 7" LINER W/HGR & LINER TOP PKR TO 12096'. CCM. M&P 650 SX CMT W/ADDITIVES. DISPL CMT W/MUD & BUMPED PLUG. CIP @ 1955 HRS. ACTIVATE HGR & REL. SET LINER TOP PKR & REV CIRC DP W/8-12 BBL CMT RETURNS. RIG DN CMT EQUIP. PRESS TEST CSG & PKR TO 3000 PSI, OK. POOH. DAY 59 (7/15/92) 12163'TD/12060'ETD 26" CONDUCTOR @ 289' 18-5/8" @ 982' 13 3/8" @ 3820 9-5/8" @ 10063' 7" L F/9641'-12086' 692 PSI POOH, LAY DN EXCESS DP. CHG BOPE RAMS. MU BHA, 6" C/OUT ASSY & RIH PU 3-1/2" DP. RIH, TAGGED TOC AT 11895'. PRESS TEST CSG TO 3500 PSI F/30 MINS, OK. DRILL CMT, LC, FC F/11895'- 12060'. CIRC. PRESS TEST CSG TO 3500 PSI F/10 MINS, OK. POOH. DAY 60 (7/16/92) 12163'TD/12060'ETD 26" CONDUCTOR @ 289' 18-5/8" @ 982' 13 3/8" @ 3820' 9-5/8" @ 10063' 7" L F/9641'-12086' 692 PSI RU SCHLUM. WLIH TO 12040'. RUN CET/CBT/GR IN 7 CSG F/12032'- 9640' TOL. WLOH. CHG SET UP F/9-5/8". RAN SAME LOG IN 9- 5/8" CSG F/9614'-7280'. GYRO WELL F/SURF TO 12030'. RAN SCHLUM SEISMIC VELOCITY SURVEY F/11957'-6082'. LAY DN EXCESS DC. MU TANDEM CSG SCRAPERS & RIH. RECEIVED SEP 1 4 1992 Alaska 0il & Gas Cons. Commission Anchorage DAY 61-63 (7/17-19/92) 26" CONDUCTOR @ 289' 18-5/8" @ 982' 13 3/8" @ 3820' 9-5/8" @ 10063' 7" L F/9641'-12086' 437 PSI RIH TO 12060' ETD. REV CIRC DRLG MUD OUT OF WELLBORE W/FIW. DISPL WELLBORE TO FIW/3% KCL. POOH. LD EXCESS DP. CHG RAMS TO 2-7/8". PU RIH W/433' TCP GUNS. PERM PKR, COMPLETION EQUIP ON 2-7/8" TBG STRING. HYDRO TEST ALL EQUIP TO 5M. CORRELATE GUNS ON DEPTH, LAND TBG & TEST HGR. SET PERM PKR AT 11356' W/3000 PSI, TEST BACKSIDE, OK. INSTALL BPV. REM 13- 5/8" BOPE STACK. INSTALL CIW 3-1/8" 5M VALVE TREE & TEST TO 5000 PSI. RELEASE RIG AT 1800 HRS 7-19-92. DAY 64 (8/3/92) 12163' TD/12060' ETD 9-5/8" C @ 10063' 7" L F/9641'-12086' 437 PSI SKID RIG OVER SLOT #3-11, WELL #50. RESUME WELL OPERATIONS AT 0000 HRS 8/4/92. RECEIVED SEP 1 4 1992_ Alaska 0il & ~as Cons. Commission Anchorage ORIGINAL MICROFIL-M SUB- SURFACE DIRECTIONAL SURVEY UIDANCE r~ ONTINUOUS ~ OOL Company UNOCAL Well Name GRANITE POINT #50 Fieid/L c ..(COND ~/3-11 238§'S & L~J/Z'~- I-KU~ N~ CORNER,SEC 13,[10N,k:12W) 0 ation GRANITE POINT~ KENAI~ ALASKA Job Reference No. Date 92433 16-JULY-92 Loc~cled Bv: Computed By: HAUGAARD R. KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR UNOCAL GRANITE POINT #SO GRANITE POINT KENAI, ALASKA SURVEY DATE' 16-JUL-92 ENGINEER. HAUGAARD METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 55 DEG 0 MIN WEST UNOCAL GRANITE POINT ~50 GRANI~ POINT KENAI, ALASKA COMPUTATION DATE' 17-JUL-92 PAGE I DATE OF SURVEY' 16-JUL-92 KELLY BUSHING ELEVATION' 109.10 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASUEED VERTICAL VERTICAL DEVIATION AZIk~JTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 200 oo 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 0 N 0 0 E -9.10 0 3 N 84 6 W 90.90 0 12 N 60 53 W 190.90 0 46 N 71 2 W 290.87 i 23 N 85 48 W 390.85 I 18 S 87 9 W 490.82 I 22 N 81 48 W 590.79 I 24 S 88 37 W 690.76 I 22 N 79 48 W 790.73 I 28 N 84 34 W 0 O0 -109.10 I 21 N 83 28 W I 21 N 75 4 W 0 58 N 76 27 W I 3 N 62 46 W I 7 N 68 15W I 16 N58 3W 1 12 N 62 28 W i 22 N 54 58 W I 16 N 54 18 W I 22 N 55 7 W 100 O0 200 O0 300 O0 399 97 499 95 599 92 699 89 799.86 899.83 ENGINEER' HAUGAARD 1000.00 999 80 890.70 1100.00 1099 77 990.67 1200.00 1199 75 1090.65 1300.00 1299 74 1190.64 1400.00 1399 72 1290.62 1500.00 1499 70 1390.60 1600.00 1599.67 1490.57 1700.00 1699.65 1590.55 1800.00 1799.62 1690.52 1900.00 1899.60 1790.5.0 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 -0 03 0 07 0 45 I 86 3 82 5 64 7 68 9 40 11 20 0 O0 0 25 0 05 0 51 0 56 0 O0 0 18 0 16 0 28 0 42 0 O0 N 0 06 S 0 06 N 0 41 N 075N 0 67 N 0 75 N 0 97 N I 13 N 153 N 0 O0 E 0 08 E 0 13 W 0 84 W 2 79 W 5 13 W 7 41 W 9 94 W 12 27 W 14 74 W 0 O0 N 0 0 E 0 0 0 2 5 7 9 12 14 10 S 49 57 E 15 N 64 39 W 94 N 63 54 W 89 N 75 3 W 17 N 82 33 W 45 N 84 14 W 98 N 84 25 W 32 N 84 45 W 82 N 84 4 W 13 07 14 65 16 OS 16 97 17 99 18 90 19 89 2O 71 21 55 22 26 0.34 0.20 0.34 0.29 O. 14 0.31 0.20 O. 23 0.46 O. 28 172 N 2 23 N 2 68 N 332N 406N 504N 609 N 7 27 N 852N 9 95 N 17.16 W 19.45 W 21.47 W 23.04 W 24.81W 26.60 W 28.54 W 30.37 W 32.27 W 34.14 W 17.24 N 84 17 W 19.58 N 83 27 W 21.63 N 82 53 W 23.28 N 81 49 W 25 14 N 80 42 W 27 07 N 79 16 W 29 18 N 77 58 W 31 23 N 76 32 W 33 37 N 75 12 W 35 56 N 73 45 W 2000.00 1999.57 1890.47 2100.00 2099.54 1990.44 2200.00 2199.61 2090.41 2300.00 2299.48 2190.38 2400.00 2399.44 2290 34 2500.00 2499.41 2390 31 2600.00 2599.38 2490 28 2700.00 2699.30 2590 20 2800.00 2799.10 2690 O0 2900.00 2898.74 2769 64 I 20 N 49 31W I 26 N 60 20 W I 27 N 44 19 W I 26 N 46 15 W I 32 N 42 45 W 1 18 N 43 8 W 1 44 N 80 0 W 2 54 S 77 43 W 4 13 S 72 43 W 5 25 S 69 47 W 23 O0 23 59 24 10 24 60 24 96 25 35 26.32 29.80 35.66 43.75 0 45 0 36 0 3O 0 43 0 10 0 22 1 86 I 38 I 29 I 17 11.30 N 12.95 N 14.60 N 16.39 N 18.27 N 20.08 N 21.32 N 20.92 N 19.29 N 16.52 N 35.99 W 37.87 W 39.65 W 41.51W 43.26 W 45.01W 47.06 W 51.03 W 57.05 W 64.98 W 37 73 N 72 34 W 40 02 N 71 7 W 42 25 N 69 47 W 44 63 N 68 27 W 46 96 N 67 7 W 49 29 N 65 57 W 51.66 N 65 37 W 55.15 N 67 43 W 60.22 N 71 19 W 67.05 N 75 44 W 3000.00 2998.20 2889 10 3100.00 3097.46 2988 3200.00 3196.45 3087 3300.00 3295.10 3186 3400 O0 3393 62 3264 3500 O0 3492 08 3382 3600 O0 3590 20 3481 3700 O0 3687 67 3578 3800 3900 6 29 36 7 33 35 8 46 O0 9 55 52 9 48 98 10 27 10 11 49 57 14 13 O0 3784 04 3674.94 16 31 O0 3879 78 3770.68 16 52 S 71 12 W S 74 4W S 76 39 W S78 9W S 75 37 W S 74 52 W S77 2W S 80 15 W S81 58W S 82 49 W 53 75 65 37 78 63 93 71 109 60 126 03 144 02 164 46 188 36 214 02 1.08 1.16 I .35 O. 48 0 65 1 O7 1 86 3 17 0 99 0 52 13.04 N 9 39 N 5 2 1 6 10 15 19 22 86 85 N 100 34 N 116 46 S 132 02 S 149 73 S 168 09 S 190 14 S 216 99 S 245 38 W 86 08 W 100 03 W 116 77 W 132 63 W 149 30 W 168 20 W 190 54 W 217 17 W 246 74 75 W 75 88 N 80 6 W 89 N 83 48 W 25 N 86 39 W 06 N 88 51W 78 S 89 22 W 76 S 87 42 W 64 S 86 21W 80 S 85 28 W 38 S 84 57 W 25 S 84 39 W UNOCAL GR~J~ITE POINT ~50 GR~NIT~ POINT KENAI, ALASKA COMPUTATION DATE' 17-JUL-92 PAGE 2 DATE OF SURVEY' 16-JUL-92 KELLY BUSHING ELEVATION' 109.10 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASL~ED VERTICAL VERTICAL DEVIATION AZI~JTH DEPTH DEPTH DEPTH DEG MIN DEG MIN S 83 23 W 47 16 0 S 84 9 W 71 15 31 S 84 50 W 14 15 12 S 85 57 W 71 14 52 S 87 11W 42 14 34 S 88 17 W 33 14 5 S 89 54 W 41 13 40 N 89 5 W 65 13 18 N 87 49 W N 86 54 W 4000 O0 3975 56 3866 46 16 31 4100 4200 4300 4400 4500 4600 4700 4800 4900 57 3962 81 4058 24 4156 81 4251 52 4348 43 4445 51 4542 75 4639 O0 4071 O0 4167 O0 4264 O0 4360 O0 4457 O0 4554 O0 4651 O0 4748 O0 4846 N 86 7 W N 85 31 W N 84 31 W N 83 lOW N 81 47 W N 84 15 W N 89 22 W S 86 43 W S 85 45 W S 84 55 W 13 4737.03 13 4 5000 O0 4943 56 4834.46 12 56 5100 5200 5300 5400 5500 5600 5700 5800 5900 ENGINEER' HAUGAARD O0 5041 07 4931.97 12 41 O0 5138 65 5029.55 12 35 O0 5236 29 5127.19 12 21 O0 5334 O0 5224.90 12 11 O0 5431 70 5322.60 12 33 O0 5529 22 5420.12 12 57 O0 5626.63 5517.53 13 9 O0 5723.94 5614.84 13 31 O0 5821.05 5711.95 14 5 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 239 35 263 89 287 54 310 38 332 49 353 89 374 34 393 89 412 61 430 64 0.49 0 39 0 53 0 47 0 44 0 84 0 49 0 52 0 50 0 27 26 43 S 273 69 W 274.96 S 84 29 W 29 32 34 35 36 37 37 36 35 48 S 301 10 S 328 24 S 354 80 S 380 83 S 406 20 S 430 03 S 454 41S 478 35 S 500 51W 302.94 S 84 25 W 54 W 330.11 S 84 25 W 93 W 356.58 S 84 29 W 82 W 382.50 S 84 38 W 24 W 407.90 S 84 49 W 93 W 432.53 S 85 4 W 92 W 456.42 S 85 21 W 21 W 479.60 S 85 39 W 96 W 502.21 S 85 58 W 448.24 465.42 482.20 498.48 514 12 529 92 547 23 566 09 585 84 606 42 0.24 0 23 0 33 0 47 0 32 1 08 I 33 0 73 0 49 0 55 33 96 S 523 42 W 524.52 S 86 17 W 32 30 28 25 22 21 21 23 25 35 S 545 46 S 567 15 S 588 34 S 609 63 S 631 34 S 653 93 S 675 52 S 698 53 W 546.49 S 86 36 W 33 W 568.15 S 86 56 W 82 W 589.49 S 87 16 W 88 W 610.41 S 87 37 W 06 W 631.47 S 87 57 W 11W 653.46 S 88 8 W 71W 676.07 S 88 8 W 71W 699.11 S 88 4 W 47 S 722.47 W 722.92 S 87 59 W 6000.00 5918.00 5808.90 14 19 6100.00 6014.78 6905.68 14 46 6200.00 6111.43 6002.33 14 58 6300.00 6208.08 6098.98 14 48 6400.00 6304.76 6195.66 14 51 6500.00 6401.44 6292.34 14 46 6600.00 6498.13 6389.03 14 48 6700.00 6594,80 6485.70 14 51 6800.00 6691.48 6582.38 14 46 6900.00 6788.18 6679.08 14 42 S 84 55 W 627.70 S 84 53 W 649.62 S 84 8 W 671.82 S 83 57 W 694.30 S 84 48 W 716.57 S 85 31 W 738.66 S 86 7 W 760.60 S 87 7 W 782.37 S 88 47 W 803.84 N 88 51W 824.71 0.48 0.20 O. 40 0.28 0.17 0.04 0.30 0.31 0.56 0.58 27.65 S 746.91 W 747 42 S 87 53 W 29.92 S 771.97 W 772 32.31 S 797.52 W 798 35.06 S 823.03 W 823 37.56 S 848.47 W 849 39.71 S 873.93 W 874 41.58 S 899.40 W 900 43.11 S 924.92 W 925 44.04 S 950.47 W 951 55 S 87 47 W 18 S 87 41W 77 S 87 34 W 30 S 87 28 W 84 S 87 24 W 36 S 87 21W 92 S 87 20 W 49 S 87 21W 44.08 S 975.93 W 976.92 S 87 25 W 7000 O0 6884.93 6775.83 14 37 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 6981.72 6872.62 14 29 O0 7078.55 6969.45 14 26 O0 7175.42 7066.32 14 14 O0 7272.43 7163.33 13 55 O0 7369.51 7250.41 13 59 O0 7466.34 7357.24 14 57 O0 7562.82 7453.72 15 24 O0 7659.30 7550.20 15 6 O0 7755.89 7646.79 14 58 N87 31 W N 86 10 W N85 lOW N83 2W N 79 49 W N78 1W N 81 16 W N 84 13 W N 85 12 W N 87 43 W 1014 844 96 864 69 884 01 902 80 920 40 936 93 954 41 973 94 994 01 16 0.35 0 38 0 36 0 94 0 73 0 95 I 33 0 45 O. 33 1.48 43.24 S 1001 23 W 1002.16 S 87 32 W 41 83 S 1026 39 37 33 29 24 21 18 17 93 S 1051 44 S 1075 84 S 1099 10 S 1123 52 S 1147 30 S 1174 88 S 1200 13 S 1226 30 W 1027 15 S 87 40 W 22 W 1051 90 W 1076 91W 1100 40 W 1123 95 W 1148 05 W 1174 25 W 1200 06 W 1226 98 S 87 49 W 55 S 88 0 W 43 S 88 14 W 78 S 88 31W 21 S 88 47 W 24 S 88 58 W 40 S 89 6 W 18 S 89 12 W COMPUTATION DATE' 17-JUL-92 PAGE 3 UNOCAL GRANITE POINT GRANITE POINT KENAI, ALASKA DATE OF SURVEY' 16-JUL-92 KELLY BUSHING ELEVATION' 109.10 FT ENGINEEE' HAUGAARD INTERPOLATED VALUES FOR EVEN 1OO FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION ^ZIk(UTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPAR'IURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 7852 42 7743 32 15 19 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 7948 O0 8044 O0 8141 O0 8237 O0 8334 O0 8429 O0 8525 O0 8620 O0 6715 77 7839 92 7935 07 8031 54 8128 13 8225 98 8320 15 8416 30 8511 67 15 48 82 16 1 97 15 43 44 14 55 03 15 24 88 17 37 05 17 55 20 18 6 38 8606.28 17 50 S 85 3 W 1035.84 S 76 31 W 1059.94 S 68 20 W 1086.12 S 60 54 W 1113.20 S 56 41 W 1139.49 S 51 12 W 1165.34 S 42 18 W 1193.51 S 32 39 W 1222.72 S 22 26 W 1249,94 S 12 21W 1274.55 2 53 2 50 2 93 I 90 I 13 2 41 3 56 2 58 2 79 4 01 17 66 S 1252 16 W 1252.28 S 89 12 W 21 3O 42 55 70 90 114 142 171 98 S 1278 24 S 1304 13 S 1329 81S 1351 98 S 1372 42 S 1393 78 S 1412 04 S 1426 49 S 1435 56 W 1278.75 S 89 1 W 73 W 1305.09 S 88 40 W 46 W 1330.13 S 88 11 W 98 W 1353.13 S 87 38 W 92 W 1374.75 S 87 2 W 69 W 1396.62 S 86 17 W 30 W 1416.96 S 85 21W 43 W 1433.49 S 84 19 W 86 W 1446.06 S 83 11 W 9000 O0 8810 73 8701.63 17 22 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 8906 O0 9001 O0 9095 O0 9190 O0 9284 O0 9379 O0 9473 O0 9567 O0 9661 20 8797.10 17 25 32 8892.22 18 31 99 8986 89 18 56 56 9081 46 19 4 99 9175 89 19 19 29 9270 19 19 37 41 9364 31 19 45 47 9458 37 19 59 44 9552 34 19 48 S I 39 E 1293 95 S 10 51 E 1308 31 S 21 34 E 1318 04 S 29 44 E 1323 18 S 36 27 E 1324 11 S 40 39 E 1322 09 S 45 31 E 1317.42 S 48 18 E 1310.28 S 49 54 E 1301.95 S 51 11 E 1292.84 2 91 3 54 3 10 2 58 I 48 I 50 I 39 I 08 0 59 I 17 201.41 S 1438 59 W 1452 62 S 82 2 W 230.96 S 1435 260.45 S 1426 289.43 S 1412 315 55 S 1394 342 28 S 1374 366 59 S 1351 389 54 S 1326 411 74 S 1301 433 51S 1274 43 W 1453 66 W 1450 65 W 1441 78 W 1430 31W 1416 59 W 1400 79 W 1382 08 W 1364 73 W 1346 89 S 8O 52 W 24 S 79 39 W 99 S 78 25 W 26 S 77 13 W 29 S 76 I W 42 S 74 49 W 79 S 73 38 W 68 S 72 26 W 42 S 71 13 W 10000.00 9755 95 9646.85 18 15 10100.00 9851 10200.00 9947 10300.00 10043 10400.00 10139 10500.00 10235 10600.00 10330 10700.00 10426 10800.00 10522 10900.00 10618.72 10509 38 9742.28 16 26 52 9838.42 15 43 78 9934 68 15 49 86 10030 76 16 26 53 10126 43 17 26 96 10221 86 17 19 51 10317 41 16 51 50 10413 40 15 50 62 15 45 S 53 39 E 1283 11 S 55 0 E 1273 22 S 56 22 E 1263 48 S 56 22 E 1253 62 S 57 9 E 1243 37 S 59 27 E 1231 92 S 60 6 E 1219 33 S 60 10 E 1206.83 S 61 12 E 1194.71 S 61 55 E 1182.52 I 73 i 87 0 26 0 53 0 87 0 96 0 07 0 96 0 62 0 42 453 46 S 1248.87 W 1328 64 S 70 3 W 470 486 501 516 531 546 561 575 588 86 S 1224.61 W 1312 37 S 1201.87 W 1296 37 S 1179.32 W 1281 61 S 1156.14 W 1266 94 S 1131.43 W 1250 94 S 1105.56 W 1233 63 S 1080.00 W 1217 39 S 1055.57 W 1202 35 S 1031.63 W 1187 01 S 68 58 W 55 S 67 58 W 47 S 66 58 W 31 S 65 55 W 24 S 64 49 W 45 S 63 41 W 31 S 62 31 W 21 S 61 24 W 61 S 60 18 W 11000.00 10714.90 10605.80 16 9 11100.00 10811.00 10701.90 16 1 11200.00 10907.02 10797.92 16 29 11300.00 11002 93 10893.83 16 16 11400.00 11098 94 10989.84 16 20 11500.00 11194 77 11085.67 16 59 11600.00 11290 OS 11180.95 18 21 11700.00 11384 57 11275.47 19 47 11800.00 11478 39 11369.29 20 35 11900.00 11571 97 11462.87 20 39 S 63 14 E 1169.86 S 65 9 E 1156.37 S 66 48 E 1141.94 S 66 27 E 1127.07 S 66 18 E 1112.65 S 66 45 E 1097.63 S 66 29 E 1081.69 S 65 34 E 1064.85 S 63 55 E 1047.64 S 62 40 E 1031.02 0.47 O. 60 O. 57 0.52 0.46 I. 37 I .43 I .36 O. 93 0.38 600.99 S 1007.32 W 1172.98 S 59 11 W 613.01S 982.43 W 1157.99 S 58 2 W 624.33 S 956.89 W 1142.55 S 56 53 W 635.53 S 930.90 W 1127,15 S 55 41 W 646.77 S 905.30 W 1112.60 S 54 27 W 658.18 S 879.10 W 1098.19 S 53 11W 670.19 S 851.23 W 1083.40 S 51 47 W 683.42 S 821.40 W 1068.54 S 50 14 W 698.15 S 790.08 W 1054.34 S 48 32 W 714.09 S 758.64 W 1041.85 S 46 44 W COMPUTATION DATE: 17-JUL-92 PAGE 4 UNOCAL GRANITE POINT #50 GRANITE POINT KENAI, ALASKA DATE OF SURVEY: 16-JUL-92 KELLY BUSHING ELEVATION: 109.10 FT ENGINEER: HAUGAARD INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SI..,I~-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 12000.00 11665.51 11556.41 20 46 S 62 49 E 1014.53 12100.00 11769.05 11649.95 20 40 S 63 5 E 997.93 12145.00 11801.15 11692.05 20 40 S 63 6 E 990.45 O. 50 0. O0 0. O0 730.27 S 727.18 W 1030.57 S 44 53 W 746.30 S 695.68 W 1020.26 S 42 59 W 753.49 S 681.52 W 1015.98 S 42 8 W COMPUTATION DATE: 17-JUL-92 PAGE 5 UNOCAL GRANITE POINT #~0 GRANI~ POINT KENAI, ALASKA DATE OF SURVEY: 16-JUL-92 KELLY BUSHING ELEVATION: 109.10 FT ENGINEER: HAUGAARD INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5OOO 6000 7000 8000 9000 0.00 -109 10 O0 999.80 890 O0 1999.57 1890 O0 2998.20 2889 O0 3975.56 3866 O0 4943.56 4834 O0 5918.00 5808 O0 6884.93 6775 O0 7852.42 7743 O0 8810.73 8701 0 0 N 0 0 E 70 1 21 N 83 28 W 47 I 20 N 49 31 W 10 6 29 S 71 12 W 46 16 31 S 83 23 W 46 12 S6 N 86 7 W 90 14 19 S 84 55 W 83 14 37 N 87 31 W 32 15 19 63 17 22 0 O0 13 07 23 O0 53 75 239 35 448 24 627 70 844.96 S 85 3 W 1035.84 S I 39 E 1293.95 0. O0 0.34 0.45 I. 08 0.49 0.24 0.48 0.35 2.53 2.91 0 O0 N 1 11 13 26 33 27 43 17 201 0 O0 E 72 N 17 30 N 35 04 N 74 43 S 273 96 S 523 65 S 746 24 S 1001 66 S 1252 41S 1438 0 O0 N 0 0 E 16 W 17 99 W 37 75 W 75 69 W 274 42 W 524 91W 747 23 W 1002 16 W 1252 59 W 1452 24 N 84 17 W 73 N 72 34 W 88 N 80 6 W 96 S 84 29 W 52 S 86 17 W 42 S 87 53 W 16 S 87 32 W 28 S 89 12 W 62 S 82 2 W 10000.00 9765.96 9646.85 18 15 11000.00 10714.90 10605.80 16 9 12000.00 11665.61 11556.41 20 46 12145.00 11801.15 11692.06 20 40 S 53 39 E 1283.11 S 63 14 E 1169.86 S 62 49 E 1014.53 S 63 5 E 990.45 I .73 0.47 0.50 0.00 453.46 S 1248.87 W 1328.64 S 70 3 W 600.99 S 1007,32 W 1172.98 S 59 11 W 730.27 S 727,18 W 1030.57 S 44 53 W 753.49 S 681,52 W 1015.98 S 42 8 W COMPUTATION DATE' 17-JUL-92 PAGE UNOCAL GRANITE POINT #50 GRANITE POINT KENAI, ALASKA DATE OF SURVEY' 16-JUL-92 KELLY BUSHING ELEVATION' 109.10 FT ENGINEER' HAUGAARD INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 109 10 209 10 309 11 409 13 509 15 609 18 709 21 809 24 909 27 0 O0 -109.10 109 209 309 409 509 609 709 809 909 0 0 N 0 OE 10 0.00 0 5 N 72 44 W 10 100.00 0 14 N 51 50 W 10 200.00 0 49 N 72 59 W 10 300.00 I 23 N 87 45 W 10 400.00 1 18 S 87 26 W 10 500.00 1 23 N 81 30 W 10 600.00 I 22 S 89 19 W 10 700.00 I 23 N 78 51 W 10 800.00 I 27 N 85 38 W 0 O0 -0 02 0 08 0 53 2 03 3 99 5 80 7 77 9 56 11 37 0 O0 0 26 0 23 0 76 0 54 0 O0 0 18 0 32 0 18 0 43 0 O0 N 006S 0 09 N 0 45 N 0 76N 0 66 N 0 78 N 0 97N I 16 N 1 56N 000 E 0 07 E 0 16 W 0 96 W 3 01W 5 34 W 7 63W 10 16 W 12 48 W 14 97 W 000 N 0 OE 0 0 1 3 5 7 10 12 15 09 S 47 11 E 18 N 62 10 W 06 N 64 47 W 11 N 75 54 W 38 N 82 57 W 67 N 84 9 W 20 N 84 33 W 54 N 84 41 W 05 N 84 4 W 1009 30 1009 10 1109 1209 1309 1409 1509 1609 1709 1809 1909 900.00 1 21 N 82 30 W 10 1000.00 1 21 N 75 38 W 10 1100.00 0 57 N 75 30 W 10 1200.00 I 5 N 63 23 W 10 1300.00 1 7 N 67 30 W 10 1400.00 1 18 N 58 46 W 10 1500.00 1 11 N 61 54 W 10 1600.00 I 22 N 55 42 W 10 1700.00 1 16 N 62 44 W 10 1800.00 I 20 N 55 36 W 33 1109 35 1209 36 1309 38 1409 40 1509 43 1609 45 1709 48 1809 51 1909 13 23 14 79 16 15 17 05 18 09 18 98 19 98 20 78 21 62 22 34 0 47 0 29 0 24 0 33 0 15 0 31 0 13 0 17 0 58 0 24 1.74 N 2.29 N 2.72 N 3.40 N 4.13 N 5.15 N 6.18 N 7.40 N 8.64 N 10.08 N 17 37 W 19 66 W 21 62 W 23 19 W 24 98 W 26 78 W 28 72 W 30 55 W 32 44 W 34 33 W 17.46 N 84 17 W 19.80 N 83 22 W 21.79 N 82 50 W 23.44 N 81 40 W 25.32 N 80 37 W 27.27 N 79 7 W 29.37 N 77 52 W 31.44 N 76 23 W 33.57 N 75 5 W 35.78 N 73 38 W 2009 53 2009 10 1900 O0 2109 2209 2309 2409 2509 2609 2709 2810 2910 56 2109 69 2209 63 2309 66 2409 69 2509 72 2609 81 27O9 03 2809 40 2909 10 2000 10 2~00 10 2200 10 2300 10 2400 10 2500 10 2600 10 2700 10 2800 O0 O0 O0 O0 O0 O0 O0 O0 O0 I 22 N 48 10 W I 24 N 50 39 W I 29 N 44 34 W 1 25 N 45 30 W I 32 N 43 7 W I 16 N 42 38 W 1 50 N 85 6 W 3 2 S77 OW 4 21 S 72 10 W S 32 S 69 48 W 23 06 23 66 24 14 24 65 25 O0 25 38 26 51 30 25 36 36 44 70 0 46 0 47 0 33 0 51 0 06 0 O2 I 91 ! 