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192-020
STATE OF ALASKA a AL.A OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS .,A;c,i—A- 3D+ 1.Operations Abandon❑ Repair Well❑ Plug Perforations ❑ Perforate❑ Other L] Complete Performed: Alter Casing❑ Pull Tubing 0 • Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development El Exploratory❑ 192-020 ' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-733-20014-02 • 7.Property Designation(Lease Number): et4-NNm^�e and Number: ADL0018761 Granite.Rt St 32-13RD ,(• a .v_ ;,,, ° 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Middle Kenai Oil ` ••,' 11.Present Well Condition Summary: Total Depth measured 12,563 feet Plugs measured N/A feet true vertical 10,646 feet Junk measured 11,022(fill) feet Effective Depth measured 12,473 feet Packer measured 10,450 feet true vertical 10,606 feet true vertical 9,775 feet Casing Length Size MD ND Burst Collapse Structural Conductor 668' 18-5/8" 668' 668' Surface 2,506' 13-3/8" 2,506' 2,485' 2,730 psi 1,130 psi Intermediate Production 8,417' 9-5/8" 8,417' 8,226' 6,330 psi 3,810 psi Liner 2,636' 7" 10,824' 9,964' 8,160 psi 7,020 psi Liner 2,061' 5" 12,561' 10,646' 8,290 psi 7,250 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 10,512'(MD) 9,807'(ND) 10,450'(MD) Packers and SSSV(type,measured and true vertical depth) DHL Ret.Pkr 9,775'(ND) SSSV:N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 48 70 41 586 62 Subsequent to operation: 51 16 103 586 62 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development O` Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil O ' 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: ,3/3-01/el Contact Dan Taylor Email dtaylor(abilcorp.com Printed Name Dan Taylor Title Operations Engineer Signature Phone (907)777-8319 Date 9/20/2013 z II Form 10-404 Revised 10/2012 r t• 3 RBDMS OCT 1 1 2 `.'.,.mit Original Only • • Granite Point Platform Well GP 32-13RD SCHEMATIC Completion Date: 08/20/2013 Hilcor„Alaska,LLC PTD: 192-020 API: 50-733-20014-02 CASING DETAIL RKB=110' J Size WT/Grade CONN Top Bottom 1 I 18 5/8" 70.7/B 0 668' L 13 3/8 54.5/1-55 BTC 0 2,506' 18-5/8" 9-5/8" 43.5/47 BTC 0 8,025' N80/595 BTC 8,025' 8,417' 7" 29/N-80 BTC 8,188' 10,824' 5„ 15/L-80 BTC 10,500 12,521' 18/L-80 BTC 12,521' 12,561' TUBING DETAIL 0 2-7/8" I 6.5#/L-80 I 8rd EUE I 0 I 10,512' G � 13-3/8" JEWELRY DETAIL No Item Depth swim . 1 FMC Tubing Hanger 44.50' TOL 7" GLM#10 2,405' @ 8,188' N GLM/ #9 4,108' GLM#8 5,433' 2 GLM#7 6,423' 11 GLM#6 7,190' 9-5/8" 2 GLM#5 7,817' GLM#4 8,315' GLM#3 8,876' GLM#2 9,436' GLM#1 10,195' 3 Sliding Sleeve 10,406' 4 DLH Retrievable Packer 10,450' 5 "X"Profile Nipple 10,501' fa 6 Muleshoe 10,512' 3 4 TOL5" 5 PERFORATION DATA @ 10,500' Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Date Comments L 10,600' 10,680' 9,853' 9,893' 4 10/31/1996 WLP 7 6 10,680' 10,810' 9,893' 9,957' 4 4/1/1995 WLP 1 10,810' 10,850' 9,957' 9,976' 4 10/31/1996 WLP C-5 10,850' 11,020' 9,976' 10,046' 4 4/1/1995 WLP 11,120' 11,235' 10,086' 10,131' 4 5/18/1992 TCP - 11,322' 11,524' 10,162' 10,234' 4 5/18/1992 TCP - 11,611' 11,914' 10,264' 10,373' 4 5/18/1992 TCP 11,986' 12,148' 10,401' 10,467' 4 5/18/1992 TCP TOF 11,002' C-5 v ETD=12,473' TD=12,563' 5" MAX HOLE ANGLE=69°@ 11,453' Updated by JLL 09/13/13 • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 32-13RD 50-733-20014-02 192-020 7/18/13 8/21/13 Daily Operations: 7/18/2013-Thursday Install BPV. N/D tree. N/U BOPs, install accumulator lines, cut flow nipple t/fit& install. Install choke & kill lines. R/U gas buster lines. Install drip pan &false rotary beam. Installed alarm horns. 7/19/2013- Friday Continued to NU Bop's and Test equipment.Attempted to pre-test Accumulator, Bop's and Manifolds. Asked AOGCC Rep to come on Saturday to perform test and inspection. 7/20/2013 -Saturday Installed flow line to pits. Continued to tighten Flanges on Bop's and perform Pre-test. Called AOGCC Rep and set up Rig_ Inspection and Bop test. M/U 3-1/2" test joint and landing nipple.Jeff Turkington from AOGCC performed Rig inspection of Moncla 301. Installed 2-7/8"Test joint, loaded hole and equipment with filtered inlet water.Tested Bop's,Tested Annular to 250 low and 2500 High,Tested Bop's and Equipment to 250 low and 5000 High,tested and charted all test for 10 mins. 7/21/2013-Sunday MIRU E-Line Unit. M/U 1.8 Blind Box/CCL. RIH. Sat down at 4,057', could not get down. P/U on tbg. Released tbg hanger and pulled up to 14,000. RIH W/ Blind Box down to 4,376',tools stopped and were sticky. P/U to 18,000 and tools came free. Ran down to 4,678' and got stuck again. P/U to 25,000 and ran down to 5,746', continued to pick up in increments of 4-6 thousand, moving down hole to 8,076'. Last up weight at 8,076' was 52,000. Set slips and POOH with Blind box. M/U 1-11/16" Radial Torch cutter/CCL. RIH, located a collar between the 13th and 14th gas lift mandrel. P/U to put cutter at 8,003'.Attempted to cut Tbg. POOH with ccl/cutter assembly. Attempted to pick up on tubing.Tbg would not come free, continued to P/U and stack out on tbg to try and break cut free, no success. P/U on tbg to 80,000. RIH W/1- 11/16" Radial Torch Cutter, got down to 9,936' ELM. P/U and located collar @ 9,917', made 2nd cut @ 9,884', showed no signs of movement when cut. POOH W/CCL/cutter assembly. P/U on tbg, showed no signs of being free. Worked tbg up and down multiple times, stacked out several times and P/U to 105 thousand on tbg several times, no signs of movement. Last attempt was coming up,got to 100 thousand and tbg parted, still had 13,000 on weight indicator. When pipe parted, drill line jumped a Shiv. Shut down to come up with a plan to get drill line back in shiv and strip. Stripped DL and started TOOH, laying down 2-7/8" IB thread. Laid down total 33 joints of production tbg, 1001 ft total. Grapple of patch come apart. M/U 5-3/4" overshot loaded with 3.3 grapple. P/U Overshot, bumper jar, accelerator jar on 3-1/2" PH- 6 WS. P/U 16 joints of 3-1/2" PH-6 WS. • • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 32-13RD 50-733-20014-02 192-020 7/18/13 8/21/13 7/22/2013- Monday M/U 5" overshot, bumper jar, and accelerator jar on 3-1/2" PH-6 WS.TIH/W 34 joints,tagged top of fish @ 1,041 ft, rotated tbg to right and engaged grapple on fish. P/U to 80,000 and tbg started coming up hole, dragging from 80k-90k. Laid down 2 singles. Installed pump in sub and TIW valve. R/U rig pump to circulate to pits, pumped 370 Bbls of diesel down annulus, never got back any returns. R/D TIW and pump in sub. Stood out of hole with 16 stands of 3-1/2" PH-6 t;sv` WS, laid down jars, overshot, and fish (Logan Patch). Installed TIW valve and pump to circulate.Started to pump fluid r4fj.)/ down the annulus and received a gas bubble to gas buster. Shut in well. Monitor well. Opened well on 8/64 choke to gas buster,well appeared to be dead. Started pumping diesel down the annulus out the tubing, pumped 12 bbls and got circulation to the pits, continued to circulate gas bubbles and oil/PSW out. Circulated well. Monitored well. 7/23/2013-Tuesday Monitored well, shot fluids levels on backside. Fluid level appeared to be around 300 ft. Casing on vac made difficult to shoot fluid level. Rig crew worked on rig pump, cleaned and prepped to pull out laying down. Made decision to start pulling 2-7/8" IBT Production tbg.TOH laying down. Laid down a total of 75 joints and 4 gas lift mandrels,tallied and loaded tbg onto floating pipe rack. Hooked up production diesel line to annulus, pumped 24 Bbls down and got returns out tubing. Casing and tubing both full, had to wait for fluid level to fall in tbg to start pulling again. Removed tbg board extension to make longer. Continued TOH laying down 2-7/8" IBT Production tbg, laid down total of 239 joints and 12 gas lift mandrels, approx 7,540 ft, no drag coming out. 7/24/2013 -Wednesday Cont. POOH laying down 2 7/8 IBTproduction tbg. At jt 260 had scale build on outside of tubing from joint 260 down to joint 314. Recovered 314 jts and a 13.96 ft cut. TOF @ 9846' off pipe tally. R/U wireline. P/U 4.5 LIB& 5.5 cent. RIH t/712', stacked out, POOH. Investigate LIB no show. R/U 5.88 gauge ring RIH t/8192' sat down, wk 30 min gain 10' pulling 500-600 overpull to free. POOH. R/D wireline. Prep BHA to P/U. 7/25/2013 -Thursday Set wear bushing. P/U BHA,TIH w/5.75 overshot, 4.75 bumper sub,jar, xo,44.5'. P/U 3 1/2" PH6 wk string, 264 jts, t/8245' up wt 112 , dn wt 100. Tag at 8245'.Set down 20k, wk string, unable to go deeper. POOH to 7248'. 7/26/2013- Friday TIH t/8188' looking for liner top tag @ 8245', wk down t/8247' and POOH up wt 114, dn wt 100. L/D BHA found marking on cut lip guide &scale inside overshot. R/U lines t/production. Prep BHA. P/U BHA, burn shoe, 3 jts wp, 3-4.75 dc, bumper sub,jars,xo,TIH on 3 1/2 wk string t/6250'. 7/27/2013-Saturday Cont TIH slow t/8183'. R/U circulating lines to production, R/U FIW line to pits. Fill pits w/ FIW& mix 6% KCL. Pump 6% kcl down tubing&take diesel returns t/production @ 2.5 BPM ICP 0, FCP 200psi, pump 630 bbls total. Shut down pumping, monitor well.Top off pits. R/U hyd lines in derrick& kelly hose. P/U & R/U power swivel. Break circ. wk issues with pump& pits. S • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 32-13RD 50-733-20014-02 192-020 7/18/13 8/21/13 7/28/2013-Sunday CBU getting back up to 3500 units gas.Cont. circ till units drop, shut down & monitor f/15 min, no flow. Start POOH, string coming wet. Mix& pump 10 bbl dry job. Cont POOH w/dry pipe t/BHA. Stand back& L/D BHA. R/U & pull wear bushing. M/U 3 1/2" test joint. Fill stack, choke manifold, &standpipe manifold w/water.Test BOP's as per Hilcorp & AOGCC regulations. Witness waived by Jim Regg @ 16:00 on 7-26-13. Test annular 200/2500 psi good, test all other components 200/3000 psi hold each f/5 min all good. Pull test jt&set wear bushing. Break down test jt. Prep& P/U BHA. 7/29/2013- Monday TIH t/w/5.75 shoe, 3 jts wp, bumper&jars, 3-4.75 collars, 8245', up wt 120, dn 96. P/U swivel, wash dn t/8339', getting gas units up t/5000, rot wt 107. Cont. wash dn t/8742' up wt 132, dn wt 100, rt wt 118, rot 60-70 rpm,tq off 3200, stalling while working down @ 6000 wob 15-20, circ B/u w/gas units 5000, scale returns 3/4" chunks&fines. 7/30/2013 -Tuesday Cont. clean out f/8742't/9959', up wt 140, dn wt 107 rot wt 120, circ @ 3 bpm rev 450 psi. At 9959' tubing packed off. Pressure up t/800psi, P/U t/9918' rocked circulation to free plug. Cont. w/d t/ 10026'.Tag top bushing @ 9928'w/20k, w/pressure increase verify, CBU x3+clean returns fine scale & up to 1" pieces, circulate till clean. R/D swivel. POOH t/ 8432'. 7/31/2013-Wednesday Continue POOH f/8432'. Stand back BHA. R/D Williams Pump. R/U Moncla pump &test run. L/D Wash pipe. P/U overshot, bumper sub,jars 3-collars and RIH t/9916', up wt 134, dn 110, CBU @ 2.8 bpm, 270 psi, 0 fluid loss, max gas units 62. Pump 1 BPM slide over fish @ 9926'. Pressure increase f/25-90 verify, wk pipe up to 30 over, wt fell off, set down taking wt. lower, pump down tubing w/no pressure. R/D circ line & POOH t/5856'. 08/01/13/2013-Thursday Continue POOH f/5856'. Break down BHA. No fish,grapple full of scale and markings, packoff gone. Re-dress overshot w/2-7/8" grapple, overshot w/3' ext, bumper sub,jars, 3-4.75" collars, xo, and RIH t/9918'. Up wt 134, dn wt 110, CBU long, @ 4.5 BPM, 525 psi. R/D circ line. P/U single RIH t/9928'tag TOF, work overshot over fish & set, work pipe up t/45k over,working up slow in wt increases,jar @ 30k over working pipe. R/U power swivel, attempt to release K anchor latch rotating to right no go,grapple came free while trying to wk tq down for back-off, wk overshot till able to get bite w/grapple. R/D swivel. R/U wireline. RIH w/ 1.75" bailer t/9905 wlm, hard restriction, come out w/ 1" sample of scale. L/D wireline & release grapple. 08/02/2013- Friday Continue POOH & LID BHA. P/U BHA, HE external tubing cutter, 3 jts washpipe, bushing, xo and RIH t/9840'. P/U power swivel, up wt 136 dn wt 108, rot wt 120. P/U singles RIH t/9985' P/U t/9969' pipe measurement with 4K wt increase, rotate cutter, wt fell t/ 120k indicating cut. L/D swivel &singles not in string. • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 32-13RD 50-733-20014-02 192-020 7/18/13 8/21/13 08/03/2013 -Saturday Continue POOH w/OS cutter. L/D BHA recover 82.9' fish & 1 sssv hold open tube. New TOF is 9968' pipe measurement. P/U BHA, rotary shoe, 3 jts 5.75 wp,xo,4 jts 5.5. wp, (228' wp total)top bushing, bumper jars, oil jars, 4-4.75 drill collars, xo376.89'total. RIH t/9940' up wt 140, dn wt 115. P/U swivel, CBU @ 3bpm, 420 psi. Wash down t/10196' tag bushing. CBU @ 3bpm,430 psi. L/D swivel. POOH t/2233'. 08/04/2013-Sunday Continue POOH f/2233', rack back BHA. P/U M/U BHA. RIH 5 stands t/309'. Slip & cut drill line, 100'. RIH t/9968', slide over fish t/ 10195', up wt 135, dn wt 100. P/U swivel, POOH t/10189' & catch collar pull 4k over, rotate to make cut,4k over pull fell off. POOH 2 jts& L/D seeing no collars for indication possible cut was made. L/D swivel,fluid column still full, no wt gain notable. POOH f/10133' t/surface. Break down BHA. No fish. Breakdown cutting tool, full of scale & found cutting sleeve did not slide & broke flipper dogs. R/U t/pull wear bushing. 08/05/2013 - Monday Pull wear bushing. Build test jt. Install test plug, fill stack, choke manifold & surface lines w/water.Test BOP's w/3 1/2 test jt as per Hiilcorp &AOGCC regulations, witness waived by Jim Regg @ 10:21on 8-5-13.Test annular 250/2500 psi good, test all other componets 250/3000 psi hold each f/5 min. Had one failure on body of kill HCR, replaced valve & retest good. Had failure on gas detection system replaced chip in H2S sensor, retest good. Pull test plug, install wear bushing, breakdown test jt. P/U BHA,top bushing, 6 jts 5.75 washpipe, 3 jts 5.75" washpipe, HE external tubing cutter, wavey bottom shoe. RIH t/9969', up wt 135, dn wt 105. P/U swivel, work down t/10237' @ 3bpm, 440psi. CBU x 2, @ 3 bpm, 440 psi, w/scale returns, circ till clean. Stroke pipe up t/locate collar, no signs, retry finding collar @ 10214'. P/U 4k op rotate pipe,tq spiked &fell off, stroke pipe unable to find overpull, pull 2 jts w/no sign of collar locate. 08/06/2013 -Tuesday POOH w/workstring. L/D 1 jt. of 4.5" wash pipe, fish inside wash pipe. POOH L/D 249' of 2.875" fish. POOH w/fishing BHA and cutter new TOF is @ 10,218'. Makeup 5 3/4" wash over shoe RIH w/wash pipe jars D.C.'S and workstring. RIH t/10190' up wt 138, dn 100. P/U swivel. Fluid loss today: PVT 6% KCL, 8-6-13, active 126, 8-7-13 active 120 slop tank 5.5 fluid loss to hole 0. 08/07/2013 -Wednesday Break circ, wash down to Gas lift mandrel @ 10,398 '. Circ well clean. R/D power swivel. POOH w/workstring and BHA. M/U and TIH w/cutter BHA and workstring to 10,179'. Stroke tbg. and get string wts. 142K up 100K down. R/U power swivel. Break circulation start pumping 3BPM @ 330psi. @10,272' start washing down cutter to cut off point at 10,375'+/- 08/08/13/2013-Thursday CBU clean. Unable to locate collar for cut @ 10,374'. Locate & attempt to make cut @ 10,343'. Pull singles watching for collars if not cut. R/D power swivel. POOH w/15 stands. POOH w/workstring L/D wash pipe BHA. No fish inside wash pipe. M/U and TIH w/over shot loaded with 2.875" left hand release grapple Jars Drill collars and work string. • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 32-13RD 50-733-20014-02 192-020 7/18/13 8/21/13 08/09/2013 - Friday Continue TIH w/overshot to 10,184'. R/U power swivel. Circ bottoms up. TIH to 10,218' latch onto fish jar w/25K over to insure good latch start jarring and rotating to the right working torque down attempting to release latch from packer. Broke free, string wt.gained 2-4K. R/D power swivel. POOH wet w/workstring and fishing BHA. 08/10/2013 -Saturday Break down BHA, remove grapple from fish. POOH & L/D 2 7/8" fish. 241'total w/1-GLM, sliding sleeve, anchor latch & seal assembly. Clean & clear floor. Prep BHA. Service rig. P/U BHA 7" scraper assembly, 6" bit, 7"scraper, bit sub,xo, 2297' 3-1/2 ph6 tubulars,TIH t/2,360'. P/U 9 5/8" scraper assembly, xo,xo, 9 5/8 scraper, bit sub,TIH to 5,347'. Slip 130' of drill line. Continue TIH to 10,326' with scrapers 142K up wt. 100K down wt. R/U power swivel. Circ hole clean from 10,326' to 10,419' (3BPM @ 450psi). 08/11/2013-Sunday Continue circulating down f/10,419'to Packer @ 10,452' w/bit and scrapers. Pump 3BPM 450psi. Empty out dirty water from rig pit and tanks, refill tanks with clean 6% KCL. Circulate hole clean with 6% KCL pump a total of 700 BBLS. R/D power swivel. POOH w/scrapers and bit. Pull wear bushing, build test jt, install test plug,fill stack, choke manifold & surface lines w/water.Test BOP's w/3 1/2 test jt as per Hilcorp&AOGCC regulations.Witness waived by Jim Regg @ 20:04 on 8-11-13. Test annular 250/2500 psi good. 08/12/2013 - Monday Test BOP's w/3 1/2 test jt as per Hilcorp&AOGCC regulations. Witness waived by Jim Regg @ 20:04 on 8-11-13.Test annular 250/2500 psi good,test 3.5'variable rams no test found choke valve 11 leaking. Work valve, retest good, 250/3000psi.Test all other components 250/3000 psi hold each f/5 min. Remove 3.5" test jt replace w/2.875" test jt. Test annular 250/2500 psi good,test 2.875" rams 250/3000 test good. Pull test plug, install wear bushing, breakdown test jt. M/U shoe and motor BHA,4 3/4" shoe,x/o 5 3/4" x 3.5, Mud motor,x/o,4-Boot baskets w/5' skirts,x/o bit sub, bumper jars, oil jars,4-3.5" drill collars, 3.5" in line magnet, x/o to 3.5" PH-6 tbg. RIH 2-jts. load and test motor. RIH w/ 67jts. x/o 3.5" in line magnet,x/o continue TIH w/3.5" PH-6 workstring loading tbg and testing motor every 2000',to 8,137'. Check string wt. 118K up 90K down, establish pump rate 3BPM @ 390psi. Continue TIH to 10,431' before rigging up power swivel. String wt. 146K up, 100K down. R/U power swivel, check string wt 150K up 106K down, check wt.while rotating 130K up 112K down.Torque 3400 ft Ibs, pumping 4.5BPM @ 830psi. P/U 1-jt. on power swivel,jt#331, tag packer start milling on production packer. Pump rate of 4.5BPM @1100psi 08/13/2013 -Tuesday Continue milling out packer w/motor/mill cut slips, rubber returns t/surface. Unable to make more footage. Circulated out gas units up t/5000. Hole still full. L/D 1jt. with swivel. R/D power swivel. POOH wet with workstring and motor, found shoe was 100%worn. Boot baskets were full of metal from packer and magnets had fine metal shavings on them. Recover 2.5 gal from baskets& magnets. M/U new shoe and motor BHA# 13, 204.24',4 3/4" shoe, x/o 5 3/4"x3.5, mud motor x/o, 4-Boot baskets w/5' skirts,x/o bit sub, bumper jars, oil jars,4-3.5" drill collars, 3.5" in line magnet,x/o to 3.5" PH-6 tbg.TIH 2-jts. Load and test motor. RIH w/67jts. x/o 3.5" in line magnet,x/o continue TIH w/3.5" PH-6 workstring loading tbg and testing motor every 2000',TOF @ 10,452'. • S Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 32-13RD 50-733-20014-02 192-020 7/18/13 8/21/13 08/14/2013-Wednesday Continue TIH w/3.5" PH-6 workstring loading tbg and testing Motor every 2,000',to 8,137'.Check string wt. 118K up 90K down, establish pump rate 4BPM @ 490psi. R/U power swivel. P/U 1jt. break circulation. Start cutting over packer w/motor/mill,cut about 4"then unable to make more footage,no movement w/packer downhole. Pump dry job. R/D power swivel. POOH with workstring and motor. Break down BHA. Boot baskets were full of scale&metal from packer and magnets had fine metal shavings on them. Recover 2 gal from baskets&magnets. M/U BHA#14,5 7/8"short catch overshot loaded w/4.75"grapple, bumper jars,oil jars 4- 4.75""drill collars,x/o to 3.5" PH-6 workstring. BHA total length 180.87'.TIH w/workstring to top of fish @ 10,452'. No fluid loss. 08/15/2013-Thursday Continue TIH W/Overshot on 3 1/2 PH-6 WS.TIH with BHA/166 stands and a single,tagged TOF @ 10,456'.Stacked out on fish, engaged grapple on fish and attempted to pull packer. Picked up to 160K, no movement,jarred on packer for 1 hr from 160K up to 180K,started getting a little movement(3-5")at a time,packer stopped after about 2 ft,continued jarring from 180K-200K, packer began moving up hole again, packer broke free and come up hole 10 ft and stopped again. Repeated process of jarring from 180K- 200K until broke free again. Laid down a single and power swivel. Continued SOH W/3 1/2 WS and fish. SOOH W/166 stands of WS, SB BHA, laid down overshot with packer, laid down total of 3 jts of 2 7/8 IBT Production tbg. Total Length of fish (106'). Loaded hole while standing out. Pumped total of 50 Bbls to keep hole full. MU 7" RTTS test packer. Started TIH on 3 1/2 PH-6 WS.TIH W/44 stands and RTTS. 08/16/2013-Friday TIH W/7" RTTS packer.TIH W/168 stands and 3 singles,set packer @ 10,429 ft,tested casing to 1500 psi,charted for 30 mins. Casing tested good. Bled pressure off well. Released packer and started SOOH W/3 1/2 WS,SO with total of 169 stands and a single of 3 1/2 PH-6 WS. Laid down 7" RTTS test packer. MIRU Slickline Unit. RIH W/3" Magnet,Tagged bottom @10,449 wlm. POOH. Recovered half cup of metal shavings and debris. MU 3" Pump Bailer. RIH tagged fill at 10,462'wlm. Worked bailer several times and POOH. Recovered approx. a gallon of sand/scale/mud debris. RBIH with 3" pump bailer,tagged same,worked bailer several times and POOH. Recovered same amount of fill. RD SLU, moved unit back to center bay. Moved and tallied 2 7/8 PH-6 WS to pipe racks. MU Mule shoe on bottom of 2 7/8 PH-6 and started TIH.TIH W/60 jts of 2 7/8 PH-6. MU X-Over to 3 1/2 PH-6 and continued TIH with 3 1/2 WS. 08/17/2013-Saturday TIH W/Mule shoe on PH-6 WS,Tagged Fill @ 10,462'. MU Power Swivel. Continued PU singles, washed down to 10,985',tagged hard bottom. Recoverd rubber, metal shavings,sand, and silt. Made 120 Bbls of 6 percent,circulated last 5 joints at rate of 4 Bbls/min getting 3 Bbls of returns.Started out, laid down 11 singles which had been picked up during cleanout. Continued SOH 3 1/2 PH-6 WS. SOOH W/111 stands of 3 1/2 PH-6 WS. Laid down X-over. • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 32-13RD 50-733-20014-02 192-020 7/18/13 8/21/13 08/18/2013-Sunday MIRU Slickline Unit. RIH W/3 1/2" LIB tagged bottom @ 10,900 wlm. POOH. MU 2 1/2"Sample Bailer. RBIH,tagged same depth. Worked tool a few times POOH, recovered sample of sand/silt. RBIH W/4.5 LIB,tagged fluid at 4,537 ft. POOH. RDMO. MU 2 3/8 bull dog bailer with 10 stands between flapper valves.Started in hole on 2 7/8 PH-6. TIH WI 294 total joints,tagged fill at 10,965'. Worked bailer several strokes and broke through a bridge. PU 1 single and tagged solid at 11,002'. Attempted to bail from 11,002',could not make any hole,attempted to turn on mule shoe with tongs,still no progress. SOOH W/3 1/2 PH-6, laid down X-over and 2 7/8 PH-6 WS with bull-dog bailer. Recovered 13'of fill in bailer. Made ready to start in Hole with production tbg and packer. MU Wire-line Re- entry Guide,X-Nipple w/RHCP plug, Packer,sub,slidding sleeve, 1 jt of 2 7/8 8Rd and first GL mandrel. 08/19/2013-Monday TIH W/2 7/8 Wireline Re-entry guide,6 ft pup,x-nipple w/RHCP plug,4 ft pup, 1 jt of 2 7/8 8RD,4 ft pup,7" hydraulic packer,4 ft pup, sliding Sleeve, I jt of 2 7/8 8 Rd tbg and first GL Mandrel,continued in hole with GL valves and 2 7/8 8RD 6.4 L-80 Production tbg,total of 317 jts. MU Tbg hanger on last joint, landed tbg hanger, ran lock pins in on hanger,dropped RHCP plug Bar, loaded tbg with 6%and pressured up on tbg to 1500 psi,set packer. Pressured up to 1500 psi,tested and charted packer,test good. Bled pressure of backside and started rigging up Slick-line.Total load to recover-675 Bbls of 6%. 08/20/2013-Tuesday MIRU slick-line. RIH and set catcher sub @ 10,405'. POOH. RBIH W/Kick over tool, ran down and located valve 1(bottom Valve) @ 10,195'. Latched and POOH. RBIH W/KO Tool,sat down @ 5,433',valve#8, latched and attempted to POOH. Parted Wire @ 2,400', tool fell to catcher sub. POOH w/wire. RBIH W/2"JDC,tagged and latched fish. POOH. Recovered tool string and dummy valve(8). RBIH W/KO Tool down to 8,878', located valve 3, latched and POOH. RBIH W/KO tool down to 9,453', located and POOH valve 2. RBIH W/KO Tool down to 8,331',located and POOH valve 4. RBIH W/KO Tool down 7,816', located and POOH valve 5. RBIH W/KO Tool, attempted to pull valve 6 several times,could not locate valve. RBIH and pulled catcher sub. POOH. RBIH W/2"JDC latched prong and POOH, left RHCP plug body for catcher sub. RBIH W/KO tool down to 7,189', located and POOH valve 6. RBIH W/KO Tool down to 6,443', located and POOH valve 7. RBIH W/KO Tool, located and POOH valve 9. RBIH W/KO Tool, located and POOH valve 10. RBIH setting valves from top to bottom,set valves 10,9,8,7,6. 08/21/2013-Wednesday RIH setting live GL mandrels 7,8,9, 10. RIH W/2"GS,attempted to latch and pull RHCP plug body,could not get GS to grab. POOH. RBIH W/2" LIB,tagged top of RHCP Plug body and POOH. LIB showed signs of valve looking up hole. RBIH W/pulling tool,sat down @ 10,197(valve 10). POOH. Recovered valve 10. RBIH W/Pulling tool,sat down on fish and POOH. Recovered GL valve#6. Replaced 0- rings on valve 6 RBIH and set at 7186'. POOH. RBIH W/valve 10 set at 10,197'. POOH. RBIH W/2"GS,sat down on plug body, POOH. Recovered RHCP Plug body, RDMO Slick-line Unit.Set Back pressure valve in Tbg Hanger, ND Annular, ND Double gate and flow cross, hung on bottom of master skid. ND riser on wellhead. NU Well-head,hooked up flow lines, pulled BPV and installed 2-way check,test wellhead to 5000 psi. Turn over to production • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I`C, , ci/l`?f,3 DATE: 9/2/2013 P. I. Supervisor FROM: Bob Noble SUBJECT: No-Flow Test Petroleum Inspector Hilcorp Alaska LLC Granite Point State 32-13RD PTD 192-020 912/13: I traveled to Hilcorp's Granite Point platform. On arrival I met with Hilcorp platform Lead operator Jimmy Madrid. We discussed the No-Flow. Jimmy said that he had the well flowing to atmosphere for 4+ days. He had the no-flow meter hooked up and we began the test. The test results are as follows: Time Pressures Status Flow Rate Remarks (psi) (scfm) 1300 0 Shut in well 0 1400 0.3 Shut in 0 1430 0.4 Open well 7.5 ' Bled to 0 psi; 0 scfh in 30 sec ` 1431 0 Shut in well 0 1500 0.1 Shut in 0 1600 0.2 Shut in 0 1630 0.3 - Open well 7 Bled to 0 psi; 0 scfh in 30 sec - Pressures -tubing Flow Rate - standard cubic feet per minute (scfm) I removed hose from no-flow gauge and could not hear or feel any flow. - Attachments: none l'2. f 2013-0902 No-Flow_GP_State_32-13RD_bn w w � \\� %% s 9 THE STATE Al 011 and Gas - °f l 1LAS�L �1 1 Conservation Commission :t om - GOVERNOR SEAN PARNELL 333 West Seventh Avenue *,h OF Q. ALAS Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 Dan Taylor 1MED t,11AY 16 2013. Operations Engineer 0 a Hilcorp Alaska, LLC + �✓ 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 - Re: Granite Point Field, Middle Kenai Oil Pool, Granit Pt St 32 -13RD Sundry Number: 313-.219 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 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, / / - ; 4 -t . Cathy P. oerster Chair DATED this ID day of May, 2013. Encl. • III • 4 RECEIVED STATE OF ALASKA OA MAY 0 3 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Welt ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing U • Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ After Casing ❑ Other ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development GI • 192-020 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99503 50- 733 - 20014-02 • 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 6 ; 4 p{' PtifTFoKM Will planned perforations require a spacing exception? Yes ❑ No ❑ Granite Pt St 32 -13RD 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0018761 • Granite Point Field / Middle Kenai 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): • 12,563 '10,646 12,473 • 10,606 N/A • 10,898 (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 668' 18 -5/8" 668' 668' Surface 2,506' 13 -3/8" 2,506' 2,485' 2,730 psi 1,130 psi Production 8,417' 9 -5/8" 8,417' 8,226' 6,330 psi 3,810 psi Liner 2,636' 7" 10,824' 9,964' 8,160 psi 7,020 psi Liner 2,061' 5" 12,561' 10,646' 8,290 psi 7,250 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# / L -80 10,560' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker SAB -3 Packer and Halliburton Wellstar SSSV . Packer 10,452' (MD) 9,776' (TVD) and SSSV 305' (MD) 305' (TVD) 12. Attachments: Description Summary of Proposal 12 • 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 • Exploratory ❑ Stratigraphit ❑ Development El • Service ❑ 14. Estimated Date for f. 15. Well Status after proposed work: *1/2013 Commencing Operations: Oil O i 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 Dan Taylor Email dtaylorphilcorp.com Printed Name Dan Ta Title Operations Engineer Signatur Phone (907) 777 -8319 Date 5/3/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ...zig 1 Plug Integrity ❑ BOP Test Fel Mechanical Integrity Test ❑ Location Clearance ❑ Other. * 56 OD Ps /0 p l��f (3000 1 ,r,-.. y -4:.... 4G-) aSOO PS L Ah h "- sF— 5 Q.71 — ;1 r7 r; iks19Gc % oh , • 41- S i L rz p p ;s eoAt - fr lldG•• 61.... II /l CJ / Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0" / QY REIN AS MAY 16 20 [ :' APPROVED BY _ Approved by: ( t , L Cit/Jf "L L COMMISSIONER THE COMMISSION 9 �3 Date: L : _ l / / r * i , t,G r Submit omt ane �1 5 `�� Form 10-403 (Revised 10/2012) Approve /' I t I 1 nthS from the date of approval Attachments in Duplicate • Well Prognosis Well: GP- 32 -13RD Hilcorp Alaska, LI) Date: 05/02/2013 Well Name: Granite Point St 32 -13RD API Number: 50- 733 - 20014 -02 -00 Current Status: Oil Producer Leg: 3 Estimated Start Date: June 1, 2013 Rig: DJ/t( N Reg. Approval Req'd? Moncla Rig 301 / Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 192 -020 ti First CaII Engineer: Dan Taylor (907) 777 -8319 (0) (907) 947 -8051 (M) Second Call Engineer: Reid Edwards (907) 777 -8421 (0) ' AFE Number: Current Bottom Hole Pressure: - 2,100 psi @ 10,180' TVD Anticipated reservoir pressure based on historical reservoir data. Maximum Expected BHP: - 2,100 psi @ 10,180' TVD Max. Allowable Surface - 968 psi Based on gas filled well with Pressure: gradient = 0.1 psi /ft Brief Well Summary This well was drilled and completed as a gas lifted horizontal oil well in the Tyonek C5 interval in 1992. The well was SI in October 2010 after it was discovered the tubing had parted at -277' MD. In December of 2012 the well was brought back on line after a tubing patch was installed. The well is currently producing at 106 bpd with 67% �c.. water cut (from well test dated 4/11/13). The current recompletion plan is to pull the tubing and install new tubing, gas lift mandrels and gas lift valves. Pre -Rig Work 1. Load well with filtered inlet water. Shoot fluid levels on two occasions, a minimum of one day apart. Note fluid level. Calculate bottom hole pressure based on 8.4 ppg. - 2. Circulate filtered inlet water around to displace any hydrocarbons that may be near the surface. 3. Test gas alarms. 4. Rig up slick line for gauge ring run. Make gauge ring run as deep as possible. Procedure: 1. Skid Rig over well center. 2. Load pits with filtered inlet water. 3. Set back pressure valve. s` 366012, 4. Nipple down tree and nipple up BOP. Soon ►° a. Pressure test BOP to 250 psi low psi high (Notify AOGCC 24 hrs. before pending BOPE test). 5. Remove back pressure valve. 6. Double check all rams and valves for correct operating position. 7. Release tubing hangar and lay down. 8. Rig up E -line chemical cutter. 9. Trip in hole to tubing joint above packer and make tubing cut.. (b' 10. Pull out of hole and rig down E -line. 11. Circulate bottom up displacing hydrocarbons. 12. Pull out of hole with production tubing removing TRSV, control line, and gas lift mandrels. 13. Trip in hole and retrieve tubing stub with overshot. F 14. Pull out of hole with tubing stub and latch assembly. 15. Pick up and run in hole with 9 5/8" clean out assembly. 16. Circulate hole clean and pull out of hole with clean out assembly. • • Well Prognosis Well: GP- 32 -13RD Hilcorp Alaska, LLB Date: 05/02/2013 17. Pick up and run in hole with 7" clean out assembly. 18. Circulate hole clean and pull out of hole with clean out assembly. 19. Pick up and trip in hole with tubing stinger and ported mule shoe on work string. 20. Reverse circulate and wash fill to 12,248 ft. 21. Pull out of hole with clean out assembly. 22. Pick up / Make up RTTS assembly and trip in hole to approximately 10,440 ft. a. Set RTTS tool / Install surface safety valve. 3 y 5 b. Test 7" and 9 5/8" casing to 1,500 psi and hold,201riin. /C A .v c. Reset RTTS to isolate leaks if necessary. 23. Pull out of hole with RTTS assembly and lay down the same. 24. Pick up and make up new production string, seal assembly, anchor latch, and gas lift mandrels. Run in hole spacing out. / 25. Land new hangar. `, 0 TA - (b ✓ 5 "'� ° s '-! l o 26. Set back pressure valve. 27. Nipple down BOP and install tree. 28. Remove back pressure valve. 29. Turn well over to platform production. Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. BOP Schematic t .- • • Granite Point Platform Well GP 32 -13RD SCHEMATIC Completion Date: 05/18/92 Hileorp Alaska, LLC PTD: 192-020 API: 50- 733 - 20014 -02 ,� CASING DETAIL RKB = 110' ��/ Size W T /Grade CONN Top Bottom J 1 I 18 5/ 70.7/B 0 668' ,/ L 13 3/8 54.5/.1-55 BTC 0 2,506' 18 -5/8" 2a 1!� 9 -5/8" 43.5/47 BTC 0 8,025' 2 b N80/S95 BTC 8,025' 8,417' 7" 29/N -80 BTC 8,188' 10,824' 2C 5 „ 15 /L -80 BTC 10,500 12,521' 18/L -80 BTC 12,521' 12,561' TUBING DETAIL 2 -7/8" 1 6.4/L -80 BTC 1 0 1 10,560' AMMO . 