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183-135
ge Project Well History File ~er Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~. (~ ~ ~_~ _,_~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: ~:E].~O~f various kinds NOTES: · ~ Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWE~.L DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI Scanning Preparation L~ x 30 BY: BEVERLY BREN VINCENT SHERYL~OWELL Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: BY: Stage 2 + ~ = TOTAL PAGEs ._L_~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~'~ YES BEVERLY BREN VINCENT SHERYL ~ LOWELL DATE: f'l~'~i~-S/ ~p IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: NO YES NO BY: BEVERLY BREN VINCE~'~HERY!=JMARIA LOWELL (SCANNING I$ COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si General Notes or Comments about this file: Quality Checked .,-.- 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: X Alter casing: Repair well: Other: Run Dual Completion 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL Development: X 103' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska 99519-6247 Stratigraphic: Trading Bay Unit Service: 4. Local~on of well at surface 8. Well number 1884' FSL, t378' FEL, Sec. 29, TgN, RI3W, SM Grayling G-'ISDPN At top of productive interval (4632' MD~op B-5 perf) 9. Permit number/approval number 2547' FNL, 1096' FWL, Sec. 28, T9N, R13W, SM ~ 83-0135/300-201 At effective depth (7300') 10. APl number 2554' FNL, 3224' FWL, Sec. 28, T9N, R13W, SM 50- 733-20160-90 At total depth 11. Field/Pool 2489' FNL, 3960' FWL, Sec. 28, T9N, R13W, SM McArthur River/D-2 and B-5/B-6 12. Present well condition summary Total depth: measured 8,860 feet Plugs (measured) Cmt retainers @ 7300' w/50 sx above retainer, true vertical 6,446 feet 8025', 8225', and 8445' with 50 sx below each retainer Effective depth: measured 7,300 feet Junk (measured) true vertical 5,091 feet Casing Length Size Cemented Measured depth True vertical depth Structural 377' 26" Driven 377' 377' Conductor 600' 17-3/4" 800 sx 600' 6OO' Surface Intermediate 6194' 13-3/8" 2250 sx 6194' 4564' Production Liner 2866' 9-5/8" 1500 sx 5989'-8855' 4242'-6440' Perforation depth: measured 4632'-4887', 4752'-4830', 6299'-6376'-- true vertical 3446'-3480', 3520'-3565', 4420'-4467' Tubing (size, grade, and measured depth) 2-7/8", 6.44f L-80 Tubing to4406' short string, 2-7/8" 6.4#, L-80 to 6279' long string Packers and SSSV (type and measured depth) ~ ~ ~,~.-., ~.~.-~ ~ ~., r~.~.,~~? ~.~..: ~ - ~, ~ ~ SS WF-1 SSSV @ 344', LS WF-1 SSSV at 341' 13-3/8" Model D pkrs @ 4491' and 4876', 9-5/8" Model D pkr @~6~'~. .......... .~ ~,~ ~ .... ~; ;~.~ ~.~ 13. Stimulation or cement squeeze summary Intervals treated (measured)0 R I Treatment description including volumes used and final pressure ,~:l~S~. ~ {Ji'~ ~ L:~"~'~ ~O~'~S, 14. Representative Daily Averaqe Production or Injection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 SS 9/18/2000 0 3,498 0 660 730 Subsequent to operation LS 9/18/2000 0 2,626 0 660 650 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Dan Williamson~~ [j[ )~ ~ Title: Drilling Manager Date:q '"'/¢~ Form 10-404 Rev 06/15/88 AFE #142363 SUBMIT IN DUPLICATE Unocal Alaska Drilling Workover Summary Report G-18DPN 8/15/00 to 9/13/00 20 2000 8/15/00 Set PX plug in X nipple at 5603' (below packer). Pressure test tubing to 1500 psi. 8/18/00 Pressure test annulus to 750 psi. 8/20/00 ND tree. NU and test BOPE as witnessed by Jeff Jones- AOGCC. 8/21/00 Pull tubing hanger with 50k lbs. RU APRS and make chemical cut in tubing at 5535', 15' above packer. Circ well through cut. Lay down 3-1/2" tubing. Test casing to 750 psi. ND BOP stack and 11" DCB tubing spool. 8/22/00 NU new 13-5/8" tubing head. Change rams to 5", NU and test BOPE. Test 13-5/8" flange to 750 psi. 8/23/OO RIH with 3-1/2" overshot BHA. Engage tubing stub at 5535' and jar seals out of packer, no losses to formation. POOH and recover seals and 2 jts of tailpipe. 8/24/00 RIH with 12.125" packer mill and PRT, mill packer at 5549'. POOH with packer, lost bottom gauge ring. 8/25/00 RIH with 12-1/4" mill cleanout assembly. Tag fill at 5829', wash and mill down to liner top at 5992'. Pump hi-vis sweep, POOH. Recovered pieces of slips and part of packer gage ring in junk baskets. RIH with 8-1/2" mill assy. 8/26/00 Cleanout from top of liner at 6000' to retainer at 6183'. Mill up retainer from 6183' to 6188' in 7.5 hrs (junk rolling on top of retainer?). Continue cleaning out from 6188' to 7057', good progress until last 30' which was 100% fine sand. Circ hole clean, circ sweep. 8~27/00 POOH with 8-1/2" mill cleanout assy. RIH with tandem 13-3/8" and 9-5/8" casing scrapers to 6994' and tag liner top at 5988'. Circ hole clean, pump 50 bbl hi-vis sweep, 50 bbl Safe Clean, 50 bbls FIW. Chage over well to 6% KCL. 8/28/00 POOH with tandem scrapers to log USIT. RU Schlumberger and ran USIT log from 6760' to surface. Good bond over proposed perf intervals, good casing wall thickness. Test BOPE. 8/29/00 RIH with lowest packer and Halliburton TCP guns on drill pipe. Correlate guns on depth with Schlumberger GR through drill pipe. Drop ball and set packer at 6146' with top shot at 6299', bottom shot at 6376'. Release "J" running tool with 2500 psi and 132K pull. POOH with drill pipe and running tool. RIH with 3.25" OD x 10' seal assembly on drill pipe. Stab in to packer. 8/30/00 PU out of seal bore and displace drill pipe to 4883' MD with nitrogen. Drop bar to fire guns but no indication of guns firing. RU slickline, RIH with 1-1/4" JDS overshot. Daily summary.doc 1 9/18/00 Set down at 6186', 6258', and stop at 6282'. POOH with bar, bar nose damaged due to falling thru tool joint upsets. Pressure up with nitrogen to acitvate contingency firing head. Ran out of nitrogen at 2500 psi, guns did not fire. RU slickline, RIH with bar on slickline and 250 psi on drill pipe. Sat down at 6263' (bar vent sub) spang down and set down at 6293' (firing head). Spang down and heard guns fire, drill pipe pressure still 250 psi. RIH to 6350' to confirm guns had fired and auto release had dropped guns and firing head. POOH with bar. RIH and set PX plug at X nipple at 6226'. RIH and set prong. RD slickline. 8/31/00 Fill drill pipe with KCL water, pressure test plug to 500 psi. Unstab from packer and circ, no gas. POOH with drill pipe and seal assy. RIH with middle 13-3/8" packer with 2-7/8" tubing and 3.25" seal assy. Could not stab into top of packer at 6146', rotate and circulate with no luck. POOH, bottom 2 jts of 2-7/8" tbg were bowed. MU seal assy to 3-1/2" OD x 20' long blast jt with welded 5 blade centralizer 6" OD on blast jt 1' from pin end and 2-7/8" x 5-1/2" bow spring centralizer on tbg above blast jt. 9/1/00 RIH with packer and tbg on drill pipe. Stab into packer at 6146' with no problem. RU Schlumberger, ran GR correlation Icg. Logged top of middle 13-3/8" packer at 4892' ELM. Drop ball and set packer with 2100 psi. Pressure test annulus to 1500 psi, held for 15 min. Rotate B-2 running tool to release, blow ball with 3600 psi. POOH and lay down running tool. MU dual TCP gun and blast joint assembly. 9/2/OO RIH with guns and blast joints below Y-block and upper 13-3/8" packer. Guns placed on depth at 4632'-4687' and 4752'-4830'. Stab into middle 13-3/8" packer seal bore, drop ball and set upper packer at 4491' dpm. Pressure test annulus to 500 psi. Rotate to release B-2 running tool. POOH with drill pipe and running tool. Ran dual hanger into new tubing head and test to 1000 psi. Pull hangers. MU 2-7/8" long and short strings and stand back in derrick. 9~3/00 MU dual flow tube assembly with 7-5/8" and 2-7/8" inner string with 3.25" OD seal assembly and 4.75" OD seal assembly. Run dual 2-7/8" tubing strings. 9/4/OO Could not stab tubing seals in to packer seal bore, tag up at 4503'. Attempt to vary weights between strings with no success. Pump down long string with returns up annulus indicating lower seals not stabbed into lower seal bore. POOH with dual completion. 9/5/OO Marks on lowest 3.25" mule shoe indicates lower seal assembly was not able to enter top of packer. Add indexing sub to 3.25" seal assembly and 2' long 2-7/8" pup with four 3-3/4" welded blade centralizer on top of 3.25" seal assembly. RIH on drill pipe and tag up at 4517', could not pressure test. Attempt to enter seal bore with up to 12k slack-off, no successs. POOH and found no marks on muleshoes. RIH with dummy 3.25" tubing seals only on drill pipe. Stab into lower seal bore with no problem (3-5k to push seals into seal bore) to 4531' and pressure test to 500 psi. POOH with 3.25" seal assembly. 9/6/OO RIH with dual flow tube assembly on drill pipe. Tag at 4517' and set down with more weight than before (20-35K) to get seals to bottom of seal bore at 4531'. Pressure test long string to 500 psi. PU with 55k overpull. POOH with dual flow tube assembly. Ran dual flow tube assembly on drill pipe with spacer tube in 47 seal Daily summary.doc 2 9/18/00 assembly to reduce length of seals and 2' less seals in the 32 seal ~'¢9-¢-ag at 4518' and push seals in with 15-40K. Good 500 psi test down drill pipe. PU with only 25k overpull. POOH and install 7-5/8" x 12" OD welded six-blade centralizer between the two joints of 7-5/8" casing. 9/7/O0 MU dual tubing strings on top of dual flow tube with four 3-1/2" OD blast joints and sixteen 4-1/2" OD blast joints for added weight. RIH and stab seals with 20k. Test long string to 500 psi. PU and add space out pups and dual hangers. Circ 100 bbls of corrosion inhibitor above upper packer. Land hangers with almost no weight left when hangers landed. 9~8/00 Long string did not pressure test, had returns up annulus. Did have good 500 psi test on annulus indicating 4.75" seals are holding. Pull hangers and add 2' of space out pups. Land hangers with 25k of good smooth seal travel (better than previous attempt). Pressure test long string to 500 psi and annulus to 500 psi. RU slickline on long string. Pull SSSV isolation sleeve and run 2.300" x 4' long drift through long string, set down at 1770'. RIH with 2.23" gauge ring, only small bobble at 1770', set down at 5004', work through, set down at 6132', work down to 6145'. POOH with 2.23" GR. RIH with 2.300" swedge to 4600' with no problems. RIH with 2.300" x 4' drift again, work through spot at 1770'-1791', cont RIH to 4620'. POOH and RD slickline from long string. ND BOPE. 9/9/OO NU and test dual tree. RU slickline on short string. Pull SSSV isolation sleeve at 349'. Set SSSV valve at 349'. RU slickline on long string. RIH and open sliding sleeve in long string at 4589'. Pressure up annulus to 1000 psi. RU nitrogen unit and displace down short string, taking 36.5 bbls of KCl returns up long string via open sliding sleeve. SI pressure on short string = 1400 psi. RIH with slickline on long string and shift sleeve closed at 4589'. Fluid level at surface in long string. Bled short string from 1400 psi to 650 psi. Pressure up long string to 2000 psi and fire TCP guns hanging on Y-block. Short string pressure increased 120 psi. Bled off annulus from 1000 psi to 0 psi. RU slickline on long string, change out 2 dummy valves to live gas lift valves. 9/10/00 Lay down 5" drill pipe out of derrick. Release rig at 9/10/00 12:00 noon. 9/11/00 RIH with slickline on long string to retrieve prong in PX plug. Set down at 6186' and POOH with no recovery. RIH with 2" LIB and tag prong top at 6221'. RIH with retrieving tool and engage prong at 6221', pulled off with no recovery except for pieces of blue rubber. RI H with retrieving tool again and had trouble pulling off. 9/12/0O Pull retrieving tool with no recovery. RIH with 2" bailer twice and recover pieces of blue rubber and black rubber, some metal shavings. RIH with 2.25" LIB to 6226' with no problems. Impression of top of plug body. RIH with 2.300" x 4' long drift with no problem to 6226'. RIH with 2" bailer and had no recovery. RIH with retrieving tool and engage plug body at 6226', shear pins and POH. RIH with retrieving tool and engage plug body at 6226', POOH without tool string, wire parted at rope socket. RIH with JDC latch and tag tool string 26' deeper than expected, POOH and recovery tool string. 9/13/OO RIH and engage plug at 6252' (on top of 2.25" ID bar vent sub one joint below X nipple), shear off with no recovery. Gas lift water out of tubing. RIH and engage Daily summary.doc 3 9/18/00 plug at 6226'. POOH and recover plug body, plug packed with rubber from test plug o-ring. RD slickline. Turn well over to production. Daily summary.doc 4 9/18/00 r. Trading Bay Unit Well # G-18WO Actual Completion, 9/8/00 RKB to TBG Head = 42.86 3d 4491 'MD 3e 4565'MD 3405'TVD 4632'MD/ 3446'TVD 4830'MD/ 3565'TVD Prop ~oneck Perf.' __'rop ~ ~oneck B-6 P e rf.' 5989' 10 6299'M D/ New Perfs 4420'TVD 6299'-6376' Dropped 77' guns, '"'..~. 89.42' I total ~ ~ Top of fill_l ~ \ 7300' ~~. D-2 D-9 D-10 ~ D-14 8025' 8225' ~ ~ D-16 8445' ETD = 7300' (RET) TD = 8,860' MAX ANGLE = 55° @5600' MD G-18 2000 dual schematic 9-8-00.doc SIZE 26" 17-3/4" 13-3/8" 9-5/8" Liner Tubing: 2-7/8" LS 2-7/8" SS Zone B-5 B-6 D-2 WT GRADE CASING AND TUBING DETAIL MD CONN ID TOP MD TVD BTM. BTM. CMT 1/2" Wall Surf. .341 wall Weld Surf. 61# J-55 Butt 12.515 Surf. 47# N-80 5989' 377' 377' Driven 600' 600' 800sx 6194' 4564' 2250 sx 8855' 8697' 1500sx 6.4 L-80 Butt. 2.441 Surf. 6147' 4.28" OD Blast Jts 3.5" butt 3.000 4183' 4342' 8rd 2.441 6175' 6279' 6.4 L-80 Butt. 2.441 Surf. 4406' 4.25" OD Blast Jts 3-1/2" butt 3.000 4182' 4341' NO. Depth 42.86' 1 344' 2.310 la 3009' 2.347 lb 4348' 2.347 2 4381' 2.313 5 341' 2.310 5a 3120' 2.347 5b 4369' 2.347 3a 4406' 3b 4407' 3c 4490' 3d 4491' 3.875 3e 4512' 2.385 3 4491' 4.75 4 4505' 5.812 4a 4512' 3.25 6 4565' 2.313 7 4608'-4825' 8 4876' 3.25 4880' 3.25 4890' 3.75 9 4939' 2.310 10 6147' 3.25 6151' 3.25 6161' 4.00 11 6206' 2.313 12 6239' ~250 13 6279' 2.440 PROPOSED JESVELRY DETAIL ID Item Seaboard Dual Tbg. Hanger Short String 2-7/8" SSSV 2-7/8" MMG GLM withl-1/2" dummy 2-7/8" MMG GLM with 1-1/2" dummy 2-7/8" X nipple in Short String Long String 2-7/8" SSSV 2-7/8" MMG GLM withl-l/2" live GLV 2-7/8" MMG GLM with 1-1/2" live GLV Dual flow tube, LS screwed into btn~ LS & SS screwed into top 7-5/8" casing, two jts with 2-7/8" LS inner stying 7-5/8" x 4.75" OD seal assy xover, locator 4.75" OD x 3.875" ID seal assy 3.25" seal assy Baker D 13-3/8" perm pkr w/4.75" ID seal bore Ported millout ext, six 1" dia holes Lower seal bore, 3.25" ID 2-7~8" Baker CMU sliding sleeve Y-block with Blast joints in long string 2-7/8" x 13-3/8" Middle Model D straddle packer with 10' SBE and MOE 2-7/8" Baker CMU sliding sleeve 2-7/8" x 9-5/8" lower straddle Model D packer with 10' SBE and MOE 2-7/8' X nipple, 8rd Halliburton bar vent sub Long string tubing tail, 8rd, TCP guns released Existin, 5,690' 5,755' 5,690' 5,830' 6,274' 6,280' 6,358' 7414' 7,430' 7,611' 7660 8134 8316 8350 8495 PERFORATION DATA Perf Date Present Condition 12/4/68 Isolated 9/1/00 10/30/83 Isolated 9/1/00 10/30/83 Isolated 9/1/00 10/30/83 Isolated 9/1/00 10/8/83 Block Squeeze DST Squeezed 10/25/83 10/7/83 Block Squeeze 10/7/83 Block Squeeze 10/23/83 DST Squeezed 10/6/83 Block Squeezed 10/22/83 DST Squeezed 10/18/83 DST Squeezed 10/16/83 Squeezed 10/16/83 DST Squeezed 10/15/83 DST Squeezed 2000 Workover Perforations Top 4632 4752 6299 Accum I Btm I Amt SPF 4687 55 11 4830 78 11 6376 77 6 Peff Date 9/9/00 9/9/00 Present Condition Short string Short string Long string 8/30/00 REVISED: ~ ;)/18/00 DRAWN BY: TAB Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe Dan Williamson Drilling Manager July 28, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Re: Commissioner Dan Seamount Sundry Application (Form 10-403) McArthur River Field Grayling Platform, Well G-18DPN Commissioner Seamount: Enclosed is a Sundry Application (Form 10-403) for Grayling G-18DPN. This well is currently a Tyonek D-1 gas producer that has recently been shut-in due to water and solids production. Unocal proposes to: 1 Remove the existing single completion in the D-1 interval. 2 Clean out fill and a retainer above the proposed D-2 interval. (The D-2 zone was tested during the deepening of the well in 1983 and a retainer was set above the D-2 test perforations to allow for the current completion in the D-1 interval.) 3 Run a single 9-5/8" packer with TCP guns below the packer for the proposed D-2 interval. 4 Run a single 13-3/8" scab packer with tail pipe stabbed into the 9-5/8" packer to isolate the current D-2 perforations. 5 Run another single 13-3/8" packer with a Y-block below the packer. The long string will stab into the middle 13-3/8" packer and the Y-block will have TCP guns for perforating the B-5 and B-6 intervals. 6 Run dual 2-7/8" tubing strings with a dual flow tube seal assembly that stabs into the upper single 13-3/8" packer. The dual flow tube will allow long string production and wireline access to the lowest D-2 interval. The B-5 and B-6 intervals will be able to flow through ports in the bottom of the dual flow tube assembly and up into the short string made up to the top of the dual flow tube. 7 ND BOPE and and NU dual tree and dual flow lines. 8 Pressure up the short string tubing to actuate the annulus fired TCP guns for the B-5 and B-6 intervals. 9 Drop a bar down the long string to perforate the D-2 interval. The expected start date for this well work is August 21, 2000 so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263- 7677 or Tim Billingsley at 263-7659. - Drilling Manager AOGCC cover letter G-18.doc Tim Billingsley STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 103' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface 8. Well number 1884' FSL & 1378' FEL of Sec. 29, T9N, R13W, SEWARD Grayling G-18DPN At top of productive intervaI-G0RI INAL 9. Permit number 2419' FNL & 1959' FWL of Sec. 28, T9N, R13W, SEWARD 83-0135 At effective depth 10. APl number 2416' FNL & 2364' FWL of Sec. 28, T9N, R13W, SEWARD 50- 733-20160-90 At total depth 11. Field/Pool 2489' FNL & 3960' FWL of Sec.28, T9N, R13W, SEWARD McArthur River/D-2 and B-5/B-6 12. Present well condition summary Total depth: measured 8860' feet Plugs (measured) Cmt retainers at (6185' w/80 sx below ret), true vertical 6446' feet (7300' w/50 sx above retainer), (8025',8225',8445' w/ 50 sx belwo retaniers) Effective depth: measured 6185' feet Junk (measured) true vertical 4365' feet Casing Length Size Cemented Measured depth True vertical depth Structural 377' 26" Ddven 377' 377' Conductor 561' 17-3/4' 800 sx 600' 600' Surface 6194' 13-3/8' 2250 sx 6194' 4564' Intermediate Production Liner 2866' 9-5/8' 1500 sx 5989'-8855' 4242'-6440' .- Perforation depth: measured 5690'-5735', 5755'-5800', 5830'-5870' ~,~ true vertical 4077'-4103', 4114'-4140', 4156'-4179' Tubing (size, grade, and measured depth) 3-1/2', 9.3#, N-80 @ 5636' Packers and SSSV (type and measured depth) Baker KB pkr @ 5564' Otis Ball Valve @ 334' 13. Attachments Description summary of proposal: x Detailed operations program: BOP sketch: x 14. Estimated date for commencing operation 15. Status of well classification as: 8/21/00 16. If proposal well verbally approved: Oil: Gas: X Suspended: Name of approver Date approved Service: 17. I hereby/c~rtify that the lo, re, going is true and correct to the best of my knowledge. Signed~/~,~~v{~/~,, Dan Williamson[l~}..,~ ~/)~ Title: Ddlling Manager Date: 7'-~'~0 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity.__ BOP Test ~ Location clearance Mechanical Integrity Test Subsequent form required 10- ORIGINALD SIGNED b., Approved by order of the Commissioner Taylor SealTI01~f Approved Form 10-403 Rev 06/15/88 Re~rrled 141nO SUBMIT IN TRIPLICATE UNOCALe Grayling G-18DPN 07/27/00 Proposed Workover Plan G- 18proc3.doc General Proposed Workover Procedure, G-18DPN 1 Move in rig, ND tree, NU BOPE and test with 24 hour notice given to AOGCC. 2 Load tubing with FIW. 3 Pull and lay down 3-1/2" tubing from seal bore in packer at 5563'. 4 RIH with packer mill and retrieving tool. Mill up packer at 5563' and retrieve same. 5 RUN CBL log across proposed upper intervals to determine if sufficient cement isolation is present. (This procedure assumes a cement squeeze will not be needed, calculated TOC was 4000' on 13-3/8" cement job in 1968, no useable CBL was run) 6 Clean out fill in 13-3/8" casing from 5794' to 9-5/8" bridge plug at 6185'. (May need to mud up) 7 Mill up 9-5/8" bridge plug at 6185'. 8 Continue fill cleanout to appx 6500' (base of proposed D-2 perfs at 6376') 9 Run 9-5/8" and 13-3/8" tandem casing scrapers to PBTD. Circ hole to clean fluid. 10 MU and RIH with TCP guns and packer. RU E-line and depth correlate. Set packer at appx 6100' with guns on depth in the D-2 interval at 6299'-6376' with bar drop firing head and ported sub in place above guns. 11 Run straddle packer assembly across D-1 perfs with bottom packer in 9-5/8' liner at 6100' and top packer in 13-3/8" casing at 5700' and 2-7/8" tubing between packers. 12 RIH with 2-7/8" long string with Y-block and TCP guns side-by-side with long string, guns spaced out to perf B-5 and B-6 at 4630'-4685' and 4750'-4828'. 