45 1 28 1 19 11 45 N 13 10 N 14 78 N 16 56 N 18 45 N 20 25 N 21 38 N 20 81N 19 08 N 16 18 N 36 16 W 38 06 W 39 82 W 41 69 W 43 44 W 45 16 W 47 33 W 51 50 W 57 75 W 65 90 W 37 93 N 72 26 W 40 42 44 47 49 51 55 60 67 25 N 71 0 W 47 N 69 39 W 86 N 68 20 W 19 N 66 59 W 49 N 65 51 W 94 N 65 42 W 55 N 68 0 W 82 N 71 43 W 85 N 76 12 W 3010.97 3009.10 2900.00 3111.75 3109 10 3000.00 3212.80 3209 3314.21 3309 3415 71 3409 3517 32 3509 3619 30 3609 3722 14 3709 3826 16 3809 3930 64 3909 6 36 7 40 10 3100.00 8 56 10 3200 O0 9 58 10 3300 O0 9 49 10 3400 O0 10 39 10 3500 O0 12 8 10 3600 O0 14 51 10 3700 O0 16 44 10 3800.00 16 45 S 71 26 W S 74 27 W S 76 56 W S 78 9 W S 76 4 W S 75 4 W S 77 41 W S 80 48 W S82 8W S83 5W 54.94 66.83 80.45 95.96 112.11 129.02 147.67 169.47 195.04 221.86 1 O4 1 11 I 43 0 11 0 52 I 17 2 O8 3 o7 0 81 0 36 12 64 N 8 5 1 2 6 11 16 20.18 S 223 24.08 S 253 75 92 W 97 N 87 40 N 101 83 N 118 13 S 135 84 S 152 62 S 172 01S 195 76 96 N 80 33 W 87 W 88 99 W 102 43 W 118 36 W 135 71W 152 14 W 172 67 W 196 97 W 224 97 W 255 33 N 84 10 W 13 N 86 58 W 44 N 89 7 W 38 S 89 6 W 86 S 87 26 W 53 S 86 8 W 32 S 85 19 W 88 S 84 51W 11 S 84 35 W UNOCAL GRANITE POINT #50 GRANITE POINT KENAI, ALASKA COMPUTATION DATE: 17-JUL-92 PAGE 7 DATE OF SURVEY: 16-JUL-92 KELLY BUSHING ELEVATION: 109.10 FT ENGINEER: HAUGAARD INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 4034 96 4009.10 3900.00 16 20 S 83 38 W 248.03 4139 4242 4346 4449 4553 4656 4759 4861 4964 03 4109.10 4000.00 15 49 S 84 22 W 273.21 84 4209,10 4100.00 15 23 S 85 17 W 297.42 47 4309 10 4200 O0 15 2 S 86 32 W 320.75 95 4409 10 4300 O0 14 46 S 87 40 W 343.27 25 4509 10 4400 O0 14 16 S 89 12 W 364.90 34 4609 10 4500 O0 13 51 N 89 32 W 385.46 24 4709 10 4600 O0 13 26 N 88 22 W 405,08 99 4809 10 4700 O0 13 8 N 87 14 W 423.65 64 4909 10 4800 O0 12 69 N 86 19 W 442.06 0 64 0 50 0 38 0 47 0 21 0 59 0 50 0 43 0 31 0 20 5067 22 5009 10 4900 O0 12 46 N 85 45 W 459 84 5169 6272 5374 5476 5579 5682 5784 5887 6990 72 5109 17 5209 52 5309 85 5409 35 5509 O0 5609 74 5709 68 5809 81 6909 10 5000 O0 12 38 N 84 $3 W 477 10 6100 O0 12 26 N 83 38 W 494 10 5200 O0 12 13 N 82 0 W 610 10 5300 O0 12 25 N 83 19 W 526 10 5400 O0 12 53 N 88 9 W 543 10 5500 O0 13 7 S 87 14 W 562 10 5600.00 13 27 S 85 50 W 582 10 5700.00 14 I S 85 0 W 603 10 5800.00 14 16 S 84 56 W 625 16 02 18 12 52 62 78 84 72 0 28 0 33 0 52 0 31 I 15 1 39 0 78 0 36 0 58 0 44 6094 13 6009 10 5900.00 14 45 S 84 52 W 648 22 6197 59 6109 6301 05 6209 6404 49 6309 6507 92 6409 6611 35 6509 6714 79 6609 6818.22 6709 6921.62 6809 7024.98 6909 10 6000.00 14 58 S 84 10 W 671 10 6100.00 14 48 S 83 58 W 694 10 6200.00 14 51 S 84 50 W 717 10 6300.00 14 46 S 85 34 W 740 10 6400.00 14 48 S 86 13 W 763 10 6500.00 14 SO S 87 19 W 785 10 6600.00 14 46 S 89 10 W 807 10 6700.00 14 41 N 88 28 W 829 10 6800.00 14 35 N 87 8 W 849 28 63 56 40 08 67 70 13 95 0 24 0 4O 0 28 0 17 0 07 0 35 0 34 0 60 0 44 0 51 7128 28 7009.10 6900.00 14 29 N 85 51 W 870 18 7231 7334 7437 7540 7644 7747 7851 7955 8058 55 7109.10 7000.00 14 24 N 84 46 W 890 73 7209.10 7100.00 14 5 N 81 54 W 909 77 7309.10 7200.00 13 49 N 78 43 W 926 83 7409.10 7300.00 14 23 N 78 59 W 943 29 7509.10 7400.00 15 17 N 82 56 W 962 98 7609.10 7500.00 15 16 N 84 43 W 983 57 7709.10 7600.00 14 57 N 85 52 W 1004 10 7809.10 7700.00 15 11 S 88 40 W 1025 80 7909.10 7800.00 16 34 S 79 56 W 1049 03 06 72 82 85 59 33 82 71 0 32 0 4O 0 92 0 75 I 51 I 14 0 46 0 65 I 84 2 13 FEET FEET FEET DEG MIN 27 54 S 283 50 W 284 84 S 84 27 W 30 33 35 36 37 37 36 35 34 55 S 312 09 S 339 03 S 367 38 S 393 11S 419 16 S 444 73 S 468 79 S 492 49 S 515 14 W 313 91W 341 03 W 368 58 W 395 48 W 421 54 W 446 79 W 470 36 W 493 51W 516 63 S 84 25 W 52 S 84 26 W 70 S 84 33 W 26 S 84 43 W 12 S 84 57 W 09 S 85 13 W 23 S 85 31W 66 S 85 51W 66 S 86 10 W 32 90 S 538 32 W 539 32 S 86 30 W 31 28 26 23 21 21 23 25 27 07 S 560 84 S 582 10 S 604 15 S 626 45 S 648 73 S 671 26 S 695 21S 719 45 S 744 75 W 561 89 W 583 54 W 605 07 W 626 50 W 648 62 W 671 15 W 695 50 W 719 64 W 746 61 S 86 50 W 60 S 87 10 W 11 S 87 32 W 50 S 87 53 W 85 S 88 6 W 97 S 88 9 W 54 S 88 5 W 94 S 88 0 W 15 S 87 53 W 29.78 S 770 48 W 771 05 $ 87 47 W 32.24 S 796 35.09 S 823 37.67 S 849 39.86 S 875 41.78 S 902 43.28 S 928 44.14 S 955 43.94 S 981 42.95 S 1007 90 W 797 29 W 824 61W 850 95 W 876 29 W 9O3 70 W 929 11W 956 41W 982 52 W 1008 56 S 87 41W 04 S 87 34 W 45 S 87 28 W 85 S 87 24 W 26 S 87 21W 71 S 87 20 W 13 S 87 21W 39 S 87 26 W 44 S 87 34 W 41 34 S 1033.35 W 1034 18 S 87 43 W 39 36 32 27 22 20 17 17 19 24 S 1059.05 W 1059 33 S 1084.32 W 1084 15 S 1108.80 W 1109 11 S 1133.20 W 1133 92 S 1159.38 W 1159 08 S 1186.68 W 1186 82 S 1213.58 W 1213 02 S 1240.38 W 1240 70 S 1267.66 W 1267 78 S 87 53 W 93 S 88 5 W 27 S 88 20 W 53 S 88 38 W 60 S 88 52 W 85 S 89 2 W 71 S 89 10 W 50 S 89 13 W 81 S 89 7 W COMPUTATION DATE' 17-JUL-92 PAGE 8 UNOCAL GRANITE POINT #50 GRANITE POINT KENAI, ALASKA DATE OF SURVEY' 16-JUL-92 KELLY BUSHING ELEVATION' 109.10 FT ENGINEER' HAUGAARD INTERPOLATB) V~LUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZI~JTH DEPTH DEPTH DEPTH DEG M[N DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8162.74 8009 10 7900 O0 16 0 8266.77 8109 8370.56 8209 8474.06 8309 8578.11 8409 8683.13 8509 8788.22 8609 8893.41 8709 8998.30 8809 9103.05 8909 10 8000 O0 15 66 10 8100 O0 15 6 10 8200 O0 15 3 10 8300 O0 17 15 10 8400 O0 17 58 10 8500 O0 18 2 10 8600 O0 17 53 10 8700.00 17 22 10 8800.00 17 26 S 71 42 W 1076 20 S 62 50 W 1104 S 57 53 W 1131 S 52 48 W 1158 S 44 39 W 1187 S 34 11W 1217 S 23 31W 1246 S 13 15 W 1273 S I 27 E 1293 S 11 14 E 1308 20 89 54 07 88 84 11 66 66 2 O0 1 72 1 44 2 02 4 05 2 61 3 01 3 89 3 03 3 63 26 72 S 1295.09 W 1295 37 S 88 49 W 37 51 66 85 110 138 169 200 231 88 S 1321.45 W 1322 68 S 1345.59 W 1346 80 S 1367 54 W 1369 59 S 1389 21W 1391 47 S 1409 41W 1413 68 S 1425 01W 1431 52 S 1435 48 W 1445 90 S 1438 59 W 1452 85 S 1435 24 W 1453 O0 S 88 21W 58 S 87 48 W 17 S 87 12 W 85 S 86 28 W 74 S 85 31W 74 S 84 26 W 46 S 83 16 W 56 S 82 3 W 84 S 80 49 W 9208.20 9009 10 8900.00 18 36 9313.86 9109 9419.62 9209 9526.55 9309 9631.65 9409 9737.93 9509 9844.31 96O9 9950.56 97O9 10055.81 9809 10160.08 9909 10 9000.00 18 55 10 9100.00 19 8 10 9200.00 19 23 10 9300.00 19 42 10 9400.00 19 48 10 9500.00 20 4 10 9600.00 19 6 10 9700.00 17 18 10 9800.00 15 49 S 22 18 E 1318.68 S 30 54 E 1323.55 S 37 19 E 1323.89 S 41 48 E 1321.18 S 46 47 E 1315.37 S 49 1 E 1307.24 S $0 21 E 1297.99 S 52 21 E 1288.00 S 54 27 E 1277.54 S 56 1 E 1267.40 3 16 2 89 1 53 1 55 I 63 0 54 0 32 2 13 2 14 0 45 262 87 S 1425 75 W 1449 78 S 79 33 W 293 321 348 373 398 421 443 463 480 31S 1410 69 S 1390 65 S 1368 98 S 1343 02 S 1317 47 S 1289 97 S 1261 46 S 1235 33 S 1210 38 W 1440 92 W 1427 73 W 1412 91W 1394 15 W 1375 44 W 1356 49 W 1337 07 W 1319 88 W 1302 56 S 78 15 W 64 S 76 59 W 44 S 75 43 W 97 S 74 27 W 97 S 73 11W 57 S 71 54 W 33 S 70 37 W 16 S 69 26 W 67 S 68 22 W 10263 96 10009 10 9900.00 15 42 10367 10472 1O577 10681 10786 10890 10993 11098 11202 95 10109 32 10209 10 10309 79 10409 07 10509 O0 10609 97 10709 O2 1O8O9 17 10909 10 10000.00 16 11 10 10100.00 17 10 10 10200 O0 17 21 10 10300 O0 16 59 10 10400 O0 15 52 10 10500 O0 15 46 10 10600 O0 16 8 10 10700 O0 16 1 10 10800 O0 16 30 S 56 21E 1257.18 S 56 46 E 1246.75 S 58 43 E 1235.25 S 60 5 E 1222.22 S 60 7 E 1209.08 S 61 2 E 1196.39 S 61 50 E 1183.75 S 63 9 E 1170.64 S 65 6 E 1156.64 S 66 49 E 1141.52 0.39 0.86 1.42 0.05 0.77 0.77 0.38 O. 52 0.59 O. $5 495.95 S 1187 47 W 1286 87 S 67 20 W 511.69 S 1163 527.71S 1138 543.53 S 1111 558.99 S 1084 573.56 S 1058 587.07 S 1034 600.23 S 1008 612.78 S 982 71 W 1271 24 S 66 16 W 45 W 1254 81 S 65 8 W 47 W 1237 25 S 63 56 W 61 W 1220 18 S 62 44 W 91 W 1204 27 S 61 33 W 03 W 1189.06 S 60 25 W 80 W 1173.87 S 59 15 W 92 W 1158.29 S 58 4 W 624.58 S 956.33 W 1142.21 S 56 51 W 11306.43 11009.10 10900.00 16 15 11410.58 11109.10 11000.00 16 23 11515.00 11209 10 11100.00 17 11 11620 07 11309 10 11200.00 18 38 11725 10 11409 10 11300.00 20 4 11832 81 11509 10 11400.00 20 39 11939 68 11609 10 11500.00 20 41 12046 62 11709 10 11600.00 20 40 12145 O0 11801 15 11692.05 20 40 S 66 24 E 1126.14 S 66 19 E 1111.01 S 66 47 E 1095.30 S 66 21 E 1078.39 S 65 14 E 1060.34 S 63 15 E 1042.11 S 62 47 E 1024.52 S 63 5 E 1006.80 S 63 5 E 990.45 0 43 0 51 1 31 1 38 1 08 0 60 0 50 0 O0 0. O0 636.25 S 929.25 W 1126.20 S 55 36 W 647.97 S 902 58 W 1111.09 S 54 20 W 659.93 S 875 03 W 1095.98 S 52 59 W 672.72 S 845 42 W 1080.41 S 51 29 W 687.15 S 813 29 W 1064.72 S 49 48 W 703.29 S 779 74 W 1050.05 S 47 57 W 720.51 S 746 19 W 1037.28 S 46 0 W 737.77 S 712 48 W 1025.64 S 44 0 W 753.49 S 681 52 W 1015.98 S 42 8 W DIRECTIONAL SURVEY ~C)MPANY FIELD COUNTRY RUN DATE LOQQED OEPTH UNIT UNOCAL GRANITE POINT GRANITE POINT ~1i50 USA ONE 16 . JUL - 92 FEET 92433 COMPUTATION DATE: 17-JUL-92 PAGE 9 UNOCAL GRANITE POINT ~50 GRANITE POINT KENAI, /~_ASKI MARKER 13.375" CASING 9.625" CASING LAST READING GCT -7# CASING DRILLERS TD DATE OF SURVEY: 16-JUL-92 KFIIy BUSHING ELEVATION: 109.10 FT ENGINEER: HAUGAARD INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = COND #3-11 2386'S & 1372'E, SEC13 TiON R12W MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3817.00 10063.00 12022.90 12086.00 12145.00 3800.33 3691.23 9815.96 9706.86 11686.91 11577.81 11745.95 11636.85 11801.15 11692.0S 19.82 S 221.37 W 464.70 S 1233.33 W 733.98 S 719.95 W 744.06 S 700.09 W 753.49 S 681.52 W COMPUTATION DATE: 17-JUL-92 PAGE lO . UNOCAL GRANITE POINT #50 GRANITE POINT KENAI, ALASKA MARKER 13.375" CASING 9.625" CASING LAST READING GCT 7" CASING DRILLERS TD DATE OF SURVEY' 16-JUL-92 KELLY BUSHING ELEVATION' 109.10 FT ENGINEER- HAUGAARD ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = COND #3-11 2386'S & 1372'E, SEC13 TION R12W MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3817.00 3800.33 3691.23 19.82 S 221.37 W 10063.00 9815.96 9706.86 464.70 S 1233.33 W 12022.90 11686.91 11577.81 733.98 S 719.95 W 12086.00 11745.95 11636.85 744.06 S 700.09 W 12145.00 11801.15 11692.05 753.49 S 681.52 W FINAL WELL LOCATION AT 'rD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 12145.00 11801.15 11692.05 HORIZONTAL DEPARTURE DISTANCE AZIkiUTH FEET DEG MIN 1015.98 S 42 8 W WELL' GRANITE POINT #50 HORIZONTAL PROJECTION (COND #3-11 2386'S & 1372'E FROM NW CORNER,SEC 13,T10N,R12W) IOO0 WELL' GRANITE POINT //50 VERTICAL PROJECT~0N (COND #3-11 2386'S & 1372'E FROM NW CORNER,SEC 13,T10N,R12W) ..... ...... ...... ..... ...... ..... ..... .... :::::::::::::::::::::::::::::::::::: ZLE%:Z~::Z;Z'ZZ~ ....... t'"F't'"i ..... ??-'?--i..-?-r-t ...... t'"?'h';:''' '!-~"s-* ...... ~--~-'!-r-'--'t-'-?"~ ..... ?"?"~"'~ ..... ~'"*'"?~ ...... r'-?"~"T-:"'h't"'?"?';-?'?'-7": ...... ,"';."i'"' ...... *'";"?'* ::::::::::::::::::: :::::::::::: . ~:: : ;: : :' :'~: ~: ~ ...... ~ ,: ~:,, L i"'::"'::'"? ...... :":. 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"~-~"~'"F' "'??~"~'~'"?'T":'"?""~'~'~ :i · · : · : · r""?T~? ....... ~'F~ .... ?~"~ .... ~'~'~"~ .... ?"~'"~"'~ "?~"T'?' "?'?'?"~ .... ::: ~ : : : : : : ~ : '. :,:::~ i : : ~ '. '. ~ ~ ~ ~:'.~ ~ : ~ : : : : : ~ ~,~ ; : : :~,.+;~+:-+~~+""~'~ ..... ~r'~"?" ............ %-%7 "T'T'T~ -%~ ..... %T"f .... ?'r'?'s ..... r'T'F'~ ..... F'i"i'"F."'F"FT'i .... r-;'"r": ...... r"r"r", ........... · ....... . ...... , ....... i : : : : : : : , : : : : : : : : : : : : ~ : : : : : : : : : : ~ : : : : : : t : t : : ~ : : : : : : : : : : : : ..... ~-' --~'.-~" "'?":'":'"~ ..... :-'?'~" '~'~"~'~ ";--~=:~-~ ..... ~=~"~'~ :'":'"~"?' '-~'"~"~'"~ '"Y'?"??' ~'"?"F"?'~ ...... ???"'~ ..... r"?~'"~ ...... t"'~'"~'"~ ..... ~'"~'"~'"~'", t I : : I : : : I ' : ~ : t : ~ : : . : t : ~ . I : : : : ~ : : : : : : : : : : : : : : : : : ~ : : : :;;~ ~:::,:: :,i;i ';;:. ;;;;~ ];;; ................ : :::: .... ..... COMPLETION DATE .7 //,~ i77-- CO. CONTACT ...................... -~,~GCC ~F0-L0~GIcAL U^TEFllALS INVENTORY' LI~T · . [ check off Qr li~t d,..a, ta, ~s it i,s' received ) ..... I i ........ ~ m m m ) ....... ) ........ ~J ...... { m .... I I ............ )m ~ ~ .... L .... ) mm LOG'WPE ....... nUN INTERVALS "' SCALE NO. 11] ! j') 4t 1 s) i 7) oj 19) Unocal North Americ; Oil & Gas Division Unocal Coi'poration P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITTAL August 31, 1992 HAND DELIVERED TO: Larry Grant FROM: Dick Stewart 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION P O Box 196247 Anchorage AK 99519-6247 ALASKA REGION Transmitting as Follows: Granite Point #50 i blueline and I se~4~ as~oliows: ~"~/t/~ray Sonic~/8~Ru. lx4,2~ c/~/Pl~asor Dual]'nductior~r~")Run 1,2,3 /..Density-Neutron Porosity 5" Run 2,3 .BthO Density 5", Run 2,3 icrolog 5", Run 2,3 T 5", Run 1 ,~CT 5", Run 1 ~0rmation Log- Mudlog /.X)rilling Dynamics Log - Mudlog /.Chromatography Ratio Log- Mudlog .,/6~'EDIT TAPE & Listing _~.T LIS TAPE & Listing /~irectional Survey PLEASE ACKNOWLEDGE RECEIPT OF THIS DOCUMENT TRANSMITTAL BY SIGNING AND RE~GS~ZPY. THANK YOU. ALASKA OIL AND GAS CONSERVATION COMMISSION May 19, 1992 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Gary S. Bush Regional Drilling Manager UNOCAL P O Box 196247 Anchorage, AK 99519 Re: Granite Point No. 50 · UNOCAL Permit No: 92-41 Sur. Loc. 2386'S & 1372'E fr NW Cr Sec 13, T10N, R12W, SM Btmhole Loc. 2386'FNL & 832'FWL, Sec. 12, T10N, R12W, SM Dear Mr. Bush: 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) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may .witness the test. Notice may be given by contacting the Commission at 279-1433~ Sincerely, Cha£rman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,.-~ STATE OF ALASKA --~ ALASK; ilL AND GAS CONSERVATION CO', llSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill J~ Redrill ~ 1 lb. Type of well. Exploratory ~ Stratigraphic Test j--j Development Oil Re-Entry J-'j Deepen J~I Service ~ Development Gas J-j Single Zone[] Multiple Zone J-1 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California (UNOCAL) 110' RT above MSL feet Granite Point 3. Address 6. Property Designation Middle Kenai P.O. Box 196247, Anchorage, AK 99519 ADL 18761 4. Location of well at surface Conductor #3-11 7. Unit or property name 11. Type Bond (SEE 20 ACC 25.025) 2386'S & 1372'E from NW Corner Sec. 13, T10N, R12W, SM Unocal-Mobil State #1 United Pacific Ins. Co. At top of productive interval 11516'MD/11211 'TVD 8. Well number Number 2386' FNL & 622' FWL Sec. 13, T10N, R12W S .M. Granite Point #50 U62-9269 At total depth 11968' MD/11611 q'VD 9. ADor. oxJmate spud date .. Amount 2386'FNL & 832'EWE Sec. 12, T10N, R12W, S.M. ~-~, 1992 o. 8~,~.3~,,~' $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in propert~ 15. Proposed depth property line 3100 feet 100 feet 5089 11 ~968'/11,611' feet 16. To be completed for deviated wells 17. Anticipated Pressure(see 20AAC25.035 (e)(2)) Kickoff depth 3000 feet Maximum hole angle 28 deg a~mumsurface 2032 psic, l At total depth (l'VD) 8128 psig 18. Casing program I Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight i Grade Coupling Length MD TVD MD TVD (include stage data) 24" 18-5/8" 87.5 X56 RL4C 1000' SURF 0' 1000' 1000' 2500' CU. FT. i7-1/2" 13-3/8" 68 K55 BUTT 3857' SURF 0' 3857' 3844' 4000 CU. FT. 12-1/4" 9-5/8" f7 &53.5 Pl10 BUTT 10100' SURF 0' 10100' 9900' 2400' CU. FT. 8-1/~' 7" 32 Pl10 BU'FI' 2070' 9900' 9700' 11968' 11611' 400' CU. FT. 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary Total depth: measured 289 feet Plugs (measured) true vertical 289 feet Effective depth: measured 289 feet Junk (measured) true vertical 289 feet Casing Length Size Cemented Measured depth True vertical depth Structural 172' 33" DRIVEN 224' 224' Conductor 117' 26" DRIVEN 289' 289' Surface ~'~:"'~ ~' i:' ........... 1 !VI~ E~"[~ . Intermediate _.~'~i~ ~;,. , Production ~'~..~i ~?~' "~ '::.i Liner Perforation depth: measured ~.:~:~, ~jJ & Gas C~s. .... true vertical ...... ~ ~.~ i~ ~ _~. ch0r~i ~' 20. Attachments Filing fee J~ Property plat j--J BOP SketchJ~ Diverter Sketch ~: Drilling program J~ Drilling fluid program J~ Time vs depth plot J~ Refraction analysis J-J Seabed report J-J 20 AAC 25.050 requirements J-J 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .~~_Z~c,c~/ ~' ~'Y J'' Title ,,~ e.~{'o,na / ,~.,",;//,,,'4~ ,l~/Te,q o ~,.-_./" Date.5'-./.f'-J~ Commission Use Only Permit Number number 50- .~3~. .'~ .Z 0 ~',,~ ~7z iAppr°val date .- for other requirements Conditions of approval Samples required [-] Yes,'No Mud log required [~ Yes"'~ No Hydrogen sulfide measures ~ Yes~" No Directional survey required ~ Yes ~ No Required working pressure for BOPE ~ 2M; ,~ 3M; r~ 5M; ~ 10M; L_J 15M Other: Original Signed By by the order of e~,./ Approved by r~.-.,4,~ ~ ~,.~,,~.~,-,,., Commissioner the commission Dat ~""~ Form 10-401 Rev. 12-1-85 L Submit in triplicate Granite Point 50 Drilling Procedure 04-28-92 Procedure · 1. MIRU on Leg #3, Conductor #3-11, RIH and tag top of 26" conductor at + 172' RKB. POOH. RIH inside 26" conductor to the shoe at 289' RKB. 2. Tie back 26" conductor with taper tap device and run 24" back to surface. Cement 33" x 24" annulus and seal as required. 3. Install 30" diverter system and riser to 24" casing head assembly head. 4. Drill out the 26" shoe at 289' RKB (~ 105' BML) with 17-1/2" bit and drill to 1000' MD RKB ( ± 816'BML). 5. Underream 17-1/2" hole to 24" from 289' to 1000'. 6. Run and cement 18-5/8" surface casing. 7. Install 20" BOPE stack, notify AOGCC and test accordingly. 8. Directional drill 17-1/2" hole to ± 3857, MD RKB. (600' ROP / day) Run open hole logs. Run and cement 13-3/8" intermediate casing. Run CET/CBT Change from 20" BOPE to 13-5/8" BOPE stack, notify AOGCC and test accordingly. 11. Directional drill 12-1/4" hole to ± 10100'. (450'/day ROP F/5-7000') (250'/day ROP to TD) 12. Run open hole logs. 13. Run and cement 9-5/8" production casing. 14. Directional drill 8-1/2" hole to ± 11970' TD. 15. Run open hole logs. 16. Run and cement 7" liner from 9900'-11970'. 17. Run CET/CBT and Gyro survey. 18. Run a dual 3-1/2" tubing completion with TCP guns attached to both short and long strings. Estimate TCP shots in Tyonek sands (ca. 400' of perfs) and Hemlock (ca. 400' of perfs). 19. Remove BOPE and install dual tree assembly. 20. Obtain underbalance as required and detonate TCP guns as directed. 21. RDMO. GREAT LAND DIRECTIONAL DRILLING, INC. Corporate Office 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for UNOCAL CORPORATION well ......... : GP-50 Field ........ : GRANITE POINT Section at...: 270.00 KB elevation.: 110.90 ft Computation..: MINIMUM CURVATURE Prepared.: 03/05/92 PROPOSED WELL PROFILE STATION MEAS INCLN IDENTIFICATION DEPTH ANGLE KB 0 0.00 KOP BLD 2/100 3000 0.00 END 2/100 BLD 3857 17.14 DROP 1.14/100 7418 17.14 END DROP START BLD 8924 0.00 VERT-DEPTHS SECT BKB SUB-S DIST 0 -111 0 3000 2889 0 3844 3733 127 7247 7136 1176 8731 8620 1400 TARGET A 8924 END 1.14/100 BLD 11359 TARGET B 11516 TARGET C 11968 TD 11968 0.00 8731 8620 1400 27.70 11072 10962 823 27.70 11211 11100 750 27.70 11611 11500 540 27.70 11611 11500 540 DIRECTION REL-COORDINATES DL/ AZIMUTH FROM-WELLHEAD 100 270.00 0 N 0 E 0.0 270.00 0 N 0 E 0.0 270.00 0 N 127 W 2.0 270.00 0 N 1176 W 0.0 270.00 0 N 1400 W 1.1 270.00 0 N 1400 W 1.1 90.00 0 N 823 W 1.1 90.00 0 N 750 W 0.0 90.00 0 N 540 W 0.0 90.00 0 N 540 W 0.0 iiiiii iii UNOCAL CORPOR^TION GP-50 YERTIC^L SECTION ¥IE SQctlon or: 270.00 TVO $cole.: 1 inch = 1500 feet Oep Scole.: 1 inch - 1500 feet Orovn ..... ~ 09/04/92 Qr~ot Lond Dlr~ctzonol £rillln~ ,, M~ Ider~:¢~cc~lon 14] BKB ~ECTN [NCLN ~ ~ 0 0 O 0.00 · ~ 1.14/1~ 7418 ~47 ~176 ~7. I4 ~ ~ ~ ~T ~ 8924 8731 1400 D. O0 ~ T~ A ~24 8731 1400 O. O0 ~ ~ 1.14/1~ ~ I1~ 110~ 823 27.70 · TARG~ B 11516 112~I 750 27.70 I> T~G~ C 1195 11~iI 540 27.70 ~ ~ ~195 11~11 540 27.70 12000 0 750 1500 Sectlon Oeporture __ __ · L~ G:)~8 ~ 81.3Q 11m~ ~ 2) UNOCAL CORPORATION Harlxer Ident]ftcat]on Hi:) N/5 E/~ A> t(8 0 0 N 0 E B> KOP ELD 2/]00 3000 O N 0 E C) END Z,/IOO EILD 3857 0 N ]27 It D) DROP 1. ]4/]OQ ?4]8 0 N 1]76 ¥ E> EHD mOP START BID 8974 0 N 1400 It F) TARGET k 89:::;4 0 N ]40Q It B> END ]. 14/]00 BID 11959 0 N 8;;3 It H> TARGET B 11518 0 N :750 it :][) TARGET C 119§8 0 N 540 It $> TD 119§8 0 N 540 it Qr~ot L ond D! rec t i ono I Drl I ! ! GP-50 PLAN VIEW CLOSURE ..... , 540 ft ot Azimuth 270.00 DECLINATION., 23.00 E SCALE ....... , ! Inch = 200 feet DRAWN ....... , 03/05/92 ,,, i111 IIII III! II!1 __ IIII IIII IIII i111 !111 ) '[ H IIII ._ ._ _._ III Ilml - I!11 IIII !111 ~ Illi J III I IIII ,,j IIII ~:~ I I I I '?. II II L' IIII :' ~..:~_,t~ l Ill .. IIII ':' IIII ~ :-:::.!?"~'~ i I I I ~ ' "~? II I I , ,v ~:~"'~i I I I I ~ .... IIII Ilil i' ~, ~,~. I I I I ,~ /'-~ IIII ~. ~ ~ IIII ! ~. ~' IIII ~ IIII ~, IIII 1700 1600 1500 1400 1900 1200 1100 lO00 DOD 600 700 BO0 500 400 300 200 lDO I] 100 <- '~EST: EAST -> · (Z~L. rlfl (c)97 GP'::JD Bl.~O ~',04 PN Z) GREAT LAND DIRECTIONAL DRILLING INC. Close Approach Analysis we, GP-50 _ , F~e~d Granite Point , ,, , cor,,,,y Unocal Corporation AFE# ,, A~TE.T~O~ Lee Lohoefer . D,to March 24. 1992 WELL CROSSINGS Crossing Well TVD TVD Distance Above/Below , ,, GP 12-24 621 3737 3116 BELOW GP 13-13 709 3767 3058 BELOW GP 32-23 1008 3813 2805 BELOW , , GP 44-14 587 3852 3265 BELOW , , GP 33-14 671 3869 3198 BELOW ..... GP 31-23 1123 4016 2893 BELOW , , WELLS- WITHIN 100 FEET OF PROPOSED WELL Close Approach Distance Range with well TVD .... , . ,, GP 11-13 100 2850 SURFACE TO 2850 GP 11-24 100 1320 SURFACE TO 1320 GP 12-24 100 700 525 TO 700 _ , , GP 13-13 100 3990 900 TO 3990 GP22-13 100 1450 SURFACE TO 1450 , ,, GP 24-13 100 1380 SURFACE TO 1380 GP31-13 100 1250 SURFACE TO 1250 ..... ,, GP 33-13 100 2150 SURFACE TP 2150 ,, GP 42-23 100 1305 SURFACE TO 1305 ,,, MUCI-1 100 1165 SURFACE TO 1165 , ,, MUCI-2 100 2562 sURFACE TO 2562 , , Wells Considered for Wells Considered this analysis for this analysis GP 11-13 RD D GP 33-14A G GP 32o13 RD P GP 42-23 G GPl1-13 G GP44-11 G , , _ GP 11-24 G GP 44-14 G . , GP 12-24 G MUCI-1 G ,,, , GP 13-13 G MUCi-2 G GP 22-13 G · GP 24-13 G .,~ GP 24-13A G . ,,, GP 31-13 G GP 31-14 G , , GP 31-14A G GP 31-14B G GP 31-23 G , , . GP 32-13 G _ GP 32-23 G GP 32-23A G GP 33-13 G GP 33-14 G Survey Status: P = Planned D = MWD G =Gyro Survey COMMENTS The profile for GP-50 was computed from parameters supplied by Unocal Corporation. The profiles for all other wells in the Granite Point platform area were computed from directional gyro suveys supplied by Unocal Corporation. The well crossings and close approaching wells to the proposed GP-50 are outlined above. MUCI-2 remains within 10 ft from the surface to 1500 ft TVD in addition the close approaches above. , , ANALYSIS BY: D.?~_lestad CHECKED BY: B. Price I i __, ._ 1 TUBING DETAIL: · I- ~ 2 ~ LS: 5-1/2", 9.2#, N-80 BU"FF 26" @ 289' --' , ~ SS: 5-1/2", 9.2.//, N-80, BUTT 18-5/8" @ ~ooo' ~_ _--I 1) SUBSURFACE SAFETY VALVE : - -' 2) GAS LIFT MANDRELS i-~ r-, 3) "XA" SLIDING SLEEVES I-' r-' ~ 4) "XN" LANDING NIPPLE , , 5) TCP GUNS ON SHORT STRING - --- 6) "X" LANDING NIPPLE ~ - 7) TCP GUNS ON LONG STRING ' ~ i ' 8) DUAL PACKER i - 9) PERMANENT PKR I ~-~/~"~ -I- ~ ' 3857' I~ ~[ i~ 8 T ' C 5 TYONEK 9-5/8" @ 10100' ,~X_, _-' ' P ,/ , .[2. ~, T p HEMLOCK ~ ~''~ ..... !', . 