13 -3/8" ME JEWELRY DETAIL mum MR ' No Item Depth 1 FMC Tubing Hanger 43.85' in TOL 7 "' ' 2a Halliburton Wellstar TRSV 305' @ 8,188' \ Note: Slickline 2b Weatherford Expansion Unit 312' an SSSV lock 2 -7/8" Logan tubing patch w/ loft } open tool on 2c extensions 1,052' L bottom. WL Camco "KBMG -2" Gas Lift Mandrel 1,239' 9 -5/8" cannot pass Camco "KBMG-2" Gas Lift Mandrel 1,986' 4,400'. Camco "KBMG -2" Gas Lift Mandrel 2,763' El Possible cork Camco "KBMG -2" Gas Lift Mandrel 3,288' OOP ■ screwed Camco "KBMG -2" Gas Lift Mandrel 3,810' tubing. Camco "KBMG -2" Gas Lift Mandrel 4,309' • Camco "KBMG -2" Gas Lift Mandrel 4,837' al Camco "KBMG -2" Gas Lift Mandrel 5,339' 3 Camco "KBMG -2" Gas Lift Mandrel 5,836' Camco "KBMG -2" Gas Lift Mandrel 6,359' 1 4 Camco "KBMG -2" Gas Lift Mandrel 6,855' ?.''‘f-el Camco "KBMG -2" Gas Lift Mandrel 7,388' 5 'S Camco "KBMG -2" Gas Lift Mandrel 7,922' Camco "KBMG -2" Gas Lift Mandrel 8,424' TOL 5" 6 Camco "KBMG -2" Gas Lift Mandrel 8,986' @ 10,500' Camco "KBMG -2" Gas Lift Mandrel 9,553' L 7 Camco "KBMG -2" Gas Lift Mandrel 10,398' 7" 4 OTIS "XA" Sliding Sleeve 10413' 5 BAKER SAB -3 Packer 10,452' 6 OTIS "X" Profile Nipple 10,527' 1 u 9 7 BAKER SHEAR SUB 10,560' Note: Last Wireline Note: Patch installed in 10/2012. tag @ 10,898'KB on '-' -- - 11/18/07 w/ 2" GR C -5 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Date Comments 10,600' 10,680' 9,853' 9,893' 4 10/31/1996 WLP 10,680' 10,810' 9,893' 9,957' 4 4/1/1995 WLP 10,810' 10,850' 9,957' 9,976' 4 10/31/1996 WLP C -5 10,850' 11,020' 9,976' 10,046' 4 4/1/1995 WLP ETD = 12,473' 11,120' 11,235' 10,086' 10,131' 4 5/18/1992 TCP TD = 12,563' A . 11,322' 11,524' 10,162' 10,234' 4 5/18/1992 TCP 5" 11,611' 11,914' 10,264' 10,373' 4 5/18/1992 TCP MAX HOLE ANGLE = 69 @ 11,453' 11,986' 12,148' 10,401' 10,467' 4 5/18/1992 TCP Updated by DMA 12/19/12 • • II Granite Point Platform Well GP 32 -13RD PROPOSED Completion Date: Future llilcarp Alaska, LLC PTD: 192 -020 API: 50- 733 - 20014 -02 CASI DETAIL RKB = 110' Size WT /Grade CONN Top Bottom 1 1_. 18 -5/8" 70.7/B 0 668' J 13 -3/8 54.5/J -55 BTC 0 2,506' 18-5/8" 9-5/8" 43.5/47 BTC 0 8,025' N80 /595 BTC 8,025' 8,417' 7" 29/N -80 BTC 8,188' 10,824' 15/L -80 BTC 10,500 12,521' 18/L -80 BTC 12,521' 12,561' TUBING DETAIL 1 2 -7/8" 1 6.4/L -80 EUE JEWELRY DETAIL 0 1 ±10,560' G 13 -3/8" 1 No Item Depth 1 FMC Tubing Hanger 43.85' TOL 7" SFO -1 1" GLM ±2,481' @ 8,188' SFO -1 1" GLM ±4,121' / SFO-1 1 " GLM ±5,450' ill ' 2 SFO -1 1" GLM ±6,414' L SFO-1 1" GLM ±7,192' 9 -5/8" 2 SFO -1 1" GLM ±7,819' SFO-1 1" GLM ±8,339' SFO -1 1" GLM ±8,875' I SFO -1 1" GLM ±9,440' SFO-1 Orifice ±10,210' 3 OTIS "XA" Sliding Sleeve ±10,413' II 4 BAKER SAB -3 Packer ±10,452' 5 OTIS "X" Profile Nipple ±10,527' II 6 BAKER SHEAR SUB ±10,560' 3 4 TOL S" 5 PERFORATION DATA @ 10,500' \ / Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Date Comments L 10,600' 10,680' 9,853' 9,893' 4 10/31/1996 WLP 6 10,680' 10,810' 9,893' 9,957' 4 4/1/1995 WLP 10,810' 10,850' 9,957' 9,976' 4 10/31/1996 WLP C -5 10,850' 11,020' 9,976' 10,046' 4 4/1/1995 WLP 11,120' 11,235' 10,086' 10,131' 4 5/18/1992 TCP 11,322' 11,524' 10,162' 10,234' 4 5/18/1992 TCP 11,611' 11,914' 10,264' 10,373' 4 5/18/1992 TCP 11,986' 12,148' 10,401' 10,467' 4 5/18/1992 TCP C -5 ■ masa ■ ETD = 12,473' TOF 12,248' TD = 12,563' 5" MAX HOLE ANGLE = 69° @ 11,453' Updated by JLL 05/02/13 • Bruce-Baker-GPP project KT# 01 BOP Stack 9/14/2012 11 iirorp .ikla.la. 1.1.c Nordic Rental 4.54' • • Hydril GK 135'8" -5000 111 111 11 1 111 111 Shaffer Sl - 2.83' • 13 5/8" -5000 Choke and Kill lines 21/165M w/ Unibolt connections 111111 1 III III TAA ;t�� }I ���M 2.00' •� 4k •111 1!1 111111111 4j 1st um! 111 I!I Riser 135/85MX 135/85M 11.00 fit 111 111 111 111 1.11 III III 111 111 1.00' to 3.00' 111 111 111 111 111 e . H • • Granite Point Platform 32 -13rd 10/04/2012 II aIrnrl. ■:..k .. I.i.( Granite Point Tubing hanger, FMC -UH- 32-13rd TC- 1A -EN, 13 5/8 5M X 18 5/8 X 13 3/8 X 9 5/8 X 3 1 /2 IBT lift and susp, w/ 2 7/8 3" type H BPV, 1 /4 non continuous control line, 5.990" EN BHTA, Bowen, 3 1/8 5M FE X 3" Bowen . 0 1....... P Valve, Swab, Demco- �• •' DM, 3 1/8 5M FE, HWO, * V, EE trim '' JY�% Valve, Wing, WKM -M, '1 I ' ■ ' ' ■"' 3 1/8 5M, w/ D -122 oper 1. I Tee, stdd, 3 1/8 5M X • 3 1/8 5M r1 •,' (S) Valve, Master, CIW -FL, ��, �'J 3 1/8 5M FE, HWO, EE �' 4, trim - Ii�•� � ■�g•.• Adapter, FMC -A5P, 13 5/8 5M API clamp X 3 1/8 5M, w/ 'KVA. 6" extended neck pocket Unihead, OCT type 2, 13 5/8 5M 0 III Era API hub top X 13 3/8 BTC casing bottom, w/ 2- 2" LPO on lower section, 2- 2 1/16 5M SSO on ie. — • — upper section, IP internal lockpin 1 assy __ V alve, BTN, 2 1/16 5M I 1 :�1 ■ : ' 1 B ® HWO, AA trim { ' } Valve, OCT -20, 2 1/16 5M 8 I s ��. 1 _4 e HWO, AA trim as -" . : A 1 • Valve, OCT -20, 2" LPO, 1 U1 1 11111111111111110:;,11-i.,: HWO, AA trim Starting head, OCT, 21 1/4 ® iI r 2M X 18 5/8 weld '.1-111=1111M \ —it 9 , , II STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well pi Plug Perforations L Perforate 1 Other L.j Install Overshot Performed: Alter Casing ❑ Pull Tubing El Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC - Development El Exploratory ❑ 192 -020 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: „,, Anchorage, Alaska 99504 50- 733 - 20014 -02 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018761 Granite Pt St 32 -13RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): a N/A Granite Point Field / Middle Kenai Oil 11. Present Well Condition Summary: Total Depth measured 12,563 feet Plugs measured N/A feet true vertical 10,646 feet Junk measured 10,898 (fill) feet Effective Depth measured 12,473 feet Packer measured 10,452 feet true vertical 10,606 feet true vertical 9,776 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 668' 18 -5/8" 668' 668' Surface 2,506' 13 -3/8" 2,506' 2,485' 2,730 psi 1,130 psi Intermediate Production 8,417' 9 -5/8" 8,417' 8,226' 6,330 psi 3,810 psi Liner 2,636' 7" 10,824' 9,964' 8,160 psi 7,020 psi Liner 2,061' 5" 12,561' 10,646' Vi I E ,250 psi 1 Perforation depth Measured depth See Attached Schematic DEC 2 0 2012 True Vertical depth See Attached Schematic AOGCC 1 1 Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.4# / L -80 10,560' MD 9,832' TVD 10,452' MD Halliburton 305' MD Packers and SSSV (typ a measured and true vertical depth) Baker SAB-3 Pkr 9,776' TVD Wellstar SSSV 305' TVD P ) 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A SCANNED MAR 1 8 2013 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 120 ' "._ 120 Subsequent to operation: 5 0 100 1,100 60 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development 151 # Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil — El 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: 312 -383 Contact Chad Helgeson Email chelgesonAhilcoro.com Printed Name Chad Helgeson Title Operations Engineer Signature C� 7��/ Phone 907 - 777 -8405 Date 1 Z f Zri �( Z bMs DEC 202012, Form 10 -404 Revised 10/2012 4 . L - 1 - 4 2 ^ S it Original Only Granite Point Platform li SCHEMATIC Well GP 32 -13RD Completion Date: 05/18/92 Hilcorp Alaska, LLC PTD: 192 -020 API: 50- 733 - 20014 -02 CASING DETAIL RKB = 110' I Size WT /Grade CONN Top Bottom 1 L 18 -5/8" 70.7/B 0 668' 13 -3/8 54.5/J -55 BTC 0 2,506' 18 - 5/8" 2 a 9-5/8" 43.5/47 BTC 0 8,025' 2b N80/595 BTC 8,025' 8,417' i 7" 29/N -80 BTC 8,188' 10,824' 2c 15/L -80 BTC 10,500 12,521' 5 18 /L -80 BTC 12,521' 12,561' ..= TUBING DETAIL G M 1 2 -7/8" 6.4/L -80 1 BTC 1 0 10,560' 13-3/8" I= , IMB JEWELRY DETAIL 111111 No Item Depth M 1 FMC Tubing Hanger 43.85' TOL 7" M ' 2a Halliburton Wellstar TRSV 305' @ 8,188' \ \ Note: Slickline 2b Weatherford Expansion Unit 312' In SSSV lock 2 -7/8" Logan tubing patch w/ 10ft II 1 3 open tool on 2c extensions 1,052' in bottom. WL Camco "KBMG -2" Gas Lift Mandrel 1,239' 9 -5/8" cannot pass Camco "KBMG -2" Gas Lift Mandrel 1,986' 4,400'. Camco "KBMG -2" Gas Lift Mandrel 2,763' Possible cork Camco "KBMG -2" Gas Lift Mandrel 3,288' ' screwed Camco "KBMG -2" Gas Lift Mandrel 3,810' MIND . tubing. Camco "KBMG -2" Gas Lift Mandrel 4,309' Camco "KBMG -2" Gas Lift Mandrel 4,837' Camco "KBMG -2" Gas Lift Mandrel 5,339' ' 3 Camco "KBMG -2" Gas Lift Mandrel 5,836' Camco "KBMG -2" Gas Lift Mandrel 6,359' 4 Camco "KBMG-2" Gas Lift Mandrel 6,855' Camco "KBMG -2" Gas Lift Mandrel 7,388' 5 Camco "KBMG -2 " Gas Lift Mandrel 7,922' Camco "KBMG -2" Gas Lift Mandrel 8,424' TOL 5" 6 Camco "KBMG -2" Gas Lift Mandrel 8,986' @ 10,500' Mil Camco "KBMG -2" Gas Lift Mandrel 9,553' d 7 Camco "KBMG -2" Gas Lift Mandrel 10,398' 7" 4 OTIS "XA" Sliding Sleeve 10413' 5 BAKER SAB -3 Packer 10,452' 6 OTIS "X" Profile Nipple 10,527' 7 BAKER SHEAR SUB 10,560' Note: Last Wireline Note: Patch installed in 10/2012. tag @ 10,898'KB on -'''� 11/18/07 w/ 2" GR Int C - 5 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Date Comments 10,600' 10,680' 9,853' 9,893' 4 10/31/1996 WLP 10,680' 10,810' 9,893' 9,957' 4 4/1/1995 WLP 10,810' 10,850' 9,957' 9,976' 4 10/31/1996 WLP C -5 10,850' 11,020' 9,976' 10,046' 4 4/1/1995 WLP ETD = 12,473' 11,120' 11,235' 10,086' 10,131' 4 5/18/1992 TCP TD = 12,563' 11,322' 11,524' 10,162' 10,234' 4 5/18/1992 TCP 5 " 11,611' 11,914' 10,264' 10,373' 4 5/18/1992 TCP MAX HOLE ANGLE = 69° @ 11,453' 11,986' 12,148' 10,401' 10,467' 4 5/18/1992 TCP Updated by DMA 12/19/12 • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 32 -13RD 50- 733 - 20014 -02 192 -020 10/14/12 11/3/12 Daily Operations: 10/14/2012 - Sunday Begin rigging up. 10/15/2012 - Monday Continue rigging up. Note: AOGCC Jim Regg waived witness to BOP test on 10 -15 -12 @ 4:44 PM. 10/16/2012 - Tuesday Continue rigging up & prepping for BOP test. 10/17/2012- Wednesday Preparing for upcomming BOPE Test. 10/18/2012 -Thursday Continue to prepare fore BOPE test. Test BOPE as per AOGCC & Hilcorp procedures. Test 250 low, 3,000 high, hold & chart each 5 min. all tests good except upper rams & failure on blind rams. new ram bodies and seals are being delivered for blinds. A technician is also coming to work on upper rams. 10/19/2012 - Friday R/u change out variables t/ 2 -7/8" rams, pull blind rams, repair, re- install. Pull BPV install TWC ; R/u & test blinds, 250 low, 3,000 high, hold & chart 5 min good, pull TWC & install BPV, install 2 -7/ "8 test jt, test rams, fail, pull rams, repair, retest good. yi R/d test eq & blow down surface eq. AOGCC Jim Regg waived witness for BOP test on 10/15/2012. 10/20/2012 - Saturday R/U Hard line from choke manifold to gasbuster, break down test jt, m/u landing jt, arrange decks install cross braces to sub- structure. R/U Weatherford tongs, r/u elevators & slip bowl. Pull hanger free, up wt 2,200, string wt 1,850, break off & L/D hanger. Pull & L/D 2 -7/8" tubing, 230' total string OOH, all control line came with jts. L/D hanger, hanger pup (3 /1/2 ") & xo, 7 jts 2 -7/8" tubing, and a 2.9 partial jt to part. Tubing pitted. Clean up, strap pipe, L/D tongs & secure well. 10/21/2012 - Sunday Arrange deck, M/U 2 -7/8" grapple in overshot w /3' ext. R/U tongs and P/u 2 -7/8" tubing RIH t/274' (KT #1 measurement)string wt 2,400, slide over fish 5.5', P/U to 5,200. Put 3 bbls down tubing, no fill. R/U wireline, & test lubricator to 1,000 psi good, M/U 2.34 guage ring and RIH t/ 305' wlm, tag sssv no go, POOH. M/U 8 ft stem below swedge, RIH t/ 297' wlm set down fall through sssv flapper sat down no go @ 305' wlm, pooh. R/D wireline, spot E -line unit. 10/22/2012 - Monday R/U a -line, Pull string in tension t/6,300 RIH to 831' wlm, cut tubing, pooh t/308', unable to get E -line back through SSSV, work several times, no go. Secure well. 10/23/2012 - Tuesday R/U to Pooh stripping over E -line. Work on E -line clamp. Pooh to SSSV, up wt 4,400, Break off grapple & I/d SSSV, pull E -line tools out & I /d. Continue to pooh & I/d fish, 553', 785' total I /d, cut flared & pipe deeply pitted. Break down grapple BHA, M/U overshot mill & grapple assy. P/U pipe & TIH to TOF, tag @ 832.49', up wt 5,900, string wt 5,500. Dress off TOF, wt on mill 1,000- 1,500, rot +- 20 rpm. Pull one jt & L /d, secure well, service rig support Eq. • • 10/24/2012 - Wednesday RU a -line. RIH w/ 2.25" jet cutter w/ 828' wlm. Unable to cut. CO to 2 -1/8" cutter. RIH to 828' wlm. Still no go. RU release grapple from fish @ 831'. POOH. Re -drift BHA good. Mobe out. Dress off mill w/ 8 -1/8" guide. MU mill assembly. RIH to 83' tag obstruction w/ 8 -1/8" guide. POOH. 10/25/2012 - Thursday CO BHA to grapple. TIH to 831'. Up wt 6,100, dn 5,800. Engage grapple to fish. PU to 9,000 lbs & set slips. Arrange deck, clear cat -walk, spot Expro WLU. RU wireline & MU 2 -1/4" LIB. RIH to tag @ 831' wlm. POOH. MU 2.125" swedge. RIH to 831' run through to 1,063' tag. No go. RIH w/ barbed scratcher. Attempt to retrieve hold open sleeve @ 1,073'. No go. RIH w/ 2.34" swedge. Run through to 1,073'. POOH. RD wireline. RU e-line. RIH w/ 2 -1/4" jet cutter to 1,060'. Cut, verify, POOH. RD e-line. POOH to grapple. Release grapple & LD. Pull fish, 7 jts. LD. TIH to 1,044'. Secure well. 10/26/2012 - Friday PU RIH to 1,045'. Tag & dress off tubing. Cut string wt 6,800. PU & RU w/ Lub. RIH w/ WL to 1,063' wlm. Two runs: one with wire scratcher, one with cable scratcher. Work down & up. Hit 23x w/ oil jars. No luck retrieving object. POOH. RD WL. POOH w/ overshot mill. MU patch BHA. TIH to 1,045'. Tag string wt 7,000. Work string and attempt to go down. No go. Secure well. 10/27/2012 - Saturday Work pipe attempt to go down. No go. POOH w/ string & inspect finding patch hanging on tubing cut. RU to test BOP's w/ 2- 7/8" Ti. Test BOP's as per Hilcorp & AOGCC procedures (250 low - 3,000 high, hold 5 min ea). Witness waived by AOGCC Lou Grimaldi @ 10:00 am. RD test eq. & blow down. TIH w/ overshot mill. 10/28/2012 - Sunday PU 2 -7/8" logan patch assy. RIH on 2 -7/8" L -80 563 hyd tubing to 1,050.5'. String wt 6,800. Tag tubing stump. Set 5,000 on patch. No go. Set 6,800 & work down to 1,052'. PU string. Pull to 16,000'. Work string down to land hanger. Patch @ 1,055' ±, 6,800 up dn wt. Pull landing jt. Install BPV. 10/29/2012 - Monday Prep from boat. RD hardline to gas buster. RD gas buster. RD KT #1 work platform. RD accumulator lines. ND BOP's. NU well head. Test hanger void 250 low - 5,000 high hold each 10 min. RD & prep rest of surface eq. from loadout. Test tree 250 low - 5,000 high, hold each 10 min. De -mobe hands to beach. 11/02/2012 - Friday RU to RIH with LIB. POOH with LIB and inspect tag @ 1,010' wlm. Ran in with spear and did not find the fish. Ran down to 3,000'. POOH. Rearrange tool string. RIH to 4,500' could not pull up with over weight. Proceed to work wire till it came free 3,300' before it started to move. Good still over pull 600 #. OOH LD tool string for the night. Order up different tools to RIH with tommorrow. 11/03/2012 - Saturday RIH with gauge ring to look for fluid. Made several trips in and out to pull #5 GL valve, not happening. POOH and LD for the night. Test casing to 1,000 psi w/ gas lift gas. 0 psi on tubing. Patch integrity. Pressure tubing to 1,000 psi w/ gas and 0 psi on casing. Test for 30 min. '- • i o� �y,' , THE STATE Alaska Oil and Gas F O y am _ '� OfA LASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue we Anchorage, Alaska 99501 -3572 0,0„ ALAS � Main: 907.279.1433 Fax: 907.276.7542 Chad Helgeson 19 c g,— d P--.0 Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granit Pt St 32 -13RD Sundry Number: 312 -383 Dear Mr. Helgeson: . /40,0; � 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, - Cathy P/. Foerster Chair t DATED this /Z day of October, 2012. Encl. • . RECEIVED t OCT 05 2012 STATE OF ALASKA yJ� $ is . ALASKA OIL AND GAS CONSERVATION COMMISSION A�,OG C 1 al / APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redd! ❑ Perforate New Pool ❑ Repair Wet 0 ' Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 0 Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Install Overshot 0 ' 2. Operator Name: 4. Current Well Class: 5. Permit to DriN Number: Hilcorp Alaska, LLC Development 0 • Exploratory ❑ 192 -020 • 3. Address: Strati r hic Se rvice 6. API Number: g ap ❑ ❑ 3800 Centerpoint Drive, Suite 100, Anchorage, AK 99503 50- 733 - 20014-02 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and umber property line where ownership or landownership Changes: Spacing Exception Required? Yes ❑ No 0 Granite Pt St 32 - 13RD 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0018761 • Granite Point Field / Middle Kenai 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): 12,563 • 10,646. 12,473 10,606 N/A 10,898' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 668' 18 -5/8" 668' 668' Surface 2,506' 13 -3/8" 2,506' 2,485' 2,730 psi 1,130 psi Intermediate Production 8,417' 9 -5/8' 8,417' 8,226' 6,330 psi 3,810 psi Liner 2,636' 7" 10,824' 9,964' 8,160 psi 7,020 psi Liner 2,061' 5" 12,561' 10,646' 8,290 psi 7,250 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# / L -80 10,560' Packers and SSSV Type: Baker SAB -3 Pkr Packers and SSSV MD (ft) and TVD (ft): 10,452' MD; 9,776' TVD Baker FVGE SSSV 302' MD; 302' TVD 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Development 0 • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 1 10/11/2012 Commencing Operations: Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson 777 -8405 Printed Name Chad Helgeson Title Operations Engineer Signature (Y/� Phone 777 -8405 Date /O M 'L COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 312.58•3 Plug Integrity ❑ BOP Tes Mechanical Integrity Test ❑ Location Clearance ❑ Other: -C S 0 of 1 3 O D r2 S L Subsequent Form Required: APPROVED BY Approved by: � 71/1'9 / -7 � 1F,Q,L THE COMMISSION Date: t/0 - ( — / � v r, "1' "F U! T 1 Z R N Form 10 -403 R vised 1/2010 1 ai` 0 I i Z O i Submit in Duplicate i 0 Well Prognosis Well: GP- 32 -13RD Hilcoru Alaska, LLC Date: 10/3/2012 Well Name: Granite Point St 32 -13RD API Number: 50- 733 - 20014 -0200 Current Status: SI Oil Producer Leg: 3 Estimated Start Date: October 11, 2012 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 192 -020 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Reid Edwards (907) 777 -8421 (0) AFE Number: Current Bottom Hole Pressure: —2,100 psi @ 10,180' TVD (Estimated mid perf pressure) Maximum Expected BHP: — 2,100 psi @ 10,180' TVD Max. Allowable Surface Pressure: —0 psi (Based on 0.358 psi /ft fluid gradient, Safety factor of 1,000 tvd oil cap, and 25% water cut) Brief Well Summary This well was drilled and completed as a gas lifted horizontal oil well in the Tyonek C5 interval in 1992. The well was SI in October 2010 after it was discovered the tubing had parted at "'277' MD. Production has remained SI since that time awaiting rig intervention to repair the well. A wire -line camera was run recently to determine the condition of the tubing at the part. Results from the camera run showed that the tubing was in fair condition and a relatively clean part existed. y I , The current recompletion plan is to pull the upper section of the parted tubing and replace it with new tubing 7. containing a sealing overshot. Brief Procedure: 1. RU KT #1 work platform using the platform crane (crane capacity over well is 77,000Ibs) 2. Set)P'G in production tubing 3. ND Tree. 1 ' 4. NU BOPE, pressure test BOP to 250psi lowL3,000 psi hieh. a. Note: notify AOGCC 48 hours in advance for theopportunity to witness BOP test b. If I or tubing hanger Teaks during BOP test, perform rolling BOP test on blind and pipe rams (see attached rolling BOP test procedure). 5. Pull /Release tubing hanger and lay down tubing. 6. Pull 2 7/8" tubing while reeling in SSSV control line a. Tally control line to determine how much is left in hole and how much could be left on top of parted tubing b. Lay down pipe and tally same 7. PU 5 - %" overshot with oversize guide dressed with 2 -7/8" grapple, crossover to tubing, RIH and latch 2- 7/8" tubing. 8. RU a -line to cut 2 -7/8" tubing approx. 800' in good tubing joint. 9. POOH and RD E -line • • • .. Well Prognosis Well: GP- 32 -13RD Hilcory Alaska, LLC Date: 10/3/2012 10. POOH with overshot assembly, 2 7/8" tubing, SCSSV control line, SCSSV, balance of corroded tubing a. Lay down with crane in singles on deck b. Tally tubing and control line i. Note: Observe condition of tubing end where cut to make sure tubing is in good condition with minimum scale or corrosion ii. If highly corroded, repeat step 8 & 9 deeper 11. PU 3 -5/8" OD x 5 -3/4" OD guide, Logan High Pressure Packer Type Tubing Patch dressed to Patch 2 -7/8" OD tubing, (5,000 PSI Maximum Pressure), with tea 5' extensions, w/ 2 -7/8" tubing, SCSSV, to tubing hanger, and SCSSV control line to surface. (see attached wellbore schematic for depths) 12. RIH with Crane to top of 2 7/8" tubing stub a. Slide over engage 2 7/8" tubing with patch assembly b. Make up tubing and tubing hanger P T /s J c. Land tubing hanger w/ control line d. Lock down tubing hanger 13. Set BPV, ND BOP, NU tree/ remove BPV 14. Connect SCSSV tubing line to control panel 15. Turn well over to production. 16. Flow well, Test SCSSV (notify AOGCC 48hrs prior to testing valve). Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. BOP Schematic 4. Rolling BOP Test Procedure I�, • 0 i H GRANITE POINT PLATFORM SCHEMATIC WELL# 32 -13 RD Hilcorp Alaska, LLC CURRENT COMPLETION 5/12/92 RKB = 110' CASING DETAIL API # 50- 733 - 20014 -02 SIZE WT /Grade CONN TOP BOTTOM W 1 18 -5/8" 70.7/B 0 668' 18 -5/8_ - 13 -3/8 54/J -55 BTC 0 2,506' 2 43.5/47 BTC 0 8,025' 9 -5/8" - ° N80/S95 BTC 8,025' 8,417' 7" 29/N -80 BTC 8,188' 10,824' AMMMW 5 „ 15/L -80 BTC 10,500 12,521' 13-3/8" 18/L -80 BTC 12,521' 12,561' m ° Tubing Detail 2 -7/8" 6.4/L/80 BTC 0 10,560' ANIMIr 10/22/08: Suspect Parted Tubing TOL 7" @ +/- 277' KB. Well Shut In. JEWELRY DETAIL @ 8 "188 \ 3/ No Item Depth 1 FMC Tubing Hanger 43.85' 2 BAKER "FVGE" SSSV 302' 9 -5/8 Camco "KBMG -2" Gas Lift Mandrel 1,239' Camco "KBMG -2" Gas Lift Mandrel 1,986' A Camco "KBMG -2" Gas Lift Mandrel 2,763' Camco "KBMG -2" Gas Lift Mandrel 3,288' IIIMIt Camco "KBMG -2" Gas Lift Mandrel 3,810' EMIR Camco "KBMG -2" Gas Lift Mandrel 4,309' Camco "KBMG -2" Gas Lift Mandrel 4,837' I Camco "KBMG -2" Gas Lift Mandrel 5,339' ■ 3 Camco "KBMG -2" Gas Lift Mandrel 5,836' Camco "KBMG -2" Gas Lift Mandrel 6,359' IMF 4 Camco "KBMG -2" Gas Lift Mandrel 6,855' Camco "KBMG -2" Gas Lift Mandrel 7,388' Camco "KBMG -2" Gas Lift Mandrel 7,922' 5 Camco "KBMG -2" Gas Lift Mandrel 8,424' TOL 5" 6 Camco "KBMG -2" Gas Lift Mandrel 8,986' @ 10,500' ® Camco "KBMG -2" Gas Lift Mandrel 9,553' ' / Camco "KBMG -2" Gas Lift Mandrel 10,398' 4 OTIS "XA" Sliding Sleeve 10413' 5 BAKER SAB -3 Packer 10,452' 6 OTIS "X" Profile Nipple 10,527' 7 BAKER SHEAR SUB 10,560' PERFORATION DATA I Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Date Comments Note: Last Wireline tag @ 10,898'KB or ' '�= 10,600' 10,680' 9,853' 9,893' 4 10/31/1996 WLP 11/18/07 w/ 2" GR C 10,680' 10,810' 9,893' 9,957' 4 4/1/1995 WLP 10,810' 10,850' 9,957' 9,976' 4 10/31/1996 WLP C - 10,850' 11,020' 9,976' 10,046' 4 4/1/1995 WLP 11,120' 11,235' 10,086' 10,131' 4 5/18/1992 TCP 11,322' 11,524' 10,162' 10,234' 4 5/18/1992 TCP 11,611' 11,914' 10,264' 10,373' 4 5/18/1992 TCP 11,986' 12,148' 10,401' 10,467' 4 5/18/1992 TCP ETD = 12,473' TD = 12,563' !'- °° ,� MAX HOLE ANGLE = 69 @ 11,453' Revised By: TDF 9/19/2012 • • GRANITE POINT PLATFORM H ` • PROPOSED WELL # 32-13 RD Hilcorp Alaska, LLC CURRENT COMPLETION 5/12/92 RKB = 110' CASING DETAIL API # 50- 733 - 20014 -02 SIZE WT /Grade CONN TOP BOTTOM 1 I 18 -5/8" 70.7/B 0 668' 1 18 -5/8i L 13 -3/8 54.5/J -55 BTC 0 2,506' 2 9-5/8" 43.5/47 BTC 0 8,025' N80/S95 BTC 8,025' 8,417' 12b 7 29/N -80 BTC 8,188' 10,824' 5 „ 15/L -80 BTC 10,500 12,521' 13-3/8" 18/L -80 BTC 12,521' 12,561' Tubing Detail 2 -7/8" 6.4/L/80 BTC 0 10,560' TOL7" JEWELRY DETAIL @ 8,188 E \ / No Item Depth 1 FMC Tubing Hanger 43.85' 3 2a BAKER "FV6 -E" SSSV 7 +/- 300' 9-5/8. 2 -7/8" Logan tubing patch w/ 10ft 2b extensions +/- 800' Camco "KBMG -2" Gas Lift Mandrel 1,239' Camco "KBMG -2" Gas Lift Mandrel 1,986' Camco "KBMG -2" Gas Lift Mandrel 2,763' Camco "KBMG -2" Gas Lift Mandrel 3,288' Camco "KBMG -2" Gas Lift Mandrel 3,810' Camco "KBMG -2" Gas Lift Mandrel 4,309' Camco "KBMG -2" Gas Lift Mandrel 4,837' Camco "KBMG -2" Gas Lift Mandrel 5,339' 4 3 Camco "KBMG -2" Gas Lift Mandrel 5,836' Camco "KBMG -2" Gas Lift Mandrel 6,359' Camco "KBMG -2" Gas Lift Mandrel 6,855' 5 Camco "KBMG -2" Gas Lift Mandrel 7,388' TOL 5" 6 Camco "KBMG -2" Gas Lift Mandrel 7,922' Camco "KBMG -2" Gas Lift Mandrel 8,424' @ 10,500' Camco "KBMG -2" Gas Lift Mandrel 8,986' L - 7 Camco "KBMG -2" Gas Lift Mandrel 9,553' Camco "KBMG -2" Gas Lift Mandrel 10,398' 4 OTIS "XA" Sliding Sleeve 10413' 5 BAKER SAB -3 Packer 10,452' 6 OTIS "X" Profile Nipple 10,527' 7 BAKER SHEAR SUB 10,560' Note: Last Wireline tag @ 10,898'KB on , PERFORATION DATA 11/18/07 w/ 2" GR C -5 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Date Comments 10,600' 10,680' 9,853' 9,893' 4 10/31/1996 WLP 10,680' 10,810' 9,893' 9,957' 4 4/1/1995 WLP 10,810' 10,850' 9,957' 9,976' 4 10/31/1996 WLP C -5 10,850' 11,020' 9,976' 10,046' 4 4/1/1995 WLP 11,120' 11,235' 10,086' 10,131' 4 5/18/1992 TCP ETD = 12,473' 11,322' 11,524' 10,162' 10,234' 4 5/18/1992 TCP TD - 12,563' 11,611' 11,914' 10,264' 10,373' 4 5/18/1992 TCP 11,986' 12,148' 10,401' 10,467' 4 5/18/1992 TCP MAX HOLE ANGLE = 69 @ 11,453' Revised By: TDF 9/19/2012 Bruce - Baker -GPP project .11 KT# 01 BOP Stack 9/14/2012 I1:1..,, U ..t.. I Il Nordic Rental 4.54' • • Hydrll GK 13 58" {5000 Iii la 111 /IIaI . . 2.83' - 13 5/8" -5000 Choke and Kill lines .� 21/165M w /Uniboltconnections Ili1.li XI lit lel 1 f' I I : � - F ir F ) J.-' 1 1 I , � , 2.00' 1 0 I 460,4 `d WI' lit III lit itt MOM 1111 111111119111 Riser 13 5/8 5M X 13 518 5M 11 00 Iii 11E1 al Iii lil I/I III lil III 111 1.00' to 3.00' III 1l1 al l%1 1i1 • • Hilcorp Alaska LLC. BOP Test Procedure: KT #1 Work Platform Kenai Asset Team Offshore WO Program Oil Producers, Gas Conversions Pre Rig Move 1) Blow down well, vented thru flare to atmosphere 2) Shoot fluid level at least 24 hours before moving on well. 3) Shoot fluid level again, right before ND /NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and /or corroded and BPV cannot be set with tree on, Profile and /or landing threads must be prepped while tree is off. If well is suspended with cement packer, test BOP's against well casing. Worst Case: BPV profile and landing threads are bad. Conduct Rolling Test. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) Pump 20 bbls of fluid down well b) Shoot fluid level in the well to understand actual reservoir status c) ND tree with no BPV d) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift- threads to accept landing joint to hold pressure. If the problem is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. e) Set 2 -way check valve by hand, or MU landing (test) joint to lift- threads f) NU BOP. Test BOPE per standard procedure. October 4, 2012 1 1 • 3) If both set of threads appear to be bad and unable to hold a pressure test, notify office via e-mail that neither profile will allow for a test of the BOP. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for Teaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid /pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger /BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 1) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10 -424) in Excel Format and e-mail to AOGCC and Hilcorp KAT BOPE distribution list. For state of Alaska guidelines Reference the following 20 AAC 25.285. Secondary well control for tubing workover operations: blowout prevention equipment requirements 20 AAC 25.066. Gas detection October 4, 2012 2 • HALLIBURT " Halliburton WellStarlu Tubing Retrievable Safety Valves Operational Procedure - SeK - -Equ Type Valve Note: This valve has a protection feature which minimizes the risk Q II of damage to the closure mechanism. Due to this feature, the © I ( B valve will not open unless pressure is completely equalized across the closure device. The opening procedure instructions must be followed closely to ensure proper results. 1. Pressure must be equalized completely across the closure mechanism. This is done by pressuring the control line (Gauge B) — which actuates the self - equalizing device within the safety valve. To open a TRSV with pressure shut -in below the valve, proceed as follows. li 2. When operating amulti -well platform from one control manifold, E. � . all the SCSSVs may be closed simultaneously, but each SCSSV . must be opened individually. •_ �1 3. To open a valve, close off all control line access to SCSSVs in ' • other wells and close the wing valve. II!! , 4. Apply and lock -in control line pressure of 4000 psi maximum , (Gauge B). Both the tubing pressure (Gauge A) above the valve . and the control line pressure (Gauge B) should begin to increase as the tubing pressure begins to equalize. Wait until the valve has fully equalized and tubing pressure (Gauge A) has stabilized. 4 5. Determine the Recommended Hold -Open Pressure (Gauge B) to w 4, be applied to the control line as follows: •• Recommendec Valve I 4 Control Line = Opening + Tubing + 500 pa ' Pressure Pressure* Pressure *Note: 1800 psi is the Valve Opening Pressure for 2 -3/8" through 4-1/2" WellStar safety valves with 1000 feet maximum setting depths. x 6. Apply the control line pressure determined in Step 5 to open the valve. Set the regulator on the control manifold pump to maintain the Recommended Hold -Open Pressure (Gauge B) on the TRSV during production. • During non - production operations such as completion, testing, rt acidizing, etc., the control line pressure may be increased as • , outlined in the "Guidelines For Hold -Open Pressure" in a valve's /,I Operating Manual. J Closintl 1. Shut-in the wellhead and allow pressure to stabilize (Gauge A). --aml 2. Bleed the hydraulic control line pressure (Gauge B) to zero. The safety valve is now closed. _ i _ _ 1 _ W!' ations Prior to performing wireline operations, isolate the control line pressure (Gauge B) from the ESD system. Apply a minimum of Valve Valve 2000 psi or a maximum of 6000 psi above the Shut -In Wellhead Pressure to ensure the SCSSV remains fully open during wet Open Closed intervention. These pressures take into consideration the safety valve's 1800 psi opening pressure. Monitor (Gauge B) continually to ensure hydraulic pressure is maintained to hold the safety valve open. • • Page 1 of 2 HALLIBURTON September 26, 2012 Engineering Data Sheet EQUIPMENT MATERIAL NO.: 100006156 TRSV,WELLSTAR,4.65 2.313,H2S,5K PART NUMBER: 78LXE23105 -P DESIGN SPECIFICATIONS VALVE MODEL WELLSTAR CLOSURE TYPE FLAPPER SIZE 2 7/8 LOCK PROFILE X MINIMUM INSIDE DIAMETER WITHOUT PACKING BORE 2.36 inch TOP SEAL BORE ID- MINIMUM 2.313 inch BOTTOM SEAL BORE ID- MINIMUM 2.313 inch MAXIMUM OD 4.65 inch LENGTH 51.19 inch MATERIAL 9CR -1 MO /17 -4PH 0-RING MATERIAL VITON SERVICE H2S SERVICE REMARKS H2S SERVICE BASED ON CUSTOMER DEFINED, WELL SPECIFIC CONDITIONS. APPLICATIONS MUST BE REVIEWED FOR SPECIFIC ENVIORNMENT COMPATIBILITY. MEETS MATERIAL SERVICE REQUIREMENTS OF NACE MR0175 /ISO 15156 TOP THREAD 2 7/8 -6.50 API -EU BOTTOM THREAD 2 7/8 -6.50 API -EU CONNECTION TYPE PIN -PIN TUBING THREAD TORQUE 2300 foot pound PRESSURE RATING 5000 pounds /sq. inch BURST PRESSURE 9844 pounds /sq. inch API COLLAPSE PRESSURE AT AMBIENT 7826 pounds /sq. inch TENSILE WITH WORK PRESS, WITHOUT TBG THD, AT AMBIENT, 144 pound CALC /1000 TENSILE WITHOUT WORK PRESS, WITHOUT TBG THD, AT 209 pound AMBIENT, CALC /1000 TEMPERATURE RATING 20 TO 300 Deg. F MAXIMUM FULL OPEN PRESSURE 1800 pounds/sq. inch MINIMUM CLOSING PRESSURE 438 pounds /sq. inch PISTON DISPLACEMENT VOLUME 2.63 cu. inch EQUALIZING FEATURE YES MAXIMUM PRESSURE DIFFERENTIAL AT VALVE OPENING 5000 pounds /sq. inch • • Page2of2 • CONTROL LINE PRESSURE TO EQUALIZE AT PRESSURE RATING 4000 pounds /sq. inch CONTROL LINE CONNECTION 1/8 NPT LOCKOUT TYPE WELLSTAR COMMUNICATION TYPE WELLSTAR LOCKOUT TOOL, PERMANENT 101059439 (42LOX23101) PRESSURE TO LOCK OUT 1250 pounds /sq. inch INSTALLATION EXTENSION 101049790 (22D5134) WIRELINE REPLACEMENT VALVE 101049983 (22FXE23111 -V) RUNNING /PULLING PRONG EXTENSION 101230689 (49P2038) ISOLATION ASSEMBLY LOCK MANDREL TYPE 2.313 X ISOLATION ASSEMBLY EQUALIZING VALVE TYPE 2.313 XO ISOLATION ASSEMBLY EXTENSION MANDREL 101049790 (22D5134) ISOLATION SLEEVE 101073451 (78D2219) ISOLATION SLEEVE 0 -RING 100006603 (91QV1328 -H) REDRESS KIT 101073778 (78LXR2310) REFERENCE INFORMATION INCONEL X -750 SPRING SEAT INSERT INSTALLATION TOOL 101096038 (83MO429) SEAT INSERT TORQUE -MIN 600 foot pound BODY TORQUE 2400 foot pound SPRING COMPRESSION TOOL 101096041 (83M0432) DRIFT BAR 101088123 (81R104) DRIFT BAR OUTSIDE DIAMETER 2.303 inch DRIFT BAR LENGTH 24.00 inch TEST FIXTURE -PIN END 101095823 (81T9855) API /ISO TYPE SCTRSV MEETS QUALITY REQUIREMENTS API -Q1 /ISO 9001 MEETS INDUSTRY SPECIFICATION(S) API 14A/ISO 10432 API /ISO SPECIFICATION EDITION ELEVENTH API /ISO VALIDATION LEVEUSERVICE CLASS 1,3S API /ISO VALIDATION DATE 05 -28 -98 API /ISO VALIDATION METHOD VARIATION API /ISO VALIDATION REFERENCE 78HXE23105 -P BDMI/TECHNICAL OPERATIONS MANUAL 78WSE00000 (END) (Unless specified, Dim - inches, pres -psi, weight -Ibs, temp -deg F) NOTE: Values of pressure, force and operating depths presented above are based upon empirical data and theoretical calculations. These values will vary within accepted engineering limits due to variations in material strength, dimensional tolerances and actual installed conditions. NOTE: Halliburton makes no warranty, either expressed or implied, as to the accuracy of the data or of any calculation or opinion expressed herein. Halliburton, Dallas, Texas, U.S.A. • • ' , Ferguson, Victoria L (DOA) From: Chad Helgeson [chelgeson @hilcorp.com] Sent: Wednesday, October 10, 2012 1:59 PM To: Ferguson, Victoria L (DOA) Cc: Schwartz, Guy L (DOA); Harold Soule - (C); Stan Golis; Reid Edwards Subject: RE: Granite Pt 32 -13RD (PTD 192 -020, Sundry 312 -384) Attachments: 100006156_78LXE23105- P.PDF; WellStar Self -Eq Operation Procedure.pdf Victoria, 1. I was not planning to pump kill weight fluid down the well. The well is already dead with produced fluids in the well. Two weeks ago we bled the pressure off the well and have left it standalone. The well has built a total of 5 psi over this 2 weeks. We could pump 60 bbls of FIW down the well, (the tubing and casing would equalize through the gas lift mandrels if the fluid fell to the backside.) The well has been shut -in for several years and does not build up pressure. 