13 Attach long sting to bottom of 13-3/8" packer and seal bore. 14 Continue RIH with long string, guns and packer on drill pipe. Drop ball and set single 13- 3/8" packer at 4200'. 15 RIH with dual 2-7/8" strings of tubing attached at bottom to dual flow tube with single seal assembly. Stab seal assembly into 13-3/8" packer at 4200'. (Guns will be in-line with long string beneath packer and pointed away from long string, short string will stop at the top of the dual flow tube with flow capability through flow tube and beneath packer via ports below packer.) ~ .-~'~- ,~ ~-~.v ~.=:~ ~...~ ~ ~ ~ ~' ~' ~ AUG 0 i ~,'~ ~-- ~-" ?/2?/00 _Ai~a 0i'; ~ Gas Cons. C0mmi~i0n Anr~hnmnm Grayling G-18DPN ~J~iO~~l~} 07/27/00 Proposed Workover Plan 16 PU seal assembly and circ both long and short string to diesel for underbalance purposes. Space out and land hanger, pressure test 13-3/8" annulus. 17 ND BOPE, NU tree. NU dual flowlines 18 Pressure up short string to fire B-5 and B-6 guns with annulus pressure firing heads on top and bottom of guns. 19 Drop bar down long string to fire D-2 guns. If long string guns do not fire, pressure up tubing for alternate firing head to fire long string guns. 20 Release rig. 21 Unload both tubing strings and flow dual completion. G- 18proc3.doc 7/27/00 RKB to TBG Head = 38.79' SIZE Trading Bay Unit Well # G-18WO Proposed Completion CASING AND TUBLNG DETAIL MD MD TYD WT GRADE CON'.:~ ID TOP BTM. BTM. 26" 1/2" Wall Surf. 377' 377' 17-3/4" .341 wall Weld Surf. 600' 600' 13-3/8" 61# J-55 Butt 12.515 Surf. 6194' 4564' 9-5/8" Liner 47# N-80 5989'. 8855' 8697' Tubing: 2-7/8" LS 2-7/8" SS 6.4 L-80 Butt. Surf. 6200' 6.4 L-80 Butt. Surf. 4270' CMT Driven 800 sx 2250 sx 1500 sx 6XA 5989' 9XA D-1 Perfs-- 5( ~rop 'oneck B-5 Peril __'y°neck Peril 10 7300' 8025' 8225' 8445' D-9 " D-10 D-14 _ D-16 ,...-' -.... ETD = 7300' (RET) TO = 8,860' MAX ANGLE = 55° @5600' MD G-1 $ 2000 dual schematic TCP guns.doc PROPOSED JEWELRY DETAIL NO. Depth ID Item 38.79" DCB-FBB 10" Dual Tbg. Hanger 1 300' Short String 2-7/8" SSSV 2 4200' Baker 13-3/8" perm packer with Dual flow tubes stung into seal bore 3 4230' 2-7/8" X nipple 4 4270' Short string ported enlxy beneath flow tut~ 5 300' Long String 2-7/8" SSSV 6 4400' 2-7/8" XA sleeve 7 4600'-4850' Blast joints in long siring 8 5700' Upper sWaddle packer 9 5740' 2-7/8"XA sleeve 10 6100' 2-7/8" x 9-5/8" lower sWaddle packer 11 6140' 2-7/8' X nipple 12 6170' Long string tubing tail Existing PERFORATION DATA ~¢urn Zone Top Btm Amt SPF Perf Date Present Condition D-1 5,690' 5,734' 4 12/4/68 Production D-1 5,755' 5,800' 4 10/30/83 Production D-1 5,690' 5,735' 8 10/30/83 Production D-1 5,830' 5,870' 8 10/30/83 Production 6,274' 6,276' 10/8/83 Block Squeeze D-2 6,280' 6,300' 10/25/83 DST Squeezed 6,358' 6,360' 10/7/83 Block Squeeze 7414' 7416' 10/7/83 Block Squeeze D-9 7,430' 7,450' 10/23/83 DST Squeezed 7,611' 7,613' 10/6/83 Block Squeezed D-10 7660 7,672' 10/22/83 DST Squeezed D-14 8134 8,150' 10/18/83 DST Squeezed D-16 8316 8,328' 10/16/83 Squeezed D-16 8350 8,360' 10/16/83 IDST Squeezed D-17 8495 8,511' 10/15/83 IDST Squeezed Proposed Perforations Accum Zone Top Btm Amt SPF Perf Date Present Condition B-5 4630 4685 55 Proposed B-6 4750 4828 78 Proposed D-2 6299 6376 77 Proposed REVISED: 7-27-00 DRAWN BY: TAB T.B.U.S G-18 Deepening McAdhur Ri¥ r Field ¥, VI. VII, ¥III, VII VIII IX D-I $A~ .. SAND D-lO SAND D -14 8AND O-17 ~sd (S~z*a ~/~ sxs) D-16 sd (Sqz'd w/~0 sxs) 0-I~ sd (Soz'd w/,,~1' sxs) 0,113 sd (SQZ'd w/120 sxs) ~z'd Jar isolaLton w/ 232 D-9 sd (Sqz'd w/17; sxs) ' Sqz'd for ~solatim w/ 2~Jl sxs cm~ - S~iz'd for Isolation v/ 241 sxs c~t e-2 sd (Sqz'd ~! 'S0 sxs) l~.l'd for ls~lat, ion v/ ~1 sxs sd/tlpen for ~s . .s. c~ ~Jns, ii HFF, I:ZP phase 0-1 sd/01~n for gas production ~ csg guns, 8 IFF, 120" phase . l$-1 sd/0psn for ~ production P' csg ~ms, 8 ~F, .120° phase D-la'SAND -T- 0~/0&/69 ~-/~$'-~q800' D-1 scVOpen for gas pcoduction , H~per-je~s, I HPF, 0o phase . : -. . 2" scallop gun41FF', 0· phase D-IT 8AND ~ ~690~-.~7~a' D-i sd/Oi~n for ~s production ¢.~- ¢ :~, ¢.D i · I - . ....... i , ~ ~! . I I I Il! ! I I I ! ' , , i m I "'] FLOWUNE: i 4~ CHOKE: LR~EWIT~ ONE: RI~IC~ · ' '-. ;~ ..... Q} , , co~~ m cuo~ ..... ...... I PIP; ~S-- -/ ,, ::,,, , :/ 13-5/8" 5~ I . , RIS~ AOAPT~ ELOPE 5M STACK GI~AYLING PLATFORM · UNION OIL. COMPANY Or CAL,F'.ORNLA (elSa U.NOCAL) -'- ',BRAt//N: DAC AI=.F~: 6S~ S~.ALE: NONE · . J ,' · $ · I TO GAS 8UST~ · · · · .I AUI'OMAllC: CHOK~ UNION · V~V~ UPSTREAU ~ 'mOK£S 'AR'~ la,ooa Psi ml~ IYPE · · i · i i iiii i CHO. K E ~,~ANIFOLD GRAYLING PLATFORM OIL COMPANY OF CALIFORNIA (dba UNOCAL) AUrO)~kll¢ CHOKZ o DRAWN: DAc APP'a: GS8 ~~ NONE MIXING PIT 40 BBLS · UIXlNO PIT IS k ONE: LEVEL BELOW THE ACTIVE: S'i'STEU ,I TRIP TANK ~5 BBLS 185 BBLS 1B5 BBlcS VOLUME PiT SUCTION PIT 125 8BLS- · 67 BBLS . 24-0 BBLS RESERVE PiT 4.75 BBLS SI-IAI<ER HOTEj THE 5'YS']'EM WILL BE EQUIPPED WffH A DRILL. II'Ia PIT LEVEL INDICATOR WITH AUDIO .,k VISUAL. WARHIHO DEVICES, ' EQUIPMENT LIST _1 i , , , ,_1 1) RESERVE PIT 2) DE:GASSER 4) Pff LEVEL INDICATOR (V~SUXk ~ 5) FLUID FLOW SENSOR 6) TRIP TAI, II( · 7) Pff AOffATOR~ ' R) DESILTER ~) CENTRIFUGE 10) MIXING PIT ' UN'OCAL GRAYLING MUD PIT SCHEMATIC DRAWN EIY~ DAC APP'D~ SCALE: NONE DATE~ I . STATE OF ALASKA .~_,. ' ALASKA OI~L"~AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: X Time extension: Stimulate: Change approved program: Pull tubing: X Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: X KB: 103' feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247, Anchorage, AK 99519 Stratigraphic: Service: Trading Bay Unit 4. Location of well at surface Grayling Platform Leg # 2, Conductor # 42 8. Well number 1,884' FSL, 1,378' FEL, Sec. 29, T9N, R13W, SM G-18DPN At top of productive interval 9. Permit number 2,419' FNL, 1,959' FWL, Sec. 28, T9N, R13W, SM 83-0135 At effective depth 10. APl number 2,416' FNL, 2,364' FWL, Sec. 28, T9N, R13W, SM 50- 733-20160-90 At total depth 11. Field/Pool 2,489' FNL, 3,960' FWL, Sec. 28, T9N, R13W, SM McArthur River/"D-1" Sand. 12. Present well condition summary Total depth: measured 8,860' feet Plugs (measured) Cmt Ret's @ (6185' W/80 sx below ret), (7300' W/50 sx true vertical 6,446' feet above ret), ( 8025', 8225', 8445' W/50 sx below ret's) Effective depth: measured 6,189' feet Junk (measured) true vertical 4,365' feet Casing Length Size Cemented Measured depth True vertical depth Structural 337' 26" Driven 377' 377' Conductor 561' 17-3/4" 800 sx 600' 600' Surface 6,156' 13-3/8" 2,250 sx 6,194' 4,564' Intermediate Production Perforation depth: measured 569O - 5735', 5755 - 5800', 5830 - 5870'. Kit. L I: IVl: U true vertical 4077 - 4103', 4114 - 4140', 4156 - 4179'. JUL 2,4 1998 Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 @ 5,636' Alaslm 0il& Gas C0r,:~ ........... , .... Packers and SSSV (type and measured depth) Baker "KB" pkr. @ 5,564' & Otis Ball Valve @ 334' Anchorage 13. Attachements Description summary of proposal: X Detailed operations program: X BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 8/15/1998 16. If proposal well verbally approved: Oil: Gas: X Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ,,~ ~t ~ Dale Haines Title: Drilling Manager Date: 7/22/1998 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval Plug integrity BOP Test /~ Location clearanceI "-' '"~-- Mechanical Integrity Test Subsequent form required 10- ~f'(~)*l ~,~,,O~"~ ORIGINAL ORIGINAL SIGNED-BY Robert N. Chdstenson Approved by order of the Commissioner Commissioner Date -- Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE UNOCALe Grayling G-18DPN 07/16/98 Proposed Workover Plan Grayling G-18DPN Summary of Workover Procedure G-18DPN will be recompleted from the Tyonek D-1 gas sand to the Tyonek A-l, A-3 and A-4 sands. The existing 3-1/2" tubing will be pulled out of a permanent packer at 5563'. An EZSV retainer will be set at 5500' above the current D-1 perforated interval. New perforations will be shot from 3285' to 3650' (gross interval) in the A-1 through A-4 intervals. A new 4-1/2" tubing completion will be run. Reservoir Pressure and Workover Fluid Density The existing D-1 completion is depleted and existing reservoir pressure is 1000 psi at 5690' MD/4066' TVD or 4.7 ppg EMW. The workover fluid pdor to setting the bddge plug above the D-1 interval will be filtered inlet water at 8.4 ppg with lost circulation pills as required. Expected reservoir pressure in the proposed A-1 through A-4 intervals is as follows: A-1 3285'-3320' MD 2600'-2626' TVD A-3 3554'-3605' MD 2766'-2797' TVD A-4 3632'-3650' MD 2811'-2825' TVD 1174psi 8.7 ppgEMW 1250 psi 8.7 ppg EMW 1267 psi 8.7 ppg EMW Prior perforating the above intervals, the wellbore will be changed over to 6% KCI (formation damage control) plus NaCL for a completion fluid brine weight of 9.0 ppg. ECEiv dUL 2. 4 :,',':' ;- Alaska 0il & G- 18proc.doc 7/16/98 UNOCAL Grayling G-18DPN 07/16/98 Proposed Workover Plan Description Summary of Proposed G-18DPN Workover Operations 1 Move in dg, ND tree, NU BOPE and test with 24 hour notice given to AOGCC. 2 Load tubing with FIW. 3 Pull and lay down 3-1/2" tubing from seal bore in packer at 5563'. 4 RIH with EZSV bddge plug on ddll pipe and set at 5500'. Pressure test 13-3/8" casing and EZSV bridge plug to 1400 psi. 5 Change over well to 6% KCI. 6 RU Schlumberger E-line unit and perf A-l, A-2 and A-4 intervals with 4-1/2" casing guns: A-1 3285'-3320' A-3 3554'-3605' A-4 3632'-3650' 7 Run 4-1/2" x 13-3/8" permanent packer with seal bore on wireline. Set packer at 3150'. 8 Run 4-1/2" buttress modified completion tubing. 9 Circulate corrosion inhibited packer fluid before stinging tubing seals into packer seal bore. 10 Land hanger, pressure test annulus to 1400 psi. 11 ND BOPE and NU tree and flowlines. 12 Demobilize rig. 13 Swab well to initiate gas production. RECEIVED JUL 24. 1998 Alaska Oil & ~as Cons. Commiss{on Anchorage G- 18proc.doc 7/16/98 RKB to TBG Head = 38.79' s~2~ Trading Bay Unit Well # G-18WO Proposed Completion WT GRADE CASING AND TUBING DETAIL MD CONN ID TOP MD BTM. BTM. 26" 1~" Wall Surf. 377' 377' 17-3/4" .341 wall Weld Surf. 64X¥ 600' 13-3/8" 61# J-55 Butt t2.515 Surf. 6194' 4564' 9-5/8" Liner 47# N-80 5989'. 8855' 8697' Tubing: '4-1/2" 12.6 L-80 Butt. Mod Surf. 321X3' CMT Drivert 800 sx 2250 sx 1500 sx Proposed EZSV @ 5500' KB Packer @ 5563' 6185' 7300' 8025' 8225' 8445' Proposed 3285'-3320' Proposed 3554'-3605' 3632'-3650' D-1 Sand --"' ~D-2 . Tyonec - A 1 Ped . Tyonec . A3 &Az ' D-9 D-10 -- D-14 _ D-16 ~ ETD: 6,105' (RET) TO = 0,060' MAX ANGLE = 52° @ 4482' MD NO. Depth 38.79" 1 2 3 3150' 4 5 6 7 3200' PROPOSED JEWELRY DETAIL ID Item 4.~) 4.00 3.813 DCB-FBB 10" Tbg. Hanger 4-1~" butt modified tubing Baker Locater Seal Ass3,. w/' of seals. Baker Model "FB-I" Pkr Seal Bore Ext, Cross Over to 4- I/2." tubing Otis "'X" Profile Nipple WLEG FISH: None reported STI~CtJLATIONS: None reported SLICKLINE WORK: Tag fill at 5863'WLM 6/95 K LLIVLL) JUL 24 19911 Alaska 0il & Gas Cons. Commission Anchorage Existing PERFORATION DATA ~'~um Zone Top Btm Amt SPF Perf Date Present Condition D-1 5,690' 5,734' .4 ..... 12/4/68_ Production D- 1 5,755' 5,800' 4 10/30/83 Production D-1 5,690' 5,735' .8 ..... 10/30/83 Produc~tion .... D-1 5,830' 5,870' 8 .~ . 10/30/83 Produq. tion 6,274' 6,276' 10/8/83 !Block Squeeze D-2 6,280' 6,300' ----::10/25/83 DST ~lueezed .._ 6,358' 6,360' 10/7/8~.3_. Block ..Squeeze 7414' 7416' 10/7/83 Block.~queeze D-9 7,430' 7,450' 10/23/83 DST Squeezed 7,611' 7,613' 10/6/83 Block Squeezed D- 10 7660 7,672' 10F22/83 DST Squeezed D-14 8134 8,150' 10/18/83 DST Squeezed D-16 8316 8,328' 10/16/83 Squeezed D- 16 8350 8,360' . 10/16/83 I DST.~queezed D-17 8495 8,511' 10/15/83IiDST Squeezed G- 18propsch.doc REVISED: 12/10/97 'F~ID A'i~IF~T IDV. ' h'wS'~" FLOOR 23'-9":b · 10" MUD FLOW UNE TO SHAKERS 5'-8':1: DRIP PAN '"'""--AIR BOOT ~6'~ RISER 80TTOM OF SEAL HOUSING1 4,'-10~"+ 18'-2":b HYORIL 13-5/8' 6}< ( ANNULUR PR EVENI'F_.R [ I i'-4~.' 1 2'-7t' ti.' ORILL BECK SHAFFER DOUBLE GATE BOP SHAFFER SINGLE GAlE BOP 2'-10' GRAYLING F~LATFORM COOK INLET, ALASKA GRAYLING PLATFORM SHAFFER BLOW OUT PREVENTER STACK ELEVATION UNOCALI~ 6.]1-033 MIXING PIT 40 BBLS MIXING PIT IS A ONE LEVEL BELOW THE ACTIVE SYSTEM TRIP 4-5 TANK BBLS 185 BBLS VOLUME PIT 185 BBLS SUCTION PIT 125 ,BBLS 67 BBLS 24-0 BBLS " ' SHAKER SHAKER ,, --CENTRIFUOE RESERVE PiT ,$75 BBLS NOTE: THE 5'Y~EM WILL BE EQUIPPED WITH A DRILLING PIT LEVEL INDICATOR WITH AUDIO ~: VISUAL WARNING DEVICES, EQUIPMENT LIST 1) RESERVE PIT 2) DEGASSER 3) (2) SHAKERS 4) PIT LEVEL INDICATOR (VmUAL A AU~IO) 5) FLUID FLOW SENSOR TRIP TANK 7) PIT AGITATORS DESlLTER CENTRIFUGE 10) MIXING PIT UNOCAL GRAYLING MUD PlY SCHEMATIC DRAWN BY: DAC APP'D: GSEI SCALE: NONE DATE: 1 TO GAS BUSTER /\ , TO OERRICK VENT / l'O WELL CLEAN TANK -- ~j~ ~_ 4-1/16" ~_ ~/~,, ~-~/~" ~_ ,---'r 3- ~/8" ~-~/~" ¢ ~/ CHOKE AUTOMATIC CHOKE RECEIVED JUL 2 ~. 1998' FROM CHOKE LINE VALVES' UPSTREAM OF CHOKES ARE lO,OOO PSI GATE Ty¢~chorage VALVES' OOWNSTRCcLU OF CHOKES ARE 5,000 PSt GATE TYPE CHOKE MANIFOLD GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: OAC APP'O' GS8 SCALE: NONE ox'rs: ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192. PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 November 3, 1992 Janet Bounds Unocal P O Box 190247 Anchorage, AK 99519-0247 Dear Ms Bounds: As we discussed on the phone October 28, AOGCC will be reassigning APl numbers for the wells listed below. In order to accommodate the revision of Unocal's records, we will not announce these changes to the public until the first week of December, or until you advise me that all the necessary changes are made. Give me a call if you would like to discuss this matter further. Well Name Permit # Old APl Number New APl Number Granite Pt St 17587 #3 66-52 50-883-10031 50-733-20437 Granite Pt St 17587 ~4 89-30 50-883-10032 50-733-20438-90 Granite Pt St 17587 ~6 89-103 50-883-10034 50-733-20439 Granite Pt St 18742 ~ 67-36 50-883-20008 50-733-20440 Granite Pt St 17586 ~4 67-54 50-883-20009 50-733-20441 Granite Pt St 18742 #34 79-17 50-883-20009-01 50-733-20441-01 Granite Pt St 17586 f~41 91-45 50-883-20009-02 50-733-20441-02 Granite Pt St 18742 #14 79-33 50-883-20010 50-733-20442 Granite Pt St 18742 #20 68-16 50-883-20012 50-733-20443 Granite Pt St 18742 #20RD 91-20 50-883-20012-01 50-733-20443-01 Granite Pt St 17587 #5 68-24 50-883-20013 50-733-20444 Pretty Creek Unit #2 79-9 50-283-20022 50-283-20022-90 Nicolai Creek Unit/~, 91-100 50-283-20033 50-283-20033-90 Lewis River D-1 89-72 50-283-20068 50-283-20068-90 Trading Bay Unit G-18DPN 83-135 50-733-20160 50-733-20160-90 Yours Iruly, Robert P Crandall Sr Petr Geologist /jo ALASKA OIL A~VD GAS CO#SERVATIOIV COMMISSIO~V / . ._ . - ~, ~S,/7, Permit No. ~--/~~ Bill Sheffield GOvernor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501-;-'319 2 TELEPHONE(907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well ~.~hich our records indicated was completed Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, C. V. Chatterton Chairman Union Oil and Gas --;ision' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unlen DOCUMENT TRANSMITTAL February 7, 1984 HAND DELIVERED TO: William Van Alen FROM: LOCATION: 3001 Porcupine Drive LOCATION: Anchorage, Alaska 99504 ALASKA OIL & GAS CONSERVATION COMMISSION R. C. Warthen Alaska District Transmitting: Reference: TBU 6-18 DRN One (1) box of representative core chips of cored intervals PLEASE ACKNOWLEDGE RECEIPT BY SIGNIN~ AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATED: FEB - 8 i984 Alaska Oil & Gas Cons. Anchorage Union Oil and Gas [- 1ion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unl, n DOCUMENT TRANSMITTAL November 28, 1983 Hand Delivered TO: William Van Alert FROM: LOCATION: 3001 Porcupine Drive LOCATION: Anchorage, AK 99504 ALASKA OIL & GAS CONSERVATION COMMISSION R. C. Warthen Alaska District Transmitting: One (1) set of bluelines and sepias of following logs: Volan DIL 2" and 5" CNL-FDC 2" and 5" Density 5" Sonic 2" and 5" HDT VDL SHDT Cyberlook Mudlog One (1) set of directional surveys One (1) coring log One (1) Volan tape and listing 'fCr~t~~ One (1) LIS tape and listing ~:~! PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK Y~~ RECEIVED BY: !.) ~:t'~~ ~ DATED: STATE OF ALASKA ~ ALASKA -G,~.. AND GAS. CONSERVATION CO~,.~ilSsIoN WELL COMPLETION OR RECOMPLETION REPORT AND LOG .... ' 1. Status of Well Classification of Service Well OIL [] GAS ~ SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number UNION OIL CONPANY OF CALIFORNIA 83-135 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50-733-20160 4. Location of well at surface 9. Unit or Lease Name Cond 42, Leg 2, 1884'N & 1378'W of SE CDr of Section 29, * Trading Bay Unit At Top Producing Interval 10. Well Number 2876'N & 1946'E of SW CDr of Section 28, * TBUS G-18 DRN At Total Depth 11. Field and Pool 2817'N & 3947'E of SW Cot of Section 28, * *TgN, R13W, SN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. McArthur River Field RT 99' MSLI ADL 18730 "D" Sands 12. Date Spudded 13. Date T,D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I16. No. of Completions 9-19-83 9-29-83 ]_]_--2--~3I 143 feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8860 & 6446 6189 & 4365 YES ~ NO []I 334 feet MD 22. Type Electric or Other Logs Run O!L/BHC-Soni¢/VDL; FRC/CNL/GR; D~pm~t.~r." RRI /VDI /RR/££1 · £RI /VDL/GR. 23. CASING, LINER ~N~ cE~ENTi'NG ~ E-CUR'D SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 9 5/8" 47# N-80 5989 8860 12 1/4' 1500 sxs cl ,,G,, ___ . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD . interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3 1/2" 5636 5564 D-1 sands f/ 5830-5870ND 4157-4179 TVD 8HFF ......... 5755-5800 4114-4140 8 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5690--5735 4077--4103 8 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED -~ee A~*¢hed · . · ... 27. PRODUCTION TEST Date F. i;rs~t .Production I Method of Operation (Flowing, gas lift, etc.) 11/5/83I Flowing Gas Well Date of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKE SIZE IGAS-OILRATIO 11/2/83- + 12, Hfs TEST PERIOD ~ --.' 5.35 ....I Flow Tubing Casing--~ressure CALCULATED. OIL-EEL . GAS-MCF WATER-EEL· OIL GRAVITY-APl (corr) -Press. 942 _ 24-HOUR RATE ~ -- : 12;500 -- -- 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. - RECEIVED . . : - , . Al~b Oil & Gas t:~r,~ Ahahora~e , . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 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. ,. · "E" Zone 8573 6180 See Attached Test Results . 31. LIST OF ATTACHMENTS 32. I hereby cert~that the foregoing is true and correct to the best of my knowledge Signed .~-/~~'~,~~__~-~w~_~/~-~'/i'/Title gIST DRUG SePT Date 11/15/83 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-site combustion. Item 5: Indicate which elevation is used as reference (Where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- 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". [~nrm 113-~37 ADDENDUM TO G-18 DPN COM=LETION REPORT 26. Name Blk Sqz #1 #2 #3 #4 D-17 D-17 D-17 D-16 D-16 D-14 D-10 D-9 D-2 Interval (MD) 7611-7613 7414-7416 6258-6360 6274-6276 8495-8510 8495-8510 8495-8511 8316-8328 8350-8360 8134-8150 7660-7672 7430-7450 6280-6300 Vert. Depth HPF 5337-5339 4 5183-5185 4 Cement Squeeze 250 SXS C1 "G" 250 4467-4468 4 250 4416-4417 6109-6123 6109-6123 6109-6124 5946-5957 5976-5985 5782-5796 5377-5386 4 150 4 50 _ 50 50 150 5196-5211 4 200 4420-4432 4 80 Retainers at MD 8225 8025 7300 6185 VD 5863 5685 5097 4363 w/ 50 sxs sqz w/ 50 sxs sqz w/ 50 spot on top of retainer w/ 80 sxs sqz RECE-IVED i T.B.U.S G-18Deepening McArthur River Field I I -- -- ~ ~ -- --- CA SING gt A BANDOIVM~N T DE' TA I£ I. RT-DCB © 0'. II. C.I.W. DCB-FBB Tubing Hange? a~ 38.79'. i i III. 17 3/4", .341" wall, spi~al g~ade, slip J~. casing 2 ~-] ~ 600' (¢mt w/ 800 sxs). ZV. Top of 9 ~/8" Line~ © .5989'. III V. Cement Retaine~ at 6185'DIL w/ 80 sxs cmt below ret. ' VI 13 3/8" 61~ 3-55 seal lock casin.q at 6194' (cml w/ 2250 sxs). VII. Cmt Retaine~ ~ 7300' DIL, w/ 50 sxs cmt above ~et. VIII. Cmt Retaine~ ."e 8025' DIL, w/ 50 sxs cmt below ~et. IX. Cmt Retaine~ 9 8225' DIL, w/ 50 sxs cmt below ~et. : X. Cmt Retaine~ Q 8445' DIL, w/ 50 sxs cmt below ~et. I XI. 9 5/8"~ 47~, N-80, Buttress casing ~ 8855' 3 ~ ! (cmt w/ 1500 sx) ., TUBING DE TAIL 1. 4 1/2" x ~ 1/2" c~oss-ove~ at ~9.79'. §~6 4.25 O.D.) ~ 3~4.24'. 7 -~- 3. 3 1/2" Otis "XA" Sleeve (2.75 I.D. x 4.28 O.D.) @ 5527.32' . __ ~ 4. Bake~ Locate~ at 5561.09'. 8 ~ 5. Bake~ Seal AssemOly 10.54' Length w/ A.734" O.D. Seals ~ 5561.99'. 6. Baker Model "KB" Drillable Prod. Packer ~ 5563.99' D-I SAND --- 7. 