7"L @ 11968' ~1~' ~,. "'"' "' .... ' WELL GP 50 DRAWN-CLL PROPOSED COMPLETION SCALE: N/A UNION OIL COMPANY OF CALIFORNIA (db(] UNOCAL) DATE: 2-16-92 RT 109' RKB 47' WELL HEAD STARTS HERE PROD DECK , TOP OF LEG 57' 75' 55" @ 224' RKB ~ (4-0' BML) 26" @ 289' RKB (105' BML) PROPOSED 24-" TIE-BACK (75' WATER DEPTH) SEA LEVEL (MLLW) """-- TOP 26" @ 172' RKB MUD LINE GRANITE POINT WELL 50 WELLBORE CONDUCTOR STATUS UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL SCALE: NONE DATE: 05-50-92 FLOW NIPPLE 30" 500 PSI ANNULAR L_ L_ 1 30" 720 PSI DIVERTERSPOOL F- 1 L._ I 30" 1000 PSI RISER ONE 10" DIVERTER LINE WITH A 10" HCR VALVE HYDRAULICALLY A'FFACHED TO THE ANNULAR IN A FAIL-SAFE MANNER SO HCR WILL OPEN UPON CLOSURE OF THE ANNULAR. THE VENT LINE WILL BIFURCATE USING A TARGETED TEE INTO AN EAST (PRIMARY) AND NORTH DIRECTION. EACH LINE WILL BE EQUIPPED WITH A VALVE DESIGNED IN A FAIL-SAFE MANNER THAT ENSURES ONE OF THE BIFURCATED VENT LINES IS ALWAYS OPEN. 30" 500 PSI DIVERTER STACK GRANITE POINT PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL APP'D: OSB SCALE: NONE DATE: 04/28/92 Contract Exhibit #2 FLOW .4aNNULAR BOP 21~4~2000 psi PIPE RAMS 203/4" 3000 psi BLIND RAMS ~ , 203/4" 3000 psi ~ i DRIf.f.TNG j KILL ~Tr~ .-'~ SPOOL LINE ~ .2/-..~~ ,dk~O~.43ooo p~.~~..~ CHOKE 4" 5000 psi , ! I, 4" 5000 psi PIPE RAMS 20s/4'' 3000 psi " RISER 2o¥ 3000 psi LINE~~> GRANITE POINT PLATFORM BOPE STACK 21 k" 2000psi/20%" 3000psi FILL- UP KILL LINE ANNULAR BOP 35/e"3000 psi PIPE RAMS 13%~5000 psi BLIND RAMS 35/8"5000 psi Contract Exhibit , SPOOL I~ ' 5000 psi ~1 t. 4" 5000 FLOW CHOKE psi PIPE RAMS 35/8"5000 psi LINE~ RISER 5000 psi GRANITE POINT PLATFORM BOPESTACK 13%" 5000 psi ! HEUPA~ DRILL RIG F_ASTCRANE P~PE R/tl4P P.&A. PiPE RACK 750 PSF: · . · ; '. ) SCR HOUSE WEST C~NE HOW TO C4LCUL4TE A LO~DING PER SQUARE FOOT TOTAL WEIGHT (i.e. 27,000 Lbs.) CROS$ SECTIONAL AREA (i.e. 8' x I0' = 80 sq. fL) LOAD PATE Cpounds per sq. ff.) ~ = 27,0.00 Lbs. = 338 PSF 80 sq. ft. RACK I00 PSF 320 PSF 750 PSF 100 PS-'F (ROOF) 500 PSF (ROOF) I~"~*~ ' '~1 PSF LOAO PAI'ING PLAN I , , J DECKS a ROOTS t--H UNO~ P~O~ m~N~ Po~r - t'1 1 P~ RIG 431 TO 10" CROWN VENT BLOW DOWN GAS BUSTER 1 0" TO SHAKER CHOKE TO CHOKE PANEL NOTE: SWACO CHOKES EACH HYDRAULICALLY ACTUATED VIA REMOTE. TO BOPE MANUAL SWACO CHOKE Um:~d North .Amebean 06 & ~ DIvIMon N. AS~A RE~ION CHOKE MANIFOLD Unocal PLATFORM RIGS 4-1/16" & 3-1/8", 5M MSP m~-~oN IDATEI SCALE Unocal Oil & Gas Division Granite Point GP-50 Interval: 225' to 450' (28" hole -26" casinq) · A~. Drill this interval with inlet sea water. Pump prehydrated gel sweeps to clean the hole as required. II. Interval: 450' to 1000' (24" hole- 18 5/8' casing) Am Spud Mud - Prehydrated bentonite flocculated with FIW as required. Formulation: Aquagel Caustic X-Tend II - 15 - 25 ppb - .25 ppb - .1 ppb Suggested Properties Ranges: Mud Weight - 8.5 to 9.6 Funnel Vis - 50 - 70 Plastic Vis - 10- 15 Yield Point - 15 - 25 pH - 9.0 - 9.5 API Filtrate - NC PPg sec/qt sec/qt #/100sq ft Dm Special Considerations - The primary focus should be on sufficient hole cleaning. Maximize annular velocities to reduce viscosity requirements. Loss circulation/seepage may occur in this interval. Adequate circulating volume should be maintained and monitored at all times. III. Interval: 1000' to 3'$57, (17 1/2.° hole - 13 3/8" casinq~ A_~_. Modified Spud Mud - Dump and clean pits as required. Continue with the previous mud system (P~ehydrat ed Bentonite flocculated with inlet sea water). Special focus should be placed in maintaining sufficient--mud weight in this interval. B_~_. Formulation; Aquagel Caustic PAC Desto - 15 - 25 pp~ - .25 ppb - .25 - .50 pp~ - As Required C. Suggested Properties Ranges: Mud Weight - 9.2 to 9.7 PPg Funnel Vis - 45 - 60 sec/qt Plastic Vis - 10 - 15 sec/qt Yield Point - 10 - 20 #/100sq ft pH - 9.0 - 9.5 API Filtrate - 10 to 15 cc Dm Special Considerations: 1. Maintain good theological properties to respond to gas sand problems as required. 2. Monitor pit levels and trip volumes in this section of the well. IV. Interval: ~7' to 10100' <12 1/4" hole- 9 5/8" casinq~ Am Drill this interval with a fres~ water EZ Mud-DP/PAC polymer system. Maintain this system with fres~ water addit ions. _ B. Formulation: Aquagel - 8 - 12 ppb PAC - .5 - .?5 ppb Therma-Thin - EZ Mud-DP - .5 - 1.0 ppb Baranex - ~ - 3 ppb KOH - .25 ppb Barotrol - as required C., Suggested Properties Ranges: Mud Weight - 9.3 - 10.4 ppg Funnel Vis - 45 - 60 sec/qt Plastic Vis - 10- 18 sec/qt Yield Point - 12 - 25 #/100sq ft pH - 9.0 - 9.5 API Filtrate - 6 to 8 Initially 4 to 6 final HPHT Filtrate - 18 to 20 Initially - 16 to 18 final De Special Considerations: Maximize solids control equipment to maintain the low gravity solids as low as possible. Treatments of Ba~otrol are suggested at the first indications of coal related problems in the concentrations of 3 to 4 ppb additions. IV. Interval: 10100' to 112455' (12 1/4" hole -~ 5/8" casinq) A. Drill this interval with a fresh water EZ Mud-DP/PAC polymer system. Condition the mud from the previous interval. B. Formulation: CJ Aquagel PAC EZ Mud-DP Baranex KOH Barotrol 8 - 12 ppb .5 -.75 ppb .5 -.75 ppb 2 - 3 ppb .25 ppb 3 - 4 ppb Note: use caustic soda prehydration process in the Suggested Properties Ranges: Mud We ight - Funnel Vis - Plastic Vis - Yield Point - pH - API Filtrate - HPHT Filtrate 10.2- 13.5 45 - 60 10- 18 9.0 - 4 to 5 3 to 4 16 t o 18 14 to 16 PPg sec/qt sec/qt #/100sq ft Initially final Initially final Granite Point Mud System & Related Equipment: The mud system being provided (see attached drawing) will be equipped with a barite recovery system for use while drilling with weighted mud systems. Two (2) Ideco T-1600 1600 HP, with 7-1/2" bore x 12" stroke triplex mud pump with 5000 psi fluid ends. Centrifugals - all pumps are 6" x 8" x 14" mission magnum. System complete with the following charge pumps: A. Two (2) charge pumps for both triplex pumps. B. One (1) pump for desander C. One (1) pump for mudcleaner D. One (1) pump for hopper/gun line Ail pumps powered with 100 HP motors Active tank is 540 bbl nominal volume which consists of: A. 25 bbl sand trap B. 145 bbl desander tank C. 144 bbl desilter tank D. 144 bbl centrifuge tank E. 43 bbl suction tank F. 22 bbl slugging and pill pit a. 18 bbl chemical tank Pit system will be equipped with pit level lnalca~or using visual and audio warning devices, fluid flow sensor, methane and Hydrogen Sulfide detection units. An auger system with three augers at the centrifuge, active pit, and transport area. Solids control equipment consist of the following: A. Two (2) Derrick Plus Model Flow Line Cleaners. Bo Demco desander with two (2) each 12" cones. C. Pioneer desilter with (12) each 4" cones. D. Degasser, Drillco rated at 800 gpm E. Agitators, five (5) with 32" & 24" impellers F. Mud Hopper, Geosource Sidewinder G. Centrifuge, Two (2) Pioneer Mark I Two (2) 500 bbl each reserve pits internally coated with an Epoxy-coal tar system. Pits include 3" gun lines and agitators in each unit. Fresh water storage on the platform is a beam tank with a 2500 bbl minimum capacity. Filtered Inlet Water (FIW) is readily available. Storage for mud products on the platform is limited to a sack storage system on the piperacks and drill decks which is space limited. TOTAl. VOLUI4~ : 545 BBL ~' ~] Depth 0 (~,ooo) (2,ooo) (~,ooo) (4,000) (5,ooo) (e,ooo) (7,000) (8,000) (9,ooo) (~o,ooo) (~ ~,ooo) (~2,ooo) (~5,ooo) RUN 26" CSG. . RUN 18-5/8" CSG. TIME: 65 DAYS COST: $6.0 MM LOG AND RUN 13-3/8" CSG. 7" LINER ~ 0 10 20 30 40 50 60 70 Days Estimote Granite Point Well #50 o3/31/92 Anticipated pressure: Maximum surface pressure calculation; Mud weight® 102 PCF = 71 psi/ft · · · · · · . · · . · · · · · · · · · · · · · · · · · · · · · ~$hoe (9-5/S") depth: ....................... 10100'MD/9900'TVD Estimated fracture gradient (9-5/S" shoe): ...... 0.95 psi/ft. Total depth: .............................. 1196S 'MD/ll611'TVD Bottom hole pressure gradient: ................. 0.70 psi/ft. Gas gradient (assume worst case) ................. 0.0 psi/ft. /-'~'/4 & 1/4 gas. Wellbore volume with gas kick situation: Maximum surface pressure = Btm hole press - Hydrostatic press MSP = BHP - (3/4 mud + 1/4 gas) MSP=(ll611 ft * .70 psi/ft) - ((·75 (11611 ft * .71psi/ft.)) + (.25 (11611 ft * 0 psi/ft.))) MSP = 2032 psi. Therefore, the greatest hydrostatic pressure at the 9-5/8" shoe (HPsh) is when the gas bubble reaches the shoe if a constant BHP is applied. A conservative estimate would be the maximum surface pressure (MSP) plus the hydrostatic pressure at that casing depth (HPcsg). HPsh = MSP + HPcsg HPsh = 2032 psi +(9900 ft * .71 psi/ft.) HPsh = 9061 psi This (HPsh = 9061 psi) is less than the fracture pressure at the same shoe (FPsh = .95 psi/ft * 9900 ft = 9405 psi) and thus sufficiently adequate to handle the well kick. This scenario is considered extreme since actual well kicks have seen a maximum of 300 psi on the shut-in casing pressure. Memorandum . _, _ UNOCAL April 28, ,1992 From: C. Lee Lohoefer (Unocal) Re: Granite Point Well ~50 Per our telephone conversation of yesterday regarding the permit to drill for GP #SO currently under review,by yourself. Please replace and disregard the following items with the enclosed revisions; please contact myself 'as soon 'as possible. A. GP ~$0 Drilling Procedure (dated B. GP ~0" 500 P~I Diverter Stack (dated 04 If you should have any other questions regarding this matter u11\Grunlt~\PO~9 , RECEIVED Als3ka Oil & Gas Cons. Commission Anchorage Unocal North America, "-,~ Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Robert T. Anderson Manager, Lands Alaska Region April 7, 1992 Mr. Russ Douglass Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Cook Inlet Area State of Alaska Permit to Drill Granite Point #50 Dear Mr. Douglass: Pursuant to the provisions of 20 AAC 25.005, I have enclosed check number 11191 dated April 7, 1992 in the amount of $100.00 to cover the application fee for Permit to Drill Granite Point #50. In as much as the targeted location for this well in the Granite Point Middle Kenai Oil Pool is approximately 950' from the producing interval in 31-14rd #2, we hereby ask for an exception to Rule 2. (Spacing) under Conservation Order NO. 76. Administrative approval is sought under Rule 7. CO 76 for this action. Additional oil recovery from the Middle Kenai Oil Pool is anticipated through the drilling and completion of the Granite Point #50 well. Very Truly Yours, /Kevin A. Tabler Land Administration Manger Kat:nk CC: Lee Lohoefer Dick Stewart RECEIVED APR - 8 3992 Alaska 0il .& Gas Cons, .l:;0m~issi0r~ GRANITE PT 1 11-1`3 `31- 14RD1 22-1.3 TARGET A PROP. LOC GP-50 TARGET B TARGET 13-15 % 33-13 44-14 GRANITE PT. FIELD TOP C-3 STRUCTURE MAP PROPOSED GP-50 UNmCAL-75% Hi~P 307 AC 17586 T~RGET-~ 8888 AC 3-3~-98 ADL-374041 ADL-l~587 UNBCSL~-75Z 31 TBXACF1 6 5060 I I I D. INT. PTMD 11,9~)8' t $'~R NtICAL-P5 C 742 -50 CF L )C. ON 3-3t-78 ADL-374068 '-~ GRAN TE PO NT F ELD ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 April 8, 1992 ., ADMINISTRATIVE APPROVAL NO. 76.25 Re: The application of Union Oil Company of California to drill and complete the Granite Point 50 well as a Middle Kenai Oil Pool production well. Gary S. Bush Regional Drilling Manager UNOCAL Corp. P. O. Box 190247 Anchorage, Ak 99502-0247 Dear Mr. Bush: Your application of April 7, 1992 for a permit to drill and complete the Granite Point 50 well requires exception to spacing requirements set forth in Conservation Order No. 76. The drilling and completion of the Granite Point 50 well is expected to provide additional oil recovery from the Middle Kenai Oil Pool in the Granite Point Field. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the Granite Point 50 well pursuant to Rule 7 of Conservation Order No. 76. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE [2 thru 8] (3) Admin ~179 thru [10 & 13] (4) Casg [14 thru 22] (5) BOPE ~..~,.'~.~ 4/-.?.f~- 9 ~ [23 thru 28] hr~ 31] Company 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ . 10. 11. 12. 13 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... 29. 30. 31. Lease & Well ~, /~Z2~ /~"/, YES NO 32. REMARKS Is lease ngrnber appropriate .......................................... Does well have a unique name & nLrnber ................................ ~ . . . Is conductor string provided ......................................... ~ ..... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ ~ ... Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... ,. Is old wellbore abandonment procedure included on 10-403 ............. Is adequ~'te wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... ~ .... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~O~~sig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. · ...... 0 --~ '1'Z ~0 ~: en9 i neer i ng,:, DWJ MTM ~.~ ECS RPC.~~~ BEW ~/~ ~ : jH '~?d~~ rev 03/29/91 3o16.011 :~'NITiAL GEO] UNiT ON/OFF POOL CLASS STATUS AREA ~ SHORE ........ Additional remarks' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXl No special 'effort has been made to chronologically organize this category of information. "~&a ' 'ozozOz.~ MICROFILMED ~_l: (//~./..~ ...... ,._..~ WELL NAFiE : G?a{qlq, fJ POI~4T ~5o APl ?4{]~,'~SFR : 50-73.3-204~34 ~f:Ff,':RT.~,~CE ~(~ : 92483 05:41 PaTE O P ! ~ FJLF ~,:ih~i~ : ED!'r .001 8FRV!CE : VF~$ I {.tt,~ : 00~, A07 D,g T~' : 92109/! ~X REC SIZE : 1074 F]b~' TYPE : [,,C L~ST Wt bE ******************************************************************************** ********************************************************************************* ** 5C~,~L,U~E~GER ~iEbb SERVICEM ** ** ** ** ******************************************************************************* ******************************************************************************** IS 'ra~e Verii.icati. on l, ist, J. nc~ chlU~,~ber¢~'r .~]ask8 Computtr~o Cer'~ter J.!-ISG-!,992 05:41 ELEVATIONS g~: !09.i' C ~ S I N ~ I BlT STEM t)IS HC 42 DIC ~':~!39 S!.~6 C.a 134 Sl,,~ CA 44 5f)C C~. 6a S(;C 5! 558 PaTE LOGGED: 23-jlJi',; E-~ 2 TF~ 13f~II,,l..,E!~: 10081' C ~SI~''~G 1: 1],375" ¢ DP1L[,~':~ DEPTH OF O' TO 3817' RIT SIZE 11 12.25" ¢ IOOBI' PHI 9.7 FI.,UID b!385:5.4 ~:,UD PE;$'IST[VlTY: 2.~4 r~ 78 DEGF" :~If~D C~KE ~ESISTIVIYY: 2,7R e 78 DEGF' !"*!$ 42 [)lC 39 5I:S i. 3',:, S!..,R 44 5DC 6.°, [)RS 2981 b'SC 7!2 [:'nH 377! C",'C 46? ?[,T 027 8CC 479 TCC 101 *******~ ****************************************************************** T~ I)PTbL~TR: ~2145' ,18 Toee ver.ificatf, on btst:'fr~O chlum~ercter ~task. a Com[:..ut'Inq {::e~ter 1 l-h[~G-l, 992 SL$ 6~ sue !. :~4 TCC 114 VISCOSITY,' 6<, Fbt~!P .!.~OSS; 4,2 (a 78 !>EGF PA~E: **************************************************************************************** [1N ["~ C h 50-733-204t4 ******************************************************************************* .tS Tebe Ver!f~c.a. tion !>i, stinc ch],u~:;berr.~er Alaska Comput:in~ Center &i..-AbG-1992 o5:41, T~!~',~ ~ VALti DEF I W~; GRACChi TE POINT aPI'¢ 50-733-~0434 FI.~ COND ~3-1~. 2386'S & 1372'E sFCT 13 COU~ KE~A1 ST~ ~T! USA WITN' STEWART S 0 !~i 530759 EDP PT 0, L~F KB APl) FT 109,1 EDF PT .99~. 25 EGL FT -999' 25 TOD FT 12145, TU, t, FT 12100, ~I.,, ! FT TLI ~T 9~i , D F D ('; / C 3 I .3 b~"V S 64~ O~L r 3 4, {~ST ~)EGF 7 ~ PCST gEGF 7R Field ~a~e Well ~ame API Serial Number Field Location Sect~o~ Township Ranoe County State or Province Nation Witness Name Service Order M~mber Permanent datu~ glevatio~ of Permanent Datum Log ~easured From ~bove Permanent Datum Elevation of Kelly Bushin~ Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total DePth -bogqer Bottom bog Interval To~ Log Interval Or .llJn~ F!,uld Type DrlllinO Fluid Density Orillinq FlUid Ph Dritl, im~ Fluid Visco~it~ Drlitlno Fluid Loss Resisti9~ty of Mud SagPle ~ud Sample Temperature Resisti fry of ~ud Filtrate S ~ud.F~ltrate Sample Temperate] Resistivity of ~ud Cake Samml ~ud Cake Sample Temperature Bottom gole Temperature T~RI,E TYP~? : ............................................... . IDP~ I~%~DtJCT](3E bEF~: PHAS()R P?SISTTVITY CIteD ~T)ttCTIQ~,~ '.,~FF;i[i~:, P}{nSOw COMDI~CTIVITY I~Pu. I~,;gUCF!f')~:,. S~l:[}~l{.!~ PHASOP k'.=E,S,STI'' VITY C!t,u Conductivity IL Peen Standard Processed !f,D boer:, !~r'~,~Jt;ctlon Standard Processed ~esistivtty C!!...¢~ Conductivity TI,, ~ediur~ Standerd Processed ,'t$ Tape ~;eriflcatl, c~,n Lj. stin~ :cb].tlmbe.r;qer A.lask~! Cc~r,..~ut~no Cent:er ll-~G-!9q2 05:41 P~GE: Standard Processed ~eststivlty !.n~uct ior: (~al ~hrat.:ed 4 .~'. ........ . . !~40F ~':ED lNDUC?If..'~ai OUI!~,ITY ~'~CTUR ~edi. u~'~ !ndt!ct.l. ot:~ ~eal Int.:.er~'~edlat:e Co~d~cti. vlt¥ ~,~edj. t]m Induction Quod Intermediate ConduCt. tvlt:y SFI, Peststi. vit. v t.~naverac4e~i Suontaneous Potential Cat, ma Ray tens!.o~ ?~ud Te~erat ute He~d Tenslnn ~ E b T ~ - T T[~aNSIT TI~'[: ! TRh~SIT TI~:~Z 2 Tension }~ttd Te~¢er~ture ~ead Tension 9ensity Forosttv 9ulk Densi[Y De J, ta PhotoElectric Factor Ouall, tv control, of !or:,c~ sr:aclnq ~or (~uolltv contro.l on short spacing for bDT !..,O~(J S{'~e!ci~<~ Co,".r, uted Count ~a.t'e (LL+!~U/2) Lon~] i.~ppe~ [-2 WIr~<:.~o~: Count Rate [:onq I...,(~,'~r :'~indow Count ~ate bitholo9 ':,~ir~dow Count ~ate, Short 8~:,aclnrn ! ~ndo'~, Count [~ate $hort S[)ac~.n~ 2 ~>~indo~,,~ Count Rate l,oncj Specin<'~ r~ir~h Vol taqe Short. SpacinO ~iOh Vol. teoe Ca 1. '~ud Te~:o~r~ture tS Ta~e veri. ft. cat.ior'~ I?istino chlur~-ber~er Alaska Co,~r~utin~ ~enter ~ead ~eutrom Porosit. v ~aw There, al ~,~eutron Ratio Thermal ~.~eutron Patio Ca]IbrateO ~,~eutror~ Porosity from ar~ Application Pro.ram RCFT C~TC Gamm~ Tension ~UD ResistiVity ~ud Temperature Gamma Pav !~ead Tens ion UUD Resi, stivltv PAGEt IS Tape Verlficat!on ch,l. umber~er ,Alaska ComputinO Cer~ter !1-~0G-~. 992 05:41. 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SPT US $3075q LTT3 SD~ US 53075~ 0C L · 7' ~ S D T d,... 53 n 75 o (;P SDT qb, PI, 53075q O0 T~'~S SPT [,}:~ 53075o O0 uTE:~ SPT DE;(;K 53()759 ()0 hD~I [,DT PU 53075q C,O ~{~On [o'r G/C3 ~30759 00 p~a LL?~ GtC3 ~307~g 0O PE"F I.,DT 5.]07~9 OO OSS I.,r)T 5307~o O0 bS I [>T (,Pi5 5307~9 L t., [, ['~ T C P S 530759 0 000 O0 0 ! ! 1 4 68 0000000000 000 O0 0 I ! 1 4 6g 0000000000 o 0 o 0 o 0 ! ! ! 4 6:8 0000000000 000 00 0 1 ! 1 4 68 0000000000 C, Co oO 0 .i 1. 1 4 68 o000000000 (:: C) 0 o 0 o 1 ! ! 4 68 0000000000 o o 0 00 0 ! 1 1 4 68 0 o 0 0 0 00 0 0 0 coo oo o I ~ ! 4 68 0000000000 O (", 0 oo 0 1 1 1 4 6.8 0000000000 000 00 o ~!, ~ ~ 4 6 8 0000000000 000 o, 0 0 ! ! 1 4 68 0 (') 00000000 0oo OO 0 1 ! 1 4 6~ 0000000000 000 0 o 0 ! 1 I 4 6 ~ 0000000000 o(>0 O0 0 I 1 .! 4 68 0000000000 000 O0 0 ~. ~. ~. 4 68 0000000000 000 O0 0 1 1 1 4 6~ 0000000000 000 OO 0 ! t 1 4 68 0000000000 0o0 oo 0 i 1 ! 4 68 0000000000 0 00 0 0 0 1 I ~ 4 6 ~ 0 0 0 0 0 0 0 0 0 0 ('.," 00 00 0 .1. I ! 4 6 ~ 0000000000 000 O0 0 I I t 4 6[{ 0000000000 000 oe o t ! ~. 4 68 0000000000 000 00 0 1. I ~ 4 68 0000000000 ¢.) 00 00 0 I I l 4 68 0000000000 000 O0 0 !, 1 I 4 68 0000000000 000 00 0 1 1 ! 4 6 a 0000000000 000 O0 0 1 1 ! 4 6~ 0000000000 000 O0 0 ! 1 ! 4 68 0000000000 00 0 00 o ! 1. 1 4 6 ~ 0 0 0 0 0 0 0 0 0 0 0o0 O0 0 1 1 1 4 68 0000000000 c 00 0 0 0 1 .! 1 4 6 ~ 0000000000 OeO 00 0 I I 1 4 68 0000000000 000 O0 0 ! 1 .t 4 68 0OO0000000 0('30 O0 0 ! :t 1 4 68 0000000000 O00 00 0 1 l. ! 4 68 0000000000 000 O0 0 !. !. 1 4 6g 0000000000 000 O0 0 ! I ! 4 6~ 0000000000 (,00 00 (' 1 1 t 4 68 0OO0000000 000 00 (") 1 1. 1 4 6~ 0000000000 CoO oo 0 1 ! I 4 68 0000000000 C)O0 00 C ! ! 1. 4 6~. 0000000000 000 90 0 1 I 1 4 6~ 0000000000 000 O0 o ! ! -! 4 68 000000000O 000 O0 © I 1 1 4 68 0000000000 000 O0 C l I 1 4 68 0("_.'00000000 000 oo 0 I ! ~. 4 6~ 0OO0O00000 oo0 oO o !, I 1 4 68 oo0o000000 000 OO (> 1 ! 1. 4 b9 0000000000 oon oo o I 1. 1 4 6R OO0O0no,)00 I.'8 To~e Veri. ficat~on I, istint] chlUmberqer Aiaska ComputJnq Center PAGE: . . S S I I,, D T .: P o 530 'l ~ q 0 ~S2 L[)T C o 530759 LSHV EDT V 530759 00 SSHV bl)~ V 530750 O0 817[4 LDT GtC3 530759 O0 I.,SR~ [[)T G/C3 530759 00 LI~9 bDT G/C] 530759 u .. ! i~, 53 n 75 ~ 0 (.;~ LDT G:~, P! 530759 00 T E t,~ S !., [} · 'L ~ 530759 00 N T E L [3; T b [~ 53075 q 00 Nr. HI' C~71, Pt~ g30759 ()o k .... : ',~ !,, 530759 T~:~PU Ch]L PU 530750 0 T[:Pa CNL 530759 [~' C ~.~T CN! Cb5 530759 O0 ~CFT C ~,~ L CPS 530759 00 C ~,~TC C ~:~ [., CPS S3075c, o0 CFTC CNL Cb8 530759 (1~ ~':!' C;APT 530759 00 . %_. ~, ~ ., ........ ,f ~'~ 8 C {,: L b P 530759 i) 0 ~P~'::8 Cb;l' OP~:.~b: 530759 ~"~g~-~ CS f, DE:GF 5~0759 O0 [..~'~a: C .... ~ [.~B 530759 o0 ~ .. ,.,.,.." 5~ [ ~C~:: ~'bT I', t,J 530759 GP ~ I.,T G~Pl 530759 T F N S ~.~ I., T L, B 53 t) 7 59 0 ~':~ ULT DPG~ 53a759 O0 LOG TYPE CLASS grjD NiJM~ Sg~? Et, EM REPR · . ') .? Ct. DE ( }:.!EX ) 000 00 o i t ! 4 68 0O00000000 000 0o 0 I 1 1 4 68 0000000000 000 oo o 1 1 ! 4 68 OOOO000000 000 O0 0 ! 1 ! 4 68 O0000OO000 000 00 0 1 I 1 4 68 0000000000 000 O0 0 ! I I 4 68 0000000000 000 O0 0 1 1 I 4 68 0000000000 000 00 0 ! ! I 4 6~ 0000000000 000 O0 0 I ! 1 4 68 0000000000 000 00 0 1 1 I 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 OO 0 1 ! ! 4 68 0O0O000000 000 00 0 I !, ! 4 68 o000000000 00o O0 0 1. ! 1 4 6~ 0000000000 00(> O0 0 1 !, I 4 6~ 0000000000 000 00 0 I ! 1. 4 68 0000000000 000 OO o I t. I 4 68 0000000000 o0o 00 0 ! 1 ! 4 68 0000000000 000 O0 0 I I 1 4 68 0000000000 000 00 0 t ! ! 4 68 0000000000 000 O0 0 I ! 1 4 58 o000000000 000 oo 0 ! ! ! 