2. Yes, a TWC can be used instead of a BPV. 3. I will add a step after the tubing patch is installed and the tubing hanger is landed to set a wireline plug in the x- nipple at 10,527'. We can then fill the tubing and casing and pressure test the tubing and casing to 2,500 psi. We will then have to change out a bunch of the gas lift mandrels and test the tubing independently from casing. If these fail we will have to repair the well in 2013 with the new workover rig we plan to bring up and install on the Granite Point platform. 4. The new SSSV will be a Halliburton Safety valve instead of the one I proposed last week on the proposed schematic. I have attached the information on the SSSV that will be installed. Let me know if you need any additional information for this project. Thanks Chad Helgeson From: Ferguson, Victoria L (DOA) j mailto: victoria.ferguson(aalaska.gov] Sent: Wednesday, October 10, 2012 4:21 PM To: Chad Helgeson Cc: Schwartz, Guy L (DOA) Subject: Granite Pt 32 -13RD (PTD 192 -020, Sundry 312 -384) Chad, Several questions are outlined below: 1. Do you plan to bullhead kill weight fluid in the well before pulling the tubing hanger? How will you verify the well is dead? 2. Would a TWC work better than a BPV in step 2? 3. Need a PT of the tubing /IA. 4. Do you have any information on the SSSV? Thanx in advance, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 1 ~1f~1fŒ lID~ ~~~~æ~ / AI IASIiA. OIL AND GAS / CONSERVATION COMMISSION I I August 24, 2004 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dwight Johnson Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verifications Granite Point State 32-13RD, PTD 192-020 Granite Point State 42-23RD, PTD 195-145 Dear Mr. Johnson: On August 20, 2004, AOGCC Petroleum Inspector Lou Grimaldi witnessed "no flow tests" for Unocal's Granite Point State Wells 32-13RD and 42-23RD located on the Granite Point Platform. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy. There was only a slight flow of gas and no liquid to surface during the tests. Based on the results of these no-flow tests, the subsurface safety valves may be removed from service in Wells 32-13RD and 42-23RD. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in each of the wells as required in 20 AAC 25.265. The subsurface safety valve must be returned to service in any well that demonstrates an ability to flow unassisted to surface. Please retain a copy of this letter on the Granite Point platform. Sincerely, ~ rg~ a James B. Regg ~ 1 Petroleum Inspection Supervisor cc: Bob Fleckenstein MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, 'J ~ P. I. Supervisor lW¡i ~IVJ lo~ DATE: August 20, 2004 THRU: FROM: Lou Grimaldi, Petroleum Inspector SUBJECT: No-Flow Test Unocal, Granite Point platform 32-13 Granite Point Field PTD #192-020 NON-CONFIDENTIAL Fridav. Auaust 20. 2004: I witnessed No-Flow verification on the Granite Point platform in the Granite Point Field, well #32-13. Following is a timeline and well status during test. 1115 Arrive location, Well 42-23 flowing to Crude Oil slop tank at 5 psi. Route to barrel. 1145 Flow well to barrel at bare whisper. 1200 Shut-in well at <1 psi. 1215 Open well to flow meter @ 800 scf. 1218 Well flowing gas at <180 scf. 1221 Well flowing gas at bare whisper. Shut-in @ <1 psi. 1310 Shut-in @ 3 psi, Open well to flow @ >1800 scf. 1315 Well flowing gas @ 750 scf & .5 psi. 1320 Well flowing gas at bare whisper @ <.5 psi. 1345 Well flowing gas at bare whisper @ <.5 psi. Shut-in well. 1445 Well shut-in @ 2.5 psi, Open well to flow @ 1700 scf. 1455 Well Flowing @ 400 scf & .5 psi. 1500 Well flowing @ bare whisper. 1530 Well flowing @ bare whisper. I turned well back over to production at this point. During this test there was no evidence of fluid made. SUMMARY: I witnessed No-Flow verification on UNOCAL's Granite Point Field well #32-13 on the Granite Point Platform. NON-CONFIDENTIAL CC: Dwight Johnson (UNOCAL) 6<;ANNED OCT 0 9 No-Flow GPF 32-13 08-20-04 LG.doc 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, 200!; 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. Summary; ! 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..ttachment: SVS Granite Point Pit. 05-10-01jc NON-CO,.NFID .E. NTIAL SVS Granite Point Pit. 05-10-01jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal 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 5/10/01 ............. ReteSt .... sssv Well type ii i i i ii _ Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number ,,Num,,ber ,psI .....PSI Trip, Code, ,, Code Code, ,Passed GAS.or CYCLE 11-13RD 1911330 60 40 33 P ..... 4 P "'°IL i3-13 ........ '1670210 .... 60 40 ..... 40 'ii. P 'P .......... OIL 31-13 1660550 31_ l'4RD2 1002660 .................................... 3'1-23 1670840~ ''60 ' 40' ' '4'0'i "P" ~ ....... oiL 32-13RD ~1926200~ 60" 40 ' 40! P e P ' " OIL 42-23RD 1951450 '60 ~0 34 'e e P........ 0IL 44-14 1670620 60 40 36 P e P OIL 50 19204i"0 '60 ..... ~6i''' 33' ' 'P ' 'P ...... 8 ..... OIL 51 '1920720 ' ~0 40 "'3'~' ' P P ' P ...... OI'L ~ ...... 1960130 "' 60 '" 40 ' '54 P P P .... OIL Wells: 9 Components: 26 Failures: 2 Failure Rate: 7.69% r'-] 90 Day Remarks: SSV on well 11-13 failed to hold DP. This gate valve will be serviced & re-tested. SS: ,.,o.,n we,,~ GP-50 f~afled t,0 clo..s,,e., Ted. Medley will contact Unocal Supervisors about AOGCC's ~ ,nce.m.,,.fo,r the~.,r, epair,& re-.test of,,,GP. 50's sssv.: ............... RJF 1/16/01 Page 1 ofl SVS Granite Point Pit. 5-10-01jc MEMORANDUM TO: Julie Heusser, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 7, 2000 THRU: Tom Maunder, P. I. Supervisor 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 Plt. 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, GINJ, 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 OIL 31-14RD2 1002660 31-23 1670840 60 40 35 P P OIL 32-13RD 1920200 60 40 35 P P P 42-23RD 1951450 60 40! 40 P P P OIL 44-14 1670620 60 40 35 P P e OIL 51 1920720 60 40 35 e P.., ~ OIL 54 1960130 60 40 36 P P P OIL Wells: 9 Components: 26 Failures: 2 Failure Rate: 7.7% [390 var Remarks: Well 31023 is a no flow. 12/13/00 Page 1 of 1 SVS Granite Point Plt. 12-07-00jc.xls THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 P M E E L E W A T E R IA L U N D ER TH IS M A R K E R C:LORILMFILM.~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Development: X 110' KB ABOVE MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: MOBIL STATE #1 P.O. BOX 196247 ANCHORAGE, AK 99519-6247 Service: 4. Location of well at surface LEG #3, SLOT #5 8. Well number 2390' S & 1379' E FROM NW CORNER SEC. 13, T10N, R12W, SM GRANITE POINT 32-13RD At top of productive interval 9. Permit number/approval number 3198' S & 3967 E FROM NW CORNER SEC. 13, T10N, R12W, SM 92-020 At effective depth 10. APl number 50- 733-20014-02 At total depth 11. Field/Pool 4236' S & 135' E FROM NW CORNER SEC. 18, T10N, R11W, SM GRANITE POINT TYONEK "C" 12. Present well condition summary Total depth: measured 12563' feet Plugs (measured) true vertical 10646' feet Effective depth: measured 12473' feet Junk (measured) true vertical 10606' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 654' 18-5/8" 668' Surface 2465' 13-3/8" 2506' 2485' Production 8374' 9-5/8" 8417' 8225' Liner 2626' 7" 1225 sx 15.8 ppg Class "G" 10822' 9963' Liner 2044' 5" 160 sx 15.8 ppg Class "G" 12559' 10645' Perforation depth: measured 10600-10680; 10680-10810; 10810-10850; 10850-11020; 11120-11235; 11322-11524; 11611-11914; 11986-121 46 true vertical 9853-9893; 9893-9957; 9957-9975; 9975-10046; 10085-10130; 10162-10234; 10264-10372; 10401-10468 Tubing (size, grade, and measured depth) 2-7/8" 6.4~ N-80 {~ 10560' MD Packers and SSSV (type and measured depth) Baker SAB-3 Pkr @ 10453' MD: Baker SSSV @ 302' MD 13. Stimulation or cement squeeze summary Inter~als treated (measured) ORIGINAL Treatment description including volumes used and final pressure ' 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 10/18/96 652 468 6 720 110 Subsequent to operation 11/3/1996 647 558 8 700 125 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: XX Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE UNOCAL ) RKB = 110' GRANITE POINT PLATFORM WELL # 32-13rd CURRENT COMPLETION CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 18-5/8" 70.7 B 0 13-3/8 54 J-55 BTC 0 9-5/8 43.5/47 N80/S95 BTC 0 7" 29 N-80 BTC 8,188 5" 15/18 L-80 BTC 10,500 2-7/8" 6.4 N-80 BTC 0 668 2,506 8,417 10,824 12,561 10,560 TOL ~ 8,188~ TOL ~ 10,500' ETD = 12,473' TD = 12,563' MAX HOLE ANGLE = 69° ~ 11,453' JEWELRY DETAIL NO. ITEM DEPTH TOP 10,600 10,680' 10,810' 10,850' 11,120' 11,322' 11,611' 11,986' FMC Tubing Hanger 43.85' BAKER "FVGE" SSSV 302' Camco "KBMG-2" Gas Lift Mandrels: 1239', 1986', 2763', 3288', 3810', 4309', 4837', 5339', 5836', 6359', 6855', 7388', 7922', 8424', 8986', 9553', 10398' OTIS "XA" Sliding Sleeve BAKER SAB-3 Packer OTIS "X" Profile Nipple BAKER SHEAR SUB 10413' 10,452' 10,527' 10,560' PERFORATION DATA BTM ZONE SPF DATE COMMENTS 10,680 C-5 4 10/31/96 WLP 10,810' C-5 4 4/1/95 WLP 10,850' C-5 4 10/31/96 WLP 11,020' C-5 4 4/1/95 WLP 11,235' C-5 4 5/18/92 TCP 11,524' C-5 4 5/18/92 TCP 11,914' C-5 4 5/18/92 TCP 12,148' C-5 4 5/18/92 TCP O :~2)RILLING\S CHEMATIC\GP\GPP\3213 ACT.DOC REVISED: 11/4/96 DRAWN BY: PAR Granite Point 3 2-13 rd Coiled Tubing Cleanout and Perforation Addition Summery of Well Operations 10/24/96 10/25/96 10/26/96 10/27/96 10/28/96 10/29/96 10/30/96 10/31/96 CENTERED RIG OVER GPP 32-13RD. RIH W/2.25" BAILER & TAGGED 10827'. POOH W/BAILER, NO RECOVER. RELEASE WELL TO PRODUCTION. RU COILED TUBING UNIT. NU & BOP & RISER. PULL TEST COIL. PRESSURE TEST BOP, RISER & COIL TO 5000 PSI. RIH W/2.3" MILL & 2-1/8" MOTOR ON 1.5" COIL PUMPING DIESEL ~ .3 BPM TO 10750'. INCREASED CIRCULATION RATE TO 1 BPM & WASHED TO 10,900'. LOST FULL RETURNS WHEN RATE INCREASED TO 1 BPM. WELL LOADED UP & DIED. RIH W/ PUMPS OFF & TAGGED ~ 10,885'. POOH. RD COILED TUBING UNIT. RU & TEST SLICKLINE LUBRICATOR. RIH W/2.25" BAILER & TAGGED FILL ~ 10,867'. ATTEMPT TO BAIL THROUGH BRIDGE W/O SUCCESS. POOH & RD SLICKLINE. WAIT ON GUNS. RU WIREL1NE & TEST LUBRICATOR. RIH & PERFORATE TYONEK C-5 F/10810' - 10850', 10600' - 10680' W/2-1/8" 0° PHASED 4 JSPF RETRIEVABLE STRIP GUNS PHASED 30° FROM MAGNET. 11/1/96 RD WIRELINE & RELEASED WELL TO PRODUCTION. Unocal Corporation Oil 8, Gas Operations 909 West 9th Avenue, P.O. ~ox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 U NOCA e ,ber 995 Alaska Ms. Joan Miller Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Ms. Miller: ORIGINAL Re: Granite Point State 32-13RD APl Number 50-733-20014-02 On April 1, 1995 the following intervals were perforated in Well GP 32-13RD: BENCH INTERVAL (MD) INTERVAL (TVD) C5 10,680-10,810 9893-9957 C5 10,850-11,020 9975-10,046 FEET 130 170 Total 300 Very truly yours, Candace Williams RECEIVbL DEC 2 9 1995 Ala~k~ Oil & G~ (;one, CO!'r~Tlis~ion A~chorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM~v~ISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator Operations performed: Operation shutdown Stimulate Plugg_~ ...- Pull tubing After casin~ Repair well 5. Type of Well: Development x UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Exploratory 3. Address Strafigraphic P.O. BOX 196247 ANCHORAGE~ AK 99519 - 6247 Service 4. Location of well at surface Conductor #3-5 2390' S & 1379' E from NW corner Sec. 13 T10N, R12W, SM At top of productive interval 3198' S & 3967' E from NW comer Sec. 13 T10N, R12W, SM At effective depth 12. At total depth 4236' S & 135' E from NW comer Sec. 18, T10N, R11W, SM Present well condition summary Total depth: measured 12563 feet true vertical 10646 feet Plugs (measured) Perforate X Pull tubin~l Other 1)~tum elevatiOn (DF Or ~) ~!.SL 7. Uni{ dr r~ ~p~e 9. Permit number 92-020 10. APl number 50-733-20014-02 11. Field/Pool Granite Point Tyonek "C" feet Effective depth: measured 12473 feet Junk (measured) t~ue vertical 10606 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 654' 18" 668' Surface 2465' 13-3/8" 2506' 2485' Intermediate Production 8374' 9-5/8" 8417' 8225' Liner 2626' 7" 1225 sx 158 PPG Class G 10822' Liner 2044' 5" 160 sx 158 PPG Class G 12559' Perforation depth: measured 10680-10810'; 10850-11020'; 11120-11235'; 11322-11524'; 11611-11914'; 11986-12148' true vertical 9893-9957'; 9975-10046'; 10085-10130'; 10162-10234'; 10264-10372'; 10401-10488' Tubing (size, grade, and measured depth) 2-718", 6.4#, N-80 @ 10560' MD Packers and SSSV (type and measured depth) Baker SAB-3 Pkr. (~ 10453' MD 9963' 10645' RECEtV 13. Stimulation or cement squeeze summary DEC 2 Intervals treated (measured) Alaska 0il & Gas Cons. Co~ Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data Tubing Pressure Prior to well operation 3~28~95 620 1289 5 688 125 Subsequent to operation 4/6/95 754 1143 2 690 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil X Gas Suspended 17. I hereby certify that the fore ~g~y t~ue(~a~ cerre~ct~_, to the best., of my knowledge. I Signed G. Russell Schmidt"--~:;::~~...-'" ~ltle Drilling Manager Form 10-404 Rev 06/15/88 130 Service Date i Z [ Z C,[c~ SUBMIT IN DUPLICATE ~ission ~' Cor/ducior 15 10499.5 - 10508,1' LOCAJOR JOB' Brown BR od,nj SJeeve 81965 - 10822.2' i/'' OB 29,00t/ft 14 80 LINER 10022,z 1082t0' rLOAhHC? kker 'V" , { PtLO 125611.0 CMN? ?L06 5/92 125155 - '~ !2559.0 12561.0' FLOATSNOE B~owr~ V (~raniie Poir~i Fksid APl 50 7,55 20014 02 TD: I,~56,) 47.9 104/fi.l? N75" OD 6.40~/ft N-80 TB6 !., 0[i' ~" 10680,0 10810.0' PER5 C-8, 4/i/95, 4HPF, 50', 2//8" ~iiver ,iei O~ns, 0 Ph 10559.7- 10560.4 3.51FI O~} 2.44/' [[5 SHP, BUB kker 10850.0- 11020.0' PERFS C-S, 4/1/95, 4BPF, 17% 2 I/8" Silver ,lei Guns, 0 ?h 11322.0- 11524? PERF5 C 5, 8/5/% dPf, 202', Baker .5 3/? TCP Gurus 11611.0 11914.0' Pd!5 C-S, 5/lu/9~_, 4HPF, 3015, Bob ,5 3/? fOP Guns 11986.0 12148.0 P_RF8 ~ I~, 5/5/9, 4BPF, 162', Bekel 3 3/? %P Guns DEC 29 1%95 Oil & Gas Cons, Commissior~ Per'd On4 PERMIT 92-020 92-020 92-020 92-020 92-020 92-020 92-020 92-020 92-020 92-020 92-020 92-020 92-020 92-020 92-020 92-020 92-020 92-020 92-020 92-020 92-020 92-020 DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS BD/GR CAL CET/CBT/GR DP/NP/DPR/GR DP/NP/DPR/GR DPR/GR DPR/GR DPR/GR L 8770-10240, MD L 10600-12501, ST#1 L 8370-10740, ST#1 L 8770-10240, MD L 8770-10240, TVD L 10157-10828, MD, ST#1 L 10157-10828, TVD, ST#i L 8770-10240, MD LDT/CNL/GR MUD MUD DPR/NP/GR/PHOTO L 8770-10240 L 10600-12501, ST#1 L 8450-10267 L 9350-12563, ST#1 MUD-CHROMATOGRPY L 8450-10267 PIL/GR PIL/GR 407 DAILY WELL OP REPORT SURVEY DRY DITCH 5313 5314 L 10600-12544, ST#1 L 10600-12544, ST#1 R COMP DATE: 05/18/92 R 03/12/92-05/18/92 R FINAL WELL R 0-12563, GCT $ 8450-12563, SS#851 T 10546-12593, OH-EDIT T 8412-10832, OH-TCOM/RWD Page: 1 Date: 04/11/94 RUN DATE_RECVD 3-9 07/02/92 1 07/02/92 1 07/02/92 3-9 07/02/92 3-9 07/02/92 13-4 07/02/92 13-4 07/02/92 3-9 07/02/92 3-9 07/02/92 1 07/02/92 07/02/92 07/02/92 07/02/92 1 07/02/92 1 07/02/92 09/21/92 09/21/92 05/26/92 07/02/92 07/29/92 1 07/02/92 13-4 07/02/92 AOGCC Individual Well GeoloGical Materials Inventory PERMIT DATA T DATA_PLUS Page: 2 Date: 04/11/94 RUN DATE_RECVD Are dry ditch samples required? yes no And received? 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 yes no Unocal North Americar, Oil and Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99579-0247 Telephone (907) 276~7600 UNOCAL ) DOCUMENT TRANSMITTAL November 4, 1992 Alaska Region TO: Mr. Larry Grant FROM: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Richard L. Stewart Unocal Corp. P. O. Box 196247 Anchorage, AK 99519-6247 Dear Sir: Herewith are the missing dry-cut sample intervals from wells Granite Point 32-13RD and 32-13RD ST1 (see attachment). I am at a loss to explain their absence from the sample set sent you in July. The samples enclosed were cut from samples in the file set sent to our research lab in Brea, CA. It should be borne in mind that several of these intervals were logged while drilling out cement or sidetracking, and may be of limited value. Transmitted herewith are the following samples: Unocal, Granite Point 32-13RD' 9250-9260' 9300-9310' 9310-9320' 9320-9330' 9330-9340' 9340-9350' 935O-936O' 9360-9370' 9390-9400' 9400-9410' Unocal, Granite Point 32-13RD St1' 942O-9430' 11280-11290' 11730-11740' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TR MITT I~ U. RECEIVED BYe_ ~_ _~,/_///~..,~_~ DATED: / " Naska uii & 6~ Cc.-.s. 60remission Anchorage ~ ~-~ STATE OF ALASKA ~ ~' '~ ALAS', '}IL AND GAS CONSERVATION CON ;SION '::' ~' ' ~ W, ELL COMPLETION OR RECOMPLETION REPORT AND LOG 1--Status of Well Classification of Sen/ice Well 2. Name of Operator 7. Permit Number UNION OIL OF CALIFORNIA ( d.b.a. UNOCAL) LOC. ATIQI~ 92-20 3. Address ~[~1 8. APl Number 909 W. 9th BOX 196247 ANCHORAGE, AK 99519 ~',~ J~') 50-733-20014-02 4. Location of well at surface 10~ t ~, I~ ~ 9. Unit or Lease Name 3198' S & 3967' E FROM NW CORNER SEC 13, T 10N, R 12W, S.M. GRANITE POINT 32-13RD At Total Depth [' 'V_ERJ~IF.~ ' i 11. Field and Pool 4236' S & 135'E FROM NW CORNER SEC 18, T 10N, R 1 lW, $.M. ~~i GRANITE POINT TYONEK C-3 SAND 5. Elevation110' RTin ABOVEfeet (indicateMSL KB, DF, etc.) 6. LeaseADL 1Designati°n8761 and Serial No. 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 3-14-92 5-9-92 5-18--92I 75' Feet MSLI SINGLE 17. Total Depth (MD+TVD)i 2563/10646' 18. Plug Back Depth (MD+TVD)12473/10606' YES19' Directional Sa rve~_~[] NO L_J 120' Depth where SsSv set302-5' feet MD 121 ' Thickness of Permafr°stNA 22. Type Electric or Other Logs Run DITE, LDT, CNL, GR, CBT, CET 23. CASING, LINER AND CEMENTING RECORD ,. CASING SIZE WT. PER FT. GRADE TOP I BO'I-rOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 18" 70.69 B 0' 668' 22" 13 3/8" 54 J-55 0' 2506' 16" 9 5/8" 43.5/47 N80/S95 0' 8417' 12 1/4" 7" 29 N80 8188' 10824' 8 1/2" 1225 SX 15.8 PPG CLASS"G" 5" 18/15 L80 10500' 12561' 6" 160 SX 15.8 PPG CLASS"G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD inten/al, size and number) SIZE I DEPTH SET (MD) I PACKER SET (MD) 2 7/8" 10560' 10452' MD TVD FT FT 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12148-11986' 10468-- 10401' 3 3/8" 32 GRAM DEPTH INTERVAL (MD) I AMOUNT & KIN D OF MATERIAL USED 11914-11611' 10372--10264' 4 SHOTS PER FOOT 11524--11322' 10234-10162' NA 11235-11120' 10130-10085' 27 PRODUCTION TEST Date First Production [ Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOF OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED SE P 1 Alaska 0il & Gas Cons. C0m~ss~°~ Anchorage Form 10-407 rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. P,.ECEIVED SEP 9 Alaska 0i[ & Gas Cons, 31. UST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · _A _.-N, INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records forthis well should show the details of any multiple stage cement- 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. Item 28: If no cores taken, indicate 'none". - i TUBING DETAIL' RKB 110' 1i - , 2-7/8", 6.4#, N-80, BUTT -- 2 ALL TUBING DEPTHS ARE TBG DETAIL TOPS 18-5/8"@ 668' -- 70.7# GRD B __ 1) DOT "FVGE" TBG. RET. SSSV @ 302' -- 2) CAMCO "KBMG-2" GAS LIFT MANDRELS (17) 13-3/8. @ 2506' 54# J-SS I-- 1) 1239' 2) 1986' .3) 276,3' 4) 5288' iZ 5) 3810' 6) 4309' 7) 4837' 8) 5339' I-- 9) 5836' 10) 6359' 11) 6855' 12) 7388' l-- 1,3) 7922' 14) 8424' 15) 8986' 16) 955,3' 17) 10598' , '~ 3) OTIS "XA" SLEEVE @ 10413' ~ I 4) DOT "SAD-3" HYD. PERM PACKER @ 10452' 10560' i I 9-5/8" @ 8417' 43.5# N-80 & 47# S-95 3 i ,:>-<: RECEIVED 7" L F/8188'--10824',~ I--I 5 S E P 2 1 1992. , 29#, N80 : ,Alaska 0il & Gas Cons. 6ommissio~ Anchorage 6 TYONEK C-3 INTERVALS (782') -- 11120'- 11235' MD DIL :-- 11522'- 11524' MD DIL z- 11611'- 119 14' MD DIL ' 1 1986'- 12 148' MD DIL I 5"15#L &F/ 18# 10500 L80'- 12561 ~, ETD 11475', LANDING COLLAR WELL GP 52- 1.3 Redrill DRAWN- CLL ACTUAL COMPLETION SC~E: N/A UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DATE: 9-17-92 Unocal Drilling/Workover Record Alaska Region Lease: Unocal-Mobil State Well: GP 32-13 Field: Granite Point Date: ETD: Details of Operation 03/12/92 8585' 03/13/92 03/14/92 03/15/92 8468' 03/16/92 8419' 03/17/92 8439' RECEIVED S EP 1 1992 Alaska Oil & Gas Cons. CommiSSio Anchorage At 1200 hrs begin preparation to skid PAA Rig #431 from well #11-13 to #32-13 RD. Build mud volume of 775 bbls of EZ Mud-DP. Nipple down tree and install BOPE. Note: FMC wellhead requires both alignment pins and one hold down pin to be replaced, bowl condition is fair. Plan to replace items after run and cement 7" liner. Test BOPE. Held "Fire and Abandon Platform" drills. RIH with 8-1/2" bit and 9-5/8" casing scraper (SLM), tag retainer at 8585'DPM. Displace wellbore fluid with 9.5 ppg mud. Pressure test casing to 1000 psi, ok. POOH. POOH. Rig up Schlumberger and run CBT/GR from 8611' ETD to 7100' DIL. Estimate TOC at 7310'. DIL to DPM is 26' greater. POOH. Run Scientific gyro tool from 8583' to surface. RIH with TIW 9-5/8" whipstock packer on wireline and set same at 8468' WLM. POOH. RIH with single shot directional survey and gyro packer key. POOH. RIH with TIW orientation stinger, whipstock (3 degree face), and milling assembly on drillpipe. RIH to 8466' and attempt to latch into packer key, negative. POOH. Change out orientation stinger and RIH to packer at 8468' WLM. Latch packer, shear off whipstock and ready to mill casing window. Mill casing from 8417' to 8419'DPM. POOH. RIH with window mill and watermelon mill. Continue milling casing from 8419' to 8439'. CBU. POOH. Change out milling assembly. Unocal Drilling/Workover Record Details of Operation, Descriptions/Results Page 2 Date: ETD: Details of Operation 03/18/92 8492' 03/19/92 8737' 03/20/92 8991' 03/21/92 9443' 03/22/92 9511' 03/23/92 9622' 03/24/92 9751' 03/25/92 9948' 03/26/92 03/27/92 RIH with mill dressing assembly. Dress window from 8417'-8439'. Perform LOT to 16.7 ppg EMW. POOH. Make up BHA #6 (first drilling BHA) a one degree steerable motor and RIH. Directional drill 8-1/2" hole from 8439' to 8492'. Directional drill 8-1/2" hole from 8492' to 8737'. Drilled 8-1/2" hole to 8798'. POOH. Make up BHA #7 (steerable motor, triple combo LWD tool, and PDC bit). RIH and wash hole from 8770' to 8798'. Directional drill and LWD 8-1/2" hole from 8798' to 8991'. Drill 8-1/2" hole from 8991' to 9229'. Short trip to 8398' hole conditions good RIH and ream from 9204'-9229'. Drill from 9229' to 9443'. Drill to 9509'. Unable to effectively slide steerable motor, POOH. Replace PDC bit with another PDC bit and RIH to 9355'. Re-log interval from 9355'-9509'. Directional drill 8-1/2" hole from 9509'-9511'. Drilled 8-1/2" hole from 9511'-9622', unable to slide motor. POOH. Make up BHA #8 and RIH. Ream from 9554'-9622'. Drilled 8-1/2" hole from 9622'-9751'. POOH. POOH. Make up BHA #9 and RIH to 9751'. Directional drill and LWD 8-1/2" hole to 9948'. 10096' Drilled to 10096'. POOH. 10193' POOH. Make up BHA #10 and RIH. Directional drill and LWD 8-1/2" hole from 10096'-10193'. POOH. Make up BHA #11. RECEIVED S E P 2 1 1992 AlasAa Oil & Gas cons. commis ' ou :Anchorag= Unocal Drilling/Workover Record Details of Operation, Descriptions/Results Page 3 Date: ETD: Details of Operation 03/28/92 03/29/92 03/30/92 03/31/92 04/01/92 10193' RIH and relogged with LWD from 8429'-8795'. Ream from 8795'-9954' and logged with LWD from 9600'-9954'. Continued reaming to 10193'. POOH. Tight spots at 9990' and 9956'. Ream back to 10193'. Completed reaming to 10193. POOH to 9587' tight spots from 9987' to 9783' Reamed .from 9587'-10193'. Circulate high viscosity sweep. POOH. Test BOPE. Make up BHA #12 and RIH. 10270' RIH to 9776' tight, circulate down to 10193'. Orient motor and directional drill 8-1/2" hole from 10193'-10270', stuck BHA while picking up to stroke the drillstring, bit depth at 10268'. Jar BHA indicating free above jars, remaining BHA completely in sand. Rig up wireline and run free point survey to 10149'DPM. POOH. RIH with string shot. 10089' Fired string shot at 10119' DPM and pulled free with 340K#, POOH with wireline. Circulate BHA and POOH. Backoff occurred 30' higher in BHA than expected, TOF at 10089' DPM. RIH with screw-in sub and engaged TOF at 10084' DPM. Jarred on fish for three hours without success. RIH with free point survey, hit obstruction at 10036' WLM. POOH. RIH with bumper jars and jarred through obstruction (easily) to 10186' (inside Teleco LWD tool). RIH with free point survey, free at 10123' WLM. POOH. RIH with string shot to 10123' WLM and fired same. Worked pipe free and circulated. 10113' POOH. Recovered crossover sub and one steel drill collar (32.54'). Pick up wash pipe and cripple type shoe and RIH to 9919', tight. Ream and wash to 10113' DPM (TOF). Attempt to wash over fish without success, high torque. POOH. Alaska Oil & Gas Cons. 8om~'-t~-~'~ Unocal Drilling/Workover Record Details of Operation, Descriptions/Results Page 4 Date: ETD: Details of Operation 04/02/92 10113' 04/03/92 9985' 04/04/92 POOH. Examine shoe, wear indicated TOF was inside approximately 14". Entire shoe itself was severly worn. Made up new cripple shoe and RIH. Wash from 10019'- 10113' TOF. Attempt to washover TOF without success. POOH. Make up cut lip shoe, one joint of washpipe and one joint of HWDP. RIH to 10113', rotate over TOF to 10133' slackoff to 10144' without trouble. Pull up off TOF and re-engage TOF, no problem. CCM. POOH. Make up new cut lip shoe and pick up three joints of washpipe. RIH to TOF at 10113' DPM, wash over TOF to 10169'. Rotate over fish from 10169' to 10202'. Screw into TOF with screw-in sub, attempt to establish circulation, negative. Jar on fish without success. Perform blind backoff and POOH. Back off occurred at 9985' TOF. 10098' Make up screw-in sub, RIH and screw into TOF at 9985'. Run free point survey, unable to pass obstruction at 10099'. POOH. RIH with spring jars and attempt to jar past fish, negative. POOH. RIH with string shot to 10098'. Perform back off and POOH. TOF at 10098' bottom of fish is at 10268' Agreed to plug back hole to new KOP. F~sh left in hole (F/bottom to top) is as follows; Reed bit (.80'), Drilex motor (20.76'), float sub (1.45'), Teleco triple combo tool with directional, resistivity, gamma ray and neutron porosity (radioactive source) (68.82'), monel DC (28.5'), DC (29.83'). Overall length of BHA is 150.16'. Screwed into the TOF is wash pipe with a screw-in sub, overall length is 104.28'. Prepare to plug back open hole interval. RECEIVED SEP 1 Alaska Oil & (~as Cons. Gommiss'~o~ 'Anchorage Unocal Drilling/Workover Record Details of Operation, Descriptions/Results Page 5 Date: ETD: Details of Operation 04/05/92 04/06/92 10018' 04/07/92 9809' 04/08/92 9065' Pick up tubing tail and RIH on drill pipe to TOF at 10098'. CCM. Prepare to cement. Mix and pumped a balance plug from 10098'-9448' with 258 cu.ft, of 17 ppg cement. CIP at 0730 hrs. Slurry contained iron oxide to color it red, a stipulation to abandon the RA source in the hole. POOH. Test BOPE. Make up BHA #20 and RIH to 8233'. RIH to 9716' encounter no cement. CBU. RIH to 9922' and tagged soft cement stringers to firm cement at 10018'. CBU. POOH. RIH with tubing tail to 10018'. Mix and pump balanced plug from 10018' to 9257' with 298 cu.ft, of 17 ppg cement slurry. CIP at 1654 hrs. POOH. Make up BHA #20. RIH to 9580, encountered no cement. CBU, returns were green cement contaminated. Pull to 8375' and WOC three hours. RIH and circulate to 9803' firm cement Drilled firm cement to 9809'. Pull to 9745', stuck BHA and jarred loose. Loss 700 psi of pump pressure. POOH. Lost in hole is 19.83' of Drilex mud motor and .80' drill bit. Estimate TOF at 9722'. Pick up tubing tail on drill pipe and RIH. RIH to 9810', never tagged TOF. CBU and pull to 9782'. Mix and pump balance plug with 421 cu.ft, of 17 ppg cement. CIP at 0650 hrs. Pull to 8392' and CCM. POOH. Make up BHA #22 and RIH. Wash down from 8572' to 9048' firm cement Drilled · cement from 9048'-9065'. CBU. RECEIVED S E P Z 1 1992 Alaska Oil & Gas Cons. 'Anchorage Unocal Drilling/Workover Record Details of Operation, Descriptions/Results Page 6 Date: ETD: Details of Operation 04/09/92 9380' POOH· Make up BHA #23 and RIH. Orient motor and drilled to 9067' and bottom of cement fell out. RIH searching for TOC, encountered soft to firm cement from 9148' to 9201' Orient motor and attempt to drill, difficulty sliding BHA. Cement seems to be inconsistent and intermitent. Chase cement to 9380', still soft and not ~~~~ encouraging. From 9300' to 9380', pick up weights required 90K to 150K overall pull. POOH from 9380', tight up to 9025'. Once S~P ~ ~ ~9~ inside the casing shoe the SCR generator .~,aska 0i~ ~ Gas Gone. ~0~m~$$~0~ bay #2 overheated and breaker failed to trip. This caused a small fire resulting ~n~o~8 in loss of all rig power supplied via the SCR unit. 04/10/92 9406' Completed repairs of SCR unit and re-established generator bays #1,3 & 4. POOH. Make up BHA #24 (rotary c/out assy) and RIH to 9035'. Reamed and washed down to 9388', drilled to 9400'. Short trip to 8817' RIH and drilled to 9406' CBU , · · Pull to 8417', dump and clean active mud pits and mix new mud. 04/11/92 9540' Completed building new mud volume and RIH to 9406'. Displaced entire wellbore with new 9.3 ppg mud and CBU. POOH. Make up BHA #25 (1.25 deg bent housing motor) and RIH to 9406'. Orient motor and drilled 8-1/2" hole off of cement plug to 9540'. 04/12/92 9638' CBU. POOH. Test BOPE. Make up BHA #26 (1 deg steerable motor) and RIH. Ream from 9505' to 9540' orient motor and directional drill 8-1/2" hole from 9540' to 9638'. 04/13/92 9772' Drilled from 9638' to 9772'. CBU. POOH, tight first two stands off bottom, pulled good rest of way. Make up BHA #27 and RIH to 8413'. 04/14/92 10069' Continue to RIH, ream 9717 '-9772 ' . Directional drill from 9772 ' to 9987 ' . Short trip to 9340', tight with 30-90K overpull, back ream ledge at 9540'. RIH and drilled to 10069'. Unocal Drilling/Workover Record Details of Operation, Descriptions/Results Page ? Date: ETD: Details of Operation 04/15/92 10270' Directional drilled from 10069' to 10270'. CBU. POOH to 9335', slight flow. RIH to 10270, CBU, 360 units of trip gas. Observe well, slight flow. Increase mud weight to 10 ppg. 04/16/92 10333' POOH. Make up BHA #28 and RIH, ream from 10054'-10270' drilled 8-1/2" hole to 10330'. Short trip to 9867' , RIH and drilled to 10333'. 04/17/92 10539' Drilled 8-1/2" hole from 10333'-10516', short trip to 9310' drilled to 10539' , · 04/18/92 10651' Drilled 8-1/2" hole from 10539'-10651', top of "C-3" estimated at 10613'. CBU. POOH, download logging data from MWD tool. Pressure test BOPE, bottom VBR pipe rams failed test. 04/19/92 10830' Trouble shoot pipe ram, change out top seals and test, ok. Make up BHA #29. RIH and ream from 10405'-10651'. Drilled 8-1/2" hole from 10651'-10830'. CBU. 04/20/92 POOH to 7185' observe well, slight flow RIH to 10800' CBU Circulate and increase mud weight to 10.4 ppg. POOH, tight at 10265', 10053', 10021' and at 30' intervals to 9842'_ Stuck pipe with bit at 9842' after pulling into tight spot with 100,000# overpull. Jar down on stuck pipe with negative results. Mixed and spotted 17 bbls of mineral oil EZ spot pill. Jar on stuck pipe and move pill. RU wireline for free point survey. 04/21/92 RIH with FP survey, unable to get below crossover between NMDC and HWDP. Survey indicated free at 9705'. POOH. Jar on stuck pipe and move pill. RIH with string shot and set down at 9772' stuck wireline ~~i~ ~ ~ tools in MWD. Fired string shot and freed wireline tools. POOH. RIH with string shot #2. Performed backoff with S.S. at S~P ~ ~99~ 9735'. POOH with WA tools. Pull to 9442' ~aska0i~&GasO0n$.~°mm~S~°~ and CBU. POOH. MU fishing tools and RIH. Unocal Drilling/Workover Record Details of Operation, Descriptions/Results Page 8 Date: ETD: Details of Operation 04/22/92 10830' RIH and tag TOF at 9732'. Screw into fish and jar down knocking fish loose. Pull to 9772' and CBU. POOH. Lay down BHA, MU cleanout BHA and RIH. Wash and ream from 9309' to 9873'. 04/23/92 Continue to wash and ream to 10830'. CCM. POOH, tight at 9982' and stuck BHA. Work BHA and jar same loose. POOH. Lay down HWDP and BHA. Change rams to 7" and function test. RU and run 61 joints of 7" 29# N-80 casing with TKC buttress couplings with 7" Brown three cone Hyflo II hydraulic hanger and hydraulic set liner top packer. 