3 1/2" Otis "x" Nipple (2.75" I.D. x 3.75" O.D.) O' : 5603.84' . ' 8. Mule Shoe ~ 5635.88'. ,PEt?FOt~ATIOIV t~ECOt~D IV -- ' Date Interval Condition 10/15/83 8495'-8511' D-17 sd~qZ'~ w/ 50 sxs) V ~ 10/16/83 8350'-8360' D-!6 sd (Sqz'd w/ 50 sxs). VI -- - -- 10/16/83 8316'-8328' ~ 10/18/83 8134'-8150' D-14 sd (Sqz'd w/ 50 sxs) D-2 SAND 10/22/83 7660'-7672' D-10 sd (Sqz'd w/ 120 sxs) ~ 10/06/83 7611'-7613' Sqz'd foc isolation w/ 232 sxs i 10/23/83 7430'-7450' D-9 sd (Sqz'd w/ 176 sxs) ~1 10/07/83 7414'-7416' Sqz'd loc isolation w/ VII '~ 241 sxs cmt ~ D-9 SAND ~ 10/07/83 6358'-6360' Sqz'd fo~ isolation w/ I 241 sxs cmt ' 10/25/83 6280'-6300' D-2 sd (Sqz'd w/ 80 sxs) il D-Id SAND ~ 10/08/83 6274'-6276' Sqz'd fo~ isolation w/ 91 sxs VIII ~ 10/30/83 5830'-5870' D-1 sd/Open gas p~oduction 5" csg guns, 8 HPF, 120© phase D-14SAND ~ 10/30/83 5755'-5800' D-1 sd/Open fo~ gas p~oduction 5" csg guns, 8 HPF, i20° phase IX ~ 10/30/83 5690'-5735' D-1 sd/Open fo~ gas p~oduction ~ 5" csg guns, 8 HPF, 120© phase D-16 SAND ~ 06/08/69 5755'-5800' D-1 sd/Open fo~ gas pcoduction Hype~-jets, 4 HPF, 0© phase X ~ 12/04/68 5690'~5Z34' D-1 sd/Open fo~ gas production ~' , D-17 SAND ~z ~'C~!i~~ scallop qun 4 HPF, 0© phase Xl -- -- ' '-'~ ~ -' iUL},q. ~'~:,~-;,;~C.%~;~ D.Aw. BAW CKD. ~ Fid REV. ] DATE .... I I T.B.U.S. G-18 DPN *$::; ' WELL SCHEMATIC I COMPLETED: II/02/83 I ' ' t UNION OIL COMPANY OF CALIFORNIA I , -- ., LOS ANGELES SHEETS j SHEET FORM V 247 A 5/56 750 Form D-1001-A UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET A Page No. 1 LEASE Trading Bay Unit State WELL NO. G-18 DPN CONTRACTOR Conservative Drilling Co. FIELD McArthur R'i'ver' Field' TYPE UNIT National 132u UE' BEGAN 9/12/83 cOMPLETED il/2/83 ELEVATIONS' GROUND PERMIT NO. 83'-135 SERIAL NO. ADL-18730 CASING HEAD COMPANY EN~INE'ER Graham, McAllister, Abernathy, wag. enhoffer TUBING HEAD APPROVED ROTARY DRIVE BUSHING 110'.60 MLLW SIZE DEPTH .... WEIGHT CASING & TUBING RE'CORD 'G P~A'DE REMARKS 17 3/4" 600' 13 3/8" 6194' 9 5/8" 8855' 3 l/2" 5637' .341" WALL Spiral Cmt'd w/ 800 sxs 61# J-55 Cmt'd w/ 1700 sxs B-J mix + 550 sxs "G" w/ 2% Ca C12 47# N-80 Top of liner @ 5989'. Cmt'd w/ 1500 sxs. 9.2# N-80 Single 3 1/2" completion assy. DATE INTERVAL PERFORATING RECORD E .~.'D'. REASON PRESENT CONDITI'ON 10/15/83 10/16/83 10/16/83 10/18/83 10/22/83 10/06/83 10/23/83 10/07/83 10/07/83 10/25/83 10/08/83 10/30/83 8495 -8511' 8350 -8360' 8316 -8328' 8134 -8150' 7660 -7672' 7611 -7613' 7430 -7450' 7414'-7416' 6358'-6360' 6280'-6300' 6274'-6276' 5830'-5870' DST #1 DST #2 DST #3 DST #4 B.S. #1 DST #5 B.S. #2 B.S. #3 DST #6 B.S. #4 Production 10/30/83 5755'-5800' Production 10/30/83 5690'-5735 Production 06/08/69 5755'-5800' Production 12/04/68 5690'-5734' Production D-17 sd (Sqz'd w/ 50 sxs) D-16 sd (Sqz'd w/ 50 sxs) D-16 sd ['Sqz'd w/ 50 sxsl D-14 sd LSqz'd w/ 50 sxsj D-lO sd (Sqz'd w/ 120 sxs) Sqz'd for isolation w/ 232 sxs D-9 sd (Sqz'd w/ 176 sxs) Sqz'd for isolation w/ 241 sxs cmt Sqz'd for isolation w/ 241 sxs cmt D-2 sd (Sqz'd w/ 80 sxs) Sqz'd for isolation w/ 91 sxs D-1 sd/ Open for gas production 5" csg guns, 8 HPF, 120' phase D-1 sd/ Open for gas production 5" csg guns, 8 HPF, 120' phase D-1 sd/ Open for gas production 5" csg guns, 8 HPF, 120' phase D-1 sd/ Open for gas production Hyper-jets, 4 HPF, O* phase D-1 sd/ Open for gas production 2" scallop gun 4 HPF, O* phase bATE INITIAL PRODUCTION AFTER REPAIR INTERVAL NET OIL ~UT- GRAV.' C'.P. '~F'.P'. ~HbKE'- M~F" GOR REI~RRKS 12/4/83 5690'-5734' 11/2/83 5690'-5735' 5755'-5800' 5830 '-5870' 0 - - - 1300 20/64 7000 - 0 - - - 942 - 12506 - 1750 # tbg SIP D-1 Sand 1466 BHFP (PSIA) D-1 Sand WELL HISTORY PRIOR TO REPAIR LAST COMPLETION NO. 1 COMPLETION DATE' 12/4/68 PRODUCING INTERVAL" bbgU~-bJJ~;; b/bb;-bt)OO opened o'n INITIAL PRODUCTION: See above data LAS1~ REGULAR' I~ROi). & D'ATE: C'UMULATIVE' PR'ODUCI~IbN· . . · REA'SUN FUR' REPAIR: I0 res:-ane evaluate :he ::u:: zone gas sa'n'es Form D-1001-B LEASE Trading Bay Unit State COMPLE~I ON 'DATE 11/'2/)~'3 b)k'TE E.~.D. UNION OIL CO. OF CALIFORNIA REPAIR RECORD WELL NO. G-18 DPN SHEET B PAGE NO. 2 FIELD McArthur River Field )kPPR'OVED DETAILS OF O'PERATIO~S, DESCRIPTIONS & RE'SULTS WELL HEAD ASSEMBLY TYPE: Cameron Iron Works CASING HEAD: Shaffer "KD" 12" S900 CASING HANGFR: None CASING SPOOL: None TUBING HEAD: Cameron DCB 12" 3000 # WP x 10" 5000 # WP w/ 5000 # std outlet TUBING HANGER: DCB-FBB 10" Nominal, 4 1/2" buttress bottom x 4 1/2" EUE 8rd top TUBING HEAD TOP: 4 1/2" EUE w/ 4 1/8" bore MASTER VALVES: 4" Master and Swab, Solid Block Type Tree, CIW CHRIST)~S TREE TOP CONN.: 4 1/2" EUE 8 rd Form D-1001-C UNION OIL CO. OF CALIFORNIA REPAIR RECORD LEASE Trading BaY Unit State COMPLE-TION DATE 11/'2/83 DATE E.T.'D. SHEET C PAGE NO. 3 WELL NO. G-18 DPN FIELD McArthur River Field APPROVED DETAILS OF OPERATIONS, DESCRIPTIONS ~ RESULTS '" JTS DESCRIPTION 3 1/2" TUBING DETAIL LENGTH TOP BOTTOM ,. 1 1 1 1 1 1 9 1 183 1 1 1 1 RT-DCB CIW DCB-FBB Tbg Hgr 4 1/2 butt x 3 1/2 butt XO 3 1/2 butt 9.2# pup 3 1/2 butt 9.2# pup 3 1/2 butt 9.2# pup 3 1/2 butt 9.2# pup Jts 3 1/2 butt 9.2# 3 1/2 Otis BV nipple (see attachment Jts 3 1/2 butt 9.2# 3 1/2 butt coupling {S.C.) 3 1/2 Otis "XA" {2.75 ID x 4.28 OD) Jt 3 1/2 butt 9.2# Locator-Baker 2' Baker 4.734" OD Seals Top of Model "KB" pkr 8.54' Baker 4.734" OD Seals Jt 3 1/2 butt 9.2# 3 1/2 butt coupling (S.C.) 3 1/2 Otis "x" nipple (2.75 ID x 3.75 OD) Jt 3 1/2 butt 9.2# Mule Shoe (3 1/2 butt coupling S.C.) 38.79 -0- 38.79 1.00 38.79 39.79 .40 39.79 40.19 2.15 40.19 42.34 6.02 42.34 48.36 4.70 48.36 53.06 8.31 53.06 61.37 272.87 61.37 334.24 2.22 334.24 336.46 5190.13 336.46 5526.59 .73 5526.59 5527.32 3.23 5527.32 5530.55 30.54 5530.55 5561.09 .90 5561.09 5561.99 2.00 5561.91 5563.99 2.80 5561.91 5563.99 8.54 5563.99 5572.53 30.60 5572.53 5603.13 .71 5603.13 5603.84 .73 5603.84 5604.57 31.31 5604.57 5635.88 .73 5635.88 5636.61 Form D-lOO1-C UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET C PAGE NO. 4 LEASE Trading Bay Unit State COMPLETION DATE 1i/2/83 WELL NO. G-18 DPN FIELD McArthur River Field 'APPROVED DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS DESCRIPTION 9 5/8" CSG DETAIL TOP BTM LENGTH , 14 19 30 TIW Double Valve Drillable Float Shoe 9 5/8 Butt 47# N-80 TIW 9 5/8 Butt Drillable Float Collar 9 5/8 Butt 46# N-80 TIW 9 5/8 Butt Drillable Plug Landing Collar 9 5/8 Butt 47# N-80 PUP 9 5/8 47# N-80 Butt PUP 9 5/8 47# N-80 Butt 9 5/8 Butt 47# N-80 PUP 9 5/8 BUTT 47# N-80 PUP 9 5/8 BUTT 47# N-80 9 5/8 Butt 47# N-80 TIW 9 5/8 47# x 13 3/8 61# Hydro Liner Hanger TIW 9 5/8 Tie Back SLeeve with B Profile 2.38 8852.62 8855.00 44.71 8807.91 8852.62 1.24 8806.67 8807.91 41.96 8764.71 8806.67 1.13 8763.58 8764.71 591.84 8171.74 8763.58 21.39 8150.35 8171.74 20.92 8129.43 8150.35 809.55 7319.88 8129.43 23.03 7296.85 7319.88 22.35 7274.50 7296.85 1270.72 6003.78 7274.50 6.07 5997.71 6003.78 8.32 5989.39 5997.71 13 3/8 Shoe ~ 6194.00 TOL ~ 5989.39 Total Lap ~ 204.61 Total No. of Joints 65 plus 4 pups Total Hanging Length - 2865.61 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. TBUS G-18 DPN FIELD McArthur River DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1 9/12/83 6153' PBTD (FC) 17 3/4" C. 600' 13 3/8" C. 6194' DAILY COST: $ 10,805 ACC COST: $ 10,805 AFE AMT: $1,960,000 2 9/13/83 DAILY COST: ACC COST: AFE AMT: 3 9/14/83 DAILY COST: ACC COST: AFE AMT: 4 9/15/83 DAILY COST: ACC COST: AFE AMT: 5 9/16/83 DAILY COST: ACC COST: AFE AMT: 6390' TD 6153' PBTD (FC) 17 3/4" C. 600' 13 3/8" C. 6194' $ 11,122 $ 21,927 $1,960,000 6390' TD 6153' PBTD (FC) 17 3/4" C. 600' 13 3/8" C. 6194' $ 11,122 $ 33,049 .$1,960,000 6390' TD 6153' PBTD (FC) 17 3/4" C. 600' 13 3/8" C. 6194' $ 22,971 $ 56,020 $1,960,000 6390' TD 6153' PBTD (FC) 17 3/4" C. 600' 13 3/8" C. 6194' 65 PCF 45 SEC $ 33,762 $ 89,782 $1,960,000 Commenced operations ~ 00:01 hrs 9/12/83. Completed installation of cmt lines & tested lines to lO,O00 psi. Prime & paint under pipe racks. Checked mud end on #1 pump.. Switch DC power f/ Rig #55 to Rig #54. Prepare mud tanks & pipe racks for moving Rig #54 from leg #3 to leg #2. Prepare Rig #54 for turnaround and move to leg #2. Rig ready for cargo boat ® 16:00 hrs. Work boat "Rig Engineer" not available for rig move as scheduled. Continue rig maintenance until 11:00 a.m while waiting on cargo boat to. make rig turnaround. Offload pipe racks & mud pits. Jack Rig #54 from leg #3 to leg #2. Finished rig move. Rigged up service lines. Brought 5" DP on board. Mixed & pumped a 50 bbl CaC03, 6% KCL pill across the D-1 perfs, 5690-5735', 5755-5800'. Held 225 psi against perfs for 20 min. Bled off well. Well dead $ 24:00 hfs 9/15/83. RIH w/ Myers WL & retrieved ball valve f/ 323'. RIH w/ 1 11/16" gun & perfed 4 HRF f/ 5502' to 5504' for circ. POOH w/ WL. Circ down tbg & up 13 3/8" annulus w/ 6% KCL fluid- lost returns. Mixed & pumped 100 bbl pill of FIW w/ 6% KCL, 2 RRB HEC, and 25 RPB CaC03. Well stopped taking fluid. Circ well clean of diesel fuel in annulus. Well is dead. Installed BRV, removed tree, and installed BORE. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. TBUS G-18 DPN FIELD McArthur River DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6 9117/83 6390' TD 6153' PBTD (FC) 17 3/4" C. 600' 13 3/8" C. 6194' 68 PCF 38 SEC DAILY COST: $ 48,645 ACC COST: $ 138,427 AFE AMT: $1,960,000 7 9/18/83 DAILY COST: ACC COST: AFE AMT: 8 9/19/83 DAILY COST: ACC COST: AFE AMT: 9 9/20/83 DAILY COST: ACC COST: AFE AMT: 6390' TD 6181' ETD (PKR JUNK) 17 3/4" C. 600' 13 3/8" C. 6194' 68 PCF 42 SEC $ 29,342 $ 167,769 $1,960,000 17 3/4" C. 600' 13 3/8" C. 6194' 69 PCF 44 SEC $ 76,610 $ 244,379 $1,960,000 7099'/517' 17 3/4" C. 600' 13 3/8 "C. 6194' 71PCF 47 SEC $ 40,970 $ 285,349 $1,960,000 Installed BORE & tested to 3000 psi -ok. Pulled seal assy out of pkr & circ hole clean - rec some gas. In- creased mud wt to 68 RCF &circ well clean. Well was dead. Pulled 2 7/8" tbg. Pulled & rec 2 7/8" tbg. Lifted stack & removed DCB spool. In- stalled spacer spool & BORE. RIH w/ packer retrieving tool & tagged pkr $ 5529'. Tools were wedged in pkr. Tripped jars & POOH - rec pkr man- drel. RIH w/ concave junk mill & milled on pkr $ 5529'. Packer dropped away after I hr. RIH & tagged pkr junk ® 6166'. Milled junk & cmt to 6181'. POOH w/ mill. Run Eastman gyro survey f/ 6100' - surface (50' stations). RIH w/ BHA #1. Tested D-1 perfs to 78 RCF equiv. Drill lC' out of shoe. Tested shoe to 78 RCF equiv. POOH. RIH w/ BHA #2. Followed old 12 1/4" hole to 6402'. Drld 12 1/4" hole f/ 6402-6582'. Surveys: 6341' 52 3/4° S88E 6464' 52 1//2° S88~5E Drld f/ 6582-6719'. Removed kelly spinner motor. Drld f/ 6719-6905'. Trip for bit change. RIH w/ 12 1/4" bit on 20' pendulum assy. Had no fill. Drld f/ 6905-7099'. Surveys: 6586' 49 3/4° S87.5E 6709' 49.5° S87.5E 6834' 48.25° S88E 6925' 46.5° S86.5E SHEET D 8 PAGE NO. 7 UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE ADL 18730 WELL NO. TBUS G-18 DPN FIELD McArthur River DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 10 9/21/83 DAILY COST: ACC COST: AFE AMT: ll 9/22/83 DAILY COST: ACC COST: AFE AMT: 12 9/23/83 DAILY COST: ACC COST: AFE AMT: 13 9/24/83 DAILY COST: ACC COST: AFE AMT: 14 9125/83 DAILY COST: ACC COST: AFE AMT: 7467'/368' 17 3/4" C. 600' 13 3/8" C. 6194' 71PCF 57 SEC $ 45,833 $ 331,182 $1,960,000 7548'/81' 17 3/4" C. 600' 13 3/8" C. 6194' 72 PCF 55 SEC $ 43,682 $ 374,864 $1,960,000 7675'/127' 17 3/4" C. 600' 13 3/8" C. 6194' 72 PCF 55 SEC $ 34,913 $ 409,777 $1,960,000 7736'/61' 17 3/4" C. 600' 13 3/8" C. 6194' 71PCF 58 SEC $ 44,903 $ 454,680 $1,960,000 8039'/303' 17 3/4" C. 600' 13 3/8" C. 6194' 71PCF 53 SEC $ 37,147 $ 491,827 $1,960,000 Drld f/ 7099-7204'. Lost pump on desilter. Pulled up to shoe & con- ditioned mud. RIH to bottom. Drld f/ 7204-7283'. Left btm section of survey instrument on top of Totco ring. POOH & retrieve instrument. Change bit & RIH. Drld f/ 7283- 7467'. Surveys: 7018' 44° S88.5E 7112' 43.75° S85.5E 7202' 42° S85.5E 7294' 40.75° S87E Drld f/ 7467-7494'. Circ btms up. POOH. PU core barrel. RIH. Core f/ 7494-7523'. Rec 29' of 4" core f/ the D-9 sand. PU i - 6" DC and RIH. Core 7523-7548'. POOH w/core barrel. Lay down core & coring assy. Rec 25' of 4" core f/ the D-9 sand. PU 12 1/4" hole opener. RIH. Open 8 1/2" to 12 1/4" hole. POOH for drlg assy. RIH to 7488'. Ream to 7548' (no fill). Drill 12 1/4" hole f/ 7548-7675'. POOH for coring assy. Surveys: 7306' 38° S87E 7595 37° S87.5E Finish POOH. Lay down drlg assy. RU coring assy & RIH. Core D-lC sd f/ 7675-7705'. POOH. Retrieve 14.5' core. Left catcher basket f/ core barrel in hole. Lay down coring assy. PU 12 1/4" drlg assy. RIH. Open 8 1/2" hole to 12 1/4" f/ 7675-7705'. Drill 12 1/4" hole f/ 7705-7707'. POOH. Lay down drlg assy. PU coring assy. RIH & core f/ 7707-7736'. POOH. Finish POOH w/ coring assy. Rec 28.5' D-lC core. Lay down core barrel. RU drlg assy. RIH. Open 8 1/2" hole to 12 1/4" f/ 7707-7736' w/ 12 1/4" bit. Drill f/ 7736- 8039'. POOH to change BHA & bit. Tight spot ~ 7020'. Surveys: 7707 36° N89E 7830' 34.25° S89.5E 7952' 30.5° S85.5E UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. TBUS G-18 DPN FIELD McArthur River DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 15 9/26/83 DAILY COST: ACC COST: AFE AMT: 16 9127/83 DAILY COST: ACC COST: AFE AMT: 17 9/28/83 8358'/319' 17 3/4" C. 600' 13 3/8" C. 6194' 72 PCF 55 SEC $ 40,530 $ 532,357 $1,960,000 8469'/111' 17 3/4" C. 600' 13 3/8" C. 6194' 72 PCF 49 SEC $ 33,458 $ 565,815 $1,960,000 8635'/166' 17 3/4" C. 600' 13 3/8" C. 6194' 72 PCF 50 SEC DAILY COST: $ 36,377 ACC COST: $ 602,192 AFE AMT: $1,960,000 18 9/29/83 8860'/225' 17 3/4" C. 600' 13 3/8" C. 6194' 72 PCF 47 SEC DAILY COST: $ 25,792 ACC COST: $ 627,984 AFE AMT: 19 9/30/83 DAILY COST: ACC COST: $1,960,000 8860' TD 17 3/4" C. 600' 13 3/8" C. 6194' 71PCF 52 SEC $ 79,615 $ 707,599 POOH. Test BORE's. PU 20' LC. RIH. Slip drlg line. Drill f/ 8039-8144'. Survey tools backed off sand line. POOH w/ DP & retrieve survey instruments. RIH. Drill f/ 8144-8358'. Surveys: 8103 28° S83.5E 8198' 26° S83.5E 8318 24 3/4° S83.5E Finished circulating btms up. POOH w/ 12 1/4" drlg assy. PU coring assy & RIH. Cut core #5 f/ 8358- 8388' in 30 min. POOH. Rec 15.4' of core. Change BHA & RIH. Cut core #6 f/ 8388-8415'. POOH. Rec 27' of core. LD coring assy. RU 12 1/4" drlg assy & RIH. Reamed core section f/ 8358-8415'. Drld 12 1/4" hole f/ 8415-8469'. Drill f/ 8469-8606'. Circ btms up. POOH. PU coring assy & RIH. Core f/ 8606-8635' (29'). POOH & rec 26' of core f/ the D-17 sd. RIH & ream thru core section f/ 8606-8635'. Survey: 8480 24 1/4° S83.5E Drld 12 1/4" hole f/ 8635-8860' TD. Circ & cond hole for logs. POOH to shoe. RIH to TD & circ. On 1st trip to shoe, 1st 10 stds ragged. Had two tight spots pulling 25-30M# over on 2nd trip $ 8124' & 7335'. POOH. RU Schlumberger & RIH w/ DIL/BHC-Sonic/VDL. Btm $ 8842' WLM. Surveys: 8693' 22° S83.5E 8813' 20 3/4° S80.5E Ran DIL/BHC-Sonio/VDL, FDC/CNL/GR, & Dipmeter (had to run dipmeter twice). Shot 45 SWS - rec 31. AFE AMT: $1,960,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. TBUS G-18 DPN FIELD McArthur River DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 20 10/1/83 DAILY COST: ACC COST: AFE AMT: 21 10/2/83 8860' TD 17 3/4" C. 600' 13 3/8" C. 6194' 72 PCF 49 SEC $ 78,685 $ 786,284 $1,960,000 8860' TD 17 3/4" C. 600' 13 3/8" C. 6194' 9 5/8" L. 8855' TOL ~ 5989' 72 PCF 50 SEC DAILY COST: $ 202,135 ACC COST: $ 988,419 AFE AMT: $1,960,000 22 10/3/83 DAILY COST: ACC COST: AFE AMT: 23 10/4/83 DAILY COST: ACC COST: 8860' TD 17 3/4" C. 600' 13 3/8" C. 6194' 9 5/8" L. 8855-5989' 72 PCF 54 SEC $ 59,885 $1,048,304 $1,960,000 8860' TD 8764' PBTD 17 3/4" C. 600' 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 72 PCF 58 SEC $ 27,193 $1,075,497 Completed running SWS. RD Schlum & RU Dialog on GO WL. RIH w/ 13 3/8" csg inspeotion log - stopped ~ 2330' due to hole deviation. Ran log f/ 2330' to surface. RD GO WL. RIH w/ BHA #16 (12 1/4" hole opener). Trip good to 8790'. Reamed f/ 8790' to 8860'. Ciro & oond mud for liner. Make short trip to 13 3/8" shoe - had tight spots ~ 8591' 8498' 6916' & 6792' RIH to 8860' - cleaned out 8' of fiil. Circ well clean & made short trip to 13 3/8" shoe - had tight spots ~ 8591', 8498' 6947' & 6534' Wait at shoe , , · 2 hrs. RIH to 8860'. No fill· Circ'd hole· POOH· RU & ran liner (9 5/8" 47# Butt) 65 its plus 2 flag jts & accessories. Tagged btm ~ 8860'. Circ'd liner starting ~ 2.7 BRM & increasing in stages to l0 BRM in prep to cmt liner. Cmt'd liner w/ 200 CF FIW weighted to 72 PCF w/ a PH of 11.0 followed by 100 CF FIW followed by 1500 sxs "G" cmt w/ 1% CFR-2, .3% Halad-24, & 3% NaCL. Slurry wt 16 ppg. Started mix ~ 01:00 hrs. CIP ~ 03:50 hrs. Bumped plug w/ 500 psi & set liner w/ 3000 psi. Released f/ liner & POOH. WOC for 15 hrs. RIH w/ 12 1/4" bit & 13 3/8" csg scraper. Tagged cmt ~ 5959'. C0 to TOL ~ 5989'. Cmt still soft. POOH. WOC. Service rig. RIH w/ 8 1/2" bit & 9 5/8" csg scraper to 8723'. Clean out cmt f/ 8723-8760'. C&C mud. POOH. PU & RIH w/ 13 3/8" test pkr & set ~ 5894'. Press test liner lap & 9 5/8" liner to 2500 psi. Test ok. Prep for dry test on liner lap. Displace fluid inside DP to 2200' TVD w/ N2. AFE AMT: $1,960,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. lO LEASE ADL 18730 WELL NO. TBUS G-18 DPN FIELD McArthur River DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 24 10/5/83 DAILY COST: ACC COST: AFE AMT: 25 10/6/83 DAILY COST: ACC COST: AFE AMT: 26 10/7/83 DAILY COST: ACC COST: AFE AMT: 8860' TD 8764' ETD 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 72 PCF 55 SEC $ 52,017 $1,127,514 $1,960,000 8860' TD 7530' ETD (Cmt Plug on Top Ret ® 7544') 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 71PCF 45 SEC $ 48,607 $1,176,121 $1,960,000 8860' TD 6311' ETD (Ret) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 71PCF 44 SEC $ 62,768 $1,238,889 $1,960,000 RIH w/ HR pressure recorder - tool failed. POOH. RIH w/ new recorder to 6030' WLM. Bled off N2 & tested liner lap for i hr - test was dry. POOH w/ WL & test tools. RU GO WL & ran CBL/VDL/GR/CCL log across liner. RU Dialog & ran csg inspection log. CBL/VDL/GR log showed good cmt bond f/ ETD to +7900'. (No sqz work re- quired for--D-17, D-16, D-14 tests). Ran Dialog Csg Insp Log - unable to get tools belOw 3210'-logged out of hole. Ran Eastman gyro survey f/ 8750-6000'. (Survey showed TVD 9' deep & hole $ TD, 43'N & 23'E of magnetic survey-uncorrected). Go Int'l perforated top of D-lO sd f/ Blk Sqz #1 f/ 7611'-7613' DIL using 4" OD 4 HPF carrier gun. Set Howco EZSV ret on DP ® 7544' DPN. Broke down Blk Sqz #1 perfs ~ 2700 psi. Pumped in 14 CFM ~ 3200 psi. Formation held 1600 psi statlc. Sqz'd perfs w/ 250 sxs cmt w/ 3% NaCL, .3% Haled 24 & 1% CFR-2, to a final pressure of 3350 psi ® 15 CFM. Sqz perfs held 1850 psi static. POOH w/ setting tool. RU GO Int'l. Unable to get perf gun below 6168'. POOH w/ WL. Ran 8 1/2" bit & scraper. CO 9 5/8" csg to 7530'. After conditioning hole $ 7530', POOH. RIH w/ GO Int'l 4" OD 4 HPF perf gun, perf above D-9 sand ® 7414-7416' DIL for Blk Sqz #2. POOH. RIH w/ gauge ring & junk bas- ket to 7400', POOH. Set Howco EZSV ret w/ WL ~ 7376' OIL. RIH w/ DP & stinger, stab into ret $ 7386' DPM. Broke down Blk Sqz #2 perfs $ 2400 psi. Pumped in 15 CFM $ 2000 psi, form held 700 psi static. Mixed 250 sxs "G" cmt w/ 0.75% CFR-2, 0.2% Haled 24-A, & 3% NaCL. Displaced 241 sxs below tool - final rate 15 CFM ® 2200 psi. Form held 1500 psi static. POOH. RIH w/ GO Int'l 4" OD 4 HPF perf gun, perf base of D-2 send f/ 6358-6360' DIL. for Blk Sqz #3. POOH. RIH w/ WL gauge ring, junk basket to 6600'. POOH. RIH w/ WL & set Howco EZSV ret ® 6311' DIL. POOH. RIH w/ stinger on DR. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. ll LEASE ADL 18730 WELL NO. TBUS G-18 DPN FIELD McArthur River DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 27 10/8/83 DAILY COST: ACC COST: AFE AMT: 8860' TO +6245' ETD (Cmt plug on Top Ret $ 6241' DIL) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 71PCF 49 SEC $ 44,910 $1,283,799 $1,960,000 28 10/9/83 8860' TD 6316' ETD (Ret) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 71 PCF 49 SEC DAILY COST: ACC COST: $ 33,263 $1,317,062 AFE AMT: $2,960,000 29 10/10/83 8860' TD 8760' ETD (Cmt on LC) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 71PCF 50 SEC DAILY COST: ACC COST: $ 29,228 $1,346,290 AFE AMT: $1,960,000 30 10/11/83 8860'TD 8760'ETD (Cmt on LC) 18 3/8" C. 6194' 9 5/8" L. 5989-8855' 71 PCF 50 Sec DAILY COST: ACC COST: $ 28,422 $1,374,712 Stab into ret $ 6311' OIL for Blk Sqz #3, base of D-2 sand. Broke dwn form ~ 2200 psi, pumped in 16 CFM ~ 2000 psi, form held 1000 psi static. Mixed 250 sxs cl "G" cmt & displaced 241 sxs cmt below tool. Final rate 8 CFM ~ 2100 psi. Sqz job held 1500 psi static. POOH. RIH w/ GO Int'l 4" OD 4 HRF carrier guns for Blk Sqz #4. Rerf top D-2 sand f/ 6274-6276' DIL. POOH & RD GO Int'l. RIH w/ Howco EZSV ret on DP, set ret $ 6246' OPM (6241' DIL). Broke down form ~ 2100 psi, pumped in 14 CFM ® 2000 psi, form held 1400 psi static. Mixed 150 sxs cl "G" cmt. Displaced 91 sxs cmt below tool. Final rate 1 CFM $ 2900 psi. Sqz job held 2600 psi static. POOH. Note: (Slurry used for Blk Sqzs #3 & #4: cl "G" w/ 0.75% CFR-2, 0.2% Halad 24-A, & 3% Nacl). RIH w/ GO Int'l WL w/ Dialog csg insp tool to 1900', log out of hole. RIH w/ Dialog to 3725', log out of hole. Plug rubber, cmt imbedded in tool. RIH w/ 12 1/4" bit & scraper to TOL ~ 5989' DIL. POOH w/ 12 1/4" bit & scraper. RIH w/ GO Int'l WL w/ Dialog csg insp tool to 5157', log f/ 5126' to surf. (Tight spots ~ 4250' & 5157'). Test BOP equipment. Tested ok. RIH w/ 8 1/2" bit to drill out ret & cmt. Drill out ret ® 6246' DRM, drill out cmt to 6305', drilling on ret ~ 6316'. TIH w/ 8 1/2" bit - drlg cmt ret ® 6316' DPM & CO cmt f/ blk sqz #3 f/ 6346-6371'. Drlg cmt ret ~ 7386' DPM & CO cmt f/ blk sqz #2 f/ 7386- 7495'. Drlg on cmt ret $ 7544' DPM -bit trip. Drlg ret ® 7544' & CO cmt f/ blk sqz #1 to 7671'. TIH to ETD $ 8760'. C&C $ 8760' POOH. RIH w/9 5/8" scraper, C&C mud for test. POOH. RU 3 1/2" TBG, RIH. Pressure test tbg to 4100 psi, tested OK. POOH. RU Howco DST assembly. AFE AMT: $1,960,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 12 LEASE ADL 18730 WELL NO. TBUS G-18 DPN FIELD McArthur River DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 31 10/12/83 DAILY COST: ACC COST: AFE AMT: 8860'TD 8760'ETD (Cmt on LC) 18 3/8" C. 6194' 9 5/8" L. 5989-8855' 71PCF 50 Sec $ 44,429 $1,419,201 $1,960,000 32 10/13/83 DAILY COST: ACC COST: AFE AMT: 8860'TD 8760'ETD (Cmt on LC) 18 3/8" C. 6194' 9 5/8" L. 5989-8855' 71PCF 51 Sec $ 34,589 $1,453,790 $1,960,000 33 10/14/83 8860' TO 8760' ETD (Cmt on LC) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 71PCF 50 SEC DAILY COST: ACC COST: $ 33,398 $1,487,188 AFE AMT: $1,960,000 RIH w/HOWCO DST assembly. Pressure test lubricator, test manifold and surface lines to 4600 psi. Tested OK. Fill tbg w/N2 to 350 psi surface, monitor pressure. No entry-sqz. Perfs OK. POOH w/GO, RD. Bleed off N2. Continue RIH w/3 1/2" tbg, set RTTS ~ 8398 (tbg tall ~ 8435'). Pressure up tbg. w/N2 to 1100 psi. RIH w/GO Int'l WL and 15' 2 1/8" bi-wire perf gun. Unable to get below 8159 - stuck. Pick up wt. ® tbg, came free. POOH w/WL, guns badly crimped. PU 15' 2" rigid carrier guns. RIH on GO WL to 8250'. Stuck. Work down to 8365'. Pull out of rope socket ~ 8365', left gun in tbg. Rig down GO Int'l, bleed off N2. POOH, C.O. carrier gun and junk (caps from biwire guns). Change out Hydrospring, RIH. Set dn ® TOL, H-S opened, fluid entry. POOH. Chg out H-S, RIH. RU GO Int'l, RIH w/15' 2" carrier gun on WL. RIH to Hydrospring. Pressure up tbg. to llO0 psi w/field gas. Unable to pass thru H-S w/perf gun. POOH w/GO - base of gun revealed mechanical Hydrospring not open. Bleed off pressure, release RTTS, POOH w/tbg. Change out H-S., bore 3 3/8" holes in tail pipe. RIH w/3 1/2" tbg and DST assembly. RIH w/GO 15' 2" carrier gun to 8300' WLM pressure tbg to llO0 psi w/field gas. Set RTTS ~ 8401', open Hydrospring. Locate and perf the D-17 sand (8495'-8510' DIL) (4 HRF). Bled dn tbg. 'No entry' POOH w/WL. RIH w/gun #2. Re-perf 8495'-8510' DIL, w/2' guns (4 HRF). 'No entry' RIH w/HR pressure tool, unable to detect fluid level. POOH w/WL. Fill tubing w/mud, shear out R/U sub ~ 2000 psi. Circulate btms. up - no gas. Release RTTS. SHEET D UNION OIL COMPANY OF CALIFORNIA WELL RECORD PAGE NO. 13 LEASE ADL 18730 WELL NO. TBUS G-18 DPN FIELD McArthur River DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 34 10/15/83 8860' TD 8445' ETD (Ret) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 70 PCF 48 SEC DAILY COST: ACC COST: $ 32,420 $1,519,608 AFE AMT: $1,960,000 35 10/16/83 8860' TD 8445' ETD (Ret) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 71 PCF 43 SEC DAILY COST: ACC COST: $ 45,015 $1,564,625 AFE AMT: $1,960,000 36 10/17/83 DAILY COST: ACC COST: 8860'TD 8445'ETD (Cmt ret) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 71RCF 43 Sec $ 33,194 $1,597,819 R/U 16' 4" (sg gun on WL). RIH. Locate and perf 8495-8511' DIL. (4 HRF 0° phase). POOH. R/U Howco test assy on tbg RIH. Pressure tbg to 510 psi w/fieldgas. Set RTTS $ 8400' tbg maas andopen test tool. 'Entry' wait 1/2 hr, RIH w/HR tool. Tag fluid level $ 3800' WLM, determine salt water gradient. Surface pressure built to 2650 psi in 4 hrs, bled off field gas to 0 in 5 mins. Take sample w/GO. POOH w/GO WL. Fill tbg w/mud, shear out pump out sub. Reverse out fluid. Take samples (2000 to 2500 ppm C1, 2% to 3% sand). POOH w/3 1/2" tbg RIH w/WL and set cmt retainer ® 8445' DIL. RD GO. RIH w/stinger on 5" DP, stab into ret $ 8461' DPM for D-17 sqz. Pumped in ® 12 cfm $ 2600 psi. Formation held 1200 psi. Displaced 50 sx class 'G' cmt w/0.75% CFR-2, 0.2% Halad-24, 3% salt below tool at a final rate of 10 cfm ® 2850 psi. Sqz job held 2400 psi after 10 mins. Circulate bottoms up - no cmt returns. POOH w/DP. RIH w/4" 4 HPF (tbg conveyed) 120° perf guns and DST assembly on 3 1/2 "tbg. Tag ret $ 8467' tbg measurement, set RTTS $ 8261' tbg measurement. RIH w/GR tool on WL, locate D-16 sand. Release RTTS and reset $ 8258' tbg measurement. Re-log, POOH w/GR. Pressure tubing to 1150 psi w/field gas, drop firing bar. Perforate the D-16 sand 8316'-8328' and 8350'-8360' DIL. 'Entry' fluid to surface in 3 mins. Bleed off field gas cushion and flow well thru 16/64" choke, chg to 24/64" choke. Shut in well. Finished RIH w/HR pressure tool to 8275'. Test and evaluate the D-16 sand. POOH w/HP tool. Stuck tool ~ 8265'. P~lled 2500' lbs while flowing well. WL came free. Pulled high drag up to 5800' POOH w/WL. RD WL. Mix & pump ~0 Bbls of FIW w/6% KCL and 20 lb/abl CaCo3. AFE AMT: $1,960,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 14 LEASE ADL 18730 WELL NO. TBUS G-18 DPN FIELD McArthur River DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 37 10/18/83 DAILY COST: ACC COST: AFE ANT: 8860'TD 8200'ETD (Cmt ret) 13 3/8" C. 6194' 9 5/811L. 5989-8855' 72 PCF 49 Sec $ 104,896 $1,702,715 $1,960,000 Kill well. Circ btms up. RIH & tagged ret ~ 8466' tbg meas, 8445' DIL. No sand fill on ret. POOH. RIH w/drillable bridge plug and set ~ 8200' DIL on WL. RU 4" O.D. 4 HRF 120° phase tbg conveyed guns & DST assy & RIH. Set RTTS ® 8078' DIL. Pumped N2 cushion, 1950 psi surface, 2355 psi ~ top of perfs. Perforate F/8134'-8150' DIL ~ ll:O0 pm. Flowed D-14 sand ll:05 pm. -11:35 pm. $ 4-3.5 MMSCFD, 2013 surface press. 38 10/19/83 8860 ' TD 8200'ETD (Cmt ret) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 72 PCF 47 Sec DAILY COST: $ 49,288 ACC COST: $1,752,003 AFE AMT: $1,960,000 39 10/20/83 DAILY COST: ACC COST: AFE AMT: 8860'TD 8084'ETD (Cmt ret) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 71PCF 46 Sec $ 48,566 $1,800,569 $1,960,000 Tested D-14 sand. Data in table below. Completed DST $ 8:18 p.m. POOH w/HP tool on WL. LD HP tool. PU sample catcher & RIH. Completed RIH with WL sample catcher & took sample ® 8110'. POOH rigged down WL. Started pumping kill pill down TBG ~ 2275 psi. By the time 24 bbls were pumped, pressure went to 3000 psi indicating plugged TBG. Closed hydrospring ~ 8059 & bled press off TBG thru test separator. Filled TBG with mud, sheared pump out sub with 1800 psi, & reversed TBG. Spotted 50 bbl kill pill outside pump out sub. Pulled RTTS loose & watched fluid level in wellbore. It didn't move. Slacked off on TBG. Tagged RET $ 8200' (No Fill). Reversed TBG, well dead. POOH. 100% of shots had fired. Rigged up WL with 9 5/8" Howco E-Z Drl Ret RIH & Set Ret ® 8084' DIL. ROOH/WL. Made up tubing conveyed guns & test assy for D-lC sand. RIH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 15 LEASE ADL 18730 WELL NO. TBUS G-18 DPN FIELD McArthur River DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4O 10/21/83 8860' TD 8084' ETD (Cmt ret) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 71PCF 46 SEC DAILY COST: ACC COST: $ 49,650 $1,850,219 FE AMT: $1,960,000 41 10/22/83 8860' TD 7630' ETD (Cmt ret) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 72 PCF 48 SEC DAILY COST: ACC COST: $ 50,491 $1,900,710 AFE AMT: $1,960,000 42 10/23/83 8860' TD 7630' ETD (Cmt ret) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 72 PCF 45 SEC DAILY COST: ACC COST: $ 49,389 $1,950,000 AFE AMT: $1,960,000 Positioned pkr & guns in prep for D-lC test. Dropped firing bar. Guns did not fire. Made two attempts to fish firing bar without success. RIH w/HP to find fluid level. Found fluid 8 7485'. Had .87 bbl entry, which equates to a 2.4% expansion of the rat hole fluid. POOH w/HP tool. RIH w/fishing tools on WL. Spud on firing bar attempting to fire guns without success. POOH without firing bar. Filled tbg w/mud & POOH. Confirmed that guns did not fire, due to bad caps. Made up new guns & test assy. RIH w/new guns & test assy. Set pkr ® 7605'. Perforate the D-lC sand f/7660'-7672' w/1820 psi of N2 on surface. Guns fired ® 8:15 a.m., 10/22/83. Had no pressure increase in 30 minutes. Bled surface press to 100 psi. RIH w/HR tool and sample catcher on WL. Fluid level ~ 7419'. In 1.5 hrs, HR tool indicated a 3.5 psi BHR increase, while surface press remained constant 8 100 psi. POOH w/HR tool & sample catcher. Filled tbg w/mud & POOH w/test assy. RIH w/9 5/8" EZ drill cmt ret and set ~ 7630' DIL. POOH w/WL. RIH w/D.R. in prep to sqz the D-lC sand. Completed RIH w/DP Sqz the D-lC sand f/7660'-7672' w/150 sxs class "G" 3% Nacl 1% CFR2, 3% Hadad 24A. (Had break-down $ 2700 psi, final rate of 9 CFM ® 2500 psi. Held 200 psi w/pumps off 2 mins.) CIP $ 4:16 a.m., 10/23/83. POOH w/DP. RIH w/guns & test assy. Set pkr ® 7375'. Perforated the D-9 sand f/7430'-7450' DIL, w/1757 psi N2 cushion on surface. Fired guns ® 5:40 p.m. Bled off cushion to 1141 psi in 30 min. Produced 1 bbl of mud to separator. RIH w/HP pressure recorder. Surface pressure built to 1191 psi & stabilized. Found fluid level $ 4140' MD. Established gradient in fluid to be .47 psi/ft. RIH w/HP recorder. Couldn't work below 7160' MD. Stabilized press ~ 7160'MD 2250 psi. Opened well to flow, bled surface press down to + 200 psi. Shut in well for build-up & took fluid sample w/WL. Pull out w/WL. Gradient on way out .34 psi/ft on BTM. WL parted $ surface in lubricator while POOH w/2500 lbs line pull. Recovered WL. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D RAGE NO. 16 LEASE ADL 18730 WELL NO. TBUS G-18 DPN FIELD McArthur River DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 43 10/24/83 DAILY COST: ACC COST: AFE AMT: 44 10/25/83 8860'TD 7400'ETD (Cmt ret) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 72 RCF 46 SEC $ 118,166 $2,068,265 $1,960,000 8860'TD 7400'ETD (Cmt ret) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 72 PCF 46 SEC DAILY COST: $ 53,958 ACC COST: $2,122,223 AFE AMT: $1,960,000 45 10/26/83 DAILY COST: ACC COST: AFE AMT: 46 10/27/83 DAILY COST: ACC COST: 8860 ' TD 7500'ETD (Cmt) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 72 PCF 5I SEC $ 36,119 $2,158,342 $1,960,000 8860' TD 8463' (JUNK) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 71 PCF 45 SEC $ 25,271 $2,183,613 Prep to kill well. Filled tbg w/ 12 Bbls of mud. Fluid level after D-9 test was approx 1300' MD. Blew RO sub. Reversed tbg full of 72 PCF mud. Removed lubricator, clamped wireline & picked up w/ airtugger. Re threaded WL thru shives and spliced onto WL unit. POOH w/ WL. Circ btms up. POOH w/ test assy, (100% of guns fired). RIH w/ cmt ret on WL and set ® 7400' DIL. POOH w/ WL. RIH w/ DR & sqz the D-9 perforations (7430'-7450') w/ 200 sxs class "G", 3% NEC1, 1% CFR2, .3% Halad 24A. Pumped 5.5 CFM into formation $ 1800 psi w/ a final pumping rate of 8 CFM ® 2400 psi. Sqz job held 1700 psi with pumps off after two mins. Cmt in place $ 3:04 PM. POOH w/ DR. Make up & RIH guns & test. Set RTTS $ 6230'. Rerf D-2 sand f/6280'-6300' Flow well for clean-up, shu~ in. RIH w/HR on WL - sporadic readings. POOH. Cut off 1500' of WL. RIH w/HR tool. Begin flow testing ® 5:07 p.m. Completed DST of the D-2 sand. Killed well. POOH w/ testing assy. Change upper pipe rams to 5". RIH w/ 5" DP. Drl on ret ~ 7408' DP maas. Drl cmt f/ 7414'-7500. Drill cmt f/ 7500-7582', drill ret 7642', 8094', 8218' (DPM). Tag btm ~ 8463'-junk under bit. POOH. RIH w/ 12 1/4" bit & 13 3/8" scrpr. AFE AMT: $1,960,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 17 LEASE ADL 18730 WELL NO. TBUS G-18 DPN FIELD McArthur River DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 47 10/28/83 8860' TD 8225' ETD DIL (Cmt ret) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 71PCF 41 SEC DAILY COST: ACC COST: $ 45,003 $2,228,616 FE AMT: $1,960,000 48 10/29/83 8860' TD 6185' ETD DIL (Cmt ret) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 72 PCF 39 SEC DAILY COST: ACC COST: $ 68,460 $2,297,076 AFE AMT: $1,960,000 49 10/30/83 8860' TD 6185' ETD DIL (Cmt ret) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 71PCF 40 SEC DAILY COST: ACC COST: $ 98,225 $2,395,301 AMT: $1,960,000 50 10/31/83 DAILY COST: ACC COST: AFE AMT: 8860' TO 6185' ETD DIL (CMT RET) 13 3/8" C. 6194' 9 5/8" L. 5989-8855' 71PCF 40 SEC $ 29,266 $2,424,567 $1,960,000 Finish RIH w/ bit & 13 3/8" scraper to 5989' (TOL). POOH. RIH w/ bit & 9 5/8" scraper to 8463'. POOH. RIH w/ Dresser Altas Vertilog (csg inspection log). Tool malfunctioned while RIH. POOH. Fix tool. RIH end log out of hole. Change out Hydril bladder. RIH w/ EZ drill cmt ret and set $ 8225' DIL (8243' DPM). Prep to sqz the D-16 sand (8350'- 8360' & 8316'-8328') Sqz the D-16 sand (8350'-8360' & 8316' -8328') w/ 50 sxs cmt, ("G" w/ 3% salt, .75% CFR-2, .2% Haled 24-A). CIP $12:20 a.m. 10/29/83. POOH w/ DP. RIH w/ cmt ret and set $ 8025' DIL (8037' DPM). Sqz the D-14 sand (8134'-8150' DIL) w/ 50 sxs cmt, (same es slurry above). CIP ® 8:18 a.m. POOH w/ DP. RIH w/ cmt ret end set $ 7300' DIL (7310' DPM). Spot 50 sxs cmt (same slurry as above) on top of ret, isolating the D-9 & D-lC sands below cmt ret. POOH w/ DP. RIH w/ cmt ret and set $ 6185 DIL (6190' DPM). Sqz the D-2 sand (6280'-6300' DIL) w/ 80 sxs cmt, (same slurry as above). CIP $ 9:40 p.m. 10/29/83. Circ& cond mud. Circ & spot perf pill (6% KCL, 20 lb/Bbl CeC03 in FIW) across the D-1 sand. POOH w/ DP. RIH w/ csg gun on WL. Unable to get below 5560' WLM. POOH w/ WL. RIH w/ gauge ring & junk basket on WL. Unable to get below 5560' WLM. POOH w/ WL. RIH w/ 12 1/4" bit on DR to 5989' TOL. POOH. RIH w/ WL and perforate the following D-1 intervals w/ 5" csg guns, 120° phasing 8 HRF: 5830'-5870', 5755'-5800', 5690-5735' DIL. RIH w/ guage ring (12") and junk basket to 5700'. POOH w/ WL. PU & RIH w/ Baker Model "KB" perm pkr. Set pkr ® 5569' DIL. POOH w/ WL. RIH w/ pkr seals on DP. Test pkr $ 5555' DPM to 300 psi, (OK). POOH & LD DP. PU BOPE & install DCB spool. Change rams in double gate to 3 1/2". RIH w/ 3 1/2" comp assy. Stab into pkr & test to 300 psi, (OK). UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 18 LEASE ADL 18730 WELL NO. TBUS G-18 DPN FIELD McArthur River DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 51 11/01/83 DAILY COST: ACC COST: AFE AMT: 52 11/02/83 DAILY COSt: ACC COST: 8860' TD 6185' ETD (CMT RET) DIL 13 3/8" C. 6194' 9 5/8" L. 5989-8855' FIW $ 129,980 $2,554,547 $1,960,000 8860' TD 6185' ETD (CMT RET) DIL 13 3/8" C. 6194' 9 5/8" L. 5989-8855' $ 53,788 $2,608,335 Land tbg and locate 2' above pkr. Remove dummy from ball value landing nipple $ 334'. Open "XA" sleeve $ 5527' w/ WL. POOH w/ WL. Displace annulus w/ pkr fluid, (FIW & 1% Nalco 938, 1000 ppm 1153, & 100 ppm 3656). Nip/DN BOP, nip/up tree & test to 5000 psi. RU lub on tree. Displace fluid in tbg to 5527'. Close "XA" sleeve and POOH w/ WL. RU lub w/ HR pressure recorder. Open well for initial clean up. TEST AND EVALUATE THE D-1 SAND REP TABLE BELOW. COMPLETED RESERVOIR TEST $ 2400 MID. RIG DOWN DRESSER ALTAS. RELEASE RIG FROM AFE #331412 $ 2400 HRS 11/2/83. AFE AMT: $1,960,000 .. ~ CORING LOG from '~-~' ~' £HBISTENSE~ BIAI~III~H PIIlII1UUTS Uti. - Home Office: 1937 South 2nd West Mail P.O. Box 387 Salt Lake City, Utah __ii i ' WELL INFORMATION EQUIPMENT PERFORMANCE Company-.fi-Z..4//.¢.Z~. ..... O././. .... C.~.Z~,~.,~..,,~..,.~..... Core Barrel No../,_~_A..//~.._/~._.....~....~'..,,?Z~-~./~. ............ Interval Cored -- Finish_~.,~..~. C o n t r a c to r. ~'~,A/~'.L,~.~'. 49. ~. Z V.~' ................... ~.. S i z e- .~-.~..,.~...~. ............. L e h g t h.. :~. ~..'. [././__~. E:~.~. _./:,,:94~,~_ Start..?.-~..?.~ N u m be r.'~'../~/~ .~. L/./~. ~ ..... .~..Z-.~).Z'..~-..-~./~.[J:l..~.:/~>-' Bit No.~,,.~_..-..~..~.7.~. ....................................... Footage Cored ........ ~....C~..'.'. ..... C o u n t y .('.~J~...l/b',Z~ .,~'. S t a t e....,~..L--:/', j~./~/~.. S~ze.~.~...~ ~ Type../~..C.7._/.~. _~ .............. ..... ~r,, Core Recovery ....... _~.._~ ......... ~,~, / / · Hole Size.~..'..'~. ....... :~.~,...,~'J.~'.....//.~.Z./..--. ........ Previous footage...~-~.__ .................... ~ % Recover / - . .1,.~, ,-" .~ ..... ~" ................................ ~,~ ' 2 .... Format,on Name ...... , .... ._'.~'.."ZT .... ./.J.~./ ........ This core ........... ..~.~. ...... Core No ./.. ~ _~ ~./~ ~ /?,uT' /4U','~/~,/ . t ~ U/';' / ~'~U~.'/Z. "' ' ........... ': ...... - ............. ~; ........ *-..~ .......... ;--. Formation Disc ...... t ............................................ Total footage ..... .~....~.". ............................. ~D..~£X~ ......... Mud- Wt ....... ~'. Vis ~ '7-- --- ~;// / ~X ~ ~ ................. Pump Pressure 7~9~ Linner Siz~,~ ,, ,4/ ,.~ , ................. ~---~-.~- ~ ...... afro K es.._.'~'...~.. ~ !... / -,, NO. /,1 ' (? ~.'l ./j /~,). PENETRATION RATE MINUTES PER FOOT OPERATING CONDITIONS FEET INTERVAL CORE° ~ ? , ;, ,~, ~ ,~. ,.,~ ,0 ,,~,' ~0 ~0 .0 ~o ~0 .0 ~o~0 I I I I I I I I I I I I I I I ! I I I RPM GPM ~ '-~,';' ~ I I I I III I I IIIk ~ "/ ~ I I !1111 I I lily~° ~ ~Y7 d I I IIIII I I III1 '~ f x-ow. 8 ,o~ ~ IIII!! ,, p~- d I I I ! I III}, - , ~ / ,~ J o,~ 'J I I II III I I I II~ " ',::r~ I I I I III I I III1 A " //I III! : II II! '*' '" ~~' '~ /z I I II I1:1 ..... I II I1~ ,, ~ I I !1111 ., ,o ~iL I I l.,,ll I I I1~~ " II I! , '/~~ 3oI I IIIII I I I IF1 ' ~ I I IIIII I I II1~ - - J J JJJJJ II IIll _,~ I I IIIII I II III ~, I I Illll ! I illl ,,,~, -';~. j ._,3 I I I I t TUBE , ,, I IIII I I I1~ (~ '-'~ 46 I ~M ~ '":/'--- ,~ I Ii Ilk · I I I [ U~ " ~ ~ :~. - I I I I1 ; I I Iit ~ora~ x'~ · i1111 ~ ! I IIII1' I II1~ ~8 I i IIIII I I IIII s9 I I i IIII I I I Ilk' ~o . I I IIIII I I ilIH X-OVER SUB \~/ \ 7~,v ~ / \/-,. . SUB OUTER TUBE ..: , .; . . SUB CORING LOG from CHRISTENSENT ill. tM§ li PIIOI1UCTS CO. Home Office: 1937 South 2nd West- Mai! P.O. Box 387 Salt Lake City, Utah J ~' ,L~ "'? L)OTe._..~..~..."_L .... ~,~r.J...,'.~..:__ !_ J WELL INFORMATION C om pon y./~,1/./'61..~ .... O..[/.-, ......~. :~ ~.1.t~'~ _~.~... Co nfra cfa r. '~. ~'~ ~.J~..1,'.'i.~.~'. J.~.. ~. ................... Number :,3. l~.~--~-.~.( .l':c't~.. .... .~.l../?].~.l?~[)./.'?.~....,'~..f o r~ / ' ~ / -'-' t ,~'~ / )' "') :/4 County.~.,.Q.O.l.. .... z,.V..:Z:.l .... Sta e .... ~.,.~,a .~.. Hole c~.. : ~ !~ ~ ~ 6~ C ITl ~L)v - t-~- -~ ....... ~--~ .... ~.~ ............ ~ ...... Formation Name_..~.,....~. ..... .............................. Mu~- wt ...... ~.,..fi: .......... Vi~ ..... :.~ ~' -. ~ .............. EQUIPMENT PERFORMANCE Core BarreJ / / / "- / No..~-._.~../.~.~.-~ ...... ,'~..L~Z1Z.~Z? ......... Interval Cored -- Finish...~.u~..ct~,~ - 3 ~ /~ ~ / ~ -- Start.~.~ Size.~S.~.~. ........... Length..~.../;./.~..~].G~/,~.~ ~ ~ - Bit No..~..=.qY..g~ ..................................... Footage Cored...:~.~ .......... s. -~ i ..... ,: - t o Co~e R,,o~.ry .... ~..~._.( ........ ,ze4.~.~X.~ .............. /ype..i~t_~.Z .............. ~_ .- ~ c Yo Recover ....... ~.~:..x~m ......... Previous footage_,~,..~. ............................. ~ o, ~ / ,/ ./, .o;~_ .~. ~. _ .. ~ ~ i,~//~ /~1~ (Or~ ............. ~,.~ ..... kOr~ ~ ..... ..~ ........................................................ Total ~ 1~ footage ....... ~ .................................................................. Pump Pressure .... L.~.~. ...... bnner S~ze..:.~.~.~:_.:: .... Strokes .... ~.~ ....... '7 tt-i~ r' t!! PENETRATION RATE MINUTES PER FOOT OPERATING CONDITIONS NO. ~ . "'i' ,1 FEET INTERVAL ROTATING FLUID CORED 2 3 4 5 6 7 8 9 10 15 20 30 40 50 60 70 8090 WEIGHT RPM GPM i I i i I i I i I I iii Il i J I : I , , , , , ,,,, ~,,, I ; j ; i ; ; :..- .~; -. 0 :i' / 'J L ? ~ ! , , 3 ,) ..' -F .I ; ~-, , s .'- '2 %. " .J _ " 6 ":., ':f 7 ~).-~ , 9 -'~? , , 10 ~.~-? :4 - ' :.' 1 i 5~ L.I 14 "~ 7 15 "' .~ ; .i · . 17 .¥~ ,. 18 ./.:. ~ 19 ,".-: " 20 '"? .'~ ':: 22 /; ?.' , .,' :2:3 ~,./-. 24 j .,' ;. ? :26 .'~;,o ,~/,; .~j.: .l': 27 28 29 30 31 32 33 34 35 36 37 38 39 40 _ 41 42 43 44 45 46 47 48 49 50 51 52 " -- 53 54 56 57 58 59 -- 60 X-OVER SUB JARS SAFETY JOINT SUB OUTER TUBE SUB OUTER TUBE SUB BIT _ ~ · -- CORING LOG from , UHBISTE' SEi HI t I[iI H Ptl§llUUTS Uti. Hame OffiCe: 1937 South 2nc~ West' Mail P.O. Box 387 Salt Lake City, Utah · __ ............ .' .'....~....,,.. ]...' ............. WELL INFORMATION Formation Name..~.,-zT~.~..:/.?,.~...~Cl.,,.7~~. ................. Formation Disc .................................... Mud - Wt ..... ~....~. ............... Vis...~ ...................... EQUIPMENT PERFORMANCE Core Barrel No ~.:4//cA4/ ~, ~/~ ~.- ......... ................... ~.~_ .... v.,'~, .......... Interval Cored -- Finish Size.. ~ ~ ,~ L+ .Length. ~, C?/ ]-'./,~,~C.