4 6~ 0000000000 000 oo 0 1 I 1 4 6~ 0000000000 000 O0 0 ! 1 I 4 68 0000000000 000 0(> 0 !, ! 1 4 6~ 0000000000 000 OO 0 I 1. ! 4 68 0000000000 00o O0 0 1 1 ! 4 68 0000000000 o00 oo o ! 1 !, 4 68 0000000000 000 O0 0 i !, 1 4 6g 0000000000 000 O0 0 !. 1 ! 4 68 0000000000 00o 00 0 ! I ! 4 68 0000000000 oo0 00 0 ! ! 1 4 68 0000000000 o00 O0 o I 1 ! 4 68 0000000000 ~mmmmmmmmmmmmm m~'mmmmmmmm..mmmmm~.mmmmm--mmmmmmmmmmmmm~mm P E ;'~'"I' . I 2152.00 C IL,u. 07[.: 6. 699 I !¢D.I)T~; 143 . 375 SFl,~: I:')TW e. 07o DTT,. Slit 74,400 7'T~. S}')T 412. LTT'2, BDT 8 [~ ti, TFN~. SgT 3805. DP I--J T. I,P'r -909. O!,,S, !.:t)? -999. 250 Ll,. LDT -909,259 lb1..875 IDP[~,UTE 6,172 CI~P,DTE .~ 64,125 i1.,9,9TE 6,090 CILM.DTE ~' ...... t'~TE 3.OQ() IMOF,DTE zO 000 lhOF',; ................... 10.82n I I P ~. i-:}TE 140.750 IiX~.DT~ 7.4 3~3 c;w DT~ 56.219 TK~S.UT~ '010.0 HT~'.:,i:[)TK 4!8.500 bT,SPT 74.100 D~b~,SPT 74 700 TT!,SOT 7!3.~00 ~m4,SoT 510[000 I, TTI.SflT 1177.600 LTT4,SDT 970.800 GR.SDT !64,125 uRES.Sr)T -0.070 HTEN.SDT -999.~50 O,?Ur~, !.,DT -999.250 PgF.LDT -999,250 bS.I,BT -999.250 [,U.LDT -g99.250 SS!.bPT -g99.250 S82.LDT 147 000 149:250 2.000 32 03i ]sos:ooo 76,200 6!8 800 to slsoo 56,219 4!8,500 -99g,250 -999,~50 -999,250 chlumberc~r ~lask. s Comput..ip~ Center DEPT. !21(!0.000 C!DP, o',rE I '-~ P ~ D T E 6 8 ! 3 C I !,.,, D. D T E II,~t. !)TF 6.703 IFRE,DTE I ~'RD. DTE ! ,~ 3. 375 T GFLU. UTE 6. ! 25 SP, DTE ........, ........ DTI,,. S[?.T T TT2. SDT 4! 2. 000 TT3. SDT [.,TT2, SI)? 890,000 bTT3'SDT TENS.SfPT 5,100.000 ~TF, M. SDT DPHT.LDT 44.7! 3 ObS. BDT O, 15 b[..I..r:~. 2 6.500 I,iTH.bDT LSHV, I,DT 202~,O00 SSHV. bDT ~TEV.LDT !~5.125 ~aES. LOT p T ¢~ ~. C N b .3,597 T ~t p H. C N L RC~'~,; T. CN t,,, 22~5.252 RCFT.Cr~L D E P ~". ! 200 (;'. 00 ~':. C I '[!'RD.DTE 134,875 SFLU. DT~ 6. 566 SV. DTE ~!7E~. DTE i84.259 P T L. S b T 77.200 ~ T L ~:,~. S D 'r TT~. SbT 3 ~2,00() TT3. LTT2.SDT 726.O00 LTTB.SDT D~4I. L!)T 15.24.$ CbS. Lb? o. OOa OSS. LDT LL. Lg~ 150,750 LS~V.LL:T 202,1.ooo SSHV.LDT LUpH. [,F:,T 2.3a ¢ CA[,I. f4TF~v r~T PT?;n. C~.!I, 2.945 6~, Cf.el, 93.313 · ..- 1992 -999 ~50 S1RH. !,DT -999 ~ 50 -999 250 ),.tTE'.[':~, i',DT -999~ 250 TNRA, -999.250 CNTC,CNb -999 250 S , . "~ S , -999 . 250 -999,25() '~4:TE~a * ¢4LT ! 6.4. ! 25 I L _r;;, 9 T E 20.000 IDOl', DTE t O. a20 I!~U.DTE 7'!'313 ' 6R.DTE -0 070 HTE~,;~, DTE 74~ 10() r~Tr, F. SDT 713.200 ~'T.4.59T 1177.6o0 L~T4.SO!' 184.125 ~4FES,SDT I , 91.2 D[~O, LOT 0,305 50.656 SSi.~,}DT t902,000 S!RH,LDT 5,34.4 G~. LDT ...... 4~.063 H'rE~J LgT 626,865 C~TC. CNL 5170.000 uRES.CNL 4,551 ~ ~ ' ~ b T !53.250 IDPH.DTE 153.875 !LD.DTE 20,000 !DQ.F,DTE 13.3 ,t 4: I ! R ~, U T E 74. 000 G~, DTE 638 80~ TT4.SDT 103o~0o' bTT4,SDT ~ 84.250 Mt~ES, SDT 7.382 DRHO.bDT 0.010 LS. LDT 70.375 SS!.LDT 1~91.000 SI, RH.bD~ a, 5 ! 6 ~R. LDT -C 062 HTE:~. BDT I. O3~ 694 9. 250 CR, ~[,T -~.Ob2 HTE"~, ~4LT :999 250 9991~5o -999,250 -999.250 -999,~50 -999.250 :999.250 999.250 6.160 6'086 3.000 140.625 56.21.9 6~5.000 4.700 510 9,o: °° -O.070 -0.100 516 500 203~125 2 094 4~:438 794.000 3479 24~7i538 0 063 43 438 6.520 6 492 o o 0 o 148.375 60.906 660.000 76.800 488.000 973.200 -0.070 -0.003 283.250 193 5O0 2:396 93.3~3 751.O00 2.783 3135.580 -0.062 93 313 CI~P.DTE C!LM.DTE IMOF.DTE I!X~ DT SDT TTI~SOT BT!!.SDT HTEN.SDT PEF.LDT bU,LDT SS2.5D? S!~H.LDT EN$.LDT NPH!.CML ~POR.CNL CFTC,CML ~TE~,CNL TENS.MLT C!~P.DTE CIbM.DTE IEgF.DTE IIX~.DTE TENS.DTE DT.SDT TTI,SDT bTT1.SDT GR.SDT HTEN.SDT PEF,LDT LU.LDT SS2.LDT bSRF.LDT TENS,LDT NPHI.C~L WPCR.CML C~TC.CNb ~TEM.CNL TENS.ULT PAGE:: '999,250 '999,250 :~99,250 '~99.250 :999.250 999;250 -999,250 146.750 I49'000 0,O00 32'094 54001000 76.200 618.800 IOB5.600 56.219 85'000 ~07,875 539 500 221 250 2.012 5170.000 46,585 41.831 699 442 ~5:125 5170,000 156,250 157.375 0,000 5i;4 71,1 5~000 77,600 485,200 876.800 60,906 660,000 3.822 264.750 ~69'000 2,385 5330,000 30,641 29 165 1163i250 185 125 5330.000 DFpT. 1! 900.00C I ~.[,:'U, DTE 2! ,70',] ! L O T F 2 i, ! ~ 5 SFLU, O~E ~2,656 , r, PTI,. S.T 64,5oo TT~, SPT 303,600 L~'T~,SD~ 6P~,600 L~. LDT lo~. 43~ LS. tdV, LDT 2034,000 L u r~ ~. 5 P T 2.56 i XTF:V. [,,DT 125,625 TNP e ~'~ i, 2.249 GP. CN'I~ ~0,547 '~iT'g~'~. Clq L 709.500 ~ T g ~,:'. ~,' !.., T 709.500 IL ~ DTK' 25,4P4 I ' ' 11 ~r:,' DTE 26.578 I IX .. ~., ~ ........ ~ . ~. . T~;~. DTF l ~ 4.8 V 5 ~,! [? ES. DTE DT'[.,. SPT 81.300 DTI.,~. 5DT Tm~. SDT 347.6o0 TT3 [, T T 2. S D T 797.600 L T T 3. S D T TFr~JS. SDT 5140.000 LL.L~T 114.938 [.,,ITH. LDT LSHV.LDT 2o]3.0ao LUP?. [,D'I 2.516 CAI, I. L.:DT ~TE~. LD~ 186.125 PCh~7'. C ?,iL 457t.043 ~CFT.CN!_~ g~. C~,~L 40.906 T~}h,S. CNL HT~:~. ¢~[,T 665. 500 ~4~ES. ~.~I,T I"~ [~: p T. 1 !. 700. 000 I~Pt,~ DTE: l!ar,.r)q'~ 12.977 S FT.,': r', T ~" 8~l .563 ~TT, ~DT 62 bTT?. St'~? 61 4. ~ _ :.. , ,:,. ?Ft-:S. e r,~, 5h 1 O, f}(') 9~PI. l.,b7 2.720 11-Al)G-1992 05:4:1 40, ~8 t IDPH.:OTE ..... D~' E 20. 000 IDROF. ......... !,042 ~ DTE .3,~13 GR,DTE ~:~3. ~00 DTLF'. SDT 546. OO TT4,SPT ~70,400 , 2.637 D~HO.LDT 0 ' 090 b 8 ' L O T 34. 094 88 !, LOT -0,061 HTE~, bDT !O. 752 TN~h, C~L 52i. 5.000 ~4RES.CN5 9. 656 GR, aLT 30,609 IDPH,~.TE 30.4~4 !LD,[)TE 20,000 !DOF,[)TE I .460 !IR~.DTE 14,977 GR. gTE -0.069 'HTEN'. DTE D~ 1.116,400 LTT4,S.. !84.875 ~RES' Sr)T 2.510 DPHO.LDT 0.046 34. ~ 19 875.000 S!RH,LDT 8.35~ GR,bDT -O.Obl HTE~,LDT t5.7~9 z447,58~ CNTC .. , C N L 'O.Obl 1-3.414 IDPH. L)TE 14.328 !LD. [:'TE 20,000 TDOF.DmE 0.571 I!Pu..DTE 19.578 G~. OWE -0. 070 HTE~.~. DTE 62. 800 DTI.,F, SPT 540.~(>0 TT4-. SDT ~4.000 LTT4.SDT !~4.750 ~ES.SDT 2.605 DRHO,LDI: 24 O. 44. 20. 679. 64 . 426. 754. O, 21..2. 212 t9. 709. 3954', 19. !85. 32. 0 36. 657. 104. 522. 0o 0. 225. 40 665~ 1. 5072. 40. 4 18. 3~ 60. 412. 739. O. 813 453 000 939 938 000 100 ~00 400 070 091 000 000 .354 547 50O 080 181 06 ! 547 625 625 781 000 281 625 500 100 4OO 00 69 005 750 375 479 906 5OO 77.2. 061 906 1.25 5O0 75O O,90 938 891 5OO 9O0 4O0 600 070 067 IgP.DTE i~iOF,DTE IIXN.DTE :.PEN S, DTE TT !. 8DT LTTt 'SOT GR,SDT HTEN, SDT PEF.LDT LU, LDT S82. LDT LS~H. LOT NPH 1, C N I..~ NPO~ TENS, ~"t..,T C!MP.DTE C!LM,DTE IMOF..DTE !IX~'DTE TE~S.DTE DT.SDT TT!.SDT LTT~.SDT GR,SDT HTEN.SDT PEF.LDT LU.LDT SS2,LDT LSR~.LDT TENS.LOT ~PHI.C~L NPOR.CNL CWTC.CNL ~TE~.CNL TENS,NI.T CIMP DTK IMQF.DTE IIX~.DT~ T[NS.DTE DT.SDT TT~.$DT LTTI.SDT ~R.SDT HTEN.SDT PEF.LDT 46. 5210 65. 437. 751. ~0o 679, 9. 20 1949 185 5215 40 O, 'i5. 51.40 529 955' 657. 5 247 2 5045 1.5 i? 2920 186 5045 063 281 000 801 000 700 6O0 600 000 539 250 ]75 545 000 6~5 957 000 594 219 000 242 000 200 600 600 625 500 496 750 750 502 000 674 109 125 000 18 953 0 000 '111555 5010 000 63 800 413o200 741,200 30.891 688.500 5,316 :ch!.u~'~berger AlasKa Comptttf~q Center g F7 p .'r, ! 1500. u o 0 C I D P. t:,'!i' E ..... ~' .. It,~ Draw 3e 172 IFPE, .-~ 30 23~ IlX[) DInE sFLIi. ~T~ 4:7. I>O{) ~'T~~ D'IE 1 ~],SOi, ~'~RES,'~ ' ' UTI,. SF)T 74.200 .~,37 304,4 O{', TT3, .. ~ ...... . TF~:;S. SPT 4945. ont) Ol_,S. t.~ ~)'r - (:. 027 OS S. !,DT LT,.L, DT .!33.t25 L!TH.bDT LaNV. l:tJ')T 2023.00() SSHV. !.,~T a T E a. T~ D T I F 4.625 ~.~ R E S. 1, D :!' RT,iP, C ~,; l.: I. 6~2 T:',i PH .Cai.: C~ C!,~ 1, 33.9n~ TFNS,C~L -.- e ..... , . .. ~..~ : . ..... ~' I..,'v 61 6. NOt': ,11-~:UG-!992 05:4t O, 083 LS, bDT 47.2!9 SS!. ,BDT 1864,000 8,672 GR, LgT - 0.0 b 1. g 7? E ~,~, L D T 9,635 T~RA' C~qL 44~o,713 CNTC,CNL 5015.000 9.4 ! 4 GR. ~,! I..., T -0,06! 22,656 IDPH,DTE 23.797 ILO, [)TE 20. 000 1~,051 I !R!~, [)TE -0 070 .HTE~.!, DTF; 66; 200 DTLF. sOT 58~.000 T:T4, SgT 94 ,600 LTT4,SgT !.84,000 ~F~ES, SOT 2,520 0,025 I,S. LDT 55.906 ssi, I.,, DT 1829.000 S1RH,LDT 8. 453 ~P, t.,DT -0.061 HTE~,.bDT 11,932 TNRA.CNb 3448.116 C~TC,Ci~L 49b0'000 8,773 GR.aLT -0.061 27.594 30.689 ! L 20,000 IDOF.DTE 0.785 30, I4! GR.DTE 73'500 DTLF,SDT 5S~ 600 TT4,SDT 97~: 4(:0.. 183.500 ~RES.SDT ~, ~39 DRHO.!,DT O. 0~3 !.,S, LOT 64,000 SS ! , I. fl24.000 S!RH.LDT 8 . 516 CR , ~0,061 HTF :xi. [.,DT 4..420 Tl',lR A. C~; L 31 9! ,659 CPiTC, CNL 4880.000 ~,~pEs, CNb ~,7U3 GR. ~4LT -0.0~1 2 2 387 35~500 682,500 1,337 3,396 63Z0.061 35.500 185.875 44.094 .969 4(~.000 ~7'047 42 563 659i500 66 100 .440 800 80R 800 -0.07o 0.006 228.~75 191't. 25 2.486 42'875 6375(30 11486 5751,590 -0.061 42,875 185,625 36.219 32.563 0.000 31,500 30.813 673,500 71.700 458 400 ~28:Ooo -0.070 -0,002 257.750 191.009 ~.447 33.906 616.500 ], 652 5816.845 -0.061 33.906 184.625 L[!.i~DT S52.LDT TENS.LOT NPHI.CNL NPOR.CNL CFTC,CN[, TEN'S,~LT CI~P,DTE CIL~.DTE I~OF.DTE IIt~.DTE TEMS.DTE PT.SOT TTI.SDT bTT1,SDT GR.SDT HTEN.SDT PEF.LDT LU.LDT SS2.I,.,DT LS~ bDT NP~I.C~[. ~POR.CN!, ~TE~,CNL T~NS,~bT PAGE: .625 2.537 5015,000 8,75t 9,25! 4~29,051 85,875 2~,156 2 .422 0,000 -8 703 4970 000 67 500 446 400 8O8 000 42 563 659 500 4 152 22~ 500 253 750 2 ~12 .o0 496o 11.255 I .550 3902,882 185,625 4960.000 31.234 3 .125 0,000 -10 586 4945i000 76 300 453.600 833.200 30,813 673,500 3,680 248 500 258:000 2.439 4880.000 13.677 14 423 3531. i812 184 6~5 4880,000 11, DEPT, 1 ~1. 400, OOO CiDP. .......... ! ! r~p. DTF 63,50o SFLU. UTE ! 4,438 SP. DT?~ D T L. $ [> T 63.90 ~'J 9 T L H. S D T TTP. SDT 2oS. LTTP.SDT 617,40o LTTt, SDT . ~ ~.~ CaT D P l,:i !. !, D T 4,6 t g P ~ 0 ~. L P T OLS. I,D~ O, 0 t 6 LMl.,}V. LDT 20P8,000 SS~V.LDT bt:Pv~, l,.,OF 2,592 CALI.LPT ~TN~. Ct:L I, b I I TNPH. CMl., PC~T. Ctcb 4976,799 RCFT.CNL G~,C~L .78,406 TENS.CNL ~ r . . ~[~., DKPT. !t300.000 ! ~P;!. DTK ~ 7,922 CIbD.PTE Tl~:, DTE 15.953 i['RE.DTE I!P~.DTg 66,875 I!XU.DTE SFLU, DTE ! 3.0~3 8P.DTE ~' ~ '.; J' ". ~,' "':* O ~..' · ... TT~, 8[}T 2~6. 000 TT 3. SDT !..,TT ?. SDT 6~9 600 TENS.SDT 4880.000 t') P t~ I. L D T ~, 4 q 5 R i,i 0 a. L D T O!jS.LI)T -0.005 Oc" LD,t [,[,. LDT 95.625 L!T~-t, I.,DT Ls~v. Lr)'.r po:]2,uoo i_.Ui-~H.I,[)T 2 645 C&T,I.LpT R~'~,~r:. C~ h 1.537 TNPH. C~'~L PC~:T. CN L 5 ! 47,22 l. }'~ CFT a~. C~,~I, 32.719 MTEjM CAE, 74(,. OOO 1. ~ ~. [.5'r~7' 1 6.609 I'Lu.~TF !5,8! 3 ,[F~.:.DTE I 'I' P D, {'? 'r g ~ 4.913 I I X i), SFf,If. DT~7 I 8,5PO SP. DTI,.SDT 7!.50U nmi ~: SDT ~ - ' ' ~- ''~ · - TTg. SDT 3!~) ~;0,. T73.SDT LWT?. S!}T 650.2C, 0 LTV'~. ~'.' ~ ,. ..... . . . , . ., 11-ALiG-1992 05:41 65.000 !DPa. DTE 70,625 ILO.DTE 20.000 IDOF,DTg 2.328 IIP~,!. DTE -0. 070 HTEFg, DTE 58.' 200 ..... P~'LF,o~DT 5 4 o. s o o 8/48' 000 LTT4,SDT 182.750 ~4~E5 SD'I' 2.574 0' 007 L,S. LOT 45. 406 SS1. LDT !826.000 81kii. BDT a.992 G!~, LDT -0,062 HTEN. LOT i4.923 845,558 C~:TC,, 930.000 9,414 GR. 5!bT 67.188 iPP~i. DTE 71,375 ILD, . 20. 000 !PO~. DTE .... 938 4~, , DTE -0,07 0 49.400 DTLF;SDT 554.000 TT4,SDT 883.200 LTT4.SDT I ~2,250 gRES. SDT 2 . 6 4 2 [) R H 0 . L D T 0.008 35.813 SSi.bDT IR2B.000 SI~H.LDT q.7~}l G~,LDT ~ 062 ~TE~.~. LOT 3402.230 C's?TC. C~'b 4925,000 t'r~ES.CNL 10. ~ 34 Gk. HI.,T 51,750 5~ ,363 20:000 6.!37 IIR~,~. UTE 45. ! 56 G9, PTE '0.070 HTE',q. D~E 7! .600 DTLF,SDT 56~.200 TT4.SDT ~60.000 LTT4.SUT !~1,750 t~lPFS,SDT 15.367 4 1,4:8 'Oiooo 69.975 36.!56 667 500 63~]00 423.600 733.600 -0. [!70 0,300 206,625 I. 84. ! 25 2.57.4 38. 406 716o000 1.760 527~.925 - . 062 38.406 !84'000 14.867 !4.000 0 000 59'469 674.500 6].100 426.000 761.600 -0.070 0.0!l 1.87.750 !86.250 2 586 321719 740.000 1.479 5594.734 -0.062 32 719 19.297 17.219 0.O00 60.0O0 38.125 686.000 66.600 455.600 622.000 -0.070 CI MP. DTE CIL, M,DTE I~.OF.DTE !I×~ DTE DT.SDT bTTI,SDT G R; SBT ETE. ,SDT PEF, [,DT LU, bDT 882, LOT LS~'.M. BDT TENS,LgT NPOR,CML CFTC,CNL ~TEY. CNL TENS,MLT CIMD.DTE CIL~,DTE I,QF,DTE IIXM.DTE TENS.DTE T~T,SDT · 1.8DT LTT!,SDT GR.SDT HTEN.SDT P~F.LDT LU.LDT 8$2.LDT LSPH.LDT TEN'S.LDT NPH!.CNI~ NPOR.C~L CFTC.CNL ~TE~.C~L TE~S.~bT CISP.DTE CIL~.DTE IMOF.DTE IIX~.DTE TKN$.DTE DT.SDT TT~.$DT LTT1.SDT GR.SDT ~'FEN.SD? 7~o688 0.000 '8 773 4930 000 64 500 417 600 732,400 36.!56 661,500 ,063 !98,250 247,375 2 572 4930 000 14 715 14 986 3112347 !84 000 4930.000 55.750 . 00 -I0,773 4880.000 6~,100 4~ .600 756 800 33.031 674,500 5,082 184 375 246 750 2 631 4925 000 9 523 12 043 3765 539 183 375 ~925'000 60.156 63.219 0,000 -6.625 5005,000 73.200 457.600 7gO,@O0 38,125 686,000 cblumber¢]'er AlasKa Com, put::fnO Cent: er DT~: J a, 82 .. C T>T: !5 7~1 iFPE,gTE IIPD,DTE 5~:219 T!XD,D~E DT[,.SDT 4:9.900 DTL~. SI">T SDT 357. 600 TT3, SDT LTT~.SDT 760.800 LTT3.SDT TENS.SDT 4935.000 LOT -0. 004 OSS. LDT Lt,. !,[:)T 421,250 LSHV,LDT 1990,000 SSHV, !,,DT LUPH.LDT 1,809 CALI,I.,DT L[>'? 182.250 f~t R ES. LDT CNL 4.104 GP.CN!;, 43.406 TENS.C'NL HT~;~:. ~LT 828,500 aRE:S. MI,T ):KPT, 11 f':O0,00:) CTDp. I up ~.,: · D T ~ ? 7.56,3 C I L ! l R D ' r) 1: G 42,966 i SKI,t). hTE 2~ 1. 500 ~,:TEv r~WF J,~:f:, 750 DTf.. SDT 116,8 OC' i:}TL~:. SOT TT2. SnT 49P. ~00 TT3. SOT t ~T~. SPT 902. aOc, LT~3. ...... ~ ~ ~ ....... t)~Hf. LDT ~!, 65!:~ O!.,S. LDT (), 007 ¢1SS. !~DT {,L. f.,f.)q~ 519.000 LITH.I,DT LS ~-!t!, LgT 1993. () C (:;' SSH V kC~:~ C~:I.., i717 021 (;~. Ct::L 31.57 g t-iTF,~,;.CNI, ..... 744. OOC,. . ~CA~,,'f,T. *,, ~ . , ~ , . ~-, :.,. 992 ................ : 4! 2.566 O. 032 LS. LDT 50,750 SS1,LDT !.81 O, 000 SIR 9.64 ! ¢; a. b D T -o.062 16,016 2321,581 C~:T "' ' 'C, C~ 5225.000 I O. 156 G~, ~:LT 48,531 IDPH,OTE 20,000 8 q 1. 4 ! I 0,0 t. HTK::, DTE 103~, .0 LTT4,,SDT !~1.125 ~RES, SDT 1,677 DDHO, bDT O. 085 [.~S. LDT !40 250 S81.LDT 1 J , 922 GR, LDT '0,062 465,591 ~NTC'C~L 4965,000 ~gES,CNL 1 ~ .813 GR, ~.!bT 36,~75 1 P't T' D.. d D .. E 39.781 II, F,' . 20.000 IDQF'. DTE 6.324, !!R~,i. DTE 54,406 '0.070 HTE~',J. DT~ !19.300 DTbF.SDT 874.400 TT4,SDT 13~0.800 LTT4,SDT !80.750 ~R~:S, SDT ! .633 DRHO,LDT 16! .125 SSI.bDT t79~.000 S!~H.LDT !1.7!9 -t).063 HTK~:I. LOT 64 229 371:211 Cf,:TC, CML 1 ! , 484 GR, aLT -0.063 0 ~94.~25 2,482 38.938 1096.000 1.875 4592.790 0 062 182o875 0,594 9.531 0,000 60.125 57,188 714'000 51 2OO 544 800 887 200 -0 07t 0 I07 8 o:soo 1.88,000 2,043 4.3'406 828.500 3836 2037:919 -0.062 43.406 182.250 2;.094 2 .109 0.000 37.750 28.8!3 701.000 122.500 693.200 1201.200 -0.070 ~0.036 9 0.5(30 214.500 1.761 3!.578 744.000 4.631 1,821.094 -O.063 31.578 181,6~5 PEK, LOT LU . IiDT SS2, LDT LSRH,LOT ~:S, LDT :¢H:I CNL ....... CF'tC.CNL CNL TENS., .'. ,~ ,, C:IaP.DTE CIL~.DTE IMOF.DTE IIXM.DTE TENS.DTE DT.SDT TT~,SDT LTTI;SDT ~.SDT HT~.$DT F.LDT P~U,LDT LSRH,LDT TENS.LDT NPHI.CML NPOR.CNL CFTC.CML ~TE~.CNL TENS,MbT CIMP.DTE CIL~.DTE IMOF.DTE IIX~.DTK 'TEN$.DTE DT.SDT TT1.SDT LTT!.SDT GR.SDT HTE;N.SDT P~F.LDT LU.LDT S$2.I~DT LSRH.LDT TENS.bDT NPOR.CNL CFTC.CF!, ~TEM,CNL TE~S.M[.,T PAGE ,~ 13 4,11.7 210'500 253 125 2 547 5225 000 15 624 !7,265 254!'828 82,875 5 ~.~.000 53,094 63,344 0 000 -6 047 4935 000 49 900 554,400 876,80:0 57,188 7!4,000 15,8i3 758,500 268.250 1,783 4965,000 45,488 5~ .514 .151 182,250 4965'000 36.250 39,719 0,000 -11,547 4895.000 121,700 701,600 1154.800 28 7o,: O0 12 867 921 000 309 750 ~ 668 4985 000 60 135 64 673 398:900 181,6~5 4985,000 'chlUmberqer Alaska Compt~tins Cent:er ~ F ~ D'r F 18 0.25 0 ~ P F; S, f)T ~ ~ T L, $ P ~ I 0 g, 5 r~ 0 P TI. :~.J. q r..v TT2, SDT 4 ~4,000 TT3,SDT V ~:~ ~ . b g T ~ 3 , 218 R ii O ~. t, g T L[~,LI')T I~4:000 Li'.,'d LDT , · ~r ~NV,!,D~ 19~8. 000 SSHV, LDT ~T~':~ LPT i 8 1, OO(~ ~4RES,, [ C ~ L 4.04 () T N P H. C .~; L pCNT.CNL 2204.092 RCFT,CWL El P T. 10800.0 O 0 C l r~ p. p T E ' . ............ IFF:[,.DTE I R [.t, L) T E ~ 7 ~' = ~" '! !' X O, P T E; SFb!:!, DTF I 0.64 ! SP. PT!.,: SDT 99'30r' DTT,~4 sP'r T'r2, SDT 370,4C, 0 TT3. SPT TT2, gDT ~ 12,400 LTT3,SD:[ TF~''e S[)T 4725 O0U ~TF'~I sr~' :,~ ~.~ ~ ~ ,.-. ,,,, . . ~ ....,, D~HT ,!,DT -8, (') ! 8 O!.,S. LD~.I' 0,043 OSS, 1, I,. LDT 79.6~ I.,IT~I. LDT LgMV Lh~r 1°~4.,000 ,bSN~.Lr) TEv. LDT I ~0.75o ~.~RES. LOT PC,',~,C~,,~[, 302o.~9C, R Fr C~t- aP.CWt 29. IVP FpT. I. 07~0. O00 CTDo. [';TF ~ P H. P T R7 9.4. 77 C I T, [). g T F: TI,u.PTF 8,703 TFR~;.P,E biTWv . DT~ I 7 9,375 ~PFS. DTE F' ~ !,, S D'r ~¢ 2. o 0 o D tr .I., r,}. s O T 7'I'2..SD'f' 3~7.z."Of~ '1'3.5Di' TT2. SDs' 730.4o~'~ LTT3. SPT ! ! '"AL!G-!. 992 05:41 15i., !'25 I 54,125 2 o. o o o 8 266 -0,071 1 1 1. 900 761,600 1. 2(,)2.4o0 2.267 0,066 I. 787. 000 !1,680 -0 063 44 297 51..~ 699 4970 000 i i 95,563 97. 000 20.000 9,430 48.000 -0,~7! 99.. O0 722. 400 ~.~!9o600 179,..975 2.782 0.037 1.78!,000 11.047 -O.063 2t~.414 :I051.. 3~6 4.~b0,000 11 ,570 -0.063 93.250 98,125 20.000 7,395 55.094 -0.071 21.8O0 646. Ot)O IO81.2on .!.. 7g, 375 !bD,DTE I [>OF, Jil, RM ,f)TE GR. HTE~,? , , .f' [. TTg,SDT LTT'i, SDT O~ H.r3. bDT !.,$, I...~ D ? 5~ 1 . bDT ~ 11:;:~ ........ GR.: bDT HTEN, LOT T!'.~R A, CNL .... · ,,, ,,; · C N L dR, M bT NTEU, MLT 6,6t3 6,484 0.000 149,875 28,438 674,500 !07.800 596.800 1030.000 -0.071 0.022 360.750 213.250 2.~.72 35.000 736.000 4.008 2077.977 -0.063 35 000 l l:ooo 10,461 10.297 0,000 146 375 69$. 000 102. 000 56 !. 6OO 969.600 -o 071 0;027 156. 375 !83.375 2,672 29.1.72 699,500 2.770 3558.598 -0.063 29 1.72 l o:Tso 10.719 10.18~ 0 000 !08~56] 65.000 683 500 '"79~000 504,o00 88~.400 -0.071 CIMP.DTE !MOF,DTE TENS,DTE DT,SDT TTI,SDT LTT~,SDT HT~W,SDT P~F.LDT LII,LOT S iLvT LSRH,LDT TENS,LDT MPH'I,CML CFTC,CNb TEbS.~LT cIb~P,DTE CIL+~.DTE IMO. F.DTE IIXM , ~ TE!q $. DTE DT SDT TTI~SDT bTT l. SDT GR,SDT HTEN, SDT PEF. bDT LU. bDT ss2 LSP~, bDT TEN$,LDT ~PHI,CN5 NPOR.C~L CFTC,CNL TENS.~LT CI~P.DTE CI[.,~.DTE I~OF.DTE IIXM.DTE TENS.DTE DT,SDT TTI.$DT LTTI,SDT GR.SDT HTEN.SDT 159 000 0 000 -15 578 4765 000 400 1039 600 28 438 674 5~0 I0 ~ 250 282 5O0 2 244 ~970 000 48 745 39 04] ' 558 079 !81 000 4970~000 140,1~5 155,250 0,000 -9.406 4725 000 100 600 585 200 965 600 36 t88 698 000 7 023 2 375 2 754 4860.000 27 32 682 !318 022 180 750 4860 000 105,500 1!4,813 0.000 9,I09 47~5,000 81.100 506,000 S87,200 65,000 683,500 ,!S q'aee verification Listi, r:c? chIumberqer Alaska ( m~t'..in~ center bi LDT 37! ~!)0O LITk!.!,~DT LSaV. LPT 19a 1. 000 . .C~gb 2513.303 ?~TEX~. ';~ [~T 736.500 0600. 30,234 2 V. 7 48.43 7 2,300 3 1. 4,000 ] 0. 503 0.0 t:) 4 124.500 19 ~ 5 , 00 () 2 . 502 179.875 1 77 ~ 43.844 729 500 · ....... .I: ~'' P ~'~. O 'r [,; 8,2 a 2 C ! b D SFIi.,U. DTE q. 207 SP. DTE ~Tg~,~ , [~'~F 17 fi. 37 5 r~TT,. 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BDT 28.693 THR~..C~IL ~n77.702 C~,TC.CWL 4a25.O()0 1 1 .g45 213,250 1.9!9 68.31.3 736.500 3 586 2962:791 ;0 063 180.125 42.344 34.750 0,000 31.438 45.438 699,500 70.700 45!.200 8~0.400 0.071. 0 007 ]7:soo 186 000 :sio 43 844 729~500 ! 747 4979:974 -0 063 43:8a4 1.79,875 8477 s: o6 0.000 !21.375 57.594 697.000 70 800 844,000 -0.071 0.063 261.500 213 125 21 7s 56.094 642.000 2.772 3233.@95 5b.094 179.~25 L D T 882.LDT LSR~.LDT TENS.LOT ~PHI,C~L ~PoR.C~b CFTC.CML ~TE~.CNL TENS,MbT CIMP.DTE CILg.DTE IIX~.DTE TEMS.DTE DT.SDT TTI.SDT LTTI.$DT GR.SDT HTE~N'SDT PEF I~DT bU:LDT SS2.LDT LS~H'LDT TENS,LOT NPHI.CNL NPfJ~.C~b CFTC.C~L ~TE~.CNL 3E~S,~bT CIMP.DTE CILM.DTE IMOF.DTE !IXM'DTE TENS,DTE DT.SDT TT1,SDT LTTI,8DT GR.SQT MTEN,SDT PEF.LDT I,; l]. I,, D T S$~. LOT LSRH. [,DT TENS.LOT NPNI,CNL NPOR.CNL CFTC.CML TENS.MbT PAGE~ 15 4,758 669,500 316.500 1,863 45,000 5141.096 46,885 837,458 180,125 5145,000 31.078 33'031 0 000 -12 664 4690 000 72 100 452 800 824 000 45 438 699 500 6 !04 226 000 252 875 2 482 4835 000 12 390 13 6~2 2932 792 179,875 4835,000 !.21 188 i28:500 0 000 4615 000 741100 70 000 40 800 57 594 697~000 7 590 258i250 263 750 2'418 4425 000 26 963 28 549 !160,2!0 179,125 4425,000 c~l.~!mbercJer Alask:a COr~'~Futinq (?enter DFPT, ! 0400,000 I ~PF. DTI~7 !~,906 CILD,DTE 1 t5~, DT~7 J. 7.844 I Tr~D,I)TF 47,094 IIXD'DTE ~d T E ~.~ DTF !.77,g75 !...~.!2,SDT 65I 200 L~7~ TF~S. SPT 4575,000 DPI~I,LBT -.~ ' 5J (} PHOB,LDT OL, S. L DT 0.0 30 L L, L D T 83,0 O 0 L 1. T H L, SF~V, bDT 1977,000 SS~V L['~, LDT 2 , 752 CALl ~EU, LDT i78,375 ~tR~ S.LDT ~?'%'~, C~'~ L 2.273 ~ C ~,,~T. Ct.:,JL 383~,813 RCFT,C~*b NTF~'.CNL 732,500 00,000 CIDP,PTE 15,008 C!LD 15,()39 I""'" .. . 55,4 O 6 I ! X 17,750 SP,DT 33(> $~nf:: TT~ SDT 40 ;:' 0 S D T 70, o I02,063 LITH, LDT ..... ,. 2c~27. 824 9~ 1. fPO0 1. 1-AUG-1992 05:41 4. ~. 688 I D P 51, 51,969 ILO, r)TE 20 000 0,793 26, I~S ,0,07! HTE;¢~, DTE] 1,800 DTLF,SDT 564,000 TT4,SDT 1014,000 LTT4.SDT 177,875 MRES,SDT 2,724 DF~HO, LDT o n41 b8 10' 727 'GR.LDT 1487,887 CNTC,CNL 4600,000 MRES,CUL -0.0~3 57,938 IDPi;~,DTE ~ 1.405 I b D, D T 20,000 IDOF,DTE 2,449 I!R~I,DTE 32,53 !. GR, DTE -0,072 HTEN,DTE ~6.100 DTLF.SDT 668.0C0 TT4,SDT !039,2()0 LTT4,SDT 177,375 ~.604 DRHO,LDT 0.021 LS, LDT 37.563 SS! ,LDT 748 000 S1R~,LDT -0,063 ~TEt~,LDT 30,01,8 T~IRA,CNL 97! ,948 C~:TC, CNL 48q0.000 i5,797 20,031 ILD,OTE 20,000 3 051 -~4]o~7 ~. o~; 70.300 DTLW.SDT 591.200 TT4.SDT 9~1.200 LTT4.SDT k ,,~, S D T 20,516 19.219 0'000 5~ 188 700 500 66 000 439 200 ai: -0.071 163:000 1.73,875 2.736 61.813 732 500 36~2 ~7 ! o:o6. 61. 813 17 8 .' 37 s 17.250 16,266 · o, ooo 5.8.1.25 700,500 · 69.900 503 200 -0 072 o: 1.98.500 187.750 2'557 60.844 921,000 2.848 2919.?16 O.063 60.