04/24/92 8188' RIH with liner to 8138', make up swivel and plug dropping head on DP stand. Perform rotating and reciprocating torque test. RIH with liner, wash and ream liner from 9874' to 10830' extremely difficult. Circulate liner clean while rotating and reciprocating. RU DS cement lines and test same to 4700 psi. Mix and pump the following: 8 bbls water, 50 bbls of 12.5 ppg Mudpush spacer, 253 bbls (1225 sx) of 15.8 ppg class "G" cement slurry with additives, drop plug, 5 bbls water and displaced with mud using rig pumps. At 92 bbls of displacement a pressure packoff occurred and simultaneously unable to rotate and reciprocate liner. Pressure up to 2500 psi and set liner hanger (pinned for 2350 psi), elected not to set liner top packer (LTP). Safety released off hanger and pulled up 4' to 8184' and reversed circulated out 38 bbls of good cement. Top of liner at 8188' with shoe at 10824'. POOH. Offload 3-1/2" DP from work boat. 04/25/92 8933' PU DP and RIH. Tagged cement at 8189', clean out cement to 8197' (drillable packoff). Continue to clean out cement from 8197' to 8217'. Pressure test (positive) liner lap to 3000 psi (limitation on 9-5/8" csg) and held for 30 minutes,liner fromOk'8217Drill'-8933 out,. cement inside 7" Unocal Drilling/Workover Record Details of Operation, Descriptions/Results Page 9 Date: ETD: Details of Operation 04/26/92 9544' Drill cement to 8957'. POOH. MU mill and PU HWDP. RIH and drilled cement from 8957'- 9544'. 04/27/92 10347' Continue to clean out cement inside 7" liner from 9544'-10347'. 04/28/92 10730' Drill cement from 10347'-10730'. Circulate clean and pressure test casing/liner lap to 3090 psi for 30 minutes, ok. POOH. Test BOPE. 04/29/92 Make up dressing mill and RIH to TeL at 8190'. Dress TeL and tie-back sleeve. POOH. RIH with test assembly, dry test liner lap to 700 psi, test indicated slight leak. Establish breakdown of formation at 4150 psi, pumped 0.9 BPM at 2850 psi. Engage TeL, pressure up to 4500 psi and hydraulic set liner top packer. Attempt to re-establish breakdown, pressure to 4500 psi for 30 minutes, ok no leak off. POOH. 04/30/92 10814' POOH. Make up BHA #36 (c/out assembly) and RIH to 10731'. Drill landing collar, cement and float collar to 10814'. Circulate and clean active mud tanks. Mix and conditioned mud. 05/01/92 10901' Continued to mix mud. Pumped 50 bbls of water spacer and changed the well over to 9 ppg PHPA mud. Cleaned cement, and shoe, from 10814'-10,835'. Circulated. POOH. RIH with BHA # 37 (steerable motor). drilled 6" hole from 10,835'-10,901'. 05/02/92 11406' Drilled 6" hole from 10,901'-10,925'. POOH and reamed from 10,824'-10,925'. Drilled 6" hole from 10,925'-10,964'. Tripped for a BHA. RIH with BHA #38. Drilled 6" hole from 10,964'-11,046'. 05/03/92 11237 ' Drilled 6" hole from 11,046 '-11,165 ' . Circulated. Tripped for BHA. RIH with R~E~VED BHA #39 drilled 6" hole to 11,237'. $ E P 1 1992 Alaska Oil & Gas Cons. Commissio~ Unocal Drilling/Workover Record Details of Operation, Descriptions/Results Page 10 05/04/92 05/05/92 05/06/92 05/07/92 05/08/92 05/09/92 05/10/92 05/11/92 05/12/92 SEP 1 Alaska 0il & Bas Cons. 'Anchorage 11386' Drilled 6" hole from 11,237'-11,263'. Circulated. Tripped for BHA. RIH with BHA #40. Drilled 6" hole to 11,386'. 11532' Drilled 6" hole from 11,356'-11,532'. Circulated. POOH for bit. Tested BOPE to 5000 psi, OK. RIH the same BHA, BHA #40. 11778' Cont'd RIH with BHA #40. Drilled 6" hole from 11,532'-11,778'. Circulated. 11993' Cont'd to circulate. POOH for a bit. RIH and drilled 6" hole from 11,778'-11,993'. 12201' Drilled 6" hole from 11,993'-12,180'. Circulated. Trip for bit. Drilled 6" hole from 12,180'-12,201'. 12563' Drilled 6" hole from 12,201'-12,563'. Circulated. POOH. 12563' Cont'd to POOH. RIH with drill pipe conveyed TLC open hole logs. Rigged up the side entry sub. Pumped the wireline and wet connect to the latch. Logged from 10,613'-12,550' with phasor induction, LDT, CNL, and GR log. Logged going up and down. Pulled free from the wet connect latch. POOH with wireline. POOH with the drill pipe conveyed logs. 12563 ' Cont'd to POOH. Rigged up a lubricator. RIH with a CBT/CET log and logged from 10,220'-10,560', good bond. Rigged down wireline. RIH with a reaming assembly and reamed from 12,367'-12,563'. Circulated. POOH. 12563' Cont'd to POOH. RIH with two joints of 5" 18# L-80 casing and 50 joints of 5" 15#, N-80 casing. Ran a Baker Model H Liner top packer, Baker Hyflo II hydraulic liner hanger, and a Baker model HR hydraulic disconnect with a 6' extension. RIH and tagged bottom. Pumped 27 bbls of mud push, pumped 160 sx of 15.8 ppg class "G" cement with additives. Displaced cement with mud. Pressured up to 2500 psi to set the liner hanger, pressured up to 3500 psi to set the packer. Pressured up to 3700 psi in an attempt to shear off the release, the tool did not release. Released from the tool by turning to the left to back off. Reverse circulated. Unocal Drilling/Workover Record Details of Operation, Descriptions/Results Page 11 5/13/92 5/14/92 5/15/92 5/16/92 5/17/92 5/18/92 12475' POOH. Tested BOPE to 5000 psi. RIH with BHA #45, 4" mill, 7" casing scraper, 9- 5/8" casing scraper. Pressure tested the casing to 3000 psi. Rotated through the hanger assembly. RIH and tagged the landing collar at 12,475'. Circulated. Changed hole over to drill water. 12475' Cont'd to change over to drill water. Cleaned the mud tanks and changed over to filtered 3% KCl (55 NTU). POOH. 12475' Cont'd to POOH. RIH with Baker 3-3/8" "TCP" perforating guns and packer. Set the perforating packer at 10,351'. Filled the drill pipe to achieve a 1000 psi underbalance. Fired the guns by pressuring up on the annulus, perforated; 12,148'-11,986', 11,914'-11,611', 11,524'- 11,322', 11,235'-11,120' DPM. Reversed out, no oil. POOH to 10,474'. Well taking 60 bbl/hr. Spotted a 27 bbl sized salt pill. Hole still taking fluid 40 bbl/hr. 12475' Spotted a 28 bbl sized salt pill. POOH. Changed top pipe rams to 2-7/8" and tested to 5000 psi. RIH with 2-7/8" completion and a Baker SAB-3 packer. Hydrotested the tubing to 5000 psi. 12475' Completed running and hydrotesting 2-7/8" completion. Landed the completion. Dropped ball. Pressured up to 2500 psi to set the packer at 10,452'. Pressure tested the annulus to 1000 psi, OK. Blew the ball out of the ball seat with 2700 psi. Set BPV. 12475' Removed BOPE and riser. Installed FMC/OCT adapter flange and 3-1/8" 5M CIW tree. Tested the adapter flange and tree to 5000 psi. Released Rig at 1200 hrs. $ E P 1 199 . Alaska 0/1 & Gas Cons. Commission Anchorage May 13, 1992 Teleco Oilfield ~ .es4~c-~_ ..... ~ Anchorage, AK NOW 99518 EASTMAN TELECO (9o7) 562-2646 a Baker Hu§h~ oomp~ny _ - ............ , ,, ....... ._ JOB #861 TAK UNOCAL CORPORATION GRANITE POINT PLATFORM WELL #GP32-13RD & GP32-13RD SIDETRACK Attached please find a copy of the final well report for the above mentioned well. Eastman Teleco appreciates this oPPOrtunity to provide MWD service. Eastman Teleco is committed to providing the highest quality MWD Service and we would welcome any comments or questions concerning this report or any of our other services. Sincerely, Thomas A. Brockway Petroleum Engineering Supervisor TAB/el Enclosures MICROFILMED A S~IAT COMPANY WELL REPORT FOR UNOCAL CORPORATION GRANITE POINT PLATFORM WELL NO. GP32-13 RD WELL NO. GP32-13 RD SIDETRACK API# 50-733-20014-02 COOK INLET KENAI, ALASKA TELECO OILFIELD SERVICES JOB # 861-TAK Submitted By: Tommy Foster Robert McCarthy Paul Smith Blake Cromartie April 23, 1992 RECEIVED MAY 2 6 1992 [iii .& Gas Cons. uurnrnission ~chorage DISCLAIMER Teleco does not guarantee the accurateness or correctness of interpretations provided in or from this report. Since all interpretations are opinions based on measurements, Teleco shall under no circumstances be responsible for consequential damages or any other loss, costs, damages or expenses incurred or sustained in connection with the use of any such interpretations. Teleco disclaims all expressed and implied warranties related to it's service which is governed by Teleco's standard terms and conditions. TABLE OF CONTENTS I. GENERAL WELL INFORMATION II. WELL SUMMARY III. DRILLING AND ENGINEERING a) Run Summary b) BHA Record c) Mud Report IV. FORMATION EVALUATION V. SURVEY LISTING VI. TELECO SERVICES RECEIVED ~AY 2 6 ]992 Gas Cons. ~Jommissi.o..~ I. GENEP~AL WELL iNFORMATION RECEIVED GENERAL WELL INFORMATION OIL COMPANY OIL COMPANY REPRESENTATIVES WELL LOCATION WELL TYPE SPUD DATE DRILLING CONTRACTOR RIG NAME RIG EQUIPMENT TELECO SERVICES TELECO JOB NUMBER TELECO PERSONNEL UNOCAL CORPORATION P.O. Box 190247 ANCHORAGE, ALASKA 99519 LARRY MACALLISTER SHANE HAUCK MIKE McCALL SURFACE LOCATION: 2390' S & 1379' E of NW corner Sec. 13 T10W R12W SM Leg 3 Slot 5 DEVELOPMENT MARCH 13, 1992 POOL ARCTIC ALASKA PAA 431 DIESEL ELECTRIC DIRECTIONAL SURVEYS GAMMA RAY DUAL PROPAGATION RESISTIVITY NEUTRON POROSITY COMPENSATED BULK DENSITY SURFACE WEIGHT ON BIT RATE OF PENETRATION CIRCULATING TEMPERATURE 861 TAK TOMMY FOSTER BLAKE CROMARTIE PAUL SMITH ROBERT McCARTHY I I. WELL SUMMARY RECEIVED WELL SUMMARY Teleco's Measurement While Drilling (MWD) service was utilized on Unocal's well GP32-13 RD located in the Granite Point field, offshore Cook Inlet, Alaska. Teleco was used to provide directional surveys, gamma-ray, dual propagation resistivity, neutron porosity and compensated bulk density logs. The triple-combo logging suite was used to correlate with existing logs to identify lithologies, and pick formation boundaries. Logging services began at 8429 feet MD and were used to a depth of 10238 feet MD (resistivity sensor depth). The well was sidetracked at 9410 feet MD with directional only service. The sidetrack was then logged using dual progagation resistivity tools from 10158 to 10808 feet MD where casing was set and formation evaluation services ended. The 6 3/4 inch formation evaluation tools were used to log 2459 feet in 263 circulating hours. III. DRILLING AND ENGINEERING DRILLING AND ENGINEERING This section briefly outlines the drilling activities involving Teleco on Unocal's well number GP32-13 RD and GP32- 13 Sidetrack on the Granite Point Platform in Cook Inlet, Kenai, Alaska. A concise description on a run-by-run basis follows. Unless otherwise stated, all depths listed in this section are referenced to measured depth. RUN NO 1: 8439 to 8798 ft. TOOL NUMBER AND TYPE: 644-52, 4X MILLER D-TF1 At 8439 feet MD Teleco's Directional only service began in 10 feet of open hole below a window cut in 9 5/8 inch casing from 8417-8429 feet MD, where a whipstock had been set to initiate departure. Teleco's MWD directional tool was run behind a 1 degree bent housing Drill-X mud motor. A Reed 51-A bit with a jet configuration of 3x16 was utilized. At this point a successful kick off was made through the previously milled window. This marked the first KOP of the well. It was intended to build angle to 70.0 degrees and achieve an azimuth of 124.3 degrees azimuth. Pump pressure was approximately 2200 psi with 93 strokes per minute (spm). The inclination built from 13.7 to 25.1 degrees while steering to an azimuth of 129.3 degrees. At 8798 feet MD the BHA was pulled to change out the bit, lay down the directional only tool and pick up Teleco formation evaluation logging tools. NO 2: 8798 to 9512 ft. TOOL NUMBER AND TYPE: 2536-08, 3X SPLIT PHASE MODULAR TC This marked the initiation of Teleco's formation evaluation services. Teleco's Triple Combo logging suite was run behind the same 1 degree bent housing and Drill-X motor utilized in the previous run. An Eastman PDC bit with 4x12 jet configuration was utilized. While drilling, pump pressure was approximately 2100 psi at 92 spm. The mud weight was stable at 9.4 ppg @ 8700 ft. The inclination maintained a steady increase from 25.1 degrees to 29.9 degrees while the direction took a slight right hand walk to 127.9 degrees azimuth. A short trip was made at 9230 feet. At a depth of 9512 ft. with 35 hours on the bit, it was decided to pull the BHA to change the bit. Teleco decided to lay down its DPR sensor (Gamma/Resistivity) and pick up another DPR sensor. This was done as a precaution to compare resistivity curves from two different sensors to insure noted curve separations were valid and not due to tool error. Curve separation was matched with the second sensor over a short relogged section of the wellbore. The density sub was also laid down before running in the hole for Run 3. An intermittent failure from density memory data was confirmed. RUN NO 3: 9512 to 9629 ft. TOOL NUMBER AND TYPE: 2536-08, 3X SPLIT PHASE MODULAR TC A similar BHA was utilized for Run 3, with Teleco again providing Triple Combo services. The same type Eastman bit was run. The mud weight remained constant at 9.4 ppg. While sliding, pump pressure was approximately 2150 psi at 92 spm, 460 gpm. The inclination was built from 29.9 degrees to 34.5 degrees with the azimuth holding at 127.9 degrees. At a depth of 9629 feet with 15.5 hours on the bit, it was decided to pull the BHA, change the bit and the mud motor in an attempt to increase the ROP. RUN NO 4: 9629 to 9753 ft. TOOL NUMBER AND TYPE: 2536-08, 3X SPLIT PHASE MODULAR DC A Fulcrum BHA was run to accommodate rotating of the drill string in hopes that the ROP might be increased. The density sub was dropped from the Teleco suite (downgrading from Triple to Double Combo service) in order to eliminate the full gauge stabilizer and achieve the fulcrum assembly needed for building angle. A Hughes ATM-22 bit with a 3X12 jet configuration was utilized. While rotating, the ROP averaged 7 feet per hour (fph), while the pump pressure was approximately 2100 psi at 92 spm, 460 gpm. The inclination built from 34.5 to 37.3 degrees with the direction remaining relatively constant at 126.8 degrees azimuth. The inclination was not increasing at the desired rate, so the drill string was pulled, in order to change the bit and make up a steerable drilling BHA. Total hours on the bit was approximately 27.5 hrs. RUN NO 5: 9753 to 10095 ft. TOOL NUMBER AND TYPE: 2536-08, 3X SPLIT PHASE MODULAR DC Teleco was run behind a 1 degree bent housing and Drill-X mud motor. The Double Combo Teleco suite run on the previous run was utilized once again. An Eastman Christensen (PDC) bit with 2 X 11 and 2 X 13 jet configuration was used. It was necessary to slide the entire run in order to catch up the angle that was lost the previous run. While sliding the ROP averaged 10 fph while the pump pressure was approximately 2100 psi at 92 spm, 460 gpm. The inclination built from 37.3 degrees to 47.5 degrees with the direction taking a slight left hand walk to 121.5 degrees azimuth. At 10095 feet the drill string was pulled in order to change out the bit and mud motor. Total hours on the bit was 36.0 hrs. RUN NO 6: 10095 to 10195 ft. TOOL NUMBER AND TYPE: 2536-08, 3X SPLIT PHASE MODULAR DC Teleco was run behind a 2 1/2 degree bent sub and Drill-X mud motor. The identical Teleco suite used on the previous run was utilized once again. A Hughes ATM-22 bit with 2 X 11 and 2 X 13 jet configuration was used. Again, it was necessary to slide the entire run in order to try and catch up the angle that was lost on run 4. While sliding the ROP averaged 15 fph, while the pump pressure was approximately 2100 psi at 92 spm, 460 gpm. The inclination built from 47.5 degrees to 51.1 degrees with the direction remaining constant at 121.5 degrees azimuth. At 10195 feet the drill string was pulled to change the bit and BHA. RUN NO 7: 10195 to 10195 ft. TOOL NUMBER AND TYPE: 2536-08, 3X SPLIT PHASE MODULAR TC UNOCAL company personnel elected to make a wiper trip in order to improve downhole conditions. The Density sub was added to Teleco's logging suite in order to log the section of hole where the density-sub was dropped. A REED HP-51-A bit with a 3 X 12 jet configuration was used. It was recommended that ROP should not exceed 125 fph while utilizing the density tool during reaming for relogging. This limit was never reached due to hole conditions causing extreme torque. While reaming the ROP averaged 75 fph, and the pump pressure was approximately 2150 psi at 92 spm, 460 gpm. The density log was completed, a bottom hole survey was taken at 10144 feet (52.1 degrees inclination & 121.5 degrees azimuth) and the drill string was pulled. RUN NO 8: 10195 to 10267 ft. TOOL NUMBER AND TYPE: 2536-08, 3X SPLIT PHASE MODULAR DC Teleco was run behind a 1 1/4 degree bent housing and Drill-X mud motor. A Reed bit, identical to the bit used on the previous run was utilized, with a 3 X 14 jet configuration. Again, it was necessary to begin sliding immediately to regain the angle which had fallen behind the well plan projection. While sliding the ROP averaged 25 fph, and the pump pressure was approximately 2100 psi at 92 spm, 460 gpm. The inclination built from 51.5 degrees to 53.0 degrees with the direction remaining constant at 121.5 degrees. At 10267 feet the drill string became stuck. After jarring for 12 hours, a free point operation recovered all of the heavy weight drill pipe. After several unsuccessful attempts to recover the BHA, it was decided to abandon the logging suite to plug back and proceed with a second kick off. RUN NO 9: 9922 to 9922 ft. TOOL NUMBER AND TYPE: 2601-10, 3X SPLIT PHASE MODULAR DPR Teleco services were downgraded to a DPR, run behind a 1 1/4 degree bent sub and Drill-X mud motor. An RBI bit, with a 3 X 14 jet configuration was utilized. The top of the cement was not tagged until a depth of 10018 feet, too deep for the well's directional objectives. The drill string was pulled out of the hole to make another attempt at setting a plug. RUN NO. 10: 9922 to 9922 ft. TOO NUMBER AND TYPE: 2601-10, 3X SPLIT PHASE MODULAR DIR Teleco services were downgraded once again to provide directional only service using the same modular tool. This was done to place the directional sensor closer to the bit. The top of the cement was not tagged until a depth of 9808 feet, too deep for the well's directional objectives. The mud motor and bit parted when jarred, as the drill string was being removed from a tight section of hole. That fish was cemented in the borehole while preparations were being made to kick-off the well a second time. RUN NO. 11: 9282 to 9282 ft. TOOL NUMBER AND TYPE: 2601-10, 3X SPLIT PHASE MODULAR DIR Teleco directional only services were utilized along with the identical BHA as the previous run. Cement was tagged at a depth of 9282 feet, but was not competent and would not hold weight. The rate of penetration averaged 150 ft/hr., while the weight on bit was 90 klbs. The pump pressure was approximately 2100 psi at 92 spm, 460 gpm. The decision to pull out of the hole was made in order to run back in the hole with a rotary assembly. This decision was made because the condition of the hole was worsening. RUN NO. 12: 9282 to 9542 ft. TOOL NUMBER AND TYPE: 2601-10, 3X SPLIT PHASE MODULAR DIR Teleco directional only services were utilized along with the identical BHA as the previous run. The rate o~ ~~t~!o._n averaged 10-15 ft/hr., while the weight on biat The pump pressure was approximately 2100 psi 92 spm, gpm. The inclination built from 30.0 to 35.9 ~r~e~ ~hile the direction remained constant at S52E. ~The ~s~n~ pull out of the hole was made in order to add ~~~~~h~lssl~~~u~ drill string below Teleco in order'to reduce the A~~ o~ ~ error caused by magnetic interference. RUN NO. 13: 9542 to 9776 ft. TOOL NUMBER AND TYPE: 2601-10, 3X SPLIT PHASE MODULAR DIR Teleco directional only services were utilized along with the identical BHA as the previous run except that a lead monel collar was placed under the Teleco tool, in order to reduce magnetic interference. The rate of penetration averaged 10-15 ft/hr., while the weight on bit was 65 klbs. The pump pressure was approximately 2100 psi at 92 spm, 460 gpm. The inclination built from 35.9 to 43.9 degrees while the direction walked left to S54.6E. The decision to pull out of the hole was made at a depth of 9776 feet in order to change out the bit and the mud motor. RUN NO. 14: 9776 to 10272 ft. TOOL NUMBER AND TYPE: 2601-10, 3X SPLIT PHASE MODULAR DIR Teleco directional only services were utilized along with the identical BHA as the previous run. The rate of penetration averaged 15-20 ft/hr., while the weight on bit was 65 klbs. The pump pressure was approximately 2100 psi at 92 spm, 460 gpm. The inclination built from 43.9 degrees to 58.9 degrees while the direction walked slightly left to S58.5E. The mud weight was a consistent 9.4 ppg. The decision to pull out of the hole was made at a depth of 10272 feet in order to change out the bit and the mud motor. RUN NO. 15: 10272 to 10653 ft. TOOL NUMBER AND TYPE: 1617-23, 3X SPLIT PHASE MODULAR DPR Teleco Dual Propagation Resistivity (DPR) services were reinstated along with a fulcrum assembly. A RBI bit was run with a 3 X 11 jet configuration. The rate of penetration averaged 10 ft/hr., while the weight on bit was 40 klbs. The pump pressure was approximately 2300 psi at 79 spm, 350 gpm. The inclination remained constant at 59.4 degrees while the direction was a constant S57.4E. The mud weight was a consistent 10.0 ppg. The decision to pull out of the hole was made at a depth of 10653 feet in order to change out the bit. RUN NO. 16: 10653 to 10831 ft. i TOOL NUMBER AND TYPE: 1617-23, 3X SPLIT PHASE MODULAR DPR The identical BHA, as the previous run, was utilized. The rate of penetration averaged 15-20 ft/hr., while the weight on bit was 55 klbs. The pump pressure was approximately 2350 psi at 81 spm, 380 gpm. The inclination did not build as intended while the direction remained constant at S57.4E. The drill string became stuck while tripping out of the hole to change out the BHA. Once the drill string was freed Unocal decided to set a 7 5/8 inch liner. Therefore, Teleco logging services ended at 10831 feet MD. 'TELECO RUN TOOL TYPE TOOL NO BIT NO HOLE SIZE (in) BIT TYPE JETS (1/32") DEPTH IN (ft) DEPTH OUT (ft) FEET MADE AVG WOB (klb) FLOW RATE (gpm) PUMP PRESS (psi) MUD WEIGHT (lb/gal) Table 1: Teleco Run Summary D-TF1 644-52 8 1/2 HTC 3 X 14 8439 8798 359 20 300 2500 9.4 MOD-TF1 2536-08 8 1/2 EC-PDC 3 X 14 8798 9512 714 15 420 2150 9.4 MOD-TF1 2536-08 8 1/2 EC-PDC 3 X 12 1 X 14 9512 9628 116 45 420 2150 9.4 MOD-TF1 2536-08 8 1/2 HTC 3 X 12 9628 9753 125 45 420 2100 9.4 TELECO RUN TOOL TYPE TOOL NO BIT NO HOLE SIZE (in) BIT TYPE JETS (1/32") DEPTH IN (ft) DEPTH OUT (ft) FEET MADE AVG WOB (klb) FLOW RATE ( gpm ) PUMP PRESS (psi) MUD WEIGHT (lb/gal) Table 2: Teleco Run Summary MOD-TF1 2536-08 8 1/2 EC-PDC 2 X 11 2 X 13 9753 10095 343 45 420 2100 9.5 MOD-TF1 2536-08 8 1/2 HTC 2 X 11 2 X 13 10095 10195 100 30 420 2150 9.5 MOD-TF1 2536-08 7 Relog 8 1/2 REED 3 X 12 10195 10195 1767 45 390 2000 9.6 MOD-TF1 2536-08 8 1/2 REED 3 X 14 10195 10276 81 45 390 2100 9.9 R£CE]V D MAY 2 6 ]992 _!~fiil.& Gas Uo~s. uummission '-'" ' Anchorage TELECO RUN TOOL TYPE TOOL NO BIT NO HOLE SIZE (in) BIT TYPE JETS (1/32") DEPTH IN (ft) DEPTH OUT FEET MADE AVG WOB (klb) FLOW RATE (gpm) PUMP PRESS (psi) MUD WEIGHT (lb/gal) Table 3: Teleco Run Summary MOD-TF1 2601-10 8 1/2 RBI 3 X 14 10018 10018 420 2100 10.0 10 MOD-TF1 2601-10 10 8 1/2 RBI 3 X 14 10018 10018 420 2150 9.9 11 MOD-TF1 2601-10 10 -RR 8 1/2 RBI 3 X 14 9282 9406 124 45 420 2100 9.9 12 MOD-TF1 2601-10 10-RR 8 1/2 RBI 3 X 14 9406 9542 136 45 420 2100 9.4 Table 4: Teleco Run Summary TELECO RUN TOOL TYPE TOOL NO BIT NO HOLE SIZE (in) BIT TYPE JETS (1/32") DEPTH IN (ft) DEPTH OUT (ft) FEET MADE AVG WOB (klb) FLOW RATE (gpm) PUMP PRESS (psi) MUD WEIGHT (lb/gal) 13 MOD-TF1 2601-10 11 8 1/2 RBI 3 X 14 9542 9776 233 72 420 2100 9.4 14 MOD-TF1 2601-10 12 8 1/2 HTC 3 X 14 9776 10272 496 65 420 2150 9.4 15 MOD-TF1 1617-23 13 8 1/2 RBI 3 X 11 10272 10653 381 38 360 2300 10.0 16 MOD-TF1 1617-23 14 8 1/2 RBI 3 X 11 10653 10831 178 55 360 2350 10.0 SECTION NAME (1) BIT ( 2 )DRI LL-X ( 3 )X0-FLOAT (4) LC (5) TELECO-DIR ( 6 )MONEL (7) DC (8) DC ( 9 )X-OVER (10) HWDP (1) (11) JARS (12) HWDP (46) SPECIAL BHA ITEMS: (1) Bit #:1 (2) Mud Motor ( 4 ) Stab (8) TELECO MWD SECTION NAME (1) BIT ( 2 )DRI LL-X ( 3 )FLOAT (4) X-O (5) TELECO MOD (6) X-O (7) MONEL DC (8) DC (9) DC (10) X-O (11) HWDP (1) (12) JARS (18) HWDP (46) SPECIAL BHA ITEMS: (1) Bit #:2 (2) Mud Motor (3) DENS STAB (4) TELECO MWD BOTTOM HOLE ASSEMBLIES BHA #1: 8439 '-8798' SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft .75 8.500 0.75 20.85 6.750 21.60 1.45 6.8125 2.250 23.05 9.00 6.500 2.250 32.05 36.11 6.750 68.16 28.50 6.500 2.250 96.66 29.83 6.375 2.312 126.49 30.20 6.500 2.750 156.69 2.34 6.437 2.880 159.03 33.02 5.000 2.25 192.05 33.02 6.250 2.250 225.07 1387.97 5.000 2.250 1613.04 Bit Type:Eastman PDC Flow Area:..451 Drill-x multilobe With 1 Degree Bent Sub # Blades:3 Fish Neck:2.30 Blade 0D:8.50 Serial #:644-52 Type:DIR-TF1 BHA #2: 8798'- 9512' SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft 1.25 8.500 20.87 6.625 1.45 6.812 2.250 2.27 6.500 2.880 71.80 6.750 1.16 6.500 2.880 48.50 6.125 2.250 29.83 6.375 2.312 30.20 6.500 2.250 2.34 6.437 2.810 30.00 5.000 2.250 33.02 6.250 2.250 1387.97 5.000 2.250 1.25 22.12 23.57 25.84 97.64 °RECEIVED 147.30 177.13 2 o 7.3 3 fY.:A Y ~. 6 i992 2 0 ~iaifk~ Oil & 23 9.67~ LGas Cons. .Commi~i~.. 272. 69 1660.66 Bit Type:Eastman PDC Flow Area:.451 Drill-x multilobe With 1 Degree Bent Sub # Blades:3 Fish Neck:2.02 Blade OD-8.50 Serial #:2536-08 Type:3x SPLIT PHASE MOD SECTION NAME (1) BIT ( 2 ) DRI LL-X ( 3 ) FLOAT (4) X-O (5) TELECO MOD (6) x-o (7) MONEL DC (8) DC (9) DC (10) X-O (11) HWDP (1) (12) JARS (18) HWDP (46) SPECIAL BHA ITEMS: (1) Bit #:3 (2) Mud Motor (3) DENS STAB (4) TELECO MWD BHA #3: 9512'- 9629' SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft 1.25 8.500 1.25 20.87 6.625 22.12 1.45 6.812 2.250 23.57 2.27 6.500 2.880 25.84 72.01 6.750 97.64 1.16 6.500 2.880 98.80 48.50 6.125 2.250 147.30 29.83 6.375 2.312 177.13 30.20 6.500 2.250 207.33 2.34 6.437 2.810 209.67 30.00 5.000 2.250 239.67 33.02 6.250 2.250 272.69 1387.97 5.000 2.250 1660.66 Bit Type:Eastman PDC Flow Area:..480 Drill-x multilobe With 1 Degree Bent Sub # Blades:3 Fish Neck:2.02 Blade 0D:8.50 Serial #:2536-08 Type:3x SPLIT PHASE MOD SECTION NAME (1) BIT (2) NB STAB (3) X0 ( 4 ) TELECO (5) NM STAB ( 6 ) MONEL (7) DC (8) DC ( 9 ) STAB (10) x-o (11) HWDP (12) JARS (13) HWDP (46) SPECIAL BHA ITEMS: (1) Bit #:4 (2) Stab (5) Stab (4) MWD ( 9 ) Stab BHA #4: 9629'- 9753' SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft .80 8.500 0.85 5.35 8.500 2.812 23.34 2.27 6.500 2.880 24.78 66.34 6.750 34.09 4.50 8.500 2.750 40.15 28.50 6.125 2.250 49.79 29.83 6.375 2.345 55.20 30.20 6.500 2.250 56.27 5.27 8.500 2.250 97.44 2.34 6.437 2.810 100.08 30.00 5.000 2.250 106.19 33.02 6.250 2.250 135.49 1387.97 5.000 2.250 165.29 Bit Type:Hughes Flow Area:.331 # Blades:3 Fish Neck:l.83 Blade 0D:8.50 # Blades:3 Fish Neck:l.83 Blade OD:8.50 Serial #:2536-08 Type:3x SPLIT PHASE MOD # Blades:3 Fish Neck:2.00 Blade OD'8.50 SECTION NAME (1) BIT ( 2 )DRILL-X ( 3 )X0-FLOAT ( 4 )X-OVER ( 5 )TELECO ( 6 )MONEL (7) DC (8) DC ( 9 )X-OVER (10) HWDP (1) (11) JARS (12) HWDP (46) SPECIAL BHA ITEMS: (1) Bit #:5 (2) Mud Motor (5) TELECO MWD BHA #5: 9753'- 10095' SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft 1.25 8.500 1.25 20.85 6.625 22.10 1.45 6.810 2.250 23.55 2.27 6.500 2.880 25.82 68.81 6.750 94.63 28.50 6.125 2.250 123.13 29.83 6.375 2.310 152.96 30.20 6.500 2.250 183.16 2.34 6.437 2.810 185.50 30.00 5.000 2.250 215.50 33.02 6.250 2.250 248.52 1387.97 5.000 2.250 1636.49 Bit Type:EC-PDC Flow Area:.590 Drill-X multilobe with 1 Degree Bent Sub Serial #:2536-08 Type:3x Split Phase Mod SECTION NAME (1) BIT ( 2 )DRI LL-X (3) BENT SUB (4) BIT SUB ( 5 )X-OVER ( 6 )TELECO (7) MONEL (8) DC (9) DC (10) X-OVER (11) HWDP (1) (12) JARS (13) HWDP (46) SPECIAL BHA ITEMS: (1) Bit #:6 (2) Mud Motor (6) TELECO MWD BHA #6: 10095'-10194' SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft .80 8.500 O.8O 21.25 6.625 22.05 1.27 6.810 2.250 23.32 2.90 6.500 2.250 26.22 2.27 6.500 2.880 28.49 68.81 6.750 97.30 28.50 6.125 2.250 125.80 29.83 6.375 2.310 155.63 30.20 6.500 2.250 185.83 2.34 6.437 2.810 188.17 30.00 5.000 2.250 218.17 33.02 6.250 2.250 251.19 1387.97 5.000 2.250 1639.16 Bit Type:EC-PDC Flow Area:.590 Drill-X multilobe with 2 1/2 Degree Bent Sub Serial #:2536-08 Type:3x Split Phase Mod SECTION NAME (1) BIT (2) NB STAB ( 3 )X-OVER ( 4 )TELECO (5) MONEL (6) DC (7) DC ( 8 )STAB ( 9 )X-OVER (10) HWDP (1) (11) JARS (12) HWDP (46) SPECIAL BHA ITEMS: (1) Bit #:7 (4) TELECO MWD ( 2 ) Stab ( 8 ) Stab BHA #7: 10194 '-10194' SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft .80 8.500 0.80 5.35 6.625 2.813 6.15 2.27 6.500 2.880 8.42 67.76 6.750 76.18 28.50 6.125 2.250 104.68 29.83 6.375 2.310 134.51 30.20 6.500 2.250 164.71 5.27 6.625 2.878 169.98 2.34 6.437 2.810 172.32 30.00 5.000 2.250 202.32 33.02 6.250 2.250 235.34 1387.97 5.000 2.250 1623.31 Bit Type:REED Flow Area:.331 Serial #:2536-08 Type:3x Split Phase Mod # Blades:3 Fish Neck:l.83 Blade OD:8.50 # Blades:3 Fish Neck:l.83 Blade 0D:8.50 SECTION NAME (1) BIT ( 2 )DRI LL-X ( 3 )X0-FLOAT ( 4 )X-OVER ( 5 )TELE CO ( 6 )MONEL (7) DC (8) DC ( 9 )X-OVER (10) HWDP (1) (11) JARS (12) HWDP (46) SPECIAL BHA ITEMS: (1) Bit #:8 (2) Mud Motor (5) TELECO MWD BHA #8: 10194'-10276' SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft .80 8.500 .8O 20.76 6.625 21.56 1.45 6.810 2.250 23.01 2.27 6.500 2.880 25.28 66.55 6.750 91.83 28.50 6.125 2.250 120.33 29.83 6.375 2.310 150.16 30.20 6.500 2.250 180.36 2.34 6.437 2.810 182.70 30.00 5.000 2.250 212.70 33.38 6.250 2.250 246.08 1387.97 5.000 2.250 1634.05 Bit Type:REED Flow Area:.451 Drill-X multilobe with 1 3/4 Degree Bent Sub Serial #:2536-08 Type:3x Split Phase Mod SECTION NAME (1) BIT ( 2 ) DRI LL-X ( 3 ) X0-FLOAT ( 4 ) X-OVER ( 5 ) X-OVER ( 6 ) TELECO ( 7 ) X-OVER ( 8 ) MONEL ( 9 ) STAB (10) DC (11) X-OVER (12) HWDP (i) ( 13 ) JARS (14) HWDP (45) SPECIAL BHA ITEMS: (1) Bit #:9 (2) Mud Motor (6) TELECO MWD SECTION NAME (1) BIT ( 2 ) DRI LL-X ( 3 ) X0-FLOAT ( 4 ) X-OVER ( 5 ) X-OVER ( 6 ) TELECO ( 7 ) X-OVER ( 8 ) MONEL ( 9 ) STAB (10) DC (11) X-OVER (12) HWDP (1) (13) JARS (14) HWDP (45) BHA #9: 10018 '-10018' SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft .8O 8.500 .80 20.80 6.625 21.60 2.98 6.810 2.250 24.58 1.16 6.500 3.750 25.74 1.23 6.500 2.880 26.97 51.30 6.750 78.27 1.12 6.500 3.250 79.37 28.50 6.125 2.250 107.89 4.88 6.375 2.310 112.77 31.13 6.500 2.250 143.90 1.09 6.437 2.810 144.99 30.39 5.000 2.250 175.38 32.98 6.250 2.250 208.36 1358.08 5.000 2.250 1566.44 Bit Type:RBI Flow Area:.451 Drill-X multilobe with 1 3/4 Degree Bent Sub Serial #:2601-10 Type:3x Split Phase Mod-DPR BHA #10: 10018'-10018' SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft .80 8.500 .80 20.80 6.625 21.60 2.98 6.810 2.250 24.58 .85 6.750 2.880 25.74 3.05 6.500 2.250 26.97 36.37 6.750 78.27 1.12 6.500 3.250 79.37 28.50 6.125 2.250 107.89 4.88 6.375 2.310 112.77 31.13 6.500 2.250 143.90 1.09 6.437 2.810 144.99 30.39 5.000 2.250 175.38 32.98 6.250 2.250 208.36 1358.08 5.000 2.250 1566.44 SPECIAL BHA ITEMS: (1) Bit #:10 (2) Mud Motor (6) TELECO MWD Bit Type:RBI Flow Area:.451 Drill-X multilobe with 1 1/4 Degree Bent Sub Serial #:2601-10 Type:3x Split Phase Mod-DIR SECTION NAME (1) BIT ( 2 ) DRILL-X ( 3 ) X0-FLOAT ( 4 ) X-OVER ( 5 ) X-OVER ( 6 ) TELECO ( 7 ) X-OVER ( 8 ) MONEL ( 9 ) STAB (10) DC (11) X-OVER (12) HWDP (1) (13) JARS (14) HWDP (45) SPECIAL BHA ITEMS: (1) Bit #: 10-RR (2) Mud Motor (6) TELECO MWD SECTION NAME (1) BIT ( 2 ) DRI LL-X ( 3 ) X0- FLOAT ( 4 ) X-OVER ( 5 ) X-OVER ( 6 ) TE LE CO ( 7 ) X-OVER ( 8 ) MONEL ( 9 ) STAB (10) DC (11) X-OVER (12) HWDP (1) (13) JARS (14) HWDP (45) SPECIAL BHA ITEMS: (1) Bit #:10 RR (2) Mud Motor (6) TELECO MWD BHA #11: 9282 '-9282' SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft .80 8.500 .8O 20.80 6.625 21.60 2.98 6.810 2.250 24.58 .85 6.750 2.880 25.74 3.05 6.500 2.250 26.97 36.37 6.750 78.27 1.12 6.500 3.250 79.37 28.50 6.125 2.250 107.89 4.88 6.375 2.310 112.77 31.13 6.500 2.250 143.90 1.09 6.437 2.810 144.99 30.39 5.000 2.250 175.38 32.98 6.250 2.250 208.36 1358.08 5.000 2.250 1566.44 Bit Type:RBI Flow Area:.451 Drill-X multilobe with 1 1/4 Degree Bent,Sub Serial #:2601-10 Type:3x Split Phase Mod-DIR BHA #12: 9406'-9542' SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft .80 8.500 .80 20.58 6.625 21.60 2.98 6.810 2.250 24.58 .85 6.750 2.880 25.74 3.05 6.500 2.250 26.97 36.37 6.750 78.27 1.12 6.500 3.250 79.37 28.40 6.125 2.250 107.89 4.88 6.375 2.310 112.77 31.13 6.500 2.250 143.90 1.09 6.437 2.810 144.99 30.39 5.000 2.250 175.38 32.98 6.250 2.250 208.36 1358.08 5.000 2.250 1566.44 Bit Type:RBI Flow Area:.451 Drill-X multilobe with 1 1/4 Degree Bent Sub Serial #:2601-10 Type:3x Split Phase Mod-DIR SECTION NAME (1) BIT ( 2 ) DRILL- X ( 3 ) XO-FLOAT (4) LEAD COLLAR ( 5 ) X-OVER ( 6 ) X-OVER (7) TELECO ( 8 ) X-OVER ( 9 ) MONEL (10) STAB (11) DC (12) X-OVER (13) HWDP (1) (14) JARS (15) HWDP (45) SPECIAL BHA ITEMS: (1) Bit #:11 (2) Mud Motor (6) TELECO MWD BHA #13: 9542'-9776 SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft .80 8.500 .80 20.86 6.625 21.66 2.98 6.810 2.250 24.64 9.01 6.625 2.250 33.65 .85 6.750 2.880 34.50 3.05 6.500 2.250 37.55 36.37 6.750 73.92 1.12 6.500 3.250 75.04 28.40 6.125 2.250 103.44 4.88 6.375 2.310 108.32 31.13 6.500 2.250 139.45 1.09 6.437 2.810 140.54 30.39 5.000 2.250 170.93 32.98 6.250 2.250 203.91 1358.08 5.000 2.250 1561.99 Bit Type:RBI Flow Area:.451 Drill-X multilobe with 1 Degree Bent Sub Serial #:2601-10 Type'3x Split Phase Mod-DIR SECTION NAME (1) BIT (2) DRILL-X ( 3 ) XO- FLOAT ( 4 ) LEAD COLLAR ( 5 ) X-OVER ( 6 ) X-OVER ( 7 ) TELECO ( 8 ) X-OVER ( 9 ) MONEL (10) STAB (11) DC (12) X-OVER (13) HWDP (1) (14) JARS (15) HWDP (45) SPECIAL BHA ITEMS: (1) Bit #:12 (2) Mud Motor (6) TELECO MWD BHA #14: 9776'-10272 SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft .8O 8.50O .8O 20.86 6.625 21.66 2.98 6.810 2.250 24.64 9.01 6.625 2.250 33.65 .85 6.750 2.880 34.50 3.05 6.500 2.250 37.55 36.37 6.750 73.92 1.12 6.500 3.250 75.04 28.40 6.125 2.250 103.44 4.88 6.375 2.310 108.32 31.13 6.500 2.250 139.45 1.09 6.437 2.810 140.54 30.39 5.000 2.250 170.93 32.98 6.250 2.250 203.91 1358.08 5.000 2.250 1561.99 Bit Type:RBI Flow