~5£ - ~ x ~ .,-- ............................................. ,Start .,'.-:~ .... ;. Bit No..~.!..4/..Z..~...,~..7~ ........... Footage Cored...;. ................... Si z e.. ~./~...~...,~-. ............ Type...~. !.~ - /~ Core /~'~ ...................... Recovery, ......: ............... Previous footage_.~...~___~ ......................... % Recover..::,:..~.:. D' Th sco e £O Core No .... ...... . .... .................................. Total footage ........C~"..Z?.: ....................................... ,.".]~.. ~,~ ~....~.:/[~.: ...................... / ! Pump Pressure._..~..~_!~. ...... Linner Size/_]~:~..~.~. ...... Strokes_.;~.(~ ....... X-OVER SUB JARS SAFETY JOINT SUB OUTER TUBE SUB OUTER TUBE -. : _ . SUB , , BIT . ,. · ,o. ..:; /-.'-:' ,~'~,'~iJ PENETRATION RATE MINUTES PER FOOT OPERATING CONDITIONS FEET INTERVAl. ROTATING FLUID CORED 2 3 4 5 6 7 8 9 10 I$ 20 30 40 50 60 70 8090 WEIGHT RPM GPM 2 .. 6 '~ ' ' 7 'i -,! i-, I 0 "; ................... ..,~ . . 14 16 . 1-7 , 19 ... 20 - .- ." 22 ...... 23 26 ............................................... ,. ............. 28 29 30. .. '."'2,'~ /~.,';' 31 32 .... ' _ . _ 3a 34 ....... - 35 - .- 36 37 .... . , ........ .38 ........ 39 40 41 - 42 .., 43 44 ..... ........... 45 . 46 47 ~8 I ...... 49 50 51 52 54 56 -- 57 -- 58 59 60 CORING LOG from I]HRISTEN§EN .IIlAIII]N'I] PIt[IllUI]TS I][I. Home Office: 1937 South 2nd West WELL INFORMATION Company..(../,(,,.//~.,~.......~./..Z... .... .~'.~z.".)')..~.,:.~. Contr actor.';~:~."~ ~'..~.~ .1,./..,~...~. t'./,/~. ............... ~:... C o u nty('/,~.D./,5'../...~...Z...~. ~...... Sta te. ' . D..L./..,.Sj.ff/.~.. Hole Size I .,.'..'.~..../~. z.! J.. ................. H.P.&.,~ ........ Forma.on Nome..:~:/~:._~..F: .... ?~O'~:.E' ......... Formation Disc ................................................... Mua-wt ..... ..7......~ ............... Vis. 3:._~. ................ Mail P.O. Box 387 Salt Lake City, Utah EQUIPMENT PERFORMANCE Size Bit No.; ...... .................... : ....... Footage Cored..~. ............... ¥~ Recover .... ~_ ..... .~. ..... ~ .......... Pump Pressure .(~.~_. ...Linnet Size.,_.~.¥.~ ...... Strokes..~.j ......... NO. ~ (.~ ° ~ O )~ PENETRATION RATE MINUTES PER FOOT OPERATING CONDITIONS FEET INTERVAL ' ROTATING FLUID CORED it 2 3 4 $ 6 7 8 9 10 15 20 30 40 $0 60 70 8090 WEIGHT RPM GPM I I I I II Il ~ .~ .:~ :1 I I F':~ -": -:'n " 4 ,o ~ ~/~ 'i III ,, ,¢ ,= .~o, IIF. 2o .~ -~., 2. ~ :; · , f 22 , ,. 26 .~ ? J ) 2Z z g 'l. . _ 28 ':.-q. I ,, III 33 34 · ~ !11 ~z III ~¢ III ~o II! ~ III ~= III - ~ Ill l ,~ I1, ~0 I1~ ~, I1~ ~ Iit ~s~ llk ~o Ilk ~ X-OVER SUB JARS 't SAFETY JOINT SUB OUTER TUBE f SUB OUTER TUBE : ' / SUB BIT .~: ~-.;!:-::-.-:_-::~i CORING LOG from I]HBI STI] Si] ' .BI/IM § PII flliU I]TS Eft. Home Office: ! 937 South 2nd West C~--z"c~,'~,'~/] Mail P.O. Box 387 Salt Lake City, Utah Date_.,~-..~.,..: ........ .--../.i...:... ~.:._- WELL INFORMATION C o m p a n y. '.'/. ~'~./.~ ~..... ~.. Z./....~l:~,.q.'],,:.~?.,/. ~./.~.~ ....... Co n t r a c t o r :':~2/tZ,~,C'.~.t,: ~.T. !.(./~. ........................ Number..~.,. ~'.b.)../,..//.~. ]. ,:¢(. ~. .... /.~.~ 7..~.0. n/..~.1.'...~T./.,;. County' .~,-~..,Z..~.... [.f.' .~.~..~.. ~ ......... ,State .,'; ;..z ~,~.,:.r. t ........ · '~ ~ ~'-~- ./~,~,~..,~.c.)~.~ .............. Hole S~ze:~..:_~r ..... c,-~--- Formation N am e....-~...,r. ~.,..,-~.. .... ~-4-~ ................. / /ut'~ / /~ ~'~-~Z Formation Disc ................................................... Mud - Wt...L. .... ~"~ ................. Vis ......................... EQUIPMENT PERFORMANCE k,~ I ~,~//0,~/ ..~/~//Z~-~) Interval Cored Finish:;' ~' '3~ Core Barrel ,,u.~:.: .....,: ..... ~.~ ..... <.c~.~ .............. :-. -- ........ / ~ . ;.~..L.~.,~4~: ~., ~.,' -- Start;~.~.~. Size,z~.~ ................ Length ~ Bit No..~ ~E Z~ ~ Footage Cored ~ / ..... Z..d ........... Si z e..:~ ~Z.~..':~... ............ Type..,¢_.~..z..~ ............... o~R ~' '] ~ Yo Keco e ..... ~._~..~..~ ........... Previous footage.:C]. ........................... This core ............ Z0.~ .... Core No.~.~ ....... '~,~ .,~ . Total footage .....~_j ................................ : ...................~- .- Z~/-~ .................... ' .~z..:~6..t~[T ..... trokes~J ............ Pump rressure=: ................ Linner S~ze : S NO. ~' '~t ~ i: ,~'/~ i PENETRATION RATE MINUTES PER FOOT OPERATING CONDITIONS ROTATING FLUID CORED 2 3 4 $ 6 7 8 9 10 I$ 20 30 40 50 60 70 8090 WEIGHT RPM GPM / 6 .f. ~ .. 4 14 ' "~ . 25 .......... , , 3o ,4, 7,9? '.~ 32 33 34 ...... ; 35 36 37 ~ 38 39 ~0 ~2 ~3 44 46 47 ~8 49 ~0 51 52 54 57 58 59 60 ~ X-OVER SUB JARS t SAFETY JOINT / SUB OUTER TUBE -- . - / SUB OUTER TUBE · -~~ SUB .~____ BIT e WELL INFORMATION Com pan y...".~!../~./...~..4/, i... ~/...6. .... ~....~.rj!..~../!./.~.'.';.~. .... Contr actor ~ :~ ..~.:~m.,~',x.~. ~-/4. ~-/. ~ -/.'~. - .............. ...~:-. County !~;~(~¥.[.A../.Z: .~.?. .......State..;;'!/..-~'. ]?..O.~.J. }'. ./'. !.. I ~ . · ! ,< .."m l,./, -- Hole ..... ......... Formation Name .... .-~..,,..,c.l,.,:..~.....L0?:L/.'....,~.. ......... ,.. / /U/ ; i// .... "- Formation u,sc ................ : .................................. M, -wt .... .............. ................. CORING LOG from cun S T , sr, 'n ann n pnnn'U[:TS [:§. Hame Office: 1937 South 2nd West Mail P.O. Box 387 Salt Lake City, Utah ~ ~ -~~~~ Date ..~ ~/~.. ;~ ~ .~.~:~.~.. EQUIPMENT PERFORMANCE Core Barrel No..'~.~.~.~.~. .... ~.~.//?j~ ....... Interval Cored -- Finish.~.~/~ *~ / ~ ~ - ~.~ Size.. ~ ~ ~ Len th ~6 t~,',~/'~'Z//~-~ ~ ~ ..... ~ .................... g ........................... Start :~_.~.~.u. Bit No. 3 ~z~..?..~..7..~.~ ................... Footage Co~ed.._,,..7...~ Size..:~-~.j(.~ ............. Type...~]?.~Z...~. ....... ~... Core Recovery .... ~.~,...~ ....... Previous footage_.L':~ ............................. % Recover ...... :~j~:...r:..~ ...... Thi r 'k 7 ~ ,, ,-' ~Jlfll~ /~../7~ ~?. ~-J ~ ~ ~ ~ s co e ............... : ...... ,.~ore mo .... ~.~. ........................................... Total footage .... ~..~ .....(.Z/:(/.jT_...~Z~../_ ............. ~_~_:.J ..../J,~. ........................ ~. ~'-~ /~ - . Z'~ Pump Pressure._~.~ ......... Linnet b~ze..~_;~.~._~.:~ ......5troxes.__L?.:4 ....... /'~/;~ NO.. ~, ~/ PENETRATION RATE MINUTES PER FOOT OPERATING CONDITIONS FEET INTERVAL ROTATING FLUID CORED 2 3 4 $ 6 7 8 9 10 I$ 20 30 40 50 60 70 8090 WEIGHT RPM GPM o I J , ~ , iJ Ill ~,,, .... J J i t I .... I '"' , ' "; ~ 3 4 6 7 8 - 10 - 11 12 I 13 ' - 15 20 21 25 28 ~' .~' 6/~:~ 29 30 31 32 - 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 ~ X-OVER SUB JARS t SAFETY JOINT SUB OUTER TUBE i SUB OUTER TUBE f SUB ~,, BIT ' ~ ~ r CORING LOG from Home Office: 1937-South 2nd West Mail P.O. Box 387 Salt Lake City, Utah IJate .~...~. ~., ~..,~-~.U./.. :.. j-~, ~..... WELL INFORMATION EQUIPMENT PERFORMANCE ~ ~ /' x' ,-" , .:,, ; ,,? .? - Company.c~.X1//!..~... .... .~.... (.~.....~'.~,'..~.l.-~-/~.~.'.~'//~ Core Barrel No..~.~...~.~:~-:.~ ........ Interval Cored -- Finish._:.~-..~ Co n t r a cto r)~~'~. ~.~.L ~.~ ........... ~ ' ~ ~ S,ze.~...~..~.2~ .......... Length_~'.,~...~:.,'.~.~Zp~ 7~ -- Start.:,:~.~ N,mb,r',~./Lg]~.Lt~46...~.~.~~~/;~ i ', '~ ~'~ ' ~ ~ ' B t No.~...'~.~.~../..~k..~ ................................. Footage Cored ..... ~.~..~ ........ ~ ~ / '~'~ 't re/'~ " - ~ ~ County.~.~..~.,~.,~ ..... S a .... Z-~)~.~. Size.~ ~ ~ .._Type../.~_~._~ .... ~.~.: Core Recovery~..~...~ ........ Hole Size./~.~ .... ~.~../:~.~ ........ Previous footage.~.~ ............................. ~ .... % Recover ..... ~,.~..~ .......... ~ '- '~ /// - core Formation Name:./.fG.;.~./ ...... 7' ~'~4~' ...... This ............... .. . ................ ~.,_, .... LX.~C/.L,~.6.. ............ ~-~,~ c ~ ' ~':~/~ ~/F) t..~...F.~,..~( ........... Formation Disc ................................................... Total ..... Mud- Wt .... /.,..:) ................ v,s ....................... Pump Pressure .... ~_-~ .......Linnet Size~2.~.:~..]~_...Strokes...~.[~. ..... NO. .~.~.. ,_) i,~ ~/~,~i PENETRATION RATE MINUTES PER FOOT OPERATING CONDITIONS FEET INTERVAL ROTATING FLUID CORED 2 3 4 $ 6 7 8 9 10 IS 20 30 40 $0 60 70 8090 WEIGHT RPM GPM ' "~, '? _ ----.i_l:J :" ''~ ..~.._,:.', c, 3 .,"~ ,.-7 .: ~ ,"z ~.!! I I e //4 -. .- III " '" II1 12 /"'~ ~13 ,":')' ~6 -7 7- 17' ": ~ 18 "7 -/~ 19 "~ "' 'J 20 .- ,~ _~ ~,-, .'-I 21 '/~ ., 22 '; ~x. ......, 23 '~ '-"/ ;' .,,~ 26 ? ) 27 '~ ~ · 28 ~' .L/ · 30 ,:., .:3 k.:)::,.,1fi., 31 32 33 35 :36 ~- - 47 , _. · · ' ~ X-OVER I sub JARS ~L SAFETY t JOINT f SUB " ,, OUTER TUBE ~ . OUTER TUBE ..- '[ SUB BIT -. 30. D-1 SAND PERFS ~ 5830-5870', 5},~---5800, 5690-5735' DIL, AVERAGE I.,~ERVOIR PRESSURE + 1586 ,~. PSIA -- 'Clean Up Flow Test 1 Test 2 Test 3 Test 4 Wellhead Average Pressure BHFP Test Time Q(MMSCFPD) (BWPD) (PSIA) (PSIA) (HRS) 11.588 68.0 893 1478 6.0 2.975 4.8 1382 1563 1.0 6.074 0 1318 1538 1.0 ~ ECE / rED 9.329 0 iiso 1507 i.o 12.506 4.8 942 1466 3.0 ~/ NOTE: ALL BHFP ARE RECORDED F/ HEWLETT PACKARD SURFACX5 READOUT 4,l~k~ RECORDER, LOCATED ~ 5770' DIL. 4122' VD. ' D-2 SAND TEST PACKER 6230' DIL (4390' VD) TEST RERFS 6280'-6300' DIL (4420'-4432' VD) AVERAGE RESERVOIR PRESSURE + 1755 PSIA PRESSURE TEST AVERAGE WELLHEAD BHFP TIME Q MMSCFPD ..BWPD PSIA PSIA (HRS) TEST #1 10.518 42 . 1155 159---~ 1-75 (Clean Up) TEST #2 2.861 0 1285 1732 1.0 TEST #3 5.398 0 1328 1691 1.0 TEST #4 8.071 0 1405 1635 1.25 TEST #5 11.643 0 1327 1582 2.25 //*NOTE: ALL BHFP ARE RECORDED F/HEWLETT PACKARD SURFACE READOUT RECORDER, LOCATED IN TBG TAIL ~ 6250' DIL (4402' VD). NO CORRECTION WAS MADE TO AD3UST PRESSURES TO DATUM. D-14 SAND TEST PACKER 8078' DIL (5731' VD) TEST PERFS 8134'-8150' DIL (5780'-5796' VD) AVERAGE RESERVOIR PRESSURE + 2640 PSIA PRESSURE TEST- AVERAGE WELLHEAD BHFP TIME Q MMSCFPD BWPD PSIA PSIA (HRS) TEST #1 4.548 9.6 1940 2428 1.5 TEST #2 1.125 0 2202 2599 1.0 TEST #3 2.245 0 2122 2569 1.0 TEST #4 3.500 0 2061 2517 1.0 TEST #5 5.545 4.3 1992 2399 4.5 · *NOTE: ALL BHFP ARE RECORDED F/HEWLETT PACKARD SURFACE READOUT RECORDER, LOCATED IN T8G TAIL ~ 8114' DIL (5763' VD). NO CORRECTION WAS MADE TO ADOUST PRESSURES TO DATUM. D-16 SAND - ISOCHRONAL PRODUCTION TEST DATA.. TEST PACKER SET @ 8251 DIL TEST PERFS 8316-8328 DIL (5946-5958 TVD) 8350-8360 DIL (5967-5977 TVD) TEST #1 TEST #2 TEST #3 TEST #4 TEST #5 WELLHEAD AVERAGE PRESSURE Q (GAS) MMCFD BWPD PSIA 6.721 84 1909 1.653 106 2198 3.270 120 2076 4.951 0 2043 7.0-7.7 91.2 1953 TEST BHFP- TIME PSIA (HRS) 2484 1 2634 1 2611 1 2587 1 2411-2433 2~5 (RATE VARIABLE CHOKE CUT OUT) TEST #6 6.5 1.3 2014 2463 3.5 *NOTE: ALL BHFP ARE RECORDED F/HEWLETT PACKARD SURFACE READOUT RECORDER LOCATED IN TBG TAIL ~ 8275' DIL. NO CORRECTION MADE FOR DATUM. Eastman/ Whipstock l A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TIONA L SURVEY R. C. Warthen ~OV 2 2 19~3 UNION OIL COMPANY COMPANY G-~8 WELL NAME MacArthur River Field, Cook Inlet LOCATION JOB NUMBER A1083G0215 TYPE OF SURVEY Gyro Multi-Shot SURVEY BY W. Coram Gas Cons, Alaska DATE 12-Oct-83 Eastman Wh s tq c k /' ii: / (907) 563-3650 P. O. Box 4-1970/Anchorage, Alaska 99509-1970 October 12, 1983 UNION OIL COMPANY P 0 Box 6247 Anchorage, AK 99502 Well Number: G-18, Leg 2, Slot No: 42 Location: MacArthur River Field, Cook Inlet, Alaska Type of Survey: Gyro Multi-Shot Date: 06-October-83 Method of Calculation: Radius of Curvature/Average Angle/Tangential Surveyor: W. Coram Job Number: A1083G0215 Attention: Mr. Jim Callender Dear Mr. Callender, We are enclosing the original and twelve copies of the Gyro Multi- Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and we trust that we may continue to serve your needs in the future. ly, ~/ Tom Jon'~~~ Distric~chnical Coordinator TJ/db cc: file Enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide SURVEY CERTIFICATION SHEET Surveyed from a depth of O Well# G'-//e State feet to a depth of ~//~ feet. Type of Survey ~///-~ Directional Supervisor/Surveyor_. The data for this survey and the calculations for this survey were obtained and performed by me according to the standards and procedures as set forth by Eastman Whipstock, Inc. and are true and correct to the best of my knowledge. ~/~~ '//~-} ~/~y~ Directional S u p e r v iT.r.//S u rv~y or The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Eastman Whipstock, Inc. This report represents a true and correct Directional Survey of this well based on the original data obtained at the well site. Original Copy - District Office File One copy to Houston Office D-1121 SURVEY CERTIFICATION SHEET Company ~/A/~-~>/4 (~T~ ~-o~.~v~/ Job#~}/~83~ml/~-Date Leasel'~A~LT~u~ /~E~ ~c~ Well~ ~-/~ State Surveyed from a depth of ~oo o feet to a depth of ~~ feet. Type of Survey . ~~ o yc ~~ ~ J'~~~~ Directional Supervisor/Surveyor ~~ The data for this survey and the calculations for this survey were obtained and performed by me according to the standards and procedures as set forth by Eastman Whipstock, Inc. and are true and correct to the best of my knowledge. Di rectl onal S u pe rv ~ s o r/~-r<vey or The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Eastman Whipstock, Inc. This report represents a true and correct Directional Survey of this well based on the original data obtained at the well site. Original Copy - District Office File One copy to. Houston Office D-1121 I..IN ! ON el! L COMPANY L E G .2, '.--:1 .... FIT 4 '.--", N E L L N 0: G- 1 ,_,o G I'1'._--: / G H :--: , .... ICl B N n: I-~ 0 2(] 7 / ~ 1. 0:--::3 F~ 0 2 ] 5 ORAYLING F'LTFM, TBU, MACARTHLIR RIVER FIELD, L-:l-lnl-::.' TNLET, ALA:--:I-:.'.'A GMS, O-/:,:!.c~r~ MD, '.:;LIRVEYOR: D PEF'FERKORN, D~TE RI IN: ]. ,:, - ._-, E F - ,:, .:, GYRO NO: .305, CAMERA NO: 16/_-.6, ?0 DEG A/IJ NO: 1566 GM'S, /_-.00C)-8750 MD, SLIRVEYOR: W, CORAM, DATE RUN: 06-Fz,Z:T-8:3 FORE'.3IIgHT: DOLLY VARDEN S16 50W SURVEY TAKEN FROM ROTARY TABLE VERT I CAL F-;ECTION CALCULATED:' I N PLANE OF '-'r"FIr"Fl'-'"'"' ': r I~. I' ....-..,l"tg. D.T. REL. T]'LN: N 77 DEG, 0 MIN E .. RECORD OF '.:;URVEY RADII_IS OF' CURVATURE METHOD .IN I ON F-~ I L COMF'ANY _EG 2, SLOT 42, WELL NO: G-18 GMS/GMS ,JOB NO: GC)207/AIF):::::-:GC)'-:.'15 3RAYLING PLTFM, TBU, MACARTHUR RIVER FIELD, COOK INI_ET, ALA'.:;KA COMF'UTAT I ON T I ME DATE 1/=,: (]) 7: 3'? 07- 0 C T - :E: ::: F'AGE NFl.. .1 TRUE qEASURED DRIFT .RIFT COURSE VERTICAl_ VERTICAL SUBSEA R E C T A N G U L A R C L. 0 S LI R E DOGL~.G DEP]'H ANGLE DIRECTI fin LENGTH DEPTH SECTION 'FVD C O 0 R D I N A T E :--: [II.:.TAN'-' F'_.E DIRECTIfIN SEVERIT FEET D M D FEET FEET FEEl' FEET FEET FEET D M £:G/100F C). (':,0 (") (:). F). (')(') 0.00 -1 i. 0./_-. C) 0.00 0. ()C) 100. 0 15 S 25 W 10(:~. 10(:). 00 - 0. 1:3 - 10./.,0 0.20 '.:; 0.0'.=; W 15 ('). 0 15 '.=; 6 W 5 O. 15 ('). C) c') - 0.24 :3'.::v. 4 (') 0. '1.1 F; 0. 15 1.4 20 O,. 0 1 ~ ':' 5 W 50 '='0¢) 00 -. 0 .:. 1 '-'"'~ ........ :,.-=.4.0 0.62 o O, 17 W '.--. '50. ~] 15 S 9 W 50. '.':. '50. o 0 -.('). :--:8 1 :T=:9.4~') ('). 84 '.=: F). 20 W :2:00. 0 .'=:_ 0 ._.':-' 9. W .~. ¢). . :300 .00 - 0 . .:; .... 0 1 .':-: 9 .4. 0 1 . 16 ¢'.., 0. .-._,'-' :' W :=:50. 0:30 '.S 1.9 14 50. :35('). 00 -(:). 7 C) 2:3.9.40 1.59 F; 0. :':45 IAI 400. 0 30 '..=.; 14 W 50. 399.99 -.0.92 289. :39 2.00 S 0.4.8 W 450. 0 ::-:0 S 2 W 50. 449.99 -1.07 :=: :;',": 9 ., 3'.-T~2.44 S 0.54 W 500. 0:30 S 0 E 50. 49'F;. '.-.'¢ 9 - 1.18 :38 ?;. 39 2.87 S 0.55 W 0.00 0 0 0.22 S 25 0 W 0.43 S 20 15 W 0./.,.5 S 15 19 W 0.86 S 1:':: 13 W 1.19. S 12 4 W 1.6:3 L:; 12:35 W ,.'.'" 0/., S 1 :--: ":',..._.'=i W 2.49 S 12 28 W 2.92 S 10 4/., W 0.00 0...'::,~ 0.17 0.01 F). 0:_:: C)( -) 0.17 0.0'.:; 0.21 0.03 ._,._,(.). 0 15 6 E ..,0 '=-'~'"' 99 n ._1'"t' .':" . . . /=,(:)('). 0 4.5 N 7'.--; E F, ,~ ..... .. 0... .~ ,=; c¢. 9'.-"; 650. :=: 4.5 N 7:2 E =' · _,0, .:. 64'F,'. 94 '700· ,..'=' 1.5 N 75 E ..0. ... ,,.. 7~(';,_.. 12 r). N 74 E 5,(:) . 74:_.: . ,=,'"'7 3.24 S 9 23 W 0.51 :2:. 44 ::; :2:37 W 1./.,2 2.:_::9 S 29 47 E 6.01 6.85 S 77 44 E 9.02 15.19 N :36 38 E 7.5:!· :::00. 1.3 15 N 6:-_-: E 5C). 797./.,/., 850. 13 0 N 59 E 50. 846.35 ".:;C~0. 12 15 N 58 E 5c). F=:'.--;5. 14 950. 1:3 45 N 58 E 50. 943.86 1000. 14 45 N 57 E 5(:). 9.92.32 1050. 16 15 N 60 E 50.. 1040.50 1100. 17 15 N /.,0 E 50. 10:::8.:38 1150. 18 15 N 61 E 50. 1136.00 ..,..... 1200. 20 0 N 62 E . .~";0.. 1183.24 1250. 21 45 N /.,2 E 50. 1229,). 95 ":-.'.~ 7/., /.,,:,7.0/., 3/_-,. ,,'2,8 7:315.75 47.04 784.54 57.67 8:2::'=:. 26 69.27 881.72 4,89 N 25.31 E 25.78 N 7.9 4 E lc).40 N 35.24 E 36.74 N 73 34 E 16.1.1. N 44.5/., E 47.28 N 70 8 E 22.0,7 N 54,. 10 E 58.42 N /:,7.47.' E 2:::./.,8 N /_-,4.4.::: E 70.5'7 N /.,/., 1 E ':' 1 '74 92'9 9c') "" = /.,6 · .. .. . .:,...i. N 95.72 977.78 42.8/., N 110.34 1025.4.0 50. :=:'7 N 126.12 1072./-,4 58.19 N 14. 3 '::":' 1119 '-' :' =; :' ....... :,._, /..6. N . . i ..,. 75.87 E 83.83 N 64 50 E 88.35 HE '.:;8.20 N 4,4 7 E 1(2)1.61 E 113.41 N 6:3 3:3 E 116.(2) 1 E 129.7:E: N 63 22 E 1:1_:1.74 E 147.59 N /-,3 12 E 5.41 . ,"', ,~ I .5/=, 3.40 2.00 2.09 c, F']/-, ....... 1300. 1350. 14oo· 1450, 1500. 23 0 N 62 E 50. 25 0 N 61 E 50. 26 30 hi 61 E 50. 28 15 N 61 E 50. 29 45 N /.,1 E 50. 1276.19 161.7:2 i 1/., 5..5'.=; :;...... 7...49 N 148 54 E 166.62 N /.,:2: 4 E 1321 · 8/., 181 · 31 1211 .'2~, 8.~''l. 19 N 1/.,6.42 E 186.95 N 62 54 E 1 '-' / '-' ~:' ':; '::'; ":' '=' ':'~ '":' Fi ':' · :1 ~-?'/.l. 9. (3..'Z.:. 02, .1l~I'~I. 1 ,":'.' 6. '30 ,' '." 7~'l hi 1 ..... . 4.1 E .....'.I ·/.' 6, N 62 42 E 1411 '" F '"':' . 2':) :'::: 0 c'). 70 06 '..' 0 :-~ ,'q':' ' . .:, .) z.=4 .... 1. . 1 .87 N ......... = E 2:2:1 .64 N /",Z ._'::':'... E 145.5.02 247.59 ].344.42 118.62 N 22/.,.72 E 255.88 N /.,2 2:2: E 2.50 4.08 3.00 3.5(3 3.00 NION OIL C:F~MF'ANY EG 2. SLOT 42., WELL. NO: G-18 GMS/GMS ,_lOB NO: G0207/A10:E:3G0215 RAYL. ING PLTFM, TBU. MAC:ARTHUR RIVER FIELD, COOK INLET, AI_.A'.E;KA COMPUTAT I ON T I ME DATE 16: 07: :39 07-0C'T-83 PAGE NO. 2 TRUE ,EASURED DRIFT DRIFT COURSE VERTICAL VERTIC:AL SUBSEA R E C: T A N G U L A R C L 0 S I_1R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIREE:TION SEVERIT~ FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100F' 1550. 31 45 N 62 E 1600. :2::2:45 N 62 E 1650. 35 45 N 62 E 1700. :2:8 0 N 63 E 1750. 4(:) 15 N 64 E 1800. 42 45 N 64 E 1850. 45 0 N 6:} E 1900. 46 4.5 N 63 E 1 ':..-~ 50. 49 15 PI /:.:3 E 2000. 50 0 N 64 E .~ r~ 1497 9'--~ 272 '-"'-' '--' 's'--~ 19 E '--.':2:1 44 N /-,'--.' 1 ::: E 4.13 ........ ~..~, 1:387. :39 1:2:0.81 N ... - ... ..... 50. 1540.04 2':'.~:2:. :2:5 1. 429.44 14.:3.51 N 27:2:. 07 E 302',. 4.:2: N 62 17 E 4. ('~(') 50. 15:'-": 1.12 325.8::,' 1470.5:2 156. :'-':'2 N 2'F~8.2:3 E :336. '.;~8 N 62 15 E 4.00 50. 1621 12 3.=;4- 9 ::: 1510..=~ ~' 17 r). 74 N :324 c, 4 E 36/-, 9 F: N /-, ? 1/:, E 4 66 50, :1.659, ?0 :385,/:,0 1547, 30 184, :_::2 N 353,08 E 3'?8, 52 N ./:,2 2:.2 E 4,/_-,7 50. 1697. :::5 5(]). ]. 7:33.39 50. 1768.20 5r). 1801.65 50. 1 :B3z~. £)4. 417.8::: 1586.75 451.58 1622.79 4,86.40 1657./:,0 ._.:; ...~.".' '-.'. 45 1691 . (')..--q. 559.4.9 1723.4-,.]. 19':7.34 N 3:2:2.85 E 214.81 N 41:2:. 86 E · ~ :--.:4. 2:2:1 1. ,:'~ N 4..4._. E 24.7.97 I',1 478.94 E 2.64. 'F.~/.-, N 513, 03 E 4:::1.64 N 62:2:0 E 466.29 N 62 34 E 502.18 N /:.2:2:6 E · ~:~:'-.-~. "-"'-~ N /"---' :--::E: E 577,,4.1. N 62 4.1 E 4. '71 3.50 5.00 2.1.4 2o50. 51 0 N 6:3 E 2100. 51 15 N 63 E 2150. 51 15 N 6:_:: E 2200. 51 30 PI 64 E 2250. 51. 45 , N /:,4 E 50. :' 1:_:65,,85 597"00 1755.25 282.18 N 547.56 E 50 1897.2'.'_-:, 634 ', 7'?' ' 1786,/.':,:-_-:' 299. ;':':5 N 5:--:'.'._", 24. E 50.: 1928.52 67:2.61 1:.-.':17.9:2 317.55 N 616.':."~:-': E 50.: 1'?:59,7:2: 710.5~ : 1849.13: 334-.98 N :651.?~4 EE ' : , ~c~ :199¢) 77 ': 748.78 1":'"¢ ....... ~.'-' ........ = ,=, )" 17 .$.5 :Z. 16 N :,,::, 7.1 '7 E 2300. .~l:2.' 0 hi 64. E 2350. 51 45 N 65 E 2400. 52 15 N 65 E 2450. 52 0 N 66 E 2500. 52 0 N 66 E 2550. 52 30 N 67 E '2600. 52 45 N 67 E 2650. 52 .1,5 N 67 E ........ ,~7(.0,52:30 N 67 E 2750. 52 0 N 68 E 50. 2£)21.64 787..1. 1 1911.04 ?] .... :'(] ~'-' 5 ':'":' =' '-'-"; ':.'-~ 4 .... (.). ~...._ .,-::, .. i .., ,.-.._, ..... I I I. 91 50. 2083,, 30. :--:64., 04 1972.7C) 50. 211:3. ?'2 902.7:2 200:3. :--: 9 ~ (") 2144 7'z' 94.1 4. 0 9 (-):z: 4 1 ':' 50. 21 '75.3'2 9 80. 2 '7 2064.79 p'] (") ":,'-.,ri':9 ,. . . '" (""' =' ..... ~..._ ...... 74, 1019 4, (") ,.'., .-.,._, ,, 14 50. :22:3/:.. 18 1058.46 :2.1. 25. 50. :2:'.'.. ' 66,70 1097.46 215/:.,. 10 !90. 2297.31 1136.45 2.1. 86.71 :369.' 4.1 hi 722 . ":;._ ._,":' E 386. :34 N 758. (3:3 E 4(')2.99 Pi 79:2:. 7:2: E 417. :36 N 82':.'/.65 E 4. :35.38 N 865.64 E :E':11.48 N 62 55 E 0,50 850.80 Iq 6:3 0 E 1.65 8'.-.-~ (). 18 hi 63 5 E 1. (') 0 9:29.61 N 6:3 11 E 1.66 ,:~/.c, 97 PI 6.3 I':'E,_, OF' "~ 45.1,. 15 N 901,9() E 100:3.44 N 6:3 26 E 4.66.67 N 9:38.47 E 1C)4.8.10 N 6:3 34 E 4-8:2.1'7 PI '274.9'? E 1087.70 N 6:3 41 E 497./_-,4 N 1011,,44 E 1127.24 N 63 48 E 512.77 N 1047.'76 E 116/_-,.69 N 6:3 56 E 1. :::7 0.50 1,00 0.50 1. :.--.:7 L,.,2800 51 45 N 6,8 E ' 2850. 51 15 N 6,8 E 2900. 51 0 N 68 E · .,1 1.,:, N 68 E . 300C). 51 30 N 68 E 50. 2:328.18 1175. :30 2217.58 ~ ('). '-' '-' ~"-' 3. '- ~' . . ~.:,._, .'... :31 121 ;~._, 2248 ,,'71 · .50. 