~44 177.875 03.281 49.906 0.000 20 313 722,000 69,900 455.200 800.400 CIMP.DTE CIb~,DTE I~:~OF.DTE !IX~.DTE TENS.DTE DT.SOT TTI.SDT LTT1.SDT GR'SDT HTEN,SDT PEF;LDT LU,LOT $S2,bDT I.,SRH,LDT NPHI.C~b NPflR, CNb Cr ,.: C. CNb ~TEM. CNL TENS.MbT CI~P.DTE CIbM.DTE I~OF.DTE II×U.DTE TMNS.DTE DT.SDT TTI.SDT LTT~,SDT GR.SDT HTEN.SDT PEF. LDT LU bDT $o2:LD* II~SRN,LDT TENS'LDT NPhI.CNL NPQR.C~b CFTC.CNL ~TEu.CNL TEN$.~LT CI~P.DTE CILP.DTE I~OF.DTE IlXU.PT~ TE~S.DTE DT,SDT T'rl SDT GR.SDT HTEM,SDT 52.875 ,000 5~.ooo 4575.000 66 900 438 400 824 400 68 125 7O0 500 5 746 159 875 216 625 2 727 4600 000 ~9 440 ~8 476 I66 ]75 17~ 724 4600 000 66.563 6~,438 ,00o -9'~28 4570,000 69 500 5!3 600 893 200 58 125 700 500 4 484 192 750 246 375 2 594 4890 000 28 834 27 984 1042 515 177 875 4890 000 19.063 21 344 0:000 -9,594 4515,000 71,400 447,600 802,400 139,531 722.000 ~18 Ta~e Veri, ficatlon Listin(~ ~chl. umber¢~er A].esk8 Co~...Jti. n...,,, 0 ('2ehter. ObS,LP:? -0,0! 2 LL.LDT 1 I9.3 !3 t],SNV. L[)T t951.000 R T ~:~ P, C ~ L !, 664 GP, C?:[L 49.375 ;-~TEN. ~f..,T 7 ~ 5. 500 D'[f~PT, I0! O0.O(~t~ CIDP.DTE IL~,DTE 14,602 I~;~,DTE 50.406 IIXP, [;T~5 DTL, SOT ¢0,200 DTLN. SPT LTT?.SD~ 9o8.aeo LTT3.SDT TF~$. SUT 4345.0e0 ObS. LOT 0.016 OSS. LOT LI~.LDT !dS ,250 btTH. I,DT L~NV,LDT !9~4,000 SSHV.LDT ~CNT,CNL ~373,285 RCFT,CNL GP, C~'.:'~ t, 57.219 PEPT. 10000,000 CIDF. DT.E !~'P?.DTE 46.644 CILD. !)file IL?. [)TF} 47,906 SFLt~. DTE 65.06~ ~dTE';. DTE 166.¢,25 ~4 RES. !)T!f [}T~. SPT 78.100 PTLq. SDT TT2. S[:,T 390,40C' LTT~.Si>T 766.000 LTT 3.5I', !~ TF?~.Sf)T 7575,00C ObS. !,aT -9e~, 250 LL,L?~ -99q.250 l.,Sqv. I P'r .qqo 75o [,UP,. ~,[>T -999.250 ~'~,,P. (~t;L -999.250 T~Pit. C~.'L ~i7'K~ ChL -~Oq },~, ~.~CAL ~Z!.T - · - . -- -- .~ o , -,..; : : 1 ~ -~ i..iG-~. 992 O5:41 2,497 DR~O, LOT O, 017 [..S, LOT 42.844 SSI.LOT ~ 740.000 $1R~{. LOT 9. 305 GR,:LOT -0,063 gTEq. LDT 1.~.6i9 TNR.h. CNb 323~ . 30~ cNTc. C~I. 4540.00o ~RES.C.NL 9. 609 -0.06 ] ~,~TEM, HLT 57. 125 IDPH.DTE *~'5 gTE 55,,~,,. 0 ILO, ~ 20.000 ! P O F. D T E 15 3q CgR DTE '0,072 HTE~q, DTE a {) o · o o o J} f 4 ' s ~ f t~90.000 LT'T4.S[ T .76.3'15 ~RES,SDT 2,425 DR~O,LDT O, 037 L5, LDT 71,500 SSI,bDT i742,000 S1R~d, LOT I !, 266 G~, LDT -0. 063 HTFN. LPT 42.009 'fl.:.~At .CN 6~6,354- .... C~'~TC, , ~ C~'~ .., _b 4460.000 ~RES,CNL 11,. 406 G R, ~ b T 15,250 I'DP~,DTE 18,266 ILD,D'rE 20,000 I . 074 ! Ig:~, DTE -0. 037 NTE~,~. DTE 69. 400 DTI.,F. SDT 670.400 TT.!.SDT 1082.~300 I,T~4.SDT 166.625 ~ES.SDT -g99.250 DRHO.LDT -999.250 L$,LDT -999.250 SSI,LOT 999 25o 8! R~. E,,DT -99q. 250 HTEf.~.bDT -999,~50 TN~A.CNL -999.250 C~TC.CNL -g99.~50 ~gES.CNL -999.~50 0.003 187.250 2.500 49.375 7~5,500 ~. 562 55!~,790 -0,06] 49' 375 ~77,500 19.172 18,078 o.ooo 64,938 48.219 734.500 90.100 638.000 l!12 400 0,026 277,250 2O5 250 57 219 ~4:.ooo 3.606 ~45]..36g -0 063 s7:~t9 !'t6.875 65 50O 54[71.9 0 000 22i172 -999 25O 1776.000 -45 600 525~600 9~7,600 -0.037 -999 ~50 -9991250 -g9g 250 2!.2!9 -g99.250 -q9g 250 -999:250 -999 250 -999.~50 PEF.LDT LO.LOT $$2.LDT bS~M.bOT TEaS.LOT NPHI.CNL NPOR.C~L CWTC'~b TENS'MbT . CI~P.DTE CIL~.DTE IMOF.DTE I!XM,DTE DT,SDT TTI,.SDT bTT~[ .$DT GR,SDT ~TENiSDT PEF,LDT bU.LDT SS2*~DT LSRH'I, DT TENS.LOT MPHI,CNL ~POR.C~L CFTC.CNb {TEM,CML TEaS.MbT CI~P,DTE C!L~.DTE IM@F,DTE IIX~,DTE TEMS.DTE PT.SDT TTi.$DT LTT1,SDT GR,SDT HTEN.SDT PEF,LDT LU.bDT SS2.LDT !.,S~H.LDT TENS.LOT NPHI.CNL NPOR.CNL, CFTC,C~}L ~TE~.CNL TENS,MI, T PAGE: 17 222,1~5 252'250 2,498 4540,000 II~]46 !2,~960 3547,625 177,500 4540*000 49,!25 68~438 0 000 -I. 1 !25 4345 000 89 600 644 000 tlOf 600 734 0 4,375 258'~50 27~,750 ,39~ 4460 000 41 590 4~ 076 686 934 ~76 875 4460 000 0.000 0.]16 7575.000 74,900 521,200 9!8,800 -999,250 1776,000 -999,250 -999,250 -999,250 -999,250 -999 ~50 -999:250 -999,~50 -999,250 -999,250 -999.~50 I$ T ar~e Veriticat~or~ 1,istlnO chlumber~er ~.].,.':~ska Co~put,in~ Celt. er DFPT. 9900.000 CI[}P.D?E I~}l. DT~ 14.3a4 I!~D.DT~ 69.063 II~D.DTE SFLU, DTE t 4,74~ $P, DIE ~w~TM ['>TF ! 66,750 t~v~E~ D T L. 8 D T 7 t). 7 0 O D T I, N. .......... ~D T TT~.$DT 37! .600 TT3.SDT bTTg,SDT 735,~00 LTT3,SDT TENS.$DT 7t85,()o0 MTEN.SDT DP~i.bDT 2,487 RHOB.LDT eLS. LDT O. 009 OSS. bDT [,~.bDT 101.81.3 !,ITH.LDT :; ..I~[}T 2.619 CALl. RCr~T. Ck~!, 24~9,258 NCFT,CNL C;P. C~L ~5. !25 HTFk~.NbT :!~547. 000 NRES, ~LT IL~,DTE 53,656 ¢ TF ! 2,797 D T E ~ 0. ~ 38 [) T F'~ 167.000 gDT 68,900 SD'F 371. 200 S r ~ T 744,. 00 (3 S [':: T 7235.000 !., D T 7.73 c L [9 'r 0.0 ~ ! I,P'r ! 39. 250 V.l.D 1957.()00 b n T 2,4 ~ ~ LIPT ! 67. OhO Cr~. ~ ,7~ C~:l, 39a9,94.~ I!-.,aUG-!o(g2 o5:41 72.625 I D 75.938 20,000 ID~F,DTE 1.298 !IR~;,DTE 72. 000 GR. DTE 69:900 DTLF, SDT 650.000 TT4,SDT 1.023.600 LTT4,SOT 166,750 2,609 DRHO O. 010 LS, LOT 50.719 SSI,LoT i 789,000 SiRH. bDT -0,036 HTEN. [,DT 30,545 TD'RA. CNI~ 7~7,134 C~TC,CNL 7185,000 ~RES,CNL t 3,234 GR -0,036 MTES~, z~LT ! 2. 656 IDPH. DTE t, 4.031 iLD DwE 20.000 IDQF'DTE -0.!46 I I~:~. [)TE '55,128 GR, DTE '0.036 HTE~,2. DTF 67 . 300 DTLF, SDT 650.~00 TT4,SDT 1031.200 LTT4.SDT 167.000 N~RES. S[)T 2'522 DRH~.bDT O, 036 I.:S,LDT~ 83,625 SS1. DT 1793.000 S1RH.LDT 12. ~6 ! G~. bDT -0.036 HTEN,LDT 1~'777 TMRA,CNb 2295.]60 C~;TC,CNL 7235,000 ~,IRES,CNL 12,922 Gu. MbT -0.036 37.250 IDPH.DTK 39. (~94 IbP. DT~] 20.0{?0 IDOF. DTE ~0 625 I IR~;. DTE - 2:563 j0,036 HTE~.~. DTE I ~.4oo O~bF,SDT ~72.4(:,0 'rT4.SDT 1015,20~ [,TT4.SDT 16,6,750 ~SFS,SPT 1,3.758 13.164 0.000 70.938 95.!25 1547.000 6~.600 514.000 887.fi00 -0.036 -0.001 !,97 250 181:625 1547.000 2.81] 26!2.442 0.036 95.125 166,759 78.9]8 25O ooo 17o719 40.813 1606.000 -9.000 514.000 884.800 -0 036 o:o4 246.750 204.500 ~.369 40.813 1606 000 4194.41~ -0,036 40,813 ~67,O00 26.828 25.547 O.000 40.438 71,563 1653.000 70,400 516.800 ~B3.200 -0.036 CIMP.DTE CIbM.DTE IMOF.DTE IIX~.DTE DT.SOT TTI.SDT hTTI,SDT G~,SDT HTE~,SDT PEFoLDT LU'LDT bSR~.LDT TENS'LDT NPHI CNL NPOR CN[, CFTC ~TE~ CNL TENS,~bT CIXPDTE IMOF,DTE IIX~.DTE TEM$.DTE DT.$DT TTI.$DT bTT1.SDT GR.$DT HTEN,SDT PEF.bDT LU,LDT 882 bDT hs .: nT TENS,LDT ~PHI,C~L CFTC,CNL ~TE~.CML TMMS,~LT CI~P.DTE CIL~.DTE IIX~.DTE TEiqS.DTE UT.SDT TT!.SDT LTTI.SDT GR,SDT HTE~.SDT 69,688 74.813 0,000 ~,486 7185.000 70 200 506 400 ~84 000 95 125 1547 000 2 953 190 875 241:250 7!852 609 000 70 1 923 047 ! 66 750 7185 000 17.406 000 72;0 965 s:ooo 68 900 5ti,!600 881 600 40.813 1606 000 O 2,227 232.875 267'750 79 10 940 12 667 2493 169 !67 000 7235,000 35.063 . 6.211 7425,000 68 800 5231200 888 800 71 563 1653.000 Tape Verificatl. or~. ListIr~o ,~ht.u~,herOer ,~!:aska Computtno Cer~ter 99,8 ~ 3 LITiS. L!)T 1951,0O0 SSHV. LPT ! 66.750 a R :~ S. L P T ~. 57 ~ Tt<PH. C~L 3075,3!~ PCFT. Cb,~L 71,563 1653,000 1653.009 URES, ?,~LT DFPT. 9600,000 CIDP T L u. t) T K ~., 4.906 ! F R E. t3 T E SF'LU, hTF ! 5,(3~ ~'P ~ · ........ DTL,SDT 69,300 DTI.,N, GDT .... '~ LTT?.Sr>T 748,40t) 1,~ t 3.SDq' L P ~.~ I, L D T 2.367 R ~40 B, L D T L S ~.j V, l, [;, 'r 1935.0 n 0 $ $ B V ' , L ......... D T LUPH, LDT ~, 6.19 CgI.:I. ~TWv bDT 1.66,00o ~R~$,bDT .~ ... ~ ~ ....... . [,..~, CNI, 3,067 T%PH.CNL R C % ~', C ~,} b 24 a !. 540 R C F T. C N l, HT~:~'.CNL 164 !, 000 XCAL. NI,T I~PM,PTF 6.55~ CI LD. [)TP.~ I)?'I,. GUT 7~, 3C0 DTL~'.[. SPT TT9, GDT 396. ~00 TT3. SPT D P ti T. L !~'~ 4. i 55 R ~ 0 B. I. [2 T th · - · -, . -, ..... bt,, LPT 10~. 375 !,.rT~i. LDT . ~ .... I.,,. HV. [,D~ 19a3,000 ,~$~V. I.,DT L~PR, bDT 2,563 CALl I.UT · · ,,. .- L, d~.C~r 55.219 q' }< hl~' CrL 1, o92 1780 !,2 -0 27 !O35 74125 '3 -0 .633 'DRH[}. LDT 01. 3 LS./,BT ,688 SSi,bDT 000 $tRH, ~DT .555 "G~, ~DT .036 HTEN,LDT 376 TPR..A, Cblb .~40 CNTC,C~L ,OOC aRES,CML .036 ~ TE~,t, ?.~bT 56.0 58.8 20,0 -23,5 -0,0 67.O 1~23,6 166.0 2,6 0,0 54,0 1.778.0 12.5 30.0 ~36,7 7215,0 i3,7 144 7 146:7 20,0 -8.0 "'f). 0 73.8 730.0 11.46.0 165.3 2.5 0.0 5~,7 I 782,0 !.2.7 -0.0 692,0 6890.0 13.7 0 , 004 !92,375 1 ~2.750 2'613 71 56,3 ! ,s3:ooo 2 52! ~0.036 · 1. 563 166.750 17.844 16.9R4 0.000 63.625 84.375 164!..000 67.10(} 512.400 S.83.600 0,036 0 5 25 1~4 ~75 84,375 1641 ..000 2 838 2629~747 -0. 036 84.375 J66,000 6.902 6.809 0 000 55 219 !61 :ooo 74.400 558.000 1 2O0 0.0!4 21!.750 1,9~.000 2.510 55 219 3.04] 2457.748 -0.036 55.219 1.65.375 P~;F.[,,DT S$2.LDT LSRH.LDT TENS.LDT NPHI,CNL NPOR.CNb C~TC.CNb aTE~.C~L C I M.. P , D T~7 C'!L~. DTE I ~4' r..:) F, P I' 1 ! X~. DTE TEN S, DTE DT.SbT TTI ,SDT bTTI ,SDT (,.. SDT HTMN, SDT PEF, bD~ b U. b D '~ SS 2, LOT bSRF. LDT TE~?S, LDT ~POR CNb T Et'J S, ~LT ClaP.DTE I~OF.DTE IIXg. DTE TENS.DTM DT,SDT TTI,SDT [.TT!.SDT GR,SDT ~iTY~.SDT PEF.[JDT LIJ.I, DT SS2.LDT LSRH.LDT TE~S.LDT ~PHI.CNL ~PO~.C~L CFTC.C~t ~TF;~.CNL TE~!S,ULT PAGE~ 2,854 t85.125 24~:875 629 742~'000 23,301 26 916 1187180~ I66'750 7425,000 66,188 67,000 0.000 3'557 72~g'000 . ,900 5~5 200 886 800 84 375 !641 000 2 887 190 750 245 625 2 605 7215 000 28 066 ~0.229 918,646 166,000 7215,000 152,375 158,625 o;ooo 11,406 68~0.000 6.900 594,800 997,600 55,2i9 1613,000 3,139 206,625 250,125 2,566 68~0 000 31.505 798,009 165,375 6890,000 I$ T a~e Ver,ification Llst:ir,;q chlum~eroer ,Alaska Comp,!ti~O Cer, t. er ]~PH,r)TF ~9.8~1 C]LD,DTE' TL'.PTF J.~'609 IFRE, ~T[{j I~RD.DTE d9.531 II~D.DTE SFI.,U.PTF 22, t 72 SP,PTE HTE~.DTE 164.b75 ~4RES. DTE [ ~,S,bT 728.~0(? bTT3,SDT TF?,~S, 8r~f 6750.000 ~TE~. SPT D P ~ I, I~ iL.> T 10,4 ! 2 R H 0 B, L P T O[,S, LDT -0,037 OSS' LDT LL,LDT !35.375 bSF{V,~DT ~.g3~,009 ..... SSHV.LDT LUSH. L[>'r 2,426 C~LI.~,DT ~<C'~ T. (7~4 L 2516.65k~ RCFT.C?,L OEPT, 9300,000 CI!)P. DTE t ~-PH. DTE 69,563 CIL[).[3TE I b~,*'. DTF! 60.750 !FF'.E, DTE I~RP,D~TE I1,750 IIXb,DT~.: SFI !~,PT~ 93,438 nO PTP ........... ~,.,+ . ~ ,,' .... OTL,SDT 71, ........ ~ ~,, ..... ~':T2, SOT 36B, 400 TT3, SPT [,,TT~, S[)T 738,400 LTT3.SDT T ~. ,e.,_S P 69 f) 0, O000R 7 PMTEds'i tl ~ ' SBTI., D T I')~H I. I],D~ g, ....... . ...... OLS.I.,r~T O, C, ! 6 ~)S$. !,DT LT.,. I.,DT :127. 063 LITH, LDT I,~HV,LOT !.933,000 SSHV, },D'j.~ t., U P ~.~. !., P T 2.50 0 C a I~ I. l, [2 T ~'~N'o. CNL ! .702 RCNT. C,'-~L 4513.039 RCFT.CNL D F [~ T. 920 o. 00 r' C I P P. [:, T E I~PH,PTF 54.750 l L~. DT~: 52, I 25 '[FPE. f~TF I!RP,DT~: 13,969 TT2. S[)T 387.2~O T~ 3. SnT LTT9. S~T 7 ~6. (;aC ~,!,T3. S[)T TE~iS. SOT 6745.00(? ;'~2'E~,~. SDT 05:4! 42. 500 IDPH, 44,563 ILD,DTE 20.000 tDOF,DTE 1,841 IiR~.OTE · r)'"r' E ,,,65.313 -O. 036 HTE~, DTE ~2. 400 DTLP, SDT 400 TT4,SDT 642'600 [,TT4. SDT 993, ... 2.47 ~ DRHO. LDT 0.040 I.. S. L D T 67.500 sSI.LOT 1778,000 S1RH.bDT 12,43() ~R. LDT -0,036 HTE~f,LDT 30.650 TNRA.CN[, 826,011 CNTC, Ct4L 13,648 G~.aLT -o,036 !2.070 IDPH.OTE 13 !1.7 ILD. . D T g 20,000 IDQF.[.)TE '-0 ~I, 9 i IR~4, DTE -120:68~ 6R DTE -0,036 HTE~, DTE 69, lO0 DTLF,SDT 6b~.400 TT4.$OT 989,200 LTT4,SDT · , ~e SDT !64 3'75 MREo. 2,500 Dr~HO,L~T 0,009 LS,LDT g2.~3 SSl,t, DT 1777 OOO ~402.799 C:~:TC, CNL 6900.000 ~RES.CNL i 3. O 00 (;R. M!.,T -0.O36 23.516 22,422 0.000 5l 000 156~.000 78.400 5O7 6O0 862~400 -0 0:36 0i046 262 500 20~ 250 2 316 Sli3t3 1.568 000 21993 2622 115 -0 036 3 81 3~5 82.750 76.I88 0.000 lq 664 1579.000 69.200 521.600 849.200 -0.036 0.005 240 5O0 2 475 40~188 t579.009 !.661 5 434 40,188 !64.375 73.250 64.875 0.000 1~.250 41.34.~ 1607.000 79.1.00 541.~00 938.400 -0.036 CI~P.DTE CIL~.DTE !MOF,DTE IIXM.DTE TENS.DTE DT.$DT ,T~I,SDT L.T'[:I;$OT · GR.SDT HTEN,SDT PEP,bDT !!!,LOT SS2,LDT LSRH.LDT TENS.LDT NPOR.CNL CFTC.CNL ~TE~'.C~L TENS.ULT CINP.DTE CI!.,~.DTE I~QF.DTE IIXM.DTE TENS.DTE DT.SDT TT~.SDT [,TT1.SDT GRoSDT HTE~.SDT PAGE: 20 50,250 53.688 o.0oo 675~ '293 .000 ~8,700 5 9,200 8~',400 ,313 1598,000 2 877 254 000 274 250 2 432 6750 000 3g14~5 3 2~7 903903 164 875 6750'000 14,578 0.092 6900.000 71,200 521.200 870,000 40.188 1579.000 2'277 226.875 260.500 2,494 6900.000 1.0.57:] 11.718 2666,472 164.]75 6900.000 18.250 19.172 0'000 t,144 6745.000 77.100 549,200 935,600 41.344 1607.000 Tape Ve.r'J.~fJ~cat:..ior~ l.~istinq 'chlt]mberqer .AlasKa ComP~]t:.i. no C. enteT I v p 54 ' D T I~: 2 !, 6 4 1 l ..... ~1~. 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LOT 26.044 ~40,~4~ C~.~TC,CNL 6610.000 15.555 -0.037 ,~0,007 2.6. 000 !8~.250 ..,4~6 41 344 t 6o 7: ooo 2.0t I 3731.5O6 -0.036 4 1,34:4 ! 64 , 000 24.844 23.2t9 O,00O 46.781. 48 344 1580 000 !1.4 400 725,200 13~2,800 0.037 979 50 240 125 !,623 48 344 1580~000 4.147 1482.581. -O 037 4~:344 1~3.~50 11 430 11.:242 0.000 94.938 81 125 1.69i~000 73.200 515.600 ~83.600 -0,037 0.110 297.5o0 229,500 2.137 8!.125 1691.O00 2.575 2889.341 -0"037 81 J25 162~750 PEF.bDT bU.LDT 8$2.LDT LSRH.LDT TE~S.LDT NPHI,CNL ~POR.CNL CFTC,CNL CIb~.D E I~OF,DTE !I'X~ t)TE s: T TT1.SDT bTT!oSDT HTE~,SDT PEF.LDT LU,LDT ENS,bDT PH1.CNI' NPOR.CNL CYTC.CgL CI~P.DTg C!L~.DTE IMOF.DTE !I×M.DTE TEM$.DTE DT.$DT TT1 .SDT LTTI.SDT 6~,SDT HTE~.SDT PEF.LDT LU.LDT SS2,LDT LSRH.LDT TEMS.LDT NP[~I.CNL NPOR,CNL CFTC.C~I., MTEu.C~L TENS.~LT 2 209 239 750 258 250 2 457 6745 000 15 86t 16 571 19!5 746 164 000 6745 000 46,156 49,219 0,000 3.453 6455 000 ti3 500 73~ 000 !33 600 48 344 1580 000 2 080 90 000 37~ 250 1 700 6455 000 49 861 49 916 352 797 16] 250 6455 000 95,563 100,250 000 6610o000 75.500 494.400 892.000 ~1,125 169!,000 3.021 278.250 303 500 2 359 6610 000 23 502 26 143 1o86 113 162.750 6610.000 I8 Tar..,.e verlflcatlo~ List. ir, O ct',.lutr, berc~er Alaska Computipn center .......... DTT SDT 127 600 P LTT~, SDT !. O99. 200 LTT3' 5E>T TF!q6., BDT 6235.000 DPHI.LUT 49,029 RFOB.i~DT O I, 8 I, !.) T 0.91 () O S S. L D T I, SHV. !~DT 1917,000 SSNV.LDT ; ~ ~. ES, LnT GP. C~L 75.3! 3 FiT~?K~ C..~,L 15~ 1.0o0 aPAL ~4LT a 800.000 C I P., P. i.', T F. PTE 42,71 q IFRE ,13~E ....... ~ .... DTE ~d,O00 P, SP DTFi F'~ DTL,SI3T 76.900 DT!..,i1, SDT SDT 386,800 TT3, SL, T MDT 796, GO0 I~TT3, SOT =,~W ~635. LDT 0. 007 OSS.LD'I !, 9 T 173.00 ¢ !., I T'H, !., h T !., ['~'~ I 900.0 o 0 S 3 H V. L l) C~,~L !. 7?9 TatPH. C{';L FCNT. C~':[, 422~.896 RCF',!?. CN t, GP.C?iL 3~,84.4 'rENS.C~L C?~T, 1734,000 ~CAL KIlT 11-AiJG-1992 05:41 19.656 IDPH.OTE 21 641 I'LO. [)TE 2 o: o o o ~1,747 ! I.R~4, UTE - 3.43~ GR. I)TE -0. 037 UTEri, PTE i07'500 DTLF.SDT 986.4. C0 TT4.SDT l, 555,200 LmT4. SDT 16~,!25 ~'R'.ES, SDT 1.84:1 DRHO.LOT 0,019 324. ~r)O ..... .. 176! .000 81RH.LDT 16. 703 Ga. LDT -0.037 HTE?~.LDT 57'650 TLRA.CNL 334. !30 CF~TC. C~ L 6235.000 18.016 G~.~4LT -0. 037 26.469 IDPH.DTE 27,609 20.000 IDQF,D !,658 IIR~*~ f)TE -~35,375 -o. O36 HTEN.DTE 7~,60o 9TLF.SDT 692.200 TT4.SPT 1094.400 L~T4,SDT 161,500 ~'~RE5. SOT 2.423 DRH'O, I, DT 0 046 LS,LDT 1091750 754. ooo s Jl.~19 'GR'LDT -0.036 HTE?}.LDT 13.430 2~4.313 C~:TC.C~L 6635,000 I ~. 899 GR 47.625 IPPH,hT6 51.406 !Ln. DTF~ 20.000 !DOF.DTE 4 902 IIR~4. DTE - l 21; ~.75 (;R. OT~; -0.037 ~ TE',~ DTE 76.2 0 o 0 T L ~: s f)T 668.800 TT4.SDT !094.000 LTT4.SD'P !61..0t)0 ~R~TS. 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C~L J 6!a,0OO ~CAL. ~.iLT ~',I L T 16 ! 8,009 ~ R F S. i:-: L T DF:pT. ~500.000 ClPP, !:)TE !'uPU.DTE 5. :iq2 C I!,:b'. DTE !L~'~. DI'E 5,44.5 TFR~.], I)TE I I 1~ D. 9 T ~ DTT,. SDT 75.10C, F~Tt, N. S[)T w T ?. S L? ,r 4 T E: ?: S. $ D T ~; O 05, c O 0 ~4 ,:r K ~4. S D T Of..,,c. [,[.)T -0.01 (: QSS. i,DT LI,. LbT 133. 375 r.~].~H. LF:T LSHV. Lb'l: Lt:RH. ~,p'r 2.453 CAI.:!. Lr)T aqE~. !,:9m ! 59. a75 ~PFS. LDT I i-,ai,!G-! 992 0 , 020 t r~ T !757:000 Si~H'DOT 12.016 20,226 TNRA.CaL 1384,309 CNTC.C~qL 6340.000 13. l 02 G a. ~'.,~ L T -0.037 9. 20.000 1 !5 Q F. !) T E 5,609 11 R ~4. DT E: -54,094 GR,DTE -0,037 HTF?,~, DTE 74,500 DTLF,SDT 693,~00 TT4,SDT 1-,060,800 LTT4,SDT 160,250 ~RE:S. SDT 2. 276 DRHO. LOT 1. 3 ~. ' ~ '7 5 s s 1 ' !., b'r t253.000 a!RH.LOT 15,461, GR, LDT "0.037 HTEN,LDT 33,527 TNRh,CNL 644,486 C~TC,CNL (: ! 45. 000 ~RES,CNL 15,836 GR.~LT '0,037 !72,125 !PPH.DTE: 174,750 !LD. D~E 15.805 I!P~'4. DTE -53.563 G~.DTE -0.037 HTEN.OTE 74.~00 DTLF.SDT 706,~00 TT4.SDT lf)92.000 L~T4.SDT 159.875 ~:r ES.SDT 0.0 t 7 LS 76. 000 SS! · LDT 1748.000 SiRH,LDT 13.78q G~,LDT -0.037 HTE~, LDT 1~.737 T~'4Rg.CNL !371.gb0 6005,000 qRFS.CNL 14.703 GR. ML'r -0.037 000:3 2801750 195.875 2.389 49,250 170~.000 2,211 3369.832 -0.037 49.~50 16~,000 i0.461 10.31.3 0.000 100.563 57 844, 1618:o0o 74.200 544.800 92I. 200 -o1. 0.153 454,500 25~.500 ..... .824 57 844 I618:000 3 168 2183:oe3 ~0 037 7:844 160.~0 805 0.009 172.750 38 250 ~575:oou 74.60o 557.200 947.&00 -0.037 n 024 2ss:ooo 201.500 2.377 38.250 1575.000 ?.~76 348~.7~9 -0.037 38,250 159.875 PEF,LDT LU, LDT SS2. bDT LSRM, LDT TEM$,LDT NPHI,C~L C:k~c.c,~ MTEM,CNL m~N:S ~LT C!~P,DTE CIbM'DTE tMOF.DTE tlX:~.DTE TEMSDTE TT~ SDT LTTi:SDT GR.SDT HTEN'SDT PEF.LDT LU,LDT 582,LDT I,,SRH.LDT TENS LDT CFTC.CSL ~TE~'C~L TENS.~LT CI~P.DTE CIL~.DTE !~OF,DTE IIX~.DTE TENS.DTK DT,SDT TTI.SDT LTTI,SDT GR.SD? HTEN.SDT P~iF.LDT LU.LDT S$~.LDT LSRH.LDT TENS.LDT NPHI.CNL NPOR.C~L CFTC,CNL ~TE~.CNL TEWS.~LT PAGE: 23 2.348 262'000 26~'500 ,400 631~.000 20,863 1536 '316 .'176 161,000 6340.000 1. '313 0 000 91109 61:45'000 73,100 537, O0 922'~00 57,844 16!8.000 3,!37 423,250 6145,000 31.851 32 733 684 520 0oo 181 875 is~15oo 0,000 14.359 6005,000 75.400 557.600 943.200 38.250 1575,000 24 125 27 000 2.453 6005.000 17,628 18.199 16t6,477 159,875 6005.000 Tape Verification i istir::q chl,a~ber~2er Alaska Co~,outinq Center I "v'PP' ,. BT g ;!0.898 CIL[). DTF~ 1 L ~. D T ~ 11.1 33 ! F R F:. r~ T E' l'l RD. i) TF 81 ~ 625 IIX[). DTE; T[~'NS. SDT 61SO.Pt~,0 [>PI!I, LDT iI,566 LUR~, La'~ . . C,A. LPT RT. ~ P. C [~ L 2.7 C 6 T % P H. C N L PEP'T, 8300,000 ¢I9. P,OTE !L~, DTB !.4,563 !FRE.DTE I IR~.BT[~ 58.93~t I!X[~.DTE SFLU,DTE 16,43g LTT~. SDT 8 ~7.6(.,0 bTT3. SDT DPHT,LDT 15.5~t) Ol,S. LDT -0,029 L !.. !., [) T ! ~ 3.25 (> 1.., I T ~. L D T LSHV.I,DT 1~94.000 I.,!~P [~. L!>* 2.77(> CAI,I. !,[)T R'r ~,~~ ' ", T pC~,;T CNL 2767.~46 PCF.T.Ci:~L (;P [C~:'L '70,313 ~TF:~.~, Cn~I. ! 575,000 ~.~C~ ~Tlf k;. ~,, 1,~ ~ 575. 009 il-AUG-1992- . ,: 05:41 91.563 IDPH.DTE 92. ! 25 !LO, DTE 2©,000 IDQF.DTE 4,4i8 IIR~q,[)TE - 60 .. 250 -0,037 7oo 720.400 TT,4' s[)T 1127,200 LTT4.SOT 159,250 . 459 P R . .007 LS,LDT 8J'l~d5 SSI.LDT 1742,000 SI RH. LDT 13,313 -0.037 UTE%, LDT 26,6O6 q33,970 CNTC.CMb 6~ 50.000 ~F~ES. CNb 14; 273 (*0.688 IDPH.i)TE 65.~I. 3 il,D. DTE 20.000 4.816 IIR[~ DTE -47, ~44 GR ' -0.037 HTE~¢.DTE 77.400 DTLF,SDT 744 800 TT4.SDT 1 i {"')7 [ 600 LTT4 · ' '" ....... 1.58.750 ~RES.SDT 2.393 DP~10.LDT 0. 043 LS. LDT t.()3' 93~ SSi ,.bDT 1743 O0O S1RN, I, DT -0.037 19.518 1157,435 5795.000 ~PES.CML i 7. 344 -0.037 36.094 IPP~. ~)TE 37.9~g l LD. OTg 20.000 !DOF.DTE 2.~85 I!R~.DTE -~ 3. 938 CR, DT~ '0.037 NTE~4.9TE ~0.000 DTI~F, SDT 754.400 TTi.SDT lJ.~4.800 I,TTg. SDT 15~,250 a F~/S. 8[>T 10.914 1.0.844 0.000 85.063 81.625 1658 000 :ooo 560 000 9731600 -0,037 0.006 . 2.430 ~.625 1,658 000 2726,102 -0.037 81 625 591 so 16.469 15.188 0.0OO 5.125 o.313 t575'000 74.200 599 200 -0 037 0~118 346.750 ~37.375 2.035 70.313 1575.000 2.355 2895.628 -0.037 70,3~3 158.750 27.703 26 329 o: o(io 32.719 36,000 1634.000 82.200 593.600 1011.200 -0.037 C!~P, DTE CIL~ - DTF I !X~, DTE OT SOT LTTI.SDT GR,SOT HTE[~,SDT PEF, LOT LU LDT LSRH, bDT T~U S. N POR. C N CFTC, C NL ~qTf~. CN L TENS.mBT CtaP.DTE CILM.DTE IMGF.DTE · . ~ ~ "'~ TEa$,D~L DT,SDT BTTI SDT c;rlS T PEF,LDT LO.LDT SS2LDT LSRHiLDT TE~S BDT NP~I,C~L NPOR.C~L CFTC.CNL ~T~,C~b TENS.~LT CIgP.DTE CII~.DTE IMOF.DTE IIX~.DTE TENS.DTE DT.SDT TT~.SDT [.,TT1.SDT G~.SOT HT~N.SDT PAGEI :24 91.688 89,750 0,000 81 200 565 600 971 600 Si 625 1658 000 2 457 240 125 267,250 2,453 6150.000 t02,196 6150.000 65 8t3 68 625 0 000 5795 88 000 603 600 985 200 70,313 1575.000 2,969 327.250 3!7,250 2 273 5795:000 19.227 19,314 1263 028 158:750 5795.000 32,875 3.4,406 0,000 2.691 5980,000 5 ,400 1018,400 36,000 1634,000 !S Tane V~r~l,i, cati.n~ ~istinQ chlumber~er Alaska Co~Out:.i. no Center DFP? .~ I nO. (~n{) ¢'IOP.DTE !~ ~}"~ DTE7 4,41C CTI D I -" .... I a~.- IL~.... ~F ,! 324 IF~E,PTE l ! R r,. D T ~? 199,12 S SFI,U. O TF 4:. 082 .... $ t)'r 418, ~ o o T T 3, S i') T I..,TT2. SDT 836,800 D P W 1, L D Y I 1.. 949 R ~-~ O B. !., g T },DT f~ 01 ~ i'}SS 'I.!'~T L L. L U T 13 ~. 8 75 I..,: l T H. b D T L S H V. L D · 1 223,00 () S S ~.~ V, L I) T L T.!Ra. LDT 2,447 CAI~!,bUT ..... -,~ ~CteT C~L 232...(..~4a RCFT CNI., GR CNT, 63.628 ....... · . C N [.. 1. 735.000 ~.~ C ,~ b. ,~ .. ; ~ ':'. : v ~ .. .~ . a,39~ TFR~.r>TE 1 ! ti ['> · !::, T E 99.125 T, SFI, U, gmS:'; ! 6,125 SP. DTE ~'~ T ~.,;~ . DTF 1. 57,259 ~'TL. SPT 72.200 ~?Tt~i, SDT TT?. SPT 37.~. 000 TT3. SDT LT~:2. ST)· 802.40a LTT3. SD:_T TF~';S, Sa~ 57~5.000 OI.,$. LUT 0.019 QSS. [.;!,. !.,I?~ T 123.563 !,SHV. LDT 1 ~'i ~q, O('~C SSHV. }'~DT [~m~,:~ ChiT., 2.b25 T~:.~PN CNT. ...... ~ -~ ~ . . ~,C',~T. CK[, 267 ~. b23 RC~T. !-iTEN. CNT, ! 677. ,)00 ~CA[.,. ~,<I,'F 1 !-Al!C;-!. 992 O5-4I 2.449 0'0~ 6 LS, LDT 91 375 SSi.SPT !737 000 Slla'!i,'bOT !~ 242 ~' '"i BDT , n37 H'.. [, ~,., 15,5~9 I877,393 C~ TC,CN[, -0.037 221,875 223.875 iT,.,D, gTE 20.000.. IDOF.DTE 16,703 !!RF~ DTE -~3.625 ' GR','DTE 87 800 DmLF'SDT 75'7~200 ~T4,SDT 1344,000 LTT4. 157.625 aPE~S,SDT 2.453 DRHO. L, DT O. 038 LS. bDT ~5 125 !72g.000 81RH.BDT 13. 