Area:.451 Drill-X multilobe with 1 Degree Bent Sub Serial #:2601-10 Type-3x Split Phase Mod-DIR SECTION NAME (1) BIT (2) NB STAB (3) LEAD COLLAR (4) NM STAB ( 5 ) TELECO ( 6 ) MONEL ( 7 ) STAB (8) x-o (11) HWDP (12) JARS (13) HWDP (45) SPECIAL BHA ITEMS: (1) Bit #:13 (2) Stab (5) Stab (4) MWD ( 9 ) Stab BHA #15: 10272'- 10653' SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft .85 8.500 0.85 5.34 8.500 2.812 6.19 9.01 6.500 2.880 15.20 4.55 8.500 2.812 19.75 52.88 6.750 72.63 28.40 6.125 2.250 101.03 4.88 8.500 2.880 105.91 1.09 6.437 2.810 107.00 30.39 5.000 2.250 137.39 32.98 6.250 2.250 170.37 1358.00 5.000 2.250 1528.37 Bit Type:Hughes Flow Area:.331 # Blades:3 Fish Neck:l.83 Blade 0D:8.50 # Blades:3 Fish Neck:l.83 Blade 0D:8.50 Serial #:2536-08 Type:3x SPLIT PHASE MOD # Blades:3 Fish Neck:2.00 Blade 0D:8.50 SECTION NAME (1) BIT (2) NB STAB ( 3 ) LEAD COLLAR (4) NM STAB ( 5 ) TELECO ( 6 ) MONEL (7) STAB (8) x-o (11) HWDP (12) JARS (13) HWDP (45) SPECIAL BHA ITEMS: (1) Bit #:14 (2) Stab (5) Stab (4) MWD (9) Stab BHA #16: 10563'- 10831' SECTION SECTION SECTION CUMULATIVE LENGTH OD ID LENGTH ft in in ft .85 8.500 0.85 5.34 8.500 2.812 6.19 9.01 6.500 2.880 15.20 4.55 8.500 2.812 19.75 52.88 6.750 72.63 28.40 6.125 2.250 101.03 4.88 8.500 2.880 105.91 1.09 6.437 2.810 107.00 30.39 5.000 2.250 137.39 32.98 6.250 2.250 170.37 1358.00 5.000 2.250 1528.37 Bit Type:Hughes Flow Area:.331 # Blades:3 Fish Neck:l.83 Blade OD:8.50 # Blades:3 Fish Neck:l.83 Blade 0D:8.50 Serial #:2536-08 Type:3x SPLIT PHASE MOD # Blades:3 Fish Neck:2.00 Blade OD:8.50 MUD INFORMATION RUN DEPTH WEIGHT PVIS ft ppg cp 1 8700 9.4 27 2 9443 9.4 27 3 9511 9.4 27 4 9622 9.4 31 5 9948 9.5 25 6 10193 9.5 26 7 10200 9.7 19 8 10267 9.8 24 9 10017 10.0 22 15 10285 10.0 28 16 10640 10.0 29 YIELD PT lb/100ft 19 16 17 21 20 19 14 12 10 25 24 GEL FILT CHLOR 10s/10m cc mg/L 4/7 3.8 1800 3/8 4.2 1700 1/3 3.8 1700 3/7 3.6 1800 3/8 4.0 1800 4/10 3.8 1800 3/5 3.8 1700 3/6 3.8 1600 2/5 4.0 1800 6/9 3.2 1500 6/11 3.2 1700 SAND SOLID CAKE pH/ELEC % % STAB n/a 5.0 3 10.5 n/a 5.0 3 11.2 n/a 5.0 3 10.7 n/a 6.5 3 9.9 n/a 8.0 3 9.7 n/a 9.0 3 10.2 n/a 8.0 3 10.1 n/a 10.0 3 10.1 n/a 10.0 1 11.7 n/a 10.0 3 9.9 n/a 12.0 4 9.6 ADDITIONAL MUD INFORMATION RUN Rm TEMP Ohm/M Deg F 1 2 3 1.10 74 1.10 74 1.10 75 4 1.20 76 5 1.30 74 6 1.00 79 7 1.20 74 8 1.20 74 9 1.20 76 15 1.10 74 16 1.15 76 Rmf Ohm/M l~c Ohm/M BHCTemp Rm(cor) Deg/F Ohm/M .99 1.25 136 .62 1.10 1.25 138 .63 1.05 1.60 138 .63 1.05 1.55 142 .66 1.10 1.30 152 .67 1.15 2.00 138 .58 1.10 1.90 140 .65 1.10 1.95 140 .65 1.15 2.00 138 .65 1.10 1.90 156 .54 1.20 1.80 162 .54 IV. FORMATION EVALUATION FORMATION EVALUATION G32-13 RD was a high angle production well drilled for Unocal Corporation from the Granite Point Platform, located in Cook Inlet, Kenai Borough of Alaska. Teleco logging services were used to correlate known stratigraphic markers in order to identify and drill parallel within the C-3 formation bedding plane. Logging began in the TM-37 formation at a depth of 8765 feet measured depth. All depths referred to in this section are measured depths taken below the rotary table. Drilling continued in the 8 1/2 inch hole, through the TM (38- 41) formations, GP sand, TM (40-42) and the objective C-3 marker, encountered at a depth of approximately 10008 feet (9602 ft. TVD). The C-3 marker was picked using the gamma ray in conjunction with resistivity log response. Gamma values showed a gradual decrease directly above the marker, while resistivity values experienced a slight ramping increase in value. The C-3 was picked where the gamma ray reached its lowest level. The C-3 target, consisting primarily of well sorted very fine grain, quartz sandstone displayed a maximum resis- tivity of approximately 60 ohm-meters using the phase resistivity measurement. The attenuation resistivity was off scale. Minimum gamma ray readings in this zone averaged 40 apparent API units. At a depth of 10276 feet, after several unsuccessful recovery attempts, the Teleco tool was cemented downhole. A cement plug was set up the hole and after several attempts the well was successfully sidetracked at 9410 feet. Teleco's DPR service was used for the sidetrack from 10158 to 10808 feet MD. The C-3 formation was encountered at 10617 feet. This was a much deeper measured depth than the original well bore and was due to the higher inclination of the sidetrack. The log response was consistent with that seen from the original well. The phase resistivity increased to 60 ohm-meters and the amplitude resistivity went off scale at 10626 feet. The minimum gamma-ray measurement showed a slight increase and averaged 44 apparent API units. V. DIRECTIONAL SURVEY DATA TELECO OILFIELD SERVICES, INC ALASKA DISTRICT UNOCAL Well Name Location Date Surveyed Job No. Survey Performed By : GP 32-13 RD : GRANITE POINT PLATFORM : COOK INLET, ALASKA : : FEB 27, 1992 : 861TAK : PAUL SMITH This survey is correct to the best of my knowledge and is supported by actual field data. COMPANY REPRESENTATIVE TELECO OILFIELD SERVICES, INC Client : UNOCAL W~ Name : GP 32-13 RD Lo ~tion : GRANITE POINT PLATFORM : COOK INLET, ALASKA : Date FEB 27, 1992 Filename : 861TAK No Interpolation Plane of Vertical Section : 124.3° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+23° 6.000'E Platform north : +0° 0' 0'' (T) Grid convergence : +0.0000° Client We~'~ Name L°~ zion TELECO OILFIELD SERVICES, INC .' UNOCAL : GP 32-13 RD : GRANITE POINT PLATFORM : COOK INLET, ALASKA : MD C%L INC DIR TVD ft ft deg deg ft 8400 0 13.9 104.0 8209 8478 78 16.7 102.6 8285 8595 117 19.6 112.7 8396 8687 92 21.4 125.8 8482 8753 66 24.0 129.3 8543 8858 105 26.1 129.3 8638 8948 90 26.4 129.6 8719 9072 124 26.7 129.6 8830 9159 87 27.2 130.3 8907 9256 97 29.2 128.6 8993 9365 109 30.1 127.2 9087 9437 72 29.9 127.9 9150 9530 93 33.6 127.2 9229 9634 104 37.4 127.2 9313 9700 66 37.3 126.8 9366 ;-~808 108 38.7 125.8 9451 9903 95 42.1 122.9 9523 10025 122 47.5 121.5 9610 10124 99 51.1 121.5 9674 10144 20 52.1 120.8 9687 10181 37 53.0 120.1 9709 10222 41 53.8 120.5 9734 10267 45 53.8 120.5 9760 Page 1 of 1 Date FEB 27, 1992 Filename : 861TAK No Interpolation VS LAT DEP D'LEG BUILD TURN ft ft ft °/100 °/100 °/100 1245 -57 1468 0.0 0.0 0.0 1264 -61 1488 3.6 3.6 -1.8 1299 -73 1523 3.6 2.5 8.6 1331 -88 1551 5.3 2.0 14.2 1356 -104 1571 4.4 3.9 5.3 1401 -132 1605 2.0 2.0 0.0 1440 -157 1636 0.4 0.3 0.3 1495 -193 1679 0.2 0.2 0.0 1535 -218 1709 0.7 0.6 0.8 1580 -247 1744 2.2 2.1 -1.8 1634 -280 1787 1.0 0.8 -1.3 1670 -302 1815 0.6 -0.3 1.0 1719 -332 1854 4.0 4.0 -0.8 1779 -368 1902 3.7 3.7 0.0 1819 -393 1934 0.4 -0.2 -0.6 -432 1988 1.4 1.3 -467 2039 4.1 3.6 -512 2111 4.5 4.4 -552 2175 3.6 3.6 -560 2189 5.7 5.0 1886 1947 2033 2108 2124 -0.9 -3.1 -1.1 0.0 -3.5 2153 -575 2214 2.9 2.4 -1.9 2186 -591 2243 2 . 1 2 . 0 1 . 0 2222 -610 2274 0.0 0.0 0.0 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 2354 ft 105.0° TELECO OILFIELD SERVICES, INC ALASKA DISTRICT UNOCAL Well Name Location Date Surveyed Job No. Survey Performed By : GP 32-13 RD : GRANITE POINT PLATFORM : COOK INLET, ALASKA : : FEB 27, 1992 : 861TAK : PAUL SMITH This survey is correct to the best of my knowledge and is supported by actual field da a~ COMPANY REPRESENTATIVE TELECO OILFIELD SERVICES, INC Client : UNOCAL W,~~'~ Name : GP 32-13 RD Locution : GRANITE POINT PLATFORM : COOK INLET, ALASKA : Date FEB 27, 1992 Filename : 861TAK Interpolated 100 ft of MD Plane of Vertical Section : 124.3° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+23° 6.000'E Platform north : +0° 0' 0'' (T) Grid convergence : +0.0000° Client We~'% Name Lc ~tion TELECO OILFIELD SERVICES, INC UNOCAL GP 32-13 RD GRANITE POINT PLATFORM COOK INLET, ALASKA Page 1 of 1 Date FEB 27, 1992 Filename : 861TAK Interpolated 100 ft of MD MD C~L INC DIR TVD ft ft deg deg ft 8400 0 13.9 104.0 8209 8500 100 17.2 104.5 8305 8600 100 19.7 113.4 8400 8700 100 21.9 126.5 8494 8800 100 24.9 129.3 8585 8900 100 26.2 129.4 8676 9000 100 26.5 129.6 8765 9100 100 26.9 129.8 8855 9200 100 28.0 129.6 8943 9300 100, 29.6 128.0 9031 9400 100 30.0 127.5 9118 9500 100 32.4 127.4 9203 9600 100 36.2 127.2 9286 9700 100 37.3 126.8 9366 9800 100 38.6 125.9 9445 9900 100 42.0 123.0 9521 10000 100 46.4 121.8 9592 10100 100 50.2 121.5 9659 10200 100 53.4 120.3 9721 10267 67 53.8 120.5 9760 VS LAT DEP D'LEG BUILD TURN ft ft ft °/100 °/100 °/100 1245 -57 1468 0.2 0.2 1.2 1271 -63 1495 3.3 3.3 0.5 1301 -73 1524 3.7 2.5 8.9 1336 -91 1555 5.1 2.2 13.1 1376 -116 1586 3.2 3.0 2.8 1419 -144 1620 1.3 1.3 0.1 1463 -172 1654 0.3 0.3 0.2 1508 -201 1688 0.3 0.3 0.2 1554 -230 1724 1.2 1.2 -0.2 1602 -260 1762 1.7 1.5 -1.5 1652 -291 1801 0.5 0.4 -0.5 1703 -322 1842 2.4 2.4 -0.1 1759 -357 1887 3.8 3.8 -0.2 1819 -393 1934 1.2 1.1 -0.4 1881 -429 1984 1.4 1.3 -0.9 1945 -465 2037 3.9 3.4 -2.9 2015 -503 2097 4.5 4.4 -1.2 2090 -542 2160 3.8 3.8 -0.3 2168 -582 2227 3.3 3.1 -1.2 2222 -610 2274 3.7 3.6 -1.0 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 2354 ft 105.0° TELECO OILFIELD SERVICES, INC ALASKA DISTRICT UNOCAL Well Name Location Date Surveyed Job No. Survey Performed By : GP 32-13 RD ST#1 : GRANITE POINT PLATFORM : COOK INLET, ALASKA : : FEB 27, 1992 : 861TAK : PAUL SMITH This survey is correct to the best of my knowledge and is supported by actual field data. .... .~.~...~..~... COMPANY REPRESENTATIVE TELECO OILFIELD SERVICES, INC Client : UNOCAL W~Name : GP 32-13 RD ST#1 Lo~.~ion : GRANITE POINT PLATFORM : COOK INLET, ALASKA : Date FEB 27, 1992 Filename : 861TAKST No Interpolation Plane of Vertical Section : 124.3° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+23° 6.000'E Platform north : +0° 0' 0'' (T) Grid convergence : +0.0000° client Well Name L~,~tion ~LECO OILFIELD SERVICES, INC - UNOCAL · : GP 32-13 RD ST#1 · GRANITE POINT PLATFORM : COOK INLET, 'ALASKA · Page 1 of 1 Date FEB 27, 1992 Filename : 861TAKST No Interpolation MD C~L INC DIR TVD VS LAT DEP D'LEG BUILD TURN ft ft deg deg ft ft ft ft °/100 °/100 °/100 9410 0 30.0 127.6 9129 1646 -290 1795 0.0 0.0 0.0 9473 63 35.9 128.7 9182 1680 -311 1822 9.5 9.4 1.7 9569 96 41.0 128.2 9257 1740 -348 1869 5.3 5.3 -0.5 9663 94 43.9 125.4 9326 1803 -386 1919 3.7 3.1 -3.0 9756 93 47.3 124.4 9391 1870 -424 1974 3.7 3.7 -1.1 9846 90 50.4 122.9 9451 1937 -462 2030 3.7 3.4 -1.7 9939 93 54.5 121.9 9507 2011 -501 2093 4.5 4.4 -1.1 10035 96 56.6 121.2 9562 2090 -543 2160 2.3 2.2 -0.7 10129 94 58.0 121.5 9612 2169 -584 2228 1.5 1.5 0.3 10222 93 58.9 121.5 9661 2248 -625 2295 1.0 1.0 0.0 10284 62 59.2 121.9 9693 2302 -653 2340 0.7 0.5 0.6 10317 33 59.0 122.2 9710 2330 -668 2364 1.0 -0.6 0.9 10347 30 58.8 122.2 9725 2355 -682 2386 0.7 -0.7 0.0 10376 29 58.4 122.2 9740 2380 -695 2407 1.4 -1.4 0.0 10413 37 58.6 122.2 9760 2412 -712 2434 0.5 0.5 0.0 ~,~438 25 58.8 122.2 9773 2433 -723 2452 0.8 0.8 0.0 462 24 58.7 122.6 9785 2454 -734 2469 1.5 -0.4 1.7 ±0504 42 58.7 122.6 9807 2489 -754 2499 0.0 0.0 0.0 10534 30 58.7 122.6 9823 2515 -767 2521 0.0 0.0 0.0 10565 31 59.1 122.6 9839 2542 -782 2543 1.3 1.3 0.0 10599 34 59.4 122.6 9856 2571 -797 2568 0.9 0.9 0.0 10650 51 59.7 122.6 9882 2615 -821 2605 0.6 0.6 0.0 10689 39 59.7 122.9 9902 2648 -839 2633 0.7 0.0 0.8 10720 31 59.7 122.6 9917 2675 -854 2656 0.8 0.0 -1.0 10749 29 59.8 122.6 9932 2700 -867 2677 0.3 0.3 0.0 10782 33 59.8 122.6 9948 2729 -883 2701 0.0 0.0 0.0 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 2842 ft 108.1° TELECO~OILFIELD SERVICES, INC ALASKA DISTRICT UNOCAL Well Name Location Date Surveyed Job No. Survey Performed By : GP 32-13 RD ST#1 : GRANITE POINT PLATFORM : COOK INLET, ALASKA : : FEB 27, 1992 : 861TAK : PAUL SMITH This survey is correct to the best of my knowledge and is supported by actual field data. .......... COMPANY REPRESENTATIVE TELECO OILFIELD SERVICES, INC Client : UNOCAL W~, Name : GP 32-13 RD ST#1 L~ ~tion : GRANITE POINT PLATFORM : COOK INLET, ALASI~ Date FEB 27, 1992 Filename : 861TAKST Interpolated 100 ft of MD Plane of Vertical Section : 124.3° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+23° 6.000'E Platform north : +0° 0' 0'' (T) Grid convergence : +0.0000° Client We~, Name Lo aion T~LECO OILFIELD SERVICES, INC : UNOCAL : GP 32-13 RD ST#1 : GRANITE POINT PLATFORM : COOK INLET, ALASKA · Page 1 of 1 Date FEB 27, 1992 Filename : 861TAKST Interpolated 100 ft of MD MD C~L INC DIR TVD ft ft deg deg ft 9410 0 30.0 127.6 9129 9500 90 37.3 128.6 9203 9600 100 42.0 127.3 9280 9700 100 45.3 125.0 9352 9800 100 48.8 123.7 9420 9900 100 52.8 122.3 9484 10000 100 55.8 121.5 9542 10100 100 57.6 121.4 9597 10200 100 58.7 121.5 9650 10300 100 59.1 122.0 9701 10400 100 58.5 122.2 9753 10500 100 58.7 122.6 9805 10600 100 59.4 122.6 9857 10700 100 59.7 122.8 9907 10782 82 59.8 122.6 9948 VS ft 1646 1697 1761 1830 1903 1980 2061 2145 2230 2315 2401 2486 2572 2658 2729 LAT ft -290 -322 -361 -401 -443 -485 -528 -571 -615 -660 -706 -752 -798 -844 -883 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 1795 0 . 3 0 . 3 1.4 1835 8.2 8.2 1.0 1885 4.7 4.6 -1.3 1941 3.7 3.3 -2.3 2002 3.7 3.6 -~.3 2067 4.1 4.0 -1.3 2135 3.1 3.1 -0.9 2207 1.7 1.7 -0.0 2279 1.1 1.1 0.1 2352 0.6 0.4 0.5 2424 0.6 -0.6 0.2 2497 0.4 0.2 0.4 2569 0.7 0.7 0.0 2641 0.3 0.3 0.2 2701 0.4 0.4 0.0 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 2842 ft 108.1° VI. TELECO SERVICES SURFACE SYSTEMS TELECO SERVICES TR2300-049: M-SERIES: DIRECTIONAL-GAMMA RESISTIVITY NEUTRON POROSITY COMPENSATED BULK DENSITY 1.33 SOFTWARE CONVENTIONAL MWD TOOLS: TYPE DATA TRANSMISSION SIZE S/N Directional 4X Miller 6 3/4" 644-52 MODULAR MWD TOOLS: TYPE DATA TRANSMISSION SIZE S/N Collar 3X SPLIT PHASE 6 3/4" 2536-08 Collar 3X SPLIT PHASE 6 3/4" 2601-10 Collar 3k SPLIT PHASE 6 3/4" 1617-23 Memory n/a 6 3/4" 6418 Neutron n/a 6 3/4" 6322 Neutron n/a 6 3/4" 6326 Density n/a 6 3/4" 6205 Dens ity n/a 6 3 / 4" 6310 Res/Gamma n/a 6 3/4" 6666 Res/Gamma n/a 6 3/4" 6189 Res/Gamma n/a 6 3/4" 6189-3 DOWNHOLE MEASURED PARAMETERS - DIRECTIONAL: INCLINATION, AZIMUTH, TOOL FACE ORIENTATION GAMMA: NATURAL GAMMA RADIATION RESISTIVITY: DUAL PROPAGATION NEUTRON: POROSITY, NEAR/FAR COUNTS DENSITY: COMPENSATED BULK DENSITY, PHOTO ELECTRIC CROSS SECT. TEMPERATURE: DOWNHOLE CIRCULATING SURFACE MEASUREMENTS - KELLY HEIGHT ROP (RATE OF PENETRATION), ' WOB (WEIGHT ON BIT) STANDPIPE PRESSURE (*) Explanation of Tool Types MOD-TFi: Teleco Tool Family 1 -- Dual Propagation Resistivity, Modular DC Natural Gamma Ray Detection (Scintillator) Neutron Porosity Compensated Bulk Density Directional D-TFI: Teleco Tool Family 1 -- Directional (only) ~o~. co~Po~o~ JUL 0 2 1992 Alaska Oil & Gas Cons. Commission Anchorage MICROFILMED GREAT LAND DIRECTIONAL DRILLING, INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY UNOCAL CORPORATION COMPANY GP 32-13 REDRILL WELL NAME GRANITE POINT PLATFORM LOCATION AL392Dll MWD 05/18/92 JOB NUMBER GARY PAUL TYPE SURVEY __ DATE SUPERVISOR NAME TITLE SIGNATURE TIE IN @ 8478.0 FT 12563.0 FT DEPTH INTERVAL FROM TO 03/15/92 05/10/92 DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. ..... 1 ....... -I ........ I / ...... 1 ....... ] ! 1 ' ! ' ! ! ! ....1 I 1 ....... } I ] ~ GREAT LAND DIRECTIONAL DRILLING, Client .... : Field ..... : Well ...... : Section at: Engineer..: UNOCAL CORPORATION GRANITE POINT GP 32-13 RD 124.30 GARY PAUL INC. S MEAS INCLN C DEPTH ANGLE 7 0 0.00 7 100 0.27 7 200 0.47 7 300 1.17 7 400 1.65 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 7 500 1.96 7 600 1.56 7 700 1.48 7 800 1.33 7 900 1.33 RECORD OF SURVEY 7 1000 1.17 7 1100 1.13 7 1200 0.98 7 1300 0.89 7 1400 0.86 DIRECTION AZIMUTH 7 1500 1.11 7 1600 0.70 7 1700 1.03 7 1800 4.19 7 1900 8.55 0.0 -109.0 0.0 0.00 100.0 -9.0 -0.2 314.98 200.0 91.0 -0.7 230.31. 300.0 191.0 -0.4 172.25 400.0 291.0 1.4 160.05 7 2000 11.21 7 2100 15.33 7 2125 15.33 499.9 390.9 4.1 154.09 599.9 490.9 6.7 152.01 699.8 590.8 9.1 153.56 799.8 690.8 11.1 160.44 899.8 790.8 13.0 164.27 999.7 890.7 1099.7 990.7 1199.7 1090.7 1299.7 1190.7 1399.7 1290.7 1499.7 1390.7 1599.7 1490.7 1699.6 1590.6 1799.5 1690.5 1898.9 1789.9 1997.4 1888.4 2094.7 1985.7 2118.8 2009.8 Computation...: Survey Date...: KB Elevation..: Reference ..... : Magnetic DCln..- RELATIVE-COORDINATES FROM-WELL-HEAD 0.0 N 0.0 E 0.2 N 0.2 W 0.2 N 0.8 W 1.1 S 1.3 W · 3.5 S 0.7 W 3:13 PM 2) ^Survey Codes: 7/GYRO (GLDD (c)92 3213R3D B1.30 6..4 S 0.6 E 9.1 S 2.0 E 11.5 S 3.2 E 13.7 S 4.1 E 15.9 S 4.8 E 14.7 162.13 18.0 S 5.5 E 16.2 167.58 20.0 S 6.0 E 17.4 176.91 21.8 S 6.2 E 18.4 180.43 23.4 S 6.3 E 19.1 190.73 24.9 S 6.1 E 05/19/92 RADIUS OF CURVATURE 05/19/92 109.00 ft AL392Dll 23.10 E 176.56 26.6 S 6.0 E 196.54 28.2 'S 5.8 E 182.33 29.7 S 5.6 E 106.04 33.1 S 8.1 E 110.95 36.6 S 18.6 E 20.0 20.7 21.3 25.3 36.0 53.0 124.27 44.6 S 33.7 E 75.9 129.82 58.4 S 52.1 E 82.5 129.82 62.6 S 57.1 E CLOSURE DISTNCE AZIMUTH /lOO 6.4 174.95 0.31 9.3 167.89 0.40 11.9 164.56 0.08 14.3 163.27 0.15 16.6 163.14 0.00 18.8 163.15 0.16 20.8 163.31 0.04 22.7 164.03 0.15 24.2 165.01 0.0S 25.7 166.20 0.03 27.3 167.28 0.25 28.8 168.31 0.41 30.2 169.34 0.33 34.1 166.32 3.19 41.1 153.11 4.36 55.9 142.87 2.71 78.2 138.28 4.14 84.8 137.62 0.00 0.0 0.00 0.00 0.2 314.98 0.27 0.8 284.40 0.20 1.7 229.13 0.70 3.5 190.84 0.48 1 ........ ! I ] .....} I I I ' ! '1 ! ' I ~ 1 1 1 1 I ! ' GP 32-13 RD S MEAS INCLN C DEPTH ANGLE 7 2150 15.45 7 2175 15.45 7 2200 15.45 7 2225 15.61 7 2250 15.65 7 2275 15.75 7 2300 15.79 7 2325 15.87 7 2350 15.86 7 2375 15.98 7 2400 15.95 7 2425 15.93 7 2450 16.04 7 2475 16.06 7 2500 16.25 7 2525 17.00 7 2550 17.49 7 2575 18.20 7 2600 17.14 7 2625 16.79 7 2650 16.53 7 2675 16.47 7 2700 16.12 7 2725 16.06 7 2750 15.68 7 2775 15.58 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY SECTION DISTNCE DIRECTION AZIMUTH RELATIVE-COORDINATES FROM-WELL-HEAD Page 2 05/19/92 CLOSURE DISTNCE AZIMUTH 2142.9 2033.9 89.1 130.26 66.9 S 62.2 E 91.3 137.07 2167.0 2058.0 95.7 130.26 71.2 S 67.3 E 98.0 136.61 2191.1 2082.1 102.3 130.26 75.5 S 72.4 E 104.6 136.21 2215.2 2106.2 109.0 130.28 79.8 S 77.5 E 111.2 135.85 2239.3 2130.3 115.7 130.24 84.2 S 82.6 E 117.9 135.53 2263.3 2154.3 122.4 130.38 2287.4 2178.4 129.2 130.33 2311.4 2202.4 136.0 130.29 2335.5 2226.5 142.7 130.22 2359.5 2250.5 149.6 130.20 88.5S 87.8 E 92.9 S 93.0 E 97.4 S 98.2 E 101.8 S 103.4 E 106.2 S 108.6 E DL /lOO 0.50 0.00 0.00 0.6/ 0.16 124.7 135.25 0,40 131.5 135.00 0.16 138.3 134.77 0.32 145.1 134.55 0.05 151.9 134.36 0.48 2383.6 2274.6 156.4 130.36 110.6 S 113.9 E 158.8 134.18 2407.6 2298.6 163.2 130.45 115.1 S 119.1 E 165.6 134.02 2431.6 2322.6 170.1 130.72 119.6 S 124.3 E 172.5 133.89 2455.7 2346.7 176.9 130.78 124.1 S 129.5 E 179.4 133.77 2479.7 2370.7 183.9 131.03 128.6 S 134.8 E 186.3 133.66 133.4 S 140.1 E 193.5 133.59 138.4 S 145.7 E 200.9 133.53 143.5 S 151.3 E 208.6 133.48 148.6 S 156.9 E 216.1 133.44 153.4 S 162.5 E 223.4 133.36 2503.6 2394.6 190.9 132.53 2527.5 2418.5 198.3 131.33 2551.3 2442.3 205.9 133.06 2575.1 2466.1 213.4 131.39 2599.0 2490.0 220.6 130.54 2623.0 2514.0 227.8 129.40 2647.0 2538.0 234.9 127.76 2671.0 2562.0 241.9 123.39 2695.0 2586.0 248.8 120.69 2719.0 2610.0 255.6 116.29 2743.1 2634.1 262.2 112.36 158.0 S 167.9 E 230.6 133.25 162.4 S 173.5 E 237.7 133.11 166.5 S 179.2 E 244.6 132.90 170.2 S 185.1 E 251.4 132.60 173;4 S 191.1 E 258.1 132.23 176.2 S 197.2 E 264.5 131.78 0.13 0.08 0.45 0.08 0.76 3.04 2.01 2.92 4.28 1.42 1.10 0.58 1.94 0.86 1.99 1.20 ^Survey Codes: 7/GYRO .... 1 ] ........ 1 ...... I I ! I I I i. ! 'I ? 3 - 1 I I I 'l / GP 32-13 i S MEAS C DEPTH 7 2800 7 2825 7 2850 7 2875 7 2900 7 2925 7 2950 7 2975 7 3000 7 3025 7 3050 7 3075 7 3100 7 3125 7 3150 7 3175 7 3200 7 3225 7 3250 7 3275 7 3300 7 3325 7 3350 7 3375 7 3400 7 3425 RD INCLN ANGLE 15.'29 15.41 14.93 13.82 13.04 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY SECTION DISTNCE DIRECTION AZIMUTH 2767.2 2658.2 268.7 110.91 2791.3 2682.3 275.1 108.22 2815.4 2706.4 281.3 104.87 2839.7 2730.7 287.1 100.13 2864.0 2755.0 292.3 95.54 12.60 2888.3 2779.3 297.0 12.57 2912.7 2803.7 301.3 12.21 2937.2 2828.2 305.3 12.27 2961.6 2852.6 308.9 12.35 2986.0 2877.0 312.3 12.70 3010.4 2901.4 315.6 13.09 3034.8 2925.8 319.0 13.38 3059.1 2950.1 322.5 13.87 3083.4 2974.4 326.0 14.29 3107.7 2998.7 329.7 14.69 3131.9 3022.9 333.6 15.15 3156.0 3047.0 337.6 15.44 3180.2 3071.2 341.7 15.47 3204.3 3095.3 345.9 15.43 3228.3 3119.3 350.1 15.43 3252.4 3143.4 354.4 15.23 3276.6 3167.6 358.6 15.05 3300.7 3191.7 362.8 14.87 3324.8 3215.8 366.9 14.90 3349.0 3240.0 371.0 14.81 3373.2 3264.2 375.1 ^Survey Codes: 7/GYRO RELATIVE-COORDINATES FROM-WELL-HEAD Page 3 05/19/92 CLOSURE DISTNCE AZIMUTH 178.7 S 203.4 E 270.7 131.29 180.9 S 209.6 E 276.9 130.79 182.7 S 215.9 E 282.9 130.24 184.1 'S 222.0 E 288.4 129.67 184.9 S 227.7 E 293.3 129.07 90.31 185.2 S 233.3 E 82.86 184.8 S 238.7 E 79.73 184.0 S 244.0 E 75.45 182.9 S 249.2 E 72.75 181.4 S 254.3 E 297.8 128.44 301.9 127.75 305.6 127.02 309.1 126.28 312.4 125.51 71.42 179.8 S 259.5 E 315.6 124.72 71.65 178.0 S 264.7 E 319.0 123.91 71.29 176.2 S 270.2 E 322.5 123.11 71.63 174.3 S 275.8 E 326.2 122.30 72.33 172.4 S 281.5 E 330.1 121.48 72.54 170.5 S 287.5 E 334.3 120.67 73.00 168.6 S 293.6 E 338.6 119.87 73.20 166.7 S 300.0 E 343.2 119.06 73.49 164.8 S 306.3 E 347.9 118.28 73.67 162.9 S 312.7 E 352.6 117.52 74.07 161.1 S 319.1 E 357.5 116.78 73.93 159.2 S 325.5 E 362.3 116.07 73.73 157.4 S 331.7 E 367.2 115.39 73.86 155.6 S 337.9 E 372.1 114.73 74.93 153.9 S 344.1 E 377.0 114.09 152.1 S 350.3 E 73.43 381.9 113.48 DL /lOO 1.23 0.90 2.12 4.57 3.26 2.02 1.42 1.55 0.81 0.59 1.42 1.56 1.16 1.96 1.69 1.60 1.84 1.16 0.15 o. 1~ 0.11 0.80 0.72 0.72 0.31 0.53 ..... 1 1 ! ! 'l .....I "1 '/ ! I / ? 1 I } I I - i ~t I GP 32-13 RD S MEAS INCLN C DEPTH ANGLE I 7 3450 14.65 7 3475 14.60 7 3500 14.17 7 3525 13.99 7 3550 14.17 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY SECTION DISTNCE DIRECTION AZIMUTH RELATIVE-COORDINATES FROM-WELL-HEAD 3397.3 3288.3 379.2 74.03 150.4 S 356.4 E 3421.5 3312.5 383.2 73.83 148.6 S 362.5 E 3445.8 3336.8 387.2 74.57 146.9 S 368.4 E 3470.0 3361.0 391.1 75.05 145.3 S 374.3 E 3494.3 3385.3 395.1 74.85 143.8 S 380.2 E 7 3575 14.05 3518.5 3409.5 7 3600 13.77 3542.8 3433.8 7 3625 13.60 3567.1 3458.1 7 3650 13.67 3591.3 3482.3 7 3675 13.40 3615.7 3506.7 7 3700 13.05 3640.0 3531.0 7 3725 13.11 3664.3 3555.3 7 3750 13.06 3688.7 3579.7 7 3775 13.22 3713.0 3604.0 7 3800 13.09 3737.4 3628.4 7 3825 13.02 3761.7 3652.7 7 3850 12.95 3786.1 3677.1 7 3875 12.85 3810.5 3701.5 7 3900 12.87 3834.8 3725.8 7 3925 12.85 3859.2 3750.2 7 3950 13.07 3883.6 3774.6 7 3975 12.97 3907.9 3798.9 7 4000 12.91 3932.3 3823.3 7 4025 12.89 3956.7 3847.7 7 4050 12.95 3981.0 3872.0 399.0 403.0 406.8 410.7 414.5 418.2 421.9 425.6 429.2 432.9 Page 4 05/19/92 CLOSURE DISTNCE AZIMUTH 386.8 112.88 391.7 112.30 396.7 111.74 401.5 111.22 406.4 110.71 74.86 142.2 S 386.1 E 411.4 110.22 75.47 140.6 S 391.9 E 416.3 109.74 74.66 139.1 S 397.6 E 421.2 109.28 75.21 137.6 S 403.3 E 426.1 108.84 75.04 136.1 S 408.9 E 431.0 108.40 7 4075 12.86 4005.4 3896.4 74.96 134.6 S 414.5 E 435.8 107.99 74.60 133.1 S 419.9 E 440.5 107.59 74.80 131.6 S 425.4 E 445.3 107.19 74.34 130.1 S 430.9 E 450.1 106.80 74.37 128.6 S 436.3 E 454.9 106.42 436.5 74.66 127.1 S 441.8 E 459.7 106.05 440.2 74.49 125.6 S 447.2 E 464.5 105.68 443.8 74.36 124.1 S 452.6 E 469.3 105.33 447.4 74.57 122.6 S 457.9 E 474.0 104.98 451.0 74.87 121.1 S 463.3 E 478.9 104.65 74.32 119.6 S 468.7 E 483.7 104.32 74.48 118.1 S 474.1 E 488.6 103.99 74.61 116.6 S 479.5 E 493.5 103.67 74.58 115.1 S 484.9 E 498.4 103.36 74.45 113.6 S 490.3 E 503.3 103.05 74.51 112.1 S 495.7 E ^Survey Codes: 7/GYRO 454.6 458.2 461.8 465.5 469.1 472.7 508.2 102.75 DL /lOO 0.66 0.21 1.73 0 72 '~ 0~72 .... 0.48 1.13 0.70 0.31 1.08 1.40 0.25 0.20 0.65 0.52 0.29 0.28 0.40 0.09 o. lO 0.89 0.40 0.24 0.08 0.24 0.36 GP 32-13 RD S MEAS INCLN C DEPTH ANGLE ._ 7 4100 12.81 7 4125 12.99 7 4150 12.89 7 4175 12.81 7 4200 12.71 VERTICAL-DEPTHS BKB SUB-SEA 4029.8 3920.8 4054.1 3945.1 4078.5 3969.5 4102.9 3993.9 4127.3 4018.3 7 4225 12.80 4151.? 4042.7 7 4250 12.73 4176.0 4067.0 7 4275 12.78 4200.4 4091.4 7 4300 12.74 4224.8 4115.8 7 4325 12.76 4249.2 4140.2 7 4350 12.72 4273.6 4164.6 7 4375 12.74 4298.0 4189.0 7 4400 12.71 4322.3 4213.3 7 4425 12.58 4346.7 4237.7 7 4450 12.56 4371.1 4262.1 7 4475 12.60 4395.5 4286.5 7 4500 12.40 4419.9 4310.9 7 4525 12.50 4444.4 4335.4 7 4550 12.35 4468.8 4359.8 7 4575 12.34 4493.2 4384.2 7 4600 12.18 4517.6 4408.6 7 4625 12.31 4542.0 4433.0 7 4650 11.93 4566.5 4457.5 7 4675 12.20 4590.9 4481.9 7 4700 12.15 4615.4 4506.4 7 4725 11.92 4639.8 4530.8 RECORD OF SURVEY SECTION DISTNCE 476.2 479.8 483.4 487.0 490.6 494.2 497.8 501.3 504.9 508.5 DIRECTION AZIMUTH 74.42 74.02 74.50 74.73 74.89 RELATIVE-COORDINATES FROM-WELL-HEAD Page 5 05/19/92 CLOSURE DISTNCE AZIMUTH 110.7 S 501.0 E 513.1 102.45 109.1 S 506.4 E 518.0 102.16 107.6 S 511.8 E 523.0 101.88 106.1 S 517.1 E 527.9 101.60 104.7 S 522.5 E 532.9 101.33 74.66 103.2 S 527.8 E 537.8 101.07 74.66 101.8 S 533.1 E 542.7 100.81 74.72 100.3 S 538.4 E 547.7 100.55 74.94 98.9 S 543.8 E 552.7 100.31 74.15 97.4 S 549.1 E 557.7 100.06 512.0 74.38 95.9 S 554.4 E 562.6 99.82 515.6 74.54 94.4 S 559.7 E 567.6 99.58 519.1 74.52 93.0 S 565.0 E 572.6 99.34 522.7 74.33 91.5 S 570.3 E 577.6 99.12 526.2 74.45 90.0 S 575.5 E 582.5 98.89 529.7 533.2 536.6 540.1 543.6 74.13 88.6 S 580.8 E 74.55 87.1 S 586.0 E 74.49 85.7 S 591.2 E 74.70 84.2 S 596.4 E 74.57 82.8 S 601.5 E 587.5 98.67 592.4 98.45 597.3 98.25 602.3 98.04 607.2 97.84 547.0 74.66 81.4 S 606.6 E 612.1 97.64 550.4 74.55 80.0 S 611.7 E 616.9 97.45 553.8 74.35 78.6 S 616.8 E 621.8 97.26 557.2 74.01 77.2 S 621.8 E 626.6 97.07 560.6 74.42 75.7 S 626.9 E 631.5 96.89 563.9 74.39 74.3 S 631.9 E 636.3 96.71 DL /1oo 0.20 0.72 0.41 0.31 0.40 0.36 0.28 0.20 ' 0.17 0.17 0.17 0.09 0.12 0.52 0.08 0.17 0.80 0.40 0.60 o. 05 0.64 0.52 1.52 1.08 0.21 0 92 ^Survey Codes: 7/GYRO GP 32-13 RD S MEAS INCLN C DEPTH ANGLE 7 4750, 11.74 7 4775 11.73 7 4800 11.66 7 4825 11.60 7 4850 11.61 7 4875 11.58 7 4900 11.62 7 4925 11.62 7 4950 11.54 7 4975 11.58 7 5000 11.41 7 5025 11.36 7 5050 11.35 7 5075 11.46 7 5100 11.39 7 5125 11.28 7 5150 11.21 7 5175 11.13 7 5200 11.17 7 5225 10.92 7 5250 10.92 7 5275 11.~04 7 5300 10.96 7 5325 10.73 7 5350 10.68 7 5375 10.54 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY SECTION DISTNCE DIRECTION AZIMUTH RELATIVE-COORDINATES FROM-WELL-HEAD Page 6 05/19/92 CLOSURE DISTNCE AZIMUTH 4664.3 4555.3 567.2 74.40 73.0 S 636.9 E 641.0 96.54 4688.8 4579.8 570.5 74.19 71.6 S 641.7 E 645.7 96.36 4713.3 4604.3 573.7 74.36 70.2 S 646.6 E 650.4 96.20 4737.7 4628.7 577.0 74.88 68.9 S 651.5 E 655.1 96.~03 4762.2 4653.2 580.3 74.49 67.5 S 656.3 E 659.8 95.88 4786.7 4677.7 583.5 75.05 66.2 S 661.2 E 664.5 95.72 4811.2 4702.2 586.8 74.79 64.9 S 666.0 E 669.2 95.57 4835.7 4726.7 590.1 75.11 63.6 S 670.9 E 673.9 95.42 4860.2 4751.2 593.4 75.52 62.3 S 675.8 E 678.6 95.27 4884.7 4775.7 596.7 75.65 61.1 S 680.6 E 683.3 95.13 4909.2 4800.2 600.0 75.62 59.9 S 685.4 E 4933.7 4824.7 603.2 75.46 58.6 S 690.2 E 4958.2 4849.2 606.5 75.28 57.4 S 695.0 E 4982.7 4873.7 609.7 75.67 56.1 S 699.8 E 5007.2 4898.2 613.0 75.90 54.9 S 704.6 E 5031.7 4922.7 616.3 76.08 53.7 S 709.3 E 5056.2 4947.2 619.5 75.64 52.5 S 714.1 E 5080.8 4971.8 622.7 75.82 51.3 S 718.8 E 5105.3 4996.3 625.9 75.28 50.1 S 723.4 E 5129.8 5020.8 629.0 76.18. 49.0 S 728.1 E DL /1oo 5154.4 5045.4 632.2 76.21 5178.9 5069.9 635.4 76.36 5203.5 5094.5 638.6 76.57 5228.0 5119.0 641.8 76.60 5252.6 5143.6 644.9 76.85 0.72 0.05 0~28 0 · 2~ 0 .'07 0.15 0.17 0.05 0.33 0.16 688.0 94.99 0.68 692.7 94.85 0.20 697.3 94.72 0.05 702.0 94.59 0.44 706.7 94.46 0.28 711.4 94.33 0.44 716.0 94.21 0.29 720.6 94.09 0.32 725.2 93.96 0.18 729.7 93.85 1.0] 47.8 S 732.7 E 734.2 93.73 46.7 S 737.3 E 738.8 93.62 45..6 S 741.9 E 743.3 93.52 44.5 S 746.5 E 747.8 93.41 43.4 S 751.0 E 752.3 93.31 5277.2 5168.2 648.0 76.87 42.4 S 755.5 E 756.7 93.21 0.00 0.48 0.32 0.92 0.20 0.56 ^Survey Codes: 7/GYRO SP 32-13 RD MEAS INCLN DEPTH ANGLE 5400 10.44 5425 10.26 5450 10.36 5475 10.15 5500 10.09 7 5525 10.12 7 5550 9.81 7 5600 9.68 7 5625 9.58 7 5650 9.32 7 5675 9.10 7 5700 9.04 7 5725 9.02 7 5750 9.13 7 5775 9.10 7 5800 9.13 7 5825 9.12 7 5850 9.05 7 5875 8.82 7 5900 8.84 7 5925 8.69 7 5950 8.77 7 5975 8.68 7 6000 8.52 7 6025 8.21 7 6050 8.07 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 5301.7 5192.7 651.1 5326.3 5217.3 654.2 5350.9 5241.9 657.2 5375.5 5266.5 660.3 5400.1 5291.1 663.3 5424.8 5315.8 666.4 5449.4 5340.4 669.3 5498.7 5389.7 675.1 5523.3 5414.3 678.0 5548.0 5439.0 680.8 5572.6 5463.6 683.4 5597.3 5488.3 686.0 5622.0 5513.0 688.6 5646.7 5537.7 691.2 5671.4 5562.4 693.7 5696.1 5587.1 696.3 5720.8 5611.8 698.8 5745.4 5636.4 701.4 5770.1 5661.1 704.0 5794.8 5685.8 706.6 5819.6 5710.6 709.1 5844.3 5735.3 711.6 5869.0 5760.0 714.1 5893.7 5784.7 716.5 5918.4 5809.4 718.9 RECORD OF SURVEY 5943.2 5834.2 721.2 DIRECTION AZIMUTH 76.99 77.94 77.70 77.88 78.12 77.77 77.49 77.36 77.21 76.75 RELATIVE-COORDINATES FROM-WELL-HEAD Page 7 05/19/92 CLOSURE DISTNCE AZIMUTH 41.3 S 759.9 E 761.1 93.11 40.4 ~S 764.3 E 765.4 93.02 39.4 S 768.7 E 769.7 92.94 38.5 S 773.1 E 774.0 92.85 37.6 S 777.4 E 778.3 92.77 36.7 S 781.6 E 782.5 92.69 35.7 S 785.9 E 786.7 92.60 33.9 S 794.1 E 794.9 92.44 33.0 S 798.2 E 798.9 92.37 - 32.0 S 802.2 E 802.8 92.29 76.26 31.1 S 806.1 E 806.7 92.21 74.86 30.1 S 809.9 E 810.5 92.13 75.13 29.1 S 813.7 E 814.2 92.05 74.35 28.1 S 817.5 E 818.0 91.97 74.38 27.0 S 821.3 E 821.8 91.88 74.59 74.87 75.60 76.08 76.30 25.9 S 825.1 E 825.5 91.80 24.9 S 829.0 E 829.3 91.72 23.9 S 832.8 E 833.1 91.64 22.9 S 836.5 E 836.9 91.57 22.0 S 840.3 E 840.6 91.50 21.1 S 844.0 E 844.2 91.43 20.2 S 847.6 E 847.9 91.36 19.2 S 851.3 E 851.5 91.29 18.2 S 854.9 E 855.1 91.22 17.3 S 858.4 E 858.6 91.15 16.4 S 861.9 E 75.71 75.43 75.08 74.75 75.53 75.86 DL /lOO 0.40 0.73 0.40 0.84 0.24 0.13 1.24 0.26 0.40 1.04 0.88 0.28 0.08 0.45 0.12 0.12 0.05 0.29 0.92 0.08 0.60 0.32 0.36 0.64 1.24 862.0 91.09 0.56 ^Survey Codes: 7/GYRO GP 32-13 RD S MEAS INCLN C DEPTH ANGLE 7 6075 8.12 7 6100 8.27 7 6125 8.59 7 6150 9.42 7 6175 10.54 7 6200 10.70 7 6225 10.88 7 6250 11.06 7 6275 11.58 7 6300 11.68 7 6325 11.72 7 6350 12~09 7 6375 12.18 7 6400 12.45 7 6425 12.76 7 6450 12.87 7 6475 13.10 7 6500 13.39 7 6525 13.63 7 6550 13.80 7 6575 14.14 7 6600 14.42 7 6625 14.56 7 6650 14.77 7 6675 14.47 7 6725 14.65 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY SECTION DISTNCE DIRECTION AZIMUTH RELATIVE-COORDINATES FROM-WELL-HEAD Page 8 05/19/92 CLOSURE DISTNCE AZIMUTH 5967.9 5858.9 723.6 77.36' 15.6 S 865.3 E 865.4 91.03 5992.7 5883.7 726.1 78.92 14.9 S 868.8 E 868.9 90.98 6017.4 5908.4 728.6 78.09 14.1 S 872.4 E 872.5 90.93 6042.1 5933.1 731.3 78.36 13.3 S 876.2 E 876.3 90.87 6066.7 5957.7 734.3 75.85 12.4 S 880.4 E 880.5 90.81 6091.3 5982.3 737.3 75.53 11.2 S 884.9 E 885.0 90.73 6115.8 6006.8 740.4 74.97 10.0 S 889.4 E 889.5 90.65 6140.4 6031.4 743.5 74.76 8.8 S 894.0 E 894.0 90.56 6164.9 6055.9 746.7 74.87 7.5 S 898.7 E 898.8 90.48 6189.4 6080.4 750.0 75.65 6.2 S 903.6 E 903.6 90.40 6213.9 6104.9 753.3 75.38 6238.3 6129.3 756.8 76.73 6262.8 6153.8 760.3 77.54 6287.2 6178.2 764.0 78.46 6311.6 6202.6 767.8 78.75 6336.0 6227.0 771.8 79.85 6360.3 6251.3 775.8 81.36 6384.7 6275.7 780.0 82.18 6409.0 6300.0 784.4 82.82 6433.3 6324.3 788.9 84.35 5.0 S 908.5 E 908.5 90.31 3.7 S 913.5 E 913.5 90.23 2.6 S 918.7 E 918.7 90.16 1.4 S 923.9 E 923.9 90.09 0.4,S 929.2 E 929.2 90.02 0.7 N 934.7 E 934.7 89.96 1.6 N 940.2 E 940.2 89.90 2.4 N 945.9 E 945.9 89.85 3.2 N 951.7 E 951.7 89.81 3.8 N 957.6 E 957.6 89.77 4.3 N 963.6 E 963.6 89.74 4.7 N 969.7 E 969.7 89.72 5.0 N 976.0 E 976.0 89.71 5.1 N 982.3 E 982.3 89.70 5.1 N 988.6 E 988.6 89.70 5.1 N 1001.2 E 1001.2 89.71 6457.5 6348.5 793.6 85.94 6481.7 6372.7 798.4 87.20 6506.0 6397.0 803.5 88.17 6530.1 6421.1 808.6 89.24 6554.3 6445.3 813.8 89.85 6602.7 6493.7 824.2 90.63 DL /lOO 0.23 0.61 1.28 3.3' 4.49 0.64 0.72 0.72 2.08 0.42 0.17 1.50 0.39 1.09 1.24 0.49 0.97 1.17 0.97 0.7( 1.41 1.16 0.61 0.88 1.21 0.37 ^Survey Codes: 7/GYRO GP 32-13 RD MEAS INCLN DEPTH ANGLE 6750 14.46 6775 14.44 6800 14.36 6825 14.32 6850 14.55 VERTICAL-DEPTHS BKB SUB-SEA 6626.9 6517.9 6651.1 6542.1 6675.3 6566.3 6699.6 6590.6 6723.8 6614.8 7 6875 15.03 6747.9 6638.9 7 6900 15.71 6772.1 6663.1 7 6925 15.87 6796.1 6687.1 7 6950 16.58 6820.1 6711.1 7 6975 17.37 6844.0 6735.0 7 7000 17.70 6867.9 6758.9 7 7025 18.16 6891.6 6782.6 7 7050 17.98 6915.4 6806.4 7 7075 18.03 6939.2 6830.2 7 7100 17.68 6963.0 6854.0 7 7200 17.37 7058.3 6949.3 7 7300 16.29 7154.1 7045.1 7 7400 15.49 7250.2 7141.2 7 7500 16.01 7346.5 7237.5 7 7600 16.69 7442.4 7333.4 7 7700 17.98 7537.9 7428.9 7 7800 17.34 7633.2 7524.2 7 7900 17.61 7728.6 7619.6 7 8000 17.16 7824.0 7715.0 7 8100 16.30 7919.8 7810.8 7 8200 15.22 8016.0 7907.0 RECORD OF SURVEY SECTION DISTNCE 829.4 834.6 839.9 845.1 850.3 855.7 861.2 867.0 872.8 879.0 885.3 891.9 898.4 904.9 911.4 936.~9 961.7 985.5 1009.7 1035.4 1062.9 1090.7 1118.0 1145.4 1171.9 1197.0 DIRECTION AZIMUTH 90.62 91.37 91.47 91.42 91.71 91.17 91.68 91.53 91.71 91.45 92.27 92.21 91.40 91.76 92.07 92.41 93.85 95.91 99.16 100.96 101.84 99.60 100.23 101.08 101.63 102.44 RELATIVE-COORDINATES FROM-WELL-HEAD 5.0 N 4.9 N 4.8 N 4.6 N 4.4 N Page 9 05/19/92 4.3 N 4.1 N 3.9 N 3.7 N 3.5 N CLOSURE DL DISTNCE AZIMUTH / 100 3.3 N 3.0 N 2.7 N 2.5 N 2.3 N 1007.5 E 1007.5 89.71 0.76 1013.7 E 1013.7 89.72 0.20 1019.9 E 1019.9 89.73 0.32 1026.1 E 1026.1 89.74 0.1~ 1032.3 E 1032.3 89.75 0.9~ 1.1 N 0.5 S 2.8 S 6.4 S 11.3 S 1038.7 E 1038.7 89.76 1.93 1045.3 E 1045.3 89.77 2.72 1052.1 E 1052.1 89.79 0.64 1059.1 E 1059.1 89.80 2.84 1066.4 E 1066.4 89.81 3.16 17.2 S 22.8 S 28.0 S 33.5 S 39.2 S 1073.9 E 1074.0 89.83 1.35 1081.6 E 1081.6 89.84 1.84 1089.4 E 1089.4 89.86 0.78 1097.1 E 1097.1 89.87 0.24 1104.8 E 1104.8 89.88 1.40 1134.9 E 1134.9 89.95 0.31 1163.8 E 1163.8 90.02 1.09 1191.0 E 1191.1 90.14 0.81 1218.0 E ~ 1218.0 90.30 0.58 -1245.7 E 1245.7 90.52 0.7~ 1274.9 E 1275.0 90.77 1'.