2:2:Sr0.69 1252.40 2:2F:0.09 ~ .... C~. z. 4.~ Z. 07 1290.84 '"¢.,=,'-' ~ I. 4. 7 5£) ~"~ ~":' 2° 2342 . ~.- .......... 132:9 ,, 4,2 ..... 527.51 PI 1084.4,3 E 1205.93 I',1 64 4. E 542.17 I',1 1120.71 E 1244.97 N /,4 11 E 556.75 N 11..9;6.80 E 12.:=::3.81 hi 64. 18 E 571.3:3 N 11'22.:37, E 1322./::,5 N 64 25 E 585.96 N 122'.'-/.11 E" 1361.64 N 64 31 E (). 50 1.00 0.54) 0 ,, 5(:) 0.50 NION OIL COMPANY EG ..], SLOT 4. 22, WELL NO: G-18 GM:Z:/GMS .JOB NO: GO207/A10822:G0215 RAYLING PLTFM, TBU, MACARTHLIR RIVER FIELD, F:OOK INLET, ALASKA COMPUTAT I ON TIME DATE 16: 07: :2:9 07-0CT-823 PAGE NO. · 3 TRUE IEAS;I_IRED I]RIFT DRIFT COURSE VERTICAL VFRTICAL .'_--;UB.'E:EA R E 62 T A N G U L A R C L 0 '.--_: LI R E DOGLEG DEF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT' FEET D M D FEET FEET FEET FEET FEET FEET TI M DG/100F' 23C) 50. 51:2:0 N 70 E 23100. 51 45 N 70 E 3150. 52 0 N 70 E :2:200. 52 2220 N 70 E 3250. 52 45 N 71 E 322200. 53 0 N 71 E 232225c). 53 15 N 71 E :2:4 0 o. ":...,.'-'=, 0 N 71 E 234!:=N.'). 53 0 N 72 E :.:: .=; (.) (] 71 c, 1.5 N 7:2: E 3550. 53 15 N 7:2: E 3 6 0C). 252 45 N 73 E 23650. 52:3(") N 75 E :3700. 52 15 N 75 E :2:750. 53 0 N 75 E 50. 2484.4.1 122262E:. 17 2:37222. 81 50. 2.515. 45 1407. C. xE: 2404.84 50. 2546. :2:1 ! 446. 12 2435.71 5 (] '-' ~'- 4 o =i '=' · .' ..,., 76. ':.):=: 1_.,_,., 2466 32 mm . -- mm -_~-o,. · 50. 2607.2:2: 1524· :=3:3 24'.-.76. 6:3 50. 2637.45 156,4.. 48 2526.85 50. 2667.4.6 1604.2.']6 2556.86 (-) 2697 46 1/-,44.04 '"'~"-'/ ,c:6 . , , _ ..' ._l ,L':, ..'., u - !:9 ("). 2 '72 '7. ~ ~-- · 7 :=: . rY._, ...... , 168:2: 2616 '- = '-' ~- . _ _ 7..:..:,, 66 2/-,4/-,. 96 50, .-..7._ 7 .=;/-, 1 ..... ' .... 5'79.'...,-,8 N 1265.64 E 140c).65 N 64 3:3 E 613.39 N 1302.4.:=: E 143'?.623 N 64 47 E 6':.-']6.84 N 1339.4.4 E 1478. :E26 N 64 55 E 640. :=: 6 N 12227 6.5'F/ E 1518.24 N /=. 5 3 E 653.63 N 1414.c)4 E 1557.80 N 65 12 E 3. 1222 0.50 0.50 1.00 1.67 666.61 N 14.51.74 E 1597.47 N 65 2c) E 0 67'?.623 N 142-=:';?.55 E 1/=.:=27.27 N /=.5 2:=: E 0.5C) /=,'.-.? 2. / ~ ........ :,._, N 15 2 7 :E: 7 E 1/=,7 7 7(.')5.32 N 1565.24 E 1716.81 N /=,5 45 E 1.60 -:,o E 17._,=,.54 N /-,.5 54 E 1 /_o 717.._,...'=' Fi N 16 C). :::_. ..... _ . _ .... 50' '~ .¢.7,_,7.47 1 7 ":,.=, ~ ~. .'"6 76 ,3 7 '-"- . · ..., ,_, - /..', · ~'-~ ...., . , · . 7.$:-'~.06 N 1641 6 9 E 1796.23c2) N 6 6 :2: E , 50,' 2817.56 1803;46 2706'.96 740.74"N' 167':.}.88 E 1835.94 N 66 12 E 50. 284'7.92 184:3. 13 2737,,32 751.69 N 1718.08 E 1875.322 N 66 22 E .~]o 2878,44 1'-''''°,=,,:,=.7 1"-~7/.-.7 84 761 .94 N 17._,6~ c,c, E 1914 48 N 66 o.--.'-'" E o- -- m m · .., ._i ~ M ............ 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",'" ~', .=,.=, 74, 4. 6 ':,.~in,-? 9 .1. :=:';.'.'/-, 2 ,:, 6 ,:,'-":.:~.=,' 11 N .~ .=,' ,.:,/- ':¢; 7 4 E o.~ c,.-., 4. ~ N 69 ":' 1 E 1 0 0 ... · d2.. ,- -..- .. · .... . . · n # ~ ,_ ..I,d~ n .- d~, m UNION f]IL Cr]MPANY LE:G 2., SL..OT 42., WELL NO: G-l:=: GM.S/GMS ,JOB NO: G(:)2C)7/A1C):=::=:GC)215 GRAYLIFI,} F'L..TFM, TBU, MACARTHUR RIVER FIELD, COOK IFILE]', ALASKA C:OMF'UTAT I ON T I ME DATE 16: (}7: :]'9 c)7-.0CT-:-=,'3 PAGE !',10. · 4 , - TRUE ' MEA'.E;URED DRIFT 1]RIFT COUR::;E VERTICAL VER"rlCAI._ SIJBFEA R E C ]' A N G U L A R C L 0 S U R E DOGL:E( DEF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 iD R D I N A T E S DI'.E:TANCE DIRECTION SEVERI] FEET D M D FEET FEET FEE'r FEET FEET FEET D M DG/100F 4550. 51:30 N :31 E 4-600. 51 30 N 82 E 4650. 52 0 N :32 E 4700 ?] ~.' .c: 0 N 8.3 E ' 4750. 5:]: 0 N :32 E o. 3405. 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N 72 2.7 E; 'F¢79.3L-] N 3128.44 E 327:3. :15 N 72 37 E 982.20 N 3169.17 E 3:317.89 N 72 47 E 50, :3996.71 :3:349.22 :3886. 11 50. 4025.57 3389.55 2:914.97 50. 4054.34 :342'.;.~. 8'F; 3943. '74 5C) 4Cx..]:2.. 93 .3470.22 ::-:'.:.~7 ';":. 2::]: 50. 4111. :}4 3510.61 4000,, '74 985.4)5 N 3209, 91 E 3357.65 N 72 56 E 987.89 N 3250.64 E 3.397.44 N 7:3 6 E 990.39 PI 3291.46 E 3437.23 N 7:3 15 E '.'?'.'72. 18 N :3332.44 E 3477.01 hi 7:]: 25 E 99 :]:7/:, 2 N ':":' 7"-" ':'.% :":: 4 · 56 E 16. N 7:3 '-'= ...,I ._~ -- ..#! m 1.91 0.00 C) '";" O. 00 0.00 1.62 1. C)0 C). 5C) 0,. 'h 0 C). 00 C). 00 :[.71 1.72. 0.50 .......... 5800. 55 3C) N 88 E 585c). 55 30 N 88 E 59C)0. 55 C) N 89 E .......... 5'250. 55 0 N 89 E fl . 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E L-,050. 54 £) S ::/0 E 6100. 5:--: 45 S 8'.-? E 6150. 5:3 4.5 S 88 E 6200. 5:3 15 S :=:L-, E E C T I 0 N T V D FEET FEET 6250. 53:15 S 85 E 6300. 5::: 15 S 85 E /_-,350. 53 0 S 85 E 646)0. 52 45 S 85 E .6450. 52 15 'S :35 E 50. 4254.02 3711.77 4143,, 42 50. 4283.23 3751.38 4.172./_-,3 50. 4:2' 12.71 37'.T~0.65 4.202. 11 50 4. :342 27 o,--,-:,,.-/ 6'? 4. ':-' c: 1 67 50. 4:--:72.01 38L-,8.3:3 42./:, 1.41 50. 4401. 'F~:3 3':.-'~06.53 42?/1.3::: 50. 4431.85 3'744.64 4321. :25 50. 4461.85 :3'.--.¢82. 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L-,1 :'::. 37 0.00 0..50 0.50 1.00 6500. 52 0 S 85 E 6550. 51 15 S 86 E 6600. 51 0 S 8:3 E ./::,/::,50. 50 0 S 8-/ E 6700. 49 15 S 87 E 5o. :." 4.=,5:2. 16 40'~5.85 444.2 ~/-, '-'¢'~'= """ ..... . .:/..,..:, ~ N '-"-' ~ '~ .... ~.3 N 76 14 E .... · :. ;. ~.~. 41 E 4 n ';~ ~:. '"" ~0. ' 4~:::4 20 4.1:,..: .... 24 447::: 60 ~72 27 N 4017.4.'F~ E 4.1':":' 47 N 76 .24 E " ' '~":4 N 40~A :36 E 4.1'7c~ 78 N 7~ :3:3 E 50. 461 =~ ='''' , = _ _ ~*,:, ~ 7 u. ,~... ...... ..... ,,:, 4170, & .., 4 ~;o 4. '- '" 50 4647 29 ,~, c:,~, ~ ...... ' ,- ~, . 4..~07, 4.:,.:,c,, 7!~ ;~6,:, 5~ N 40¢~4 91 E 4207 :=:9 N 76 42 E Pso ............ 467'F¢ 7:~ 4244.4.4 4~/-,9 1'::' '",_, 'F,66 .=, ='6 N 41.::2, 74 E 4244.46 N 76 F~_ O. E 0.50 2.17 :3. 1 r_**. ..~., ,c.:..-, 1. F-10 /_-,75C). ...."[9 0 ..,c:' 87 E 6800. 4.:3 45 S :.=.:7 E 6,85 C). 4:3 0 '.E; 87 E 6?/00. 47 45 S 8:3 E /- o :, ..... 46, 45 S,_,':'9. E 7000. 46 0 S 89 E 7051. 45 0 S 89 E 7100. 44 0 S 8'.-? E .:..:7150, 43 4.5 N ?/0 E 7200. 4:3 0 N 90 E 50, 4. '71'"..'. 50 4. 2 :=: O, 7 '.'-.'¢ 4 .:,/' ('.) 1 . ':? 0 5C). 474-5, 38 4:316, '=?'.:.? 4634, '78 ~.-( ...... ,~.;.-, .:, .). 4. 778 :']'.-./ '-?',? 4/.':,/-., 7 'F.,' · .~..:, .,....' ..... 50. 4-812.13 4:3:=:8.65 4.701.53 50,, 484.,/_-,. 07 4424. :Z.'C) 47:'::5.4'7 50. 48:30.57 4.45'P. :3:2 476'r?. '77 51. 4'=? 16.31 44.'F/4.. 6,1 4:305.71 4':?. 4?/51,26 4.527, '.'74 4.8,.].C~ ,,/=,6 50 4?/87, 31 4561, ./:,:E: 4876, 71 56). 5023./=,5 4595.09 4913.05 ':~ 64., · ,o N 4.170.70 E 42:=:0.7¢/ N 76 59' E 0,50 ?L..,2, ./:, 1 N 4:20:E:. :31 E 4317, 00 N 77 7 E 0, 50 '.:;//:.0./',5 Iq 4.245~ 6,3 E 4:352. '.:,'L'. N 77 15 E 1,50 9.=;,.? 0:3 N 47:82 L-, 8 E 4. ::.': :=: 8. ''~ =' /.., N 77 '-"-' ,, ....... ~.--'.', E i 5'7 ""'= "" . · 44. ,, .:, 6, '"". :..._,,:,,, ()7 N 4.:'::l'P :3'.:.:' E 24. '"' N 77 .... (") E 757, 4.4 N 4355, 5'7 I::: 4.457,. 56 N 7'7 :::6, E 'F./5L-,,81 N 4.:.3'.:./1.S/4. 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L-,8 ~/55. ?/0 N Zl../:,60.4(:) E 4757.4-2 N 78 :..-.:'.5 E 0.5C) 1.5C) 2. :2.00 2. C)0 LiN T ON 0 ! L F:AMF'ANY L E G 2, S L 0 T 4 2, W E L L NI-I: G- `18 O 1'I:_--; / G M:_--; .J 0 B N FI: G 0 2:('~7 / Pi 10 ::-': :E: G C) 215 ORAYLING PLTFM, TBLI, MAF:~RTHLIR RIVER FIELD, C. FHDK INLET, 'RL. AL::KR C 0 51F' U T A ]' I Fi N T IMF DATE 1/_-,: o 7: :]: 9 0 7 - 0 C T -. 8 :'-': F'ROE Nr'3.. /-., ~ ., MEAF;URET'~ T]R'[ FT TiR ! FT I"IEF'TI--I ANGLE I"~!RECT ION LENOTH DEF'TH FEET D M D FEET . FEET TRI_IE C:EILIRSE VERTIF:AL. VERTICAl_ SUBSEA R E C: T A N G U L A R C L lEI ::; U R E ]DCGCE C 0 n R D I N A T E ::: DISTANCE DIREr:'rION :_'-;EVEF,'I 7500. :'::8 45 N ?() E 7550. 3:-_-: :2:0 N '.--./0 E 76 C)('D. :':-:7 45 :':; :--': 9 E 7/:,50. 37 15 :::; :_::::: E 7700. :::5 30 S :3:3 E F-;Er_'.' T I L-iN TVD FEET FEET 775A. 34 4~ S ,-,o = -- i~,~ ~.1 E 7:E:OC~. 3:3 15 ...,'-~ :::_ '--..'. E 7850. :-_-:1 30 hi 70 E 7':.-J 00. 30 4.5 N 90 E 7 ? 50. '2'? 30 N 'F. JOE 50. 5250.20 47:.-]:6.56 513':.?. 60 50. 52:E:'F¢. 26 4:E:16. 97 5178. 6,6 50. 5328. 60 4:_::4/:,. 'P'P 5:'21 :::. 00 50. 53/:,8.27 4876.46 5257./:,7 5(). 540,8.52 4'?.'05. 1 (} 52':T-'7. ':."/'.:..~ 50. 54.4'.--.¢. 4.2 49.]:2.88 5:3:38 ,, 82 50. 54'P0.87 4959.95 :5:.-.-::9(3.2'7 50. 55.]:3.0':7¢ 4985. S~',:: 5422.. Zl.'.::, = ' ='- =-"= ::::'-.? .~i 011. 17 .s 4/, !'-,', 29 · .,(.). ........... .~l ..j / ,j 50. ."2;61 '::','. 14 5035..62 .=;508.54 FEET FEET D M 9.55. '? 0 N 46'? 1.7 :::: E 4788.17 Iq 7 :"4:2.:"? E 955.9¢) N 4'722.99 E 481:E:.75 N 78 :--:4 E 955.63 1'4 475:'::. 86 E 484:_--,'. '.:.)/:, N 78 38 E '.-."/.'.54,84 N 4- 7 :':: 4,2 ::: E .,-1-:-:': 7 :F:,, 64 hi 78 4- :3 E ,-- I~'" ;.,._,..:-, ...... ::.'!:CD N 4.:!.::1:'_::, ':'.".-.' [.:.. 4'.?(}7. '=';c:: .D N 7:--: 4.:E: E '? 5'7-'I, 8 (":' N 4. 84' :2 ,, 67 E 4935 ,, .'.5 ,1. N 78 5:2 E: 952.07 N 4:"']70.62 E /'.~'F.','.':,2, SCD N 78 5/.::, E ...... 4. ~,',:, ::~ 0 E: . ':/;...1'=, 8:3 N 48'? 7 '::':~ E '- '""-. N 7'? c~ E: 'F;51.83 hi .4. 92:3. :2:3 E ![i;01 .q.. 40 N 7 9 :3 IF: 'F/F-; _l. 8:':: 1`4494:-'.:. :2::2', E :50:39.04 N 79 7 E D G / 100 (:). O. 50 I. '.:.)/4 1.5::: :E:. 50 .:i0 :3.2(] :3 8,/- 1.50 2.50 8000. 28 45 N 70 E 805c~. 28 0 N 9(] E 8100. 27 I5 N ?0 E 8150. ':'~ 4..5 c:. c:,9 · ,-. ........... E 8200. 25 45 S 8? E 8250. 25 15 .S.: 88 E 8:--:00. 25 0 S :-=,'8 E :E: 350. 24 4. 5 :=;,_,o,_,o E .... 8400. 24 45 S 87 E, 8450. 24 15 S 86 E 50. 5886.02 516 :."'".':./:, :E: 5775.4. 2 !5 0 =" '-' '-'" .... 5 ':"-':~ · _, ;-.:, .L ~:t'? 1 1 'v !=;:":: 2("D 69 ii u . i_, .. Ii ....... 5C) ='¢~-'~ . 65 =;.-.,('v:) F:;C) ~:;'-'/ . .., :. / ,- .... .. ............ : ,'-, ,:, 6 C) 5 50. /:,022.06 r-';227~./:.,:E: 57.'~ 11.4.6 50 60/.,7 F,/., ~c, ao Fi,/., ~.=,-~.' ........ ~..~-... ........ , ::~._,6. '.-.?6 95 C) 7 ¢) N ~.'" C) '"'' F:; ~,,".; .:, ...... :, ,. ,:,r4 .1. E ... 17:3 26 N 7 ~::....., E; 1 .... '"'" ':.? 49.95 N 5106. :3'7 E 51 ':.'?:3. '?/8 N 7'~.'/ 2:3 E 0.50 '.~4'-v '-'" ?:; ":":;' =;":'~ 4 "=';1 1`4 7'? "-"], E 0 .,::. ,':: N 127 E.". ._, ............ · · Ii . o..I., ':.--¢ .4. :":: . :3 `1 !`4 '"" 148:30 ="-' ''=' . .: , E ..,.~>.,4,91 N 7'? .:':':,4 E. 0,84. '::/.. 47 ,04. N '::;.. ....; A'..} , A. 0 [.: '~... "".... =;._ ._'=,, 04. N 7 .... 8500. 23 45 S 86 E 8550. 22 30 ::; 86'E 8600. 22 15 8:35 E ......... 8650, 22 15 S 85 E 8700. 2 .o 1 ?:; S '='~ E ?; cD 611:3 '-"--' =;'.';'/. ':? 0 cD /-, c) cD'2./- ":' . ~ ~ # ,,.4...i ',., a- -' .' · ............I ..#! 50, 615 '?, ?." 1 :'~ .. ~..-., ,_, o .-;,.. '7 F: /:. 04 '3 ./., .. 1 50. 620 !""5.4. 5 !5305. '.'.'? :.':: 6 ()'.:::' 4 ,, 85 , 50 /:,251.73 532:3. 'P 4 /::, 141..1. :3 50. 6298. CpO 5341. '?5 61 C,::7.4,0 945.62 N 5189. ,'2,.:'? IE :.'".';274. '74 hi. 7 ? 40 E 1.00 '~ '-'")"" =' '-"? "' 7 '~.:~ ":' 'F/4. 4-. 2. 5. N ..... -: .... :, . :-'.: 7 E .;,.:: ,", .:,. 7 '7 hi 4. 4 E-" .... ,, :::; ..... (") ':.-/42.7/:, 1`4 .'.-.]227. ::35 E 5:3.1, 2..1. 7 Iq '79 47 E O. '.:,? .1. ?.:'41 ,, 1 1 N :5246.71. E :5330.44 N .7.'F./ 50 E O. 00 9:3'.::). 4/:, hi 5265.57 E: 5348. '72 N 79 5:3 Ii?.' ('D ,, 00 PRO,_IEC:TEf'~ TO TD 8860 22 0 c. 84 E FINAL CLO.'=;I IRE. __ - DIRECTInN:_ N,:,'-'c.) DEGS ._,'-' MI N:::; ...,":"-.'.:. .'-]Fl'"":'-'...., E DISTANCE: 54.06.47 FEE]' UNION OIL OOMPANY LEG 2. SLOT 42. WELL NO: 9-18 GMS/QMS GRAYLING PLTFM. TBU. MACARTHUR RIVER FIELD EASTMAN WHIPSTOCK, INC. 0 0 550 2000 4000 1300 2050 3050 4050 5050 6050 6000 8000 7051 7800 8550 I I I 2000 4000 6000 VERTICAL SECTION CLOSURE ,~, 06.47' N 8'0 3 32 E DATA FILEt 01836' VERTICAL PROJECTION SCALE 1 i.N. =. 2000 FEET UNION OIL COMP ANT LEG 2. SLOT 42. WELL NO: G-18 GMS/GMS CRAYLING PLTFM. TBU. MACARTHUR F~IVER FIELD !EASTMAN WHIPSTOOK. INO. HORIZONTAL PROJECTION SCALE 1 IN. ~ 1000 FEET DEPTH INDICATOR: TVD 3705 ~1 ~0 ~584 5097 5931 FINAL STATION~ 18~ ~ DEPTH 8860 MD. 6446.~i TVD ! NORTH 9~3.~5 EAST ) CLOSURE 5408.47 N 80 ~ 32 E Eastman Whipstock A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TIONA L SURVEY UNION 0IL COMPANY COMPANY WELL NAME MacArthur River Field, Cook Inlet LOCATION JOB NUMBER A1083G0215 SURVEY BY W. Coram TYPE OF SURVEY Gyro Multi-Shot OFFICE Alaska DATE 12-0ct-83 Eastman (907) 563-3650 P. O. Box 4-1970/Anchorage, Alaska 99509-1970 October 12, 1983 UNION OIL COMPANY P O Box 6247 Anchorage, AK 99502 Well Number: G-18, Leg 2, Slot No: 42 Location: MacArthur River Field, Cook Inlet, Alaska Type of Survey: Gyro Multi-Shot Date: 06-October-83 Method of Calculation: Radius of Curvature/Average Angle/Tangential Surveyor: W. Coram Job Number: A1083G0215 Attention: Mr. Callender Dear Mr. Callender, We are enclosing the original and twelve copies of the Gyro Multi- Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and we trust that we may continue to serve your needs in the future. '-- /Tom J~. ~~ ~ Distr~u.'echnical Coordinator TJ/db cc: file Enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/SaJes/Woddwide SURVEY CERTIFICATION SHEET Company L/~/~I~ ~/'L Job#~o~3~m2o~ Date Well# ~'-//~ State Surveyed from a depth of 0 feet to a depth of ~_,/<__~ feet. Type of Survey ..~'~~ Directional Supervisor/Surveyor The data for this survey and the calculations for this survey were obtained and performed by me according to the standards and procedures as set forth by Eastman Whipstock, Inc. and are true and correct to the best of my knowledge. ui rec~ional Supe rviy~Surv6yor The data and calculations for this survey have been checked by me and conform to the standards and procedures-as set forth by Eastman Whipstock, Inc. This report represents a true and correct Directional Survey of this well based on the original data obtained at the well site. Original Copy - District Office File One copy to Houston Office D-1121 SURVEY CERTIFICATION SHEET Company ~/A/Z-o/-/ C~>~ ~'~o,--~z~v~ Job#..~/o83~o7/>- Date o~- Oc~-~] Lease/~A~~ /~E~ ~~ Well~ ~-/~ State Surveyed from a depth of ~ooo feet to a depth of ~7~~ feet. Type of Survey . ~oyco~~ J'~~~~ Directional Supervisor/Surveyor ~~ The data for this survey and the calculations for this survey were obtained and performed by me according to the standards and procedures as set forth by Eastman Whipstock, Inc. and are true and correct to the best of my knowledge.~j~(~~ ~~~,~ Directional Supervisor/$~'v6yo~ .... The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Eastman Whipstock, Inc. This report represents a true and correct Directional Survey of this well based on the original data obtained at the well site. C h e q~/ed .by: ~? J-, _ Original Copy - District Office File One copy to Houston Office D-1121 I.INION OIL COMPANY LEG 2, '.::LOT 4::.-.', WELL NO: G-18 GMS/GM::: ._lOB NO: GO207/A108:::G0'.-:'.15 GRAYLING PLTFM, TBI.I, MACARTHUR RIVER FIELD, COOK INLET, ALASKA GM'.::: 0-/_-.100 MB, '.-_-:URVEYOR: D PEFFERKORN.: [)ATE RUN: 1'.::-SEP-83 GYRO NO: 305, CAMERA NO: 1666, 90 DEG A/U NO: 15/_-./:. GMS., /_-.(')00-8750 MD, :---;URVEYCIR: W. CORAM, DATE RIJN: (-) 6 - 0 c: -r - :::.: :--: FORE::;IGHT: DOLLY VARDEN ::;].6 50W F;URVEY TAKEN FROM ROTARY TABL. E ' I VERTICAL SECTION CALCUI_ATED IN PLANE OF FRCF'OSAL_ DIRE:CTION: N 77 DEG. 0 MII',I. r..i:' R E L-.:I- R.EI 0 F t'".'i;I.,.I R V E Y T A N G E N T I A L M lie T H 0 D UNION OIL C:OMF'ANY L. EG 2, '.:;LC~T 42, WELL NO: G-I. 8 GMS/GMg; .JOB NO: L](')2C)7/A1083C~O';:'1._"; GRAYLING F'LTFM, TBU, MACARTHUR RIVER FIELD, COOK INLET, ALASKA C:OFIF'U'F AT I ON T I ME DATE (. ,:,. 42: 1:2: 12 -.- 0 C:'f' - :3:3 PAGE NO: i TRUE MEAS:URED DRIFT DRIFT COUR'.::E VERTICAL VERTICAL SUB'.3EA R E C: T A N G i..! L A R C L 0 ,.:; II R E £u]GL.E DEF'TH ANGLE DIRECTION LEhlGTH DEPTH SECTION TVD C: 0 0 R Fi I N A T E S DISTANCE DIREC'I"IC~N ::;EVERI FEET D FI D FEET FEET FEET FEET FEET FEET D M DG/100 0. c) 0 0 0. 0.0C) 0. o0 -1 .1. 0./_':,(') (). 00 0.00 0.0C.) 0 (') 0.00 100. 0 15 C-; 25 W 10(]. 100.0(:~ -0.27 -10.60 0.4(") F; 0.1::: W 0.4-.4 F; 25 0 W o.2.5 150. 0 15 ,.E; 6 W 50. 150.0 (') - 0. :34 :_39.40 0./:, 1 ,.E; (). 21 W 0.6.5 :E; .1. :E: 42 W 0. 1 '7 20(]. 0 15 'S 5 W 50. 200.00 -0.4,1 89.40 0. ::4:7: S (').2:3 W 0.8/:, 'F; 15 15 W 0,.0;/ :250. 0 1.5 :_=; 9 W 50. 250.00 - 0.49 1:2:9.40 1.05 S 0. :26 W I. O',F: ~.'-": 1:359 W 0. ('):3 ! :'::_ O. C) . O. 5:0 ._.-'::' '-?. W ~_ 0. 5:0 Cl.. ¢1. 0 - ()../-,_ ~_ 1 :q 9 .4. C~.. ! .48 ::!; O_. :3:3 W ~ ,, '::...., 1 '.E; 12:3 :q W ,:I ,0 :--:50. 0:30 S 19 W 5c). :349.79 -0.::::8 2:39.:39 1.:39 S 0.4.7 gl 1·95 L: .1.4 0 W 0. 1'7 4. 00. 0 :::_ 0 '.=;14 W F,_ 0 . .":-:_ ,r.~. ,:.~. . '--.~. ':'.~. .- .1. . 0 :::: 2. :::_ '--.~..."::.. 9. 2.3 .1. o._, (') . =;._ ':',_, 14 2. :38 F; .1. 4 0 W ¢)... ¢)9 ='" .... .- . .... 7.~ S O. =''- W ,:., ,-, 1 :3 .1. 7,.' 9 W c) 21 4..:, o. 0 :':: 0 :5: '2 la .55., c) 449. '--~'''-'¢ 1,1 '-} 5: :3'-.') :':::'-.'7¢2. ' .~ .::, ~* '-' ':' 500. 0:30 E: 0 E 50. 499.99 -1.29 :389.2:9 3.18 S 0.5? W 3.2:4- .':.; .1.0:7:1 W 0.0:3 550. 0 15 S 6 E /:,0c). 0 4.5 N 79 E /:,50. 3 4.5 N 72 E 700. 8 1,5 N 75 E 750. 12 0 N 74 E - 4..: ,3".'-¢ :3. "!.o S. (') !57 W · _,C='- } ·F, 4o 9'~ 1 ':'"':' ""':~ . ?]0'.... .=i,':;,,--.~_. . . '4:.~,'::. _ ' '0 ./_-,7 489 . ':":'...,,_, ..... ':._, .... .~,:,~' .:," .... ' : 0 .07 E !50 64'P ::::::, 2. '~'::) ' "':'-' ~' '-' '"'' "~' ''"' 7 '= 3 1 ::: E ., _ ..,., ,..I,.,]~ 2". ~,';:.' , .~.." ..* 75 f') ·" /-,'_:'.~ 9 ':'/- 9,76 ~:: "" '-' : ...... , ...... ,,:,,:,. 76' ::: 0.4 ! '.:: ': 'i 10. 11 E -" '",. ", ., ':i , ': . · .,L='), 748.2'7 o(.~., ...... 14 6:37 /:.7 .~.'":' 4/'. N ':' "'20, 1 1 E , , :3,45 S '? 29 W :'::.28 '.::; 1 .1.7 E :3,,91 :3 54. 34 E 10.12 '.E;87 41 E 2C).26 N 8:3 :2 E 0. !51 1../:,2 /-,. 01 9.02 '7.5.1. 800. 13 15 N /:,:3 E :E:50. 13 0 Iq 5'P E '".> ('} (')1 "-' = "";':' E .... · .- .1. o N ..,_, 950. 1:3 45 N 58 E. 1000. 14. 45 N 57 E 1050. 16 15 N 60 E 1100. 17 15 N /:,0 E 1150. 1:_: 15 N 61 E ......... 1200. 20 0 N 62 E t250. 21 45 N 62 E 50. 796.94 5o. 84.5.65 50. 894.5:2 50. 943. 50. '.:'.~'P 1.4:3 :.:,: 1.26 6:.'::6 ,, :'::4 7. L-,6 N 3(). :'-'::2 E 41.96 7 ::: 5. t") 5 1:3.4:5 N 3'?. 96 E 51.99 7 8:3.9:2 19.07 N 4. 8.9 L-, E /' ":' 2 ::: 8..., '"''''''',,~. 4 :E: ...,,'":,..,:-~ :.37 N':"'"' 0:3 Ii'-' 75, _1. 9 8:::':0.8::': 32.30 N 69.71 E 50. 1039.4.4. 8:::. 57 'P:,.]:8.84 50. 1087. l'P 102.75 976.59 50. 11:34.. 67 117. :::0 1024.07 · 50. 11 ,_,':'1 ,66. 1.5:4. , .:,'-"-'.-'. 1071 ,06 50. 1:228. 10 152.22 1117.50 :3'P, ::.::C)N 46.71 N 54,31 N 62, ::::3 N 71.0:3 N ':' 1 8:3 E 94.. 67 E". ~.. ,:,. :36 E 1 :"::9 '- .... 56 4 5C: . .:,..:.' E 1 .8:3 N 6:3 E:' :3. l?.C)O. ':.":' C) N 62 E 1'3=^ '"'.=, 0 N 61 E .. ,_1 L.~ # 1400 "1- ~:0 N 8,1 E 1450. '-'"' ..',:, 15 N /_-,1 E 1500. ~.'9 45 N 6 .1. E 50. 1274.12 171.09 116:3.52 -ra'-(- '":' ".""~ ".') ""(")'::' ':' 4. · :, .), 1 ..., 1 . , 44. 1 . 1 .4. 0 1 .,: .......... 50. 1364.19 212. :..:.:5 1253.59 50, 1408. :2:':: . 2:35. !:'?P 12'P'7, 6:3 50, 14.5 l, 64 259,, 4. 4- 134-1,04. .... =i-', .~:.. 5 C 8¢) 2C) N 1 ._ 7 ¢)'7 E 1 '76 36 I',1 6:2:.=;7 Ii?.: "" 90.45 N 175.55 lie 19'7, 4',3 N 62 45 E 4.. (:)',iii 10 .1., 2/.':, Iq 195,0'7 E 215', 7 8 N 6 2:5: 4. E: 3.0 ( 11":',:. 74. I',1 ' :2.1 .,., '= , 76 lie 24.:::: ,44 1'4 /- :;':... :. .... :,":',.:, E :3 , '::; "... (. ":'/- '::' ':.' 5 ":' 1:24., 7'7 N 2:37 ,4..6 E ............ ,, =... N 6.':.it .1. 7E ...,, ('). ( LIN I ON. A I L F:OMF'AhlY L. EI] :2, .-'E:L -IT 4'-" _ · -., N E L L N n -. G- 18 O M'.=; / G M'S ,J 0 B N 0: G C) 2 c-~ 7 / A 1 c-) 8 :--: G c) 21.5 GRAYLTNG F"LTFM, TBU, MAF:ARTI4LIR RTVER FIELD, ROOK TNLET, ALAF;KA C 0 hi F' U T A T I 0 N T I ME DATE 08: 4:2: i :3 1:2- 0 C T - 8 :':: P A GE NO' '2 TRIJE MEA'._::I_IRED DRIFT DRIFT C:CH..IR'.=;E VERTICAL VERTIC:AL SI...IB'.:;EA R E C: T A N G U L A R C: L 0 S LI R E TOF. j;L.E DEF'TI'-! ANGL. E DIRECTION LEN[3TH DEPTH ~=;ECTION TVD C 0 C[ R D I N A T E S DI:--;TANC:E DIREF:TIF~N SEVERI' FEET D I'1 D FEET FEET FEET FEET FEET FEET D M DG/100 " 1550. 31 4.5 N 62 E 1/_'.00. :3:-:: 45 N 62 E 1650. :_--:5 45 N 6_-,2 E 170(:}· 3:=: 0 N 62 E 1750. 40 15 N /=,4 E 1L::O0. 42 4.5 N 64 E 1:-_-..:50. 45 0 N 63 E 1'700. 46 45 N 63 E 195C). 4'? 15 N 6:_:: E 2000. 50 0 N 64 E 2050. 51 0 N 63 E .?10(:). 51 15 N 63 E 2150. 51 15 N 63 E ' ~.'c-~O .~i i :30 N 64 E 225c). 51 45 N 64, E 50. 14'.-.? 4. 16 50. 15 :=: 5.7:2: 50. 1576. :=: 1 50. 1615.71 50. 1653. :97 2:E: 4.86 138 :'=':. 56 :=: 11 6'.=.~ 1-4 ...._, 1:3 3:3'?. 91 1465.71 :--: 6'.9.7 :E: 150.5. 11 4'01. 25 154:3. 27 1:2:7.12 N 260.70 E 150. 16 N 285.22 E 163.87 N 311.0:2 E 177, :-:.:=;,. N ,:,'-"-"-'.:, o, 4.4. E 192, 01 N :-::/=,7.4- 8 E ,.,~.), 1690.59 50. I '-'-= '...-.~4 7~.._,. · .50. 176 O. 20 50. 17'? 2.84 ~ 0 1824 '-?':' ,.~.' ~" ,:,~/. · .,0. 1 45 F, '. 887. ,.0 '"':' 1 74 .. 50 "'ii::': 1 '~ 1 '.-.?. c')4 .:, .).. 195 c') 1 A 50 .' ";~'"::"'"1 "?"' ' .= ,=, 1 "12 76'7.8 c) 1870. ~ ':' 4:34., '-"-' = - .:, ... 1.._, 7 '.-:', '.-}':.? 468, 6:7:: 1615. :34 '"; ')'". '.=.~7. _ . · _ (...:, 164'.':~ /',0 54.0.72 1682. :24 578,04 1714,2::--: 206,89 N .'_--:97, 'F/8 E 222, 94 N 4'29, 49 E 23'F/.4.7 N 461,94 E 256, 67 N 4'....75. 69 E 273.46 N bi.30..1. 1 E 2';74 = · _,6 N 62 1= E :2:22.:3:3 hl 62 14 E 351.55 i'4 62 1:3 E -'5 ~-, .~,,:,,',33 N 62 17 E 448.5F:; N 62 32 E 8:.=.:. 'F'cZ) N 62 :E: 4 E .:,(.) .-,.-, ..... ..... :,.~: Iq 62 '::/', E: '='='-' 20 Iq /=.2:2:'7 E ,_l ,-...