055 G~. bDT ' 0,037 34 238 TNRA.CNL 7 o 4 ~ 736 C 5885,000 '~ES.CNL -0.037 106,563 !r~Pia DTE · , .. k/ ..' ;~: m ., 109.313 IL!.). Otg 20,000 IDOF.DTE 8.750 -40.000 G~,DTE -0.037 84.~()0 DTLF.SDT 65~.000 TT4.SDT I 1 !7 . 200 LTT4. SDT 157.250 MRES.SDT 2.498 D~tHO, LDT 0.014 l.,8, LDT 57.68g 881 ,LOrn 1727.000 12.393 GR,LDT -0.037 ~4.O9~ TNP~.C~4L 1080. 365 C~:TC. C~L 5745.000 0. 002 260 ' 500 I92.875 2.438 36 000 1634."000 t.920 3831 '654 0 O3'! ] :ooo 158'9.50 4 50.4 0. 000 216.750 63.688 1735'000 .81. 800 ! 157 600 -0.'037 0 014 262~~750 !.99 625 2 383 63 688 1735::000 3 1.72 2451. 053 -0 ~37 88 !57.625 9.375 9.!41 0 0OO 4!.281 1677.000 7.t.000 533.~00 8 400 ~0 0O2 !~'/.750 2.506 41 2 482 28~] ]947 -0.037 41.281 157,250 CI~P. DTE C!LM..OTF IMOF,DTE IIX~.DTE TENS. DTE DT.SDT TT 1 SOT 1: SOT GR.SDT HTEN. SDT 8S2.LDT LSRH, bDT TENS.LDT N~I .CNL NDOR.CNL CWTC.CNL ~4 T F~I. CNL TENS.~LT PA ~,g: :25 2,. 68 244; I'~5 262,750 2 ,445 5980.000 14 412 15 608 2041 073 158 250 5980 000 lit.,°o '000 0 000 l0 445 5885 000 9O 000 586 800 1004 400 63 688 I735 000 2 428 245 875 264,250 2.438 5885.000 32,869 34,211 777,330 ~57,625 5885,000 100,375 119,063 0,000 7.848 5745 000 78i000 533'600 947 200 41 281 1677~000 2.768 221.000 253.750 2.498 5745 ~00 2 1t75 24,797 1167,432 157.250 5745.000 D~PT, 7900.00(? CIQP,DTF ~;TE~. PT~ 156,750 9T!,,SDT ~3,100 D~I..N SPT ., .~ ~ .... LTT2.SD~ 838.900 LTT3.$OT T~J.N$. SDT 5715.000 DPNI !..,OT !2.656 .... · ,. · bL,LDT !~6 375 LIT . . 00 a S o~ ~...i V. L D T ~TE~'. LDT t56.750 ~ ..,~.T C~,~!, 25~.4. 327 ~ C~L DEPT. 7800.000 CIDP.DTE I~DU DTE !.3,750 C , .:F !3.586 IF~E,[)TE ]. TRP.DTE 69.~13 I I'.~,9. DTK SF !..,U. D',r~ 14.328 GP. DTE 1,~ T E~ , . .......... . DT!,.SDT 83.900 DTi. ~!. GDT YT2, SDT ,425. 200 TT3, l.,T'r2.5DT ~36.409 q' F. t,~ S, s t;:; T 55 a 5.0 C 0 ',~ 'r' F ~,!. S D T OI,S.~,PT -0.o20 LI,. 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SDT t56,500 aPES,SDT 2,492 DR~[),LDT 0. 027 LS. bDT 71~938 SSI.LDT 19 000 S1B~i,LDT -~.037 HTE[~, LDT 17'872 .slo.sgs 55~5.000 15,602 -0.037 ~TE~'~. ~ I,T 85.125 IPP%I, OTIS: 86.938 20.000 IDOF. DTE 6.594 I. IR'~, DTE -52.4,06 G~, DTE -o.037 73.000 DTLF.SDT 693.600 TT4.SDT ~.0~5.~00 I,TT4.GDT ~5.750 4.707 4.680 n. 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' t, PT 17.281 LOT O, 919 OSS. bDT LOT I 61,, 250 LIT bSHV.LI)T i873.000 LUR~.LDT 2,373 CA, bi.bDT L D T 153, a 75 ~,~k E $. L D T HTE~ . C~:t!.. 1629,000 ~!.T 16~9.00() aRES. aLT DEpw, 73OO.000 CIDP.DTE I~'[:'~ D'TF'~ 4.9 156 IIRD.DTF 37,094 I'iXD.DTE SF:L,t~. DTE 154. ! 95 SP. DTE ~ T E ~ r),r E ! 53.625 ~4 R E ~, i'~ ~ E . . ......... ~) .. TTg. S[:)T 53~, ~f')0 TT3. SPT L,~T~'SDT I048.60C I,TT3,SDT TENS.SDT 5235.000 ~4TE?.SDT DPHI. b[)T g3. 144 OL8. LIoT -0' 055 OSS. LDT Lr,. LDT ! ()37. <?OO biTS!. LDT !:,SF.iV. LPT 1877.000 SS~V.LDT LU~u LDT 1.2P2 ~' ~ .... -.~, i.~TE~ tr~ 1 ~3.62~ ~RE'5 !.,PT I ,. , .:~ . ~, ,,~ . ,., ~ P Ci~iT. C~,I.., 1377.27g Gn.C~:!, 3!,813 F ~F:~;. C t~,~ 1., 1, 569. OO~ ~T~:~ , ~L,T 156q. 0OO ~ R[~;S. Y!,T DF, PT, 7200. OCO ClPP. I I,~'. DTF~ ! 8. OR ~ IFR~':. DTE ! I p.h, D~F: 45.93~ I S~Lt'. DTF ~i:), 141 E,P. DTI:: ~'T F:u . nTF 15~. 875 PT!.,. 8[)T ~.5. 900 DTL~:. 8D2' ~T~. SbT 440.,40(' TT3. SbT L ~ T 2. S D T 8 a 3.200 !~'r T 3.8 [> 'i' T F ~ g, 8 D ~ 5 230, O 0 G ~-:~ T g !4. g P T 1. 1-AUG-1992 05.,41 77,000 IDP!'{, DTE 79,438 ILD,DTE 20.000 IDOF.OTE 6. 477 IIR~<, DTE '77. 375 CiR,DTE T0,038 HTEN DTE 7 724,400 TT4.SDT 1is4.600 t.,,TT4, sr>T 2. 365 DRHO, LOT 0, ~07 b= bDT q9. 500 ~Sl. LDT !704.000 S!RH:, I~DT 12.766 G R, L, r) ~ O,03a HTEN,L3T ~4.557 T ~j R t,,, C N L !050,619 CNTC,CNL 5345,000 ~4PES, CNL i4,242 GR. ~LT -0.038 ~TE~4,~LT 31..500 IDPH.DTE 35.500 20.000 Ir..oF. OTE , DT g 3.5 4 I 200 DTLF,SDT 954'800 T'.,r4, SDT 1.362.400 LTT4,SDT 1,27~ D~Hr), LDT 'O.0~6 .... ~o. BDT 774.500 SS1,LDT 20. ~ ~ 6 O R. L r.~ T -0.03~ HTE:",I. L, DT 64,523 284.1~7 CNTC.CNL 5235.000 m~ES.CNL 19.844 47.969 IDP~.DTE 51.C00 !LD.DTE 20.000 IDOF.DTE 4.004 I!Rq. DTE '101.875 GF'. DTE -0.03_~ ~2.900 DTL}',SDT 756.000 TT4.SPT 13~.aO0 LTT4,SDT 152.875 Y~RF5. S[)T 12.977 1,2.5'1.8 0.000 70 625 1.629 000 '78 1oo 544 80O 9972600 -0.038 0.002 99 500 2 354 48i219 1629 000 2,626 30~9 666 o:o3e 48,219 153.875 3!,734 2~.141 ,.000 33,563 31.8!3 1569.000 118.300 763.200 1203.200 -0.038 0.002 1, 8 000 22~4'!25 31.8!3 1569 000 4~680 1443,904 -0.038 31,813 !53.625 20,828 19.594 0.000 50.781 a0.125 1636 O00 596.000 985.600 -0.039 Ct ;v~p. !~QF,DTE DT. SDT TTi.SDT L. TT ~ 'gDT G~'SDT HTL~ SDT PEF: LDT LU, LOT SS2.L, DT bSRH. LDT T E ~:~ $. LDT CNL NPCt~. C,5~L CFTC, CNL TENS. CI~P.I)TE CIL:~ DTE I~QFiDTE IIXM.DTE TENS.DTE DT,$DT TT!.SDT LTT~,SDT GR.SDT HT~N SOT PEF:LDT LU.LDT SS2.!..,DT LSRH.L,~T TENS.LDT NPHT.CNL NPOR.CNL CFTC.CNL CIMP.DTE CI[,U.DTE !mOF.DTE IIXE.DTE TE~S.DTE DT.SDT TTI.$DT bTT!.SOT GR.SDT HTFN.SDT PAGEI 28 76,000 74,500 0,000 ,367 534 ,ooo 82,400 556,800 990,~00 48, 19 1629.00'0 3.186 276 50 · 276 750 5345 0 1217,358 !53.875 5345 000 20,328 35.28~ 0o00 0 ?~6 5235 000 130 400 735 200 il9e 800 31. 813 1569 000 1.937 2162.000 404.000 1,275 5235.000 64. 309,387 153.625 5235.000 52.906 53.469 0.000 3 865 5230:000 88.500 585.600 985,200 40.125 1636,000 7100,000 C I [.'~ [:' T> T F · .~ ~ ,, ~ ....... ~ , ... SFT,U p'rE 139 ooo sp. OT[,.SDT 165,200 TT~.gDT 537, bOO TT3, gDT LTTD,$1)T 1,!74,400 LTT3.SDT TF~',JS. SOT 5240,000 DPt'fi I,D~ ~2,030 OSS .... . L [::5, T - (). !,,,L. BDT t04! .000 L S H' V. L D T 1 ~ ~ 4.00 (:' S S N V', L b T bI!RF~. BDT 1.30~ CAT.l:. BDT f4TE~'. L[:.~T 152, l?$ R*NP'C[~L 5.385 G~.ChL 30.891 H T E ~,~, C ~ l.. 1623,000 N C .a L, ~4 L T ITRD.DTF !75. i25 !IXD.DTE SF'LTT. UTF'. 5.074 SP, ET.E ~TFV. DT~ 1~1 'b25 MRES. DT~ r>~l,, sPT g I., 10(:, DTI,N. SDT · T~. SDT 389. ~O0 TT3. I.,TT~" 8DT 8~9.20~ LTT3,Sf)T TFNS. S[)? 5200. ()00 ?~TFk. SPT DPH~ l., 12' T 6.~75 RHO[~.. bDT [,r .T,DT J 24.c'00 f,ITH. ..... '2 T..,S l~ V. I, f':~T 1~51 .0n(, SSHV.LPT !,t?P~, T,[)T 2,50 a CA[,I, ~T~}~ I~'r 151 ,6Pq ~qPEYS RT[~P .CN[, 3.017 T:'.JP~. CN I pC~q'. C~o [, 2441.224 PCFT. Ct:L I,l-'AUG-!992 05141 107,500 J '1(13,8('.)0 S1RH,LDT 12,89! CR, CDT -0,038 HTEa,bDT 22.739 ..... CN L !256,124 CNTC,CNL -. 9,250 (;~. ~,~[,T -999 250 NTE~;~, 13.075 :T. DPH, DTE 22,531 I t., D 20 000 ' ..... ' T 4.203 II'RM.O E -71.000 6R.DTE -0,038 HTFN.DTE I12 400 DTLF,oDT "7 s OT t 037,600 TT4, i52. 125 ~4~ES.sDT ~,296 DPMO, BDT 0.026 L8. LDT ~79.000 SSt.BDT 1697,000 S1RH,LDT 20' O0O G~, b[)T ...I E ~,, L r')T 87.090 Tf4RA., CNL 239.25~ CNTC.CNL ~' CNL b240.000 -999. ~50 GF~. -,999,250 90~.87~ IDPM.DTE 2<) . ~$5 .~.[~o. OT~; ~0.ooo -45.~13 -o.o3s 726,000 TT4.SDT 1!67.600 .~T~ SPT 151.625 ~RFS. SBT 2.546 DnHr']. I, DT O. 02 ] !,8. l.,nT 65.250 SSI,GDT ~692.000 S~H,LDT I 4.680 GP. bDT -0.03~ NTF:N, !jUT 30.~56 TN~$,.CNL 764,41! CNTC,CNL 52r)n. 000 u .... . ... . . ...... ~r,,> CNL -q99. 250 -999,250 ¢4TF~:. qbT 0 014 3131250 205,375 2.283 40..125 1636.000 2.368 999 ,038 .25n -999,~50 72 000 42375 0 000 30.891 1623.000 1,22.!00 795.600 I~42 4O0 0,005 2082.000 236 250 1623 00 52628 1,401.256 -0 038 - 91 5o -999,~50 4 949 41914 0 o00 20! 625 79.625 !615.000 7~ 400 5 22 oo 99~.400 -O.038 0.047 235.875 204.~25 2.383 79.6~5 !615,000 2.953 2515.~0~ -0.03~ -999.250 -999.250 ClRP ,DTE CILM n~p. , ~,~ .a, .::~ !MOF,DTE II×~.DTE TEDT,SOT ' ~ SDT BTT1,SDT GR,SDT ~.. ', E~ ,.: , . PEF,LDT LU,LDT BSRI~i,LDT TE~S,LDT NPHI,CNL CFTC,CNL TEM$.~LT CIMP.UTE C!L~.DTE I~OF.DTE I!X~,DTE TgNS.DTE DT.SDT TT1.SDT bTT1.SOT GR.SDT HTEN.SDT PEF.LDT LU,LDT SS2.l, Dm LSRH.BDT TENS.LDT NPHI.CNL ~POR.C~L CFTC,C[B ~TE~.CNL TENS.~LT PAGE: 29 288' 27 :ooo 0,000 52~0,870 24"089 1387,797 152,875 '999'2:50 25.375 22,078 0 000 i 942 5240 000 115 500 808 400 1349 200 30 89! 1623 000 I 264 2080 000 389'000 1,.290 5240'000 63;418 84,833 276,753 152.125 -999.250 210,~00 214. 25 0.000 11..758 5200 oo0 80i400 56O 000 994 800 79 625 1615~000 2.740 223,6~5 270'750 2.498 5200 000 28~933 29.516 849.306 I51.625 -999.~50 ,IS Tar~,e VerliI, catlon l,isti, r'~a ;chlumber~er AlasKa Computing (.'enter DEp'~. 690 D T ~'; i 3 r',TE 1% TT2. SDT 40 ...... ,oPT TFNS, SDT ~0~ DP;~T .I,DT LU~. L~T RC~,~T.CNL 225 HTE~; . Cb:L 159 H~EN. ~LT -99 D~P7. 6 ~ 0 'I~P~, DTE 2 1 T ~ D, D T ~.'. 3 S F' L~,~. UTE 6 ~,~TEv DTE 15 .8 [)T 10 TENS. $[..)T 502 DPF! J'. I, DT 7 OLS, LDT ' bSHV !,~gT 1~6 ~T ~.:~. LDT .I 5 R'Tk~ P, C ~q I~ ~TFa~, CF~L 152 NTFF, ~-~LT '99 DEPT. 670 IL,v . DTE I I T ~F). DT5 5 S F[.,I.;. DmF. ! ~,~Tg~/. PTF ! a DT[,. S[)T ! 0 WT?. SDT 47 LT~?. SV~T ! TF*~G SDw 5r~l . - H~ I - - '' . 0.000 C t !3 p. I> T E 5.656 C!LD.DTE 5.~3 6,750 IIXD,DTE 5,020 SP, DTE 4.500 D'!:' b t~, S P T 6.400 TT3.SDT O, 000 ~!TF~ SDT ,- 0,0 r) n S S H V. ~., D 2.31 I Cat, I. I,,,DT 3, a 52 T ~ P H,C.. g, ] 04 ! .875 TENS, CN[., 0. C 00 C I D 7 725; 5. 06 6.656 I!XD.[>TE 4,875 SP, DTE 8,000 4,000 TT3 4.000 LTT3,S[)T 0. (J 32 (:~ S S, [., [.::' T 4.. 5 o 9 L :r T ~'{, l, D T ~i,C00 SSHV,LDT ! .4~2 CAI,I. !,r,T 0,625 4.950 Tt,~PH. C~L 1. 766 RCFT. C~.!L 9.25C !!-~UC-1992 05~',41 I 7,625 ILD.. ' bTg 20,00() I"t' brg .... . -0 038 83 200 DTLF, SDT 7<~4 000 TT~,SDT 1:164 800 LTT4.SDT 15!,125 F4RES.SDT 2.38! DRHO.LDT 0,053 ! 8, bDT 97,813 SS! , bDT 1,693.000 I. 5 , 492 GR. LF)T ~ N [.~ 31. 797 TNR~, ...... 704,573 C~</'TC.CNL -999 250 GR,~LT 35 I 906 IDPH. DTE 221,700 DTLr,~DT 848 ~()0 TT4.SPT 1.390~ 40() LTT-4. SDT 150 625 ~RF,$. SDT 0,008 LS, LDT 510,250 SS! .bDT I693,000 S!.~'~,LDT I 8. 906 GR, bDT -O.03~ Hq'E ~. !,UT 64.~24 TNRi. CNL 277.26~ CNTC.C~b :999 250 (;~.~I..,T . ~ ~ .- 62.25n TDPH. DTE 64. 250 !LT). DTE 20.000 Ib6)F. [)TE 1.457 I I~,~. DTE -8 1 . ~75 CP. DTE; ~90. Olio TT4, Slit 345. 200 LTT4. SDT 149.625 t~FS.SOT 6,309 6,340 0,000 !60,000 81,07.5 596,000 !. 7 o o 57! 200 oo].' 600 - 0 O 38 o:o73 327. 000 222,875 2. 146 81,875 596. 000 3.1. 26 3 -999,250 -999°2g0 27.828 25.438 0.000 37.375 62.281 1529.000 1 o6.5oo 690 400 1202:4oo -0.001 I52 000 '"23~1!25 ! 455 000 1618.~9! -0.038 -999 250 -999~250 1,6.047 15.555 0.000 71 375 1571 000 !05~800 682.000 1156,O00 -0,038 ClaP,DIE CIL~,DTE IROF,DTE IIX~,DTE TENS.DTE DT.SDT TT!.SDT LTT1 SD HTEN.SDT PEF.LDT LU.LDT SS2,LDT LSRH.LDT TENS.LDT NPHI. C~L ~POR. C~L CFTC. CML ~TE~. CNL TENS, ~bT C!~P.DTE CiL~.DTE IHOF.DTE IIX~.DTE TENS.DTE DT,SDT TTI,$DT bTTI,SDT HTEN.SDT PEF,LDT bU,LDT SS~,LDT LSRH.LDT TENS.LDT NP~I,CNL NPOR.CNL CFTC.C~L MTE~,C~L TENS.~LT CI~P.DTE CILY.DTE IMQF.DTE !IXV.DTE TENS.DTE DT,SDT TTI.SDT LTTi.$DT GR,SDT HTFN.SDT PAGE: 30 176,625 169'875 0,000 7 117 5020 000 85 800 574 800 !000 000 81 875 159~ 000 ' :461 305 500 294 250 2 307 5020 000 3 213 31 996 815 852 !51. 125 -999 250 6,188 9.344 0.000 -0 399 5025 000 12 100 68~ 1205 200 62 281 1529 000 2 207 !503,000 382.000 1.450 5025.000 62 6~4 348,250 150,625 '999,250 69,500 75,313 0,000 2,748 50!0,000 105 500 6741400 1147 600 76 875 1571,000 !$ ~'~3r_,e ver!flcatlor: ch]..u~berr..!er Alaska Comp ut ino: Cet~t er DPHI. LOT 58. 337 RHO'~. LhT L~, LDT 564. 000 L!TH. LDT LSHV,LDT ! ~72,(::00 8S}:V, [~I)T LU~H,LDT ~ .646 CALl, I~DT RTt-,~ P. C:<: !~ 4.049 T~4PH.C~,L RCNT.C:Vb 15B3,989 RCFT,CHL HTK~. ~LT -999,250 ~RES, 3,JLT 6600 ! 6 q0 ~ 7 f, ~ 84 o 0 ! 69 ! 872 2 1, 4~ 2 1603 -999 I~PW,DTF ! 3. 148 DTF I 3.148 !)TE: 74,6~ SFLI~. [3TV 15.664 I)T[: ! 48,375 $ [) T ~ 7.500 BDT 4 ~ 5.20 u SPT 920. 000 $ {.) T 501 0. ~ C c, Ltl'>* 21.54 :'4 !_,PT 0.01 ! LDT i ~ 1.75<~ LS~V.Lg, 1 Lt~PH. LI~T 2. 305 BDT 148.375 Cbb 3135,!2]. .Cu[, 38,656 CIDP. DTF, CI!,.,D. DTK !PRE.DTE 8P, [3 T L N, $ D T . S D T .cDT RHf3B. t.,DT G,SS. LOT b I T H, L [) T SS~V. CALl, LDT RCFT. ~4~ES, ~LT 1. 1. ,'AUG 1,687 DRE[}. bDT -.0.021 LS, bDT 328,000 88!. ,LDT 168~.,000. ole RH.LOT,.. ! 6,422 ' GR,:LDT -0.038 HTE~:,t. t,,DT 46. !66 TNRA,CNb 3B7,287 CNTC.CN.L 5010. 000 MRES, CNL -999,250 GR, ~,~I,T -999,250 ~TEM, ~4LT I66.125 IDPH,DTE !68'009 !I.,D. DTE 2( . 000 Ir)OF DTE 15 . 953 I i R :~,: . a T E -107. 750 GF, DTE 87,400 DTI~F,SDT 7~6,g00 TT4,SDT 1240 , 0 00 1, T'I" 4 , S D T 14.8,750 /i~RE~. SDT . ..' ' LDT 2 348 DRHL, 0 0 12 1,8 LDT 1~0:375 1686.000 SJRH.LDT 13.484 G~,hDT 19.725 I473,175 C~::TC, C~JL 4240,00() ~IRES,CNL -999, ?50 GE, ~LT 20.000 5.7~1 !!RM,DTE -73,250 GR. DTF: -0,038 HTEN.DTE 9.2oo 1252.B00 LTT4,SDT O.0O8 LS.LDT 125.1G8 SSi.LOT 1684.000 SI. RH.I,BT 12.523 GR. L[)T -0.038 H~EM, [,DT 22,2q7 T,}i~A CNL i192.2~5 CpTC [ C~,t,, soio.ooo -~99.250 0 1085, 250, 1. 76. 1571. 1703~ -999, -999, 1603. 82 1065 '0~ O, 31.3. 20I. 31. 1.603. 2. 3637. -0 -9991 -99qo 12. 12, 0 ~6. 1603. 10~0 ol 336. 1.97. 36 1603[ 2. 3269. -999, -999, 053 000 375 509 ~75 000 9~ 914 038 250 250 O 16 945 750 156 000 600 2O0 20O 038 007 750 1.56 000 198 610 038 250 250 19 000 063 656 000 700 000 400 O38 005 500 375 31.8 656 000 457 068 038 250 C I ~ P. DTE CIL~'DTE !MQF DTE I IXM: DTE TENS~ DTE DT .gDT TT1, gDT bTT! , SDT G R, 8 O T HTF:M, SDT PEF LOT ~ · bU, t.,DT SS2 LDT bS~ ~: LDT TEMS,LDT NPOR.C~L CFTC, CNL 8TE~. CNL TENS.~LT CI~P.DTE CIL~.OTE IMOF.DTE IIX~,DTE TENS.DTE DT.$DT TT~.$DT LTT1.SDT GR.SDT HTEN.SOT PEF,LDT LU.LDT SS2.LDT LSRH,LDT TK~S,LDT ~PHI.C~L NPOR.CNL CFTC,CNL ~TE~.CML TE~S.MI,,T PAGE: 31 3.008 1043,000 4t3,750 1.634 5010 000 45 604 47 240 427 521 !49 625 ~999 250 121.000 12 '625 0.000 8.578 4840.000 87.700 613,600 I055'200 31,I56 160 '000 I 786 287 750 281 500 2 340 4840 000 18 081 1,8 ~37 1644. 88 148 750 -999 250 7. 000 0'000 4 734 5010 000 ,7:000 6~4 ~00 10691600 36 656 2 000 309 500 279 500 21299 0 000 5012 351 21,965 1389.090 148 375 -999:~50 D~PT. 64100,00(! CIDP.DTE I~'P~,L*TE ~ 5 008 IL~;, DT'F. !4.664 I~,DTF g0.!88 IIXg,DTE SFLU. DT~ 2 ~, 859 DT!,. Sf)T 77.000 DTLN,SDT ~..~ ....... ~ ~ LTT~,SDT ~14.800 LTT3.SDT T~i',~S , :$ DT 4875.000 ~qTE;b, MDT o Ls, b !')T 0,00 ¢ t.., I,,, L D T !. 4.4.875 L I T !'t, L D Y LSklV. LI>T 1 871,000 SSHV. bDT L!!RW, LDT P. 4 t 4 C.A!.,I. L f'~ T RTNP ' 1:~ 750 f~! R F~8. RC!,~T. Cf,~ L 3778.055 ~CF'T.CNL GP.CNL 34..781 TENS.CNb H T E t~. C N L 1604.000 ~:~ C a L. P,~ L T aTE~, ~if~T -999,250 ~RES. ~qLT DEPT, 6300.000 CIDP.PTE Iuu '~ DTE !1.4,~4 CILP TL ' ....... ,[)T[ J 1,53:J ! t a t:. D T K 84,250 I t X D i"; T E NTE'~, DTE 147. 375 ~RES. DTL.SbT ~4',400 9TL~.SDT T q" ~ . S r> · 4 l 8 . 40 C T q' 3 . $ n T TFNS.Sf)? 4920.000 DPHI.!,DT 7,650 P}'!OB. I~DT OL,$. !.,DT -0. O 1 <) OSS. LOT Lf,, I,DT 1 '~,875 L!TH. I,P.T I.,SHV. Lt)T lS~5.O00 SSaV.LDT R~'~P.CNL 2.465 ~'iPq.CNL PCPT. C~,-,f~ 2qq4.8t9 HTETM , Ci; l., ! 6 g 7. (i)()0 ' · ..... .' ¢~ .. '. I1-~iJ(;-~.992 05:41 ~ 5. ? 75 I D P 20.000 IDOF,DTE 8.758 I IR~,~. DTE ~0,039 HTE?q, DTE -/ 7.800 DTI F',oDT 724 000 TT4.SOT 1. i 30 [ 400 LeT4. SDT I47,750 2.416 DR~!O. bDT -0. 006 LS. bDT 97,68¢ SSi .!,DT !,6~0.000 S1R!i. t, DT !2,445 GR. PDT ~ .... ' .... LDT 16[44~ !835.319 C~!TC, C~L 4875.00 t) -gg~. 250 92.0 ~. ~ I I., i,), b T E 20.000 IDOF,OTE 500 DT!,F,SDT 745.200 TT4'SDT :I176.S00 LTT4.SDT 147. 375 ~RES,SDT 2,524 O R (>. 02 9 I,,, S. L 9 T 73.125 SSI,LOT 1679,000 SIRN.LOT i 6,719 GR. bDT -0. 039 HTE{~, bDT 23,974 1009 693 C~,~TC, CNL ~0~0o0 ~RES.CNb -999. 250 (¢~. ~'~ t.,'r -999.250 177.625 IPPH,DTE 180.75(3 ILl). DTE 20 C I_fl) OP O. TE . ,90 . 9.063 I TR~.~, UTE - o. n 3 o H T 9g.?O0 DTI.,F'. SDI' 921 .bOO TT4 1!.703 1!,266 0.000 64.625 34.781 1604.000 75,600 565,200 971.200 -0.039 -0.002 274.000 192.625 2 1604 0 0 3920,468 -999 -9 9:25o 11.227 io.8 2 0.000 B2.125 81 063 1687 000 78 500 574 800 !013 200 -0 039 01095 264 750 220:7so 2 230 81:063 1687.000 2,647 28Z5778 .0:039 -999.250 -999'250 5.625 5 527 0:000 !69 750 !628.O00 104.400 676.400 !06!.600 -0.039 C!MP,DTE C!b~ DTE Ii×~ bT DT,$DT TT~,$DT LTTI SDT HTEN,SDT PEF,LDT L ti, b D T 582,LDT L, SRH. LOT TE~$oLDT CFTC.C~b ~TE~.CNL TEMS.MbT C!MP,DTE CIL~,DTE IM~F.DTE i!XM DTE DT,SDT TT!'SDT bTTt,SDT GR~$DT H~EN, gDT gE, LDT I,U. LDT $S2oLDT LSgH.LDT TENS.LDT ~'i ~ a I. C N b NPO~. C~II, CFTC. CNL ~TE~ oCNL CI~P,DTE CIL~.DTE I~OF.DTE I!X~.DTE TENS.DTE DT.SDT Tg~I.SDT bTTI.SDT GR,SDT HTEN.SDT 66.563 68.t25 0'000 5,336 4875.000 77,800 562 400 969 600 34 781 !604 000 I 995 258 500 271 500 2 4 7s: 6.oo 6,04~ 2013,696 147,750 '999,250 87,063 ,688 806,000 6 445 4920 000 77 700 583 200 1 O06 4OO 81 063 1687 000 3 389 251,750 292'500 2 428 9 o:ooo 23 550 211045 1.104i902 147 375 999 250 208,875 180 250 0~000 2.951 4785,000 129,400 682,800 104~.600 77"375 ~628,000 chlumberger A].aska Con~utiB9 Ce~?ter PEr'!;:. 6006,000 CIDP.DTE I'~PH.DTE 9,305 CILD,DT~: ! [.~ ~,~. !DT~ 9. O ~ 6 TFRE, [~TE7 iTPF,.DTF ~2.! 25 IIXD.[)TE SFLU. DT'E q, 5 39 SP.'DTE ~,,~TF:~ DTE 1a6.62 PT!.. SDT 88.30(3 t)~I,i~. SDT TT2. gDT 409. L?T2, SPT 846. (:OO !,TT3. SDT TFNS. 8!.)T 4775.00 [-~H :l. I.,t)T 21 ,~25 ObS. !.,9~ -O. 055 OSS. T,PT Lb. I.,PT 255. ~156 I,I]~H. LgT [,SHV. bI"T ! 86 3. 000 SSEV. - '. . a~ T ~-~ P. C ~..; !.. 3.299 ..... J ...... . ~ ..,, . . 1. 1 AUC- 5- - ,, 1992 0 .41 2,237 DRHO.bDT 0,101 LS, 126,313 SSi.bDT 1674.000 S.1. R t,!. L, DT -0 ' 039 }'{TEN, BDT 48'449 TNRA,CNL 387,913 C~,ITC. CS!L 47~5,000 ~ES,CNL -999.25o i76.025 20 . 000 'IDO.:P . T.)TE.. 16.313 -50,~38 G~ DTE -0. 639 ' ..... ,' 88 500 PTI,F. SOT s20'4oo ?T4,SOT !242:000 L.~T4.SOT 146,875 . F~ES SOT ~,4.~2 DRNO,LDT 0,017 I,S~LDT 87,750 881.,bgT 1675.000 S!RH,LDT 1~.6~8 (JR.LOT -0.030 ~TEN.LDT 67~.549 C~qTC,CNb 4865.000 5!RES. CNh -999. 250 101.. 5 o 3 I P P 'ti, D T E I. C, 3.750 1 h D. I)'T' E 20.000 IPOF.DTE 6,53! IIR~.QTE -33,438 G~:.DTE - 0.039 ~ T E i'~. P T E 80. log DTLF.SDT 734.000 TT4.SDT 1206.000 LTT4.SDT 1.46,625 MRES.SDT 2.290 D~HO, I,.,DT O. 024 I.,8. bDT 134. 750 881. LOT 1672.000 8!~'H.LgT i, 6.39 l (; -0.039 H TE~":J. bDT 32.920 5~.515 C~,~TC.C~b 4775.000 -999,250 G~. -q99. 250 0 ~.36 , 71: oo 253.875 !.832 77.375 i628,000 4.!9~ !.6~3.252 0,039 -999.2~0 -999.~50 0 000 184!500 63 !,88 1613.000 92 e00 650:400 !077,600 -0.0]9 0 058 297!000 215 500 2,229 63 188 161'3i0003 097 2382 860 .0 039 -9991250 -999,250 9.836 9'63! 0,000 !04.063 59.250 1617.000 79 800 5792600 !015o200 -O.03q 0.203 484.750 272.250 1.722 59.250 1617.000 3.142 2063.000 -0.039 -999.250 -999o250 PEF.bDT LU.LDT 8$2.I, DT LSRH.LDT LOT TE~$.r~i, gPO~,CNL CFTC,CNL TENS,~LT CINP,D:TE CIL~,DTE ImOF.DTE IIXm. DTE ..E. NS.DTE DT,SDT TTI SDT bTTI:SDT GR.SDT HTE~.SDT PEF,I, OT LU.I, DT SS2.LDT LSRH.LDT ];E.S bDT NPHI:CNL NPO~.C~L CFTC.CNL C~L TE~S.~L~ CI~iP DTE !MQF.DTE !IX~.DTE TE~$.OTE DT.$DT TT! SPT GF,SDT ~TEN.SDT PEF.bDT LU.LDT SS2.LDT LSR~,LDT TE~S.LDT NPHI.CNL wPOR CNb CFTC:CNL MTg~.CWI, TMNS.~bT PAGEI 33 2.770 440,000 325'750 2.I0 4785.00g 53,088 413,859 147,250 '999.250 !96. 0 000 10 742 4855000 86 600 642 400 1072 800 63 ~88 1613 00 2 637 280 750 295,500 2,363 4855 00 779. . 146, 75 '999.~50 107,375 110.000 0 000 9i258 4775 000 80 000 578,400 1037,600 59 250 1617i000 3 189 458 000 3~! 500 2 086 4775 000 31 094 32 646 64B;953 146 625 -9991250 IS Ta~,~" e~ Ve..riflcat!or~, ' I,i, sti~ chlumbergo, r Alaska Computinq Center I3P'PT 5900 <)On .., .,.., .... ~ .. , ....,, FI,,U DTF o g75 . S D T 84,.. 40 () t, T T P. 8 P T 85 ~, ~ 0 o TENS, 8DT 47~0. O0O D~H!. i.,,OT 17, 137 OLS, [OT -0,0~I, L l.,. L D T I ~ J.. () 0 () I,SHV,LI>~ !a~a.00o PeN T. C"::i!., 2.345,909 (; ~, C ~J L 73,250 t,l T E ~<~. C a L ! 5 ~ t. 000 pFpT. Sa00. ~00 I I~D. OTE 75.6~5 SFI',~ PT~ ...... · .., ~ ~= . ! 45,t~n9 LT~ Sr)T 8q4,~00 TFN~ ,SUm 4a7n , nO(~,,. ObS. bO? -0,0 ! 1 LI ,bDT !.45,375 I..,,,H~,I,DT lES9,000 bURH.LDT ~.400 k~v~. I,D~' 145 0 t', ~ pC[q~ CNb 24.~q q~2 · - ~ . , . ~ .- .. . ~:~ ~ .... OEPT. 57o0.0n0 !~PH.OTE 16.063 ! L~*. bTE ~ 5. ....' ~ .... SYLt'. Dq:E 18.938 , ....J :,., ~ , I1-AUG-tg92 05:41 76 625 7~: 875 ILD, DTE 20, O00 IDOF 6,805 II ..... .DTE - 71.250 O 749,200 TT4.SOT [" SDT 145. 375 ~P'~S, 8DT 2,367 DFC,HO, bDT 0.022 h 8. b D T 94,43~ 88! ,!,DT 1671 000 8].Ra,LDT ' t6~828 GR. LDT 760.6!6 CNTC. C~L 4780,000 ~PES, CNL -999,250 (;~ ~bT 84,000 85,375 II,D, DTE 2 O, 000 I D 3 887 -45 , ~ 13 · ~ . .. '~ ~ " -0 03~ HTE~,~. L,'.. E, 87.000 DTLF.SDT J. 224,g00 LTT4.SDT 145.000 ~RES,SDT 2,438 0.023 1., ~0.375 SS!,LDT 1672 g(,g S] RH,bDT -0 03q 28,316 811,737 CNTC CNL 4670,000 -99o.~5o GR. YI.T -O9~. 250 ~ TE ~'~, ~ I..,T 64.000 IDP~. hTE 67, O 00 I L, 0. r> T E 20.000 ID-OF.OWE -53. !, a 8 ~a. DTg 64.0G0 DT[.F. SDT 696. ~00 TT4. SDT ~ 1 ~9. 600 L, TT4.8E'r t44.~75 ?4PE~ SOT .... O ~ .. 13.039 !2.508 0 000 89 3 ,i..56! 000 78 800 567 6O0 1024:000 -0'0~9 0.087 341 500 228. 250 2,096 156!. ~.:~i~ 2556.736 -0 039 -999 i 250 -999 250 !1.89t I1.703 0,000 85.!88 73,438 1638.000 88.000 625,~00 0~9 276.250 206.50~ 2.314 73.438 1638.000 2,937 ~63~.~5 -0.039 -999 -9992~5o 15.617 14.922 0.000 62,156 3~.656 1601.000 64.000 527 600 9~62oon -0.039 CIMP.DTE CILM.DTE !~OF.DTE IIX~4 DYE DT.SDT T' BDT LTTIoSDT GR,SDT HT~N.SQT PEF.LOT LU, LDT 582 o bDT ~ ~ LDT bo~ TENS.LDT NPNi,CNL 'P 0 R. C N L " C ~ L ,.F .CC. ~TE~.C~L TENS,MLT CIMP,DTE CILM,DTE I~QF,DTE IIXM.DTE TENS.DTE DT,SDT TTI.SDT LTT1,SDT GR SDT HTENiSDT PEF.LDT LU,SDT SS2.LDT LSRHobDT TENS.LDT ~P~I.CNL NDO~.CNL CFTC.CNL CI~P.DTE ![,M DTE IIXM.DTE TENS.DTE DT°$DT TTI.SDT LTT1.8DT g R. S{)T HTEN, SDT PAGE: 34 84,438 4.523 4780.000 83,600 568.400 6OO 1561 000 2,863 20 750 ]14 750 2 279 4780 000 ~7 480 27 754 920.3~1 145,3 5 -999,250 8~,875 'ooo 7.445 4670.000 92 00 624 gOO 1063 600 73 438 1638 000 2 705 261 750 280,000 2 404 4670 000 29 052 28 894 940 ~36 145,000 -999.250 62.188 65 500 0 000 7 219 4655 000 66 600 524 000 988 400 38 656 !601 000 ,lis ~?a~.:,e Verificat. ion ListJ..!'