~29 1304.7 E 1304.9 91~00 0.67 1334.3 E 1334.6 91.20 0.28 1363.6 E 1364.0 91.41 0.46 1391.9 E 1392.4 91.61 0.86 44.9 S 1418.4 E 1419.1 91.81 1.08 ^Survey Codes: 7/GYRO SP 32-13 RD MEAS INCLN DEPTH ANGLE 8300 15.07 8400 13.93 8478 16.70 8595 19.60 8687 21.40 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 8112.5 8003.5 1221.4 8209.3 8100.3 1244.8 8284.6 8175.6 1264.0 8395.7 8286.7 1298.9 8481.9 8372.9 1330.9 3 8753 24.00 8542.8 8433.8 1356.3 3 8858 26.10 8637.9 8528.9 1400.6 3 8948 26.40 8718.6 8609.6 1440.3 3 9072 26.70 8829.5 8720.5 1495.5 3 9159 27.20 8907.1 8798.1 1534.7 3 9256 29.20 8992.6 8883.6 1580.3 3 9365 30.10 9087.3 8978.3 1634.2 N 9410 29.97 9126.3 9017.3 1656.7 3 9473 35.90 9179.1 9070.1 1690.8 3 9500 37.60 9200.7 9091.7 1706.9 3 9569 41.00 9254.1 9145.1 1750.5 3 9663 43.90 9323.5 9214.5 1813.9 3 9720 46.00 9363.8 9254.8 1854.1 3 9755 47.30 9387.8 9278.8 1879.6 3 9846 50.40 9447.7 9338.7 1948.1 3 9939 54.50 9504.4 9395.4 2021.8 3 9992 56.40 9534.4 9425.4 2065.4 3 10035 56.60 9558.2 9449.2 2101.2 3 10071 57.60 9577.7 9468.7 2131.4 3 10129 58.00 9608.6 9499.6 2180.4 RECORD OF SURVEY 3 10180 58.90 9635.3 9526.3 2223.8 DIRECTION AZIMUTH 103.42 104.03 102.60 112.70 125.80 RELATIVE-COORDINATES FROM-WELL-HEAD Page 10 05/19/92 CLOSURE DISTNCE AZIMUTH 50.7 S 1443.9 E 1444.8 92.01 56.6 S 1468.2 E 1469.3 92.21 61.4 S 1488.2 E 1489.5 92.36 72.4 S 1522.9 E 1524.6 92.72 88.1 S 1551.0 E 1553.5 93.25 129.30 103.6 S 1571.2 E 129.30 131.8 S 1605.6 E 129.60 157.1 S 1636.3 E 129.60 192.4 S 1679.0 E 130.30 217.7 S 1709.2 E DL /lOO 0.16 1.14 3.55 2.6f 2.72 128.60 127.20 127.64 128.70 128.80 128.20 125.40 124.40 124.70 122.90 1574.6 93.77 4.04 1611.0 94.69 2.00 1643.8 95.48 0.34 1690.0 96.54 0.24 1723.0 97.26 0.60 246.9 S 1744.6 E 1762.0 280.0 S 1787.2 E 1809.0 293.7 S 1805.1 E 1828.8 314.8 S 1832.0 E 1858.8 324.9 S 1844.6 E 1873.0 352.2 S 1878.8 E 1911.5 390.1 S 1929.6 E 1968.6 413.2 S 1962.6 E 2005.6 427.6 S 1983.6 E 2029.1 465.7 S 2040.5 E 2093.0 121.90 505.2 S 2102.7 E 2162.6 121.50 528.2 S 2139.9 E 2204.1 121.20 546.8 S 2170.5 E 2238.3 121.90 562.6 S 2196.2 E 2267.2 121.50 588.4 S 2238.0 E 2314.1 611.0 S 2275.1 E 2355.7 121.20 98.05 2.10 98.90 0.89 99.24 ' 0.37 99.75 9.42 99.99 6.30 100.62 4.94 101.43 3.40 101.89 3.79 102.17 3.74 102.86 3.60 103.51 4.47 103.86 3.62 104.14 0.67 104.37 3.10 104.73 0.85 105.03 1.82 ^Survey Codes: 3/MWD 7/GYRO N/INTERPOLATED GP 32-13 RD S MEAS INCLN C DEPTH ANGLE 3 10222 58.90 3 10284 59.20 3 10317 59.'00 3 10347 58.80 3 10376 58.40 3 10413 58.60 3 10438 58.80 3 10462 58.70 3 10504 58.70 3 10534 58.70 3 10565 59.10 3 10599 59.40 3 10650 59.70 3 10689 59.70 3 10720 59.70 3 10749 59.80 3 10782 59.80 3 10906 65.00 3 10939 67.30 3 10965 68.00 3 11000 67.50 3 11055 66.80 3 11095 66.30 3 11120 66.10 3 11149 65.90 3 11185 66.80 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY SECTION DISTNCE DIRECTION AZIMUTH 9657.0 9548.0 2259.7 121.50 9688.9 9579.9 2312.8 121.90 9705.9 9596.9 2341.1 122.20 9721.3 9612.3 2366.8 122.20 9736.5 9627.5 2391.5 122.20 RELATIVE-COORDINATES FROM-WELL-HEAD 629.8 S 657.7 S 672.7 S 686.4 S 699.6 S 9755.8 9646.8 2423.1 122.20 716.4 S 9768.8 9659.8 2444.4 122.20 727.8 S 9781.2 9672.2 2464.9 122.60 738.8 S 9803.0 9694.0 2500.8 122.60 758.1 S 9818.6 9709.6 2526.4 122.60 771.9 S 9834.6 9725.6 2553.0 122.60 786.2 S 9852.0 9743.0 2582.2 122.60 802.0 S 9877.9 9768.9 2626.1 122.60 825.7 S 9897.6 9788.6 2659.8 122.60 843.8 S 9913.2 9804.2 2686.5 122.60 858.2 S 9927.8 9818.8 2711.6 122.60 9944.4 9835.4 2740.1 122.60 10001.8 9892.8 2849.9 127.30 10015.2 9906.2 2880.0 125.40 10025.1 9916.1 2904.1 124.70 871.7 S 887.1 S 950.0 S 967.9 S 981.7 S 10038.3 9929.3 2936.5 125.20 1000.3 S 10059.7 9950.7 2987.2 124.60 1029.3 S 10075.6 ~9966.6 3023.8 126.10 1050.5 S 10085.7 9976.7 3046.7 125.40 1063.8 S 10097.5 9988.5 3073.2 125.20 1079.2 S Page 11 05/19/92 CLOSURE DL DISTNCE AZIMUTH /100 2305.8 E 2390.3 105.28 0.52 2351.1 E 2441.3 105.63 0.68 2375.1 E 2468.5 105.81 0.90 2396.8 E 2493.2 105.98 0.67 2417.8 E 2516.9 106.14 1.38 2444.5 E 2547.3 106.33 0.54 2462.5 E 2567.8 106.46 0.80 2479.9 E 2587.6 106.59 1.29 2510.1 E 2622.1 106.81 0.00 2531.7 E 2646.7 106.96 0.00 2554.0 E 2672.3 107.11 1.29 2578.7 E 2700.5 107.28 0.88 2615.7 E 2742.9 107.52 0.59 2644.1 E 2775.4 107.70 0.00 2666.6 E 2801.3 107.84 0.00 2687.7 E 2825.5 107.97 0.34 2711.7 E 2853.2 108.11 0.00 2801.8 E 2958.4 108.73 5.22 2826.1 E 2987.2 108.91 8.52 2845.8 E 3010.3 109.03 3.55 2872.3 E 3041.5 109.20 1.88 2913.9 E 3090.3 109.45 1.57 2943.8 E 3125.6 109.64 3.38 2962.4 E 3147.6 109.75 2.47 2984.0 E 3173.1 109.88 0.90 10111.9 10002.9 3106.2 124.20 1097.9 S 3011.1 E 3205.0 110.03 3.43 ^Survey Codes: 3/MWD GP 32-13 RD S MEAS INCLN C DEPTH ANGLE 3 11218 67.70 3 11262 69.00 3 11292 69.30 3 11336 68.80 3 11381 69.00 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 10124.7 10015.7 3136.6 10140.9 10031.9 3177.5 10151.6 10042.6 3205.5 10167.3 10058.3 3246.6 10183.5 10074.5 3288.6 3 11429 69.30 10200.6 10091.6 3 11477 69.10 10217.6 10108.6 3 11531 69.20 10236.9 10127.9 3 11625 70.50 10269.2 10160.2 3 11664 70.60 10282.2 10173.2 3 11696 70.10 10293.0 10184.0 3 11720 68.90 10301.4 10192.4 3 11778 68.60 10322.4 10213.4 3 11809 68.50 10333.8 10224.8 3 11902 68.40 10367.9 10258.9 3 11997 65.80 10404.9 10295.9 3 12090 65.60 10443.2 10334.2 3 12135 65.50 10461.8 10352.8 3 12183 64.90 10481.9 10372.9 3 12276 64.90 10521.4 10412.4 RECORD OF SURVEY 3 12367 64.20 10560.5 10451.5 3 12462 64.20 10601.8 10492.8 3 12518 63.30 10626.6 10517.6 X 12563 63.30 10646.8 10537.8 3333.5 3378.3 3428.8 3517.0 3553.7 3583.9 3606.3 3660.3 3689.2 3775.6 3863.1 3947.8 3988.8 4032.3 4116.5 4198.5 4283.9 4334.1 4374.1 DIRECTION AZIMUTH RELATIVE-COORDINATES FROM-WELL-HEAD 124.90 1115.2 S 3036.2 E 124.80 1138.6 S 3069.7 E 123.40 1154.3 S 3092.9 E 125.40 1177.5 S 3126.8 E 125.20 1201.7 S 3161.1 E 124.00 1227.2 S 3198.0 E 125.80 1252.9 S 3234.8 E 125.10 1282.2 S 3275.9 E 125.90 1333.4 S 3347.8 E 126.90 1355.2 S 3377.4 E 126.30 1373.2 S 3401.6 E 126.20 1386.5 S 3419.7 E 126.90 1418.7 S .3463.1 E 126.30 1435.9 S 3486.3 E 126.40 1487.1 S 3556.0 E 125.70 1538.6 S 3626.7 E 125.60 1588.0 S 3695.6 E 125.80 1611.9 S 3728.8 E 126.60 1637.7 S 3764.0 E 126.80 1688.0 S 3831.5 E 127.60 1737.7 S 3897.0 E 127.20 1789.6 S 3964.9 E 128.50 1820.5 S 4004.6 E 128.50 1845.5 S 4036.0 E Page 12 05/19/92 CLOSURE DL DISTNCE AZIMUTH /100 3234.5 110.17 3.28 3274.1 110.35 2.96 3301.3 110.47 4.20 3341.2 110.64 4.1~ 3381.8 110.82 0.59 3425.4 110.99 2.28 3469.0 111.17 3.30 3517.9 111.37 1.15 3603.5 111.72 1.58 3639.1 111.86 2.30 3668.3 111.98 2.28 3690.1 112.07 5.01 3742.4 112.28 1.17 3770.4 112.39 1.71 3854.4 112.70 0.14 3939.6 112.99 2..80 4022.3 113.25 0.23 4062.3 113.38 0.43 4104.8 113.51 1.85 4186.9 113.78 0.1£ 4266.9 114.03 1.05 4350.1 114.29 0.34 4398.9 114.45 2.45 4438.0 114.57 0.00 ^Survey Codes: 3/MWD X/EXTRAPOLATED t I t ) ! 1 ] - '1 "! ! } } I } ..... 1 ..... 1 ] ....1 t GP 32-13 RD SUBSEA DEPTH 0 100 200 300 400 5OO 600 700 8OO 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL Page 13 05/19/92 MEAS INCLN TVD DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT AZIMUTH FROM WELL HEAD 109 0.29 109 0 0 307.36' 0.20 N 0.20 W 209 0.53 209 0 0 225.08 0.14 N 0.81 W 309 1.21 309 0 0 171.15 1.27 S 1.23 W 409 1.68 409 0 0 159.51 3.71 S 0.57 W 509 1.92 509 0 0 153.90 6.64 S 0.70 E 609 1.55 609 0 0 152.15 9.32 S 2.07 E 709 1.47 709 0 0 154.19 11.68 S 3.27 E 809 1.33 809 0 0 160.79 13.92 S 4.20 E 909 1.32 909 0 0 164.07 16.14 S 4.89 E 1009 1.17 1009 0 0 162.63 18.20 S 5.52 E 1109 1.12 1109 0 0 168.45 20.13 S 6.02 E 1209 0.97 1209 0 0 177.24 21.94 S 6.24 E 1309 0.89 1309 0 0 181.39 23.55 S 6.27 E 1409 0.88 1409 0 0 189.41 25.07 S 6.10 E 1509 1.07 1509 0 0 178.43 26.82 S 6.02 E 1609 0.73 1609 0 0 195.21 28.31 S 5.80 E 1709 1.33 1709 0 0 175.19 29.88 S 5.59 E 1810 4.60 1809 1 0 106.51 33.31 S 8.76 E 1910 8.82 1909 1 1 112.31 37.20 S 20.01 E 2012 11.70 2009 3 2 124.93 45.90 S 35.68 E 2115 15.33 2109 6 3 129.82 60.89 S 55.06 E 2219 15.57 2209 10 4 130.27 78.70 S 76.16 E 2322 15.86 2309 13 4 130.29 96.91 S 97.63 E 2426 15.94 2409 17 4 130.47 115.35 S 119.39 E 2531 17.11 2509 22 4 132.26 134.52 S 141.35 E 2500 2635 16.68 2609 26 5 130.07 155.32 S 164.74 E GP 32-13 RD Page 14 05/19/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA DEPTH 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 50OO MEAS INCLN TVD MD-TVD VERT DIRECTION DEPTH ANGLE BKB DIFF CRRT AZIMUTH RELATIVE COORDINATES FROM WELL HEAD 2740 15.84 2709 31 4 118.12 172.14 S 188.57 E 2843 15.06 2809 34 4 105.76 182.29 S 214.25 E 2946 12.57 2909 37 3 84.00 184.93 S 237.86 E 3049 12.68 3009 40 2 71.50 179.86 S 259.15 E 3151 14.31 3109 42 3 72.34 172.31 S 281.86 E 3255 15.46 3209 46 4 73.53 164.42 S 307.60 E 3359 14.99 3309 50 4 73.77 156.80 S 333.88 E 3462 14.63 3409 53 3 73.93 149.53 S 359.32 E 3565 14.10 3509 56 3 74.86 142.79 S 383.76 E 3668 13.47 3609 59 3 75.09 136.48 S 407.40 E 3771 13.19 3709 62 3 74.42 130.35 S 429.94 E 3873 12.86 3809 64 3 74.37 124.15 S 452.24 E 3976 12.97 3909 67 3 74.49 118.03 S 474.36 E 4079 12.85 4009 70 3 74.50 111.92 S 496.46 E 4181 12.78 4109 72 3 74.77 105.78 S 518.48 E 4284 12.77 4209 75 3 74.80 99.81 S 540.32 E 4386 12.73 4309 77 3 74.53 93.77 S 562.11 E 4489 12.49 4409 80 2 74.36 87.75 S 583.65 E 4591 12.24 4509 82 2 74.63 81.90 S 604.83 E 4693 12.16 4609 84 2 74.31 76.11 S 625.57 E 4796 11.67 4709 87 2 74.33 70.44 S 645.78 E 4898 11.62 4809 89 2 74.81 65.03 S 665.60 E 5000 11.41 4909 91 2 75.62 59.86 S 685.40 E 5102 11.38 5009 93 2 75.91 54.83 S 704.91 E 5204 11.13 5109 95 2 75.42 49.95 S 724.14 E 5100 5306 10.91 5209 97 2 76.58 45.33 S 742.98 E I I I I } ! -I } ) ] GP 32-13 RD Page 15 05/19/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA DEPTH 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 MEAS INCLN TVD MD-TVD VERT DIRECTION DEPTH ANGLE BKB DIFF CRRT AZIMUTH RELATIVE COORDINATES FROM WELL HEAD 5407 10.39 5309 98 2 77.27 41.05 S 761.25 E 5509 10.10 5409 100 2 77.99 37.25 S 778.90 E 5610 9.64 5509 101 1 77.30 33.50 S 795.85 E 5712 9.03 5609 103 1 74.99 29.65 S 811.71 E 5813 9.12 5709 104 1 74.74 25.40 S 827.14 E 5914 8.75 5809 105 1 75.96 21.51 S 842.40 E 6015 8.33 5909 106 1 ~75.23 17.64 S 857.11 E 6117 8.48 6009 108 1 78.37 14.40 S 871.13 E 6218 10.83 6109 109 2 75.13 10.38 S 888.15 E 6320 11.71 6209 111 2 75.43 5.22 S 907.55 E 6422 12.73 6309 113 2 78.72 0.48 S 928.64 E 6525 13.63 6409 116 3 82.82 3.16 N 951.67 E 6628 14.59 6509 119 3 88.30 4.98 N 976.77 E 6731 14.60 6609 122 3 90.63 5.08 N 1002.82 E 6835 14.41 6709 126 3 91.53 4.55 N 1028.52 E 6938 16.25 6809 129 4 91.63 3.82 N 1055.85 E 7043 18.03 6909 134 5 ' 91.62 2.79 N 1087.30 E 7148 17.53 7009 139 5 92.23 1.72 N 1119.36 E 7253 16.80 7109 144 5 93.17 0.33 N 1150.41 E 7357 15.83 7209 148 4 95.03 1.72 S 1179.54 E 7461 15.81 7309 152 4 97.89 4.80 S 1207.39 E 7565 16.45 7409 156 4 100.33 9.46 S 1235.89 E 7670 17.59 7509 161 5 101.57 15.31 S 1265.80 E 7775 17.50 7609 166 5 100.17 21.53 S 1297.21 E 7879 17.55 7709 170 5 100.10 26.91 S 1328.16 E 7700 7984 17.23 7809 175 5 100.95 32.64 S 1359.07 E t ' ! ' ! I ' } I } } ' } } ! ! I ' } ~ I } ] } ..... ] GP 32-13 RD Page 16 05/19/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA DEPTH 7800 7900 8000 8100 8200 8300 8400 8500 8600 8700 880O 8900 9000 9100 9200 9300 9400 9500 9600 9700 9800 9900 10000 10100 10200 MEAS INCLN TVD MD-TVD VERT DIRECTION RELATIVE COORDINATES DEPTH ANGLE BKB DIFF CRRT AZIMUTH FROM WELL HEAD 8089 16.40 7909 180 4 101.57 38.56 S 1388.76 E 8193 15.30 8009 184 4 102.38 44.45 S 1416.55 E 8296 15.08 8109 187 4 103.38 50.48 S 1442.95 E 8400 13.93 8209 191 3 104.03 56.62 S 1468.12 E 8504 17.33 8309 195 4 104.81 63'.16 S 1495.51 E 8609 19.88 8409 200 6 114.71 74.34 S 1527.29 E 8716 22.55 8509 207 7 127.35 94.64 S 1559.76 E 8826 25.46 8609 217 10 129.30 122.96 S 1594.76 E 8937 26.36 8709 228 11 129.56 154.06 S 1632.62 E 9049 26.64 8809 240 12 129.60 185.85 S 1671.06 E 9161 27.24 8909 252 12 130.26 218.38 S 1709.98 E 9275 29.36 9009 266 14 128.36 252.60 S 1751.83 E 9390 30.03 9109 281 15 127.44 287.61 S 1797.16 E 9510 38.12 9209 301 ,20 128.71 328.97 S 1849.58 E 9643 43.28 9309 ,334 33 126.00 382.10 S 1918.38 E 9787 48.37 9409 378 44 124.08 440.81 S 2002.83 E 9947 54.79 9509 438 60 121.84 508.66 S 2108.25~E 10130 58.01 9609 521 83 121.50 588.73 S 2238.50 E 10323 58.96 9709 614 93 122.20 675.51 S 2379.50 E 10515 58.70 9809 706 92 122.60 763.39 S 2518.33 E 10712 59.70 9909 803 96 122.60 854.36 S 2660.57 E 10923 66.21 10009 914 112 126.30 959.47 S 2814.42 E 11178 66.62 10109 1069 154 · 124.40 1094.11 S 3005.51 E 11453 69.20 10209 1244 175 124.89 1239'.75 S 3216.31 E 11741 68.79 10309 1432 188 126.45 1398.12 S 3435.52 E 10300 12007 65.78 10409 1598 166 125.69- 1543.99 S 3634.14 E ! ..... 1 1 1 ....... } ....... } } ....1 } .... } ..... ! } ! .. I } ..... } ..... 1 ~P 32-13 RD Page 17 05/19/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT AZIMUTH FROM WELL HEAD 10400 12247 10500 12478 64.90 10509 63.94 10609 1738 140 126.74 1672.22 S 3810.39 E 1869 132 127.58 1798.62 S 3976.67 E ~P 32-13 RD Page 18 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 05/19/92 MEAS INCLN VERT-DEPTHS SECT DIRECTION. REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST AZIMUTH FROM-WELLHEAD DIST AZIMUTH DL/ 100 0 0.00 0 -109 0 1000 1.17 1000 891 15 2000 11.21 1997 1888 53 3000 12.27 2962 2853 309 4000 12.91 3932 3823 462 0.00 0 N 0 E 0 162.13 18 S 5 E 19 124.27 45 S . 34 E 56 75.45 183 S 249 E 309 74.61 117 S 480 E 493 90.00 0.0 163.15 0.2 142.87 2.7 126.28 0.8 103.67 0.2 5000 11.41 4909 4800 600 6000 8.52 5894 5785 717 7000 17.70 6868 6759 885 8000 17.16 7824 7715 1145 9000 26.53 8765 8656 1463 75.62 60 S 685 E 688 74.75 18 S 855 E 855 92.27 3 N 1074 E 1074 101.08 34 S 1364 E 1364 129.60 172 S 1654 E 1663 94.99 0.7 91.22 0.6 89.83 1.4 91.41 0.5 95.93 0.2 10000 56.44 9539 9430 2072 11000 67.50 10038 9929 2936 12000 65.79 10406 10297 3866 121.44. 532 S 125.20 1000 S 125.70 1540 S 2146 E 2210 2872 E 3041 3629 E 3942 103.92 0.7 109.20 1.9 113.00 0.2 b~qOCAL CORPORA-[ ~ON I t ! t I L I I ; ..... [ ! 0 750 ~500 2250 3000 3750 4500 Section Departure GP 32-~3 RD VERTICAL SECTION VIEW Section at: 124.30 TVD Scale · ! inch = ~500 feet Dep Scale' 1 inch = ~500 feet Drawn · 05/19/92 £r'eat Land Djr'ectJonaJ Dr~]]Jn# ~arker Identification MD BKB SECTN INCLN A) KB 0 0 0 0.00 B) REDRILL #! TIE-1N B400 B209 1245 t3.93 C) REDRILL 12 TIE-IN 94t0 9~2§ t65B 32.52 D) TO 12563 i0645 4376 63.50 UNOCAL CORPORATION Marker Identification MO N/S E/N Al KB 0 ON OE 8J REORILL #t TIE-IN 8400 57 S 1468 E CJ REORILL #2 TIE-IN 9410 294 S iB06 E DJ TI) ~2563 ~847 S 4038 E Great Land Oirect~onal Or~ll~n# I,, GP 32-_13 RD PLAN VIEW CLOSURE · 4440 f~ a~ Azimuth i~4.5B OECLINATION' 23.~0 E SCALE .......: ! inch = 500 fee~ BflANN. ' 05/~5/92 250 0 250 <- NEST ' EAST -> 500 750 iO00 i250 i500 I750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 Unocal North Americr ~'ql & Gas Division Unocal Corporation 909 West 9th Avenue, R ~. ~ox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL R. C. Warthen Regional Manager Development Geology & Geophysics Alaska Region DOCUMENT TRANSMITrAL July 28, 1992 L-,, ~'~ DEL!VERED 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 : g ¢,.co/_ /.Z,S"Z3 ' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THIS DOCUMENT TRANSMITYAL. THANK YOU. RECEIVED BY:~ ,/A c...~~'''''''---~ DATED: R ~a, y-,~f~t'~ ! O UL 2 9 Alaska 0tl & 6as Cons. Commission Anchorage ~.,) ~ ?~o' - )NE COIY OF Unocal North America, .... ';I & Gas Division Unocal Corporation 909 West 9th Avenue, R.,_. Jox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL ) R. C. Warthen Regional Manager Development Geology & Geophysics Alaska Region DOCUMENT TRANSMITTAL July 7, 1992 HAND DELIVERED TO: Larry Grant FROM: Dick Stewart 3001 Porcupi ne Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION P 0 Box 196247 Anchorage AK 99519-6247 ALASKA REGION Transmitting as Follows: Granite Point Field 32-13RD One sepia of each Dual Propagation Resistivi;Cy, Gamma Ray Bulk Density, Gamma Ray Density Porosity, Neutron Porosity, Gamma Ray, Density Porosity, Neutron Porosity, Dual Density Porosity, Neutron Porosity, Dual Photoelectric'~ Propagation Resistivity, Gamma Propagation Resistivity, Gamma Ray Ray "-' Granite Point Field 32-13RD Sidetrack #1 One sepia of each Dual Propagation Resistivity, Gamma Ray TVD and MD DATED: PLEASE ACKNOWLEDGE RECEIPT OF THIS DOCUMENT TRANSMITTAL BY SIGNING AND RETURNING ONE COPY. THANK YOU. RECEIVED BY: ~..,.~ RECEIvtu jUL 0 7 1992. Alaska 0il & 6a~ Cons. Commission Anchorage Unocal North America,--'~il & Gas Division Unocal Corporation 909 West 9th Avenue, P., .,ox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL ) DOCUMENT TRANSMITYAL July 2, 1992 R. C. Warthen Regional Manager Development Geology & Geophysics Alaska Region TO: Larry Grant HAND DELIVERED 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 Field 32-13RD ~.~ One blueline and one sepia as follows: Mudlog-Formation log Mudlog-Chromatography Ratio log Daat~ Propagation Re,sistivi~,~6~,l~ay / .. B~_.~mity~ .Gamma Ray ~ ~ 1(~ ~' ~'"~ ~ ~ '~'~"~ ' ~/~ ' esistivity, Gamma Ray ,./..__J r-ex: ~) t, ed' · ~, ?/~,/ ~~tion Resistivity, Gamma Ray ,One copy -. D~ctional ,survey ~ -- i'll1 ,, = ........ . ...... - ............ -- Granite Point Field 32-13RD Sidetrack #1 One blueline and one sepia as follows: MudlOg. Formation log ':~// ,Lithodensity-Compensated Neutro0. GR Phasor Induction-Gamma Ray 5" an"'"'d ~)'/'/ .cET-CBT, GR~ ~l~r~Profil¢ ~/ .... Two each blacklines as follows: Dual Propagation Resistivity, Gam~~irectional One Edit tape and listing ,./ One LIS verification listing/TCOM, RWD tape PLEASE ACKNOWLEDGE RECEIPT OF THIS DOCUMENT TRANSMITI'AL BY SIGNING AND RETURNING ONE COPY. THANK YOU. ~ RECEIVED BY: ~ / ~,-..~.~ DATED: RECEIVED JUL 0 2 1992 Alaska Oil & Gas Cons. Commission Anchorage Unocal North Americap-~', Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITYAL May 22, 1992 FIRST CLASS MAIL 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: Unocal, Granite Point Field 32-13RD and 32-13RD Sidetrack #1 1 copy of Final Well Report . £CEIVED MAy 2 7992 .... ,~' ~chorage PLEASE ACKNOWLEDGE RECEIPT OF THIS DOCUMENT TRANSMITTAL BY SIGNING AND RETURNING ONE COPY. THANK YOU. DATED: ,e'-/2.//.f ~ AOGCC GEOLOGICAL MATERIALS iNVENTORY LIST C~eck' Off er list data as it is received.*list received date for 407', if not reejuired list as NR ~7 !* ~/]~d'ril'ii"~ histe~' I~ . su~eyl ~~ell tests ~! cot. descripti.~ c?red inter, Is ~ c°re ana'lysis j~ (~. d~ ditch int. wals , ~ , "~l N~ I . , ,,, ,,, ,,,, , !, ,,,, ,,, ,,,,,, ,, , ~ ! ~ ,., digital data " IklTCnl,r,.o SCALE iL,..,,~' '""-' TYPE i RUN ,l~l , Ln.V/4,LO HO. {to,thc nearest foet] , [inchl100'] 1i ~' ¢'~/ ..... .-- ": /~ D lye_ .... /~ .... / ,,, /c~&~--~ /2, ,~c~ ~ ,3, ,, , ii i i i ii ii i i i ~l _l i , ~ ....... ~ f I , TO: THRU: FROM: MEMORANDUM Stme of Alaska i: ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~,h DATE: Lonnie C May 13, 1992 Commissioneru FILE NO: lg513-2.doc Blair Wondzell ~t~ P. I. Supervisor Louis R Grimaldi TELEPHONE NO: SUBJECT: BOP Test-GP 431 Unocal GP 32-13 RD Granite Pt Platform Permit 92-20 Granite Pt Field Petr inspector Sunday, April 28, 1992 I witnessed a BOP test on Unocal's Granite Point Platform. This was a weekly test for the platform's rig which is presently drilling Well GP 32-13 RD. The test went very well with all equipment operating and holding pressure. The test went quickly and the impression I received was that the crew was familiar with the drill. I believe that the rig and platform personnel should be commended on their efforts for refurbishing this platform. The ongoing work is impressive and should make this one of the better platforms in Cook Inlet. In summary, I witnessed a very good BOP test on Unocal's Granite Point Platform. Attachment 02-001A (Rev. 6/89) 20/1 lfMEMOi. PM3 OPERATION= Drlg X Wkvr~ Operator (.~ ~t} ~OC, ~gh k_ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report DATE TEST: Initial Rep ~/~? ~t~AJ ~ ~-~ O ~J C ~' Weekly ~ Other Rig phone # ~S Location (general) Housekeeping (general Rsrve pit/l~/Y~ ,. MUD SYSTEMS: Trip tank Pi t gauge · Flo~ monitor Gas detectors Well sign Rig~ V~I Audi o Location: Sec~_~_ T/Z~)~ R)2 uJ M ,_~ /~ Rig# ~ / Rep ACCUMULATOR SYSTEM: Full charge pressure Press after closure Pump incr clos press 200 psig Full charge press attained Controls: Master Remote ~ ~ Blind ~witch cover psig psig min yO sec min ~D~ sec Upper Kelly BOPE STACK: Lower Kelly Test Pressure Annula~ preventer ~ ~)1~) ([~) Ball type Pipe rams 0 .~(5> ~ Inside BOP Blind rams J~)~ ~ Choke manifold Choke~ l i ne val yes ~ ,~-~ ~;)~ Number val Yes HCR ~alve ~)d~)(~ Number flanges Kill 1)ne valves Check valve ,,~/~ TEST RESULTS: KELLY AND FLOOR SAFETY VALVES: Test pressure 3 C) ~'q-.--~ Adjustable chokes / Hydraul ical ly operated choke F~ O~ Test pressure Test pressure Test pressure Test pressure Repair or replacement of failed equipment to be made within days. Notify the Inspector, and follow with written/FAXed [276-7542] verification to Commission office. Distribution: orig - AOGCC c - Operator c - Supervisor STATE W I TNESS REOU I RED? yes no~,,, j 24-HR NOTICE GIVEN? yest no Waived by: Witnessed by:_ ~" ~/ '~ '~-.~' .... C.004 (rev 03/92) WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 February 24, 1992 Gary S. Bush Regional Drlg Manager Union Oil Company of California P O Box 196247 Anchorage, AK 99519 Re: Granite Pt. 32-13RD Union Oil Company of California Permit No: 92-20 Sur. Loc. 52390'S & 1379'E from NW corner Sec. 13, T10N, R12W, SM Btmhole Loc. 4151'FNL & 58'FWL, Sec. 13, T10N, R12W, SM Dear Mr. Bush: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. 'Notice may be given by contacting the Commission at 279-1433. David W. on, Chairman Alaska Oil nd'Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Unocal North American-'--" 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 February 18, 1992 Mr. Russell Douglass Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 GRANITE POINT FIELD STATE OF ALASKA Permit to Drill Well: Granite Pt. 32-13RD Dear Mr, Douglass: In accordance with AOGCC Regulation 20 AAC 25.005 (Permit to Drill), enclosed please find check number 11188 in the amount of $100.00, payable to the State of Alaska, Department of Revenue to cover the permit fee for the above captioned well. Aisc enclosed is form 10-401 in triplicate, covering the subject permit for your approval. Should you have any questions, please contact the undersigned at 263-7604. Thank you in advance for your consideration. Very truly yours, Robert A. Province Landman RAP:da Enclosures RECEIVED FEB 19 1992 Alaska 0il & Gas Cons. Commission Anchorage ,,-,, STATE OF ALASKA --- ALASKA .~AND GAS CONSERVATION CON. SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill J-1 Redrill ~ 1 lb. Type of well Exploratory J-1 StratigraphiC Test J-J Development Oil Re-Entry J--J Deepen [-JI Service r-J Development Gas j'-J Single Zone J--J Multiple Zone r-J 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool (UNOCAL) Union Oil Company of California 110' RT above MSL Granite Point 31 Address 6. Property Designation Tyonek P.O. Box 196247, Anchorage, AK99519 ADL 18761 4. Location of well at surface: Conductor #3-5, 2390'S 7. Unit or property name 11. Type Bond (SEE 20ACC25.025) & 1379'E from NW corner Sec. 13, T10N, R12W, SM Union Mobil State #1 United Pac. Ins. Co. At top of productive interval: 10,398' MD/9,785' TVD 8. Well number Number U62-9269 3,101' FNL & 3,793' FWL, SEC 13, T10N, R12W, SM Granite Point 32-13RD At total depth: 12,489' MD/10,736"fVD 9. Approximate spud date Amount $200,000 4,151' FNL&58' FWL, SEC,,,14~', T10N, R12W, SM March 1992 12. Distance to nearest 1..~ 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD a,d TVD/ property line 3,100' 2,300' 5,089 12,489 '/10,736' 16. To be corn pleted for deviated wells 17. Anticipated Pressure(ss 2o AAC 25.035 (e)(2)) Kickoff Depth 8 400' MD Maximum hole angle 63 deg. Maximum s,,,f~ce 1342 psicj At total depth (TVD/ 4187 p~S 18. Casing program Setting Depth size Specifications Top Bottom Q ua ntity of cem e nt Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 32# Pl10 Butt. 4,389' 8,100' 7,921' 12,489' 10,736' 650 sx (565 cu. ft.) -- 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary FF_B Total depth: measured 12,489' feet Plugs (measured): Retainer at 8,585' MD true vertical 10,736' feet Alaska 0il & Gas 00ns. Effective depth: measured 8,585' feet Junk (measured): true vertical 8,391' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 668' 18" 668' 668' I nterm ediate 2,506' 13- 3/8" 2,506' 2,485' Production 8,822' 9-5/8" 750 sx 8,822' 8,622' Liner 1,583' 7" 475 sx 8,614'- 10,197' 8,419'-9,984' Perforation depth: measured -See attached true vertical 20. Attachments: Filing fee ~ Property plat E] BOP Sketch~ Diverter Sketch E~ Drilling program E~ Drilling fluid program [] Time vs depth plot BI Refraction analysis E] Seabed report E~ 20 AAC 25.050 requirements 21. I hereby certify_ that the foregoing is true and correct to the best of my knowledge Signed (~ Oomm~ssion Use Only ,-) ' Permit Number (:~ APl number ApproT~al d~e See oover letter e -zo I 0- I~/ J ~ l/J~ forotherrequrements Conditions of approval Samplesrequire.d BI Yes~,~No Mud log requi~d E] Y.es~No Hydrogen sulfide measures B Yes~_No Directional survey required '/.~. Yes ~ No Required~r BOPE~J~ 3M; BI 5M; BI 1OM; F-] 15M Other:/'~ [ % ~,. , ~¢, ~ ve~~ ~ ..~"~~ by the order of Appro ,,_ ~ Commissioner the commission Date Form 10-401 ~e~.~-~-':1-85 Submifin triplicate . Granite Point 32-13RD Drilling Procedure Plu.q and Abandonment Procedure: 1) 2) 3) 4) 5) 6) 7) 8) 9) lO) 11) 12) 13) 14) Move in and rig up. Kill well. Run in hole with 8-1/2" bit to 8,585' ETD. Run a CBL and Gyro from 8,585' to surface. Mill a section window in the 9-5/8" casing from 8,400'-8,480'. Underream the milled section to 15". Equalize a cement plug from 8,585' to 8,200'. Wait on cement. Clean out cement to 8,300' and pressure test 9-5/8" casing. Drill out cement to shoe at 8,400' and perform leak off test. Prep to begin redrill of 8-1/2" hole. Directionally redrill a 8-1/2" hole from 8,400' to 12,489' MD. Run open hole logs. Run and cement 7" liner from 8,100' to 12,489'. Run a CBL and Gyro from ETD to surface. Perforate the Tyonek "C" at intervals (_+ 800') with tubing conveyed perforating guns. Run a single 3-1/2" production tubing string. Place well on production. Note: Should H2S be encountered, UNOCAL will conform to all requirements as set forth in 20 AAC 25.065. RECEIVED FEB 1 9 t992 Alaska Oil & (~as Cons. bUillinissi~O~ Anchorage Top ~-t~"ANITE POINT ~32'-~q WELL SCHEMATIC 18' C 668' 13 3/8" C 2506' - 7" Liner at 8614' 9 5/8" C 8822' 9182' Top of Fish Packer at 9472' Pack er at 9775' 7/8" Tubing to 10,109' PBTD 10,154' 7" C 10,197' T.D. 10,200' ~ECEIV'~'D _ FEB 1 9 1992 Alaska OiJ & Gas Cons. Comrnissior, Anchorage 8585' Baker M, odel K-1 Cmt. Retainer (Cmt d W/280sxs ~'~'~;~-?~.~'~;~ Cmt plus A dditiv es) r.~%: ;~. ~,~...~?-~ o-..'-:'/.': ~.'~. ~,',~.'~ J-I ~~ IL .. PERFORATiONS 9200~-9225' "A" ZONE , 9512'-96 I 7' 9704'-9749' ZONE 10,016'-10,046' 10,052' 10,072' 'C" Z'''~ -- ~./i~ 10,083'-10,108' · ---- ---,-, .............. -- -, ................. ;,'r',' .......... '" ',',',; ............. .',',;,'¢, ' ............ ,',','" '," ',',',',',',',',' :,',',',',' ' ',',' ' :.:~:~:~:~:4.:.:.:.:.:.:.:~:.:.:.:.:.:.:.:~:~:.:...:.:.:.:.:~:.:.:.:.:.:~:~:~:.:~:~:`:.:.:.:.:.:.:.:. ~:.:.:~:~:.:~:~:~:<.:.:.:.:.:.:.:.:.:.:.:~:~:~:.:~:.:.:.:.:~:.:.:.:.:.:.:.:.:.:.:.:~~.:.:.:.:.:.:.:. ================================================= 9200 9225 8994 9019 sqz'd 9512 9617 9305 9410 sqz'd 9704 9749 9496 9541 sqz'd 10016 10046 9806 9835 sqz'd 10052 10072 9841 9861 sqz'd 10083 10108 9872 9896 sqz'd FEB 1 9 199 . Alaska Oil & Gas Cons. Anchorage E.P.A. Approved Mud Program Unocal-Mobil State Granite Point 32-13 Redri11 Mud type: Seawater/Fresh water polymer mud Hole size: Depth: 8-1/2" 8400' to 12489' measured depth Mud Properties Weight: Viscosity: PV: YP: pH: Gels: API Filtrate: 9.5 to 10.5 ppg 45-55 sec/qt 10-15 cP 12-18 lbs/100 sq ft 9.5-10.0 lO/3O 4-8 CC'S/30 min HPHT (200 deg): 16-20 cc's/30 rain RECEJV FEB 1 9 t992 Oil & Gas Cons. L;omrr, ission'. Anchorag~ 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 32-13 REDRILL Field ........ : GRANITE POINT Section at...: S,55.70,E KB elevation.: 109.00 ft Computation..: RADIUS OF CURVATURE' PROPOSED WELL PROFILE Prepared.: 01/24/92 RECEiveD 7 9 992 Alaska Oil & Gas Cons. Commission Anchorage STATION IDENTIFICATION MEAS INCLN DEPTH ANGLE VERT-DEPTHS SECT BKB SUB-S DIST DIRECTION REL-COORDINATES DL/ BEARING FROM-WELLHEAD 100 TIE-IN 8425 8500 BEGIN 2.5/100 BLD 8525 8600 END OF TURN 8650 13.69 8235 8126 13.69 8308 8199 13.69 8332 8223 15.57 8405 8296 16.82 8453 8344 1273 S 75.50 E 1290 S 74.75 E 1296 S 74.50 E 1314 S 63.22 E 1328 S 55.70 E 87 S 1482 E <TIE 92 S 1499 E 0.1 93 S 1505 E 0.1 100 S 1522 E 2.7 107 S 1534 E 2.8 8700 8800 8900 9000 9100 18.07 8500 8391 20.57 8595 8486 23.07 8688 8579 25.57 8779 8670 28.07 8868 8759 1343 S 55.70 E 1376 S 55.70 E 1413 S 55.70 E 1454 S 55.70 E 1499 S 55.70 E 115 S 1547 E 2.5 134 S 1574 E 2.5 155 S 1605 E 2.5 178 S 1639 E 2.5 204 S 1676 E 2.5 9200 9300 9400 9500 9600 30.57 8955 8846 33.07 9040 8931 35.57 9123 9014 38.07 9203 9094 40.57 9280 9171 1548 S 55.70 E 1601 S 55.70 E 1658 S 55.70 E 1717 S 55.70 E 1781 S 55.70 E 231S 1717 E 2.5 261 S 1760 E 2.5 293 S 1807 E 2.5 327 S 1856 E 2.5 362 S 1909 E 2.5 9700 9800 9900 10000 10100 43.07 9355 9246 45.57 9426 9317 48.07 9495 9386 50.57 9560 9451 53.07 9622 9513 1848 S 55.70 E 1917 S 55.70 E 1990 S 55.70 E 2066 S 55.70 E 2145 S 55.70 E 400 S 1964 E 2.5 439 S 2021 E 2.5 480 S 2082 E 2.5 523 S 2144 E 2.5 567 S 2209 E 2.5 TARGET A END OF BUILD 10200 10300 10399 10400 10497 55.57 9680 9571 58.07 9735 9626 60.54 9785 9676 60.57 9786 9677 63.00 9831 9722 2226 S 55.70 E 2310 $ 55.70 E 2395 S 55.70 E 2396 S 55.70 E 2481 S 55.70 E 613 S 2276 E 2.5 660 S 2345 E 2.5 708 S 2416 E 2.5 709 S 2417 E 2.5 757 S 2487 E 2.5 TARGET B TD 12289 12489 63.00 10645 10536 63.00 10736 10627 4078 S 55.70 E 4256 S 55.70 E 1657 S 3806 E 0.0 1757 S 3953 E 0.0 bNOCA L CORPORAT 1 ON Harker Identification ND BKB SECTN INCLN A] T/E-IN 8425 8235 t273 ~3.69 B] BEGIN 2.5/100 OLD 8525 8332 t296 t3.69 C] ENO OF TURN 8650 8453 i32B t6.82 D] TARGET A t0399 9785 2395 60.54 ~ END OF BUILD t0497 9B3! 24B! 63.00 FI TARGET B t22B9 t0645 407B 63.00 ~ TD tE4B9 t0736 4256 63.00 ! GP 32- ~3 REDRILL VERTICAL SECTION VIEN Section at: S 55.70 E TVO Scale.: ! inch = 600 feet Dep Scale.: ! inch = 600 feet DPawn ..... : 0!/24/92 SPear Land Dlrect~onal flUILD 2.50/~00 REDRZLL ORIGINAL HELL D E ANGLE 63.00 DEGREES F 600 900 t200 ]500 ~800 2~00 2400 2700 Sec,t i, on O.e..p..arture 3000 3300 3600 3900 4200 4500 4BO0 I' Sreat Land D~rect~ona] GP 32-13 REDRILL iCLOSURE · DECLINATION ' SCALE · DRAWN · PLAN VIEW 4326 ft at S 66.04 E 0.00 E I inch = 600 feet 0t/24/92 UNOCAL CORPORATION Marker Ident i flcat ion ND N/S E/H Al TIE-IN 8425 87 S t482 E B} BEGIN 2.5/,00 GLO 8525 93S tSO§E D} TARGET ~ i0399 708 S 24~6 E EJ END OF BUILD ,0497 757S 2487E F] TARGET B ,2289 ,657S 3806E G] TO t2489 ,757S 3953E I 300 0 30O <- HEST · EAST -> ORIGINAL WELL ~ ~ TARGET A RADIUS 200 ~ ~. ~G~ B ~IUS 200 FI I I I I I I I I ~ ~k' 600 900 t200 t500 t800 ~t00 2400 2700 3000 3300 3600 -~00 4200 4500 4800 I 5i00 I 18" @ 688' //1 J-55 @ 2506'Z TUBING DETAIL' 3-1/2", 9.3#, N-80, BUTT 1) SUBSURFACE SAFETY VALVE 2) GAS LIFT MANDRELS 3) "XA" SLIDING SLEEVES 4) PERMANENT PACKER 5) "X" LANDING NIPPLE 6) TCP GUNS (REMAIN-IN-HOLE) 7" TOL @ 8100' & 47# N80//S95 @ 8400' 4 HEMLOCK INTERVALS 7" L @ 12489' 32# Pl10 //1 WELL Granite Pt. 32-i3 Redrill PROPOSED COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN' CLL SCALE' NONE DATE' 02- 14-92 Granite Point 32-13 Redri11 Anticipated Pressure Calculation February 13, 1992 Maximum surface pressure calculation: Mud weight: ............................. 72 PCF = .50 psi/ft. Shoe (9-5/8") depth: ........................ 8400'MD/8211'TVD Estimated fracture gradient (9-5/8" shoe): ...... 0.90 psi/ft. Total depth: .............................. 12489'MD/10736'TVD Bottom hole pressure gradient: .................. 0.39 psi/ft. Gas gradient (assume worst case) ................. 0.0 psi/ft. Wellbore volume with gas kick situation: 3/4 mud & 1/4 gas. Maximum surface pressure = Btm hole press - Hydrostatic press MSP = BHP - (3/4 mud + 1/4 gas) MSP=(10736 ft * .50 psi/ft) - ((.75 (10736 ft * .50psi/ft.)) + (.25 (10736 ft * 0 psi/ft.))) MSP = 1342 psi. Maximum casing shoe hydrostatic pressure calculation: The maximum 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 summation of the maximum surface pressure (MSP) plus the hydrostatic pressure at that casing depth (HPcsg). HPsh = MSP + HPcsg HPsh = 1342 psi +(8400 ft * .50 psi/ft.) HPsh = 5542 psi Fracture pressure at casing shoe calculation: Fracture pressure at the casing shoe (FPsh) = .90 psi/ft * shoe depth TVD FPsh = 0.90 psi/ft * 8211' FPsh = 7389 psi Hydrostatic pressure at the casing shoe is less than the corresponding fracture pressure (HPsh < FPsh), therefore the completion is capable of handling even this extreme well kick scenario. 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 G. 18 bbl chemical tank R ¢EIVED FEB 1 9 992 0il & Gas Cons. Commission Anchorage Pit system will be equipped with pit level indicator 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. B. 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. J j · ITl, I j,r~,_., .?.._~..