~ n ':.76.4 '.--.~N 62 4. :--: E r .:,._, Iq A2.' 44 E 674,,:34 N 62 45 E .1. 3. :33 N d:.2 4. 6 E 4. 1 :--: 4. cE)C) 4. 4.6,/=, 4.67 .tj,'' ..,0 4.. 71 3.50 =' 0 C) 5::": .50 00 75'2.46 N 62 4.9 E 1,/=,.4 791 '71 N /.. 2 ~'''' ..... ,..:, E" . ...~ (..) 23 OcE), :'"' · _' ." c') N 64 E 235C). 51 45 N 65 E 2400. 52 15 N 65 E .2450. 5:.2 0 N 66 E 2500. 52 0 N 66 E .255C). 52 3c1) hi 67 E 2600, 52 4.5 N 6,7 E 265c), 52 15 N 67 E .... 2700, 52 30 N 67 E 2750. 52 0 N /_-,8 E 50 2011.90, 806.19 1901.30 50. 204':;'. :36 :344.60 19:32 ,, 26 (] ":' 0";":'. .. _ .. .-.... .... 47 88:3.27 1 ':~/-, 2.87 50 2104,25 92 .1.. 9!=; 1 '.-.?'.=) :3.65 50, 2135,03 96 cZ) , 62 2:0:24,43 50 216!5.47 997.>. 6? 2(:)54 ,, 87 50. 2.1 S/5.74 10:2:8 ,, :=:9 2085. 14. 50. 2226. :2:5 107'7.82 2115.75 5(]). ~ 2256.78 1116. r-':8 2146. 18 ~2;0. 2287.57 1155.80 2 .1. 76. '.-.? 7 378, 1 .'.5 N :394.. 74 N 4.11,45 hi 427.4.8 N 44 :-::, 5(') N 740.10 E c:":'1,_,._, . 11 N 62 56 E c").. 5¢) '77!:-] 6::.", E ::::7A ""'= ":' ........ :,._, N,.,/-":'._,... E 1 . 6.5 ':' 11 5 :L E: ..T~(')9 ~ ..... :,6 N 6:3 7 E .1. 0() 84. 7 51 F£ '~74'F~ '-' 1 N /'. '=' ... ....... 14 E 1._/.6 x . m, t '] ~""'"' .5A El '::?:=:=: "~-' ,=,,=,.=,. . _ _ ~ ..:, / N 6:3 ...":' :l E: C .) 459.00 N 920.02 E 102:F.:, 1.6 I',1 6::? ::.i:? E 474 ....... =;'::; N '?:. '"'.:, 6 ............./'. "-] E 106, 7 :::'-} N 6 :'-: :::'? E: 4'.:.'~ 0.00 N '~'.'} :3.04. E ,110'7. ::.".",/:,N 6:3 4. 4 E 505,50 N 102'.".Z,56 E 1146,96 N 6:3 51 E ?¢) 26_-, N 1(-)/.::,,/_-, c')':.'¢ E 11:-::/_-, 2/-, N /.",'-: ........... · .., E 1.87 0.5(') 1. 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' ~ 4 . ii'. 7 0._ 44 .1. 71 ,-1.7 ,45 'pt.,::: 70 N Zl.].':":~ ":'s E 4.2'P8 77 N 77 :3 E · ,.. n . m., .. u '.,''-, ~ . ,, '.::)/--, 1.7:3 N 422./:,. ',B'P lie zI.:3:34. '.::)2 N 77 1 1 E 0.5() 959.78 N 42/=,4.00 E 4. :370./::,9 Ix! 77 19 E 1..50 ':.? 58.4. 9 N 4300. S'9 E '1. 4-0/=,. 50 N 7'7. :26 lie 1.57 '::~' ="..:,7 ~",:,/:, N 4:2:37 40 E 444 ]. ':.; 1 N 77 o.:, E 2 3 ~ b - at . 50.. 487:2.7:i,:,: 44. 76./.", C). 47/'=, 2. 18 S.' 57.2:3 N 4:37:3. :36 E 44'76.90 Iq '77 :-:: 9 Iii; 1 ,, 5 51. 4. 90 rE:. 8.5 4. 51. 1./::, 0 4.79 :i'.::. 255 ',:;:' !5/=,. 6 C) N4. 4. 09.4. 2 E: 4, 51. 1.99 h,I 77 .4. 6 E ' 1. 4 '.-.',. 4. ? 44. ,:')'.::'; 4 F--'; 4. 4.62 4 ::3 ::-.': :2:. 4 '.-.":' 9' 5.6.00 N 4- 4 ,q. 2. ,1. 5 E." 4 !:545 ,, 1 :i:: I',,I 77:51 E 2..:_':..q. 5 C). 49' L: 0, 21 4. 578. ::-: 1 4869.61 '.=.,' :5,/:.. 0 0 N4478 ,, 0:3 E 4. 57 L=.! ,, '? 4I',1 7.7 5'7 E 1. ,.1. 7 50. 501/=,. 78 4,"_-, 1. 1.54 4S'0,';:,. 18 S'5/.=,. ':')0 N 4..'.'.-'51:2,, 13 E 4../,.:, 12.2S' Iq 78 2 E .1. ,, 5() ......... 725C) 42 45 N F/r.) E 730(:). 42 0 ' N 90 E 7350. 41 C) N S/O E 7400. 40 0 N 'PO E 7450. 3S; 0 N 90 E fl. . .:, .,..,.:,, :..5 0 464,.1-, 61 4'?,~ 42 ,, 'F' C) 5C). 50'::?0.65 4677. :'21 4'F'80. O~:-i 5 C). 51 .'2:8..5:9 4709. 17 5017. '7 9 50. 5166.69 4, 7 q 0./I, 9 5 () 5/.:, ,, 09 50. 5205.55 4,77 :I. 14. !:.505)4, ,, ':=/5 '!.":'56.0() N 4.54,/:, 07 [::: 4645,, 50 N 78 7 E (). 5() 95/:,. 00 hi 4. 57'.:.'>. !5:3 E 467:B. 2.'.5 Iq 7 :F: ], :3 E 1.. 5 C) 'F; 5/_-,, C) 0 N 4../:, 12 ,, .5::':: E 4.'71 C),, :=: 6 I',1 78 17 E 2.00 ?5/=,, 00 N 4644, ,.1.7 Ii:' Zl. 741,84 1'4 7:'2:22 E 2,, 0() .-.._,,=,,, 00 N 4./-,7~"q_ _. 9:::. .. [.:.: 4.772,, /.,:,6 hi 7°,_, ::.?7 E 2.0(': IJNION. OIL COMF'ANY LEO 2~ '.:'!;LOT 42, WELL NO: G-l:=: GMS/GMS ._lOB NO: GO207/A1083GC)21.5 GRAYLING PLTFM, TBU, MACARTHLIR RIVER FIELD, COOK INI_ET, ALA'._:;KA C 0 M P I...1T A ]' I 0 N T I ME f)ATE ("~ 8: 4. 2: 1:3 1 ':.2-0 C T - 8:3 F'AGE NO' 6 TRUE MEA'.=:URED DRIFT DRIFT COURSE VERTICAL VERTICAL :=;UBF;EA R E C: T A N O LI L A R C L 0 S U R E DOGL. E DEPTH ANGLE I]IRECTION LENGTH DEF'TH F:ECTION TVD C 0 0 R D I N A T E S DI:=;TANCE DII'~ECTION :_:;EVF:RI' FEET D M D FEET FI=ET FEET FEET FEET FEET D M -' 7500. 28 45 N 90 E 7550. 38 30 N 90 E 7600. :37 45 '._:; ::::'? E 7 650. :37 15 '._:; s::8 E 7700. 35 3c) S L=.'8 E 7750. :]:4 45 S :E::E: E 7 :E: A.A.. 3:3 15 ._,'=' :::_ 9. E 7850. :=:1 30 N S'O E 7'F.,'c)0. 3(] 45 N ':.-,'0 E 7950. 2'? :30 N 90 E 50. 524.4.54 48A !. 64 51:3:3.94 5c). 528:=:. 67 4.8:31.97 5] 7:=:. 07 0 5:3'-"-' 21 48/=, 1 6'7 ='-'12 61 · ,,' ._-0 · . . ,_1 ~-~ ~", .-, ..... ~..~..,~4-. ...... =,/=,.-, A! 4:::90 90 ='-'='-' 4! DO. 54CX_:,'. 7 ! 491 :=:. '.'--/5 52'?:3. ! ! 50. 5444.80 4':-.,'46.4.:=: 5334.2:'.0 50. 54:_--:6.61 4'..7/7:3.08 5376.01 .50. 5529'. 24 4'F.,'F./F:, 5:.::: 5418.64 50. 5572.21 5(_')22:. 44 5461.61 50. 5615.7:]: 5047.4:':-: 5505. 1:3 956, 00 N 4707,23 E 480:3. :3:=: N 7:_:: ::-:1 E ':~/-, ................ Ac'~ N 473::--: :=:/-, E-' 4:-]:3:-": :_=:4 Iq 78 '"':-:.,o E'] 955.47 N *:1.7/_-,:-_-.:, 96 E 4863.7q- N 7:."-': 4('~ I.'E '.-T/.'.34,4.1 N 4. 79':..-/. 21 E 4. 8'.:.'/:3, 19 N 78 45 F 95:=:,4-0 N 4828,23 E 492!.4.6 N 7:.--: 50 E '? 5'7::, 4.1 N 4':E:56, 71 E 4. 94. 9, 7:1 N 7 ::2:54 IE ~.':...; ,=, '-?..._'~ 1 . '='...._, '--' N 4884 . 1 .":' ........ E 4976. (') ';.:' N '7 :::: ...... E 951,9:'=: N 4910.'.".i:4 E 50(])1,67 N 79 2 E 951.9:3 N ,-I-'? 35.81 E 5 ():,7::,.5,. 77. N 79 !5 E 9'51,93 N 4960, 42 E .:5050, ? 4 N 7'.::..' 8 E 8000. 2:3 45 N 90 E ::2:0.':50. 28 0 N 9' cE) E 810 c). 27 15 N ':.",'c) E 8150. 25 45 S L.::9' E :-:20c). :25 45 S 8'? E 8250. 25 15 S 8,'_=: E 830c). 25 0 S 88 E ,=,':,~ n 24 4-5 S o,:, E 840c). 24 4!5 S 87 E 8450. 24 15 S 86 E 8500. 23 45 S 86 E 8550. 22 30 L=; 86, E 8600. 22 15 S :s:5 E 5:65(]). 22 15 S 85 E 8700. 22 15 S :=:5 E 9. F.,_ ¢).. 4.3 hi ..":,: .... ('~ 9 .~ ,6. 0 E :-~_ 1 ,.=,...':'" :'. 4. :5: hi 7'? 26 E 1 . :2:2 949.69 N 5116.72 FZ 5204.1cE) N '7'? 29 I::E 94 :-':. 9./-,_ hi 5137 .64 E '::;... ,:....-,.-,...:. ~.,,L....=; 4 Iq 79. 32 E 0 , .... .'::i 9-4. 7.,_,':'/-_, hi51,.,=' ,':,'-., .J '= 4 I::. ._,=' '-'.,:: 4. 4- ,90 N .... 7':) "":, ..., = I:.-] () ,, ::: ".1. 9 4. 6, 4. 3 hi 517'.=/, 0:3 E: 5'2 6 4,7'.'-.'~ hi 7 9 ".ii:'.-'.~ E 1 ._, .) ............. 6110. '.'.? 4 .~ .~ 7,::,. 4.::,6 C) 00 24 94 !=~ c')";' N 19'-? 12 E :-,:,4 . :3 ] N IE ! ,, 0 (:) 50. .615'7. 1:3 52':-.//=,. 75 ,'.'.:,046. 5',3 94:3,../=,'F¢ hi 5218 ,, 2() E 5:]:0:;:'. 85 hi 79 45 E '.]!:. 50 50, 620:3, 41 5:314,75 /=, 092.81 942. () 4 hi 52:37, 06 E 5:3.':-2.1.. 12 hi 79 4:3 E O. 91 5(]. 6249, 69 53.'2_-:2.76 61.39. (')'i? 940. ,"'::9 N 5255. ',:,)2 E 5:':-::2:9.39 hi 79 51 E 0. ()0 5 A /-, '2 ':..:' ~ '::'/-. ~ :'~.':.,] A. '2'/-, (=, :1. "" ':":' :2:/., ':/"::' '-' '= '"" '= "' ,=,._, ; .:,,:, 74 I',1 !=;',.-."'74 ....... 78 IS ._,.:,._, 7, .6'7 N 79 :;'::' E 0., 0() ~ ,.. ..... # ,, .......... ~ .. # .,..J . PRID,_IECTED TO TD ,:,,:,6.). 2'.-' 0 c-.., 84 E 110 6444 °1 ~ ' ...... 4t)7.44. ""-"-'. · . 6.:,.:,.:, 7 ! ...... · .-.. 4. 7 hi ._ .:,.:,4.29 E 5 41 :::; "" ''"' .... F I NAL CLOSURE - D I RECT I ON: Iq :=-.:c) DEGS ...,~'-' M I Iq:::; '='.:, '-'.::,El-'_..:,'" E D I STANCE: :54. 15, 2:E: FEET 0.00 UNION OIL COMPANY LEG 2. SLOT 42. WELL NO: 0-18 GMS/GMS GRAYLING PLTFM. TBU. MACARTMUR RIVER FIELD EASTMAN WHIPSTOCK. INC. 0 0 550 1~00 2000 2050 3050 4050 4000 5050 6050 7051 6000 7800 8550 8000 J' I I 2000 4000 6000 VERTIOAL SEOTION ! CLOSURE ~"~1,4~5.28 N §0 5 5 E VERTICAL PROJECTION SCALE '1 IN. -- 2000 FEET UNION O!L COMP ANT LEO~ 2. SLOT 42. WELL NO; G-18 GMS/GMS GRA'fLING PLTFM. TBU. MACARTHUR RI'~ER FIELD EASTMAN WHIPSTOCK. INC. HORIZONTAL PROJECT[ON SCALE I IN. ,- lO00 FEET DEPTH Ir4D[OATOR~ I'VD ~~319 FINAL STAT[ONt ~ .... DEPTH 8860 HD. 644~.3i TVD 1856 NORTH 932.47 EAST 5334.~9 ' CLOSURE 5415.28 N 80 5 5 E Su~gested~orm to be inserted in each "Act~" Well folder to d~eck for timely compliance with our regulations. Operator, Well Name and Number Reports and Materials to be received by: /~' ~' Date Required Date Received Remarks , Ccmpletion~Report Yes /'~ . _.. , /< . [ . Core ~scrip~on C /.,~ - : i*+ .y" Drill St~ Test RemUs -&:<:~::¢~ ~ : ~' ~d~On Trot Re~rts . Digitiz~ ~ta . /~ ~ , ~ ~ ~ ..... STATE OF ALASKA ALASKA~:riL AND GAS CONSERVATION CC~vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. UNION OIL CONPANY OF CALIFORNIA 83-135 8. APl Number 3. Add~ BOX 6247 ANCHORAGE AK 99502 507-33-20160 4. Location of Well Conductor #42, Leg #2, 1884'N & 1378'W of SE Corner, Section 29, T9N, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) RT 99'MSL 12. I 6 . Lease Designation and Serial No. ADL 1872~0 9. Unit or Lease Name Trading Bay Unit 10. Well Number TBUS G-18 DPN 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Abandon the following sands: D-16 f/ 8350-8360 & 8316-8328 w/ ret at 8225 & sqz w/50 sxs cmt D-14 f/ 8134-8150 w/ ret at 8025 & sqz w/ 50 sxs cmt D-9 & D-lO w/ ret at 7300 & 50 sxs cmt on top of ret D-2 f/ 6280-6300 w/ ret at 6185 & sqz w/ 80 sxs cmt Verbal approval by Russ Douglas on 10-28-83. NOV Alaska Oil & Oas Anchorage 14. I here~y cglrtify that the foregDJ4~g is true and correct to the best of my knowledge. ,'7 s! TideDistrict Drlg Superintendent 7ze ~ce be,ow for Commission use I ~f{'~itions of Approval, if any: Date November 4, 1983 By Order of Approved by COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1-80 submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - ' ' STATE OF ALASKA ALASKA 'L AND GAS CONSERVATION C, JMISSION MONTHLY REPORT'OF DRILLING AND woR'KOVER OPERATIONS · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 83-135 '3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 5o- 733-20160 4. Location of Well at surface 9. Unit or Lease Name TRADING BAY UNIT Conductor #42, Leg #2, 1884'N & 1378'W of SE corner, Section 29, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RT 99' MSL ADL 18730 10. Well No. TBUS G-18 DPN 11. Field and Pool MoAR!HUR RIVER FIELD "D" SANDS For the Month of SEPTEMBER , 19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations ~ 00:01 hrs 9/12/83 Rulled 2 7/8" tbg. Recovered pkr ® 5529'. Reopened 12 1/4" hole to 6402'. Drilled 12 1/4" hole f/ 6402-8860' TD. 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description 4" Core f/ 7494-7523' " 7523-7548' " 7675-7705' " 7707-7736' " 8358-8388' " 8388-8415' Rec 29' f/ D-9 Sands " 25' " D-9 " " 14.5'" D-10" " 28.5'" D-lO" " 15.4'" D-16" " 27' "D-16" 4" Core f/ 8606-8635' Rec 26' f/ "E" Zone Shot & rec 31 sidewall cores f/ 6291-8561' 15. Logs run and depth where run Gyro f/ 6100' to surface Ran DIL/BHC-Sonic/VDL f/ 6291-8561' " FDC/CNL/GR f/ 6192-8561' " Dipmeter f/ 6291-8561' .1 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereb that the foregoing is true and correct to the best of my knowledge. SIGN LE DISTRICT DRLG SUPT DATE 10/14/83 j~--~rt on this ' ' NOT form is required for each calendar month, regardless of the status of operat.ons, and must be filed in duplicate with the Alaska Oil alOft'Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 ~ Submit in duplicate R~.v. 7-1 September 1, 1983 Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Re~ Trading Bay Unit G-18 DPN Union Oil Company of California Permit.No. 83-135 Sur. Loc. 1884'N, 1378'W of SE cr Sec. 29, TgM, R!3W, SM. Btmhole Loc. 3037'N, 3637'E of SW er Sec. 28, T9N, R13W, SM. Dear Mr. Anderson: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one eublc inch chip from each foot of recovered core is required. Samples of well cuttings and a wad log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. ~any rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these aream are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to .commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State ia prohibited by AS 46, Chapter 3, Article 7 and the regulations.prOmulgated .thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. ,~r. Robert T. Anderson Trading Bay Unit G-18 DPN -2- September I, 1983 To aid us in scheduling field ~rk, please notify this office 24 hours prior to comt.~encing installation of the blowout prevention equipment so that a representative of the Con-mission may be preg. ent to witness testing of the equipment before the surface casing shoe ig drilled. ~,~,ere a diverter systet,, is required, please also notify, this office 24 hours prior to commencing equipment installation ~o tha~ the Commission may ~i. tness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so t~,at ~e ~'--nay have a witness present. Very truly yours, C. V. Chatterton. Chairman of ,BY ORDER OF THE CO~MISSiON Alaska Oil and Gas Conservation C. on~m...ission , l~. be. 6:,~/A Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environ~nta! Conservation w/o encl. Union Oil and Gas Division: Western Region Union Oil Company -~,.,.-,;alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager August 31, 1983 Mr. Chat Chatterton Ak. Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska McArthur River Field, Grayling Platform Trading Bay Unit State G-18 Dpn. ADL-18730 (8-86-71-5755-601352) Dear Mr. Chatterton: Enclosed for your approval are three (3) fully executed copies of the above captioned Permit to Drill TBUS G-18 Deepening. Also enclosed is our Check No. 19264 in the amount of $100.00 to cover the required filing fees. Upon approval of same, we would appreciate a copy so that we may complete our files. Very truly yours, Robert T. Anderson / / sk Enclosures cc: $. R. Callender A. Lannin-O & G, Pasadena AUG AlasKa Oil & Gas Cons, Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COwfMISSION I='I=RMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS ~ SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE ~] 2. Name of operator UNION 0IL COHPANY OF CALIFORNZA 3. Address PO BOX 6247, ANCHORAGE, ALASKA 99502 4. Location of well at surface Conductor #42, Leg #2, 1884'N & 1378'W of SE corner, * At top of proposed producing interval ~,~ +3007'N & +3074'E of SE corner, A~totaldepth ~3037'N. & +3637'E of SL~corner, $~c. ~-~. ~Section ~, TgN, R13W, SM. -"// 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and ser'ial no. RT 99' MSL J ADL 18730 9. Unit or lease name TRADING BAY UNIT 10. Well number TBUS G-18 DPN 11. Field and pool McArthur River Field "D" Sands 12. Bond information (see 20 AAC 25.025) National Fire Insurance Company of Type Statewide Surety and/or number Hartford (B5534278) Amount $200,000.00 13. Distance and direction from nearest town NW 23 16. Proposed depth (MD & TVD) +9600' & +~290 19. I~--deviated (see 20 AAC 25.050) KICK OFF POINT feet. 14. Distance to nearest property or lease line miles +2300 feet 17. Number of acres in lease feet 3840 20. Anticipated pressures MAXIMUM HOLE ANGLE 37 o I(see 20 AAC 25.035 (c) (21 Proposed Casing, Liner and Cementing Program 15. Distance to nearest drilling or completed well +4000 feet 18. Approximate spud date 9/6/83 2930 psig~~ SurfaCe 3000 psig@ 6300 ft. TD (TVD) SIZE Hole Casing iL2 1/4 9 5/8 Weight 47# CASING AND LINER Grade ~p~g N-80 22. Describe 1. 2. 3. 4. :5. 6. 7. 8. proposed program: Length M D 2700 +5900 SETTING DEPTH TOP TVD 1+3900 I Drill 12 1/4" hole to +8600' MD (+6390' VD). Run logs. Run and cement 9 5/8" liner from 8600' to 5900'. Clean out to liner top and test same. Clean out inside of liner to float collar. Run gyro survey & CBL log. Squeeze if necessary. Test D-16 and D-17.sands individually and squeeze off. Perforate D-1 and D-2 sands. Set "DB" packer between D-9 and D-10 sands and test. MD BOTTOM TVD tSEOO ',+639o I I I QUANTITY OF CEMENT (include stage data) 1000 sxs cl "G" RECEIVED Alaska 0i! & Gas Cons. Commission Anch0ra§e 23. I hereby ~~s,tru/~to the best of my knowledge SIGNED Robert T. A TITLE District Land Manager ~-~e~~ fo-~ Commissio-----~---~ use DATE 8/31/83. CONDITIONS OF APPROVAL Samples required Mud Icg required Directional Survey required I APl number LYES ~NO E}YES ~NO ~YES E~NO I 50-- ~-~.0/ 60 Permit number ,~ Approval date cove, APPROVED BY/ Z/~///~MISSIONER DATE~eptet:Qber 2, 1983 ~.-/'~_ '/ t ~~~/'~) by order of the Commission -- Form 10~01 Submit in triplicate Rev. 7-1-80 TBUS G-18 DPN PERMIT TO DRILL AUGUST 30, 1983 22. PROPOSED PROGRAM: (continued) 10. Set model "D" pecker below D-2 sand and test. 11. Run dual 3 1/2" tubing with dual packer in 13 3/8" csg and single hyd packer above D-2 sand while stabbing into "D" packer. 12. Flow D-1 and D-2 sands end test D-2 sends. Release rig. 13. Close sleeve in long string and perf below "DB" packer in D-lO sand -test same. 14. Set plug in "DB" packer. 15. Perf D-9 sand and test same. 16. Complete well as a dual D-1 and D-9/D-iO completion. f RESENT TI3.U. G -18 PROPOSED 17 5/4", .341"Wall, Slip dt CASING at 600' 2:~/e'' COMPLETION STRING MODEL "D" PACKER W/SEAL ASSY. AT.5530' ..~690 - 57.~5' 5755'- 5800' D - / $1~ND D-/ SAND 13 ;/8,61¢', d-55,Seal-lock CASING at 6194' Set 95/8'',4T'/~' ,H'- 80 CASING nt RROX3' MD --DUAL 3~/2" COMPLETION STRINGS DUAL HYD. PACKER TOP D-/ S.4ND 5688' HYD. FACKER (' TOP D -2 SAND 6'£98' PERMANENT PACKER TO/:' D- 9 SAND 7291' PERMANENT PACKER TOP D-lO SAND ,7507' CEMENT RETAINER TOP D-/6 SAND 8t32' CEMENT RETAINER ' TOP D- 12' SAND 8408' f , CASING AND TUBING DESIGN WE,, T~US ~-IS FIELO CASING STRING ~ ~ ~' BOROUGH 1. MUD WT. I ~ #/_~ HYD GR. I ~7~ psi/ft. MUD WT. II #/q. HYD. GR. II 2. DESIGN BY psi/ft. M.S.P. psi ._ INTERVAL DESCRIPTION CASING SIZE Bottom Top LENGTH Wt. Grade Thread 1. ~ ~" 3~00~p $~me '27oo' q7.~E~ .,N-BO ,, ~m~s WEIGHT W/ BF W/O BFA" lbs ..... TENSION MINIMUM -top of STRENGTH section TENSION lbs 1000 lbs TDF COLLAPSE COLLAPSE PRESS. ~ RESIST. bottom tension psi psi ~o l ~ qs~oo CDF /.5 INTERNAL BURST MINIMUM PRESSURE YIELD psi psi BDF ~'/~ ~7~ OIL CONPA~ OF CALIFORNIA l ~ '~ - -I. I -. ~ --~ Noto~: All v~lu~ tn t~t,. D~pth~ sho~n or~ TYD. Clos~ 5128 ?tot N 78 da9 5gmin E Bottom hol~ TVO b'9~9 TMO B800 Mo§neti¢ declinotior~ 24 de§ 90 min £ HORIZONTAL vIEW UNION OIL COMPANY OF CALIFORNIA UNION T' B.U. G-18 -_ RADIUS DF CURVATURE SINGLE SHOT SURVEY SCALE: 1 inch: 1DOD ~eet Gas [~orLs: ~' - . ~HChot-O.Oa '-'OIDii]ls~;iur: DRAWN: 8-24-89 I· · . .. .5000 ~u~, ~ · ., G~ TE VA L'VE MOTE ' ALL CHANCES [,lUST HAVE WRIT.TEN APPRC',/&L BY THE DISTRICT ORILLIN6 SUPERI2tTENDENT t / ,, vo '~ 5 9 ',~ ~o G-18 DPN, ,~.~ ~ ~ BHL:, I ........ ~ 2 : ' ~G-4R '--.. / ' ~AfLI~ - - ~ - ~ ~ / ,o ~ / ~ s ~ ~',( ~ '~,~ ' < ~ * '- - ~ ~ .I, ~ ' -- ~ ' 14 k ~ VO I0 241 ' ! - ~ ~ ~,,. .... . '- . .. -... ~ ~v ~ 7' ~ / % ~ / ZI. ':'~ ~ .'-.:-%/ ~. ~ / ~~ ~/ ~ / ~' r ~ , ~ ~ .... ' k ' k vo~o 2e '~ ", i / ~ ~ ,~ ~ , ~ f~ Ii i ' r-- ,o.. ,. · . ~ ",X Z ', "' ~ / ~ "1. - Alaska District · ,' '~ ", i0 TD 10 800 ~ ~lO V ~ ~ ~ ~` 0~ T~ I '~ ~ i ~ ~ ~ 0 r~.~ -t~:,,, TRADING BAY UNIT : 'vD 9'6~7 ~ ~ ~' , VD 9923 ~ G-3 RD 'e, ", ~,/ '~ /v~ ~,~, McARTHUR RIVER FIELD ~ ~ ~ 9 722 ~ ,,~ D_~O'~ j ~, I ~ ~ GRAYLING GAS SANDS ~~-2e + ," " /' .~ ~ STRUCTURE CONTOURS 1000 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Company~ Lease & Well No, YES NO REbIARKS (1) Fee / (2) Loc//~x,'~ 1 Is the permit fee attached · 2. Is well to be located in"a defined pool ................. ' : ~'~'~~-z 3. Is well located proper distance from property line .~ .... ~.~~.~__~ 4. Is well located proper distance from other wells .................... 5, Is sufficient undedicated acreage ava. ilable in this pool ....., ,, . 6. Is well to be deviated and is well bore plat.includ, ed ,. '~''] ' [ 7. Is operator the only affected party ................ 1,. 8. Can permit be approved before ten-day wait .......................... ~.--__ (3) Admin.(.~-,,-thru '-[i2 thru 20) (5) BOPE f-,3/-f3 ~'~1 thru 24) 0 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20, 21. 22. 23. 24. Does operator have a bond in force ............................. ~ d Is a conservation order.,neede ...................................... Is administrative approval needed ................................... Is conductor string provided ...................................... Is enough cement used to circulate on conductor and surface ...... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons .................. Will surface casing protect fresh water zones ............. Will all casing give adequate safety in collapse, tension Is this well to be kicked off from an existing wellbore ..... Is old wellbore abandonment procedure included, on 10-403 . .. Is adequate well bore separation proposed .... ............ Is a diverter system required ........ Are necessary diagrams of diverter';~'~ ;~i~;~;';;;;;h;d Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (Feb.78) .................. 