~q ;ch!um. ber~3er A.!as~:a Comrt:utin,.',~ Center ~.~TE'~ LOT 144375 ., ~ .. ~ ,,., ..... . ....... ~N~, C .....t~ L !. 896. T ~'{ P, C b~ L ~ C N T, C ~ L 4 0 ~ 0,4. 99 NT~N, ~'; [.,T -9c~9, ~50 aaFS. aLT 560 n, 0 n n I~PH, UTE 5,215 CtLD,DTE ,, DTL, S[)T 95.200 DTL!4. SPT bDT 469,200 TT3, SD'I: $[)T 895 ~00 LTT3,SDT !., D T - 0,0 ? 7 Q S ~};, !, P T L D T 2,1.. ~ 9 C A L I', 1, D T ~TE~. ~L I 144.375 G~. C~.~L 58,094 FiT~)~t, C~!b 1633,000 1.' ~ put')'}' ~: ~,. 238 1' 1,~ ~,TT 5 -' ' · ..... '. ~ '-' II~P r~'r' ~ 1.6n, 87S DTT.$[>~ 99.bO0 ~-' s ?., . . .... LI~RN, f,nT "' 123 .,' ~. ~ RT~n.CNL 3.682 2,5~9 ORHO,LOT -0. O! 7 LS' bDT 56. 594 SS~ ,bDT t665,000 Si E.LDT l 2,766 GR, LDT HTE~. 20i4'365 ChTc,cNL 4655.0~0 ~R ES C~L -~99,250 ~TE~ ~LT 170 oo0 IbP~.,DTE 20 ~00 IDOF,UTE -49.0i)0 GR, DTE 94,900 797,600 ' ~T4'SDT .... ;, ..... , SOT 144.37~ 2.277 DRHD.hDT 117.875 1664 000 L[):~ 15,563 Ga, I~DT ~ 0391 HTE~. bDT -., CNL 53~ ,~33 4595,000 -999,250 GR. MbT -999,250 180,125 IUPH, D?!i: 187.500 !bO,UTE 20.001) 12,773 !IP'~. UTE -4J .781 GR,DTE -0. 039 H":E~.: OTE 99.500 DTLF,SDT 947.2o0 TT4.SO~ !315.600 LTTg,SDT 143,750 ~.~RES, SOT . . ,.., ~ 0' 009 LS, bDT 136.25a SS1 ! 5, O 16 GR. bDT -9,03g HTE'~. L, DT 3S.Sq7 a7~.31~ C~.~T'C. CUb -999.250 ~TF. ....... ,~bT -0 0!0 178875 38,656 1601.000 1,~36 -:039 -999.250 -999.250 5 879 0.000 183.375 58 094 !633:000 95.300 604,000 ,039 0.075 394,750 230,125 2.037 58.094 1633.000 3 268 2033:299 0039 -999,250 5 547 0 000 la7[5oo 61.313 1618,000 92,600 726.000 1168.400 -0.039 0 075 4e:5oo 234.125 1,968 61.,31~ 161.8.000 3,582 1~45,O40 -0.039 -g99.~50 -g99.~50 PEF,LDT LU,L~T SSa.LOT TENS.bDT NPHI,CNb NPOR,C~L CFTC,C~L ~TE~'CNL TENS.~LT C!~P,DTE CtL~.DTE I~OF,DTE II'×~ liTE TENS,DTE DT'SDT TTI,SDT LTTI.SDT G~.SDT HTEN.SI)T PEF'LDT LU.LDT SS2.LDT LSRH.LDT TENS LOT apOR CNG C TCiC MTE~.CNL TE~S.MLT CI~P.DTE C!L~.DTE IMQF.DTE IIXM.DTE TENS.UTE UT.SOT TT1 SOT bTTIiSDT GR,SDT HTEN.$DT PEF,LDT LU.LDT 8S2 LOT [.SRH:LDT TENS.LOT NP~I.CN[, NPO~.CNb CFTC.CML ~TEg.CNL TENS,~LT PA~E: 2,828 199.500 248 125 2i578 4655'000 12,932 14 275 2208 ~66 144~75 -999 250 191,625 I94'875 0 000 1 344 459~ . 000 102500 630 000 1076 800 58 094 1633 000 3,098 369,000 ,2.1 4595000 33 334 O42 144 375 ~999 ~50 19 750 0 000 8 844 000 7t3 600 11541800 61 16!8 000 2 641 422 750 339 000 2 131 4515 000 39351 37 76! 528 987 143 750 -999250 35 ~I.$ Taee Veri. ficatior~ l,.i. stjnc~ ;cb.lUmberc~er AlasKa Co,'outin:~ Center 5400.000 CIDP.[)TL 3.453 ClI, D.DTE 3,4 86,900 !)TL~. SPT 16! ,000 1242,000 SSHV.L. DT 1.42 75~'~ 3 ] 0,315 ~ C F T, C ~ L DF, PT, 530o.o00 CIDP.DTE !!k~.DTF' 39,469 !!X['). DTE SFLU, OTK f~4,6~' SP. DTE MTE~. DTE 142,250 NRFS,DTE TT2. SDT 5t 6. 400 TT3 LTT?,$~T 1150 400 LTT3.oDT TENS. S[)T 4330. 000 OILS. [,~t)T -0. 067 LL. Li>T !006.500 !,ITH. !,DT ~C~'~ T. C~'.~L !2al .429 aCFT. CNI, 1 !-ALPC-1992 05:41 277,500 IDPH.OTE 281 .750 20 , 000 I D O F . D T E 20,578. I'IR~'.. DTE 30 9 DTE ' ,7~ 7 ~R, ... oO, 040 [',!~:~, gTE 804,400 TT4.SDT ~253.600 LTT4,SDT 142.750 ~!RES. 8DT 2,~20 DR!~Ci, bDT 0.034 LS. LDT 84.500 S81.LDT 1664.000 S1Ra. LDT 1,5.891 GR.LDT 30,04() HTE~:3 LDT ~.059 T ' .... 698,53! CNTC,CNL 4515.000 MRES..CNL -999.~50 GR' ?4LT "999. 250 NTEN, 36, ~ 3 ~I ! D P H. i ~ T E ] 674 IIR~. DTE -0,040 HZE.~ 7)TE 127 1.030:400 DTLF,SDT 4. 00 T T .!, S D T 1550.400 BTT4.SDT 142.250 MRES.SDT 1.295 DRanO, BDT O, 02~ tS. bDT 74o. ooo ssi.. 1661.000 SI. RH, bDT 19,31. :] ~a, BDT '0,040 IITE~4. LDT 68.80 ] T:'IRA.CNL 244.94~ 43~n.000 UF. ES. CN~L -999. 250 GR. ~LT 5.809 IDP~i. DTE !l 1 . ~34 I!,U. 0TE 20. nO0 II)OF. :)~g 2.600 I!R~.~. DTE -C9,189 Ck. DTF -0.040 }.ITEk:. DTE 129.300 hTLF.SDT 1112. 800 ?T4.8DT !657.600 I,~'T4. SOT ! 40.875 ~,: R K S. S t) T 2,10. 50. 16!6, 100. 6!2 1091 -0 0 ,303. 220. 2, 50. 2417 ~0 -999, -999, 27. 45. 27. 1528. 1.26, 76~. 1339. -0 o: 2072. ~3~. 1528. 5. 1375. -999, -999. !72. 23. 16. !554 123~ 831. 1435. 602 545 000 250 000 4O 0 000 6O0 040 072 75O 000 1.89 000 064 4?9 040 0 22 250 o00 906 547 00o 800 8OO 6OO o40 O0 e o00 375 25] 54.-7 000 O88 .38! 040 250 250 !25 93e 00o 547 641 00o 700 2O0 600 040 CI~P.DTE C!LM.DTE INOF.DTE I!X:~,DTE bT.MDT TTi.SDT LTTJ;.$DT GR,SDT ~TEN,SDT PEF'LDT LU,I.,~DT $$2,LOT LSRH,LDT TENS,LDT NPN!.CNL "~ CNB ~PO..~, CVTC.C~t, ~TE~,CNb TEMS,~bT CI~P,DTE IIXM,DTE TEN$,DTE DT.$DT TTI,$DT LTTI.SOT GR,SDT HTE~.SDT PEF.LDT LU.LDT $S2.LDT [,SRH,LDT TENS,LDT NP~I.CNL NPORoCNL CFTC.CNL ~TE~,CNL TKNS,~LT CI~P.DTE CILM.DTE IIX~.DTE TENS.DTE DT.$OT TT1.SDT LTTI.SDT GP.SDT HT~N,$DT PAG~I 36 289,500 290'250 0.000 18,953 4515.000 oo t6t6 000 3 158 285 500 295 500 2 348 4515 000 30 3t 92 777 ]79 142 750 -999 250 44 t56 48 313 0 000 2 609 4330 000 ooo 8 400 1528 000 21]~ '199 ,000 394,500 1,~86 4330, 00 64'849 ?0,t10 289,577 142,250 -999,250 19 703 241734 0,000 1,76e 4355,000 158,200 851,600 1451,600 16~641 1554.000 chlumberger Alssk'.a Co~put,'ing Ce.r~ter 992 05: 4 t ,,,, C ~ )., 1554.000 a C h i::.,, ..... DFPT. 5! 0©, O()c~ C!DP,DT[< 1.12 It~P,~,DTK ~,758 CILD.DTE !!3 I L '~ . D T E 6,9341 'l F ~ g. r> q~ E 20 .~ [',q'F -53 ~ , DTK a3.695 BP. ....... ,. ,.. L;, T 1 r~ 2.300 0 T L :'4 ,.> D 1~ 94 TT~ ~ SDT 459.20O TT 3. SDT 786 TK~:S.SO~ 44a0.000 ~,'TEa. 8[>T 139 DPI-~ l ,LDT ~5,'795 R }-'!OB. !.,[>T 2 OL8. L).'¢ T -0.05b OS8. bD'r 0 LL. LDT 220, ~50 L!TIq, LPT ! 1 ~ LSHV.I,BT tS52,000 $SHV,LDT 1660 L U~ ~.!. bDT 2.154 CALI. bDT i 3 ~,<~Tt'~ LbT 139,5OO ~,RES LD'r -0 R~'~,'~ Cr:{L 2.07q TNp~ C~,}L i7 .. ~. ~ ~ .~ .... .,..~ ~C~,;T. C~,x L 3009. !0~t ~CFT.C~?L 1563 IU:P~. DT~ 11 .b05 C !LD. I.:~T~] 96 l [., ~:. I)T~: !1..367 IFPE. [:,TE 20 I I't~D. DT~3 87.~75 ! T. Xg. DTF 7 SFT,I~.DTr ] 1..438 ~ r)T~ , ..... -. D? r. 1. .12s - '' ~ 1':~3 ~ .~, ...... r)TT.,.SpT ~.~oO . IL~.S~T 74 T',F2.8DT 3f:b. ~OC; TT 3. SPT 739 '{., ~ 'r 2. $ ~. T F; 4 5, (, O ~ > !2.: T T '~. 8 D T 12 ! 4 TF~,~$.SPT 4315. nor:; ~FT:4.SDT 130 r) T.S I [':,q' -'" 017 QS8 l,~'r {'~ -' .._t .. ~ . .. k. ~ ~ .. . .. 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LBT .5!~ TNRA.CNL .442 CNTC.C~L .000 ~PES.C~L .250 GR. ~LT .250 ~ T~;~'~. ~bT n 006 :]o~'ooo 22]s175o I ,212 1325.066 0 -g99.250 8.875 8'773 0.000 ]36.125 42.438 !705.000 !04.800 576.000 8 000 °lo:o4o 0 061 4201000 25O 42 438 1.7051000 2 204 3428 372 -999.250 -999.~50 10 6~ !0:398 0 000 42.031 1634.000 72 200 55~:000 ~ ~oo '°Io:o o 0.048 214.625 200 625 2:439 4~.031 !634.000 1.644 4743.304 .250 -909.~50 CIMP.DTE I~OF.DTE I!X~.DTE TENS'Di:E DT.$DT TTI.SDT LTTI.SDT GR,SDT HTE~.SDT P~F.LDT LU.LDT SS~.LDT hSRN.LDT TENS.bDT NPH!.CNL NPOR,CNL CFTC.CUb ~TE~,CNL T~NS.~bT CIMP ~ ...'E CIb~ T~OF" DTE TENS.DTK DToSDT TT 1. SDT GR.SDT PEF.LDT LU.LOT SS2.L~? 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LDT -999. 250 LS, LDT · -O9g, 250 SSi ,bDT -999,250 -999,250 G R bDT 999,250 -999,250 TNRA,CML -999,2b0 CNTC,CNL ..~Eo,CNb 999,250 g. -g99,250 70,125 I D P !'~, D T 7.3.500 I I.: D, P T E 20.000 I[)QF,DTE 3.9!9 !!R~,DTE 0.233 GR.DTE - o. 1 ! 9 tq'r E','; r'~T E 14o, I043.200 1594. 400 LTT4, gDT '999~z50 ~999,250 881,LDT -99q,250 SJ R~t;.LDT -999,250 Ga, LDT -999.250 -999,250 TNRA,CNb -999.250 CNTC,CNL '99g.250 MRES,CNL -999. 250 GR,MbT -999,~50 -999 25 -999:25 999 ~5 999.25 -999.25 -q99,25 :999o25 99 'XS -999,25 0,00 41.56 921,50 1.39,60 8 .oo -999.25 -999.25 -999 25 -999o25 -999,25 -999.~5 -99925 -999i25 -g99 25 83.!25 IDPFi, UTE 12 02 0 84 750 !l,.O. DTE !!:78 20,0n0 T .~aw DTE 0 O0 3,428 !'IPq. DTE 84:68 -6.9!0 Gk,DTE 50 21 -0.110 gTE;:4' DTE 943~50 ss. 7oo 33 oo iF3 !, 600 bTT4, gDT ! 49~, ~0 119.5o0 MRgS,SDT -O,11 -q99.250 [)RH~. 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SDT PEF I.,DT SS2,LDT LSRM,bDT TENS,bDT NP~I.CNL NPOR.CNb CFTC,C~L TEM$.~bT CIMP.DTE CILM.DTE IMQF.DTE !I×~.DTE TENS.DTF DT.SDT TT1 SDT GR.SDT HTEN.SDT PEW.LOT bU.LDT SS2.LDT LSRH.LDT TENS.LDT NPHI.CNL NPOR,CNL CFTC.CML ~TE~.C~L TENS.~LT '999,250 -999'~50 :999,250 999'250 :999.2 ,999'~o0 ,999~250 999"250 92,438 SI,063 o'ooo ;ooo ~,400 139,200 4 .563 92 ,500 '999,250 '999.250 '999. :999'250 ,999"250 ~999~250 999.250 '999'250 '999.~50 86.125 89, 38 0.000 4'836 2555.000 168.200 8301000 1506,800 5O 2!9 9431500 -999 250 -999:250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 250 ,!'$ ?ap,,e Verif-icatlop. Listir~'~ ~cblur~ber~er al. aska Co~out:,i~ Ce.nter DEPTo 2400,000 ClPP,DTE !~'PW. D?E 1.2.422 CILD.DTE t L,~, DT~ ~,i ,4.30 !F~E,DTE iIP~,DT~? 63,969 S F L ~. U T E J 1.461 S P. D l' E aT~;~;~. ~TE I ! 9. 750 DTL,SDT !20'500 DTL~:~. SDT TTg. SI)T 52 !. 600 TT3. SDT LTT2'SDT !If{2.009 LTT3,SDT D~H!.I,D~ 999.250 0I,,,$,LDT -999,250 OSS, LDT b!,. LDT -999.250 [,,ITH. hUT !,SHV,LDT '999,250 SSHV'.LDT p,4 LDT -999 250 C I;{TK,, ' ' ~C~T, CNL -999,250 RC~'T.CaL GP,CNL -999,250 TE~,~S, CNL ....... '. , ~,~[,T '999 , , . O ~. r-': T, 2 ? a 0,000 C I'~PP. DTE fi.313 l[,v DT~, ~.141 IFfY '' .' , - . >. . ~ 0.938 TT2.8[>T b31.2f)C TT3, SbT L T T 7. S r,, 126 .~. O O ~' T g !'5 S. S D T 24 ~; b. 00 {.,;' ~,' T g' ~.,'. S [5> T h b G -1 69,938 70,375 ILg' 2 o, o 0 0 I [;. O ~, ' D T E ....... , DTE 2,95 ! l I P ~ [.:;,T E -0,1 t 7 'HTK~,~ ' DTE 118.600 DTLF,SDT !043' ~00 TT4,SDT 1656~a00 bTT4.$OT !19,750 aRES.Sir -999.~50 DPHO, bDT '999. 250 LS. LDT 'g99.250 8$I,LDT '999.250 SlaM,bDT '999.250 Ga,hOT -qt:O, 250 -999.250 T~iRA, C:NL '999.~50 CNTC,CNb -99g, 250 MAES, CNL -999 ~50 14.28 14 .19 0 O0 46 31 932 50 1!8.60 768.00 140!,40 -0:.I! -999125 -999,25 -999.25 -999.25 -999.~5 -999 ~5 -99925 -999.25 -999.25 -999~5 -9991~5 72. 938 IDPH. DTE t 3.69 77.688 !L. 9. DTE 12.85 20.000 I!)OF,DTM 0,00 4,730 IIr~,i)Tg 81 43 6,4!.0 GR,DTE 45~53 -o.116 HTE~,DTE 930,50 1i. 4.900 DTLF.$DT 116.70 1o54,4o0 VT4.SDT 816 00 1572.~00 I.~T4.SDT 1.386180 -999[2b0 DRHo,LDT -999.25 -999.250 l,,,S.bOT -999.25 '999.250 S8!,L!)T -999.25 99~,250 qR,Lb? 99.25 '999,250 HT~!.LDT -999.25 '999,?50 T~R~.CNL -999.25 '999.250 CNTC.Cb!b -999.25 '999.250 M~ES.CUL -999.25 '999o250 G~.~LT -999.25 .- · ...... k'LT -.q99,25 -gq9 250 ~9.563 IPPH.DTE 91.250 !LO.DTE 20.000 !DOF.DTE 3,359 !IR~.I)TE 5,410 G~.DTE -0,1.16 ~TFW.DTE t2~.300 DTLFoSDT i.!20.800 ~T4.$DT !7a4,000 bTT4.SDT ~20.O38 MRES.SDT 1!.15 !0.05 0.0() 1!6.00 53.53 938 50 126150 ~74.00 1507.60 -0.1t CIaP.DTE TEN:S.DTE DT.SDT TTI.SDT bTTI.SDT GR.SDT HTE~.SDT PEF'LDT sLU.LDT $2~LDT LSRHobDT TENS.LDT NP'~i.CN5 ~PORoCNb CFTC.CNL aTE~.CNb TENS.~bT C!MP,DTE CIL~,DTE IMOF.DTE !IXM,DTM '~ ~ . ~EN~.DTE TDT.SDT ..TI'$DT LTTI SDT · HTEN.SDT PEF.LDT LU.LOT SS?.,LDT LSRH.I, DT TEMS,bDT NPHI.CN!., ~por.c~t, CFTC,CNL mTEM,CN[.~ TFNS.~LT CIaP.DTE CIbM.DTE IaOF.DTE TIXM DTE DT.SDT TTI.SDT LTT!,SDT GP.SOT HTF:M,SDT PAGE: 48 87,~38 0.000 2535. 123.700 775 600 I4!0 000 46 3!3 93~ 500 -99 250 -999 250 -999 250 -999 250 -999 250 -999 250 ~999 ~50 999 250 -999 250 -999 ~50 82 75O 0,000 25t5 ~48 300 830 800 1403 600 45 531 930 500 -999 250 -999 250 -999 ~50 -999 ~50 -999 150 -999 250 -999 250 -999 ~50 -999 ~50 -999 250 120 250 122~750 0,000 4,656 ~465.000 il . oo . 9.600 1517 600 53:531 938,500 ,:I$ Tare Yerificati. o~, I.,istInC ;chlumberqer Alaska t.7ow, put!~? Cer~t,e,r D T ~ .14 258 ~F 63 ' .... ' ....... ,4, 3 ~ I I ~TL.SDT :!..15.700 DTI~N,SDT gDT 538,000 -T~3.8DT $ [> T t 022,400 !., T T 3, S O T T~NS.SD, 2430,000 DP~!,LgT -999,250 RPOB,I,DT LE;T -999,25() OSS. LDT L!.:. L[:,T -999,250 LOT -999,259 SS}{V. , [,DT -999. 256 R~'~P,CNL -999.250 T NPi:4. CNI., ~CNT'CNL -999,250 RCFT.CNb (;P,CNL -999,~5f> HTE~,~.CNL -9~9,250 U. F p T 2000.06 (~ C I [.'. P ,, D T F: Il ~,,', ~TE 10, 387 !PRE. !>TE ' .... .. p ......... ..,.- !..~ .- . ~ ..... . ........ P T I.. S D T ! 34:, I. 0 (} [) T L ~;. 5 [> T TTP.SI)T 53J.6C(> TT3.SDT L~T2. SDw 1347.60(.~ bT~3. S!)T . . ... : _:. , ~ ~J QLS. LDT -999.2~) OgS. LDT I,f .[.UT -999.250 LITN.I..PT bSb~v bDT .oq~ 2~(', SSHv I,r;T : ~ ~ .... ~ ~ _ !.,t.!RP. f,Or -qc~.250 PC¢~T.CbL -99U.75() F'CFT. Cb~L GP.CNL -999.25() ll-hUG.l.r~92 05:4! '" 999,250 D R H (). L D T -999,250 I.S, LOT -999,250 S,SI -999,250 S -999. 250 -999. 250 TNRA, CNL -999,250 CNTC,CNL ' 999,250 M 1'~ E S, C N L -999,250 GR, ~LT -999.250 65. ¢ 0 0 I D P 20,000 IDOF.DT~ 3,569 i'iRM, DTE 4. 7 I. CR. 9i 5,200 T T4, S~T ! 562, Ot)O LTT4, SDT 121.063 ~aRES, SOT -999,250 DR~[.), L, DT -999. 250 !,5, LDT -999' 25() SSl ,LDT -999.~50 Si.R~,LDT :o99,250 G[~ LDT ~90,250 H TE~:~'' bDT 2999,~50 999,250 '999,250 '999,250 GP, ~[.,T -qgo, ~50 ' TM ' ~'4LT 75,563 IDFH.DTE 7a,625 20.000 !DOF.DTE 4,1.52 IIP~i,PTg -0.123 GR -0.116 HTE~.~, DTE 127.600 DTL~',.SDT 1209,~0o TT4.SDT 1825.~00 LTT4.SDT 120,750 -999.250 DRHO.LDT '999.~50 '099.250 SIPS.hD. 'ggq. 250 OR , LDT -999.250 [~TEN. LDT -999 250 -999 ~ 250 CNTC ' . C N L -999.250 -999.250 '999.2 -999.~ -999.2 -9991~ -999o~ -999.2 -999.2 -999.2 -999.2 -999,2 153 14;4 0 0 66 5 43 929 50 115.3 '/39.6 -999 2 -99:912 -999,2 -999.2 -999.2 -999. -999 -999'9. -999.2 -999.2 13.2 12.7 O0 43.5 923.0 122.6 975.6 1584.0 -99q 2 -999~2 -999°2 -999o2 99 2 -999.2 -99.2 -990.2 50 50 50 50 50 50 5O 5O 50 50 50 75 45 O0 00 O0 O0 O0 15 50 5O 5O 5O 50 50 5O 5O 5O 5O 5O 7 Il 00 50 63 O0 O0 00 O0 16 50 50 50 50 50 50 50 50 50 50 5O PEF.LDT LU. LDT SS~, bDT LSRH.LDT TENS. bDT NPHI, CNL i:\I POR, CNL CFTC. CNL ~4TE~,CN5 CI~P.DTE C!L~.DTE IMOF.DTE IIX~'DTE TENS,DTF DT.SDT TTI,SDT LTTI.$DT GR SOT HTEN:SDT PEF.LDT bU.LOT SS2.LDT LSRH*LDT TE~S.SDT NPNI.CNL NPOR,C~L CFTC,¢NL ~TE~.CNL TENS.~LT CIYP.DTE CILU.DTE I~OF.DTE IIXM.DTE TENS.DTE DT.SDT TTI SDT GR.SDT HTE[~.SDT PEF.LDT LD.LDT SS2.LDT LSRH.LD? TENS.LDT NPHI.CNL NPOR C~L CFTC~C~L TENS,~LT PAGE: 49 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -99 250 -99~ :250 -999 250 -999250 69 '2 ' 0 ooo 5 500 o o 1' 746 400 1266 000 43t 929 i00 '999 250 "999 250 ,.999 250 -999 -999 250 -999 250 -999 -999 250 -999 250 -999 250 98 438 96:375 0000 5:6s2 2365,000 200,600 935,200 1587.600 4~ 563 92]!000 -999 250 -999'250 -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 99 250 ~IS Tape Verlficat!on Listi~o ~chlumber¢/~er Alaska Co~p:!t;ir~<~ Cer~ter DFPT. !9©0,000 !~P-w'. DTE 8,797 I L~. F..:TE 9,406 IIRD.DTK 74,189 SFL'U, DTF 6. 750 ~TE~, [:.TK 1i9,875 DTI.,. SDT 1 TT?, TKNS.SDT 2275.000 OLS..LDT 9~9 2:50 ,, 'e' GP.C~L ~999,~50 HTENeCNL -999 250 , u 00, D T ! ~p~'~ DTE J5.453 II~D,DTE 55,969 D~' . . SF.LU. .r,~ J 1.742 TY?, S[)T 526. :~O0 TT3. SDT ~.TT~ Sr~T 1i72 ()C0 T~NS.SDT ~500f) R:TF~i SI>T 0LB. LO'r -999,259 085. L L I.~, L i:') T - 9 o 9,25 O L I T H, L i> T [.,SF V.I..,t~T -909. 250 ASH V, I.,PT ........ . .... ,. A !, I, L b T ~TE~ .Lf>T -09'9. 250 [~" ~,C~:I. -9oa.250 ~C~'~;g: C~;L -9~9 25(:: . . e ~ .. . i!-AUG-I. 992 05:41 81.!88 IDPH,DTE 82,3!3 ILD,DTE 20,000 IDOF.OT~ 4,738 !iRa,DTE -0,J. 38 (;R,DTE '0,115 HTEN,DTE 1.25, !00 DTLF', SDT J.!74.000 TT4.SDT 745'600 LTT4,Sf)T -999~250 -~99,250 L$.~DT -~99,250 $$!,bPT -999,250 ~TE:!. LDT -999,~50 TN[~A,CNL '999,250 CNTC -o90 250 M~ES'C~b .C~L "99°.2S0 55,000 !DPH,DTK 5~,31] IL!:).DTE 2o.o0o 3,0~6 IIR~,f.)TE -~.!.7~ ,.. ~" I:)TE '0,I!5 HT~N,DTE !20,500 DTLF,SDT 10(~2,400 TT4,SDT 1!90CO -999.250 SSI.LDT -999.250 -~99 250 HTE~..:.LDT -..,99~250 TNeA,CNb -99~250 -990.250 89.J~g !DPg. DT~ 92.688 !LD.DTE 0.0()0 IDOF.DT~; 4,960 TIPT,DTE 0.~74 -0.!15 129.900 DTLF.SD~ llb?.400 TT4.$DT 1822.800 !,TI4.S9T 118.875 12.3o5 12..1.~1 0,000 100.500 44,750 929.0O0 ~22"600 921 600 15151200 -O 115 -999 50 -99~ 250 -99.,. 250 -999 250 -999 250 -999,250 -999.250 -999 250 -999 250 -999 250 -999 250 18.!72 17 125 0:000 64,125 44.!25 25000 20:300 773.200 1~28,400 -,O 115 -999' .~50 2999 250 999:250 -999 ~50 1999 250 999:250 -909.250 -999.250 -999.250 -999.~50 1! 2O3 !0:78! 0.000 115.063 48.500 923.500 127.500 ~99 600 -0.115 C.I~P.DTE IMOF',DTg !IX~.DTE TENS,DTE DT,$DT TTI.$DT LTT~.SDT G .... ,SOT HTEN SDT PEF I,DT LU bDT ss ~ t,~T LSR}I,LDT TENS,LDT NPHI CNL NP0~:C~:L CFTC.CNL TMNS,MLT CI~P,DTE CIL~ I ~0~': DTE I I X~. DTE TENS. DT.E DT, SDT TT1, SDT LTTi. SDT GR.SDT HT[:N, SDT PEK. LDT LU, bDT SS2,LDT LSR~.LDT TENS.LDT NPHI,CNL 5PS~ .CNL CrTC'C~L ~TE~,C~L C!~P.DTE CIL~.DTE IMOF.DTF IIXM.DTE TENS.DTK DT.SDT TTI,SDT LTT1,SDT GR,SOT HTEN,SDT PAGE: 50 113,563 10.6 'o:loo 9 648 2275 000 195 600 934 400 .929 000 999 250' '-999 250 -999 250 -999 0 '~999 250 -999~50 -999 250 -999 250 -999 250 64,688 67.563 0,000 5 770 2225 000 142 000 776 000 I432 000 44 925 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 -999.250 124,875 121,688 0.000 9 008 2225 000 190 700 902 800 1530 400 48 50O 923,500 ~ ,ave Verification List;ir'~a ;c.~lu~-~herqer Alaska Co~,Put~:.~o Center D F p T. 16 I ! P D, P T E SFLU. ~'~ 1! .844 ~ T ~" ~ DTF 1!9,12~ D T ~, 8 D T 1 ...... T ~ 2, S O T 52.3. :6 o 0 1':, T T 2. $ [> T i. 1 o. 6.00 0 T ~: N $, 8 D T 2 ! ! 5. {) 00 DPHT,Lr')T -9oq 2~o OI,S,[~DT -999 250 ~, !.,, 1, D T - 999,250 LSHV, LD'P -9 · ... I, ~;' ~. l,[, t'~'r - 9 t~ T {;" ~, bDT , -..., ' ....... . .... 5 (;~.CN!, -999,250 ,.. , ~...,- ~ .... M!3T -gqq 25r) UFPT, 0 [: ('; C I 1500'07fi CTI.,D l[,~ DTF 1.2,242 IFPE.I"~T~ . . ~ .. ....... II~O l'~'w 57.21.c~ IIXD PTF' . . ~ -., . ,.. . .. ~ --. .... , sF[,I!. I'~7'F ! 0.781 SP. DTF: ;~.'-' T ~': '9 . r:.. T f< 112.250 DTL SPT ~n4.900 DTI L~'T?, SDT 1 '187,600 I~TT3. T E ¢,i $, S D * 2 0 6 0.0 0 (') DPN I . !~DT -999.25() R~'i~. LPq'j . - ... ., .. I L, [..~DT -9Q9 259 [,SuV.~,I)T a99 ~ 0 H LUP¢, !~r2T -999. 250 CALl. LO'I: ~T~, bi)m -99q.'25Q ~4RES. LD"~ RT~P. C~.;I 999.~50 T~--~PH. CNb PP'~'. r'Wb -99° 2%0 G~'. C{-~L -909,250 TF;NS.CI:[ HT~ N. Cf!, 'qgq 2~('~ ~.,.. ..... - ~ , ~ . 11-.AU(;-!99~ 05:41 ' 9 q 9, .,, .. -999, 50 LS, [.,DT '999. .';99. 250 SS1, [~DT -999, 99. 250 S 1 Ri'!, LDT -999, -099.250 GR. ~., . -999,250 HTEt<i. LDT -999, -999.250 TNRA,CNL q99, 999,250 C};~TC, { ....L 2999. -999.250 -g9g, 250 GR '999,250 ~TE*!, MLT -999, 7., 000 20,000 I!)QF,DTE 2.725 IIRra DTE 1.875 " (' , UTE '0.!t5 120.700 DTLF'SDT !054,400 TT4:,SDT !~54,400 bTT4.SDT i 9.1 '~5 ~,'~ R ~$, SbT '999,250 DR~O,L!)T -999,250 [.~Se LDT -999.~50 SS!~ .LDT ~ ~" ( ...... '9~,2~ ) StRN.LDT ~999 250 G~. t..,DT -999,250 -999,250 CNTC,C~Jb ..... ~0 .~ ES C~L · 999, ~5 ~ GR, -99q.250 13. 1.2, 0. 76' 45, 925. 122 801 ' · I462. -999, -999. -999 -999~ -999 -999~ -999, -999, -999 -999, 61. g 75 1 P P H:. ['. T E 16 ('4.125 II~D, DTE i5; 2o.ooo IDo,~' PTg 0 2. 498 : , [) T E 7 -2. ! 15 G~, QT~; 39, -0.115 BT[:?-i. PT~ 90~, lO50.BO0 TT4,at)T ~10. 1565 20~ bTT4,..q9m 142! -999,250 DRHO./,DT -999 -999. 250 -999.25a S8!.[.DT -999 -999,250 SI.¢H.LDT -999~ -999. 250 Ga. LDT -999. -qaa 250 HTE~.;. bDT -909. -q99.~bO C~:TC. C~b -999, -g99.~50 MI~ES. CN[., -99g. -qgg.250 GR. qI.,T -999. -999.250 ~!TEN. qbT -999, 250 250 250 250 250 250 25O 25O 25O 250 250 71 9771 000 125 531 500 300 600 800 115 250 250 250 250 250 ' 0 ~5 25O 250 250 250 25O t. 41 586 000 375 78! 5O0 900 000 20o 115 250 250 250 250 ~50 250 25O 250 250 250 PEF,LDT LU.bD~ SS2.LDT bSRH.LDT TENS.[,,DT NPH!.CNL NPOR CNL CF T .. ~TE~. CN b TE~S.~LT CI~'P.DTE CII,,~.DTE 'NQF DTE TENS,DTE DT.SDT TTloSDT bTTt.SDT HTENiSDT PEF.LDT LU.LDT SS2.LDT bS~.BDT TENS.LDT NPNI,C.NI, NPOR.CNL CFTC,CNL ~TE~.CNL TENS.~LT CIgP.DTE CIhM.DTE I~qOF DTE TE~S.DTE DT.SDT TT1 e 5TTllSDT GR.SDT HTEN.$DT PEF,LDT S$2 bUT LSRH~!~DT TE~S.LDT NPMI.CNL ~pr'lP C~L, C ClC L ~TE~,CNL PAGE~ '999,1~0 -999. 0 -999'250 -999;250 -999'250 -999'250 -999,250 -999,250 -999~250 -99~250 87,063 80,313 oo 2115!000 i23;900 806'400 I464,00:0 45'531 925'500 -999,250 -999.250 -999 50 -999 150 -999 250 '999 250 -999,~50 -999.250 -999. 50 '999,~50 82,750 8!.625 0 000 2060,000 119,300 820,800 !430,000 39.781 903,500 -999,250 '999.250 -999 250 -999 250 '9991250 '999,250 '999,250 '999,250 '999,250 IS '!:ape Verifi. cat!or~ I. istina Chlumberqer Alaska Computin9 Center ~400,000 CIDP. i.)T[; D T g ~, ! 02 C I [. D, PT E D T F 73,275 DT~: 7,0 ] 5 ~TEU.DTF 117.1~8 SDT 134. 600 'OTL~q .SDT gDT 60!. 600 TT3. SD'r TF~'~. S[:)T 2065,000 .LDT -999,250 RHOB.LDT LDT -999,250 L P T - 999, ~ 50 b I, T H ' L t) T LDT -999. 250 L U, T - 999,250 C h !, I, L D T LDT -999. 250 ~*~ ....... C. ~ L - 999,250 T ?,~ P H, C ~,~ L PCPLOT. C~L -909.~50 RCFT,CP[~ G~.CNL -999,'750 TENS,f'NL -999,250 DEPT. 13OO,000 CiDP.DTE I~PH.DTE 6.6! 3 C!LD.DTE TL.~.DT~ 6,45'7 IFRE,DTE II~r'.DTE ! 1 3. 375 !.IXD.DTE SFLU. DT~7 7,309 SP. DTE .,. ....... , S r)"r i37.~'~O~ ,,~ D T L N ' , S f)'r T?2. ,SDT 53c~. 60{., Tq' :.~. 8ri"- ')" i. TT~ SDT !2~8' "' ' . ,OCO [.,TT 3. ~DT [)PB!. L[~T '999.250 R~'~Ob. LDT OLS. LOT '999,250 QSS. LDT t,~,.LDT -999,750 L!TH. [,PT !..,!.'P' [~ [ [~T -999. ~S~, CA!,I. I,DT gTEu. I,[)T -999.250 ~,~aES. LDT ~Ne,CN!, -909.250 T~!D~,CNL GP. Cp:,~[, -999.25a 'PF~JS. CI, L }4 Ty~'. ~-~ T,T -999, ~5~ ~" ~ ES. ~' I,T 05:41 75.938 I !) P H. O T E 8t .313 IL.b. OTE 20.000 !DOF,OTE 4,652 I!R~4,DTE 1.,897 GR,O g -0.116 g TE.'