~,.~ ........ .~.~ · ..~, t ,-+---4--~--.---,J ! i I +o I TOTAL VOLUI~': ~ OB/. FILL- UP KILL LINE BOP [13 %" 3000 psi J PIPE RAMS 135/o"5000 psi BLIND RAMS 135/8"5000 psi [~-..L~W~'~....-"IT- SPOOL ~ 4" 5000 psi 11 I] 4" S000 I la~'5000 psi RZS~ ~ Contract Exhibit #2 RECEIVED FLOW -, ~ CHOKE psi LINE=~[~ F[[B 1 9 1992 ~iaska 0il & Gas Cons. Anchorage GRANITE POINT PLATFORM B.OPE STACK 13%' 5'00'0' psi I I I I TO 10" CROWN VENT GAS BUSTER TO CHOKE PANEL 1 O" TO SHAKER SWACO CHOKE NOTE: SWACO CHOKES EACH HYDRAULICALLY ACTUATED VIA REMOTE. BLOW DOWN -- TO BOPE i MANUAL SWACO CHOKE m I CHOKE MANIFOLD Unocal PLATFORM RI6g 4-1/16" & 3-l/B", 5M MSP ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE [2 thru §]~ ~ [14 thru 22] [23 thru 283 (6) Other /~°C z/~-~//¢~. ~29 thrd '3'1'] Company YES 1. Is permit fee attached ............................................... L 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 ............................ 9. Does operator have a bond in force ................. ' ................. 10. Is a conservation order needed .............................. 11 Is administrative approval needed . _ 12. Is lease ncrnber appropriate .......................................... L 13. Does well have a unique name & nc~nber ................................ · 14. Is conductor string provided ......................................... 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. 16. Is enough cement used to circulate on conductor & surface ............ .. .. 17. Will cement tie in surface & intermediate or production strings ...... 18. Will cement cover all known productive horizons ..................... ~ " 19. Will all casing give adequate safety in collapse, tension, and burst. /d/cz 20. Is well to be kicked off from an existing wellbore ................... ~ .... 21. Is old wellbore abandonment procedure included on 10-403 ............. ~ .... 22 Is adequate wellbore separation proposed ............................. .~ .... 23. Is a diverter system required ........................................ 24. Is drilling fluid program schematic & list of equipment adequate ..... j~ ..... 25. Are necessary diagrams & descriptions of~BOPE attached .... 26. Does BOPE have sufficient pressure rating -- test to ~o~opsig ..... 27. Does choke manifold comply w/API RP-53 (May 84) ...................... /~ ... 28. Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS' 29. Are data presented on potential overpressure zones ................... 30. Are seismic analysis data presented on shallow gas zones ............. 31. If offshore loc, are survey results of seabed conditions presented... . ...... 32. Additional requirements ............................................. Lease & Well NO REMARKS O 'rZ ~O geology' DWJ RPC~ eng i neer i ng~. BEW , RAD'o '/29/91 1 INI'TIAL GEOI' 'UNIT 'ON/OFF POOL CLASS STATUS AREA ~ SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special 'effort has been made to chronologically organize this category of information. LIS VERIFICATION LISTIN~ FOR: GP 32-13 RD & GP 32-13 RD ST-1 COOK INLET RECEIVED JUL 0 2 199~ Alaska Oil & Gas Cons. Commission Anchorage BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE LIS TAPE GENERATED FOR UNOCAL WELLS GP 32-'13 RD & GP 2'1-13 RD ST-'1 AZT BDCM BDC2 BDUM BDU2 DPEM DPE2 DPSU DPS2 DRHM DRH2 GRAM GRAS GRA2 GRAX GRCX INC NFBM NFBS NNBM NNB2 NNBS NNBA NPSM NPSS NPS2 NPSX RAAM RAAX RACM RAC2 RACX Azimuth - True (Posted) Bulk Density Compensated [RWD] Bulk Density Compensated (Relog) [RWD] Bulk Density Uncompensated [RWD] Bulk Density Uncompensated (Relog) [RWD] Photoelectric Cross Section [RWD] Photoelectric Cross Section (Relog) [RWD] Density Porosity (SS) Uncompensated [RWD] Density Porosity (SS) Uncompensated (Relog) [RWD] Delta RHO - Density Correction [RWD] Delta RHO - Density Correction (Relog) [RWD] Gamma Ray Apparent [RWD] Gamma Ray Apparent Smoothed [RWD] Gamma Ray Apparent (Relog) [RWD] Gamma Ray Apparent [MWD] Gamma Ray Corrected [MWD] Inclination (Posted) Neutron Far Base [RWD] Neutron Far Base Smoothed [RWD] Neutron Near Base [RWD] Neutron Near Base (Relog) [RWD] Neutron Near Base Smoothed [RWD] Neutron Near Base Averaged [RWD] Neutron Porosity (SS) [RWD] Neutron Porosity (SS) Smoothed [RWD] Neutron Porosity (SS) (Relog) [RWD] Neutron Porosity (SS) Smoothed [MWD] Resistivity (AR) Apparent [RWD] Resistivity (AR) Apparent [MWD] Resistivity (AR) Corrected for Borehole [RWD] Resistivity (AR) Corrected for Borehole (Relog) [RWD] Resistivity (AR) Corrected for Borehole [RWD] deg g/cc g/cc g/cc g/cc B/e B/e p.M. p,u. g/cc g/cc MWD-API MWD-API MWD-API MWD-API MWD-API deg cps cps cps cps cps cps p.u. p.u. p.u. p.u. ohm-m ohm-m ohm-m ohm-m ohm-m RADE RAD2 ROP ROPA RPAM RPAX RPCM RPC2 RPCX RPDE RPD2 RPDX RPTM TCDM TCDX TVD WOBS Note: Resistivity (AR) Dielectric Corrected [RWD] Resistivity (AR) Dielectric Corrected (Relog) [RWD] Rate of Penetration Rate of Penetration (Averaged) Resistivity (PD) Apparent [RWD] Resistivity (PD) Apparent [MWD] Resistivity (PD) Corrected for Borehole [RWD] Resistivity (PD) Corrected for Borehole (Relog) [RWD] Resistivity (PD) Corrected for Borehole [MWD] Resistivity (PD) Dielectric Corrected [RWD] Resistivity (PD) Dielectric Corrected (Relog) [RWD] Resistivity (PD) Dielectric Corrected [MWD] Time Since Drilled (PD) (Elapsed Time) [RWD] ODS Temperature [RWD] CDS Temperature [MWD] True Vertical Depth Surface Weight on Bit AR is Amplitude Ratio PD is Phase Difference RWD is Recorded While Drilling MWD is Measured While Drilling SS is Sandstone ohm-m ohm-m ft/hr ft/hr ohm-m ohm-m ohm-m ohm-m ohm-m ohm-m ohm-m ohm-m min deg C deg C feet klbs Copyright 1987, .1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TApESCAN REVISION' 2.64 Start of execution: Mon 11 MAY 92 2:22p ! = = E C H O I N G I N PARAMETERS- ! INPUT PARAMETER FILE: TAPESCAN.INP I 2 3 4 5 6 7 123456789012345678901234567890123456789012345678,90123456789012345678,9012 I AUTOCURV = 0 , I Automatic Curve renaming: 0=OFF, 1 =ON 2 AUTOFILE = 0 , ! Automatic FILE= generation: 0--OFF, 1--ON 3 COMMENTS -- I , ! Decode LIS Comment records: 0--OFF, 1 =ON 4 INFORECS = I , ! Decode LIS Information records: 0--NO,1 =YES 5 LISTMETHOD = 0 , ! Listing Method: O--depth units 1 =tape units 6 LISTFREQ = 25, ! Usting Frequency: Every n units 7 LISTMAX = 0 , ! Listing Maximum (0--no limit, value=list limit) 8 STATS = 0 , ! Statistics generation: 0=OFF, 1--ON 9 FORCETYP = 0 , ! (1 =BIT,2--LIS ... thru 35--Array Accoustic) (see table) 10 WRITEASCII = 0 , ! If 1, all ascii files will be written (file0001.dat,etc.) 11 WRITETAP = I , ! Write Tape-Image File: 0=NO,1 =YES 12 SPLITLIS = 1 , ! If I and WRITETAP on, split LIS logical tiles to physical 13 SUBFILES = /1,2,3,4/, ! Tape Subtile write selection (WRITETAP must be on) 14 INTERPOLATE ="YES' ! Set up for TAPE2WDS to interpolate datums ('YES'or'NO') 15 END = = U S E R I N P U T P A R A M E ! T E R S AUTOCURV = 0 , AUTOFILE = 0 COMMENTS = ~ , INFORECS = I , LISTMETHOD = 0 , LISTFREQ = 25, LISTMAX = 0, STATS = 0 , FORCETYP = 0 , WRITEASCII = 0, WRITETAP = I , SPLITLIS = 1 , SUBFILES = /1,2,3,4/, INTERPOLATE=YES' END !-- PROCESSING INTERVAL FROM 0.000 TO 0.000 ............. ! !-- CONSTANT PARAMETERS ........................................... AUTOCURV= 0.~E+00 AUTOFILE = 0.000000E+00 COMMENTS = 1.00000 FORCETYP= 0.(XXXX)0E+00 INFORECS= 1.00000 LISTFREQ= 25.0000 LISTMAX = 0.000000E + 00 LISTMETH = 0.000000E + 00 SELFTEST= 0.000000E + 00 SPLITLIS = 1.00000 STATS -- 0,(XXXXX)E + 00 WRITEASC-- 0.(XXXXX)E + 00 WRITETAP= 1.00000 dpcoef-- 1.00000 dpcte = 1.00000 drlength = 0.000000E + 00 listwave = 0.000000E + 00 maxrecln = 0.000000E + 00 minrecln = 0.000000E + 00 nsamples = 0.000000E + 00 numcurvs = 0.0(X)(X)0E + 00 numdatar = 0.000(XX)E + 00 numrecfl = 0.~E + 00 tfendep = 0,(XXX3(X)E + 00 tflevsp = 0.000000E +00 tfstdep = 0.0(XXXX)E+00 wcrbot = 0.(XXXXX)E +00 wcrlevsp = 0.00(XX~E + 00 wcrtop = 0.000000E + 00 !-- ARRAY PARAMETERS ............................................. ! SUBFILES( 1)= 1.00000 SUBFILES( 3) = 3.00(300 SUBFILES(5) =-9999.00 SUBFILES(7) =-9999.00 SUBFILES(9) =-999g.00 SUBFILES(11) = -9999.00 SUBFILES(13) = -9999.00 SUBFILES(15) = -9999.00 SUBFILES(17) = -9999.00 SUBFILES(19) = -9999.00 SUBFILES(21) = -9999.00 SUBFILES(23) = -9999.00 SUBFILES(25) = -9999.00 SUBFILES(27) = -9999.00 SUBFILES(29) = -9999.00 SUBFILES(2) = 2.(XXXX) SUBFILES(4) = 4.00000 SUBFILES(6) =-9999.00 SUBFILES(8) =-9999.00 SUBFILES(10) = -9999.00 SUBFILES(12) = -9999.00 SUBFILES(14) = -9999.00 SUBFILES(16) = -9999.00 SUBFILES(18) = -9999.00 SUBFILES(20) = -9999.00 SUBFILES(22) = -9999.00 SUBFILES(24) = -9999.00 SUBFILES(26) = -9999.00 SUBFILES(28) = -9999.00 SUBFILES(30) = -9999.00 SUBFILES(31) = -9999.00 SUBFILES(33) = -9999.~ SUBFILES(35) = -9999.~ SUBFILES(37) = -9999.~ SUBFILES(39) = -9999.00 SUBFILES(41) = -9999.00 SUBFILES(43) = -9999.00 SUBFILES(45) = -9999.00 SUBFILES(47) = -9999.00 SUBFILES(49) = -9999.00 SUBFILES(51) = -9999.00 SUBFILES(53) = -9999.00 SUBFILES(55) = -9999.00 SUBFILES(57) = -9999.00 SUBFILES(59) = -9999.00 SUBFILES(61) = -9999.00 SUBFILES(63) = -9999.00 SUBFILES(65) = -9999.00 SUBFILES(67) = -9999.00 SUBFILES(69) = -9999.00 SUBFILES(71) = -9999.00 SUBFILES(73) = -9999.00 SUBFILES(75) = -9999.00 SUBFILES(77) = -9999.00 SUBFILES(79) = -9999.00 SUBFILES(81) = -9999.00 SUBFILES(83) = -9999.00 SUBFILES(85) = -9999.00 SUBFILES(87) = -9999.00 SUBFILES(89) = -9999.00 SUBFILES(91) = -9999.00 SUBFILES(93) = -9999.00 SUBFILES(95) = -9999.00 SUBFILES(97) = -9999.~ SUBFILES(99) = -9999.00 SUBFILES(101) = -9999.00 SUBFILES(103) = -9999.00 SUBFILES(105) = -9999.00 SUBFILES(107) = -9999.00 SUBFILES(109) = -9999.00 SUBFILES(111) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES(115) = -9999.00 SUBFILES(117) = -9999.00 SUBFILES(119) = -9999.00 SUBFILES(121) = -9999.00 SUBFILES(32) = -9999.00 SUBFILES(34) = -9999.00 SUBFILES(36) = -9999.00 SUBFILES(38) = -9999.00 SUBFILES(40) = -9999.00 SUBFILES(42) = -9999.00 SUBFILES(44) = -9999.00 SUBFILES(46) = -9999.00 SUBFILES(48) = -9999.00 SUBFILES(50) = -9999.00 SUBFILES(52) = -9999.00 SUBFILES(54) = -9999.00 SUBFILES(56) = -9999.00 SUBFILES(58) = -9999.00 SUBFILES(60) = -9999.00 SUBFILES(62) = -9999.00 SUBFILES(64) = -9999.00 SUBFILES(66) = -9999.00 SUBFILES(68) = -9999.00 SUBFILES(70) = -9999.00 SUBFILES(72) = -9999.00 SUBFILES(74) ---9999.00 SUBFILES(76) ---9999.00 SUBFILES(78) ---9999.00 SUBFILES(80) ---9999.00 SUBFILES(82) = -9999.00 SUBFILES(84) = -9999.00 SUBFILES(86) = -9999.00 SUBFILES(88) ---9999.00 SUBFILES(90) --'-9999.00 SUBFILES(92) -- -9999.00 SUBFILES(94) = -9999.00 SUBFILES(96) -- -9999.00 SUBFILES(98) = -9999.00 SUBFILES(IO0) -- -9999.00 SUBFILES(102) = -9999.00 SUBFILES(104) = -9999.00 SUBFILES(106) -- -9999.00 SUBFILES(108) -- -9999.00 SUBFILES(110) = -9999.00 SUBFILES(112) = -9999.00 SUBFILES(114) = -9999.00 SUBFILES(116) -- -9999.00 SUBFILES(118) = -9999.00 SUBFILES(120) -- -9999.00 SUBFILES(122) = -9999.00 SUBFILES(123) = -9999.00 SUBFILES(125): -9999.00 SUBFILES(127) = -9999.00 SUBFILES(124) = -9999.00 SUBFILES(126) = -9999.00 SUBFILES(128) = -9999.00 !-- STRING PARAMETERS INTERPOL= YES _. Input Tape Device, LU (1) is: TAPEC: Output Tape-Image tile, LU (2) is: J:\DATA\TAK~I.TAP (Output Tape-Image file Will be created) -- Tape subtile 1 selected for writing... Tape subtile 2 selected for writing... Tape subtile 3 selected for writing... -- Tape subtile 4 selected for writing... Listing Method ("LISTMETH") = 0, Depth Unit oriented listing. -- Usting Frequency ("LISTFREQ") is every ( 25) units of Depth. Listing output limiting (LISTMAX) not enabled... - (to enable list limiting set LISTMAX positive) Data Statistics reporting ("STATS") has not been enabled. - (Specify STATS= 1 to enable this feature) Automatic curve renaming has been disabled by user input (AUTOCURV=0). Automatic "FILE =n" card generation is disabled. ('This is the program default, AUTOFILE=0) -' (Specify AUTOFILE = 1 to enable this feature) LIS comment record decoding (COMMENTS= 1) has been enabled by user input. LIS information record decoding (INFORECS= 1) has been enabled by user input. The WRITEASC option has not been enabled... (to write ASCII subfiles specify WRITEASC= 1) Tape Subtile 1 is' type: US **** REEL HEADER **** LIS 92/05/07 TELECO 01 ** LIS CUSTOMER LIBRARY TAPE TELECO OILFIELD SERVICES **** TAPE HEADER **** LIS 92/05/07 00000861 01 TELECO TCOM RWD LOG DATA FROM UNOCAL WELLS GP 32-13RD & ST-1 Tape Subtile: I Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 2 'is type: US **** FILE HEADER **** MAIN .001 1024 CN : WN : FN : COOK INLET COUN : KENAI STAT :ALASKA LIS COMMENT RECORD(s)' 12345678901234567890123456789012345678,9012345678,90123456789012345678901234567890 THIS FILE CONTAINS THE TCOM MEMORY DATA FROM WELL GP 21-13 RD. ALL CURVE NAMES WITH AN S IN THE FIFTH CHARACTER HAVE BEEN SMOOTHED. ALL CURVES CONTAINING A "2" ARE FROM REAM SECTION. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 121314 15 16 000 I 0000000 I 000 I Rep Code Count Bytes 68 49 196 Sum: 49 196 196 00000000'1. [ J_-I] e unpu~ -- ONE DEPTH PER FRAME Tape depth ID: FT 49 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 AZT MAIN 68 I DEG 2 BDCMMAIN 68 I G/C3 3 BDC2MAIN 68 I G/C3 4 BDUMMAIN 68 I G/C3 5 BDU2MAIN 68 I G/C3 6 DPEM MAIN 68 7 DPE2 MAIN 68 8 DPSU MAIN 68 9 DPS2MAIN 68 10 DRHM MAIN 68 11 DRH2 MAIN 68 12 GRAM MAIN 68 13 GRASMAIN 68 14 GRA2MAIN 68 15 GRAXMAIN 68 16 GRCXMAIN 68 17 INC MAIN 68 18 NFBM MAIN 68 19 NFBS MAIN 68 20 NNB2MAIN 68 21 NNBM MAIN 68 22 NNBSMAIN 68 23 NNBAMAIN 68 B/E B/E PU PU G/Ca G/C3 CAPI CAPI CAPI CAPI CAPI DEG CNT CNT CNT CNT CNT PU 24 NPSM MAIN 68 I PU 25 NPSS MAIN 68 I PU 26 NPS2 MAIN 68 I PU 27 NPSXMAIN 68 28 RAAM MAIN 68 29 RAAXMAIN 68 30 RACM MAIN 68 31 RAC2 MAIN 68 32 RACXMAIN 68 33 RADEMAIN 68 34 RAD2 MAIN 68 I PU 1 OHMM I OHMM I OHMM I OHMM I OHMM I OHMM I OHMM 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 95180 03 1 4 45 350 01 1 4 45 350 01 1 4 45350 01 1 4 45350 01 1 4 45 350 01 1 4 45 350 01 1 4 9558003 1 4 95580 03 1 4 9558003 1 4 9558003 1 4 9558003 1 4 9558003 1 4 9558003 1 4 9558003 1 4 9558003 1 4 95,580 03 1 4 42 890 01 1 4 42 890 01 1 4 42 890 01 1 4 42 890 01 1 4 42 890 01 1 4 42 890 01 1 4 4289003 1 4 4289003 1 44289003 1 4 4289003 1 4 95 181 03 1 4 95 181 03 1 4 95 181 03 1 4 95 181 03 1 4 95 181 03 1 4 95 181 03 1 4 95 181 03 I 961. I. 1.0 08696 I. 1.0 086G6 I. LO OG6G6 I. 1.0 08696 I..E~ I. BI. G6 I. ~0 I, gl. G6 I. 80 L6LG6 1~ L 80 1.81. G6 I. ~0 1.61. G6 t~ ~ CO 1.61. g6 ~ I. 1.0 0/.6 g6 I. 1.00Z6 G6 G'IN I. B9 NIV~ $8OM 6~ 1.4 I. 139 NIY~ a/u. et, -~93(:] L e9 NIY~XOO1 Zl~ =193a I. B9 NIV~ ~ao1 91, NIl61 I. 89 NI¥iN 1611d1::1 St, tNINHO I. 89 NIVIH XOdbl lxtx ININHO I. 89 NIVIN ~Odbl I~'lx ININHO I. SS NIVP, I =lOdbl ~tx ININHO I. ~ NIV~ XOdbl I.t, ININHO I. S"9 NI¥~ ~Odbl Ot~ ININHO I. g9 NIVIH INOdbl 6~ ININHO I. g9 NI¥1N XVdEI 6~ ININHO I. g9 NI¥1H ~Vdt:l Z.-C Hd-I I. g9 NIVV~ VdOI::I 9~ Hd-i I. ~ NIVIN dOId cjl~ _ ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES -- Data Record Length indicates: 5 FRAMES * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 1482 Tape File Start Depth = 8415.~ Tape File End Depth = 10267.000000 Tape File Level Spacing = 0.25(XXX3 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subtile reference is: **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 83752 datums Tape Subtile: 2 1489 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes 32 Tape Subfile 3 is type: US **** FILE HEADER **** STK1 .002 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS THE DPR MEMORY DATA FROM WELL GP 32-13 RD ST-1. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.25(XXX3 Entry Type(-16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: I 2 3 4 5 6 7 8 910111213141516 000 I 0000000 I 000 I Rep Code Count Bytes 68 25 100 Sum: 25 100 100 fndun a [FT ] 1.00(X)0000 3 ONE DEPTH PER FRAME Tape depth ID: FT 25 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod I AZT STK1 68 I DEG 4 2 CAAM STK1 68 I MMHO 3 CACMSTK1 68 I MMHO 4 CPAM STK1 68 I MMHO 5 CPCMSTK1 68 I MMHO 6 GRAMSTK1 68 I CAPI 4 7 GRAS STK1 68 I CAPI 4 8 GRCMSTK1 68 I CAPI 4 9 INC STK1 68 I DEG 4 10 PDCMSTK1 68 I DEG 4 11 PDDISTK1 68 I MIN 4 12 PDDM STK1 68 I MIN 4 13 RAAMSTK1 68 I OHMM 14 RACMSTK1 68 I OHMM 15 RADESTK1 68 I OHMM 16; ROP STK1 68 I FPH 4 17 ROPASTK1 68 I FPH 4 18 RPAM STK1 68 1 OHMM 19 RPCMSTK1 68 1 OHMM 20 RPDESTK1 68 I OHMM 21 RPIM STK1 68 I PTS 4 22 RPTMSTK1 68 I MIN 4 23 TCDMSTK1 68 I DEGF 24 TVD STK1 68 I FT 4 25 WOBSSTK1 68 I KLB 4 100 4 95180 03 1 4 4 45350 01 1 4 4 45 350 01 1 4 4 45350 01 1 4 4 45350 01 1 4 9558003 1 4 9558003 1 4 9558003 1 4 95580 03 1 4 95190 03 1 4 95 193 01 1 4 95 193 01 1 4 4 95 181 03 1 4 4 95 181 03 1 4 4 95 181 03 1 4 95 970 01 1 4 95 970 01 1 4 4'95191 03 1 4 4 95191 03 1 4 4 95 191 03 1 4 95191 03 1 4 95 191 03 1 4 95980 01 1 4 95980 01 1 4 95980 01 I ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 9 FRAMES * DATA RECORD (TYPE# 0) 942 BY'rES * Total Data Records: 313 Tape File Start Depth = 10130.(XXX:X:X) Tape File End Depth = 10832.(XXXXX:) Tape File Level Spacing = 0.25(:X)00 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11285 datums Tape Subtile: 3 318 records... Minimum record length: Maximum record length: 62 bytes 942 bytes Tape Subtile 4 is type: US **** TAPE TRAILER LIS 92/05/07 00000861 01 **** REEL TRAILER **** LIS 92/05/07 TELECO 01 Tape Subtile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes End of execution: Mon 11 MAY 92 2:23p Elapsed execution time = 1 minute, 39.4 seconds. SYSTEM RETURN CODE = 0 Tape Subtile I is type: LIS SSOM OAk xa01 ~aol 1611d1:1 Xadld 8:ad8 :lOde XOdld ~:Odld I610dt:l XVdI:i P, IVdI:I VdOl:l dOB ~ave 3a~ xo~ ~OVl=! v4o~ ~ IN~ XSdN ~SdN SSdN INSdN ¥SNN SaNN INgNN gBNN SB-IN I/4B_-IN ONI XOl:19 ;BYB~) S~:19 IAIVI:IE) ~Hl:la i/4Hl:la ~Sda risda ~3dO IAi:Ida ~lqaB IAIrlaB ~oa8 IAlOaB ~ HJ. d3a Si-I :ed/q s! ~ el~qns edel 8450.0000 2.1147 0.2119 -999.2500 28.2347 29.8667 16.7528 -999.2500 5.1686 -999.2500 8475.0000 2.2461 0.1422 -999.2500 -999.2500 29.2210 15.9146 -999.2500 8.0314 -999.25(X) 8500.0000 2.3929 0.0875 -999.2500 27.0878 33.5424 24.6208 -999.2500 9.0137 -999.2500 8525.0(XX) 2.5406 0.0397 -999.2500 28.9207 31.1487 29.3279 -999.25(X) 9.7091 -999.2500 103.1026 6.6744 0.2119 -999.2500 6504.0879 27.8306 16.7528 -999.2500 -999.2500 -999.2500 102.6538 5.8456 0.1422 -999.2500 -999.2500 30.1926 15.9146 -999.2500 -999.2500 -999.2500 104.4991 5.4480 0.0875 -999.2500 6729.8320 33.7875 24.6208 -999.2500 -999.2500 -999.2500 106.6573 3.5488 0.0,397 -999.2500 6575.6143 32.2652 29.3279 -999.2500 -999.2500 -999.25O0 2.3266 6.6744 53.3443 15.6949 6507.5937 -999.2500 -999.2500 -999.2500 5.3850 -999.2500 2.3884 5.8456 52.2623 16.5923 -999.2500 -999.2500 -999.2500 -999.2500 8.4170 -999.2500 2.4804 5.4480 84.3344 17.2453 6734.5986 -999.2500 -999.25(X) -999.2500 9.4640 -999.2500 2.5803 3.5488 76.3245 17.8650 6574.4951 -999.2500 -999.2500 -999.2500 10.2050 -999.2500 8233.4512 2.3266 32.4413 51.9413 28.2347 6504.0879 -999.2500 13.7790 -999.2500 5.3850 8257.5625 2.3884 24.4775 52.9478 -999.2500 -999.2500 -999.25(X) 13.1950 -999.2500 8.4170 8281.6738 2.4804 15.5844 83.7794 27.0878 6729.8320 -999.2500 18.8870 -999.25(X) 9.4640 8305.4766 2.5803 6.6,331 79.0402 28.9207 6575.6143 -999.2500 21.6200 -999.2500 10.2050 8329.2363 2.1147 32.4413 53.3443 28.2321 27.8306 -999.25O0 13.7790 5.1686 -999.2500 -999.2500 2.2461 24.4775 52.2623 -999.2500 30.1926 -999.2500 13.1950 8.0314 -999.25O0 -999.2500 2.3929 15.5844 84.3344 27.2205 33.7875 -999.2500 18.8870 9.0137 -999.2500 -999.2500 2.5406 6.6,331 76.3245 29.1406 32.2652 -999.2500 21.62(X) 9.7091 -999.2500 °999.2500 8550.13O00 2.4229 0.1255 -999.2500 36.0587 23.8589 10.3100 -999.2500 5.5541 -999.2500 108.8154 4.8407 O. 1255 -999.2500 6730.5234 23.9527 10.3100 -999.2500 -999.2500 -999.2500 2.5483 4.8407 64.4710 18.4846 6727.1973 -999.2500 -999.2500 -999.25O0 5.7910 -999.2500 2.5483 13.7663 68.9710 36.0587 6730.5234 -999.2500 9.0170 -999.2500 5.7910 8352.9961 2.4229 13.7663 64.4710 36.1338 23.9527 -999.2500 9.0170 5.5541 -999.2500 -999.2500 8575.0000 2.2890 0.1590 -999.2500 36.4308 22.9461 15.3732 -999.2500 7.5191 -999.2500 110.9735 5.4866 0.1590 -999.2500 6693.4824 22.5617 15.3732 -999.2500 -999.2500 -999.2500 2.4479 5.4866 49.2424 19.1043 6700.6738 -999.2500 -999.2500 -999.2500 7.8740 -999.2500 2.4479 21.8805 49.5393 36.4308 6693.4824 -999.2500 12.8090 -999.2500 7.8740 8376.75,39 2.2890 21.8805 49.2424 36.5092 22.5617 -999.2500 12.8090 7.5191 -999.2500 -999.2500 86(X).0000 2.1986 0.1342 -999.2500 32.5164 25.5314 12.9301 -999.2500 6.8942 -999.2500 113.4120 5.3581 0.1342 -999.2500 6526.7715 25.3889 12.9301 -999.2500 -999.2500 -999.2500 2.3328 5.3581 53.5139 19.6978 6524.8369 -999.25OO -999.2500 -999.25O0 7.2110 -999.2500 2.3326 27.3555 53.9047 32.5164 6526.7715 -999.2500 11.0240 -999.2500 7.2110 8400.4473 2.1986 27.3555 53.5139 32.4450 25.3889 -999.2500 11.0240 6.8942 -999.2500 -999.2500 8625.0000 1.8468 -0.0135 -999.2500 15.7487 68.0714 54.0302 -999.2500 19.4503 -999.2500 116.9717 7.3069 -0.0135 -999.2500 5962.6074 58.(XX)9 54.0302 -999.2500 -999.2500 -999.2500 1.8334 7.3069 92.0214 20.1870 5976.6406 -999.2500 -999.25O0 -999.2500 20.6600 .-999.2500 1.8334 48.6759 94.0211 15.7487 5962.6074 -999.2500 32.9770 -999.2500 8423.8770 1.8468 48.6759 92.0214 15.7532 58.0(X)9 -999.2500 32.9770 19.4503 -999.2500 -999.25O0 8650.(XXX) 2.2895 120.5315 5.9054 2.3202 5.9054 2.3202 21.8477 2.2895 21.8477 0.0307 -999.2500 28.5552 29.9468 18.1097 -999.2500 8.2315 -999.2500 8675.0000 2.1087 0.0880 -999.2500 20.8046 41.6589 68.2947 -999.2500 11.7115 -999.25OO 8700.0000 2.3054 0.1286 -999.25(X) 31.6269 26.6514 9.6831 -999.2500 5.5559 -999.2500 8725.(X:XX) 2.1741 O. 1232 -999.2500 33.6412 24.4538 11.7258 -999.2500 6.2553 -999.2500 8750.(XXX) 2.1995 0.0867 -999.2500 0.0307 -999.2500 6584.3105 29.9656 18.1097 -999.2500 -999.2500 -999.2500 124.0913 6.6591 0.0880 -999.2500 6166.0928 41.7718 68.2947 -999.2500 -999.25O0 -999.2500 126.4894 4.9892 0.1286 -999.2500 6568.8145 26.7127 9.6831 -999.2500 -999.2500 -999.2500 127.8152 6.0139 0.1232 -999.25O0 6518.0811 24.4813 11.7258 -999.2500 -999.2500 -999.25O0 129.1409 5.3060 0.0867 -999.25(X) 82.2673 20.6761 6584.7070 -999.2500 -999.2500 -999.2500 8.6320 -999.2500 2.1967 6.6591 81.2984 21.1652 6168.7178 -999.2500 -999.2500 -999.2500 12.3440 -999.2500 2.4339 4.9&92 66.7319 21.9121 6565.3613 -999.2500 -999.2500 -999.2500 5.7930 -999.25(X) 2.2973 6.0139 54.5232 22.8970 6516.8379 -999.2500 -999.2500 -999.2500 6.5330 -999.2500 2.2862 5.3060 51.3257 23.8818 80.3609 28.5552 6584.3105 -999.2500 14.7140 -999.2500 8.6320 8447.3047 2.1967 32.8064 79.3309 20.8046 6166.0928 -999.2500 37.7010 -999.2500 12.3440 8470.7324 2.4339 20.8865 64.4505 31.6269 6568.8145 -999.2500 8.5210 -999.2500 5.7930 8493.9707 2.2973 28.8423 51.6071 33.6412 6518.0811 -999.2500 10.1140 ..999.2500 6.5330 8517.0,,332 2.2862 27.3029 53.1129 43.5625 82.2673 28.5804 29.9656 -999.2500 14.7140 8.2315 -999.2500 -999.2500 2.1087 32.8064 81.2984 · 20.8908 41.7718 -999.25O0 37.7010 11.7115 -999.25(X) -999.2500 2.3054 20.8865 66.7319 31.6530 26.7127 -999.2500 8.5210 5.5559 -999.2500 -999.2500 2.1741 28.8423 54.5232 33.6094 24.4813 -999.2500 10.1140 6.2553 -999.2500 -999.2500 2.1995 27.3029 51.3257 44.2135 30.6620 6642.0(ZX) 6684.1553 6450.9902 18.5893 18.4266 27.2087 -999.2500 -999.2500 -999.2500 9.0294 9.0294 -999.2500 7.9990 7.9990 -999.2500 -999.2500 -999.25(X) -999.2500 5.6619 5.6619 -999.2500 5.9060 5.9060 -999.2500 -999.2500 -999.2500 -999.2500 8540.0957 -999.2500 8775.(XX:X:)129.3(X)0 2.6184 2.0933 2.4996 2.0998 6.2351 6.2351 9.1164 33.3444 0.1172 -0.0065 92.5438 87.13,39 66.7642 -999.2500 -999.2500 24.4400 27.1562 27.3596 27.7544 6556.0000 6552.4385 6364.7715 31.7353 31.4950 30.0435 -999.2500 6.8291 -999.2500 6.8220 7.4692 -999.2500 6.7240 6.7240 -999.2500 -999.25(X) 5.3892 -999.25(X) 5.3764 4.5275 -999.2500 4.7090 4.7090 -999.2500 7.(X:X:X) -999.2500 -999.2500 8562.7930 -999.2500 8800.(X:X:X)129.30(X) 2.2155 2.0793 2.3049 2.0861 4.4068 6.3662 20.9166 34.1770 -0.0894 -0.0068 64.3851 62.2632 59.9622 -999.2500 -999.2500 24.9400 18.3437 19.2086 26.7437 6531 .(ZX:X)6510.0625 6424.5889 53.0035 50.0278 31.6218 -999.25(X) 29.9447 -999.25(X) 29.8764 50.0336 -999.2500 21.9480 31.3930 11.3988 19.1123 26.6404 -999.2500 26.4267 12.8098 -999.2500 28.2130 13.5190 -999.2500 90.0000 135.2750 -999.2500 8565.4414 15.2707 8825.(XX:X) 129.3000 2.5665 2.1131 2.4993 4.83,96 4.3935 1.7285 9.1356 -132.7014 0.0672 0.1133 56.1177 55.4479 55.3,307 -999.2500 -999.2500 25.4400 39.3125 39.4148 -999.25(X) 6736.(X3(X) 6737.9961 -999.2500 21.2945 21.2369 -999.2500 -999.25(X) 6.9203 -999.2500 6.9131 7.7630 -999.25(X) 6.26(30 6.9680 39.6705 38.6458 4.9571 -999.2500 4.9460 4.7665 -999.2500 5.1500 4.9610 -999.2500 39.(:XX:X) 123.35(X) -999.2500 8608.0879 19.2044 8850.0000 129.3(XX) 2.6365 2.1763 2.5259 2.0353 4.2145 7.0321 7.5235 37.2523 0.1106 0.1410 40.1224 41.2120 42.1530 -999.2500 -999.2500 25.94(X) 50.5625 50.3757 28.1212 6920.5000 6916.8203 6392.7451 16.4680 16.5286 29.5849 -999.2500 7.9481 -999.2500 7.9390 9.5787 -999.2500 7.1120 8.4390 51.3,331 50.7291 5.9586 -999.2500 5.9432 6.4376 -999.2500 6.2030 6.7260 -999.2500 54.00(X) 123.9125 -999.25(X) 8630.7344 19.8135 8875.0000 129.3567 2.5956 2.0652 2.4776 1.9597 3.7080 7.3596 10.4502 41.8359 0.1182 0.1055 50.5875 48.5042 43.1026 -999.2500 -999.2500 26.1567 48.8333 48.7844 28.7055 6854.6670 6857.8525 6370.1885 16.9594 16.9817 28.7752 -999.2500 9.1492 -999.2500 9.1379 13.9416 -999.25(X) 8.0870 11.7750 53.7813 52.3315 5.6359 -999.2500 5.8210 8.1804 -999.2500 6.0730 8.5770 -999.2500 63.0000 124.2500 -999.2500 8653.2285 18.0732 8900.~ 129.4400 2.6107 2.3052 2.4931 2.2008 3.7594 5.2623 9.5097 27.2262 O. 1176 O. 1045 50.7287 49.8413 48.6062 -999.2500 -999.2500 26.2400 47.1875 47.1655 -999.2500 6802.0000 6802.2949 -999.2500 17.5085 17.5188 -999.2500 -999.2500 8.6759 -999.2500 8.6655 10.4169 -999.2500 7.7050 9.1010 65.73,39 52.6317 5.3948 -999.2500 5.3819 6.4773 -999.2500 5.6100 6.7670 -999.2500 74.0000 125.2625 -999.2500 8675.6504 18.2376 8925.00(X) 129.5233 2.6527 2.3149 2.5557 4.8396 4.7293 1.7285 5.7131 -132.7014 0.0970 0.1324 78.7443 79.7417 -999.2500 -999.2500 -999.2500 29.3233 35.1875 34.5113 -999.2500 6546.0000 6623.1494 -999.2500 23.2937 24.1884 -999.2500 -999.2500 15.1711 -999.25(30 15.1506 -999.2500 -999.2500 12.6520 0.1000 19.9869 21.9163 9.6897 -999.2500 9.6531 -999.2500 -999.2500 10.1430 O. 1010 -999.2500 66.0000 126.4625 -999.2500 8698.0723 27.4710 8950.0000 129.6(X)0 1.9844 2.3149 1.9970 4.8396 3.1632 1.7285 39.5775 -132.7014 -0.0126 0.1324 87.0572 86.6810 -999.2500 -999.2500 -999.2500 26.4048 17.9375 17.9777 -999.2500 6251.0000 6260.7090 -999.2500 51.3544 51.3153 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.1000 30.4155 40.2383 20.6067 -999.2500 20.4703 -999.2500 -999.2500 21.7630 O. 1010 -999.2500 ~ 62.0000 127.8500 -999.2500 8720.4902 29.7624 8975.0300 129.6(X)O 2.6349 2.2415 2.5527 2.1430 4.2443 6.6783 5.8993 30.7289 0.0822 0.0985 74.4567 79.4765 -999.2500 -999.2500 -999.2500 26.4653 33.~25 30.8812 23.3430 6551.0300 6566.2871 6,395.6748 25.0390 27.5162 37.2318 -999.2500 10.7668 -999.2500 10.7529 -999.2500 -999.2500 9.3640 0.10(X3 52.8929 49.4542 6.8300 -999.2500 6.8103 -999.2500 -999.2500 7.1220 0.1010 -999.2500 31.0300 128.0750 -999.2500 8742.8535 22.5981 9000.O(X)O 129.6000 2.5909 2.1904 2.5034 4.8396 4.2818 1.7285 8.8827 -132.7014 0.0875 0.0536 74.5828 78.7098 75.5170 -999.2,500 -999.2500 26.5258 28.5625 28.6113 -999.2500 6546.9990 6555.5869 -999.2500 29.6907 29.6765 -999.2500 -999.2500 27.1574 -999.2500 27.1000 33.9278 -999.2500 20.3550 24.0820 40.2353 43.4771 11.3315 -999.2500 11.2834 11.6346 -999.2500 11.8860 12.2600 -999.2500 39.(XXX) 128.8062 -999.2500 8765.2168 18.3149 9025.0000 129.6(XX) 2.5763 2.1904 2.4779 4.8396 4.1414 1.7285 10.4282 -132.7014 0.0984 0.0536 88.1518 68.5521 -999.2500 -999.2500 -999.2500 26.5863 36.50(X) 36.4534 -999.2500 6569.0000 6572.1797 -999.2500 22.4463 22.4923 -999.2500 -999.2500 20.6981 -999.2500 20.6632 -999.2500 -999.2500 16.4110 O. 1000 33.2343 46.9453 11.2610 -999.2500 11.2134 -999.2500 -999.2500 11.8110 0.1010 . -999.2500 32.0000 129.9875 -999.2500 8787.5801 13.7514 9050.0000 129.6000 2.4229 2.1904 2.3200 4.~ 2.8803 1.7285 20.0009 -132.7014 0.1029 0.0536 47.3440 47.3340 -999.2500 -999.2500 -999.2500 26.6468 39.8125 39.8054 -999.2500 6651.0000 6851.2549 -999.25(X) 20.6147 20.6198 -999.2500 -999.2500 27.5475 -999.2500 27.4886 -999.2500 -999.2500 20.5880 O. 1000 56.1977 63.0862 14.7487 -999.2500 14.6726 -999.2500 -999.2500 15.5170 0.1010 -999.2500 30.O(X)O 129.8750 -999.25(X) 8809.9434 13.1906 9075.0000 4.8396 0.0968 -999.2500 -999.2500 20.2852 45.3862 93.7298 -999.2500 31 .(XXX) 9100.0030 2.4140 0.0859 -999.2500 50.1355 18.7905 56.4493 83.1384 -999.2500 25.0000 9125.0000 2.5637 0.0269 -999.2500 50.6486 22.4087 466.0662 61.7834 18.1669 76.0(XX) 9150.0000 2.4145 0.0909 -999.2500 69.2907 14.2655 -999.2500 43.7916 25.1100 IO0.O(XX) 9175.00(X) 2.1249 129.6241 2.9225 0.0536 -999.2500 6677.0000 -999.2500 -999.2500 88.8788 -999.2500 130.3250 129.8253 2.8504 0.0859 -999.25O0 6806.0000 17.0290 -999.2500 71.4066 -999.2500 131.1125 130.0264 4.1977 0.0269 -999.2500 6638.3330 16.7167 -999.2500 63.4536 -999.2500 131.9(X)O 130.2276 3.1883 0.0195 -999.2500 6807.6660 11.5717 -999.2500 42.5209 -999.2500 132.2375 130.0196 4.1676 2.4388 1.7285 56.1563 26.7172 6675.1602 -999.2500 -999.2500 16.2526 17.1180 -999.25O0 2.50(X) 2.8504 49.8073 26.8609 6758.7510 -999.2500 -999.2500 18.0150 18.9930 -999.2500 2.5906 4.1977 57.5485 27.0046 6648.1719 -999.25O0 -999.2500 17.4363 18.3760 -999.2500 2.5206 2.6724 57.2335 27.1483 6793.1416 -999.2500 -999.25O0 20.1213 21.2410 -999.2500 2.1904 18.6725 53.2845 40.5312 -999.2500 45.5238 29.4970 -999.2500 0.1010 8832.2969 2.5000 14.3002 51.0707 46.3125 7032.8770 56.6475 33.8640 -999.2500 0.1010 2.5906 5.2307 56.8401 37.2604 6981.8105 472.9473 64.1470 -999.2500 19.2770 8876.8672 2.4340 13.3466 56.2088 58.6042 7111.3545 -999.2500 -999.2500 -999.2500 26.7860 8899.1523 2.1662 9.8606 2.3419 -132.7014 -999.2500 40.5770 20.3140 -999.2500 0.1000 16.1625 -999.2500 15.4079 2.4140 14.3002 -999.2500 44.0449 17.8293 -999.2500 0.1000 17.90.39 -999.2503 15.8398 2.5637 5.2307 44.1878 37.0502 22.2335 -999.2500 0.1000 17.3314 -999.2500 11.1796 2.4298 14.2727 92.7804 56.9500 13.6201 -999.2500 0.1000 19.9866 -999.2500 9.6906 2.4873 31.8227 0.0973 -999.25O0 29.0678 24.6322 -999.2500 10.8466 26.9431 137.CX:X30 0.0413 -999.2500 6618.00(X) 28.7903 -999.2500 11.9899 -999.2500 131.4500 131.2546 27.5299 6643.6035 -999.2500 -999.25(X) 23.09(X) 24.4120 -999.2500 125.5946 32.7500 6547.9395 -999.2500 -999.2500 -999.2500 28.7760 8921.2754 90.&909 34.1036 25.6136 -999.25OO 0.1000 22.9188 -999.25O0 53.0925 9200.13000 2.1608 -0.1378 -999.2500 24.5521 75.11363 -999.2500 10.0556 23.7637 109.0000 129.5815 4.8475 0.0512 -999.2500 5788.0000 32.8638 -999.2500 7.9266 -999.2500 131.7875 2.0138 7.2645 114.7777 28.0454 5788.1855 -999.25(X) -999.2500 40.1570 42.7000 -999.2500 2.2120 30.2052 114.0891 12.7812 6171.9580 -999.25(X) -999.25OO -999.25OO 25.3270 2.1516 29.6479 108.4288 13.0834 78.1206 -999.2500 0.1000 39.7039 -999.2500 68.6685 9225.0000 2.3619 0.1999 -999.2500 30.8292 36.5191 -999.2500 42.7614 15.5320 189.0(XX) 129.14&3 3.4605 0.0674 -999.25O0 6139.8994 27.5210 -999.2500 39.8709 -999.25OO 134.2625 2.3178 5.7197 117.9715 28.5608 6129.6338 -999.2500 -999.2500 32.2056 34.138o -999.2500 2.4293 32.2491 115.7634 23.0344 6739.4219 -999.2500 -999.2500 -999.250O 16.4410 8965.3398 2.1179 17.4594 109.2040 22.9286 38.3506 -999.2500 0.1000 31.8697 -999.2500 15.4221 9250.(XXX) 2.4506 0.0859 -999.2500 35.0417 18.8132 -999.25(X) 43.9993 17.0492 47.0000 128.7051 3.7016 0.0489 -999.2500 6799.(XXX) 23.1649 -999.2500 49.7001 -999.2500 135.1625 2.5699 5.3244 71.4428 29.0763 6809.9766 -999.2500 -999.2500 21.1492 22.3230 -999.2500 2.4995 10.0638 74.1716 43.3125 6400.6963 -999.2500 -999.2500 -999.2500 18.0730 8987.3711 2.48,39 12.0639 109.2040 44.2270 19.2123 -999.2500 0.1000 20.9881 -999.25O0 11.9820 9275.0000 2.4449 0.0259 -999.25(X) 128.3560 4.9573 0.0259 -999.2500 2.4708 4.9573 68.9790 29.3569 2.4708 12.4277 69.1192 54.0625 2.4449 12.4277 118.8289 53.6766 32.5081 6756.0000 6757.8164 6702.4121 14.8149 14.9532 26.5228 -999.2500 104.3652 -999.2500 103.8270 -3429.8267 -999.2500 46.3400 O. 1000 20.1914 28.2316 20.3262 -999.2500 20.1759 15.6641 -999.2500 21.4440 16.5830 -999.2500 60.0000 135.5(:X:X) -999.2500 9(X)9.1719 15.6464 9300.(:X)00 128.0349 2.2702 2.2702 2.2316 6.2456 6.2456 25.3600 0.0386 0.0386 79.3856 80.9688 -999.2500 -999.2500 29.56.33 32.0625 24.3291 6604.(:XX)0 6571.6895 6410.5156 26.6776 35.1819 -999.2500 45.9277 45.7725 15.5745 -999.2500 29.6340 34.9898 34.6164 11.5566 -999.2500 7.7729 -999.2500 12.1160 8.1440 131.0000 135.8375 -999.2500 9030.8984 9325.0000 127.7138 2.1385 2.1385 2.1294 6.1286 6.1286 31.5494 0.0091 0.(:X)91 76.7679 79.1911 -999.2500 -999.2500 29.7697 27.5625 23.3289 6581.75(X) 6535.9844 6462.8437 31.6075 37.7916 -999.2500 9.5182 9.5047 11.9508 -999.2500 8.3800 59.0886 57.3450 5.5209 -999.2500 7.4585 -999.25(:X) 5.7410 7.8090 104.0000 133.8125 -999.25(X) 9052.6250 9350.(:X:X:D127.3927 1.9486 1.9486 1.9513 7.6457 7.6457 42.3442 -0.0027 -0.0027 76.3231 79.2566 -999.2500 -999.2500 29.9761 24.8594 22.5235 6454.50(X) 6448.6211 64 13.0557 34.5929 38.6175 -999.2500 7.1879 7.1791 13.3388 -999.2500 6.4820 20.6704 39.3290 4.3739 -999.2500 6.2075 -999.2500 4.5360 6.4820 89.(:X:XX) 134.3750 -999.25(X) 9074.3516 9375.