25. Additional requirements Additional Remarks: ~/ mm ,.ring Geology,: Engi_~: HWK / LCS ,~~BEW f / rev: 12/06/82 INITIAL GEO. UNIT ON/OFF [ ?OOL CLASS STA.T.US,. AREA NO. SHORE f f V ,,-- Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effod has been made to chronologically organize this category of information. LIS TAPE VERIFICATION 6ISTIN~ LVP O~O,H02 VERIFICATION L~$TING PAGE ** REEL HEADER SERVICE NAME ~VOtAN DATE :83/10/10 ORIGIN ~ · REEL NA}~E . ~RE~L ID CONTINUATION # PREVIOUS REEL COMMENTS ~REEL COMM~NT~ ** TAPE HEADER SERVICE NA~E DATE O~IGIN ~6960 TAPE NA~E CONTINUATION # :01 PREVIOUS TAPE : COMMENTS :TAPE COMMENTS ********** EOF *******~** ** FILE HEADER ** FILE NA~E :VOLAN ,00~ SERVICE NAME : VERSION # ~ DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILM ** INFbRMATION RECbRDS ** MN~M CONTENTS c. , IbN nI , ch. W. ~ G-18 DPN FN ~ MCARTHUR R IV~]R RANG: TOWN: gM SECT~ CouN~ ~0, SLbPE ST~T~ ALASKA CTRY: USA MHEM CONTENTS PRES~ DWSNOgF ** RECO~D TYPE 047 ** UNIT TYPE CATE SIZE C~DE 000 000 0~8 065 000 000 0~8 065 000 000 0~4 065 000 000 004 065 000 000 002 065 000 000 002 065 000 000 0~0 065 000 000 006 065 000 000 004 065 TYPE CATE SIZE COD~ 000 000 007 0~5 bVP OlO,H02 VERIFICATION L~STING PAGE ** RECORD TYPE 047 ** ** RECORD TYPE 047 ** ** RECORD TYPE 047 ** ** C~EMTS ** ******************************************************************************* ******************************************************************************* *** *** *** THREE PERM vOLAN *** *** *** *** *** ******************************************************************************* ******************************************************************************* , * cOMpANY NAME :UNION OIL CO~'PAMY OF CALIFORNIA * * WEI, L NAM~ :G-t8 DPt~ (]2X-28) FIEI, D :MCARTHUR RIVER , * JOB NUMBER AT ~0C:68607 STATE ~ ALASKA , * DATE WELL LOGGED %~9 SEP ~3 COUNTY , * DATE L~G COMPUTED:2 OCT RI LOGGING ENCINEERiVOSS * * b0~ DATA PROCESSOR:N/A LOG ANALYST :RAY NOLD * * BASELINE ~10.404 * , ~VP O~O,H02 VERIFICATION LISTING PAGE 3 , RM~i'.59 PMFI~.~5 MUD TEMPERATURES75 EHT~128 B8112.25 * ,/////////////////////////////////////////////////////////////////////////////* ~\\\\\\\\\\\\\\\\\ ALASKA DIVISION CONPUTING CENTER \\\\\\\\\\\\\\\\\\\~ ~/////////////////////////////////////////////////////////////////////////////~ ~\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\\~ DATA FORMAT RECORD ~ ENTRY BLOCKS TYPE SIZ~ REPR COD~ ENTRY 4 1 66 ~ 8 4 73 60 9 4 65 ,lin 0 ! 66 0 DATU~ SPFC~FTCATION Bb~CKS MNEM S~RVICE SERVICE UNIT API API ADI ~P! FILE SIZE PROCESS SAMPLE REPR II) ORDER # LOG TYPE CLASS MOD NO. bEVEL CODE DEPT FT 0 0 0 0 0 4 0 CAbI PRE IN 0 2~ 3 0 0 4 0 DCAL PRE IN 0 0 0 0 0 4 0 DT PRE US/F 0 5~ 32 0 0 4 0 GR PRE GAP! 0 3~ 32 0 0 4 0 PHIX PRE PU 0 0 0 0 0 4 0 PHS PRE PU 0 0 0 0 0 4 0 PDS PRE PU 0 0 0 0 0 4 0 RH~X PRE G/C3 0 0 0 0 0 4 0 RHOB PRE G/C3 0 35 ! 0 0 4 0 RT PRE OH~M 0 0 0 0 0 4 0 RMFA P~E OHMM 0 0 0 0 0 4 0 RNA PRE OHMM 0 0 0 0 0 4 0 RWSP PR~ OHMM 0 0 0 0 0 4 0 SP PR~ MV 0 i 0 0 0 4 0 AFLG 001 0 0 0 0 0 4 0 HVOL 00! PU 0 0 0 0 0 4 0 HWT OOi PU 0 0 0 0 0 4 0 PHIE 00! PU 0 0 0 0 0 4 0 PSXO OOl PU 0 0 0 0 0 4 0 RO 001 OHMM 0 0 0 O 0 4, 0 RHGA 001 G/C3 0 0 0 0 0 4 0 ROHY 001 G/C3 0 0 0 0 0 4 0 68 68 68 68 6B 6~ 68 6B 6~ 6O 68 68 6R 68 6B 68 68 6B 68 LVP 0'10.H02 VERIFICATION SBCw 001 plJ SBEP 00! PU SBEX 003 PU SBGP 001. PU SBG~ O01 PU SBND 001 PU SBSP 001 pu SW 001 PU SWB 002 PU SXO 001 PU VCL 001 PU VDCL ~01 PU VDOL o01 PU VSH 002 PU VSND 001. PU KGAS 001 ~O KHYD 001 MD KINT 00! MD KOIL 001 MD K~TR 001 MD PHIT 002 PU PSW 002 PU RKG OOl PU ~go 001 PU RKW 001 PU 'PHIX 002 PU ** DATA ** DEPT RH~X HVOL RO SBEP 8BND SXO VSM KINT PSW PHIX DEPT GR RH~X RWA HVOL RO SBEP SBND SXO VSH 8~60,0000 174.5939 231,7 .0.0000 39 1569 -999,2500 100.0000 1000000 98 8680 0 001,0 1. 1320 11 5099 BO00..0000 5381 .3 73 !00 0000 ,,oo:oooo 96,6774 CALl PHIX RHOB RWSP HWT RHGA SBSP VC[, VSND KOIL RKG CALl PHI X RHOB RWSP SBEX SBSP VCL VSND o 0 o 0 o 0 0 o o o 0 0 o o 0 0 0 0 0 0 o 0 0 0 0 0 99. 98. 0, 2. 84. 73, 731,8 8789 7632 3691 0000 O570 0356 711.1 8680 2500 0010 0000 7486 6820 4692 644.3 0000 8373 5910 8177 2134 2500 0 0 0 0 0 0 0 0 0 0 0 0 0' 0 0 0 0 0 0 0 0 0 0 0 0 DCAL PN$ RT SP PHIE POHY 'SBGP SW VDCL KGAS }<WTR RKO P~IS RT SP PHTE RONY SBGP SW VDCL {<GAS 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0. 0 -0. 41, 5, ~0'~ -999. 100. 100, 89, 0, 0, 0, -999. lO0, 100. 45, O, 5182 8188 ~192 1250 132o 2500 0000 0000 0492 0010 0010 0000 501.4 0191 3896 5000 2193 2500 0000 0000 3935 0010 DT PDS RMFA AFI,,G PSXO SBCW SBGR SWB VDOL KHYD PHIT RKW DT PD$ RMFA AFLG PSXO SBCW SBGR VDOL KHYD PAGE. 1 68 1 68 1 68 I 68 1 68 I 68 1 68 1 68 1 68 1 68 1 68 I 68 1 68 1 68 ! 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 I 68 86,5625 -6,A591 '999.~500 0, 000 1,1320 0.0000 100,0000 89,662~ -999.2500 0,0010 0.9508 10,0000 86 5625 o! 14 0 0000 1,2193 83 2546 100:0000 93,~154 -999. 500 0,0010 hVP 010.H02 P$~ PH~X DEPT ~R RHGX HVOL R0 SBND SXO VSH KINT GR R0 SBEP SBND VSH KINT PH~X DEPT GR RHGX HVOL R0 SBMP SBND SXO VSH KINT PSW PHIX GR RHGX RWA RO SBEP VERIFICATION L%$T~G 0.0010 1.2193 20,0392 ~700.0000 47.4204 2.7279 0.4506 4.2025 5.4503 -q99.2500 42 i477 67!. 598 37 409 0.2122 R.4527 17.8121 8600.0000 I 1645 5 ':7578 0.7710 3561 -999.2500 37.7450 48.6175 44 6382 3i4333 8 0911 26 5931 8500 0000 54i0650 2 7460 0 7076 9!9238 1 6860 -999.2500 39.6526 35.2948 48 5553 219719 4 4208 23 9271 8400 5O 2 3 14 3 -999 4 0000 2779 6675 6728 8381 5796 2500 7603 RKG CALI PHIX RHOB RWSP HWT RHGA SBEX SBSP VCL VSND KOIL CALI PHIX RHOB RWSP HwT RHGA SBSP VCL VSND KOIL RKG CAL! PHIX RHOB RWSP HWT RHGR SBEX SBSP VCL KOIL RKG CALI PHIX RHOB RWSP HWT ~HGA SBEX SBSP O.0010 0.0000 11.6875 1R.1972 2.4135 0.2952 2.9884 2.7155 20.3272 0.0000 20.0132 92.5172 0.0301 0.5401 11.7392 27.1746 2.2801 0.6758 6.7995 2 7439 27:3936 45 1'149 2~8700 100.0000 0 6950 1:1634 1.19609 24[3767 2 3204 0 5662 7i0570 2 7356 26,4808 40 8898 28~3319 100 0000 0!4490 3 9604 12 1059 24:367! 2,2612 0,63J9 9,9961 2 6823 214.187 19 3388 KWTR RKO DCAL PNS RT SP ROUY SRGP SW VDCL KGAS KWTR RKO PNS RT SP PH%E ROHY SRGP SW VDCL KGAS KWTR RKO D C A L P N S RT SP PHIE POHY S B G P SW YDCL KWTR RKO DCAL RT SP PHIE ROHY SBGP SW 0.0010 0.0000 -0.5625 23,5480 10,8936 -3i.2500 13,0754 -999.2500 40.4666 64.6458 15.4406 0.0011 0.0010 14,2840 -0.5108 33.4855 7.8708 -12.7500 18.6092 0.7111 9.0636 43.4793 20.8860 0.0399 0 0010 20~2424 -0.3891 30,4419 9.1241 -16.3750 15,~370 O. 111 22.8752 28.8243 19'7419 0.1177 0.0010 15,1094 -0'1441 25,6628 47.3977 '14,2500 20,4471 0.6737 17.6432 20,1748 PHIT RKW DT PD$ RNFA AFLG PSXO SBCW SBGR SwB VOOb KHYD PHIT RKW DT PDS RMFA AFLG PSXO SBCW SBGR SWB VDOL KHYD PHIT RKW DT PD$ RMFA AFI. G PSXO SBCW SBGR SWB VDO5 KHYD PHIT RKW DT PDS RMFA AFLG PSXO SBCw SBGR SWB PAGE 20'0392 0,O000 83'9375 14,3358 0,5505 29,17 25.9099 0.0000 0.0750 6480 1 ~0000 99,6875 2~.4159 ,8485 .:oooo 091.1 30,8994 37,3142 30,0227 !oooo 9405 931 20.~000 97 0000 87 0 0000 4 4208 37 6828 43 6196 35 9009 0 0000 2i1152 23 9271 0 0000 95 2500 23:5656 3,1787 0 0000 4:1251. 11,7632 35,3867 13,2595 VERIFICATION LISTING PAGE 6 sxo 27 4316 vct, vsH 19: 7522 KINT 5~.5~21 PSW 4.%251 RKG PHIX 24,3570 DEPT 8300.0000 CALI GR 68.9054 PHIX RHGX 3.0355 RHOB RWA 0.9997 RWSP HVOL 0.0000 HWT RO 6.4376 RHGA SBKP -999.2500 SBEX SBND 100.0000 $BSP SXO 100.0000 VCL VSH 92,0392 VSND KINT 0,0010 KOIL PSW 3.1843 RKG PHIX 24.8490 DEPT 8200 GR 109 RWA 0 HVOL 0 R0 9 SBEP -999 SBND 100 SXO 10o VSH 99 KINT 0 PSW 0 PHIX 22 DEPT 8100 GR 109 RWA HVOL 0 R0 5 SBEP -999 SBND 80 SXO 100 VSH 86 KINT 0 PSW 5 PHIX 31 DEPT 8000 GR 61 RH~X 2 RWA 0 HVOL 0 RO 8 0000 CA[,I 1057 PHIX 9568 RHOB 8052 RWSP 0000 HWT 6852 RHGA ~500 SBEX 0000 $BSP 0000 VCI. .6243 VSND .0010 KOI5 .1503 RKG .4641 0000 CAL! 4175 PHIX 9535 RHOB 0849 RWSP 0000 HNT 2160 RHGA ~500 SBEX 11~6 SBSP 0000 VCL 5298 VSND 0010 KOI5 3881 RKG :7563 .0000 CALI .9039 PHIX ,8063 RHOB 3843 RWSP 0000 RWT 9125 RHGA 10.6108 VDCL 100.0o00 KGAS 2~.7529 KWTR 0.2254 RKO 14.0562 DCAL 28.1428 PNS 2.4626 RT 0.9547 SP 0.0000 PHIE 2.9463 ~OHY 8R.2843 SBGP 85.7317 SW 89.1361 VDCL -999.~500 KGAS 0.00~0 KWTR 0.0000 RKO 13.7781 DCAL 25 8911 PNS 2i4502 RI 1 19RO 0 0000 2:8703 ROHY 1.0~.3863 SBGP 91.6236 SW 74°0845 VDCL 9,2500 '990.0010 K~TR 0,0000 RKO 14,B14! 33 4161 2 3007 0 5519 0 0000 2 9836 1:01, 4360 37, 1,288 73:9902 -999.2500 0.0010 0.0000 13.0437 23 3467 2 3846 1 ~701 0 000 2 7769 DCAL PNS RT SP PHIE ROHY SBGP VDCL KWTR RKO DCAL PNS BT $P ROHY 7.4852 0.1320 0,0010 49.0981 1.8062 47.~.146 9.4648 -6.6500 3,1843 -999.2500 44.0038 100,0000 67.4714 0.0010 O,O010 0,0000 1,5281 39.5484 9.1201. '2.9000 0.1503 '999.2500 100.0000 100,00O0 51.7707 0,O010 0,0010 0,0000 2.5641 49,2255 7.1001 -17.2857 5,3881 -099.2500 83.0233 100,0000 49.9735 0,0010 0.0010 0,0000 0.7937 31.9699 5.4379 -4 9464 11i3447 -999 2500 VDOL KHYD PHIT RKW DT PDS RMFA AFt. G PSXO SBCW VDOL KHYD PHI? RKW PT PDS RMFA AFLG PSXO 8BCW SBGR SWB VDOL KHYD RKW PDS AFLG PSXO SBCW SWB VDOL KHYD PHIT RKW DT PDS RMFA AFLG PSXO SBCW 9 1 lO 7 8 -99 2 9 10 9 -99 2 0,0000 46.7473 23.5727 0,0000 3,5625 1,3547 0,5638 0,0000 3,1843 0,0000 5,8814 7.1853 9,2500 0,0010 4,8490 0,0000 0 7500 2 1100 0 8632 0 0000 0 1503 1 4703 OiO000 9 3310 9 2500 0~0010 2,4641 0.0000 105 0000 21i1690 1 2474 0 000O 5:3881 100,0000 100,0000 81,6762 '999.2500 0 0010 29:4048 0,0000 99.7500 16,0845 0.4087 0.0000 11 3447 0:0000 }JVP ~10,H02 VERIFICATION LISTING PAGE 7 SBEP -999.2500 SBEX SBND 65.2406 SBSP S×O 100.0000 VCI. VSH 64 0184 VSND , KINT 0.0010 KOIL PSW 11.3447 RKG PHIX 2~,0790 DEPT 7~00.0000 CALl GR 74.2568 PHIX RHGX 2,8090 RHOB RWA 0.5012 RWSP HVO[, 0.0000 HWT RO 8.2595 RHGA SBEP -999,2500 SB~X SBND 62'5385 SBSP sxo 100:00o0 VCL VSH 66,4791 VSND KINT 0,0010 KOI[, PSW 11 0253 RKG DMPT 7800 GR 53 RWA 0 HVOL 4 R0 5 SBEP -999 SBND 31 SXO 67 VSH 44 KINT 0 PSW 9 PHIX 21 DEPT 7700 ~R 50 HVOb 0 R0 23 ~BND 100 sxn 100 VSH 68 KINT 0 PSW 5 PHIX 11 DEPT 7600 GR 68 RHGX 2 RWA 5 0000 CAL! :7958 PHIX ,7179 RHOB .6108 RWSP ,6124 HwT .5025 RHGA 2500 SBEX i 9639 SBSP 4248 VCL ,7838 VSND .1549 KOIL ,0856 RKG ,7607 0000 CALI :68 6 P.zx ,7694 RHOB .3486 RWSP 0000 HWT 7]07 RHGA ~500 SBEX 0000 SBSP 0000 VC[,, 6917 VSND 0010 KOIL 0201 RKG 9844 ,0000 CAI, I 5690 PHIX .i594~ RHOB 2231 r~sp 46,8040 80.8453 40,7069 99.9996 0.0010 0.O000 12.7031 24,3301 9.3689 1,0201 0,0000 2,7785 46,1463 77,3782 41.9796 100.0004 0.0010 0,0000 12,953! 21.8447 2.3387 0.6670 2 9076 2:7182 17,4861 50.0238 23,5457 lO0,O000 0,0010 17,6~96 1.5 0675 13 2106 ~ 5356 0 6030 0 0000 .2 7447 34 1541 58!1257 32 22.31 -999,2500 O,OOlO 0,0000 19.6063 58.2855 1.6568 1.0683 SBGP VDCL KGAS KWTR RKO DCAL PNS RT 8P PHTE SW VDCL KWTR RKO DCAL PNS SP SBGP VDCL KGAS KWTR RKO DCAL PNS RT SP ROHY SB~P VDCL KGAS Kw~rR RKO DCAL PN$ RT SP 45,2705 100,0000 29,9725 0,0010 0,0010 0,0000 0.4531 32,9235 6,4889 -5,8571 11.0253 -999,2500 6~.5651 100.0000 29.9722 0,0010 O,O010 0,0000 0,7031 26,5368 9.9700 -13 7500 -999.2500 3162 16,221.4 0,0273 0.0010 0,1940 2.81.75 20.3198 16.7761 -15.8565 ., 5.0201 -999.2500 100,0000 l. O0,O000 25.2588 00010 0:0010 0.0000 7.3563 66.5782 10,3362 -5.3380 SB~R SWB VDOL KHYD PHIT RKW DT PD~ RMFA AFLG PSXO SBCW SWB VDOL KHYD PHIT RKW DT PDS AFLG PSXO SBCW VDOL KHYD PHIT RKW DT POS RMFA AFLG PSXO SBCW VDOL KHYD PHIT RKW DT PDS R~FA AFLG 60 6606 8 6~79 4O 0000 0 0010 22 0790 0.0000 98.6250 7,0382 10,5548 0,0000 11,0253 0,0000 87,5147 52,1320 0,0000 0,0010 23,0327 0,0000 96,1875 18,8661 0,6801 0 0000 .9~0856 35 8250 43 0344 3~ 0928 0000 0 0555 21,48~7 0.0000 6 9327 013343 0 0000 5 ~201 13 811 58 111 -999 500 0 0010 11!9844 0 0000 1.24.5625 60,1966 6,7682 -999,2500 LVP ~lO,H02 VERIFICATION HVOL RO ~BEP SBND SXO VSH KINT PHIX DEPT HVOL RO SBEP SBND VSH ~INT PSW PH~X DEPT gVOL RO SBEP SBMD SXO VSH KIMT PSW PHIX GR RH~X RWA HVOL RO SH~P SBND SXn VSH KINT PHIX DEPT GR 0.0000 -999.2500 -999.2500 -999.2500 100.0000 100.0000 0.0010 0,0000 62.6047 7500 0000 55:9562 2.9246 0.2067 0.0000 45.4194 -999 2500 22~3003 100,0000 40,7313 08I)0 7 1654 7400.0000 84,5751 2,8386 0,4472 0 0000 4 2551 -099 2500 66 3346 100 0000 86 6527 020010 5 3389 2414684 7300,00 51,09 ~.73 0.67 3,g4 4 O9 -999 25 32 92 67 41 40 97 0 1,2 7 76 25 7200"0000 8~,.3846 O0 79 21 84 44 04 O0 25 52 92 89 6'2 63 HwT RHGA S~X SBSP VCL VSND KOIL RK~ C&t,I PHIX RH08 RWSP' HWT RHGA SBEX SBSP VCt, VSND KOIL RKG CALI PHIX RHOB RWSP HWT RHGA SBEX SBSP VCL VSND KOIb CAI, I PHIX RWSP RHGA SB£X SBSP VCL VSND KOIL ¢~I,,I PHIX LISTING 0.0000 PHYE -999.2500 POHY -999,2500 SRGP -999.2500 SW 100.0000 VDCL -999.2500 KGAS 0.0010 KWTR 0.0000 RKO 14.8344 DC~L 10.6055 2.7205 RT 0.6946 SP .0000 FHIE .8945 ROHY 83.3976 SBGP 66.4332 6.9883 VDC{, 0.0000 KG~$ 0 0010 KWTR 0~0000 RKO 16 0562 DC~L 26ii534 PNS 2 3577 RT i,3837 0,0000 PHIE 2 8239 ROHY 5223225 SBGP 98,8120 Sw 58.9339 VDCL -999 2500 KGAS 0i0010 KWTR 0 0000 RKO 15,2250 25 4358 2 2915 0 6623 ~ 8049 2 7010 1.7 8848 59.1484 18,4976 100.0000 0.0010 18.6837 18.6602 50.8199 DCAL PNS RT SP PHIE ROHY 8BGP VDCL KGAS KWTR RKO DCAL PNS 0.0000 PSXO -999.2500 SBCW -999.2500 SBGR 100.0000 SWB -999.2500 VDOL 0.0010 KHYD 0.0010 PHIT 0.0000 RKW 2.5844 DT 26.0390 PDS 15.9543 RMFA -13.2500 AFLG 5.0R00 PSXO -999.2500 SBCW 100.0000 SBGR 100.0000 SwB 3,8250 VDOL 0,0010 KHYD O,00i0 PHIT 0.0000 RKW 3,8062 DT 35,6136 PUS 4.9568 RMFA '1,2500 AFLG 5,3389 PSXO '999.2500 SBCW 72.1346 SBGR 100.0000 S~B 39,8044 VDOL 0.0010 KHYD 0.0010 PHIT 0,0000 RKW 2.9750 DT 30,8677 PDS 7.9828 RMFA -14 ~750 AFt, G psxo -999 2500 SBCW 4618134 SBGR 64 1567 SWB 12,6970 VDOL 0 148t RKW 6.4102DT 65.8012 PDS PAGE -100,0000 ~999.2500 999.2500 0,0000 -999,2500 0010 :oooo 0.0000 61 0625 -412732 0,2541 2,0000 5,0800 0,0000 47.7309 38.3740 84.02{6 0.0010 8.2432 0,0000 101,1875 17,7138 0.5322 0,0000 5,3389 84,3620 lO0,0000 78,1804 -999.2500 0 0010 24!4684 0 0000 78.0625 21,~269 o. 0,0 0 7,7662 33,9295 37,1693 3955 :oooo 0 0462 1729058 0.0000 120.8750 46.8239 LVP ~10"H02 VERIFICATION LISTING PAGE 9 RWA 4 HVOL 0 RO 11 SBEP -999 SBND -999 SXO 100 VSH 99 KINT PSW 0 PHIX 53 OEPT 7100 GR 59 ~HGX 2 RWA 0 HVOL RO SBEP -999 SSND 40 SXO 91 VSH 44 KINT PSW 15 PHIX 24 DEPT 7000 ~R 88 RHGX 2 RWA 0 HVO[, 0 RO. 7 SBEP '999 SBND 68 $'XO 100 VS~ 96 KINT 0 PSW PHIX : 2 DEPT ~900 GR 96 RH~X RWA 0 HVO[, 0 RO 8 $BgP -999 SBND -999 SXO 100 VSH 93 KINT 0 PSW 1 PHIX 19 ~7841 3452 ,nO00 ,2504 ,2500 ,2500 ,0000 ,7207 ,OOlO ,t078 ,9852 0000 ~7333 7506 . ,2570 ,4773 ,7465 .2500 5988 3037 1082 2248 3623 1839 0000 .8083 5606 :oooo .5083 .2500 5302 :o000 ..0010 4386 :.4231 ,0000 ,6000 ,7976 0000 8610 :25O0 2500 iO000 7384 0010 ,7934 ,6155 RWSP HWT RHGA SBEX SBSP VCL VSND KOYL RKG CAI, I PHIX RHOH RWSP HWT RHGA SRF, X VCL VSND KOIb 1,8774 RT 1.4330 SP 0.0000 PHTE 2.8365 ROHY 36.6785 SRGP 9R.9026 SW 65.7453 VDCL -999,2500 KGAS 0,0010 KWTR 0.0000 RKO 14 0531 DCAL 24i6887 PNS 2 31A4 RT 0,2125 SP 1,0505 PH~E 2,7389 ~OHY 31,7765 SBGP 0,0000 SW 27.6265 VDCL 100,0004 KG~S 0,0010 KWTR 0.9879 RKO CALl 16,8901 DCAL PHIX 22,7250 PNS RHOB 2,3973 RT RWSP 0,8243 BP HWT 0,0000 PH~E RHGA 2,8246 ROHY SBFX 60 ~467 SBGP $BSP 93:~819 SW VCI., 6~, 5680 VDCL VSND -999,2500 KGAS KOIL 0 0010 KWTR RKG 0:0000 RKO CAI.,! PHIX RHOB RWSP HWT RHGA $BSP VCl0 VSND K C) ! l, 21.7142 DCAL 19 8374 PNS 1,6446 SP 0,0000 PHTE ~.,7919 ROHY 55,~446 SBGP lO0 0000 SN 51]8254 VDCL 9 2500 KGlS '990.!0010 KWTR 0 0000 RKO 11.5460 -0.8750 0.1078 -999,2500 89.8813 100.0000 44.4049 0.0010 0.o010 0,0000 2.7o31 30.9258 3.2245 -42,2500 16,9873 '999,2500 31,5336 90.4340 20.4299 0.0~! 0,4035 0.0o00 4.6401 31.5041 8.4053 -10.5000 1.4386 -999,a500 100,0000 41,5835 O,OOlO 0,0010 0,0000 9,464.2 28 4.342 7:7935 1.0000 1,7934 '999,2500 100,0000 100,00o0 35,0033 0,0010 0,0010 0,0000 RMFA AFLG PSXO $BCW SBGR VDOL KHYD PHIT RKW DT PDS RMFA PSXO SBCW SBGR VDOL KHYD RKW DT POS RMFA AFLG PSXO SBCW SBGR SWB VDOL KHYD PHIT RKW DT PDS RMFA AFLG PSXO SBCN SBGR VDOI~ K HYD PHIT RKW 6,1108 1,0000 0,1078 100,0000 100,0000 99,4976 -999,2500 0,0010 21,4482 0,0000 104,2500 20,0979 0.3141 0,0000 15 3623 3011058 55,9419 29,7577 0 0000 010017 24,1839 32,9433 103,1875 15 3134 0:7645 0,0000 1,4386 95 ~151 100 000 .993 2849 gg 2500 000lO .21,4231 0,0000 98,5000 12 6648 o: so 0.0000 ! 7934 ~7!3608 100 0000 90,3663 -999.2500 0,001.0 18,6155 0,0000 LVP DE.PT RHGX H¥OL R0 SEND SXO VSH KINT PSW PHIX DEPT GR RHGX HVOL RO SEEP SEND SXO KINT PSW PHIX DEPT RHGX gVOb RO 8B£P S 8 N D SXO KINT PSW PHIX DEPT RH~X HVOL RO SBE, P SEND SXO VSH KINT PSW ~lO.H02 VERIFICATION 6_R00, 97. 2. 0. 999. 100. O. O' 21: 6700. 105. 2, 0,. -099.. -999. 100. 98. O. O. 6600'. 111. 2. 0 0 7 -999 100 1,00 8. 90, O, 6500' 37 44. 0 -999 -999 -999 100 0 0000 CAI, I 7710 PHIX 9154 RHOB 5424 RWSP 000O HWT 7326 RHGA 2500 $BEX 2500 SBSP 0000 VCL 1511 VSND 0o10 KOIL 7396 RKG 9834 0000 CALI 8659 PHIX 9157 RHOB 4660 RWSP 0000 HWT 7873 RHGA 2500 $REX 2500 SBSP 0000 VCL 4365 VSND 0010 ~OIL 5674 6441 0000 CAI,I 7703 PHIX 9829 RHOB 7689 RWSP 0000 NUT 9964 RHGA 2500 $BEX 0000 SBSP 0000 VCL 9581 VSND 0010 KOIL 4168 RKG 2619 00o0 CALI 6223 PHIX 4398 RHOB 5355 RWSP 0000 HWT ~500 RHGA 2500 SB~:X ~500 SBSP 0000 Vel.. 0000 VSND 0010 KOIL 0000 RKG LISTING 18o 24. 2. O. O. 2. 88. 94. 67. '999. O. O. 20. 21. 1 o: 2. 92. 100. 66. -999. 0. 0. 17. -999. 0, 0. 22. 66, -999. 999 lO0 O, O. 5812 7670 4410 9306 0000 8470 5892 0230 8286 2500 o010 0000 2797 55O6 5028 7775 0000 8472 2679 0000 6976 2500 0010 0000 9875 4621 4]84 6110 000o 8992 5591 0917 0275 2500 0010 0000 5469 3863 4487 0687 0000 2500 2500 2500 0000 2500 0010 0000 DCAL PN$ SP PHIE ROHY 8BGP SW VDCL KGAS KWTR RKO DCAt, PNS RT SP ROHY SBGP Sw VDC[, KC, AS KWTR RKO DCAb PN$ SP PHI E [~OHY SBGP SW VDCL ~ GAS RKO PHS RT SP PHIE POHY SBGP VDCI, KWTR RKO 6.3312 37.3564 6.7588 -8.5000 0.7396 -999.2500 100.0000 100.0000 46.5848 0.0010 0,0010 0.0000 8.0297 34.6890 7.8316 2.0000 0.5674 -999.2500 100.o000 100.0000 48.6209 0.0010 O.OOlO 0,0000 7.6730 -16.7066 0,4168 -999.25o0 100,0000 IO0.OOO0 57,1824 0,0010 0,0010 0,0000 10'2969 73.5907 3750 0..,0000 '999,2500 -999.2500 100 000 -9 o: oo 0,0010 O,0010 0,0000 DT PDS RMFA AFLG PSXO SBCW SWB VDOL KHYD PHIT RKW DT PDS R~FA AFI, G PSXO SBCW SBGR SWB VDOL KHYD PHIT RKW DT PD$ RMFA AF[,G PSXO SBCW SBGR SWB KHYD PHIT RKW DT PDS RMFA AFLG PSXO SBCW SBGR VDOL KHYD PHIT RKW PAGE 97.1250 12.6665 0.6375 0.0000 0.7396 92.0590 100,0000 96.6358 -999.2500 0.0010 21,9834 0,0000 96.3125 B,glg9 0.4979 0.0000 0.5674 87.2429 100.0000 96 9568 -999:2500 0,001.0 18.6441 0,0000 94..5000 2 8254 1018030 0000 4168 97 6911 100 0000 9B 2822 ~g99 2500 0 0010 24 2619 0'0000 125.7500 72 8031, lB ~189 -ggg 500 -100 0000 -999 2500 -999 2500 0 0000 -999 2500 0 0010 0 0000 0 0000 10 LVP 010,H02 VErifICATION LISTING PHIX 73,1003 DEPT 6400. GR 75 RWA 0 HVOt m0 RO SBEP 999. SBND ~XO 100, VSH 96 KINT O, PSW PHIX 21. 0000 OALI 9124 PHIX 9585 RHOB 5140 RWSP 0000 NWT 4397 RHGA 2500 SBEX 2500 SBSP 0000 VCL 0117 VSND 0010 KOTb 5953 RKG 5482 21.0719 25.1513 2.4659 1.5443 0o0000 2.8686 103,2420 99,7801. 71.9140 -999.2500 O.OOlO 0.0000 DEPT 6300, GR 46, RwA NVOL 16, RO SBEP -gA9, SBND 20. SXO 22, VSH 29, KINT 79., PSW 3. PHIX 26. 0000 CALI 4402 PHIX 7016 7997 RWSP 7014 HWT 0096 RHGA 2500 SBEX 5816 SBSP 6006 VCI. 7248 VSND 4287 KOIL 2067 RKG 9773 14.0688 26.9493 2.2430 0.4103 10.9533 2,7115 lO.03go 21.6114 1~.6224 ~.00 0000 46!0357 0 125t DEPT 6920. GR -999 RHGX -999 RWA 0 H'VO[, 0 RO -999 SB~P -999 SBND -999 SXO 100 VSH 0 KINT .-999i PSW -999 PHIX -999 0000 CAI,,i 2500 PHIX 2500 RHOB 000 RWSP 000 HWT 2500 RHGA 2500 SBEX 2500 SBSP 0000 VCL 'o000 VSND ~500 KOIL 2500 RKG 2500 1,2 -999 -999 1 0 '999 -999 -999 0 -999 -999 -999 ** FILE TRAILER FILE N~E :VOLAN ,001 SERVICE NAME VERSION # DATE ~ ~AXIMUM LENGTH : 1024 FILE TYP~ NEXT FILE blAME 2500 ~500 2500 4840 0000 250O 2500 2500 0000 2500 2500 2500 DCAL RT SP PHIE ROHY SBGP SW VDCL KGAS KWTR RKO DCAL PNS RT SP PHIE ROH¥ SBGP Sw VDCL KGAS KWTR RKO DCAL PNS RT SP PHiE ROHY SW VDCL }<GAS KWTR RKO 8,8219 38,6954 6.1971 -0,4511 1.5953 -999,2500 74.8677 100,0000 51,9611 0,0010 O,OOlO 0,0000 1.8188 30.7899 18.7029 -25.7772 21.5782 0.6558 0.72~8 14,8606 13.7027 0,0994 0.0010 57,9586 0 -999 15 -1 100 -999 -999 100 0 -999 -999 -999 0000 :2500 .5?66 2500 :oooo ,2500 ,2500 ,0000 ,0000 ,2500 ,2500 ,2500 DT PD$ RMFA AFLG PSXO SBGR SUB VDOL KHYD PHIT RKW DT PD$ RMFA AFLG PSXO SBCW SBGR SWB VDOL KHYD PHIT RKW DT POS R~FA AFLG PSXO SBCW SBGR SWB VDOL KHYD PHIT RKW PAGE 99,2500 1,1560 10.5448 0,0000 1,5953 88,6443 91,1139 92,5965 '999,2500 O,OOlO 21,5482 0,0000 157,5000 24.6667 2,1267 0,0000 3,2067 24,7301 27,0439 18,5661 0,0000 67 6251 26:4979 0,0000 123 5OOO 0 0000 0 0000 -999 500 100 ~000 -999 2500 ,-999 2500 0 0000 -999 2500 -999 ~500 -999:2500 -999,2500 ll i LYP 010,H02 VERIFICATION LISTING PAGE: 12 ** TAPE TRAILER ** ORIGIN :6~60 TAPE NAME . : CONTINUATION # :0~ NEXT TAPE.NAME : COMMENTS :TAPE COMMENTS ** REEL TRAILER ** SERVICE NAME DATE :83/10/10 ORIGIN ~ REEL NA~E . :REEL ID CONTINI)ATION # NEXT REEL. NAME COMMENTS :RE~b COMMENTS **~******* EOF ********** Up.. O]O.!~F2 Vi-:l~'[f.~f('A, Tfr'~',! I,'Iy, TII','G Il . . 1, : *, f f; F?C'f-:;., !"~ .,'t~' T. r'.~r.i !.? F;, C [3 t:;' D S ,** oo() r) O0 o 1 R 065 ,F)O0 000 009 065 000 000 004 065 000 000 002 0 65 0 0 0 0 0 0 O 0 2 0 ~ 5 C, (') 0 ~, 0 0 0 0 6 0 A 5 0 0 ~ 0 0 0 0 () 4 0 6 5 It:',: 1 q' TYPE CAr!,,, SIZE CODE, ~T~: F'T.TT T l'. T SC C~$.'I T Y 6R 6~ 6~ ,'uF'J 01('.',,~i~2 \'EPlT'IC;'~,rI.I'I~,., I.T,q',T'rl''~c; PAGE ,4 .t '.'! ~'~ r: Fi>t' c:':/C3 42 3'3 1 0 0 4 0 'C !" [, F'[" ?.' c' I:' g ~ ',; 3 4 q 3 ,n 0 4. 0 '~', T, T T." f) <' 1." ,1 ? ~ ~ 3 (; 0 4 0 i R ~. T F'I.7 ,"; ,1 ? ,.1 p l. f; O 4 ! :,~ R a f,' ~ r' ,ri ? 0 ,; o 0 4 0 !., . , ., .,. , -4 1 .'75r;0 0. '; 332 ~ ~ . 734,1: P 50 (7). 00 f) 0 0. ~ 73 2 F? !~, r') P, r,! ;~ ,zt t 7, ] '75 C', .T. [, :4 2. '7 <') ,! 2 T,?': P 4.6797 '1 t,.x c) 41 /t ti. f'; r:.' -qgc~. 25<)'.'; IL, l) . q o, 9.2 S 0 ,.'~ {) T . <~ e., g · ? 5 0 (" 3 . (? '13 !? 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