.~, DTE ~ 33. 700 DTLF, SDT 1110,000 TT4.SDT .:!.774.800 LTT4,SDT 117'188 999.250 DR~O.LDT 2999 ~50 LS,bDT 999:25o 999. 250 CNTC, CML 999,~5o GR, k~LT 126,!88 IDPB,DTE 12~,1~25 ILl). DTE 20 . 050 ! [) O [~' , 'DT~: 7.113 IIR~4,OTE -4. I 17 GR, DTE -0. ! t. 6 HTEt~, DTE 135.800 DTLF.SDT 107~.400 TT4.SDT 1~00.000 5TT4,SOT ' 999 [ 25 0 D P H (:.]. b :')T -o9o'250 GP,LDT -99~ 250 HTE~,LDT -999.~50 CNTC.CNL -999.250 ~RES. Ct~L -999,250 GR.MLT 26. 125 I t)P_q. DTE 89 31. ] I[ f;'. r)TE 20 .' 000 4.145 !I. Rq. DTE -7.621 GR, DTE -0,! 17 HT~J!~.DTE 14q. 10o DTLF. S[)T 109~.000 TT4.SDT 17~0.O00 LTT4.SDT 13.156 !2.297 o,ooo 99,938 5!,344 911,000 1.33.800 828,400 1507.200 -0.1!6 -999.250 -999,250 -999,250 -099.250 -999',250 -999,250 -999 250 -999:250 -999,~50 -999,250 7 918 7~801 0,000 146,000 41,938 925,500 134'500 799.600 15~5i600 .. 0 1.16 -999 250 -999.250 -999 250 -999i250 -999 250 -999 250 '999i250 -999 250 -999250 -999.250 -999.250 tl.602 11.188 0.000 112 563 5516 922.000 147.400 830 800 1527~600 -0.117 CIaP.DTE C!L IIX~,DTE TENS'DTE QT'SDT ~T1.SDT L.~.TI'SDT HTEN.SDT PEF.LDT _LU, LDT s~. 2. LDT 5SRH'LDT NPMI,CNL NPOR.CNL CFTCoCNL ~TEM.CNL TENS,~LT CI~P,DTE I~OF.DTE IIX~.DTE DT.SDT TT!.SDT LTT! gDT GR[$DT HTEN.SDT PEF.LDT LU LDT bS~H.LDT TENS.LDT NPHI CNL C~TC.CNL MTE~.C~L T~NS.~LT CI~P.DTE C I 1.,~. DTE I~QF.DTE lI×~ DTE TENS: 'r DT.SDT TT!,SDT LTT1 ,$DT GR,SDT MTEN.SDT 123 375 65 206 250 000 ,oo 8 400 !505 200 51 ]44 91 000 ~99~ 250 ~99 '999 50 -99 25 -99~ 0 250 '999 250 '999 250 '999 250 I5. 50 0.000 6 543 2045 000 142 000 802 000 1518 400 925 500 -999 250 -999 250 -999 -999 250 -999 250 -999 250 -999.250 -999.~50 -999.250 -999,250 113 563 119 063 0 000 5 879 2035 000 151 400 836 coo 1521 60o 55 688 922 000 ~I$ Taoe Verit!iCati. on !J. stins chlumber~er Alaska Con'.Dr!tinG Center DPHI. L[)T -999.~'50 ,0 E; P'r . TT~. SDT L T T ?. S D T TENS,SBT D P ~ J, L 1.) T !,,I,~k f~, LDT ...... ChL DEPT 1(.~00.000 CIDP,DTE: i~iS;~'r>T~. ..... 5.1.37 CI[,D'I:,TE ..... I II, O' PTI': 131 .750 IIXD S F [.,, { ~. O T [7 4.4 CT!~. SDT t 38 TTT.SPT 47! ,60,3 ' T F ~ g, S D T ! 965.000 ~ T E H, S F; T Ol,S, ;,[3T .qqo {.~S~V, L[:T -999.250 SSHV,LDT Pwb'~ ~-[ -qqq, 25() Tt;PH. ChIL ~.C~T. C~'~ ~ 909.250 RCFT,Ch:L HTEh~. Cr,~l, -9°9.250 ! 1.-/~UG-1992 05:4:1_ -99~ 250 e,: LDT -~99~250 S:IPH.bOT -999' 250 GR, bDT '999,250 HTE~, bDT CN C. '099,250 C~, 9. 99.25' 'C~b ' ~,0 ~4RES. -999,250 -999. ~50 U T E ~,~. ~ [,,T 88.t88 IDPH, DT~3 8 ~, 000 20. 000 0,695 :I'![P. g. DTE 'i0,070 G~. OTE -0, ! 17 ['~TE:N,.DTE !33 200 DTI,F CDT t067;260 TT4.Sr>T ~731 200 LTT4.SDT ! 14~688 ~RES, SDT -999,250 D~HO, bDT '999. 250 LS,BDT -q99,~50 SS1 ,bDT '999.250 -990. 250 GR, BDT - 9 22So Ttj .c -999. 250 -990,250 ~EcS. CNL -999,~50 G~, ~4LT 144 875 I[,P~. UTE $ o 2 o o o i.'.:.,f:; 2:>T 20,000 IDOF, OT¢j 9.672 IIP~,DTE -10. 633 GR. {.)TE !37.500 DTLF.SDT 1092,800 TT4,SDT 1829 O00 LTT4,SDT -999,250 DRHO. BDT -990,250 LS.bOT -99q.250 SSI -~9g,250 S~RH.LDT -999. 250 GP, bDT ': ~' C~ b -999.250 T.RA, ... -999.250 CNTC.CNL -99o.250 -999. 250 GR. -099,250 -o99.2 0 -999 250 -999 250 -9992250 -999 50 -999 -9992 50 -999.:250 1t,336 11.227 0 48,406 930,000 133 200 7992600 o 800 -999 250 -990 250 -999 -999 250 2999 999 50 :999,250 999,250 999,250 999.250 999.250 6 895 61664 0 000 183 625 44.03! 972,500 135.900 ~12.800 1526.400 -0.116 99~ 250 -999 250 -999:~50 999.250 2999.250 -999.250 -999.250 -999.250 -999.250 -999.250 PEF.BDT LU. LDT LSRH,LDT '~ ,.~ .... . ~ E.~ S L D T ~,r CNL CIMP.DTE CiLM'DTE IMOF.DTE iIXM,DTE TENS,DTE DT,SDT TTI,SDT LTTI,SDT G~,SDT HTE:.N,SDT PEF,LDT LU,bDT SS2,bDT I~SRH.LDT TENS,bDT NPHI,CNL NPOR.CNL CFTC,CNL ~TE~.C~B TEMS.~bT CI~P DTE I~QF.DTK IIX~.DTE TENS.OTE DT.SDT TT1.SDT LTT1.SDT G~.$DT HTEN,SDT PEF,LDT LU.LDT S$2.LDT [,SRH.LDT TE~S BDT ~POR,CNL CFTC.CNL ~TEW.CNI, TEMS.~LT PAGE: 5,3 -999 250 -999 250 -999 250 -999 250 -999 250 -999 2:50 -999,250 -999"250 2999.250 999,250 00~ 8!3 563 o ooo 0 740 2015 000 137 200 803600 1476 800 48 406 930 000 999 250 :999:250 :999,250 999,250 -999,250 -999,250 -999 250 -999i250 -999 250 '999'250 i94 500 1951250 0 000 7 887 1.965 000 176!000 82O 4O0 1527 200 44 031 972~500 -999,250 -999,250 -999 250 -999 250 -999 250 -999 250 -999 250 -099.250 -999,250 -999.250 IS Taee verification Listi[~q chl. umheroer alaska Con~[:>ut. in<.~ Ce ter 05:41 54 DEP?, 940,000 IkiP~'. DTE J. 950.OOO . ........ 09 TT~,SDT 257. T 5 O · 50 !, ~ o 0 LDT -999. 250 !,L, ...... L~IFN,LDT° ,:St, RT:NP, C?.tL -999,250 c~- .c~ :t,, ~9~" 2~o C~L .qoo 250 -400.500 1532.000 -20O,375 -O 1!6 70 60O 478 800 667 600 117 ~75 -q99 -99~ 250 -999 250 -999 250 -999 250 -oq~,250 .999,250 -999 250 -~99' "' ...... .250 !DP~,OTE !LD,OTE !DQF,DTE I!R~,DTE GR,DTE HTEN,DTE DTL~,SDT TT4,SDT LTT4.$DT DRHO,LDT LS,bDT SSI,bDT $1RM,bDT GR.LDT HTE~,LDT TNR~,CNb CNTC.C~L .Eo,~Nb GR.~bT !950.000 1950.000 0. 000 -862.500 966°000 ~ 9o,8oo 369. 600 704. 400 .0 11.16 . -999,250 -999 ~50 -999i250 -999 :999,250 999,P50 -999. ~50 -999,250 -999 -999;250 C!MP.DTE CILM.DTE IMQF.DTE ItX~ DTE , ~ S. D TE TEN DT.SDT TT1.SDT HTEN.oSDT SS2,BDT LSRH.LDT TENS.bDT NPHI.CML ~POR°CML C~T.~.CNb MTEM.CNL TE~S.~bT -864,000 -850,000 0,000 ~769,000 !9!0,000 57 600 371 200 708 800 966,000 '999,250 -999,; 0 :999,250 999,~50 '999 250 -999 250 -99'9 250 -999 ~50 -999 ~50 [~E(: $'[Z~ : !024 TYPE: : !.~0 **** F T .I..,E lqEA DEF: **** SFPVICE] : FLIC D~TE : 92109111 ~::a~ PF:C SIZE : FIbF TYP~j : l~t; [j~ST Fl I.,~ ****************************************************************************** FILE Verificatior~ t.,is tir, q Alaska Cc)r~ptlt. i. n0 Center lI-AUG-~,997 05141 ¸55 50-733-20434 DATA I!>~CL, tt[:~!') - TYPE F''h~ GRANITE POINT W~J GRAk!TE; POINT #50 A¢I~ 50-733-20434 ~"L COND #3-1! 2386'S & 1372'E SFCT TOw? 1 ST~T ALASKA N~TI USA APO ;'T 109.1 TPL FT ~21nO. T[:I FT 981. DF'T ['RESH GE!., DFI) G/C3 ! 3.3 DFpH 9,30000 ! DrV S 64, !7, F I, F3 4.2 Field Name Well Name ApI Serial aumber Field bocation Section TownsBiD Ranqe County State or Province Nation witness Name Service Order Number Permanent datum Elevation of Permanent DatUm boq ~easured From AbOve Permanent Datum Mlevatlon of Kelly Bushln~ Elevation of Oerc~ri Floor Elevation of Ground Level Total ~eoth - Briller Total 5epth - Logger Bottom Log Interval Top bog Interval Drilling Fluid Type Drillin~ Fluid Density OrilltnO Fluid Ph ¢rllltno Fluid ;iscositg Orill. ino Fluid Loss gesistivtty of ~ud SamPle mud Sample Temperature ~esistivit~ of ~ud Filtrate S ,!S Ta~e Veri~:ication ti, stinc~ ,chl. t]mbi~rqer' ,A.!a~ka Co~,r~ut:.!n~i~ Cer~ter 992 05: 4i 3 24 Resistivity of Mud Ca~,e Samo! .. oa~Ple Temperature lq4, Bottom Hole TemPerature . 2 66 0 3 73 6 73 ¢ 6~ 0.166 li 66 13 ~6 0 16 66 o 60 1 ** SET m m .. mm mm ~s mmmmm m~mmms mmmmmmmmsmmmmmm mm mm s sm ms m mm m mm ~ ~ m m~m mmm t~,~ 1 DF'PT FT 530759 O0 0()0 O0 0 2 !. ! 4 6B 0000000000 !~.ulN ~!~1' ~ti~r,,~ 53n759 On 000 (~0 0 ? I I 4 68 0000000000 P~NC ~;[,T OHr<~::. 53C75q O0 (~[:i) O0 0 ~ ] I 4 69 0000000000 ,IS Taee verificatior~ List.~nq 12113,334 :1 ! riO0. 1 ! 7 0 0, !, ! ~ 0 0,000 1!500,000 ~ 1400, I 1 .~00,o0o ! ]. 000, t 0900. 10~00,000 !. 0 O 00, [;' 00 ! 0500, 1. 0400, 1. 0 3 O 0, (> 0 l 02 (:' O. 0 l 01 0(), (.)0 100(,t) · C,O 9900,000 9800, 11-ALiG-1992 05:41 0,88! 0.881 4.105 7.012 2.42 ~ 3.613 5,05! 2,453 10,492 27,5~:~.3 6.199 6.570 58,000 3.973 2,6!.3 !.734 2.°47 4.984 8,477 -999.250 13.305 3.020 0.850 O. 850 3.633 7. 742 4.125 6.35g 6.625 4.39! 9.992 39,,625 3O,,344 7. 598 6.875 ,1.896 46,156 7, ~.76 7,492 3,721 3.383 2.887 6,676 -999.?,.,50 9.859 4,875 PAGE: 57 .,!S 7'a~,e vertficstto~ bistiDq ~cblumberqer A!~ska Com~utinD C~nter ,(,-19~2 05:41 20,688 BMNO, M!.,T 9,383 BMN©, MLT 5.707 3,381 B~';NO, MbT 20.422 6.55! 1.511 B~:~NO. HLT 3. 395 BENO, ~I.,T 4.! !~ 2.1 I ! B M ~,i 0. a 5 T 3.4S8 11,242 3,342 B~NO,MLT 3,609 3. 449 2,01~ i ~. 250 B?NO. MLT 1 .4P4 BMN9. ~bT 4.702 3.609 2,31 3 I .217 !2.133 7.520 4.785 9.047 5.656 6.223 7.977 2.908 3.334 5.445 5.746 3.174 3.387 7,199 4.895 5.375 I .915 4. 430 2.820 15.14!. 2,926 2.873 3.049 4.730 3.352 1.RIO PAGE: 58 ~IS ?ar~e Veri~ilcat:ion LlstJr~C.., ;chlu~ber~Ter Alaska Cotr~putino Center S~RVICE : FI. lC V~S!O~ ~ 00!~07 DaT~': : 92/081!! F!bF TYPa ~ LO ! l"AUG-!992 05:41 59 **** F!LE Fi g ~a ?,) F:R **** SERVICE : FL!(~ V~S ION : O01a07 !)AT~ SA~,~P.!.~,k;l? ~:~V~:RY -,500b PEET LITH[) ******************************************************************************* V A L U O E F I ttN~1CA[, ompanv amc G~A~;iTE POINT Field Na~e GRANITE POINT ~50 ~,~ell Name 50-733-70434 A,p! Serial Number Verification l,,istino c:hlUr~berqer AlasKa Co~out.in<~ Cer~ter ll-AUG,I99~ 05:4~ PAGE: 60 FT FT FT FT FT 6/C3 S 9EgF 13 ! 0~4 12~ US ~ STE~RT 530759 '~09 999.25 -999.~5 12145, 12094, 981, FRESH GEL ~:iUD 3 Section TownshID County State or Province Natlo~ Witness Name Service Order Number PermaDent datum Elevation o~ PermaDent Datum Log ~easored From Above Permanent Datum Elevation of Kel!¥ Bush~n.~ ~levat~on of Derric~ Floo~ ~levation of. G~oUn~ he~el Total Depth - Driller Total Depth - Log~er Bottom ho~ Interval Top Log Interval Drlllln~ Fluid TyPe Drilling Fluid Density Drll~!.~[!~!q Ph Dri, lli~ Fluid Loss ~esistl~i, tV of ~ud SamPle ~ud Sample Temperature Res~stiS~ty of'~ud Filtrate ~ud~Flltrate Sample Temperatu .24 Resistivity o~ ~ud Ca.~e Sampl . R, gud Cake Sample Temperature B~'F bEGF 1~4,. gottom.Ho.le Tem~era:u. re TYPE : CUPV DPFT ....... ; .......................... . _ . . ................. Debt nensitv Porosity Bulk Densit.¥ Oelta Photo}.::.lect rJ,.c Factor Oualitv co~t. rol of !o~<~ spaCinq for 0ualJtV cor, tro! on short, spacing for bDT I.,oDq S~acir~q (:~{?,p~teO Count ~ate (LL+LU/2) l.;ono !:p[,eI' J-2 ?j.r~do~' Count Rate {!,UJ+bU2) Lono !..,ov~er t';i~dot,¢ Count Pate ,Short, SpacJn~ ! ',~'iDdo:-~ CouDt.: Rate Snort Spaci~ 2 ~inr~o~, Count Pate ,~IS Ta~e ver.i, fication Listlr~q ;chlUmberq~r Alaska Co~.[~utlno Cent~er IJ-~OG-1992 ©5:4! $SHV o~.ort 8~:>aci, no ~,~igh Vo'!t. aqe SIR~ ,.hart Sp ._inc 1 C~LJ Cal iDer TEt,~S Tensf, o~ }~ T g~,~ ~d Temoerature ~i~ES ~ tJ D ~eslstivitv H~'~N Head Tension NPF!l ~eut rod Porosity TNPH Ther~aI Net!t. ron~ Poros,itv T~.~.~ ~'herma~ ~.leutron Ratio Calibrateo FtPOP ~e.tro~ PorositY from a~ ap;:)licstion Proqro~ C ~' T C C N T C C~TC CFTC PAGE: 6! AlasKa Comput~n~ Center DPii' ? CS(; Pti 530759 00 RNO~ CSG GtC3 530750 nO 000 D~F~O CSG G!C3 530759 00 000 PEF CS(; 53075q (:'0 000 QLS C~G 530759 O0 000 oSS CSC~ 530759 O0 0O0 L ;~ C S C C P S 53075 q 0 o O 00 LU CSt CP~ 530759 09 000 LI, CS~ CP8 530759 oO 000 1,,I TN CSG CPS 530759 S8~ CSG CPS 530750 8S2 CSG CPS 530759 O0 000 LSHv CSC ~ 530759 OO 000 SSHV CSG V 530759 00 000 $!.R~ CBS G/C3 530750 o0 LS¢¢ CSG G/C3 530759 0() GO(: t:,{.JP~ C8~ G/C3 530759 O0 000 C~L! CSG t~ 530759 O0 (>00 GR CS{7~ (;.~ P I 530759 O0 T F ~4,~ C~SG LB 530759 O0 NTE~ CSG DEGF 530759 O0 000 ~.:,~ CSG O14~,~~,~ 530759 00 000 HTEN CSC [jB 53075q R T ~3 ~' CSG 530750 O0 COO TNP~ CBC PU 530759 T~.~R~ CSG 530759 Otj) NPf]~ CS(; PI} 53075q 9. C ~ T CSG CP$ 530759 RCFT CSG CF5 530759 CNTC CS: CPS 530759 or, 0o0 CFTC C5C Cr-~ ~3o75~ Iil-AOG-1992 05:41 O0 0 O0 0 00 O0 0 O0 0 O0 0 00 0 O0 0 O0 0 O0 0 00 0 00 0 O0 0 O0 0 00 0 00 0 00 0 00 0 O0 0 O0 0 00 0 00 0 0 0 0 00 0 0 0 (? 00 O 00 0 O0 0 00 0 00 O0 FI . a ,:~:,.,.. S gE REPR PROCESS I 1 4 68 0000000000 !. 1 4 68 0000000000 ! 1 4 68 0000000000 ! I 4 68 0000000000 1, 1 4 68 0000000000 1 ! 4 68 0000000000 1 1 4 68 0000000000 I. 1 4 68 0000000000 1 I 4 68 0000000000 I 1 4 68 0000000000 ! ! 4 68 0000000000 I 1 4 68 0000000000 !, I 4 60 9000000000 1 t 4 68 0000000000 ! 1 4 68 0000000000 1 I 4 68 0000000000 I I 4 68 0000000000 ! 1 4 6~ 0000000000 1 I 4 68 0000000000 ! 1 4 6R 0000000000 1 1 4 6~ 0000000000 1 1 4 68 0000000000 ! ! 4 68 0000000000 I. !. .4 68 0000000000 ! I 4 68 0000000000 ~. l 4: 68 0000000000 ! 1 4 68 OOO0000000 ! I 4 68 0000000000 1 t 4 68 0000000000 ! I 4 68 0000000000 1 1 4 68 0000000000 l 1 4 6~ 0000000000 1 ! 4 68 0000000000 62 DATA DYP*. 3707.0o0 D[:,"[t I. CSG 32.416 CEV. CSG 1000, Grit:. <:LS. CS(; 0.015 l.,~.CSC ] ! O. 93~ LL. C8(; 48.5O0 SS~,CSG 70,500 t.:F~v,CS6 ! ~52,0{~0 LSRq. CSG 3,963 LiJP~. C. SG 3. 094 t..~:r'~, CSC a0.3~2 ~t C~,: T. C5(:4 12V0,739 CFTC. C5C 37~. 055 ~HOb. CSG 2.!15 DRMO.CSG OS$.CSG -0.096 5$.CSG t~IT~i. CSG 12.406 SS1.CSG S5}tv. CSG 1652.000 SIRH.CSG CAL!.CSG I2.305 GR.CSG ~RgS.CSG -0.04~ HTgN.CSG ThP~oCSG 40.322 TNRA.CSG ~CFT,CSG 330.634 CNTC.CSG -0,948 103,930 47.625 4,9~0 33,000 1559.000 3,564 1328,20t Verification ~c~lu~berger Alaska Computi~.(~ Ce~t:e~ PEr. CS~ ! 6.,453 q!~S.CSG . 063 [,U~ C8 ,~.~ l, Sp~ CSG~ 3,00° NP~-i'),CSC 4() 309 RTt,~k CSG ].,', ",a ' NPOR,C:oG 40,322 RCNT'e~. . CFTC. CSC .37~, 955 DWPT 3500,C00 DP~{I ~'2C ....... ~ ....... ~.,, ~,~ J P Ii': ?, CSG 2 ~. 0 47 O[,S ~ CSG :~ 5 ..., I, 1., C S G ~ q C 7 ~, 125 L,':; N V, C S G ~i ,CGG 2,947 LLI~:H CSG I~.,~S.CSG 3440 o00 aTE.:~::~'CSG NPr)R.CSC 50.694 RCNT.CSG C~'TC, CSG 343,122 D [' P T, 340 ('), 000 D P L~' CSG 146 375 gS9,C$~ 7~, :18~ LS!'~V, CSG i..,SR~ CSt 2 770 !.,~:i.~ csG TE~S'CS(~. 3360~000 ~'~P~.~I CSC 51 , 807 ~T'.~p C,S~ ~ , i ~. ~'~' ~ · .... ~,~ pn~ CSS 4~.842 · ~ '~ ~ .,' , CPTC Co ~ 372 DFPT. 3300.000 DPEI.CSG VFF. CSd 30. 406 QI.,S.CSG I.~!.~. C S C, 151,875 LL.CSG SS2.CS~ 77.0C)0 LS~v,csG LSR~.CSC 2.72~ L~PH.CSG TFr~;S. CS(; 3375. OOO qT~~,4. ~ P!.-! !, CS(; 53.536 ~Tt/R.CSG ~,;P~. CSG ~8,8 37 Pc,..T. CSC CFTC.CSG 220.291 ! I-AtJG-1992 {)5141 32,416 O.015 OS$,CSg 48,500 LITH,CSG laSO.o00 S, H CSq 3.0~:~ CALI.CSG 133.2~6 1.260,739 RCFT, CSG 32,416 Pl!O~. CSG 0.0!5 OSS,CSg 48..500 L!TH,CSG 1847,000 SSHV,CSG 3. 094 CALI, CSG 133,250 ~PES,~SG 3,684 T~iPH, CSG 260,739 RCFT.CSG 0.!l, 8 OSS.CSG 74,563 L!T}i. CSG 1~411,000 SSHV*CSG 2.824 cAI.,,!. CSG !32.750 ;'i ~' E~ CSg 4,133 T~'P.H, CSG 13i5'930 ~CFT.CSG 70.9~.7 0,158 106.625 1.., I TH. CSC~ 842,0t:0 SSFV,CSG 2.605 2 ti5 -olo 6 12.406 1653.o00 1.2,305 -0.042 40.32~ 339,634 2.1!5 -0.096 !650.000 2.305 10,04~ 40.322 339.634 1,953 -0.145 12 523 1650~000 12.305 -0,042 312.740 1.732 -0,131 t5.477 1649,000 12.305 -0'042 50,989 267.948 1.688 -0.124 16.656 1648.000 !2.305 -0.042 58.~56 25o,601 !.479 -0.!64 2!.766 1649.000 !2.328 DRHO.CSG LS.CSG $S!.CSG $1R~.CS~ '~,cs~ sC~ TNRA.CSG C~T¢,CSG t.,sics~ SSl,CSG st~.cSG HTKN.CSG TNRA.CSG CNTC.CSG o CSG SSI..CSG $1PH.CSG GR CSG TN~A.CSG C~TC.CSG DRHO.CSG LS.CSG S81.C86 S!RH,CS6 GR.CSC HTEN.CSG TNRA.CSG CNTC.CSG DRMO.CSG bS.CSG S$1.CSG G~.CSG HTEN.CSG TNRA.CSG C~TC.CSG ORHO.CSG L$.CSG SS1.CSO S1RH,CSG G~.CSG PAGE= 63 . '938 33 000 1555 000 3,564 1 ]28,201 ,938 41 625 98O 0oo 132~ 564 201 -0 995 1!7 45 719 5 0O4 41, 000 1577 000 4,262 1385,467 46 33 4 8~5 22 656 15401000 4.~92 1,332. 4O O42 41,844 .852 30,422 !545,000 4.286 1235,040 o 50 46.281 4.785 33,500 ;C~lU,.berqer ..... ~!aska (lomPutl~.n~ Center DFPT, 2900.000 ~7F', CSG 63.813 OhS.CS(; b !:~. C $ ~ 163,500 L i.,, C S G k~n~.CSG 54,5?0 CFTC.CSG 292. ! F, FPt'. 2700.0 I,I}. t',SC 144 Sa2. CSa 9 ! . 93~; LS~V, CSG ...... 7'E[:,~. CS(; 2935. 000 '~Tf:4. CSG LPDP.CS~ 5~ .77! ~L'NT C..'.,/-. 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RH.CSG TEN CSG C~TC.CSG DRMO.CSG LS.CSG $$!,CSG S1R~,CSG GR.CSG HTEN.CSG TNRA.CSG CMTC.CSG DRMO.CSG bS CSG SS!:CSG GR,CSG HTEM,CSG TNRA.CSG C~TC.CSG DRHO.CSG LS.CSg SS!.CSG $1RH.CSG GR CSG TN~A,CSG CUTC.CSG PAGE: 64 I. 536000 1230,903 ~50 45.969 4875 !524 ~00 1275.. 27 35. 6. °°, 1259'4}5 ~I,047 46, 0 172 1509,000 4,333 1232,638 67 lso 855 15~i984794000 1455.518 '0.966 140.000 33.094 1510,000 140~:406824 ...... " ' ¢: S 6 151,750 [.., I,, (. St, 2,711 Lt~PH,CSG 57.4 ~ I P T ~,! R. C S (; 314 92,1 C' 0 O ~ ? ? 6.25 0 0 0 0 o '259 i 9 ~/ 1 I-AUG-1.992 05~4! 0 9.98 Oe' , ..... ,.:$ CSG "S T' '" 12.,1~8 L ..... rH,CSG 1836,000 SSH.'' V,csGUSG 2,572 C~L!, 12[{,375 ¢4RES, CSG 4,960 126!,838 RCFT.CSG 57,505 0'20~ 84.875 blTH,CSG 1834,C. 00 SBHV.CSG 2 795 CALl. ( Iz..62S 4, ! l ~ T?.~Pb~, CSG 1.315'3~2 RCFT,CSG 0 . 1 ! 0 088 , 84,688 LITH.CSG . , ~ ~" I ~31 , OOO SOHO, ,C 2,72g CALI,CSG 126.938 MF'.ES. CSG 4,437 T~PH, CSG 1285,1.60 RCFT,CSG 63,575 0.126 OSS,CSG 90.93~ LI'Tt.i. CSG !a3C,.000 88Hv',686 2,693 CALl, CSG 1.26,625 ~RES,CSG 4,147 T~PH'. CSG 1276.O76 RCFT,CSG 63.323 RHF..'6, CSG 0.137 085,CSG 96.43R LITH.CSG O(!n SSHV,CSG 126.~75 ~RFS.CSG 5,42n TNPH,CS~ 1227.276 RCFT,CSG 6H.746 RHOB.CSG 0.1 3] 08S,C$~ 9R,43~ LJTH.CSG !~32,(~0o SSHV.CSG 1.315 0 155 1647 . 000 1.2.3O5 -0 042 7~ 079 227 770 I , 70.1 ~0 152 1643.o00 12.461 ~0. 043 7,2~ 249.4~5 1.623 -.0 !. 65 1.64~o000 12.461 -0.043 52 524 294~62 1 601 -0: 149 17,7~1 1640.000 !2.461 -0.043 49.619 299.655 !.605 -0.144 20.203 1638.000 12.430 -0,043 56.124 276.90~ !.5'16 ~0.1~5 9.766 1640.000 DR HO. L$.CSG ,. St C86 $1RH.CSG GR.CSG HTEN,CSG TNRA.CSG CNTC.CSG DRHO CSd t,S CSG 881CSG StRH,CSG GR;CSG HTEN.CSG TNR~.CSG CNTC.CSG DRHO,CSG LS.CS6 S1RH.CSG GR,CSG MTE~.CSG TMRg.CSG CMTC.CSG DRHO.CS6 LS.CSG SS!.CSG S1RH,CSG GR.CSG HTEN.CSG TNPA.CSG CMTC,CSG DRHO,CSG L8,C86 8SI.CSG 81RH.CSG GR.CSG HTEN.CS6 T~RA.CSG CMTC,CSG DRHO.CSG L$.CSG SSI,CSG S!RH.CSG PAGE: 65 227 000 43 2!9 4 879 02 000 5 139 1259 059 '1:,010 160'750 47;750 4,809 34,063 14931000 4'506 1378;907 -! 059 167 125 45 531 4 803 31 625 1491 000 4 240 1338 105 77,125 147,219 4,793 26,953 1493,000 4,229 !342o559 -1,010 185,750 49.219 4.703 30"094 !5!2,000 4.736 1275,205 000 5 125 4,855 P F p T t 7 ( } {,. 6 o 0 P P I-,! !. r' S G ¢~:t:csc, "sa. ?s,:) ,">[:s.(:!SC; I.,!!. CS(: ] 81. 625 b!.,, CSG $82.C5(; 84.939 LSHV.CSG !.,gPu, Cj5S 2.504 LI~H.CSG TF[:S.CSG 264o.0n(} NP~T, CSG 55,64 {~ R'r~'.~R. CSG ~:P[:*~. C~C 63.090 ~CPT.CS(; CFTC. CS(; 292,365 !.!-~UG-1992 05:41 55,597 0,124 055. CSG 8 ?. 625 183! .000 8SHv,CSG 2,76~ CALI. 126 063 ~<~ CSG 4. 75 Tt~:PH. G :t260..39 RCFT,CSG 90.625 LITH.CSG I~28,oon 8SHV.CSG 2,727 CALl,CSG. 125,563 ~gR ES,C,.~."S c; 4.029 T[{PH.CSG 1227,~76 RCFT,CSG 78. 937 0.232 1.827,000 88HV.CSG 2.553 c.~uz.csc 125.51)3 gRES.CSG 5.280 T ?4 P H. C 8 G 1203.a. 38 RCFT,CsG... 65.72a RH[]B,CSG 0.161 QSS.CSG 100.06::t [,ITH.CSG !826.000 SSHV.CSG 2. 654 CALl. CS(; !25.3!3 ~RES.CSG 4. 667 T~PH. usg 11~7.9!7 RCFT'CSG 66.767 PHP:!3. CSG 0.136 OSS,CSG 98.~75 L!TH.CSG ! .8,26,000 SSHV.CSG 2.645 CALI.CSG 1.25.J~s8 aPE:S.CSG 4.452 T?~OH, CSG !197'053 ~CFT. C,5G 1.733 R b..~HO.CSG -0.146 !,7.094 SSloCSG 1639.000 $1RH.CSG 12'~30 GR,CSG -0, 43 HTEN,CSG 2~0 93 I 609 [:)RHO CSg -o:183 17 71~ ssi cs~ 1637:000 $iRH:CSG 2 461 G~.CSG ~v.asl c.~,c.csc 1.348 DRHO,CSG -0.t67 LS.CSG 1636:000 ~2 461 GR.CSG o~o~ ~Tr~.CS~ 7t723 240~554 CNTC.CSG 1 s6s D.,o cst -o:i. 5] ~slcsc 20.078 ssl.cs~ !~]s.ooo sl~H.CSC 2 461 GR.CSG 102044 240.554 1 548 -02197 LS.CSG 21 2{9 $8!.C$C 12.461 GR.CSG -0.044 HTEN,CSG 47.431 3j8..77 c~c.cs~ PAGE: 66 30 594 tsoa:ooo 4,313 !352.284' 1~0'977 1'250 49.531 4742 34 2!9 1492000 4457 136182! 45.688 4;863 ']3,375 I505'000 4.414 1.329,174 21 ,875 4.281 4,832 279]8 1'498i0004891 1242,512 -1030 190~875 48 8 30 32'844 1493,000 4 405 1274177g =1.050 I90.875 45 969 41820 34 469 1494 000 4.150 !306.758 S q'aoe VerlficatJoc, b.l. Umber~!er .ata$~a~ Co~putJnq Cer~<~,!~ PAGE; 67 LU .C8(~ 128. 375 [. h. CSG D~PT. 149~. 00fi DPH I. CSG LU. CoG I 71. a75 1.,!.,. CoG SSP. CS(; ~5.5(>o I,S~V .C . CVTf.CSfi 315. .... ( .... (; I 94'I 0.(>91 085.C8G -0.144 ¢~2 9'~a hlT~ cst · · , . ..... ~ 14 078 la22.000 ss v.cs 163 125'()6:3 ""P~ CSG -0 044 4.5~ 3 TNDH, CSt; 47; ~37 t360.95~ P(.. :. '~.CoG 330.668 ~:yl.656 RHOB.C~ ' . .... ~.. ~ (., ! 633 0'!00 '.~;, .. i i71 OS .... CS(; 0 B2 8B,750 PI'TH,CS(; 8 . 66 1822 000 ;guv CSG 1632.000 2.695 CALT,CSG 12.461 125'063 ~RES,CSG -0,044 4.967 TNPkl. (IS(; 53,685 1227 i00 RC q., . ..F ' CSG 294. 162 bS.CSG SS!.CSG SI. RH,CSG HTEN.CSG TN~A,CSG c~TC,CSG DRH~.CSG SS!,CSg SIRH CSG HTEN.CSG TNRA.CSG CNTC.CSG =0 947 127 125 48 688 · 4 859 31:078 1509 000 4 256 1489 583 '!,023 174.625 46.969 4,809 30,~31 t481, O0 4:.284 {342'945 POINT ~ 50, %0-733-20/!34 r,r)I~,;? ~50,50-733-20434 2P-'dUL-]..997 71 :.~? L.r. Ehn'].r,~-,: ti,ri, ~3-11 23&:0'~; & ~. 377'F ;cb.l~.~berr;~er Al~ske C;om~:.',utinO Center 22-JL~L-.!. 992 2t:27 C~G!~C 3: G C P C 710 4 6 13 GC.~C 7 :~, 3 TCC 161 GP~N] Tt PUIteT CN A~-' ITE POINT b ~ A 12%- CF~FD ~3-11 23~6'S & 1372'F7 422827 Field h~ame Well Name Nation State or Province County Section Township Range ~1eld Location Service O~de~ Number 21. :,~7 G :'.,)~'i P CFro VPF, P True vertical Pepth as channel <TVTCPI> D F V '! f: ~ o ! e [', e v ~ a t J. o r~ ~SD~ :orth South f'~r'iit PAGE: [$ !ra~,e ~/er~f. icatior':, .!..is'r. ing 2hlU~-err::~'er ~,]..aska ComF:,~tir~r] Centc..r 22-jL~b,.,lgg2 21:27 PAGE: (>. ()00 VDF?. GCT 0.000 E ¥~ D .R. G C'r 1479.699 -753.49~ EWPR.GCT O.OOO DE¥I.GCT 0.000 C;~EL.GCT 1479.403 DEVI.GCT -26.221 C%fEL.GCT 7 .~3 ..... V t 91.20... 2! i~F.GCT -!408.3 75 150 DEVT.GCT .516 CWEL.GCT 0.000 0.000 1~,923 ,154 ~0,671 0,000