(:X)(X) 127.2972 1.5675 1.5675 4.8396 1.7285 1.7285 60721.2031 -0.0931 -0.0931 39.1018 42.5796 -999.2500 -999.2500 30.0722 15.5781 -999.25(X3 6106.0000 6105.9844 -999.2500 59.8528 89.5523 -999.2500 35.7059 2.2316 25.36O0 71.5120 31.4122 26.1862 -999.2500 12.9540 11.5002 -999.2500 7.8246 2.1294 31.5494 66.9822 27.1184 31.2596 -999.2500 10.2860 5.5055 -999.2500 19.5138 1.9513 42.3442 69.3481 25.3298 34.8122 -999.2500 11.3280 4.3638 -999.2500 -999.2500 -132.7014 35.6126 15.8869 61.4268 -999.25(X) 35.6027 48.48S6 27.5852 -999.2500 81.1201 37.4504 -999.2500 136.1750 -999.2500 13.5928 14.2780 -999.2500 24.9510 -999.2500 29.4700 9096.0469 41.4240 13.5181 -999.2500 49.3605 9400.0000 2.0927 0.1192 -999.2500 18.5502 31.8263 -999.2500 28.2220 23.8649 -999.2500 127.5403 5.1251 0.1192 -999.2500 6715.0000 51.1536 -999.2500 25.2517 -999.2500 136.6625 2.2119 5.1251 121.2872 30.0028 6675.8437 -999.2500 -999.2500 16.6218 17.4970 -999.2500 2.2119 33.7775 118.4303 27.5625 6294.3359 -999.2500 -999.2500 -999.2500 25.4360 9117.6992 2.0927 33.7775 99.0624 27.4974 31.9558 -999.2500 0.1000 16.5158 -999.2500 19.6202 9425.(XXX) 2.4401 0.0414 -999.2500 67.7397 19.2396 28.5887 51.8569 30.4564 74.(XXX) 127.78,33 2.5525 0.0414 -999.25(X) 6755.1670 11.6178 -392022.9370 -999.2500 135.6125 2.4815 2.5525 70.0971 29.9333 6751.9551 -999.2500 -999.2500 12.4534 13.0680 -999.2500 2.4815 12.7184 70.2954 43.1562 7086.0020 28.6595 21.2090 -999.2500 32.5970 9139.3496 2.4401 12.7184 47.2157 43.0273 19.1826 -999.2500 0.1(XX) 12.3892 -999.2500 13.2389 9450.(XXX:) 2.3991 0.0212 -999.2500 71.2613 13.9667 100.0762 16.6664 34.3126 127.8022 2.6837 0.0212 -999.2500 6859.1426 11.1520 -999.2500 18.8056 -999.2500 136.1750 2.4203 2.6837 51.1092 30.4172 6854.4141 -999.2500 -999.2500 18.65.39 19.6610 -999.2500 2.4203 15.2057 51.1044 57.8036 7148.3945 100.5851 45.5840 -999.2500 9160.7949 2.3991 15.2057 44.4139 57.7781 13.9637 -999.2500 0.1000 18.5244 -999.2500 51.2845 9475.0000 2.0900 0.0980 -999.2500 31.8174 24.8247 13.1388 26.0562 127.6140 3.3881 0.0754 -999.2500 6518.6660 25.9131 14.2799 25.1848 2.6668 6.2991 72.6537 31.4118 6524.8750 -999.2500 -999.2500 7.0569 2.1654 8.9252 72.8501 33.3,3,.33 6432.6084 13.1581 11.1800 -999.2500 2.5027 33.9398 57.7046 33.2462 24.7129 -999.2500 12.0210 7.0,331 7.4893 183.0000 95(X).(XXX) 2.2243 0.0980 -999.2500 44.5862 17.9754 11.3682 10.8303 7.1477 -999.2500 9525.0000 2.0840 0.0380 -999.2500 33.6420 16.6812 8.8044 7.4924 5.7696 194.0000 9550.0000 2.0610 0.0693 -999.2500 37.7401 19.7281 12.0603 18.0350 12.6395 168.0000 9575.0(XX) 2.0427 0.0908 -999.2500 30.2992 17.4695 9.2322 16.4663 4.9407 178.0000 -999.2500 135.7250 127.4258 2.8524 0.0878 -999.2500 6680.0(X~ 16.8495 12.5511 7.9390 -999.25(X) 138.0875 127.2376 2.7716 0.1395 -999.2500 6846.50(X) 28.0792 9.4137 8.6235 -999.2500 128.1312 127.2000 3.4594 0.0058 -999.2500 6824.0000 20.9803 15.9650 19.6808 -999.25(X) 131.4500 127.2(X)0 3.4240 0.1020 -999.2500 6832.1660 27.1102 8.1663 16.5605 -999.2500 135.1625 7.3570 -999.2500 2.6668 5.1034 53.9049 32.4064 6760.6289 -999.2500 -999.2500 5.7600 5.9920 -999.2500 2.5593 6.7518 50.2146 33.4011 6846.5586 -999.2500 -999.2500 5.1138 5.3110 -999.2500 2.5668 7.7658 47.8836 34.3308 6811.9199 -999.2500 -999.2500 6.0365 6.2840 -999.25O0 2.5558 6.6763 45.2375 35.2442 68,33.7266 -999.2500 -999.2500 5.9633 6.2280 -999.2500 7.8420 9182.0488 2.3121 10.~0787 53.6184 46.6875 6721.5107 11.3852 9.8390 -999.2500 7.4800 9203.3047 2.2235 7.7973 51.8211 50.5312 6496.3613 8.8166 7.8170 -999.2500 6.0200 9224.5605 2.0667 9.2'397 46.9669 42.0937 6291.6826 12.0782 10.3680 -999.2500 13.3360 9245.0898 2.1447 11.2172 46.7927 47.5729 6466.1494 9.2450 8.1620 -999.2500 5.1440 9265.4395 -999.2500 56.7279 2.4837 25.8017 44.4058 45.6861 17.2959 -999.250O 10.7400 5.7434 -999.2500 21.7762 2.5213 34.3005 43.2673 49.4366 16.2545 -999.2500 8.3070 5.1004 -999.2500 53.6671 2.4975 35.6947 28.10,33 42.4200 19.9427 -999.25O0 13.2330 6.0188 -999.2500 47.7307 2.4649 36.8062 50.4011 47.3570 17.3717 -999.2500 7.2980 5.9658 -999.2500 50.4282 9600.(XXX) 2.1492 0.0137 -999.2500 39.7844 17.1499 7.5970 11.6849 5.1953 216.0000 127.2000 5.4218 0.0137 -999.2500 6702.(XX30 20.7379 7.6543 13.9139 -999.2500 137.4125 2.1630 5.4218 42.7344 36.1577 6688.5713 -999.2500 -999.2500 4.8701 5.0560 -999.2500 2.1630 30.3497 43.5846 45.8750 6685.6611 7.6065 6.8300 -999.2500 5.4130 9285.7891 2.1492 30.3497 39.0281 47.1904 17.7103 -999.2500 6.8770 4.8580 -999.2500 48.4945 9625.0000 2.1095 0.1206 -999.2500 34.1547 12.4750 9.5076 20.8547 8.5734 -999.2500 127.2(X)0 6.3012 0.1206 -999.2500 6744.50(X) 25.1600 11.5261 22.0576 -999.25O0 138.8750 2.2301 6.3012 38.9329 37.0712 6687.3(X)8 -999.2500 -999.2500 -999.2500 7.08(X) -999.2500 2.2301 32.7583 39.0473 63.6875 6646.5059 -999.2500 8.3830 -999.2500 8.9950 9306.1387 2.1095 32.7583 41.8946 62.1204 12.2446 -999.2500 9.9610 6.7710 -999.2500 53.3945 9650.0000 2.0115 -0.0044 -999.2500 40.4332 9.6327 12.3600 7.9414 15.4399 127.1030 6.8630 -0.0044 -999.2500 6844.0000 19.8050 40.2909 7.3164 -999.2500 137.3750 2.0071 6.8630 43.0424 37.3758 6849.6035 -999.2500 -999.2500 -999.2500 10.7530 -999.2500 2.0071 38.6989 41.8501 79.0312 6681.6465 -999.2500 10.5970 -999.2500 16.3420 9326.1816 2.0115 38.6989 41.3455 78.4387 9.5312 -999.2500 27.2220 10.2226 -999.25O0 51.8108 9675.00(X) 2.2210 0.0683 -999.25(X) 42.3635 14.2881 10.5518 6.04,33 6.6064 104.0000 126.9515 4.9809 0.0683 -999.25O0 6737.3994 19.0781 17.1400 6.5848 -999.2500 140.7875 2.2894 4.9809 49.2920 37.3379 6726.8~7 -999.2500 -999.2500 -999.2500 5.7670 -999.2500 2.2894 25.9985 48.3012 54.2375 6651.9531 -999.2500 9.2070 -999.2500 6.9050 9346.0566 2.2210 25.9985 47.1915 55.7409 14.7493 -999.2500 14.0490 5.5314 -999.2500 51.6851 9700.0OO0 2.2379 126.8000 6.4745 2.2486 6.4745 2.2486 24.9745 2.2379 24.9745 0.0107 -999.250O 28.9153 23.0901 -999.25O0 5.5967 12.8329 89.~ 9725.0(X)0 1.6226 0.0022 -999.2500 13.7140 57.7703 -999.2500 17.8484 53.2985 9750.0000 1.8568 0.0162 -999.2500 17.2752 78.0484 -999.2500 198.0883 103.9182 -999.2500 9775.(XXX) 2.4413 0.0536 -999.2500 38.9282 25.8703 -999.2500 11.6920 30.9246 154.0000 9800.0000 2.3167 0.0368 -999.2500 0.0107 -999.2500 6555.0(X)0 29.6263 196.4978 5.4657 -999.2500 144.0687 126.5685 7.1532 0.0022 -999.2500 6278.0000 79.1697 -999.2500 20.4530 -999.2500 147.2000 126.3370 8.0263 0.0162 -999.25(X) 5819.2500 50.8497 39.1930 147.3139 -999.25(X) 147.8750 126.1056 5.0604 0.0536 -999.2500 6736.0000 21.6948 -999.2500 11.1344 -999.2500 136.5125 125.8741 5.2844 0.0368 -999.25O0 117.8276 37.3O00 6552.4014 -999.2500 -999.2500 -999.2500 13.9610 -999.2500 1.6247 7.1532 100.6773 37.6241 6278.3096 -999.2500 -999.2500 -999.2500 43.2560 -999.2500 1.8730 8.0263 82.9311 37.9481 5826.6982 -999.2500 -999.2500 -999.2500 32.5280 . -999.2500 2.4,949 5.0604 121.4127 38.2722 6731.3604 -999.2500 -999.2500 -999.2500 -999.2500 2.3536 5.2844 101.7310 38.5963 120.1961 35.7812 6590.1289 -999.2500 -999.25(X) -999.2500 13.5440 9365.9297 1.6247 62.2683 102.6222 16.6250 5872.5352 -999.2500 -999.2500 -999.2500 57.6430 9385.6289 1.8730 48.0733 83.7363 13.7773 6009.4453 -999.2500 -999.2500 -999.2500 114.1060 9405.3301 2.4949 12.6499 119.1268 32.7656 6752.9229 -999.2500 -999.2500 -999.2500 33.1070 9425.0293 2.3536 20.1982 102.9000 17.7187 112.4015 35.5156 22.8933 -999.2500 57.0880 13.2238 -999.2500 51.1050 1.6226 62.2683 79.5543. 16.6687 57.9483 -999.2500 0.1000 40.2123 -999.2500 50.4862 1.8568 48.0733 59.5940 13.0587 69.6997 -999.2500 26.7760 30.3933 -999.2500 41.2431 2.4413 12.6499 109.7208 34.2909 26.4375 -999.2500 0.1000 18.8705 -999.2500 56.2196 2.3167 20.1982 98.9978 17.7968 23.1886 52.6693 -999.250O 8.5392 80.8513 154.00(30 6294.(XX)0 36.3305 -999.2500 11.8355 -999.25(X) 139.1000 6300.7314 -999.2500 -999.2500 -999.2500 31.7730 -999.2500 6146.9824 -999.2500 -999.2500 -999.2500 88.2730 9444.7305 52.8231 -999.2500 0.1000 29.7041 -999.2500 58.1726 9825.0000 2.3969 0.0291 -999.25OO 31.1679 32.5330 24.7762 14.5138 9.7110 122.0000 125.2811 5.3,.3,93 0.0291 -999.2500 6660.0000 28.7297 17.8059 11.6700 -999.25O0 141.5187 2.4259 5.3,393 75.3071 39.3084 6658.4336 -999.2500 -999.2500 -999.2500 8.8870 -999.2500 2.4259 15.3414 75.4745 26.8594 6712.3193 -999.2500 18.9800 -999.2500 10.2070 9463.9785 2.3969 15.3414 74.8710 26.9304 32.6510 -999.2500 14.5090 8.4716 -999.25O0 52.7680 9850.0000 2.2100 0.0100 -999.2500 28.0989 23.2280 15.3978 21.8715 9.1863 124.5179 5.9881 0.0100 -999.2500 6700.5000 30.1281 12.7831 23.8486 -999.2500 142.5875 2.2200 5.9881 77.5723 ~.2032 6700.9043 -999.2500 -999.2500 -999.2500 8.3080 -999.2500 2.2200 26.6686 75.1283 37.8125 6566.7891 -999.2500 12.8280 -999.2500 9.6450 9483.0156 2.2100 26.6686 76.7686 38.2666 22.2685 -999.2500 10.9150 7.9281 -999.2500 59.4779 9875.0000 1.5803 -0.0269 -999.2500 14.5918 78.9971 -999.2500 51.2015 1142.9189 144.(XXX) 123.7547 4.6031 -0.0269 -999.2500 5983.(:XX:X) 68.5004 -999.2500 48.3903 -999.2500 143.4875 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19.9717 74.1928 32.6615 27.4608 -999.2500 13.4380 9.7543 -999.2,500 2.0055 39.0605 55.7505 32.6111 31.0590 -999.2500 0.2550 9.1328 -999.2500 56.3260 2.1535 30.0893 61.4350 33.9427 24.7186 -999.2500 0.2510 6.1881 -999.2500 48.6447 2.3999 15.1600 50.8089 51.6437 16.2206 -999.2500 0.2600 6.5054 -999.2500 -999.2500 6.7980 O. 1010 -999.2500 301.0(X)0 149.0000 -999.2500 9592.1797 52.1646 10025.0000 121.5000 2.3690 2.3690 2.3237 2.3237 2.7105 2.7105 19. 7763 19.7763 0.0453 0.0453 55.7990 56.1209 55.3145 -999.2500 -999.2500 47.50(X) 40.3437 41.2244 50.8030 6810.0000 6836.3203 6928.1494 20.9081 20.5113 16.4372 -999.2500 -999.2500 -999.2500 -999.25(X) 0.2847 -999.2500 -999.2500 0.2810 9.7373 13.6210 -999.2500 -999.2500 40.7120 -999.2500 -999.2500 43.7960 O. 1010 -999.2500 215.0(XX) 150.8000 -999.25(X) 9609.9121 53.8315 10050.0000 121.5000 2.4185 2.4185 2.3492 2.3492 3.0021 3.0021 18.2324 18.2324 0.0693 0.0693 51.65,98 51.2164 49.8682 -999.25(X) -999.2500 48.4091 49.0625 46.2045 53.1233 6884.0000 6856.0518 6904.2156 16.9557 18.2210 15.6091 -999.2500 -999.2500 -999.2500 -999.2500 0.2875 -999.2500 -999.2500 0.2840 11.2514 9.2027 -999.2500 -999.2500 47.7106 -999.2500 -999.2500 51.4930 0.1010 -999.2500 297.0000 151.4750 -999.2500 9626.2129 55.5525 10075.0000 121.5000 2.4701 2.4701 2.4340 2.4340 2.5380 2.5380 13.0918 13.0918 0.0362 0.0362 53.4897 53.7388 50.0660 -999.2500 -999.2500 49.3182 55.8125 57.4556 65.9788 6900.0000 6931.4482 7040.8330 14.7084 14.3498 12.650 1 -999.2500 -999.2500 -999.2500 -999.2500 0.28,96 -999.2500 -999.2500 0.2860 20.7534 19.2388 -999.2500 -999.2500 50.6622 -999.2500 -999.25(X) 54.7450 0.1010 . -999.2500 -999.2500 150.8(XX) -999.2500 9642.5117 56.7044 10100.O(XX) 121.5000 2.5046 2.5046 2.43.53 2.4353 2.9528 2.9528 13.0094 13.0094 0.0692 0.0692 49.5655 52.69,39 62.8238 -999.2500 -999.2500 50.2273 55.0625 55.2269 60.9881 6896.~ 6874.3457 7034.4883 14.9306 14.8611 13.8131 -999.2500 -999.2500 -999.25(X3 -999.2500 0.2868 -999.2500 -999.2500 0.2830 16.7202 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52.2459 7021.8428 13.6048 -999.2500 -999.2500 49.6490 -999.2500 -999.2500 -999.2500 49.8803 52.8540 -999.2500 11.3048 -999.2500 -999.2500 37.5955 -999.2500 -999.2500 -999.2500 57.3115 53.0000 -999.2500 19.1802 -999.25O0 -999.2500 44.1772 136.4000 2.5089 12.1121 51.8108 65.2500 7055.3760 -999.2500 -999.2500 -999.2500 0.1010 9675.0820 2.4579 12.7585 48.9525 66.1521 7021.4746 -999.25O0 -999.2500 -999.2500 0.1010 9690.5312 -999.2500 -999.2500 48.7421 -999.2500 -999.2500 -999.2500 -999.2500 37.7996 0.1010 9705.7324 -999.2500 -999.2500 57.2500 -999.2500 -999.2500 -999.2500 -999.2500 44.4487 -999.2500 9720.8164 2.4502 12.1121 58.4640 67.4154 12.6391 -999.2500 0.2840 49.1688 -999.2500 25.0653 2.4395 12.7585 51.5841 66.2369 12.4092 -999.2500 0.2860 46.0362 -999.2,500 30.5828 -999.2500 221.2121 49.8803 -999.2500 11.3048 -999.2500 0.2850 37.5955 37.5955 -999.2500 221.2121 -999.2500 -999.25O0 19.1802 -999.2500 -999.2500 44.1772 44.1772 49.3386 lee:l = ~un q dea e~ ede.L O(X)O~'O = §up~:ls le^e'l 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Tape File Depth Units = Feet Tape Subfile 4 is type: US MICROFILMED 11 II~-~ i i i i [ I ********************************************************************************* ******************************************************************************* ** ******************************************************************************* ******************************************************************************** :39~d : ~d~ 9fiOlA~d ~ : # ~Oi£~fiNIiNo3 3I?]J : NlgiaO : "iM~ gFlOiA3~d IS Ta~e Verification Listinq cblumberger A!aska Co~p~.lti~q Center PAGE: ELEVATiO~,~S ~F{: ! 10' DRtBLE~ LOGGER t 12550' 9.6~5" 47 b.~% !~ DRtLbE~ DE;PTH OF B417' 7" 29 !,.,B Ca DRILLER D~;~""f'H OF t0~2.4' BIT SIZE !: 6" ~ 12563' TYPE FLUID 'I~ !',,IOBE: PHPa DE~SITY: 9 FbUID !i.~OSS: 3.,4 !~.UP RESISTIV'IT¥: F'!LTa/iTE RESIST!V!TY., '~!'[JD CAKE RES!STIVI~Y: .59 ! .9~, ~ 68 DEGF LOGGING DISTRICT; DTC-EC 264 PD?{-L 2823 NSC-E 730 GPlC-A ~3:4 !.DP/A~4A: R. ssoq P~nt~ q~ P~nt~ Du~IT~O IeA~UI ~Oq do~ I~nza~uI boq ~o~o~ zaTTTzO - q~daO Ta^eq puno~D ~o uo~e^et2 zOOt2 ~Izzeg ~o ~o~.~ pa~nseai~ boq mn~eO ~ueue~e~ ~o uoT~e~ aDu~AO~d I0 abu~ dT~U~O& L o 0 9 E £ L E 0 q 9 T uofsue2 peen ~£H A':t~SO~Od UO~na~ '[e~eq& A]'~o~od uo~oe¢ IHdN uotsu~ Pe~H A~d e~eD iS Tar~e Verification bistlno zhl, umber~er Alas<a Comt~t~t~no Center I.-'JUN-!992 !~:!3 EPT F .... 551,!. O0 .00 O0 !. I, I 000000, O0 C!!~P DTE a~,~ 548511. O0 000 O0 0 I i ! 4 68 0000000000 !DP~ DTE C,::~.~,:;:~ 542SJI 00 000 00 0 1. ! 1 4 6B 0000000000 CIMP DTK l~::,tHO 54851:! 00 000 00 0 I i ! 4 68 0000000000 I~PN DTE OH::,~ 54:8511 O0 GO0 O0 O ! ! i 4 68 0000000000 C!LD DYE ,q~4hO 54851~. 00 000 00 0 l. 1. I 4 68 0000000000 I!.~D DTF 0~,~ 5425ll O0 000 O0 O I ! 1 4 68 0000000000 ClL'~ P!?K ~:~a~.i<:.~ 54a51.! O0 o00 OO 0 1 1 ~ 4 6g 0000000000 II.:~ D~E Oii?';~,~ 54:S5ti 00 000 00 0 1 1 ! 4. 68 0000000000 1FRK D?g hZ 54851 J, 00 000 00 0 1 I 1 ~ 6a 0000000000 !DQF DTE 5495! I 00 000 0m 0 1 1 I 4 68 0000000000 !~OF DTE 5485t!. 00 000 00 0 1 I 1 4 68 0000000000 il!RD DTE ;q::4}~O 548511 O0 000 O0 0 I 1 1 4 68 0000000000 IIXO DTE ~,~,,iai'..~ 548511. O0 000 OO 0 !. I 1 4 68 0000000000 IIR~ DTE F~,:t~a 54~511 O0 000 O0 0 1 I 1 4 68 0000000000 IIX~4 DTE y~:}..~'~3548511. O0 OOO O0 0 1 I I 4 68 0000000000 SFLI.i DTE OH;:~'~! 54~5!1 O0 000 O0 O 1 1 1 4 68 0000000000 SP aTE ;::V 5485 !. 1. 00 COO O0 0 I 1 1, 4 88 0000000000 GR DTE (;bPI 548511. O0 000 00 0 I I I 4 6a 0000000000 TEaS ~TE k~3 548511 00 000 o0 0 i ! I 4 68 0000000000 ~"rEu DTE DE(;F 5~aS~! OO 000 O0 0 i 1 1 4 68 0000000000 MRE:g OTE [~H~'~ b4~5!1. O0 o00 O0 0 1 I 1 4 68 0000000000 HTE~ DTE bB 5~5!1 O0 000 0O 0 1 1 1 4 6~ 0000000000 RB aTE [)'EG 548511 00 000 00 0 i ! 1 4 68 00000000O0 AZI~: DTg t)E(; 54851,1 00 O00 00 0 1 I 1. 4 68 0000000000 u~g! aTE DFG 5:185! 1 00 000 O0 O ]. ] 1 4 68 0000000000 DEV'I DTE OEG 54851'1 00 000 OO 0 1 I 1 4 68 0000000000 Pl.~% r)T[: DEG 5'!8511. o0 000 OC, 0 1. 1 1 4 6~ 00O0000000 DPHI I.,[)T P[J 54~511 00 000 O0 C: ! I 1. 4 68 0000000000 R~C~ LD17 G/C3 54:~51.1 00 000 00 O 1 1. I 4 68 0000000000 DRH~ 50T G/C3 548511 ()0 0(.?0 00 0 !. 1 ! 4 68 OOO0000000 PF~ !,DT 54'35! I 00 O()0 0O 0 1 I 1 4 6a 0000000000 OLS !.., D T 54~51 1 00 00n O0 0 I ! 1 4 6~ 0000000000 GSS I.,PT 54~51 t. t~O 0~0 O0 (> ! 1. 1. 4 68 0000000000 LS L~T CPS 54~5t ! O0 OOO O0 0 I !. 1 4 6~ 0000000000 L!I L[':T CPS 54851 ! O0 000 O0 (: I 1 I 4 68 0000000000 LL !.., C- T CPS 54B511. 0(, 000 oO (.~ ! !. 1. 4 68 0000000000 LIT~ L[~T CPS 5485!1 or, 000 O0 ~., 1. ! 1 4 6~ 0000000000 881 I.., D T CPS 5~4~511 O0 O00 O0 0 1 :1 1 4 68 0000000000 882 LD:r CPS 54a51 I 00 0o0 00 0 1 1 I 4 6a 0O00000000 I.,SHv LDT V 54251 1 O0 000 O0 C, l 1 1 4 6~ O000000C, O0 SS~i¥ I,[)T V 54~511 ()O 0C, 0 0() O 1 J. 1 4 6g 0000000000 SIRN I,OT G/C3 54~b1.1 00 000 00 (: ! I ! 4 68 000DO00000 I,SP~ t, DT G/C3 54a51l (..n ooo O0 0 !. l 1 4 68 0OO0000000 LU~N I,i:)T G/C3 54~511 O0 OOO O0 0 I 1 I. 4 68 O00000000O C~L! LF)T IN 54i~511 O0 OOO O0 u 1 1 1 4 68 0000000000 RR BDT [)FG 54~51 } O0 0OO O0 C 1 i 1 4 68 0000000000 A%I~~ I.,DT {:) E (; 542511 O0 000 O0 0 !. 1 1 4 6~ 0000000000 ~.~gI T,DT r)gG 5~511 00 000 O0 0 ! ! 1 4 6g 0000000000 DKVI bDT [)EG 5'!251! O0 000 O0 C, ! !. 1 4 6g O0000OO000 IS Ta~e. verificati, on Listir~q cblomberoer nlasP, a C, omputi~1 Center 1-dU~?-1,992 !.,~:1,3 ~ ..... $ F .... I 0 0 i{ D E R P!AZ LDT DEG 54~51! O0 000 O0 GR I,.~9~ G~:Pl 5,4~51. I O0 000 00 T E ~$ L~,~) T ....... b E 5485 ! ! o 0 O. O_ O. 00 ~TEu LDT DE(;F 548$t! O0 000 O0 .... ,~ ..... ~,'. 5 8511 O0 000 0() NPH! C~L pl~ 54~511 00 000 O0 RTNR C3;L 54851! 00 000 O0 TN 1:'~ CNb PU' 548511 OO 000 00 TN~ C~I., 54851! O0 000 00 NPOP CNL PU 54~51! O0 000 O0 RC~JT: CNL CJPS $4P%11: 00 000 (>0 RCFT Chh CPi; 548511 ()0 000 OO CNTC Cab CPS 54S5!! ()0 000 O0 CFTC C ~i !.,, CPS 5~,~ 5:1 !. O0 00() O0 g ~ C ;xi I., G,a P I 54851. I. 00 000 0 o T ...... ~!S I, LB 5485!.1 O0 000 00 ~PEg CN!,:, OH?i~ 54:a5tl O0 000 O0 NTE~ CNL DEGF 548511 O0 000 O0 HTEN Cf~;L Ln 54851 l O0 000 00 ,.. ~ } ~ ........... A g I ~ C ~,:~; 1., 0 (; ,:i 4851 ! 00 0 O 0 00 H .gI CN:I., oEg 5~.8511 oO O00 O0 DEVI C2JI, OEG 5485!1 O0 000 00 pi. Ag C?~L OEG 54¢51! 00 000 O(> A I APl: A APi ~':I:~,~ ............ IZg REPR PkOCg$8 LOG TYPE CLhSS ~OP ~u~O SA~P g!..,E~ CODE (HEX) 0 1 ! 1. 4 6a 0000000000 0 l ! I. 4 ~8 0000000000 0 I 1. 1 4 68 O0000000O0 0 1 I I. 4 68 0000000000 0 l 1 1 4 68 O000000000 o I I 1 4 6~ 0000000000 0 1 !. ! 4 68 0000000000 0 1 ! 1 4 68 000000o000 o I ! 1 4 68 0000000000 0 1 I 1 4 08 0000000000 0 l !. I 4 6~ 0000000000 © 1 ! I 4 68 0000000000 ~ ! l t. 4 68 0000000000 0 1 I l 4 62 0000000000 0 ! I I 4 6a o000o00000 0 ! 1 1 4 68 o000000000 0 I ! 1 4 68 0000000000 0 I !, I 4 68 0000000000 o 1 !, 1 4 62 oo00000000 0 I. ! 1 4 68 0000000000 0 1. i 1 4 68 0000000000 0 I ! ! 4 68 0000000000 o I 1. ! 4 6~ 0000000000 0 1 !. I 4 68 0000000000 0 1 1 1 4 6~ 0000000000 , · i) ~ T A * * DEPT, I~593.5©o I ~-~¢U. [):!:E 1 !.,~'. DTE I IRE~. UTE S F l.,{t .DTE 42, ~TE~'. O'!'E 173.750 DP}iI, Lt)T 6. 'l I ! O !., S, [, U, T O, 0 ! 7 L L. I, O T LS~V.LDT 1366.000 LURH. LDT 2,557 H~Z!. LOT TE[':8, bDT I O NPHJ.C?~[., CFtC, C~/I, ~TF,~ . C?:I., i 73.75u fl ~gl. C/v!, ~ 0,962 22.563 !" DP !.!. DT~; a4,~. l CI.~4P. DTE 23.719 I'1~o, (')TE 42.125 C I: 1..,~. DTE 20.000 !D~2F. 9TE; 3.000 I~iOF.DTE · 1 371 I:l~,"~.OTg: 20.969 IIXa.DTE 3~5 ~ 750 "(;~. OTF: 1 I 7.313 ~E)4$. DTE -C.093 NT~: '~. i?,TE !0~.g75 RB.DTE 8().9e2 9k:VI. i)T~; 03.607 P1AZ.DTE 2,539 D~L:,. LD? 0.002 PEF.I, DT 0.020 ].3. 217.000 !,ti. BDT q3,46.9 SSI,LOT 194.500 8S2.LD~Y 399.0o0 8IR~i,LBT ~,527 bSR~,LDT 6.0~,0 ~b, LDT 134,286 AZI~.LDT t.~3.6C, 7 Pl~Z.LDT 194.402 GR.LDT 173,750 ?,~RES, Li)T -0,093 HT.~.jN, LOT a37! .2~I PC.~T. CNb 6162.!79 CNTC,CNL 117.3! 3 TE?0S. C~ib 1085.000 ~RES. CNL 102.~'75 ~ ~. Ci~'i, 134,786 AZI~.C~L (:3.6()7 P!AZ,CS~L 194.402 21.313 22.03t 2,000 6,418 1085,000 134.206 194,402 6,?73 20~.750 268 000 2535 80'962 117~3!3 102.~7b 1.298 ~818.734 -0.093 80.962 !$ Tare Veri!icatien LiSti. nq 2hlUmberqer h!ask:a Computing Center tlRB.DTE 2! .734 SFLU. CTE 42. 938 SP. OTE . ...... ~ ,- LL. LOT i 16. 375 LIT~. L,!)T L D BoHr. LOT ~ 366. 000 So~U. ~ D 962 DEV I. oi..) ' N P H l. C N l,, 11.17 ~ 8 '.r ?,~ p.. (.? N L ~ T E ~:. C N l 73.75 o H T E :q. C i'~ L ! ~ P ~. D !ir [: 34,. 625 C SF[,t~ DTE 27 45.;i SP DTE NTE,~.DTE 173.375 AZ!~.DTE ~1..727 HAZ!.DTE D P H I. L D T 1 i. 996 ~ }'! 0 [.~. L P T ,.~ S 5. i D T OLS.LDT 0 012 [.,L [jOT 1_ 2~:: 750 LSHV.[,DT ~.366,0g0 SSHV. I.,DT LURN.LST 2.479 CA!,, I. t.~OT HgZI. I,;')T 81.727 [)EVI. i,DT TENS. [.,[)T 1 O45. 000 t~'rEu. !.,,PT NP0~.CaL 15.1~7 CwTC. C~[, 43~!. Oq8 G~.C~;L ~'rEu.CS]b !73.375 DEPT. ! 230il,. OCli) CltbP. IIRD.DT~ 27.43~ [IXO.OTE SFI..,U. DTE 31,. b I o SP. ~TE~. DTE 172. t~75 '~RES. ATI~,~. DT~ 82.010 ~AZI.OTE DPH !. LOT ]. 2. 407 ~;ob. OLS. I, DT 0. OC;9 OSS. i,DT LL,. LOT ! 34. Oa0 [.,I TH. LOT LSHV. LOT 1. 36~>. uO~ S,SH~;. bDT LIJRP.LDT ?.455 Ha.Z l. LOT 82. () 1 ~., D~]V I. t,PT 22 , $ ~ 3 ! D P [{ , D T E . 828 ! b i',) nTE 20.000 I90F,DTE 1.270 ! I~:~' DTE 353, O00 G~:, OTE 80.962 DEVil,gTE 2.497 -0 011 L%,bDT 5.~56 b3.6~i7 PlAZ,LDT 173.750 ~RKS, LDT " I, 3 42 T ~ P ?~, C N [, 8371'291 RCF'I . 1,17,3!3 TENS,CNL 550,5 O 0 Ra, 63,607 P!gZ,CNL 2 8,4 o 6 I 29,844 .... 20 OuO l r),Q F 328. 250 GR. - 0,0 80 g! .7'27 DE~!.DTE '0.0 i0 L5. 5~. 7bO SS! .Lgr !400.000 5. 992 R6. e3 7~9 Pl AZ.bDT ! 73~375 ;4FES, LOT 64 O 5.908 4.2. gg.i TENS, C~,IL 612. C)On 03.759 PlAZ.C~L 25.953 Il)P4. t)TE 30 o 26,6 O.4. al e: 4.500 G - n. 075 82.010 -0. OOO b5. [,PT h6.87fi SSt.LOT 5. 824 ¢6. LOT o4,4i6 :~! AZ.LOT 0,000 21. 078 I t 7,313 550.500 63.607 -0,0!3 226.750 1,87.875 2.563 1,34.286 194.402 -0,093 :I0 801 1;62!379 ~lSO 000 .. 134,2,86 194:, 402 35 156 0 000 42. 094 612.00o 63.759 -0.01, 4 245.750 i 90. 250 2.52O :!52.658 2.1.2.29O -0.0~0 !4.874 3951.0! 4 1045.000 152.65~ 212.9.90 34.531 33.000 0.000 28.0'11t 39.625 69B.500 64.416 -0.0()1 255.250 19~.250 2.449 153.828 713.310 -0.075 PAGEI 20.953 22,156 0'000 6,793 1180,000 134.i286 !94.402 4 715 220 625 272 250 2,510 80,962 117,3!3 550,500 1,298 8818.734 -0,093 80,962 28.844 29.703 0 000 5:590 !045 000 152 658 212 290 3.467 234.000 277,750 2,465 81.727 42,094 6~2.000 1.534 6831'717 -0.080 81.727 28.906 29.516 0,000 6.941 1120 000 213.310 3.123 242.375 288.500 2 445 39.625 693.500 qLS'9~a g69'g ~gL'6oE L69'~$I O00'O~I~ 000'0 090~[8 t£0'0- ~99'g8~9 O09'LE9 090'~8 69~'g O~g'g6g ~£'L~ O00'OLg[ 000'0 [98'08 gLO*O' 0Ig'9969 O0 IgL E98'~8 LL~' 00~'~8~ ~'L8°8~ ~0~'~ ooo°o~'~l L98'~ oo0'0 9~0'8t 69~'L~ 010 ' ~8 c.:.;L0'0- 88~ I £dq'Nq £dq'~Sd ~£d'nXiI ~£o'wqI3 rl~O'xlZV £Qq'fiq ~oq'M~d 3~O*Z~Id ~,O'~Xli M&o'wqlO £oq'Hsgq ~O'dWI3 SOO'O- I69'g9 Oqg'£E 000'0 SLE'E~ 9~'['~ O00'OLE'{ iLO'O- O0~'~og ~gg'6Pg OIO'O 0O§'££9 gLg'91 000 ' 0 889',L§ gL, 8'90g %~'6Pt gLO O- gLS'90g 6~ g O00'g~g PO0'O OOS"t[L 000°0 IS Taoe Verif..ica. ti, cn List.inc~ chlU!:~berger A],aska Comvt~.tinq Center' BI~,. !,,DT !.36.250 L,!Tii.LDT I,~SH¥. LDT 136~.0©0 LURH,LDT 2.443 CALi.LDT ~ ~ Z I . L D T 81 . J 77 ~, E '? I . L D T NPHI.CNL I~''3. 524 ~T~.CNL NPO~.CNI, !5.g72 ~Ct'iT,CNL CFTC . C t:,~ L 4044 . 842 OR . C~L MTE~ . C~ I,, !71.375 HAZI.CNL 81.t77 DEV I.. C~:~L D E P T l I 9 o 0. .. TE ......... DTE ! 7, IIRt,. .................. SF[.,U. OTE 59. 625 SP. DTE ~TE:~. DT"E !70,750 ~:4RFS.DTE AZ!~',OTE gl.271 ~AZI DTE ObS. bDT 0.0O0 (]SS. bDT LL.LDT !~5'68~ UITH.LDT LS!-iV, [,DT 1366,0Off SSBv, LDT LUR~, LDT 2,529 C~!,I, LDT HAZY bDT al,27I DEVi TE;NS.LgT !o45 000 NPO~, CNf] 11 ,66~ CFTC, C ~ !., 54 8 ~:~, ~TE~{', CNI, 17{' 750 HTF~ " " .. :,' · · t ..,,,. l ~ 0 88 i , bDT 1399.000 81 ~5i, bDT 5,092 Ri3,LDT 65.691 PlAY LDT I. 696 TF!PH. CNL 5q()8.941 RCFT,C~L 37.250 TENS,CNL 654 ' 000 ~.b. C ~,~ !.~ :1 a, ! 88 I D P !i, DT E 19. 250 ILD.DTE 20,000 I 0.364 336. 500 CR,'bTE -O.071 ~; 1,271 O E;'V !, O T E 2.521 DRHO.&DT '0.010 l.,S, LDT 60.156 SSl,bDT 399.0 O 0 $1 R H, I., P T 5. ~63 bR.167 PilZ.L, DT 170.750 ! .428 7067.403 ~CFT,CNL 38.0~3 TE~:8,CNb [~47. 000 RG, C~VL bB. I t:,7 PI.,~Z.CLb I~.266 .1' DPfq, OTE ~ 9..32 ~ ! b 20.000 !I>0F', DTE O. 218 :[ !a ~. I>TE 347,750 Ga -o. 07 ! ~ 1.502 D o.0t;2 LS,LDT 70.43g 88! .LOT ! 39q.(-)00 S! F.:I. I.,DT 5.82,i I 7o. 37 5 xE~.:S. LDT I .R77 ? ! 3,75 g R C F '[', C ,'~ .[-~ 33.503 r k; f,: S. C ~,,i b ~ 63.560 R ~, C ~.~ L 6~ .363 !9.261 I..DPH. DTE 20.297 I! 9.DTE 2 o. 0 {) 0 I r',, ~ F. D T E 0.446 r_.!R .~,OTE !.96.750 2 455 152:697 209.762 -0.071 15.!.~5 3632.616 t 110 000: !52:697 209.7~2 54.938 51.966 0 o 00 16:688 38 063 847: .000 68.:!67 -o. 006 224'125 190,625 2.551. 1,{8.936 203. 009 -0.071. 11,8:5 4940,4 2 1.045 000 148:9:i6 203. 009 54 719 5.t:6 a 0 O00 16:547 33.56) ~03.500 ~ 363 258.500 19.8.875 2.441 154.367 -0.07! 14.a50 3854.963 940 000 15~[367 209.076 51 8!3 49:250 O. 20. ClXP.DTE CILM.DTE IMOF.PTE PAGE: 10 283,500 2'438 81,177 37.250 654,000 1,608 6392,228 ~0,071 ,1'177 !6.6 0'o00 5'7 i045,0~40 148;936 203,009 2.820 217 000 275 000 2 525 81.271 38'063 847.000 1,376 74t8,243 ~0 071 1:271 16719 17;391 0.000 5.695 940.000 154,367 209.076 2.828 248,125 286.500 2.439 8i.502 33,563 803.500 1.540 6632.570 071 21.438 21.203 0.000 .6,328 IS Tape Verification ListJ..nq ~!um~erger Al. as~:a t.o~.putine Cent;er SFbU, DTE .42,000 SP, MTE~, DTE 169,625 iiRES., AZIZa. DT~ 80,971 HAZI.DTE DPH!, LDT I~, 335 LL.LOT 1~3.75o LSHV.LDT !366.00!) SS!'~V. I,,DT LUR~.LDT 2.4!8 C~LI.LDT H l Z I, L [')T 80, 971. O E V '.[ b ..~ .~. TENS.LDT lifO.000 qTEa,LDT NPH!.C~iL 16.927 RT~:~R. C~L CFTC,CNL 3~37.527 GR.. ,C~'.~L ~TE~'CNL 169.625 HIZI.CN[., 80,97! DE'V I,C~L DEPT. 1 ! 600.00(i ..., D T g 5 (~, 09 ~- I!R~.DT~: 19,094 MTE~.DTE 16~.875 DPHI, LDT ] 2.038 ODS. bDT O. 025 LL,LDT 134,90(~ LSNV.LDT ~366,00(~ L!tRt-~. LDT 2.467 H~ZI.I~DT i~0.092 T E H 8. I., D T a 25.000 NPH!.CNL 16.3!7 c F T C. C ~ i.i .] 7 2 7.4 :~ 4 NTE~. CF~I, 168,875 DEPT, llbO.q f~().'.) ClDP. !uP~. PTC 54.571 :t CII,~). IIRD nTK ~n t,O0 .I.lXi'~ ~T~ SFLU. DTF 52.3 d4 SP. F, TE~ ~ ./ . . e . . . -,,, _ ' ~ . '. DPFiI.i~;! lJ.~3a P~,O~.I, Ll..LDT 133. 375 LIT~.. LOT LS~'d. LDT 1365. 000 SS~V, LOT !,,!iRa. I.~DT 2,461 CAI:'[. HAZ!, LiST 8(-~. n67 i) KV !.. bDT HPN !. C~'~I., 14.5! a R'F~,~R. CN L NPOP.C~'! 14.41 5 ~C¢,T,C:~L CFTC. ClUb 4237,55P GR 1.-JLi~,J-19qp 18:I'3 302.2fi0 GR. D?E -0.O7!. HTE!'~!. DTE ~.~ O. 971 P F: V I. D T E 2.413 DRHO. O. 0t5 LS. b[)T 72.063 SS1 .bDT t. 399.000 S!RH,LDT 6,468 RB.LDT 69,4~J] I. o9.625 ~PES, bDT 55~3,797 RCFT,CaL 768,500 RB,CNL 69'463 P!AZ'CN6 19,953 IDPi,i, !)TE 0 953 ILD, OT£ n, 35.3 I I R 3 12 · 750 t~ t,:. !) T g eO.ogP 2.451 DRHO. LDT O, Ol 0 L5, LDT 68 06 ] 1.39a~000 5,824 R~., LDT 69.842 P1AZ,LD'r !68.875 1.715 5830.7q3 RCFT, C'NL 4! ,531 Tg~J8. CNL 73~,no0 R3, CNI., 69.842 2(,). q53 !DP{q. OTE 21 .964 !Li~. OTE 20.000 0. :~40 IlgwU.DIE 305. 750 GR. DTE - {'). 0 71 ~. 455 D~O. LDT O. 01. 5 [,$. [~DT e4.875 88!. !.,~'r 13~.Ot.;0 SIRH.i, DT 5,8 ~: 3 P a, L!-)T 6 ~, 922 P l le~,O00 ~RES, Lt)T 1..5a'7 625l .9iQ RCF"r. Ci'~ b 6g.922 P 1. A Z. CI~I.~ 37.063 768.500 69,48~ 0.0O6 272.000 20a 250 1.55.156 208'15I -0,071 16.6 2 6 3030.813 !lio.ooo 1 ss. ~ 56 0,0~4 ~?'6 ~ 0'00O !8 984 41~531 738.00O 69.~42 0.000 ~53.250 19~.250 2.45:3 ~,47 05(:} 198~'~94 0.071 ~6.~25 3365,444 825,000 147 950 47.6~8 45.438 0.000 17,984 40.344 366 000 0.006 253,625 201.750 2,426 153.4:]7 205.805 -0.071 14,615 3~04.810 565.000 153.437 205,805 C!~P.DTE CILa,DTE I~QFoDTE IIX'M DTE RB.DTE P!AZ.DTE PEF.LDT LU,LDT 882,LDT LSRH.LDT AZ!~.LDT GR.LDT HTEN.LDT TMRA.CNL CNTC.CNL ~RES,CNL AZI~.CNL CIMP.DTE CILN,DTE I~QF.DTE IIX~.DTE TENS DTE PI. aZ,DTE PEF. LDT LU. LDT SS2.LOT LSR~.I, DT AZ!~.LDT GR.LDT ~TE~.LDT T~!RAoCNL CNTC.CNL ~kFS,CNL AZiM.CNL 11I.:0,000 !55,I56 208.151 3,06! 256.750 290,750 2,~06 80,971 37,063 768,500 1'731 O. 1 80,971 !9,297 1,9,953 0,000 ? 035 825 000 147 950 198 894 2 838 238 ]75 281 750 2.451 80.092 41,531 738,000 1.651 2,057 61~0,07i 80,092 18.328 1.8 891 o2ooo 6.129 565,000 153,437 205.805 3.201 240,500 284.750 2.447 80.067 40,344 366.000 1.534 b533.638 -0.07i 80,067 ~ ..lUmberc~er AlasKa Ccmoutinq Center !L~.DTE 58.375 I!PD.DT~ !7.5d7 SFLU. ~TE 55.219 ~iTE;~,~. DYE 166,625 AZI~t.DTE 79.61 3 QLS, LOT -0,004: L !.,. L ~) ! 1, 43,875 H~ZI,LD'Y 79,61 ~ NPH!,CNL ~7,695 NPUP,CF;b 16,941 CFTC,CN!. 3567 257 H~ZI,CF'L, 79,613 DEPT. !!300.000 CIDP.DTE I'~PF~. 13TE 5,3,84'~ CILD.DTE It..,~, DT'E 52,500 IF~E, I IE~D, DTE7 1.9. ~59 I!XD. DTE'. S~LI. '!'E 8.S13 SP. ~TEP~, DTF 166.000 AZI~~. DTE 79,56 ~ HAZI, O P H I. l,, D T !. 6,334 P 0 I. S. L D T 0,91 ~ 0 S 5, L D T L S H v. !,, t) T i. 3 O 5. n 00 S 5 H ?. L [) T !, !.! p H. L D T 2,404. C H ~ Z I. !., D T 79,561 !) ~.; v I. i5 D T TENS. bD~ 51 O. oOU ~-~TEq. LDT NPHT.CNb ! 7 .o2~ RT~R.CttL N P g ~::. C 9 I., i 6.935 R C ~,~ T. C t, b CFTC, CNt.. 3460, ~ 96 G~;~, C~L M T E ;u · C N L 16 ~:,. {; 0 () a T H~ZJ, Cr:.:l, 79. 561 DEPT. ! 1200. 000 C1 IL'.PTE 52,094 IF'P~;, OTC i IRD. r)TE 1 a. 047 I SFLU, DTE 49. 025 NT~'~ . r:,TE i ~; 5. 125 AZ I ~,~. DTE', 74.599 h DP~!I.. bDT I 3. ~("4 bL. LOT i '~7.750 L ITH. i.,0 I.,SHV. I, DT 136 '~-. 0O0 SSv~V. LDT [,URH. I,DT 2.443 C.~L1. }i AZI. !~DT 7 ~:. 599 D~V!. I_..i) T TE~IS. i..,DT 740. t,O() :~'['Eu. I,DT 9 266 ILD' . .0 T E 20.000 IDQF,DTC 0..478 IIR[~, OTE -0.072 79,613 D E'V :I, 0 T E 2,.407 DRHO,LDT 0. O 12 LS, 73,750 88!, LDT !397.000 5,824 t:8.985 PlAZ.bDT !66,6~5 ~ RES, I.,!,.)T 1.774 TNP/i, CNb 5723,006 4'0.2~1 TEMS, Ci~!L 674.500 a.b,C~b 68.985 PI. hZ,CML 2I. a28 ILD,OTE 20.000 !DQF.DTE (), .300 I I R ~,.~. D T E 22,25 0 G R, i)T E -0.O72 HTE?q.DTE 79,561 DKVI,DTE 2.3~O DRHfl, LDT 0.0 (; 3 L $. I,., D T 139'2,0u0 51RH.LDT 5. 992 Ri3, LDT 68.750 P~.AZ. LDT I .~4 TaP~.CNb 5~23.~5 PCFI'.CaL 30.231 TE~,~S, C~S 14,000 RS,Cab 68.7b0 Pl AZ.C~4L 19.84,4 ! Dl:'i4. DTE 20.891 ! I.,;). 20.0 U O ! i) (4 F. P T ~; 0.654 IIR;~.OTE 306. ~00 (:a. DTE -0.0'! 3 !.{TE4. DT'E] 7g.59~ DEq!,f)T~J 2.426 g~i4C~. LDr ~. 003 L3. L~r ~7.375 SS! .bDT 1397.00a 5 . 992 E!>, LOT ~7.098 PlAZ.LOT 54,719 5!..875 0.000 16,297 40,281 674,500 68.985 0.004 274,500 203.875 150, ~02.209 -0.072 16.875 3!35.584 580.000 1.50,729 202,209 4:8,125 45,78i O 000 !. 125 39,281 714.000 68,750 -0,007 280.500 198.375 2 416 151!653 203 492 -0.072 17 005 !0 000 203.492 5n 344 0.000 1~,266 40.8!3 629.0(!0 67.09~ -0.006 2~1.250 196.6~5 2.453 154.525 207.051 -0.073 .. ~P DTE C!LM..DTE i~OF.DTE tI:X~ DTE Pt. AZ,DTE PEF.bDT bU.LDT SS2~LOT bSRH,bDT AZIM.LDT GR,LDT MTEN,LDT T~RA C~TC[C~L aRES,CSb AZ!M,CNL C!MP,DTE CIba:,DTE IM~F.DTE iIXM.DTE TEN$,DTE RB.DTE P!.AZ,DTE PEF.LDT LIJ.LDT SS2.I.,DT LSRM.LDT AZIN,LDT GR,LDT HTE~.I.,OT T~,CNL CNTC,CNL ~PE$.CNL IZI".CaL CI~P.DTE CILM.DTE IMOF.D~E IIX~.DTE TEN$.DTE ~B,DTE P1AZ.DTE PEF.I, DT LU.LDT SS2,LDT I,SRH.Li)T AZI~.bDT GR.LI)T PAGE: 12 16. 47 17,~25 o,0oo 6'6?6 580~000 150,729 261,250 291,750 2,4:0i 79,6i 40.281 674,500 1.743 6043,768 -0,072 79,61.3 8.547 ~9,047 o.ooo 5,8!3 810,000 I51,653 203,492 3.264 262.750 288,750 2 387 79~561 39.281 714.000 1 748 -0.072 79.561 18,375 !9.188 0.000 6,137 740,000 154.525 207.851 3.223 247.250 283,500 2.430 78.599 40.813 629.000 0~'~ ~6F'£ 90~'9~ 000'09~ ~O~'L 000'0 $[~'6L £L0'0- [8£'668~ 89L'I 6~'£~ 8~'6L O0~°ES~ OLO'E 000:06~ t~6 ~ 000'0 ~L9'8~ E9£'6L 018'! O00'50L t£O T~ [9£ 6L 96~ ~ O~Z ~6~ 0~9 ~ ~L~'~O~ OtL°O~ 000~£§ 000"0 ,L6~'O~ ~8L°'6I 66~'8L gLO'O' 8E~'088§ £O'I'flq &dq'A3d qND'~!ZV £oq'HsS"i £Qq'~SS £(lq~fiq 3£fl'ZVTd ~&Q'NXII a~o'Nql~ qNO'~IZ¥ ~Oq'WtZV ~ZQ'~d 3&Q'~qlD ~iO'dN1J 000'99~ gOO'O- 69~ O~ OoO'O 696'69 [LO'O- 6~'e O~L'~fi~ oo~'L9~ 6~E'L9 0os'~8~ 000~0 EL~'§O~ OEL'O~ ~LO'O- ['LS'~O~ OEL'O~'[ O~'E 0~L'66~ O~£'LLE ~00'0- §~['99 O00'~Ot, 000:0 [S8'LO~ O00'09L 8~O'LI rhlumberqer Alaska Computir'~c.~ Cent, er LL.LDT i39,875 L!Td. L!)T LSgV,LDT t363,0o0 5S}~V.LOT h U ~ P. !~ P T 2.430 C !~ L ].. L k~ T ~hZl .LDT 78,9~ DEv 1. L, DT TENS, BDT 460. fl00 ,~TEY. L[)T NPOR. C~<~L 17,120 ~TE~. ......... H A Z I. C !)-~ b 7 ~. 968 D E V I. C ~':~ h DEPT. ~03oO, 000 !LU,DT~ i'950.O00 IFRE;,DTE IIRD.DTE ~2.14t iIXD,DTE SFLU. DTE 9696. o0o SP, OTE ~TEg, DTE t61,500 AZIM.DTE 37,555 D P H I. L b T 21.660 ~: Iq O ~.. b [) T' OhS, LDT 0.016 (~SS, bDT BL.LDT 4[~.688 LITH,LBT LSHV, LOT 1365, CO0 SS~4V, LDT [:,URN. LDT 3,0~2 CAL!,LDT HhgI. LOT 37,555 DEVI.LOT TENS.LDT 445.000 CFTC. C:~'.L i9~;;. 666 ~TEU. Cr<L 16! .500 DEPT. 10'70¢). 000 CIt) IUPU. pTE I 9S(?, 000 C I I~ID, BT~7 77. 484 I iX fi;. I)TF SFLU. UTE O. 215 SD. DTE ?~TE~: . D'.t~ ] fO. O0 ~ AZ!~ . DT~ 347. o85 DPHT. LDT ! 5.1.23 RFiO;3. LDT L[;. L[>T 55. ~:~44 LiTH.LDT LS~!V.[,PT ] 365.000 SSHV bl~kU..t.,OT 2.g4q. CAbI.I,D'"',,. HAZI. !,;i~T 347,0~5 DEV!.L[-.T hoO~.C:~L ~5.()62 CWTC.CNI.. !275. 331 HggT, C~X;h 347 ,og5 DEV.! 992 .[8: i 3 67.6S8 SSi.bDT !396,000 5,992 RB, LDT t:4.896 PI~Z.bDT 102.000 I.. 746 T 56k. 9.654 RCFT,CNL 37.719 949. 500 R'[~, C~NL 64,896 PJAZ.CNL 2~. 797 ,ILk~'?,{)TE 23. 891 IbO, OTZ 20,0 (; 0 ! P 0 F, D T E 79.000 i IR~. DT~; 302.750 GR,DT~ -0,074 H T E ~'.,~, DT~2 37. ~" .:> 55 [3 E V I, 0 T E 2' 293 DRHO, bDT -0 (',~4 La.bDT 139q.000 SI~.bDT 5. 992 R B, b~'.r 59.96! PIAZ,LDT I61.500 iZRE~9, bDT .34(.~. O 17 RCFT, 23.656 T E: C,~ S. k, ~ !, 916. 500 R~. CNL 5~.96I ~IAZ.CNL 30.047 30. 906 IL;). DTE 20.00 fi I 6 ~. t 25 T iT ]15.250 GR.DTE -0.074 HT~,~. DTE 347.6~5 DEr I. i')TE 2.400 O. 026 LS. LDT 12.7V 3 SS1. bDT 1399.0'.~O S1P~{.LDT 5. 656 R~. LDT 59.550 P~ gZ.LDT I°0.0L;O ~4¢E5. L. DT 2..!82 .25~6.g12 ~CFT. C:'~L 2a.9~:4 59.550 P!hZ.C~I, 26.531. !LO..aTE 20. r} 00 I !? Q t;. 7)T E 73.o(>3 !IP~'.DTE 1, 97,625 2.439 156,206 212.896 - 0.074 17.634 3069.572 460. 000 156.206 212,896 45,844 41.844 0. 000 -5,047 23,656 916.500 , 52 105,500 6!..219 4.5q8 15O, 432 i63.621 -0.074 1,8 942 1769~43q 445 000 t63,621 33 250 0.000 -10,797 28.984 88~.000 59.550 -0.532 120.313 85.313 3.988 128.163 70.014 -0.074 24.280 1!54.59] 225. 000 !28.163 70.O14 39. 406 37.656 0 o ~.64i CIMP.DTE CILM.DTE IMQF.DTE !IX~.DTE TE~$.DTE RB,DTE PIgZoDTE PEF.L[DT LU.bDT SS2.LDT LSR~,LDT AZIM,LDT GR.LDT HTEN,LDT TNRA,CNL C TC.C L AZI~.CNL CI~P.DTE CILg.DTE IgOF.DTE IIXM.DTE TENS.DTE Rb. DTE P!AZ.DTE PEF.LDT LO.LDT S$2.LDT LSRH.LDT AZI~,LDT (;R.LDT HTEN.LDT Tb~A.C~L C~TC.CDL ~RES,C~L AZI~.C~L CIYP.DTE CILM.DTE IEGF.DTE iIXg.DTE PAGE: 1,4 284,500 2'418 78'968 37~71~ 949'50 1,716 5861,854 -0,074 78,965 -7,348 -5,259 0.000 -135,375 445,000 !50,432 163,621 8!,438 1~,688 !9 ,938 3,043 37,555 23"56 I 860 3535:053 -0,074 37,555 -13,617 -11.320 0,000 '203,625 225 000 1282~63 70.014 36,281 128.875 1!3.625 2,932 347,685 28,984 B88,000 2.222 2789,755 -0,074 347,685 4.363 2,770 0.000 -142.125 ~LO 0- 0~[ ' ~ O00'LEL 8goL~ 000'06~ O00"OL;' 000'0 O00'O~L ~IO°OL 000' ~q gq q N D * D t N D £0 q' ~D iOq'~lZ¥ £Oq'HHgq &Oq'fiq £dq'~3d ~'~O'OL 000'06~ g6L°L[ ~LO'O ' O:OL ~L8'~8 O~'O- LO~'6~ O00'O§L : .'lq 1 :t Oq : ::ld,%,L 3ql-q [ /99/K6 : D 1 :I..-I. : **** Hi, fi Y ',:/:.! J, Hr't I S IS Tame Verificatlot~ ~.hlUs~berger A!ask..a Cor~Putlnq Center **** REEL TR ~ I I..,ER **** SERVICE ~A?iF7 : EDIT DATE : 9".~/Q6/ 1 ORIGIN : Fh~C REEL ~AME : 9~30! PREVI, OU8 RE~B CO~,!~BNT : t.~I~3CAJ,,GP 32-13 RD-STi,API ~50-733-20014-02
